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206-074
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:Casey Morse To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:"BLM_AK_AKSO_EnergySection_Notifications@blm.gov" Subject:MIT SCU 42-05X 9-19-24 Date:Friday, September 20, 2024 9:58:58 AM Attachments:MIT SCU 42-05X 9-19-24.xlsx Attached is the report of MIT-IA on the Soldotna Ck Unit 42-05X (PTD 206-074) performed on 9/19/24. Witness was waived by AOGCC and BLM. Thank you, Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 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. 6ROGRWQD&UHHN8QLW; 37' Submit to: OOPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2060740 Type Inj G Tubing 3878 3878 3878 3878 Type Test P Packer TVD 7687 BBL Pump 1.0 IA 1380 2146 2128 2112 Interval 4 Test psi 1922 BBL Return 1.0 OA 370 370 370 370 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp Alaska LLC Swanson River Field / SCU / 42-05 Pad Andrew Smith / Taylor Malone 09/19/24 Notes:Witness waived by AOGCC and BLM Notes: Notes: Notes: SCU 42-05X STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2024-0919_MIT_SCU_42-05X 999 9 9 9 9 9 9 -5HJJ Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 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: 07/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230728 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-23 50133206350000 214093 7/16/2023 HALLIBURTON PPROF BCU-24 50133206390000 214112 7/15/2022 HALLIBURTON PPROF BRU 223-34 50283201880000 223041 7/9/2023 HALLIBURTON RMT3D KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON EPX KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON MFC KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON EPX KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON MFC KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON EPX KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/24/2023 HALLIBURTON WFL-TMD3D MPU B-34 50029235690000 216139 7/23/2023 HALLIBURTON WFL-TMD3D MPU B-50 50029232400000 204252 7/21/2023 HALLIBURTON WFL-TMD3D MPU E-23 50029225700000 195094 6/17/2023 HALLIBURTON COILFLAG MPU F-17 50029228230000 197196 7/2/2023 HALLIBURTON COILFLAG MPU L-13A 50029223350100 223017 6/21/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON RBT PBU 11-07 50029206870000 181177 6/28/2023 HALLIBURTON RMT3D SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON EPX SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON MFC SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON EPX SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON MFC Please include current contact information if different from above. T37886 T37887 T37888 T37889 T37889 T37890 T37890 T37891 T37891 T37892 T37893 T37894 T37895 T37897 T37898 T37898 T37899 T37900 T37900 T37901 T37901 SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON EPX SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON MFC Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.01 10:05:02 -08'00' MEMORANDUM TO: Jim Regg ,q P.I. Supervisor FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 22, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 42-OSX SOLDOTNA CK UNIT 42-05X Src: Inspector Reviewed By: P.I. Supry ' Comm Well Name SOLDOTNA CK UNIT 42-05X API Well Number 50-133-20561-00-00 Insp Num: mitMFH200920181229 Permit Number: 206-074-0 Rel Insp Num: Inspector Name: Matt Herrera Inspection Date: 9/20/2020 - Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min J -T - 42-05X G 7687 g 385038503850 3850 385�— PTeD 2060740 T e Test s — - PT 1922 yP Test sl ' j [A 628 2215 - p BBL l 1 BBL Returned: 1 OA 430 - 440 -- _-_ 2210 2213 - 2213 438 440 440 - aiumped: Inte 4YRTST 1P/Ti P I Notes: MIT -IA pressured to 220OPSI per Operations Test ran out additional 15 minutes due to fluctuating injection temperature ✓ Tuesday, September 22, 2020 Page 1 of I sCt c 47- - 6 a Regg, James B (CED) Prt� Z�0&6740 From: Taylor Wellman <twellman@hilcorp.com> Sent: Thursday, June 18, 2020 3:17 PM �� To: Regg, James B (CED) 1� I Cc: Wallace, Chris D (CED) Subject: RE: (EXTERNAL] Swanson River SVS Tests - High Annular Pressures Attachments: SRU 42-05X TIO Plot.xlsx; FW: SCU 42-05X MIT Jim, Please find the responses to the wells in question. - 31B-04 (PTD 2160100) 1860 psi Your assumptions are correct on this. This well is currently on fulltime gaslift and this is the source of annular pressure. - 42-05X (PTD 2060740) 1700 psi Please see the attached TIO plot for reference. The increased IA pressure is due to the well restarting injection into storage. The pressure trend on the IA follows the injection rates and are indicative of being thermally induced. Also over this timeframe there is a pressure differential between the Tbg and IA that ranged from 400psi—1,000psi. The TxIA differential also increases over time as we are refilling the storage tank the injection/tbg pressure increases. There does not appear to be an integrity issue with TxIA communication at this time but we will continue to monitor for any signs of impaired integrity and v make immediate notification to you and Chris if there is in the future. With respect to the 2016 possible TxIA communication I've attached an email with a summary of the diagnostics conducted to ensure the integrity and that the suspected TxIA looked to be more of an anomaly than confirmed TxIA communication. If you would like additional information on these wells please let me know. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC — Kenai Ops Manager Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Regg, James B (CED) [mailto:jim.regg@alaska.gov] Sent: Thursday, June 18, 2020 1:10 PM To: Taylor Wellman <twellman@hilcorp.com> Subject: RE: [EXTERNAL] Swanson River SVS Tests - High Annular Pressures I apologize — correct report is attached. Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.re¢¢@alaska.¢ov. From: Taylor Wellman <twellman@hilcorp.com> Sent: Thursday, June 18, 2020 12:59 PM To: Regg, James B (CED) <iim.regg@alaska.gov> Cc: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Subject: RE: [EXTERNAL] Swanson River SVS Tests - High Annular Pressures Jim, I will dig into this and provide you a response. Can you re -send a copy of the inspection report? The previous one sent is for Kuparuk and ConocoPhillips. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC — Kenai Ops Manager Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Regg, James B (CED) [mailto:iim.regg@alaska.gov] Sent: Thursday, June 18, 2020 12:36 PM To: Taylor Wellman <twellman@hilcorp.com> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: [EXTERNAL] Swanson River SVS Tests - High Annular Pressures Attached is our Inspection report for Swanson River SCU wells performed 5/25/2020. The following wells were observed with elevated IA pressures: - 316-04 (PTD 2160100) 1860 psi - 42-05X (PTD 2060740) 1700 psi Inspector did not indicate 31B-04 as being on gas lift but the most recent well schematic in our well files from a 2018 workover (add perfs) shows live gas lift valves. Please confirm the source of pressure in the IA. Regarding 42-05X, what diagnostics have been done to confirm continued integrity? There were several email exchanges in 2016 regarding possible TxIA communication; the well was allowed to continue in service following diagnostics and some mitigations implemented. Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 i� i C1 T w E E ( LK ti U R' V C H a y — d 9 a o b c"e i� — d o b 0. c � m E P u E E a N o a n a 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 z Z z z z ',Z Z Z. z Z Z Z Z Z .Y ZZj. zz Z;. T�ZZZZ O O O O O O P O vt O O O vl O 0 Nl m b Vl � Q O� Vl O 0. In N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O Q O O O N n O O O O O .-. F- .Q. �-t m Tm O On Q Q Q m Al V W g m N N v< M • • MEMORANDUM - State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,December 13,2016 Jim Regg P.I.Supervisor Se-fq (71 t4((� SUBJECT: Mechanical Integrity Tests (l HILCORP ALASKA LLC 42-05X FROM: Brian Bixby SOLDOTNA CK UNIT 42-05X Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvj' NON-CONFIDENTIAL Comm Well Name SOLDOTNA CK UNIT 42-05XAPI Well Number 50-133-20561-00-00 Inspector Name: Brian Bixby Permit Number: 206-074-0 Inspection Date: 10/30/2016 Insp Num: mitBDB161031065615 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 42-05x - Type Inj N TVD 7687 - Tubing I 3610 3610 - 3610 - 3610 - PTD I 2060740 ' Type Test SPT Test psi 1922 . IA 1480 2280 - 2280 . 2280 - Interval ToTl l P/F P OA 600 - 600 - 600 600 . Notes: It was noticed a few weeks ago there was an increase in pressure on the IA.Well was shut-In,Slickline set a plug in the XN nipple and changed out the injection port in the side pocket mandrel.Well was not injection at time of test. SCANNED MAY. j. 2017 Tuesday,December 13,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, November 22, 2016 9:39 AM To: Larry Greenstein C rib 20 , 0740 Subject: RE: SCU 42-05X MIT C ,,J w2Z/20� Larry, As discussed on the phone just now,SCU 42-05X is approved for continued normal operations. The mitigations implemented of wellhead signage, monitored SCADA alarms,and a renewed awareness based on the maximum surface pressure of 3,995 psi should prevent reservoir pressure limit exceedances in the future. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone), (907)276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Larry Greenstein [mailto:Igreenstein@hilcorp.com] Sent: Friday, November 04,2016 10:16 AM To:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Subject:SCU 42-05X MIT SCANNED NOV 2 22016 Hi Chris Wanted to talk with you about the SCU 42-05X gas storage well at SRF. We've had a few suspected issues with the integrity of this well (attached)...all of which appear to be unfounded. The 10/30/16 MIT witnessed by Brian Bixby(attached)confirmed the 9/16/16 witnessed by Lou Grimaldi that everything checks out with the integrity of the well. Possibly these pressure anomalies were related to the extra stress we were putting on the well by exceeding the reservoir pressure limit established in the SIO (attached and subsequently cleared). Since we have brought the reservoir pressure down by flowing the SCU 42-05Y well, the 5X well has proven again that there isn't any tbg x IA integrity issue by passing the 10/30/16 MIT. The 5X well has remained shut-in during this diagnostic, reservoir bleed down and integrity testing period. As the most recent MIT again shows the well to be competent, we are requesting permission to return this well to service. This would include both production from and injection into the well. This time of year usually results in more production than injection, but occasionally there is extra gas being produced elsewhere that allows gas injection into storage for later in the winter use(when it gets really cold). Please let me know if you'd like to discuss this further or have any questions about what we with this well. Thank you Larry 777-8322 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Jim l7 DATE: Thursday,November 03,2016 TO: Regg � a 1(I 'Ica P.I.Supervisor i SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 42-05X FROM: Brian Bixby SOLDOTNA CK UNIT 42-05X Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 14— NON-CONFIDENTIAL Comm Well Name SOLDOTNA CK UNIT 42-05X API Well Number 50-133-20561-00-00 Inspector Name: Brian Bixby Permit Number: 206-074-0 Inspection Date: 10/31/2016 Insp Num: mitBDB1610310656I5 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 42-05X Type Inj N- TVD 7687 - Tubing 3610 3610 - 3610 3610 PTD 2060740 Type Test SPT Test psi 1922 - IA 1480 2280 - 2280 el 2280 - Interval OTHER P/F P V OA 600 600 600 600 - Notes: It was noticed a few weeks ago there was an increase in pressure on the IA.Well was shut-In,Slickline set a plug in the XN nipple and changed out the injection port in the side pocket mandrel.Well was not injection at time of test. SCANNED APR 2 2U1 Thursday,November 03,2016 Page 1 of 1 • o jizts9 THE STATE Alaska Oil and Gas F ,,-s�+�� o Conservation Commission LAsKA. 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 FA :S�� Fax: 907.276.7542 www.aogcc.alaska.gov October 26, 2016 Mr. Chad Helgeson Kenai Operations Manager Hilcorp Alaska, LLC 1 P.O. Box 244027 Sat4t4E) 'A Anchorage, AK 99524-4027 Re: Notification of exceeding reservoir pressure limit in Rule 4(a) of Storage Injection Order 6 Tyonek 77-3 Sand Swanson River Field Dear Mr. Helgeson: On October 17, 2016, Hilcorp sent an email to the Alaska Oil and Gas Conservation Commission (AOGCC)to report that a slickline static pressure survey in the SCU 42-05X(PTD 206-074)well found the reservoir pressure in this gas storage pool to be 4,921 psi, which exceeds the 4,774 psi maximum reservoir pressure limit set by Rule 4(a) of Storage Injection Order(SIO) 6. The AOGCC takes compliance with its regulations and orders seriously and appreciates Hilcorp's timely notification of this violation as well as the information provided on what steps Hilcorp is taking to correct this issue (producing an offset well to reduce reservoir pressure) and what steps will be taken to prevent this from recurring in the future (installing SCADA alarms to alert if the wellhead pressure exceeds a preset limit). The AOGCC expects similar timely notification from Hilcorp Alaska, LLC if the terms of this or other rules are violated in the future. Sincerely, A Cathy '. Foerster Chair, Commissioner • Wallace, Chris D (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Wednesday, October 05, 2016 8:10 AM To: Wallace, Chris D (DOA) Subject: Possible tbg x IA communication in SCU 42-05X(PTD 2060740) Attachments: SCU42-05X Schematic 8-27-16.pdf Good morning, Chris I got this e-mail from the SRF lead op after I left work yesterday. It appears the IA pressure has built back up on 42-05X. We bled it down from 1675 psi to 450 psi in 30 minutes( 12:30 ) and the pressure built back up to 1580 psi by 15:30. Shut the well in and bled down to 500 psi. Mostly gas very little fluid. Crystal gauges were installed before we bled any gas off. Rate-2-3 mmcfd @ 70deg. Kevin Cassidy I Lead Operator NKE Swanson River Hilcorp Alaska LLC Office 907-283-2543 SCANNED FEB 207, Cell 907-398-9566 To refresh your memory, this is the well we completed a successful, witnessed MIT on last month, yet it now seems to be getting gas into that first annulus...very disappointing. We've shut-in the well and want to see if we can figure out how the gas is getting to the annulus. The annulus pressure had built back up to—1700 psi by this morning, so that's not a good sign. Looking at the attached schematic, we hope it's either the dummied off chemical injection mandrel or the sliding sleeve that is leaking. Both of these we can try to fix with wireline, but if it's a tubing or packer leak...we're going to need a bigger tool. Our plan is to do some bleed downs and see if we can locate the small leak with wireline and then fix it, if possible. We will not inject gas into this well until we can get a successful MIT and have received permission to resume injection from AOGCC. As we find out more, we will keep you informed. Please call if you have any questions or want to discuss this well. Thank you Larry 777-8322 1 0 r 'MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg lel � DATE: Monday,September 19,2016 P.I.Supervisor `t` )j(c SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 42-05X FROM: Lou Grimaldi SOLDOTNA CK UNIT 42-05X Petroleum Inspector Src: Inspector Reviewed By: r P.I.Supry Jg. NON-CONFIDENTIAL Comm Well Name SOLDOTNA CK UNIT 42-05X API Well Number 50-133-20561-00-00 Inspector Name: Lou Grimaldi Permit Number: 206-074-0 Inspection Date: 9/16/2016 Insp Num: mitLGl60916184452 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 42-05x - Type Inj N 'TVD 7687 Tubing 4200 . 4250 4250 - 4250 PTD 2060740 - Type Test SPT Test psi' 1922 " i IA 1490 2200 2190 - 2190 - Interval OTHER P/F 1 P OA 630 630 630 630 Notes: This is the first test(official)since the sidepocket chemical injection valve was swapped out for"Dummy"GLV..5 bbls diesel pumped and returned indicating a good test of the tubing/Inner Annulus.Attention should be paid to the possibility of compromised chemical injection lines integrity. rte( eeit- i) Tit: ri ssuue f(,,,k' --t) 'utL'. Sc ,,iiekc SCANNED JUN ]. 62017, Monday,September 19,2016 Page 1 of 1 • I 1.1 . c.-. Z 0 I= 0 C:3 0 C, 0 rl, CI CI CI C:3 C:5 0 0 0 -..... tN "''s...._...... r....." -, I I ak 4- \a\ ‘....... \•-•Ar _ n 2., -... --;-• .....--.. "2. iC.4'.....A *---1.r) c....‘,...., .,.....5 -----"s"\\......s.........N.,.‘ ) ,O v.4 0 t4 747 g OC 0 .6 0 S\"""................i I 4J Cit ,—. .-4 crt 0 10 0 0 ci towni t ri - 70 gr o ch In co o 1 <1. 0 X --- i n4 4 0 1 t) III at rj c tfl .o 1.7 a 413 i_ .-+ / 2 I ca ...• .-. 0 IN lip 0 0 0 0 0 C. 0 0 0 0 0 0 0 0 .7 CI ry .-• Scy, • • e weilbore Schematic: SCU 4:,-05X As Completed ttile9rpi.Alaska_I,I.0 Well Name: SCU 42-05X Operator: Hilcorp Alaska Field: Swanson River Unit: Soldotna Creek API: 50-133-20561-00 Permit: 206-074 Well Status: Gas Storage RKB: 174'above MSL,23'above GL TD/ND: 8,155'MD/8,055'TVD PBTD/PBTVD: n/a -- Casing Detail Size Wt Grade Type Top(FT) Btm(FT) Length(FT) 13-3/8" 72# K-55 Weld/Drive 0.00 96 96 9-5/8" 47# L-80 BTC 0.00 2,621 2,621 7" 26# L-80 BTC 0.00 8,130 8,130 Tubing Detail Size Wt Grade Type Top(FT) Btm(FT) Length(FT) ( — j 3-1/2" 9.2# L-80 Atlas Bradford TC-2 0.00 7,787 7,787 U Jewelry Detail 5;tk poc4 1 Side Pocket Chemical Injection Mandrel 2,491 j 2 CMD Sliding Sleeve 7,732 C C /"AawA,et, 3 BOT SAB-3 Perm.Packer with a K-Anchor and Mill out extension 7,787 C[44D1 CO-, 4 XN-Nipple 7,808 C) 2 5 3-1/2"Ported Sub 7,829 i" ct (Pt 6 3-1/2"IBT x 2-7/8"EUE XO 7,830 I 7 Full Joint 2-7/8"EUE Tubing 7,831 CUtr4( E 3 Z 8 2-7/8"Wire Line Re-Entry Guide(Halliburton Automatic Release Assy.) 7,870 9 Top of Dropped TCP Assy.(32.8'long) 8,015 eplf.c O 0 5 Perforation Detail 7 6 Zone SPF Date Top(FT) Btm(FT) Length(FT) / 8 \ 77-3 5 7/24/2006 7,883.00 7,896.00 13 OD 009 f - Last Revised: 8/27/2016 Revised By: CAH • • Wallace, Chris D (DOA) From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Saturday, August 27, 2016 12:19 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); Wallace, Chris D (DOA) Cc: Bruce Hershberger;Joey Hensley;Joe Kaiser; Larry Greenstein; Chet Starkel; Kevin Cassidy; Daniel Paulk Subject: Swanson River SCU 42-5X Well communication Attachments: SCU42-05X Schematic 8-27-16.xls; SCU 42-05X August 27 2016.xlsx P► ) 206o7g-o Chris, We shut-in Soldotna Creek (SCU 42-05X)gas storage well yesterday afternoon after identifying a potential tubing by annulus communication. The annulus pressure had built to 1740 psi. With the well shut in,we bled the annulus pressure to 900 psi yesterday. By this morning the pressure had built back to 1740 psi and seems to have stabilized there? We are leaving the well SI while we do diagnostic work on the wellhead, chem injection valve, etc. Things seem to be stable at this time and we will update you next week when we have more information. I attached a well schematic and the DIO plot for the last 3+ months. If you have any questions or need more information, please let me (229-4824) or Larry Greenstein know. Thanks Chad Helgeson 7: � ».-� .�.........,.._, .�-. .. _.. SCANNED JAN 1 8 201Z 4 • • C) C) c) cD cli c) c::, c) • C:* CD c) c:s c) cD c:. c) 0 0 0 CD 0 0 0 C3 Op N. V3 VI 'cr re) csi v-4 4=4 I I 1 i I -"" • ' ...-. to •-• __......., ...— co 0 L 0 .:-.. I.) (1) . 11111111k IA et 0 CD CD CD CO ....-1 c kO, I 0 0 ...., kJ CD n U1 'T3 s-.....o 0 1111111r C3.-41 CL rn • CV IA c0 I ci < -1 < (3 X 0 it) 0 r:4 er lc < 0 C..) ti) I-I L.) tfl up < L.7 v-4 CD i --- cD c•-11 t_ --3 III __....._, r"- H LA------ ) ---------71' (=, ' CV (:) •1 fel irsi qr., MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,January 27,2015 TO: Jim Regg T l P.1.Supervisor n�i 1(t 1 J SUBJECT: Mechanical Integrity Tests f HILCORP ALASKA LLC 42-05X FROM: Matt Herrera SOLDOTNA CK UNIT 42-05X Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name SOLDOTNA CK UNIT 42-05X API Well Number 50-133-20561-00-00 Inspector Name: Matt Herrera Permit Number: 206-074-0 Inspection Date: 11/13/2014 Insp Num: mitMFHl41116121622 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11 42-05X Type Inj 74- TVD 7687 "Tubing 2666 - 2665 i 2665 I 2662 • 2663 PTD -_ 2060740 Type Test SPT Test psi 1922 IA 1150 2120 • 2120 • 2120 - 2120 - Interval Four Year Cycle , per, Pass ' OA 500 500 I 500 " 500 • 500 • Notes: 75 BBL's Diesel to reach required Test PSI of 2100 PSI per Operator SCANNEV ,' P't, b °/ i Tuesday,January 27,2015 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ - Q ~y- Well History File Identifier Organizing (done/ ^ Two-sided III II~III II I~I II III ^ Rescan Needed RE SCAN DIGITAL DATA OVERSIZED (Scannable) // rl[~'Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: BY: Maria Date: ~ ~ ^ Other.: /s/ Project Proofing II (4I (I II I I III I I III BY: Maria Date: SD /s/ Scanning Preparation _~ x 30 = ~ ~ + ,~_ =TOTAL PAGES ~ ~( (Count does not i ~S~ude cover sheet) t n n BY: Maria ~ Date: ~ ~ ~ / I/ I/' Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: I ~~ Qg lsl ~ `~ f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II ~I II I II II I I III ReScanned III II'III IIII IIIII BY: Maria Date: /s/ Comments about this file: ~~ o~a„~~~we, iuimiiiiuiiiiii 10/6/2005 Well History File Cover Page.doc • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Monday, February 07, 2011 2:04 PM To: McMains, Stephen E (DOA) Cc: Davies, Stephen F (DOA) Subject: 77 -3 Gas Storage at Swanson River -Pool Code 772805 Steve, Further to the work begun earlier regarding the appropriate pool classification of Tyonek gas associated with the 64 -5 and 77 -3 storage projects, the 64 -5 [772803] and 77 -3 [772805] are distinct Tyonek sand intervals so the volume accounting needs to be separate. The matter is a little further complicated since there also is an undefined Tyonek pool code at Swanson [772500]. So far as I am aware, the only wells remaining to be reconciled are 42A -05 (180 -106) and 42B -05 (182 -199). Both wells were originally Hemlock oil producers and the Hemlock was plugged with the wells being completed in the 77 -3 sand. 42B -05 was converted to GSTOR 11/7/05. First storage injection is reported in 12/05. First gas production is reported 11/05. All gas volumes are reported to the 64 -5 pool, this should be changed to the 77 -3. 42A -05 is a little more complicated. There is no record of any gas having been injected for storage. The Hemlock was plugged and the well perforated in the 77 -3 in June 2004. It appears that all gas produced from then until the well was converted to GSTOR on 10/1/05 was credited to the undefined Tyonek Pool code [772500]. Fairly regular /continuous production is reported up through 11/05 (14 days). No production is reported in 12/05 and only 7 days in 01/06. Again, all Tyonek gas from this well should be against the 77 -3 pool code [772805]. Please let me know if further information is needed. It is probably appropriate to put a copy of this message in each well file. Tom Maunder, PE Sr. Petroleum Engineer bk\--W N`k S 3/7/2011 2010 December's SRF Tyonek 77 Eiand Storage Well Monitoring Report • Page 1 of 2 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Monday, January 10, 2011 2:26 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: FW: 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Almost correct Tom. DO (0 X & Y are the active wells in the 77 -3 gas storage sand and 42A -05 & 42B -05 were completed in the same sand, but have since both been suspended. Both A & B are being used as monitoring wells in case the gas gets out of the 77 -3, but neither has open perfs in that sand today. It is true that there are a number of other wells we are using to monitor the storage reservoir that penetrate, but were never completed in the 77 -3 sand. I do believe the split of the gas storage pool code for the 64 -5 & 77 -3 sands will be forthcoming from production accounting. They truly are separate accumulations, but both Tyonek sands. Let me know if you need more info. Larry From: der, Thornas E (DOA) [mailto:tom.maunder @aTaska.gov] Sent: Monday, January 10, 2011 1:55 PM To: Greenstein, Larry P; Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: RE: 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Larry, et al, I have been working with McMains sorting out the Swanson River storage gas. The two Swanson storage projects employ Tyonek reservoirs (64 -5 and 77 -3), but they are separate accumulations. From a reporting sense, all the volumes had been being reported under one pool code. I think that has been changed or is in the process of being changed. The question I have regards 77 -3 storage. As I understand, 42 -05X and 42 -05Y are the active injection /production wells. 42 -B -05 and 42A -05 are completed in the 77 -3 sand, but are not being actively employed. There are a number of wells that penetrate the sand enroute to the Hemlock, but none are completed in the 77 -3 sand. Do I have that correct? Thanks in advance, Tom Maunder, PE AOGCC From: Greenstein, Larry P [mailto :Greensteinlp @chevron.com] Sent: Monday, January 10, 2011 9:29 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Hi Jim & Tom, Here is December's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77 -3 Sand Storage reservoir. 3/11/2011 2010 December's SRF Tyonek 77 land Storage Well Monitoring Report Page 2 of 2 Both X & Y are in heavy usage now that the winter is in full swing, but the warmth at the end of December did allow a little injection to occur. While performing the MIT on 5X last month the operators noted that leaving the annulus with 0 pressure readings didn't offer much to monitor. They put a few hundred psi on both the 5X & 5Y well 7" annulus to better monitor pressure changes. Both annuli are now showing some ups and downs related to temperature swings based on injection vs production at different rates. Neither annulus appears to be tracking or communicating with the tubing pressures, they are just much more responsive now that there is some pressure on them to observe. The pressure responses from both wells were within expectations with no indications of any loss of integrity. Bottom line, the pressures for all the monitored wells remain within their expected ranges. Larry «Master Well List TIO Report 2011 01 01.xis» LINMPIN S 7 t•Sti VENN k 3/11/2011 2011 May's SRF Tyonek 77 -3 San :rage Well Monitoring Report . Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Monday, June 06, 2011 2:10 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: 2011 May's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Attachments: Master Well List TIO Report 2011 06 01.xis Hi Jim & Tom, DO - 0 ' 0-- Here is May's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77 -3 Sand Gas Storage reservoir. The storage wells are in full injection cycle now and the tubing pressures are climbing as expected. Some of the offset producers (like SCU 12A -04 & SCU 332 -04) have pressures that move around, but nothing related to the change in use of the storage wells. Once again, the 77 -3 sand monitoring wells appear to show no indications of a loss of storage gas containment. Larry «Master Well List TIO Report 2011 06 01.xis» f:IlleKliftiED JUN tJ 6 20 6/6/2011 Plot Pre ssure & Rate vs Time - Well SCU 42 -05X 4000 - - 16000 3500 — 14000 7 3000 �9 5/8" 12000 •Tubing ''Vol Inj Vol Prod 2500 I N 10000 IL' I 1 7 /y 1 3 ✓ LL 11 2000 —___ — _ , 8000 0. 1 1500 ' ,i 6000 1000 - 4000 500 — 2000 i li —lit if ., o. ‘ 0 O o O M m O M M M M M V 0 o O O O O Date 7" 9 5 u ing Vol lnj Vol Prod TIO Report 06/01/11 0 350 3726 9114 0 05/31/11 0 350 3606 7808 Data Sheet 05/30/11 0 350 3605 8764 05/29/11 0 350 3553 8881 05/28/11 0 350 3488 8155 SCU 42 -05X 05/27/11 0 350 3459 9575 05/26/11 0 310 3456 8685 05/25/11 0 310 3465 9764 0 STORAGE WELL 05/24/11 0 315 3411 11119 0 05/23/11 0 315 3261 8232 0 05/22/11 0 315 3398 12854 0 Permit # 2060740 05/21/11 0 320 3273 13188 0 05/20/11 0 325 3184 11945 0 05/19/11 0 325 3043 7619 0 API # 50 -133- 20561 -00 05/18/11 0 330 3033 10396 0 05/17/11 0 300 2955 11255 05/16/11 0 300 2795 10335 12/01/2010 to 06/0112011 05/15/11 0 300 2795 6116 05/14/11 0 300 2740 6729 05/13/11 0 310 2918 8146 05/12/11 0 310 2865 12687 05/11/11 0 310 2570 4953 05/10/11 0 350 2621 9197 0 05/09/11 0 310 2559 8646 0 05/08/11 0 310 2625 10975 0 05/07/11 0 310 2530 10058 0 05/06/11 0 310 2490 9887 0 05/05/11 0 310 2260 5222 0 05/04/11 0 310 2254 6349 0 05/03/11 0 250 2224 8341 0 05/02/11 0 250 2329 10938 05/01/11 0 35 2096 4984 04/30/11 0 35 2143 5627 04/29/11 0 35 2080 4237 04/28/11 0 • 5 WO 6709 04/27/11 0 , 4607 6/6/2011 2:53 PM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 06 01.xIs SCU 42 -05X 2011 April's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report • Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Tuesday, May 10, 2011 4:13 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: 2011 April's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Attachments: Master Well List TIO Report 2011 04 30.xls Hi Jim & Tom, Here is April's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77 -3 Sand Gas Storage reservoir. The storage wells are now getting some gas back into the ground and the tubing pressures have started to climb as expected. Some of the offset producers (like SCU 12A -04 & SCU 332 -04) have pressures that move around, but nothing related to the change in use of the storage wells. The SCU 42A -05 well appears to have settled down lately, maybe it was the long freeze / thaw kind of spring that had this suspended well's pressures moving so much. All in all, the 77 -3 sand monitoring wells appear to show no indications of a loss of storage gas containment. Larry «Master Well List TIO Report 2011 04 30.xls» 5/16/2011 Plot Pure & Rate vs Time - Well SCU 42 -05. 16000 4000 — 14000 3500 •'9 5/8" •Tubing L a•VOI Inj •Vol Prod 12000 3000 - -- 10000 2500 d i i , 1 2 000 o- 1 1500 6000 1000_ 4000 500 2000 .11k, . 1 G3t,,tin I Li �Il�l ��I � 1 ii 0 0 O O O c, N N N N N N 0 CV O O O O Date 7' _ - TU voiPros TIO Report 04/30/11 0 35 2143 5627 04/29/11 0 35 2080 4237 Data Sheet 04/28/11 • 0 35 2073 6709 04/27/11 0 350 2070 4607 04/26/11 0 355 2186 9608 0 SCU 42 -05X 04/25/11 0 79 1049 7997 0 04/24/11 0 355 1855 6266 0 04/23/11 0 350 1833 5427 0 STORAGE WELL 04/22/11 0 350 2043 7777 0 04/21/11 0 350 1803 4839 0 04/20/11 350 0 1751 7974 0 Permit # 2060740 04/19/11 0 1603 391 0 04/18/11 35 1605 1155 04/17/11 335 1840 7620 API # 50- 133 - 20561 -00 04/16/11 350 2053 9827 04/15/11 350 1734 7934 04/14/1 0 350 1639 4502 10/30/2010 to 04/30/2011 04/13/11 0 350 1544 4222 04/12/11 350 1454 3481 04/11/11 350 1383 3888 04/10/11 ' 0 350 1348 2701 I 04/09/11 0 350 1270 1488 0 04/08/11 0 350 1206 285 1054 04/07/11 0 350 1160 0 2294 04/06/11 0 350 1194 0 2515 04/05/11 0 350 1170 2501 04/04/11 80 350 1159 0 2545 04/03/11 0 350 1210 1730 04/02/11 20 350 1146 3029 04/01/11 40 350 1228 0 2820 03/31/11 '20 350 1234 0 3252 03/30/11 80 350 1285 0 1930 03/29/11 125 350 1240 0 1421 03/28/11 160 350 1245 0 2287 03/27/11 200 3 _ 0 2305 03/26/11 190 0 2783 5/16/2011 11:14 AM - TIO Reports 7e.xls J J Dolan Master Wet List TIO Report 2011 04 30 (4).xls SCU 42 -05X • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 29, 2010 TO: Jim Regg P.I. Supervisor it (Z( ( 10 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 42 -05X FROM: Bob Noble SOLDOTNA CK UNIT 42 -05X Petroleum Inspector 1 Src: Inspector Reviewed Bry�::� P.I. Supry ZJ- NON CONFIDENTIAL Comm Well Name: SOLDOTNA CK UNIT 42 - 05X - API Well Number: 50 133 - 20561 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN101218104952 Permit Number: 206 - 074 - Inspection Date: 12/17/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 42 -05x- Type Inj. G 'I TVD 7687 - IA 600 2160 , 2160 2160 P.T.D 2060740 ' TypeTest SPT 1 Test psi 2160 - I OA 300 300 300 300 Interval 4YRTST - P/F P Tubing 3515 3515 3515 3515 Notes: This well is a storage well. They were producing it at the time the MIT was performed. Vi/l. rey -'S- I `i ZI r„ FEB U» I an Wednesday, December 29, 2010 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: lim.regg a( ..alaska.gov; doa. aogcc.orudhoe.bav(a2alaska.gov; 0oebe.brooks(@alaska.gov; tom.maunder(c- alaska.ciov OPERATOR: Union Oil Company of California FIELD / UNIT 1 PAD: Swanson River Field / Soldotna Creek Unit / 42 -05X Pad DATE: 12/17/10 DL " OPERATOR REP: Kevin Cassidy ai r AOGCC REP: Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well SCU 42 -05X Type In'. I G TVD 1 7,687' Tubingl 3,515 3,515 1 3,515 3,515 Interval 4 P.T.D. 2060740 1 Type test I P Test si 1922 Casingl 600 2,160 1 2,160 2,160 P/F P Notes: Ambient Temp -17 degF OA 300 300 1 300 300 Flowing well @ 12.1 mmcf /d Well I Type In'. I TVD Tubing Interval P.T.D. I Type test I I Test psi I Casing P/F Notes: OA Well T pe In'. TVD Tubing Interval P.T.D. Type test Test psi I Casing P/F Notes: OA Well T e In'. I TVD I Tubing Interval P.T.D. I Type test I Test psi Casin P/F Notes: OA Well I Type In'. I TVD I Tubing Interval P.T.D. I Type test I Test psi Casin P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) E 1 ` 2UILJ Form 10 -426 (Revised 06/2010) MIT _SCU 42- 05X_12- 17- 10.xis 2009 August's SRF Tyonek 77 -3 SeStorage Well Monitoring Report • Page 1 of t Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Tuesday, September 15, 2009 7:19 AM To: Maunder, Thomas E (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Sounds good Tom, I'll find a way to get this done...hopefully with the correct axis label, but if not, some kind of side note. Thanks ∎ D ( —0 Larry —Og From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, September 14, 2009 9:14 PM To: Greenstein, Larry P Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report If you can't, thats OK. The storage wells are the only ones where you all inject gas. You might just make a note in the "note field" where you give the specifics on the well. Tom From Greenstein, Larry P [mailto :Greensteinlp @chevron.com] 50.100 MAR 1 0 Zp11 Sent: Mon 9/14/2009 5:23 PM To: Winslow, Paul M; Maunder, Thomas E (DOA) Cc: Ayer, Phil M; Regg, James B (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Thanks Paul. Tom, I'll look into the program that spits out these plots to see if we can tweak it to be more accurate on the labeling. Larry Fro inslow, Paul M Sent: Mons . September 14, 2009 4:15 PM To: Maunder, Tho E (DOA); Greenstein, Larry P Cc: Ayer, Phil M; Regg, • - s B (DOA) Subject: RE: 2009 Augusts S • onek 77 -3 Sand Storage Well Monitoring R- • Tom, Prior to April 2009, we had only injected int. - 15X, and ha • • • uced from both 42 -05X and 42 -05Y. After installing a coalescer this year, we s - - • injecting into both 42 -05Y a . 2 -05X. From here on out, we will be injecting and producing fro.. •oth wells. Paul 3/7/2011 L MY / iugusis 3rcr iyonex 11-3 aaiiu aturage wen rvruruwruig tseporL rage 1 01 L. • • Maunder, Thomas E (DOA) From: Winslow, Paul M [PWinslow @chevron.com] Sent: Monday, September 14, 2009 4:15 PM To: Maunder, Thomas E (DOA); Greenstein, Larry P Cc: Ayer, Phil M; Regg, James B (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Tom, Prior to April 2009, we had only injected into 42 -05X, and had produced from both 42 -05X and 42 -05Y. After installing a coalescer this year, we started injecting into both 42 -05Y and 42 -05X. From here on out, we will be injecting and producing from both wells. Paul Paul Winslow Chevron North American Exploration & Production MidContinent / Alaska Business Unit 3800 Centerpoint Dr., Suite 100, Anchorage, AK 99503 Tel: 907 - 263 -7629 CeII: 907 - 382 -3813 Fax 907 - 263 -7828 pwinslow @chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, September 14, 2009 3:59 PM To: Greenstein, Larry P Cc: Ayer, Phil M; Winslow, Paul M; Regg, James B (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Hi Larry, et al, It will be interesting to see the pressure plot next month on 12A -04. On 5X and 5Y, there are a couple of items. One is listed as an injection well and the other a storage well. Do both wells inject gas and then produce it back? In our data base they are both listed as "GSTOR ". Also, the volume on the right axis says BBLS. Should that be MCF? Thanks in advance. Tom Maunder, PE AOGCC From: Greenstein, Larry P [ mailto :Greensteinlp @chevron.com] Sent: Monday, September 14, 2009 2:44 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Ayer, Phil M; Winslow, Paul M Subject: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Hi Jim & Tom, Here is August's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77 -3 Sand Storage reservoir. 9/14/2009 2009 August's SRF 'lyonek 77 -3 Sand Storage Well Monitonng Report Page 2 of 2 • • We are still injecting into the wells, but the volumes are slowing down as the reservoir fills up. Both the 5X & 5Y wells are getting gas injected and the tubing pressures show the increases expected. The 12A -04 well WO has been completed and production has started. It is having some problems, but we are still trying to clean up the lost fluids and get production rates up, The rest of the wells appear to have pressures for the month that don't show any indications of a response due to the gas storage operations. Bottom line, the pressures remain in expected ranges for all the wells being monitored. Larry «Master Well List TIO Report 2009 09 01.xis» 9/14/2009 Plot Prikre & Rate vs Time - Well SCU 42 -05X 4500 14000 4000 . -- -- ......9 5/8" 12000 Tubing 3500 __ -- Vol Prod _ • Vol lnj 10000 3000 X2500 8000 7 J N m F. CO O. 2000 — _.... -- ltil\r\i\ 6000 \14 4000 I 2000 500 __ o 0 0 0 0 N M O O M N o o 0 0 0 0 Date Tubing _ TIO Report 09/01/09 ' 300 - ` 0 4378 »- • _ 1113 08/31/09._ 300 0 4334 0 1770 Data Sheet 08/30/09 ";00 0 4373 0 1505 08/29/09 300 0 4373 0 1449 08/28/09 300 0 4396 0 1785 SCU 42 -05X 08/27/09 300 0 4388 0 2006 08/26/09 320 0 4393 0 1726 08/25/09 320 0 4415 0 2607 STORAGE WELL 08/24/09 300 0 4414 0 2682 08/23/09 800 0 4393 0 2763 08/22/09 .00 0 4393 0 3021 Permit # 2060740 08/21/09 300 0 4386 0 2220 08/20/09 00 0 4405 0 2557 08/19/09 i`800 0 4391 0 2771 API # 50- 133 - 20561 -00 08/18/09 300 0 4389 2820 08/17/09 300 0 4395 2751 08/16/09 ,`,` 300 0 4385 2649 03/02/2009 to 09/01/2009 08/15/09 ,, 300 0 4388 2664 08/14/09 320 0 4393 0 3122 08/13/09 320 0 4379 0 2675 08/12/09 300 0 4370 2378 08/11/09 300 0 4380 0 2328 08/10/09 300 0 4383 0 2616 08/09/09 00 0 4379 0 2392 08/08/09 -300 0 4419 0 08/07/09 300 0 4409 0 08/06/09 300 0 4396 0 33 08/05/09 310 0 4409 0 3957 08/04/09 300 0 4375 0 3921 08/03/09 300 0 4358 0 3 08/02/09 - `300 0 4366 0 08/01 /09 300 0 4368 0 07/31/09 300 0 4319 0 07/30/09 , 0 4271 0 07/29/09 . 305 •0 4279 0 07/28/09 f °—°. 3/7/2011 4:22 PM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2009 09 01.xIs SCU 42 -05X Plot Pr•re & Rate vs Time - Well SCU 42 -05Y• 1 4500 4500 4000 -- —; .._._.__ .__ - . . - 1 - - -- ,- - � -- - - -�— - - -- - -i 4000 — 9 5/8" i t Tubing 3500 'Vol Prod L. _Vollnj 3500 3000 It f 3000 2500 _. - _._...._...___ -___ ____.__ -__ _ -.. 2000 ' ,- 1 li . 1 - 250m m 2000 1500 ... — ._ - __ 1500 1000 \ ' 1000 500 - _ _. —. . 500 irlIP \ N 'N 'NOM Ilk o .1 rev iii MI1 owl A �. -- A 0 0 0 0 0 0 o a O O O t7 m O o N o o o o o o co Date 7" I Ini — TIO Report 09/01/09 100' 0 ' ......, . , ' 16 08/31/09 4 100 0 4343 0 Data Sheet 08/30/09 100 0 4369 0 1 08/29/09 100 0 4363 0 08/28/09 100 0 4386 0 1075 SCU 42 -05Y 08/27/09 100 0 4383 0 1367 08/26/09 100 0 4389 0 1225 08/25/09 F 100 0 4408 0 1852 INJECTION 08/24/09 100 0 4411 0 1919 08/23/09 100 0 4395 0 2096 08/22/09 ' 100 0 4390 0 2402 Permit # 2070820 08/21/09 r. 100 0 4378 0 1351 08/20/09 ' 100 0 4400 0 1608 08/19/09 100 0 4389 0 1973 API # 50- 133 - 20570 -00 08/18/09 100 0 4391 2109 08/17/09 _ 100 0 4391 1987 08/16/09 100 0 4381 1882 03/02/2009 to 09/01/2009 08/15/09 100 0 4384 1839 08/14/09 $ 100 0 4391 2600 08/13/09 100 0 4374 0 2082 08/12/09 100 0 4366 1673 08/11/09 100 0 4374 0 1857 08/10/09 a 100 0 4378 0 2345 08/09/09 100 0 4378 0 1951 08/08/09 100 0 4416 0 2844 08/07/09 100 0 4401 0 3388 08/06/09 100 0 4391 0 3241 08/05/09 1; 100 0 4405 0 4012 08/04/09 100 0 4374 0 3981 08/03/09 ` 100 0 4354 0 3298 08/02/09 100 0 4364 0 3871 08/01/09 100 0 4363 0 4719 07/31/09 .I 100 0 4319 0 3475 07/30/09 100 0 4269 0 1482 07/29/09 100 0 4284 0 1915 07/28/09 _ _...1;4Sa 0 4283 0 1676 3/7/2011 4:23 PM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2009 09 01.xIs SCU 42 -05Y A c.\,) \ ‘r cc _)."-\\- CS?s V.To Summary by Month: Individual Well Storage Well Name: SOLDOTNA CK UNIT 42 -05X API: 50- 133 - 20561 -00 -00 Permit to Drill: 2060740 Operator: UNION OIL CO OF CALIFORNIA Field/Pool: SWANSON RIVER, TYONEK GAS ST Sales Cd: 70 Acct Grp: 1 Final Status: GSTOR Current Status: GSTOR 2006 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Shut -In Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Days 0 30 30 27 14 26 Oil 0 0 0 0 0 0 Gas 0 331,869 422,802 110,657 83,366 200,905 2006 Totals: Oil 0 Gas 1,149,599 Cum Oil 0 Cum Gas 1,149,599 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Shut -In Gas Sto Days 21 17 10 29 21 18 13 31 8 10 0 3 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Gas 156,326 106,193 54,252 247,449 74,062 82,060 39,731 139 134,187 41,803 0 19,505 2007 Totals: Oil 0 Gas 955,707 Cum Oil 0 Cum Gas 2,105,306 2008 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Days 3 11 17 30 31 30 31 31 28 23 1 1 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Gas 3,691 117,547 239,096 223,992 212,951 117,095 75,423 44,900 24,393 9,943 1,267 716 2008 Totals: Oil 0 Gas 1,071,014 Cum Oil 0 Cum Gas 3,176,320 2009 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Gas Sto Days 9 14 1 9 31 30 31 Oil 0 0 0 0 0 0 0 Gas 96,694 80,773 1,687 66,627 348,664 162,392 89,080 2009 Totals: Oil 0 Gas 845,917 Cum Oil 0 Cum Gas 4,022,237 Monday, September 14, 2009 Page 1 Summary by Month: Individual Well Production Well Name: SOLDOTNA CK UNIT 42 -05X API: 50- 133 - 20561 -00 -00 Permit to Drill: 2060740 Operator: UNION OIL CO OF CALIFORNIA Field/Pool: SWANSON RIVER, TYONEK GAS ST Sales Cd: 70 Acct Grp: 1 Final Status: GSTOR Current Status: GSTOR 2006 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Flowing Shut -In Shut -In Flowing Flowing Days 7 2 0 0 1 3 Oil 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 Gas 35,263 6,215 0 0 66,196 • 12,889 2006 Totals: Oil 0 Water 0 Gas 120,563 Cum Oil 0 Cum Wtr 0 Cum Gas 120,563 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 0 Meth Flowing Flowing Flowing Shut -In Shut -In Shut -In Flowing Shut -In Shut -In Flowing Flowing Flowing Days 10 9 10 0 0 0 1 0 0 20 4 22 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 0 0 0 0 0 Gas 70,834 56,748 88,933 0 0 0 103 0 0 64 29,621 171,247 2007 Totals: Oil 0 Water 0 Gas 417,550 Cum Oil 0 Cum Wtr 0 Cum Gas 538,113 2008 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Flowing Flowing Flowing Flowing Shut -In Shut -In Shut -In Flowing Flowing Flowing Flowing Days 26 20 29 17 31 0 0 0 5 1 18 27 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 0 0 0 0 0 Gas 227,468 120,442 24,957 12,168 414 0 0 0 448 47,208 222,108 223,913 2008 Totals: Oil 0 Water 0 Gas 879,126 Cum Oil 0 Cum Wtr 0 Cum Gas 1,417,239 2009 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec • Meth Flowing Flowing Flowing Flowing Shut -In Shut -In Shut -In Days 29 14 21 7 0 0 0 Oil 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 Gas 127,939 89,080 46,556 59 0 0 0 2009 Totals: Oil 0 Water 0 Gas 263,634 Cum Oil 0 Cum Wtr 0 Cum Gas 1,680,873 Monday, September 14, 2009 Page 1 Summary by Month: Individual Well Production Well Name: SOLDOTNA CK UNIT 42 -05Y API: 50 -133- 20570 -00 -00 Permit to Drill: 2070820 Operator: UNION OIL CO OF CALIFORNIA Field/Pool: SWANSON RIVER, TYONEK GAS ST Sales Cd: 70 Acct Grp: 1 Final Status: GSTOR Current Status: GSTOR 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Flowing Shut -In Shut -In Flowing Days 4 30 0 0 8 Oil 0 0 0 0 0 Wtr 0 0 0 0 0 Gas 18,925 35,500 0 0 35,047 2007 Totals: Oil 0 Water 0 Gas 89,472 Cum Oil 0 Cum Wtr 0 Cum Gas 89,472 2008 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec • Meth Flowing Flowing Flowing Flowing Shut -In Shut -In Shut -In Shut -In Shut -In Flowing Flowing Flowing Days 27 16 31 30 0 0 0 0 0 9 11 27 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 0 0 0 0 0 Gas 228,082 180,632 5,280 5,255 0 0 0 0 0 80,068 94,718 312,349 2008 Totals: Oil 0 Water 0 Gas 906,384 Cum Oil 0 Cum Wtr 0 Cum Gas 995,856 2009 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Flowing Flowing Flowing Shut -In Shut -In Shut -In Days 14 13 21 7 0 0 0 Oil 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 Gas 182,169 132,598 92,950 570 0 0 0 2009 Totals: Oil 0 Water 0 Gas 408,287 Cum Oil 0 Cum Wtr 0 Cum Gas 1,404,143 0 Monday, September 14, 2009 Page 1 Summary by Month: Individual Well Storage Well Name: SOLDOTNA CK UNIT 42 -05Y API: 50 -133- 20570 -00 -00 Permit to Drill: 2070820 Operator: UNION OIL CO OF CALIFORNIA Field/Pool: SWANSON RIVER, TYONEK GAS ST Sales Cd: 70 Acct Grp: 1 Final Status: GSTOR Current Status: GSTOR 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Shut -In Shut -In Shut -In Shut -In Shut -In Days 0 0 0 0 0 Oil 0 0 0 0 0 Gas 0 0 0 0 0 2007 Totals: Oil 0 Gas 0 Cum Oil 0 Cum Gas 0 2008 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In Shut -In • Days 0 0 0 0 0 0 0 0 0 0 0 0 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Gas 0 0 0 0 0 0 0 0 0 0 0 0 2008 Totals: Oil 0 Gas 0 Cum Oil 0 Cum Gas 0 2009 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Shut -In Shut -In Shut -In Gas Sto Gas Sto Gas Sto Gas Sto Days 0 0 0 1 31 30 31 Oil 0 0 0 0 0 0 0 Gas 0 0 0 4,052 383,772 188,982 84,826 2009 Totals: Oil 0 Gas 661,632 Cum Oil 0 Cum Gas 661,632 • Monday, September 14, 2009 Page 1 , zly= • � � rte, Paul Winslow Chevron North America Chevron Petroleum Engineer Advisor Exploration and Production MidContinent/Alaska SBU 3800 Centerpoint Dr., Ste 100 Anchorage, AK 99503 Tel (907) 263 -7629 ,., Email pwinslow @chevron.com iT_ l February 23, 2009 FEB 2009 Mr. Dan Seamount, Chairman (. Alaska Oil and Gas Conservation Commission 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Annual Material Balance Calculations of Production and Injection Volumes Swanson River Gas Storage Facility #3 (Tyonek 77 -3 sand) Swanson River Field UC , .`� tZ -: ‘\.* - S G:bb\k-\C>tcj Dear Commissioner Seamount:� ® �� Attached for your review is the annual material balance calculation of production and injection volumes for the Swanson River Gas Storage Facility #3 (SRGSF #3), as required per AOGCC Storage Injection Order #6 (SIO #6). SRGSF #3 applies to the Tyonek 77 -3 reservoir, which has had four wells completed in it4Cl1 42A -05 SCU 42B -05. SCU 42 -05X. and SCU 42 -05Y). This material balance report covers the primary production period, as well as the gas storage operations that have taken place from October 1, 2005 to the present time. Attachment #1 is a table of gas production and injection volumes for the SCU 42A -05, SCU 42B -05, SCU 42 -05X, and SCU 42 -05Y wells, from the commencement of primary production (July 2004) up through February 22, 2008. Note that the January and February 2009 volumes are estimated from daily metered values. Historic reservoir pressure estimates have been obtained primarily through surface shut -in tubing pressure (SITP) readings which were then converted to bottomhole pressures. In addition to the SITP's, downhole pressure gauges have been run several times, to obtain static bottomhole pressures and /or to conduct pressure transient tests. These data points are tabulated in Attachment #2 and plotted versus the corresponding net cumulative production on the standard P/Z plot (Attachment #3). Viewing Attachment #3, it has previously been noted that the early injection cycle pressures deviate above the straight line path established from the primary depletion points. Previous Annual Performance Reports have also documented that the production volumes /pressures have deviated below the primary depletion path. The latest 2008 injection and 2008/2009 production cycles mimicked the previously established trends, indicating the continued reservoir confinement of the gas storage volumes. During the peak of the 2007/2008 winter production season (Nov. '07 — Feb. '08), a net total of 852 MMcf of gas was produced from the 77 -3 reservoir. From Mar. - Sep. '08, a net total of 889 MMcf of gas was injected back into storage, via the SCU 42 -05X wellbore. To date (2/23/09) a total of 1,322 MMcf of gas has been withdrawn from storage during the 2008/2009 winter season. Note that after the extended cold period which lasted until mid January, Chevron was MidContinent /Alaska SWU /Chevron North America Exploration and Production www.chevron.com • • Swanson River Gas Storage Facility #3 2008 Annual Performance Report Page 2 able to re- inject a small amount of gas for about a week in mid January (15 — 23 and again in mid February (13 — 20 This injection and offsetting production over the past two months, accounts for the final P/Z vs. cumulative production point seen on Attachment #3. If you have any questions regarding this annual performance report, please contact Paul Winslow at your earliest convenience. Sincerely, 24-M. Paul M. Winslow Petroleum Engineer Advisor Cc: Dave Whitacre Attachments I I Union Oil Company of California / A Chevron Company http: / /www.chevron.com • • ATTACHMENT #1 SRGSF #3 - PRODUCTION AND INJECTION VOLUMES (TYONEK 77 -3 SAND) 42a -05 42b-05 42 -05X 42 -05Y Tvonek 77 -3 Sand Totals L Cum Depletion Inventory Monthly Monthly ' Monthly Monthly • Monthly Monthly • Monthly Monthly , (Prod -Inj) (Primary- Depl Vol) Gas Gas Gas Gas Gas Gas Gas Gas Cum for POZ Total Gas Date Inj Prod Inj Prod • Inj Prod Inj Prod Plotting Inventory MCF MCF MCF MCF MCF MCF MCF MCF MCF MCF Jun -04 0 i 0 2,377,000 D , t..\ cS Jul -04 0 55,040 - 55,040 2,321,960 Aug -04 0 194,185 • 249,225 2,127,775 Sep -04 0 173,352 422,577 1,954,423 Oct -04 0 151,770 ` 574,347 1,802,653 • Nov -04 0 161,949 • 736,296 1,640,704 • Dec -04 0 116,582 852,878 1,524,122 Jan -05 0 160,730 ` 1,013,608 1,363,392 Feb -05 0 160,235 1,173,843 1,203,157 Mar -05 0 164,902 1,338,745 1,038,255 Apr -05 0 156,158 • 1,494,903 882,097 May -05 0 172,327' 1,667,230 709,770 Jun -05 0 162,359,: 1,829,589 547,411 Jul -05 0 157,953. 1,987,542 389,458 Aug -05 0 114,531 2,102,073 274,927 Sep -05 0 71,034 2,173,107 203,893 Oct -05 0 113,342 0 2,286,449 90,551 Nov -05 0 53,196' 0 20,267 ; 2,359,912 17,088 <0 \n‘ (3 Dec -05 0 0 224,142 16,950 2,152,720 224,280 i7 Jan -06 0 31,872 22,827 433, 2,162,198 214,802 Feb -06 0 17,334 172 0; 2,179,360 197,640 Mar -06 0 87,263 ' 24,813 99,300', 2,341,110 35,890 Apr -06 0 30,355 0 106,863 ! 2,478,328 - 101,328 May -06 0 0 311,189 8 2,167,147 209,853 Jun -06 0 0 12,011 0' i 2,155,136 221,864 Jul -06 0 863 0 0 0 35,263 ; 2,191,262 185,738 Aug -06 0 131' 0 0, 331,869 6,215. 1,865,739 511,261 Sep -06 0 0 0 0 422,802 0 1 ' • 1,442,937 934,063 Oct -06 110,657 0 1,332,280 1,044,720 1 Nov -06 83,366 66,196 [ �j 1,315,110 1,061,890 Dec -06 200,905 12,889; 1 1,127,094 1,249,906 Jan -07 156,326 70,834E 1,041,602 1,335,398 Feb -07 106,193 56,7481 ' 992,157 1,384,843 Mar -07 54,252 88,933 t 1,026,838 1,350,162 Apr -07 247,449 0 779,389 1,597,611 May -07 74,062 0 705,327 1,671,673 Jun -07 82,060 0; , 623,267 1,753,733 Jul -07 39,731 103 `. 1 ' 583,639 1,793,361 Aug-07 , 139 0; 0 18,9251' 602,425 1,774,575 Sep -07 134,187 01 0 35,500E 503,738 1,873,262 Oct -07 41,803 64 i 0 0 461,999 1,915,001 • Nov -07 0 29,621 ; 0 0 491,620 1,885,380 Dec -07 19,505 171,247 { 0 35,047 678,409 1,698,591 Jan -08 3,691 227,468' 0 228,082 1,130,268 1,246,732 Feb -08 117,547 120,442 ` 0 180,632 f 1,313,795 1,063,205 Mar -08 239,096 24,9571 0 5,2801' 1,104,936 1,272,064 Apr -08 223,992 12,168 ,' 0 5,2551 ' 898,367 1,478,633 May -08 212,951 414 0 01, 685,830 1,691,170 Jun -08 117,095 01 0 01 568,735 1,808,265 Jul -08 75,423 0' 0 0� 493,312 1,883,688 Aug -08 44,900 01 0 0t ' 448,412 1,928,588 Sep -08 24,393 448 1 0 0 ": 424,467 1,952,533 Oct -08 9,943 47,208 r: , 0 80,068,: 541,800 ., 1,835,200 - Nov -08 1,267 222,108 I 0 94,7181; 857,359 1,519,641 Dec -08 716 223,913 1 0 312,349 1,392,905 984,095 Jan -09 90,992 127,887 r 0 182,125 [ 1,611,925 765,075 Feb -09 • 69655 76,719 . 0 127,244 l` 1,746,233 630,767 January and February (thru 2/22) '09 volumes are estimated from daily metered figures 2/23/2009 O: \NAU \MCBU1Alaska \Depts AssetDev\CIGas \Gas CFT\Openmind\Swanson\Soldotna Creek Unit North \SCU42A -5 \Surveys \Pressure\AOGCC • • ATTACHMENT #2 SRGSF #3 - P/Z VS. CUM PRODUCTION DATA (Tyonek 77 -3 Sand) Parameter Value Units Gas Gravity 0.563 Bench Datum 7811 ft (tvd) Datum Temp. 141 ° F Datum Temp. 601 ° R Initial Z Guess 0.88 - Gauge Test Measured Datum Duration Test Depth Pressure at Pressure, Wellname Date Test Type (hrs) (MTD), ft MTD, psis Z Factor Psia Cum Gas, bcf P /Z, Psia Primary Production 42A -5 06/27/04 Surf PBU 1 0 3994 0.9803 4774 0.0000 4870 42A -5 10/22/04 Surf PBU 1 0 3050 0.9110 3646 0.5354 4002 42A -5 12/21/04 BHP Static 1 7982 3194 0.8933 3194 0.8403 3576 42A -5 2/8/2005 BHP PBU 8 7982 2482(SITP) 0.8859 2926 1.0599 3303 42A -5 06/23/05 BHP PBU 8 7811 1985 0.8835 1985 1.7931 2247 42A -5 07/11/05 SITP 2 0 1565 0.8859 1871 1.8881 2112 42A -5 08/25/05 SITP 3 0 1385 0.8923 1655 2.1024 1855 42A -5 09/13/05 SITP 3 0 1490 0.8883 1781 2.1051 2005 42A -5 10/25/05 BHP PBU 8 7811 1556 0.8959 1556 2.2666 1737 2005 Injection Cycle 142A &B -5 J 1/4/2006 JBHP Static 142 17811 11857 1 0.8803 1 2232 1 2.1423 I 2536 I 2006 Production Cycle 42A &B -5 3/10/2006 SITP 4 0 1895 0.8802 2236 2.1633 2540 42A &B -5 3/18/2006 BHP Static 1 7811 2026 0.8827 2026 2.2260 2295 42B -5 4/12/2006 BHP Static 42a- 120 0 1412 0.8911 1689 2.4038 1895 42B -5 5/4/2006 SITP 96 0 1280 0.8969 1530 2.4783 1706 2006 -2007 Injection Cycle 42A &B -5 5/17/2006 SITP 48 0 1528 0.8871 1826 2.3799 2058 42A5 6/9/2006 Psuedo SITP 192 0 2010 0.8797 2403 2.1551 2732 42 -05X 8/3/2006 SITP/ BHP PBU 15 0 1875 0.8801 2256 2.1976 2563 42 -05X 8/24/2006 SITP /BHP PFO 12 0 2400 0.8851 2886 1.9949 3261 42 -05X 9/7/2006 SITP 24 0 2826 0.9004 3396 1.7610 3772 42 -05X 9/26/2006 SITP 24 0 3347 0.9290 4000 1.4678 4306 42 -05X 10/3/2006 SITP 53 0 3312 0.9267 3958 1.4422 4271 42 -05X 10/6/2006 SITP 11 0 3309 0.9265 3955 1.4390 4269 42 -05X 10/17/2006 SITP 107.5 0 3245 0.9234 3896 1.4127 4219 42 -05X 10/20/2006 BHP PFO 8 7794 _3241 0.9216 3862 1.4015 4191 42 -05X 11/8/2006 SITP 31.5 0 3445 _ 0.9358 4118 1.2840 4401 42 -05X 11/16/2006 SITP 44.5 0 3403 0.9328 4067 1.2497 4360 42 -05X 1/7/2007 SITP 89 0 3469 0.9374 4146 1.1109 4423 42 -05X 4/20/2007 SITP 20 0 3794 0.9626 4534 0.8318 4710 42 -05X 5/22/2007 SITP 8 0 3755 _ 0.9583 4473 0.7523 4668 42 -05X 8/28/2007 _SITP 12 0 3715 0.9561 4440 0.5834 4644 42 -05X 11/26/2007 SITP 840 0 3815 0.9644 4560 0.4622 4728 2/23/2009 0:\ NAU\ MCBU1Alaska1Depts1AssetDev \CIGas \USERS\PMWIGas Storage1Swanson River\SCU 42 -05 77 -3 Sd POZ 2- 17- 09.xls 42ABXY -5 POZ data • • ATTACHMENT #2 SRGSF #3 - P/Z VS. CUM PRODUCTION DATA (Tyonek 77 -3 Sand) Parameter Value Units Gas Gravity 0.563 Bench Datum 7811 ft (tvd) Datum Temp. 141 ° F Datum Temp. 601 ° R Initial Z Guess 0.88 - - Gauge - Test Measured Datum Duration Test Depth Pressure at Pressure, Wellname Date Test Type (hrs) (MTD), ft MTD, psia Z Factor Psia Cum Gas, bcf P /Z, Psia 2008 Production Cycle 42 -05X 12/14/2007 SITP 89.5 0 3647 0.9507 4359 0.5166 4585 42 -05X 1/4/2008 SITP 31 0 3258 0.9231 3890 0.6896 4214 42 -05X 1/23/2008 SITP 7 0 2676 0.8934 3199 0.9690 3581 42 -05X 2/8/2008 SITP 10 0 1990 0.8797 j 2379 1.2923 2704 42 -05Y 2/13/2008 SITP 27.3 0 1909 0.8800 2282 1.3859 2593 2008 Injection Cycle 42 -05Y 5/16/2008 SITP 24 0 3668 0.9476 4311 0.783 4549 42 -05Y 6/6/2008 SITP 216 0 3771 0.9552 4427 0.686 4635 42 -05Y 7/6/2008 SITP 96 0 3915 0.9663 4587 0.567 4747 42 -05Y 9/22/2008 SITP 96 0 3796 0.9571 4455 0.431 4655 42 -05Y 10/7/2008 SITP 96 0 3857 0.9618 4523 0.427 4703 2008 / 2009 Production Cycle 42 -05X & Y 11/13/2008 SITP 72 0 3214 0.9182 3796 0.660 4134 42 -05X & Y 11/30/2008 SITP 24 0 2847 0.8995 3372 0.853 3749 42 -05Y 12/8/2008 SITP 96 0 2719 0.8942 3222 0.941 3603 42 -05Y 1/14/2009 SITP 24 0 1518 0.8880 1792 1.654 2018 42 -05X & Y 2/21/2009 SITP ,48 0 1777 0.8816 2104 1.748 2386 2/23/2009 0: 1NAU\ MCBU1Alaska\ Depts \AssetDev \CIGas\USERS\PMW\Gas StoragelSwanson River \SCU 42 -05 77 -3 Sd POZ 2- 17- 09.xls 42ABXY -5 POZ data ATTACHMENT #3 SRGSF #3 - POZ vs Cum Gas Production Plot (Tyonek 77 - 3 Sand) 6000 A Primary •'05 -'06 Inj Cycle 5000 - 41'06 Prod Cycle •'06 -'07 lnj Cycle ik \ \4\ • ♦ `07 -'08 Prod Cycle 0'08 inj Cycle 4000 if - - - '08 -'09 Prod Cycle a 3000 • 2000 - -- r� a a 1000 • 0 , 0 1 2 3 4 Cum Gas Produced, bcf 2 / 23 / 20090 NAU\ MCBU \Alaska\Depts\AssetDev \CIGas \USERS \PMMGas Storage \Swanson River \SCU 42 -05 77 -3 Sd POZ 2- 17- 09.xIs AOGCC (090223) ~~ `~ ~' ;. 4 < .... ~~ ~. ~'Mr sR. ~~ ~~... ~z _ ~ 3Sx < Y ii V~LA J `.. [ ,~ 4 ;~~ 4 MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporazy Internet Files\OLK9\Microfilm Mazker.doc ~h~?~ll"OC1 ~ranCisCO Castro Chevron North America Exploration and Production r~~ Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 "'''~.. '" Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE October 3, 2008 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 ~~"~~~~%' ~'~~~~~ ~> ~ ~~` Transmitted herewith is the Final Well Mud Report for SCU 42-05X. 'vVELL LOG TYPE SGALE LOG DATE IMER'dF.L LOGGED SCU 42-05X FINAL WELL REPORT 2" 11-Jul-06 136-8152 ~~-~~"~ Please acknowledge re~eipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: ~ 1(/f ff n I Date: _ • . ~~~~'~~ Debra Ouclean Chevron Morth America Exploration and Production -~^~' Technical Assistant 909 W. 9th Avenue ,; Anchorage, AK 99501 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: oudeand@chevron,com September 29, 2008 To: AOGCC Howard Okland 333 W. 7t" Ave. Ste#100 ti' ~~• ~}~ ; , ~ r, ~~~ Anchorage, AK 99501 ~ ~ ~ - ~ CD # WELL LOG TYPE NOTES 1 TBU K-18 K-18RD-VISION SERVICES_RM.LAS LAS ~K-18RD Final Survey.doc doc K-18RD Final Survey.txt ~txt ;Vision Density Neutron-CDR and Log _K-18RD.pds Pds EOW Letter Unocal King Salmon K-18RD.doc Doc 'IPdsview20kit.exe IExe 2 ;SCU 42 05X~SCU 42-05X TCP Guns Correlation 16Ju106.pdf 1 Pdf ASCU 42-05X TCP Guns Correlation 16Ju106.pds 'i Pds 3 :SCU 42-05X~DML DATA Dbraw.dbf DBF Dbraw.mdx ' MDX SCU_42-05X. dbf ~ DBF SCU_42-05X.hdr ~ HDR SCU 42-05X.mdx - MDX _ SCU_42-05X_20060625.mdx MDX SCU_42-05X_20060710.mdx . MDX SCU_42-05X_20060711.mdx MDX s SCU_42-05X_SCL.DBF ; DBF SCU_42-05X SCL.MDX ! MDX SCU_42-05X TVD.DBF : DBF 42-05X TVD.MDX SCU ` MDX _ '' SCU_42-05X xr.DBF 4 DBF 42-05X xr.DBF SCU MDX _ ;FINAL WELL REPORT E SCU 42-05X Well Report.pdf , PDF SCY 42-05X Well Report.doc DOC LAS FILE SCU 42-05X.dat j DAT ,:LOG PDF FILES I Please acknowl ~~- 6th 't'3- la ~o U~-C. 20Co-0~~~ l ~f `~1 1~'~"~~ ~ '} IQt QI t ~'c7~ SCU 42-05X DRILLING MD.PDF PDF SCU 42-05X DRILLING TVD.PDF I PDF i SCU 42-05X LWD COMBO MD.PDF ; PDF SCU 42-()5X L1ND COMBO TVD.PDF ' PDF SCU 42-05X MUDLOG MD.PDF PDF SCU 42-05X MUDLOG TVD.PDF ( PDF receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received ey: j \~ ~ ~~ i ~ Date: ~heo~l~'®i1 Debra Oudean Chevron North America Exploration and Production ~:~ Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 ,,"`'~., . Tele: 907 263 7889 Fax: 907 263 7828 E-mail: oudeand@chevron.com co #S WELL ~ LOG TYPE ~NDTES~ "MORNING REPORTS 20060623.htm HTML 20060624.htm HTML 20060625.htm HTML 20060626.htm (HTML 20060627.htm HTML 20060628.htm HTML 20060629.htm IHTML ~ - 20060630.htm (HTML 20060701.htm HTML 20060702.htm -HTML 20060703.htm HTML 20060704.htm i~HTML 20060705.htm !HTML I ? 20060707.htm HTML 20060708.htm HTML 20060709.htm HTML 20060710.htm ;HTML j 20060711.htm 'HTML 20060712.htm !HTML 20060713.htm HTML REMARKS FILE SCU 42-05X REMARKS.LAS ,LAS 4 SCU 42-05X ?SCU 42-05X USIT 15JUL06.PDF PDF ASCU 42-05X USIT 15JUL06.PDS __ ~ 'PDS 5 ;SCU 42-05X jSCU42-05X EOW Report.pdf _ jPDF 3 ;Survey Text.txt ~TXT z 6 ASCU 42 05X ?OH WIRELINE LOGS DLIS ~' { AIT_DSI_TLD MCFL_020PUC DLIS ~ 7 _-__~~. _____ ~_._~~~~_._.-__..~::--- -.._ =SCU 42 05X OH WIRELINE LOGS _ _~~w__ DLIS AIT_DSI_TLD_MCFL 021PUC.DLIS _ AIT_DSI_TLD_MCFL_022PUC.DLIS 8 'SCU 42 05X `•OH WIRELINE LOGS _ ._ ~ ~ ~ ~~ ~ ^~ Borehole Profile.PDS DS Dsi print.PDS IPDS DSI TVE Print.PDS IPDS PEX TVD print.PDS ~PDS Tcom print.PDS ;PDS 9 HV 2 'PRESS TEMP LOG FINAL PBMS.PDS IPDS ~b3' 1,13 PSP_066PUP.DLIS IDLIS _ _ PSP_066pup.las _ ..: : I,LAS _~ .::_ _ f ~-a01 10 _ _~:_:.. ,_ ...:._ . ... _ 'HV 2 =POWERJET EJ _ .. __ ,r . ! 1'~2b~ COMBINED PERF.PDS IPDS l~od3 PERFO_050LUP.DLIS :DLIS PERFO_051LUP.DLIS DLIS I'~aoy PERFO_069LUP.DLIS DLIS ~ p `~~~~ PEDFO v7vi_v P.DL,iv DLIJ ~ 11 HV 2 POWERJET PJ 2006 ~E Combined.PDS IPDS Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: ._" ~~"`.;: :D # WELL 12 `HV 2 i13 ~HV 2 f i i F ®ebra ®udean Chevron iVorth America Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: oudeand @chevron.com LOG TYPE _ NOTES - Combined.PDS.FMA iFMA PERFO_005PUP.DLIS DLIS PERFO 005PUP.DLIS.FMA ~FMA _ PERFO_006LUP.DLIS DLIS PERFO_006LUP.DLIS.FMA ~ FMA PERFO_007LUP.DLIS ~ DLIA PERFO 007LUP/DLIS.FMA I FMA _RJET BP PERFOCombined.PDS PDS PERFOCombined.PDS.FMA FMA '' PlugCombined.PDS PDS PlugCombined.PDS.FMA ~ FMA _HV2 Combined.PDS ' PDS SCMT_PSP_007PUP.DLIS ' DLIS SCMT_PSP_007PUP.LRS I LAS SCMT PSP_007PUP_NEW.TXT ' TXT SCMT_PSP_008PUP.DLIS i DLIS Le t me know if there is anything you need. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: Okland, Howard D (DOA From: Okland, Howard D (DOA) Sent: Monday, September 22, 2008 1:37 PM To: 'Oudean, Debra' Cc: Davies, Stephen F (DOA); Saltmarsh, Arthur C (DOA) Subject: Digital logging data required by State regulation Importance: High Debra, Am I sending these data requests to the right person? If not please forward to the correct person. We are still missing digital open hole logging data for these wells. This is at least the third time that I have requested this data for two of these wells. Having this data submitted to the Commission in a timely manner is required by State regulation. Additionally it is needed to properly execute our regulatory responsibility. Wells missing data: TBU K-18RD PTD 201-117 API 50-733-20254-01 SCU 42-05X PTD 206-074 API 50-133-20561-00 An additional well Happy Valley A-2 PTD 203-113 API 50-231-20014-00 The open hole data for these wells is long over-due. Please reply to this email by close of business Monday the 29th of September, 2008. Howard 793 1235 22 Sept, 2008 Previous emails are reproduced below. Debra, Have you had any luck finding the digital open hole logging data for the following wells? TBU K-18RD (201-117 API 50 733 20254 O1) SCU 42-05X (206 074 API 50 133 20561 00) Please have the required data delivered to the Commission by the close of business on the 28th of Aug. Your prompt attention to this matter is appreciated Howard 793 1235 Previous emails requesting this data are reproduced below for your convenience. Debra, 1 i This email is a follow up to the email that I sent to you on the 18th of June, 2008 concerning the submission of open hole logging data for the TBU K-18RD well that was completed the 28th of August, 2001. For you convenience the June,2008 email is reproduced here: ///////////////////////////////////////////////////////////////////////// Debra, Our records indicate that no open hole log data was sent to us for TBU K-18RD. This well was completed in August of 2001. Your completion report indicates the, "Schlumberger Anadrill MWD/LWD GR, Resistivity, Neutron Density" logs were run. ////////////////////////////////////////////////////////////////////// Debra, Help. On the 19th of January, 2007 we received paper logs for SCU 42-05X (API 50 133-20561-00) but no digital data. Please send over to the Commission the open hole logging digital data (LIS or LAS and EMF, CGM, PDS, or PDF graphics files) for this well. We would like to have this data by the close of business on the 13th of August. TNX Howard 793 1235 Tracking: Recipient 'Oudean, Debra' Davies, Stephen F (DOA) Saltmarsh, Arthur C (DOA) Delivery Delivered: 9/22/2008 1:37 PM Delivered: 9/22/2008 1:37 PM Read 2 Read: 9/22/2008 1:51 PM Read: 9/23/2008 6:47 AM i Okland, Howard D (DOA From: Okland, Howard D (DOA) Sent: Monday, August 04, 2008 1:43 PM To: 'Oudean, Debra' Cc: Davies, Stephen F (DOA) Subject: SCU 42-05X Importance: High Debra, Help. On the 19th of January, 2007 we received paper logs for SCU 42-05X (API 50 133-20561-00) but no digital data. Please send over to the Commission the open hole logging digital data (LIS or LAS and EMF, CGM, PDS, or PDF graphics files) for this well. we would like to have this data by the close of business on the 13th of August. TNX Howard 793 1235 1 a ~- DATA SUBMITTAL COMPLIANCE REPORT 8/4/2008 Permit to Drill 2060740 Well Name/No. SOLDOTNA CK UNIT 42-05X Operator UNION OIL CO OF CALIFORNIA MD 8155 TVD 8055 Completion Date 8/25/2006 Completion Status GSTOR Current Status GSTOR REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: USIT, Platform Express -Array Induction Dipol Shear Sonic w/Gamma (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T~ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Cog Perforation 5 BS 1 7000 7810 Case 1/19/2007 PDC, GR, CCL 16-Jul-2006 Log Sonic 5 Col 1 2618 8100 Open 1/19/2007 MD Dipole Shear Sonic Tool w/GR 8-Jul-2006 Cement Evaluation 5 Col 1 2600 8000 Case 1/19/2007 USIT, CE, GR, CCL 15-Ju1- 2006 ~ Log Sonic 5 Col 1 2618 8040 Open 1/19/2007 TVD Dipole Shear Sonic Tool w/GR 8-Jul-2006 ~og NeetrOn ~;~,~~ "~ 5 Col 1 2618 8040 Case 1/19/2007 TVD Array Induction, CNL, Form Den, Sonic Imager, / _ (( ( GR 8-Jul-2006 Log Nea4r'vn a .~.cu.v`~h. .~/~ 5 Col 1 2618 8040 Case 1/19/2007 MD Platform EX Array Induction, CNL, Form Den, Sonic Imager, GR 8-Jul- 2006 / /Log Caliper log 5 Col 1 2618 8040 Case 1/19/2007 Borehole Caliper Profile w/GR 8-Jul-2006 Well Cores/Samples Information: Sample Interval Set N me Start Stop Sent Received Number Comme nts ', Cuttings 2650 8155 1217 API No. 50-133-20561-00-00 r~ LJ • DATA SUBMITTAL COMPLIANCE REPORT 8/4/2008 Permit to Drill 2060740 Well Name/No. SOLDOTNA CK UNIT 42-OSX Operator UNION OIL CO OF CALIFORNIA MD 8155 ND 8055 ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? '4TN~ Analysis Y~l'1~' Received? Comments: Compliance Reviewed By: Completion Date 8/25/2006 Completion Status GSTOR Current Status GSTOR Daily History Received? ~N Formation Tops ~N API No. 50-133-20561-00-00 UIC Y Date: CJ • uzcac Chevron January 15, 2007 C ,udean Chevron North Ar Exploration and Production Tee: .gist 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: oudeand@chevron.com To: AOGCC Howard Okland 333 W. 7th Ave. 5te# 100 Anchorage, AK 99501 ~ a.m -~' ~ Q o ~~ z z ~ o qua: ~ _ w Q~ ~ p cp - p z~ ~ m u. U O~~ z a z_ J J 199-083 501331012501 SCU 21A-09 PERFORATION RECORD 2.5 5 INCH 5/20/2006 10000-10492 1 1 ~ 1 1 pds i I OMEGA HSD 161-024 501331011400 SCU 41-05 DEPTH DETERMINATION LOG ~ 5 INCH 8/27(2006. 2000-4032 1 1 1 1 PDS j , GRICCL ~ I _ i ,161-024 501331011400 SCU 41-05 ABANDONMENT RECORD 2.5 5 INCH 1690-7619 1 1 0 1 PDS HSD POWERFLOW SQUEEZE I PERF i ,161-024 501331011400 SCU 41-05 -- DEPTH DETERMINATION LOG 51NCH 9/17/2006 2000-7701 1 1 1 1 pds ~ GAMMA RAY I CCL _. ~~_ p 01332056100 SCU 42-05X ARRAY INDUCTION /COMP 51NCH 7!8/2006' 12618-8040 1 1 0 0' ~ NEUTRON/ FORMATION : DENSITY/ SONIC IMAGER/ GR 501332056100 . SCU 42-05X TVD _. PLATFORM EXPRESS -ARRAY 5 INCH 718/2006 _ _ 100-8010 1 1 0 0 INDUCTION DIPOLE SHEAR SONIC TOOL W/ GR i 501332056100 SCU 42-05X BOREHOLE CALIPER PROFILE ~ 2 INCH i 718/2006 2618-8040 [1 1 0 0 WIGR 501332056100 SCU 42-05X PERFORATING DEPTH 5 INCH' 7/16/2006'. 7000-7810 1 1 1 0' ' CORRELATION i 501332056100 SCU 42-05X _ _ DI COLE SHEAR SONIC TOOL 5 INCH 7/8!2006 2618-8100 1 1 0 ( 0 ' I 501332056100 SCU 42-05X DIPOLE SHEAR SONIC IMAGER 5 INCH 718/2006 2618-8040 1 1 0 0 WIGR TVD I I _ 501332056100 SCU 42-05X ULTRA-SONIC IMAGING TOOL / _ 5 INCH. 7/15/2006 2600-8000 1 1 0' 0 CEMENT EVALUATION / GR ! i CCL ' 188-0157 501332040500 SRU 242-16 RECORD 2 5 PERFORATION 5 INCH 8/2712006 3650-3954 1 1 1 1 PDS PDF _- - - POWERJET HSD GUNS J , ` _ `___ ~_ _ _ _ _~___ Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: MEMORANDUM TO: Jim Regg ~ JZ~zoIL~/o P.I. Supervisor l FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska OiI and Gas Conservation Commission DATE: Monday, December 18, 2006 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 42-05X SOLDOTNA CK UNIT 42-OSX Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~ Comm Well Name: SOLDOTNA CK iJNIT 42-OSX Insp Num: mitJJ061215100212 Rel Insp Num API Well Number 50-133-20561-00-00 Permit Number: 206-074-0 Inspector Name: Jeff Jones Inspection Date: 12/13/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well az-o5x Type Inj. ~ G TVD ~ 76s6 ~ IA ~ 9so zo7s ' i 2075 j zo7s ~~~ - P.T. 2060740 TypeTeSt i SPT ~~ TCSt pSl , 1921.5 i OA ~ t ]65 ~ 162 165 t65 T ~ Interval 4YRTST P~ P TUbing 3500 ~ 3500 I 3500 i 3500 NOtes I BBL diesel pumped. 1 well site inspected; no exceptions noted. ~! Monday, December 18, 2006 Page 1 of 1 _ C r ~~"1 STATE OF ALASKA ALASK; . LAND GAS CONSERVATION COMMIS AU G ~ 3 2006 WELL COMPLETION OR RECOMPLETION REPOR„~_~-lal~,i~~~, TRUE Oil ^ Gas ^ Plugged ^ Abandoned ^ zoAnczs.~os GINJQ WINJ^ WDSPL^ No. of Completions Suspended ^ WAG ^ zoa4czs.~~o 1 Other 1 b. W Development ^ Anct~(~9~tory^ Service ~ StratigraphicTest^ 2. Operator Name: Union Oil Company of California 5. Date Comp., Susp., or Aband.: July 25, 2006 12. Permit to Drill Number: 206-074 3. Address: P.O. Box 196247, Anchorage, Alaska 99516 6. Date Spudded: June 22, 2006 13. API Number: 50-133-20561-00 4a. Location of Well (Governmental Section): Surface: 1893' FSL, 509' FEL, Sec. 5, T7N, R9W, Seward Meridian 7. Date TD Reached: July 11, 2006 14. Well Name and Number: SCU 42-05X Top of Productive Horizon: ~~ FSL, 489 F EL, Sec. 5, T7N, R9W Seward Meridian 8. KB Elevation (ft): 21 15. Field/Pool(s): Swanson River Field hh ~~ Total Depth: ~~ g/~~~f~ 2659' FSL, 483' FEL, Sec. 5, T7N, R9W Seward Meridian 9. Plug Back Depth(MD+TVD): 8047'/7947' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 341805.22 y- 2457852.09 Zone- 4 10. Total Depth (MD + TVD): 8155'/8055' 16. Property Designation: A028996 TPI: x- 341838.93 y- 2458615.51 Zone- 4 Total Depth: x- 341841.5 y- 2458617.93 Zone- 4 11. Depth Where SSSV Set: None 17. Land Use Permit: N/A 18. Directional Survey: Yes 0 No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: N/A 21. Logs Run: USIT, Platform Express -Array Induction Dipol Shear Sonic w/ Gamma Ray. 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 13.375" 72 L-80 0 96' 0 96' Drive N/A None 9.625" 47 L-80 0 2621' 0 2540' 12.25" 765 sxs. G None 7" 26" L-80 0 8130' 0 8030' 8.5" 659 sxs. G None 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 77-3 Sand: 7883-7896' (7783'-7796' TVD), 4-5l8" TCP Guns @ 5spf. 3.5" 7870' 7787' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED None 26. PRODUCTION TEST Date First Production: July 24, 2006 Method of Operation (Flowing, gas lift, etc.): FIOWIn Date of Test: 7/25/2006 Hours Tested: 1/5/1900 Production for Test Period Oil-Bbl: None Gas-MCF: 1.00 Water-Bbl: Trace Choke Size: 24/64 Gas-Oil Ratio: N/A Flow Tubing Press. 1500 Casing Press: 120 Calculated 24-Hour Rate -- Oil-Bbl: None Gas-MCF: 4.8 Water-Bbl: Trace Oil Gravity -API (corr): N/A 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None COMPLETION ATE R~ S ~F~ auc ~ ~ zoos v em 'sign Form 10-407 Revised 12/2003 CONTINUED ON REVERSE 28. GEOLOGIC MARKE 29. ORMATION TESTS NAME TVD Include and briefly su ize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state Beluga Formation 3388' 3290' "None". None Tyonek Formation 5478' 5379' 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: Timothy C. Brandenburo Title: Drilling Manager Signature: ~~~--- Phone: (907) 276-7600 Date: ~- l -"~-~,~, INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and iog 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, Sait Water Disposai, Water Supply for I 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 elevation in feet above mean low low water. 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: True vertical thickness. 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, andrn 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: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Chevron • Wellbore Schematic: SCU 42-O5X As Completed Well Name: SCU 42-05X Operator: Union Oil Company of California Field: Swanson River Unit: Soldotna Creek API: 50-133-20561-00 Permit: 206-074 Well Status: Gas Storage RKB: 174' above MSL, 23' above GL TDIND: 8,155' MD/8,055' ND PBTD/PBND: n/a Casin Detail Size Wt Grade Type Top (FT) Btm (FT) Length (FT) 13-3/8" 72# K-55 Weld/Drive 0.00 96 96 9-5/8" 47# L-80 BTC 0.00 2,621 2,621 7" 26# L-80 BTC 0.00 8,130 8,130 Tubin Detail Size Wt Grade Type Top (FT) Btm (FT) Length (FT) 3-1/2" 9.2# L-80 Atlas Bradford TC-2 0.00 7,787 7,787 Jewel Detail 1 Side Pocket Chemical Injection Mandrel 2,491 2 CMD Sliding Sleeve 7,732 3 BOT SAB-3 Perm. Packer with a K-Anchor and Mill out extension 7,787 4 XN-Nipple 7,808 5 3-1/2" Ported Sub 7,829 6 3-1/2" IBT x 2-7/8" EUE XO 7,830 7 Full Joint 2-7/8" EUE Tubing 7,831 8 2-7/8" Wire Line Re-Entry Guide (Halliburton Automatic Release Assy.) 7,870 9 Top of Dropped TCP Assy. (32.8' long) 8,015 Perforation Detail Zone SPF Date Top (FT) Btm (FT) Length (FT) 77-3 5 7/24/2006 7,883.00 7,896.00 13.00 Last Revised: 8/2/2006 Revised By: LWB • • Daily Operations Summary SCU 42-05X Swanson River Field, Alaska 5/14/06: Perform dirt work on existing pad. 5/15/06: Perform dirt work on existing pad. 5/16 - 5/22/06: No Activity. 5/23/06: Install 10' Cellar. 5/24/06: Install 10' Cellar. 5-25 - 5/30/06: No Activity. 5/31/06: Prepare location to drive conductor. 6/1/06: Move in unit and start to drive 13-3/8" conductor. 6/2/06: Finish driving conductor to 96'. Cut off conductor and install wellhead. 6/2 - 6/5/06: No Activity. 6/6/ - 6/10/06: Mobilize Grind and Inject Unit. 6/10 - 6/19/06: No Activity. 6/20/06: Move Kuukpik #5 rig onto location. 6/21/06: Continue to move in and rig up. Function test diverter. M/U 12-1/4" BHA. Spud well drilling to 166' with 8.8 ppg water base mud. 6/23/06: Rotary drill 12-1/4" hole to 410'. Take gyro survey. Sweep hole with high vis and condition hole. POOH. M/LJ 12-1/4" directional BHA. RIH and drill to 562' with a 9.0 ppg water base mud. 6/24/06: Continue to directionally drill 12-1/4" hole to 2309' taking gyro surveys on e-line with a 9.2 ppg water base mud. 6/25/06: Continue to drill 12-1/4" hole to surface casing point at 2635' with a 9.2 ppg water base mud. Circulate and condition mud. Pump out of the hole. 6/26/06: R/LJ to run 9-5/8", 47#, L-80 casing. Run casing and land hanger with casing shoe at 2631'. Circulate and condition mud. Cement with 29 bbls mud push followed by 160 bbls 12.8 ppg G cement followed by 46 bbls 15.8 ppg G cement. Bump plug with 3200 psi and hole for 30 minutes. Full returns during 1 • • Daily Operations Summary SCU 42-OSX Swanson River Field, Alaska job and 29 bbls of cement to surface. 6/27/06: N/D diverter and line. N/U BOPE. Set and test casing annular pack-off with 5000 psi. 6/28/06: Test BOPE to 5000/250 psi. M/U 8-1/2" directional BHA. RIH and drill out float equipment, rat hole and 20' of new formation to strap measurement of 2545'. Pull up into the casing and perform a 15.8 ppg EMW FIT. 6/29/06: Directionally dri118-1/2" hole to 3700' with a 9.7 ppg water base mud. 6/30/06: Pull back into the 9-5/8" casing while repairing mud pump. 7/1/06: Stage back into the hole and dri118-1/2" hole to 5745' while bringing the mud weight up to 11.5 ppg 7/2/06: Dri118-1/2" hole to 6462' with a 12.4 ppg water base mud. 7/3/06: Drill 8-1/2" hole to 6475'. Circulate and condition mud. POOH for bit change. 7/4/06: Service rig and M/U new bit. RIH. Drill 8-1/2" hole with 12.4 ppg water base mud to 6665'. 7/5/06: Drill 8-1/2" hole to 7465' with a 12.4 ppg water base mud. 7/6/06: Drill 8-1/2" hole to 8007' with a 12.4 ppg water base mud. 7/7/06: Dri118-1/2" hole to 8122' with a 12.4 ppg water base mud. Circulate and condition mud. POOH to 9-5/8" casing shoe. 7/8/06: RIH to 8,101'. Circulate and condition mud. Pump high vis sweeps. POOH for logs. R/U to run logs. 7/9/06: Run quad combo open hole logs thru 8-1/2" section and GR thru surface casing. M/U clean-out BHA and RIH to 7,047'. 7/10/06: Ream to 7,100'. Circulate and condition mud. POOH for BHA change. Test BOPE to 250/5000 psi. M/U new clean-out BHA and RIH to 7365'. 7/11/06: Ream to 8,122' and drill casing rat hole to 8,155' with a 12.50 ppg water base mud. Short trip to 7,000' and run back in hole to 8,155'. Circulate and condition mud. POOH. 2 • • Daily Operations Summary SCU 42-OSX Swanson River Field, Alaska 7/12/06: Finish out of hole. Change top rams to 7" and test to 250/3000 psi. R/U and run 7" casing to 8130'. 7/13/06: Land 7" casing. R/U cementers and circulate 7" casing with 12.5 ppg water base mud. Cement 7" casing with 10 bbls chemical wash, 40 bbls mud push, 30 bbls 13 ppg lead followed by 145 bbls 13.3 ppg tail. Displace cement and stop displacement before bumping plug. Set casing annular packoff. Change top pipe ram to 2-7/8" x 5" VBR. Test to 250/5000 psi. Set casing annular packoff. M/U 7" casing clean-out BHA and RIH on 3-1/2" drill pipe. 7/14/06: RIH with clean out assembly to 7995'. Clean out cement from 7,995' to 8,047' Displace well to 3% KCL brine. POOH. 7/15/06: POOH laying down 3-1/2" drill pipe. R/U e-line. Run cement evaluation log. R/D e-line. Test 7" casing to 250/5,000 psi for 30 minutes. R/U and run 4-5/8" TCP completion on 3-1/2" tubing. 7/16/06: Continue to run 3-1/2" completion string. R/LJ e-line. Test lubricator to 300/1,SOo psi. RIH and log for depth correlation. Space out completion and M/U tubing hanger and land same. R/U e-line and run second correlation logging run. Close pipe rams and set tubing hanger pack-off with 5,000 psi. R/U slick line. RIH and land N-test tool in the XN nipple below the packer. Pressure up to 4,000 psi to set packer and test tubing. Set packer. Pressure test annulus to 1500 psi for 30 minutes. R/D slick line. 7/17/06: N/D BOPE. N/U and test tree to 5,000 psi. Release rig to rig move. 7/18/06: Rig move. 7/19/06: Rig move 7/20/06: Conduct MIT with AOGCC inspector present to 2500 psi on 7" casing x 3-1/2" tubing annulus. Test down tubing and below packer to 3,400 psi. R/U slick line. RIH to shift sliding sleeve open. 7/21/06: Shift sliding sleeve open. Circulate well with packer fluid. 7/22/06: R/U nitrogen unit and test lines to 6,000 psi. Displace tubing with nitrogen. Reverse diesel freeze protect cap into the tubing x casing annulus. RIH and shift sliding sleeve closed. Pressure up tubing to 5,000 psi with nitrogen. Bleed nitrogen back to 3,000 psi. Shut well in. R/D nitrogen. 7/23/06: Install surface flow lines. • Daily Operations Summary SCU 42-05X Swanson River Field, Alaska 7/24/06: Install surface flow lines. 7/25/06: Bleed nitrogen back to 1602 psi. Drop bar and fire TCP guns. Open well and flow back to clean-up. Release well to Production Group. Final Report. 4 Chevron Actual Wellpath Report Positional Uncertainty GSS<0-1360'>MWD<1392 - 2560'>MWD<2622 - 8122'> Page 1 of 6 ~~~ BAKER NuaNEs INTEQ ~ ~ Operator Chevron Slot SCU42-OSX Area Cook Inlet, Alaska (Kenai Penninsula) WeII 42-OSX .Field Soldotna Creek Unit Wellbore 42-05X Facility Sec.S, T7N, R9W Location lity Reference Pt i Reference Pt Local coordinates North [feet] East [fee 1892.87 -509.10 Grid coordinates Ming [US feet] _ Northing [US feet] 341805.22 2457852.09 342288.86 2455952.70 347568.07 2455882.99 Latitude [°] 60 43 28.665N 60 43 10.025N 60 43 10.024N coordinates Longitude [°] 150 53 00.901 W 150 52 50.666W 150 51 04.527W Calculation method ~ Minimum curvature ~ Kuukpik #5 RKB (RKB) to Facility Vertical Datum 174.00 feet Horizontal Reference Pt _ _ ~ Slot __ _ ~_ ~ Kuukpik #5 RKB (RKB) to mean sea level . 174.00 feet Vertical Reference Pt Kuukpik #5 RKB (RKB) Facility Vertical Datum to Mud Line (Facility) 0.00 feet MD Reference Pt ~ Kuukpik #5 RKB (RKB) ~ ~~ ~ Section Origin N 0.00,E 0.00 ft Field Vertical Reference mean sea level ...~~_ Section Azimuth 2.06° POSITIONAL UNCERTAINTY CALCULATION SETTINGS Ellipse Confidence Limit 3.00 Std Dev Ellipse Start Depth 0.00 feet Surface Position Uncertainty not included Declination 19.66° East of TN Dip Angle 73.64° Magnetic Field Strength 55549 nT chevron. Actual Wellpath Report ~~" Positional Uncertainty BAKER GSS<0-1360'>1v1wD<1392 - 2560'>MwD<2622 - 8122'> NYQrNES . Page 2 of 6 INTEQ Cook Inlet, Alaska (1 Soldotna Creek Unit Sec.S, T7N, R9W slot ELLPATH DATA (102 stations) -with Positional Uncertaint values MD (feet] Inclination [°] Azimuth [°] TVD [feet] Vert Sect [feet] North [feet] East [feet] Grid East [us survey feet] Grid North [us survey feet] DLS [°/IOOft] Build Rate Turn Rate ] [°/IOOft] [°/IOOft] Major Semi-Axis [feet] Minor Semi-Axis [feet] Vertical Semi-Axis [feet] Minor Axis Azim [°] og omment 0.00 0.000 0.000 0.00 0.00 0.00 0.00 341805.22 2457852.09 0.00 O.OOj 0.00 0.00 0.00 0.00 0.000 100.00 ' 0.130 269.430. 100.00 -0.01 0.00 -0.11 341805.11 2457852.09 0.13 0.131 0.00 0.16 0.16 3.45 179.430 200.00 0.240 309.560 200.00 0.12 0.13 -0.39 341804.83 2457852.23 0.16 0.11j 40.13 - 0.36 0.35 3.45 12.968 30_0.00: - 362.00 0.450 _ - 0.250] 313.760, 300.00 - 299.260. i _ 362.00 ~ 0.51 _ 0.73 '. _ 0.54 0.77' -0.83 -1.13 ~ 34]804.39' 2457852.64 _ 341804.10 ~ 2457852,88 ' 0.21 3 0.21; 4.20 _ -. - 0.35 ; -0.32 -23.39 0.491 0.47 _. - 0.54 0 52` 3.45 24.899 - -- - 3.45 26.9(14 - - -- _ 400.00 0.380 317.260' 400.00 0.86 0.90 -1.29 341803.95 - 2457853.01 0.43 ~ 0.34. 47.37 0.56 0.54 3.46 28.178 500.00 1.510 14.900; 499.98 2.38 2.42 -1.17 341804.08 2457854.53 1.35 1.13 57.64 0.63 0.60 3.46 38.933 536.00 2.660 24.420! 535.96 3.61 3.64 ' -0.70 _ 341804.57 ' 2457855.74 3.33 3.19 26.44 0.66 0.64 3.46 52.840 600.0_0 4.980 27.10(1 _ 599.81 7.50 7 ~17 ' 1.18 341 C~ ~~ .~0 I 2457859.54 3.63 3 631 4.19 0.71 0.68 3.46 87.402 654.00 6.470 3b 070 -- 653.52 ' 12:52 12.39_ ; - 3.89 j 341804.27 ; 2457864.42 ; _ 3.73 _ _ 3 69', 5.50 __ _ 0.79 0.7R - 3.46 1062691 700.00 ' 8.100 -- 28.730 699.12 17.88 _ 17.65 6.84 341812.30 2457869.64 ] 2.49 ~ _.-16 -2.91j - 0.86 0.79 3.45 108.715 _ 70.00 ' 8.290 29.680 748.61 24.22 _ _ 23.87 10.32 341815.86 2457875.81 __ 0.47 0.38' 1.90 0.91 0.85 3.45' 103.512 800.00 _ 9.170 27.350 798.03 31.02 30.54 13.93 341819.56 2457882.43 1.90 _ 1 76_t _ _ -4.66 0.95 0.91 3.46 92.262 80.00 'i 10.350 23.39_0 R4730 ... - 38.80 --- - 38.20. - 17 .55 - 341823.28 2457890.05 2.71 2.36 -7.92 1.02 0.96 3.45 82.523 900.001 - - 11.460 _ - j 19.190. 896.40 -- ~ - ~ 47.73 _ 47.01 ~ 20.96 34182$:81 , 2457898.81 ~~~ - - - ---~ - ' -- - - _ 8.40 2.73 2.22 1.11' 1.02 - 3.45 74.758 _ _-_„ - 950.00 13.200 10.800 945 25 ~ 58.12 ~ 57.31 ~ 23.67 341829.65 2457909-07 4.99 Y 3.48 -16.78 121 1.08 3.44 68.620 _ __ 1000.00 13.770 6.950 993.87 ~ 69.70 68.83 25.46 341831.60 ' 2457920.56 2.13 1.14; -7.70 1.31j ~ 1.15 3.43. 61.293. 1050.00 13.860 4.100 1042.43 81.61 80.71 26.61 3.41832.91 2457932.43 1.37 0.185.70 1.39 1.22 3.44 51.349 1100.00 14.010 2.500 ~ 1090.95 93.65 92.73 , - - 27.30 - 341833.76 _- 2457944.44 0.83 0.30 -3.20 -- 1.45 - 1.27 3.45 42.465 150.00 -__._. 1200.00. 3 940', x_8.580 _ T __ _ 14.700 354.930 139.48 105.71 1187.92 i 118.02 ~- __r 04.80 I 117.14 7.41 , 341834.04 ~ 26.70 341833.49 ~ _ 457956.50 ---- 2457968.85 90 1. .36 2 -- 014 _ - - 1.52 -7.84 1.53 7.30 1.61 L r 1 3 1.36 ---- - 3.46 .46 _ 35.516 1.746 1250.00 1300.00 16.070 _ 354.450 17.990 354.880 1236.13 ~ 131.17 145.69 1283.93 130.34 144.92 25.47. 341832.44 24.11 341831.28 2457982.07 2457996.66 2.75 2.74- -0.96 1.69 3.85 3.84 0.86a 1.78 1.44 1.55 3.46 3.44. 30.068 29.10' .0 1392.00 ? _ _ 18.400 355.000 _ 1371.36 - 164.15 163 45 - -- 174.10 173.44 j 22.39 't41829.80 2458015.21 0.33_ - - 1.90 _ - _ ©.81~ ~.69~ 21.46 ~ 341829.01 FvW~ 2458025.21.: 0.97 ' ~ 2.00 .66 _ ~ 4.Q7 1.821 _ ---39.865 ~ _. Chevron Actual Wellpath Report Positional Uncertainty GSS<0-1360'>MWD<1392 - 2560'>MWD<2622 - 8122'> Page 3 of 6 ~~r BAKER NYQMES. INTEQ Operator ~ ~ Chevron ~ Slot SCU42-OSX '.Area Cook Inlet, Alaska (Kenai Penninsula) Well 42-OSX Field Soldotna Creek Unit Wellbore 42-OSX Facility Sec.S, T7N, R9W ELLPATH DATA (102 stations) -with Positional Uncertain values MD [feet] Inclination [°] Azimuth [°] TVD (feet] Vert Sect [feet] North [feet] East [feet] Grid East [us survey feet] Grid North [us survey feet] DLS [°/100ft] Build Rate [°/100ft] Turn Rate [°/100ft] Major Semi-Axis [feet] Minor Semi-Axis [feet] Vertical Semi-Axis [feet] Minor Axis Azim [°j og omment 1453.00 18.000 355.500 1429.31 193.01 192.42 19.89 341827.69 2458044.21 0.70 -0.66 0.82 2.13 1.91 4.14 19.294 1513.00 17.900 354.600. 1486.39 211.37 210.85 18.29 341826.34. 2458062.66 0.49 -0.17 . -I.SO 2.46 2.01 4.21. 4.396 1575.00 18.100 354.300 1545.36 230.36 22_9.91 16.44 341824.7 5 ; 2458081.75 0.36 0.32 -0.48 2.95 2.13 4.28 359.107 . 637.00 17.600 -_ --~ 1697.00 17.700 54.600: 1604.37 - - --- 354.200 1661.55 49.19 ( - 267.22 I 48 83 14.60 -- 266 94 ; 12.82 ~ _ 341823 16 . 2458100.68 - - ~ 341821.63 2458118.81 .82 -- 0.26 ', _ 0 81 _ 0.17 -__ _~ ^ ' 0.48 3.49 __ -_ 0.67,,-- 4.06 _ 2.27 . --- 2.43 4.36 -4.45 _ 'i57 011 356.015 '` 1760.00 i, 17.800 354.5001 1721.55 286.26 286.05 ~ 10.93 341820.00 2458137.94 0.22 0.16 0.48 4.68 2.61 4.53 355.362 1820.00 17.600 353.900 1778.71 304.33 304.20 9.09 341818.40 2458156.11 0.45 -0.33. -1.00 5.29 2.79 4.62 354.939 1881.00 ' 17.500 354.100 1836.87 322.54 322.49 ; 7.17 __ _ 341816.72 ,2458174.43 019 _ ~ -0.16 0.331 5.92 2.98 4.71 354.621 1943.00 17.400 354.400 1896.02 ~ 340.96 340 99 ; _ x.30 ! 34 181_.11 248192.95 r- 0.22 _ 0 16 0.48. 6.56 ' ~ 3 19 T ~ 5 - _ 2004.00 '~ 17.500 _ _ 353.9001 1954.21 j _ 359A8 ; 359 19 ~ j _ 2458211.17 344 -~418I3.49 "' 0.30 i _ _ 0.16 - 0.82 ~, 7.19 ~ 3.40' 4.89 354.27 ' 2067.00 ' ]2800 355.700 2014.24 378.02 378.21 _ 1.71 341812.02 2458230.21 099' 0.48 2.86 7.86 - 3.63 4.99 ! 354.190 2128.00 17.900 358.200. 2072.31 ' 396.64 396.87 0.72 341811.28 ~ 2458248.89 1.27 _ 0.16 _ 4.10 8.53 _ 3.86 5.09 354.256 2190.00 18.000 357.700 2131.29 415.70 415.97 0.03 341810.85 2458267.99 0.30 0.16, -0.81 9.20 4.10 5.19 354.451 2251.00 17.700 _._- 358.300 2189.35. _434.35 434.66 -0.62 341810.45 2458286.68 0.58 -0.49 0.98 , 9.86 4.33 5.29 354.648 © 359 0 0 2249 27 453.79 ! ) 4 2 __ 097 341$14.36 _ ..- 2458,06.15 _ 1.i5 _ = 0.95 2.06 __ 10.55 - _ 4 58 _ _ 5_40, ~ 354.B72 f __ 7 _ . 2307.10 i 473.19 473 52 - -- -0.80 341810.79 - _ " ~" 2458325.» -- 1.25 --- ~_ _ - - ~ 0.82 2.9~~ 1` _ _ ___ 4.84 _ - 5.50 __ ___ 355.17. ` 243 8.00 18 70 _ 0 0 2366.76 ~ 493.44 493.77 _0.25 341811.61 ~ 2458345.78 0.22 - 0.16 0.48 11.95 ~ 5.10 5.62 355.453 2499.00 18.800 0.900 2424.52 513.04 513.37 0.19 .341812.32 2458365.37 0.45 0.16 -1.31 12.64 5.35 5.73 355.760 2560.00 - 19.000 1.100, _ --- 2482.23 I 532.80 - - 533.12 0.54 341812.93 2458385.12 , _... 0.34 0.33 0.33j - _ 13.34 5.60 5.84 356.019 - 2622 00_j _ 18.200; 1.10(? 2540.99 552.57 ~ --- 552.90 i -, ~ 0.92' 341813.57 '~ - _ 2458404.88 1.29 ~ _ - r - -1.29 0_OO~i 13_97 - 5.74: 5.45 - 356.271 -- 2684.00 16.600 358.800 2600.16 , 571.10 571.43 0.92 ' 341813.82 2458423.42 2.81 -2.58 -3.71 ~ 14.51 5.77 6.06 356.437 2745.00 16.500 358.600 2658.63 588.44 588.80 0.62 341813.66 2458440.79 0.19 -0.16' -0.33 15.03 5.84 6.17. 356.482:. 2806.00 14.600 358.800 2717.39 i 604.77 605.15 0.15 341813.51 2458457.14 3.12. -3.11: 0.33 15.52 5.89 6.28 356.577' 2929.0 _. _. ._ 11.500 359100 0 _..___-._... 2875.13 ! 62.82 ' 633.14 ~ 37 ~ 2 , ~._..._ _._",. .. 0 13 ~ 341813 43 .36 , 3.38 ? ~.a. 2458485.23 ~ 2.00 2 5 i 3.02 - ~_~_e...., - ?.021 ~ 0.13 --15.96 3 0. 6 16.38 .... _____... 6.OOf 6.09, 6.39 ~ 6.SI x - 356.659 - , f 356.732 Chevron Actual Wellpath Report Positional Uncertainty GSS<0-1360'>MWD<1392 - 2560'>MWD<2622 - 8122'> Page 4 of 6 ~ir~ BAKER NYGNES INTEQ Operator ~ ~ Chevron Slot SCU42-OSX Area Cook Inlet, Alaska (Kenai Penninsula) ~ Well 42-OSX Field Soldotna Creek Unit Wellbore 42-OSX Facility Sec.S, T7N, R9W LLPATFI DATA (102 stations) -with Positional Uncertaint values MD [feet] Inclination [°] Azimuth [°] TVD [feet] Vert Sect [feet] North [feet] East [feet] Grid East [us survey feet] Grid North [us survey feet] DLS j Build Rate [°/100ft] ~ [°/100ft] Turn Rate [°/100ft] Major Semi-Axis [feet] Minor Semi-Axis [fee[] Vertical Semi-Axis [feet] Minor Axis Azim [°] og omment 2989.00 10.700 0.300 2896.00 644.36. 644.79 -0.42 341813.47 2458496.78 1.39 -1.33 2.00 16.74 6.20 6.62 356.803 3051.00 10.700 1.700 2956.92 655.87 656.30 -0.22 341813.83 ~ 2458508.29 0.42 0.00 2.26 17.10 6.28 6.73 356.908 3113.00 9.200 356.500 3017.99 666.56 667.00 -0.35 341813.84 2458518.99 2.82 _-2.42 -8.39 17.44 6.36 6.84 356.942 31_7_5.00 ~~ 3236.00 __ 8.500 - 8.700 35.3.4.00 - X52.200; 3079.2.5_ 139.5? 676.02 - 685.03 ~ 676.50 85.55 ~ -1.18 _ - 2.32 ; 341813.14 ~ X41812.121 245852_8.50 2458537.56 1.37 -1.13 0.44'.. 0.33'~~ -5.00 - 1.97 - 17.76 18.05 6.47 ~ 6.56' 6.96 356.849. -- 7.07: 356.7671 _ - ~ 3298.00 8.800 351.100 3200.85 694.30 694.88 -3.69 341810.87 2458546.91 0.31 ~ 0.16 -1.77 18.36 6.65 7.18 356.678 3360.00 8.000 357.400 3262.18 703.26 703.88 -4.62 341810.06 I 2458555.91 1.96 , -1.29 10.16 18.66 6.74 7.29 356.641 3421.00 7.100. 3.800 - 3322.65 --- 711.26 711.88 -4.57. ._- 341810.23 ~ 2458563.91 2.02' -1.48 10.49 18.94 6.85 7.41 356.723 ~ X483.00 , __ i 700, ~ 200 _ '___ , -- X384 ..7 718.17 ~-._ ~ ,__ _. ____ _ 718.78 ~ 4 14 341810.75 I _-_ _ _ _ 2458570.81 2.26 -_226 _ _ -0.97, _ _ _ 19.18 6.96 7.53 356.823 3606.00 3.100'. 2.500; 3506.89 i 727.60 ~ E 728.20 j -3.65 ~ 341811.36 I 245R,g~i.~2 j 2.11 I -2.lli -0.57 19.52 ' 7.36 7.77 356_$44 _- 3667.00 1 400' 6.0001 3567 84 , 7_ ).99 _ -_` ~-- ~ ~~ ~ 730.59 ~ _ 0 ' 341811.54 T ~ ~ 2458582.61 I- i - ~ ` i - ^~ 5.74 2.79 ; 2.79, 19.62 7.62 7.89 356.813 3729.00 0.~00~ 2.300 3629.83 ' 731.02 731.61 3 ~31 341811.65 2458583.63 1.45 1.45 -5.97 19.68 7.75 8.01 356.806 3853.00 0300_ 203.900. 3753.83: 731.26 731.86 -3.52 341811.541 2458583.87 0.63 -0.16 -127.74 19.75 7.91 8.25 176.801 't976A0 0 a00~ 176 700 3876 83 7~) ~3 ( 731 1 ~ 63 341811.421 2458583.15 0.16 0.08 ~ 8.00, 8.50 176.837 # _ QQ _ _~ ~ 0 -- 1 1 _ 3 27 15~ 19.82' -- 1 8.11, 8.75 176.K49 `__ _ 4221 0.500 ` 2 .000 4 2 .83 729.38 730.01 x.44 341810 60 2458582.04 0.29 0 6 36.80 19.8 7~ 8.25 9.00 176.827 4347.00 I 0.400 246.500 4247.82 729.03 729.70 -5.38 341809.66 ~ 2458581.74 0.10 ~ -0.08 -6.75 19.94 8.43 9.27 176.794 4471.00 0.500 233.700 4371.82 728.51 729.20 _ -6.21 341808.82 ; 2458581.26 0.11 ~ 0.08 -10.32 20.00 8.60 9.54 176.755 4593.00 ' 0.500 -- 215.600, 4493.81 - 727.74 - 728.45 -6.95 -- 341808.07 i 2458580.52 - - - - - - --- 0.13 0.00 -14.84. 20.06 8.78 -- 9.81 176.723 _ 4716.00 ' 0.500 - 211.900; 4616.81 - ~ ~ ~ 726.82 727.56 7 54 ~: 34I807.46', 2458579.63 _ 0.03 0.00 3.01' 20.13! - 8.9b - 10.09'. ~ - 176.703 - -__ _ _ 4836.00 ~ 0.600 --- 211.100 4736.80 725.82 7~6 5A -8.14 341806.85 F ®2458578.66 0.08 0 08 0.67 20.20 7 9.15 10.36 , 176.679 _. 4953.00 ' 0.500 232.400 4853.80 724.96 7~~ 74 8.87 ___ 341806.12 _ _ 2_458577.83 - ---____ 18.21 0 19 -0 09 _ _® ~ 20.2 9.36 10.63 176.647 5076.00 0.200 255.900 4976.80 724.56 = 725. , 6 -9.50 _. _ 341805.48 ~ 2458577.46 0 27 -0 24, 19.1 L _ _ 20.38 9.59 10.92 176.627 5197.00 0.200 303.500. 5097.79 724.61 7 ~ -}, 9.88 ' - 5312.00 , 0 300', 56.300 5212.79 724.89 725.71 9.80 j 341805 10 I 2458577.53: - - X41805 19 '. 2458 x'.81 O. li 0.00 9.34 ~ - 0.37 0.09 98.09' 20.49 - - 9 84 20.60 l0 06', 11.22, 11.50 356.616 356.6241 Chevron. Actual Wellpath Report Positional Uncertainty GSS<0-1360'>MWD<1392 - 2560'>MWD<2622 - 8122'> Page 5 of 6 ~~~ BAKER NYQrMES. INTEQ Operator ~ • Chevron Slot SCU42-05X Area . _ Cook Inlet, Alaska (Kenai Penninsula) ______ Well 42-OSX Field Soldotna Creek Unit Wellbore 42-OSX Facility Sec.S, T7N, R9W ELLPATH DATA (102 stations) -with Positional Uncertaint values MD [feet] Inclination [°] Azimuth [°] TVD [feet] Vert Sect [feet] North [feet] East (feet] Grid East [us survey feet] Grid North [us survey feet] DLS [°/t00ft] Build Rate [°/100ft] Turn Rate [°/100ft] Major Semi-Axis [feet] Minor Semi-Axis (feet] Vertical Semi-Axis [feet] Minor Axis Azim [°] og omment 5443.00 0.400 32.900 5343.79 725.48 726.28 -9.26 341805.73 2458578.38 0.13 0.08 -17.86 20.73 10.30 11.82 356.669 5573.00 0.700 58.500 5473.79 726.31 727.08 -8.34 341806.66 2458579.16 0,29 0.23 19.69 20.87 10.54 12.15. 356.732 5698.00 0.900 52.600 5598.77 727.36 728.0 7 -6.91 341808.11 2458580.14 0.17 0.16 -4.72 21.01 10.78 __ 12.47 356.848' 5822.00 1.30 1.200 5722.75 728.70 _ 729.34 -4.90 341810.13 2458581.38 0.35 0.32:= 6.94 _ 21.17 11.02 12.80 357.012 _ 0 5945.00 1.400 _ 6 68.300 2 _ 6 _ ~ _ r 5.77, 1 21.331 11.27 ( 13.13 _ r 357.238 ---- 6068.00 1.SUU 54.600 _ 5968.6 731.60 732.0 0.42 341815.49 2458584A2 0.29 0.08 11.14 21.50 11.53 13.46 357.478 6192.00 1.400 79.800 6092.64 ~ 732.91 733.27 3.24 _ 341818.32 2458585.19 0.52 -0.081 20.32 21.68 11.80 _13.80 357.724 6315.00 1.300 106.600 6215.61 732.88 733.13 6.05 ' 341821.13 2458585.02 0.51. 0.08 21.79 21.81 12.07 14.14 177.945 6376.00 1.10 0 123.400 6276.59) 732.40 _ 732.61 7.21 j X41822.28 2458584.49 0.66 ~ ~ 0.33, - 27.54 21.87 12.20 14.31 . 178.025 _ r . _ 1 4 _ ~ , `60. 5 341824.60 9 I 245$53.44,, - 0.35 _, 0.16' -- - - ~ 14.80. 22.00 1~ 2.451 - - ~_ - 14.66` k78.i~6 ,~, 6622.0 r-- 0 80T _97.300 6522.5 _ -- 731 07' 731 : 1 _ 341826.79 2458582.93 _ 0.4~' _ 0.41 - _ _ " 6.42. 14 12.72 ___ _ _ 1x02' 178.351 6684.00 0.9001 16.500 6584.54 731.50 731.53 12.30 341827.36 2458583.34 1.78 0.16 -13(1.32 22.24 12.86. 15.20 358.402 6806.00 1.300 356.300 6706.52 733.81 733.83 12.49 341827.58 2458585.64 0.45 0.33 -16.6 22.48 13.16. 15.56 358.470 6929 .00 1.400, 0.800 _ _~ 6829.48: 736.70 7 36.73 12.42 341827.55 ~ - 2458588.53. 0.12 ~ 0.08 ~ - 3.66' 22.73_ _ 13.47 15._93 ~ 358.479 _ 705400 --- ~ -- 3 ~ _ - . _ i - _ __ - _ _ 2.16 22.98 13.78 ~ - ~ - 16.31 ~ 3S8.4b4 7177.00 0 00 , 7 3 ~ 1 --- -~ .~ _ - ~ 10.00^ 23.24' 14.09 _~ ~ _ 16.69 358.474 i 7302.00 1.40 19.0 . 202 36 ~ 746.14 , 746.1 13.46 341828.7 - - 2458597.92 0.24 6.88; 23.51 14.41 0.16 ~ 17.08 358.529 7420.00 1.600, 17.800 7320.32 ; 749.10 749.06 14.43 341829.73 2458600.84 0.17 0.17 -1.02 23.76 14.72 17.46. 358.608 7544.00 - 1.900 21.700 7444.261 752.70 752.62 15.72 34183206 2458604.38 0.26 024 3.15 24.05 15.05 - - - - - 17.85 '~ 358.709 - --- ~-- _ _ _ I _ -- _ -- 2.81 _ -- - ~ ~ ~ 24.20. 15 22' I -18.06; ' 358.775 7669.00 1.900 31.30 ! - 7569 19 ~ 756.61 756.47. 17.51 341832.90 I 2458608.20 0.46. 0.16' 12.79' 24.34 15.38 18.26 358.855 7795.00. 1.900 39.200 _ 7695.12 760.10. 759.88 _ 19.92 341835.35 2458611.57 0.21 0.00 6.27 24.63 15.71 18.68. 359.060 7913.00 1.800 41.200{ 7813.06 763.10 762.79 22.37 341837.85 - 2458614.45 0.10 = -0.08 1.69 24.89 16.03 19.07 359.266 -- _-- - , _-,~ 803600 - 2.100' 4~ 2001 _-__ _~___ ~ _ -- - -- 793.98 766.25 765.83 _.__.~.. ~ _. 64 0.50 0 ~ ~ - _ - --- ---- _ '_ - -~ 16.19 ..__ 25.03 _ ~ 25:47 ~ 341840.99 ~ 030 , 0 00~ _ 25.17 ~ 16.36 _.__ _ w_- 2458617.4b~ 8.25 i - 19.28.. 359.385. ---- 9.49 359.322 ------ Chevron Actual Wellpath Report Positional Uncertainty GSS<0-1360'>MWD<1392 - 2560'>MWD<2622 - 8122'> Page 6 of 6 ^%`~~ BAKER NYQ~NES INTEQ ' Operator 1 ~ Chevron Slot SCU42-OSX Area Cook Inlet, Alaska (Kenai Penninsula) Well 42-OSX Field Soldotna Creek Unit Wellbore 42-OSX Facility Sec.S, T7N, R9W LLPATH DATA (102 stations) -with Positional Uncertainty values MD Inclination Azimuth TVD Vert Sect North East Grid East Grid North DLS Build Rate Turn Rate Majar Minor Vertical Minor og [feet] [°] [°] [feet] [feet] [feet] [feet] [us survey feet] [us survey feet] [°/100ft] [°/100ft] [°/100ft] Semi-Axis Semi-Axis Semi-Axis Axis Azim Comment [feet] [feet] [feet] [°] 8074.00 2.000 44.600 7973.96 767.27 766.81. 26.41 341841.94 2458618.42 0.29 -0.26 3.68 25.26 16.46 19.62 359.600 8122.00 2.000 44.600 8021.93 i 768.50. 76R.01 27.59 341843.13 2458619.60 0.00. 0.00 0.00 25.37 16.59 19.79 359.696 ojected to TD ELLPATH COMPOSITION Ref Wellbore: 42-05X Ref Well ath: GSS<0-1360'>MWD<1392 - 2560'>MWD<2622 - 8122'> Start MD [feet] End MD [feet] Positional Uncertainty Model _ ~ _ Log Name/Comment Wellbore 0.00 1360.00 Gyrodata standazd - GWD or Single-shot _ ~ GSS <0-1360'> 42-OSX 1360.00 2560.00 NaviTrak (Standard) NaviTrak <1392 - 2560'> 42-OSX 2560.00 8122.00 NaviTrak (Standazd) NaviGamma <2622 - 8122'> 42-OSX • MEMORANDUM TO: Jim Regg ~ ~ ~; . P.I. Supervisor ~~ (I ~', ~ `° =''' FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 07, 2006 SUBJECT: Mechanical Integrity Tests ItNION OII. CO OF CALIFORNIA 42-OSX SOLDOTNA CK UMT 42-OSX Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv "-`i ! Comm Well Name: SOLDOTNA CK UNIT 42-OSX API Well Number 50-133-2056 (-00-00 Inspector Name: Lou Grimaldi mitLG060721090625 Insp Num: Permit Number: 206-074-0 Inspection Date: 7/20/2006 Rel Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well az-osx ~TYpe Inj. N j TVD ~' 7785 IA I ~ooo ~ z6oo zs7o ~ 2s~o ~ zo6o7ao sPT' ,T eTest ; ~ Test si P.T. ~ _ YP p Interval °T~R P/F P _ 260o pA o o ~ _ Tubing '~ o I ~ ° ° ~! ~ ° ° _ Notes Pre-Injection MIT. Well was pressured up to 1500 psi when I arrived and had been held for thirty minutes with no toss. I requested the pressure be dropped to 1000 psi to check for gas (none present). Repressured IA to 2600 as per Operater. Test held for thirty minutes. Passed. Monday, August 07, 2006 Page 1 of 1 FRANK H. MURKOWSKI, GOVERNOR ~-7R~ OIL ~ ~ 333 W. 7"' AVENUE, SUITE 100 ~T COl`SERQ~ilOls CO~SSIOlt ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 2767542 Timothy Brandenburg Drilling Manager Unocal PO Box 196247 Anchorage, AK 99519 Re: Swanson River Field, Tyonek Gas Pool, SCU 42-05X Unocal Permit No: 206-074 Surface Location: 502 FEL, 3370 FNL, Sec. 5, T7N, R9W, SM Bottomhole Location: 702 FEL, 2685 FNL, Sec. 5, T7N, R9W, SM Dear Mr. Brandenburg: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (90 6` 9-3607 (pager). DATED thi ~ day of May, 2006 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ~~~ sIz~IZoo~ STATE OF ALASKA ALASk~IL AND GAS CONSERVATION COMMIS' iN PERMIT TO DRILL ~n nnr. ~~ nn~ 1a. Type of Work: Drill Q Redrill ^ Re-entry ^ 1b. Current Well Class: Exploratory ^ bevelopment Oil ^ Stratigraphic Test ^ Service Q j Development Gas ^ Multiple Zone ^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: Union Oil Company of California 5. Bond: Blanket ~ Single Well ^ ^ Bond No. QD 103515406~g~~~ 11. Well Name and Number: CU 42-05X ~ 3. Address: PO Box 196247, Anchorage, AK 99519 6. Proposed Depth: MD: 8,164' TVD: 8,070' 12. Field/Pool(s): Swanson River Field 4a. Location of Well (Governmental Section): Surface: 502 FEL, 3370 FNL, Sec. 5, T7N, R9W, SM 7. Property Designation: A028996 Top of Productive Horizon: 702 FEL, 2685 FNL, Sec. 5, T7N, R9W, SM 8. Land Use Permit: N/A 13. Approximate Spud Date: 6/12/2006 /~ Total Depth: 702 FEL, 2685 FNL, Sec. 5, T7N, R9W, SM 9. Acres in Property: 1120 14. Distance to Nearest i Property: .~,408r'~' ~•~S, 4b. Location of Well (State Base Plane Coordinates): Surface:x- 341805.22 y- 2457852.09 Zone- ASP Zone 4 10. KB Elevation (Height above GL): 21 feet 15. Distance to Nearest Well within Pool: 100' fo ~zR !D - p".6 a+t 16. Deviated wells: Kickoff~depth: 500 feet Maximum Hole Angle: 18.5 degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) S2'/ C!o Downhole: 4,370 Surface: 1,534 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) - 13-3/8" 72# K-55 Weld 70 0 0 70 70 Drive 12-1/4" 9-5/8" 47# L-80 BTC 2,500' 0 0 2,500' 2,428' 1,192 cu ft 8-1/2" 7" 26# L-80 BTC 8,165' 0 0 8,165' 8,070' 694 cu ft 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/S tru ctu ra I Surface Intermediate Production Liner Perforation Depth MD (ft): 7,891'-7,909' Perforation Depth TVD (ft): 7,797 - 7,815' 20. Attachments: Filing Fee ,, BOP Sketch Property Plate Diverter Sketch ~ ^ Drilling Program ,, Time v. Depth Plot Shallow Hazard Analysis ,, Seabed Report ^ Drilling Fluid Program e 20 AAC 25.050 requirements ^ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~ Phone 907-276-7600 Date Commission Use Only Permit to Drill Number: ~©~ ^ d ~ API Number: ~+/ 50- f - .z.dJ(p ~~~~ Permit Appro al Date: S .3o fl~ See cover letter for other 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: ~ _,'("-'1 ~ ~g~-- q u,q,,~,~ ~ j'p ~ I,t~C irZ ~ . Samples req'd: Yes^ No[/~ Mud log req'd: Yes^ No[]'' ~~ ~ ~ a '~ ~ f '-0 67j 0lJ D ~,~ _ ~ HzS measures: Yes^ No irectional svy req'd: Yes[ No^ ROVED BY THE COMMISSION DATE: S~3o- ~ ,COMMISSIONER '~+f'. Form 10-401 Revised 12/2005 ~ ~ ~ ~ ~ ~ ~ ~~~ ~~' 'r/ ~ Submit in Duplicate y ~ STATE OF ALASKA ALAS, OIL AND GAS CONSERVATION COM ION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill ~ Redrill Re-entry ~ 1 b. Current Well Class: Exploratory Development Oil Multiple Zone Stratigraphic Test ~ Service ~ ~ Development Gas ~ Single Zone 0 2. Operator Name: Union Oil Company of California 5. Bond: Blanket ~ Single Well Bond No. 103515406 ' 11. Well Name and Number: SCU 42-05X 3. Address: PO Box 196247, Anchorage, AK 99519 6. Proposed Depth: MD: 8,164' TVD: 8,070' ~ 12. Field/Pool Swanso aver Field ' 4a. Location of Well (Governmental Section): Surface: 502 FEL, 3370 FNL, Sec. 5, T7N, R9W, SM ' 7. Property Designation: A028996 Top of Productive Horizon: 702 FEL, 2685 FNL, Sec. 5, T7N, R9W, SM 8. Land Use Permit: N/A 13. Approximate Spud Date: 6/12/2006 Total Depth: 702 FEL, 2685 FNL, Sec. 5, T7N, R9W, SM 9. Acres in Property: 1120 14. Distance to Nearest Property: X99`" 2ao• ~'S 4b. Location of Well (State Base Plane Coordinates): Surface:x- 341805.22 •y- 2457852.09 • Zone- ASP Zone 4 10. KB Elevation (Height above GL): 21 feet 15. Distance to Nearest Well Within Pool: 100' 16. Deviated wells: Kickoff depth: 500 feet Maximum Hole Angle: 18.5 degrees 17. Maximum Anticipat Pressures in psig (see 20 AAC 25.035) Downhole: 4,370 Surface: 1,534 18. Casing Program: Size Specifications etting Depth Top Bottom Quantity of Cement c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) - 13-3/8" 72# K-55 Weld 70 0 0 70 70 Drive 12-1/4" 9-5/8" 47# L-80 BTC 2,500' 0 0 2,500' • 2,428' • 1,192 cu ft 8-1 /2" 7" 26# L-80 BTC 8,165' 0 0 8,165' • 8,070' ~ 694 cu ft 19. PRESENT WELL CONDITION SUMMARY o be completed for Redrill and Re-Entry O perations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (meas ed): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length a Cement Volume MD TVD Structural Conductor Surface (~ Intermediate Production Liner Perforation Depth MD (ft): 7,891'-7, 9' Perforation Depth TVD (ft): 7,797' - 7,815' 20. Attachments: Filing Fee ~ BOP Sketch ~ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Property Plat 0 Diverter Sketch Q Seabed Report ~ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Repr entative: Date 22. I hereby certify that the foregoing i true and correct to the best of my knowledge. Contact Printed Name Timothy C. randenburg Title Drilling Manager Signature Phone 907-276-7600 Date ~ ~/ z. '- ~~ Commission Use Only Permit to DriN Number: Za ~ ' ~ ~ API Number: / 50- /33- ~-~ ~~~ -b~ Permit Approval Date: See cover letter for other requirements. Conditions of approval Samples required Yes ~ No [y]' Mud log required Yes [] No Hydrogen sulfide measures Yes ~ No ~ Directional survey required Yes [YNo Other: APPROVED BY Approved by: THE COMMISSION Date: Form 10-401 Revised 06!2004 O n ~ ~ ~ ~ ~ ~ AFE 165003 Submit inDuplicate 13~( • Chevron Wellbore Schematic: SCU 42-O5X Proposed Well Name: SCU 42-05X Operator: Union Oil Company of California Field: Swanson River Unit: Soldotna Creek API: TBD Permit: TBD Well Status: Gas Storage ~ RKB: 174' above MSL TD/ND: 8,165' MD/8,070' ND PBTD/PBND: n/a Casin Detail Size Wt Grade Type Top (FT) Btm (FT) Length (FT) 13-3/8" 72# K-55 Weld 0.00 70 70 9-5/8" 47# L-80 BTC-Mod 0.00 2,500 2,500 7" 26# L-80 BTC-Mod 0.00 8,165 8,165 Tubin Detail Size Wt Grade Type Top (FT) Btm (FT) Length (FT) 3-1/2" 9.2# L-80 Atlas Bradford TC-2 0.00 7,850 7,850 Jewel Detail 1 Chemical Injection Mandrel 2,500' 2 Sliding Sleeve 7,750' 3 Hydraulic Packer with tubing anchor and mill-out extension 7,800' 4 XN-Nipple 7,820' 5 WLEG 7,850 6 Dropped TCP Gun 8,165 Perforation Detail Zone SPF Date Top (FT) Btm (FT) Length (FT) 77-3 6 TBD 7,891.00 7,909.00 18.00 Last Revised: 4/28/2006 Revised By: LWB Chevron Swanson River Field ~" SCU 42-05X Gas Storage Well General Drilling Procedure 1. Prepare Location. Set Cellar. Drill and drive 13-3/8" casing to +/- 70. Install unitized well head. 2. MIRU Kuukpik #5 Drilling Rig and Grind & Inject Unit. 3. N/U and Function Test Diverter (see attached schematic) ~' 4. P/U Drill Pipe and 12-1/4" BHA. 5. RIH and clean-out 13-3/8" conductor. 6. Directionally drill 12-1/4" hole with +/- 9.2 ppg water base mud to casing point at +/- 2500' '(Note: depending upon drilling conditions, we may push the shoe depth to as deep as 3,300' MD). 7. Condition hole and POOH. 8. R/U and run 9-5/8" casing. 9. M/U and test cement lines. Circulate and then cement casing bringing cement back to surface: Bump top plug and test casir~.g to 3,000 psi. 10. N/D Diverter. N/U and test BOPE to 3,000 psi/250 psi. ~ 11. M/U 8-1/2" directional BHA c/w MWD and RIH. Drill out float equipment, rat hole and 20' of new formation. Pull back into the casing and conduct aleck-off test (Note: if the formation doesn't leak-off by a 15.5 ppg EMW, the test may be suspended). 12. Directionally drill 8-1/2" hole to TD at +/- 8,165' with Water Base Mud as high as +/-12.5 ppg depending upon hole conditions. ~ NOTE: If hole conditions, mud losses, or other issues cause us to set 7" casing early. We have a contingency plan to drill to TD with either a 6" or bi-centered bit and then run and cement a 5" liner. We would then complete the well in a similar manner as described below except the completion would be 3-1/2" tubing crossed over to 2- 7/8" inside the 5" liner down to a 5" production packer. 13. Condition hole and POOH. ,~, - J 14. R/U and run open hole logging suite from TD to the 9-5/8" shoe. 15. Make conditioning run with bit if required by hole conditions. 16. R/U and Run 7" casing to below the 77-3 sand. O~-Su.r-~cas~K~ 5~+~: G~t.See~ ~~-~?R General Procedure SCU 42-05X 1 Sur ~~ skaG~- "tZ~ aK ~~ ~ rND/~~~ /S~ S•z~.o6 Chevron Swanson River Field SCU 42-05X Gas Storage Well General Drilling Procedure 17. Circulate and cement casing utilizing caliper hole data bringing the cement top to +/- 4,000' TVD. Bump plug and test casing to 5,000 psi. ' 18. RIH with drill pipe and casing clean-out assembly. Displace well lease water. POOH. 19. R/U E-Line and- make a cement evaluation logging run. 20. R/U and run TCP gun assembly, Hydraulic Packer and 3-1/2" tubing completion string. Make correlation run with E-Line, space-out and land hanger. 21. Set Hydraulic packer with plug landed in nipple profile. Recover setting plug. 22. RIH and shift sliding sleeve open. Circulate thru the sleeve with packer fluid and then under balance tubing with Nitrogen cushion. RIH and shift sliding sleeve closed. 23. Fire TCP guns and flow well to clean-up. 24. N/D BOPE. N/U and test tree. 25. Release Rig. General Procedure SCU 42-05X 2 ,, T8N T7N AS-STAKED WELL "C" SWANSON RIVER FIELD PAD 42-05 ASp ZONE 4 NAD27 N: 2457852.09 E: 341805.22 LAT: 60°43'28.665"N LONG: 150°53'00.9D1 "W FEL = 502' FNL = 337D' ELEV = 153.2' (MSL) SECTION 5, TOWNSHIP 7N, RANGE 9W, SM AK • Z !L Q M U J W r -~ r l 1 i ~F• '~~q ~~~ ~`~E . ~~P'' ~ • ~ s`r ,~I y ~- * .~ 4 ~ ~. * ~i ~. .... ~ ~, ',•ST• ~ •A. MCLANE ,o ~ / W ' /~ ~s~~ ~ • 463~7-S . 'h~'~ ~ Z H U I W WELL "C" 502' FEL ,~. r - ~~ EDGE OF PAD / "~ -~_ _ l EDGE OF PAD S RF 42 - 05 PAD NOTES 1) BASlS OF COORDINATES: NGS COBS STATION "KEN 1" NAD 27 ALASKA STATE PLANE ZONE 4. 2)SASIS OF ELEVATION: NGS BM Q78 RESET NAVD88. SRF PAD 42-05 'WELL "C" AS-STAKED SURFACE LOCATION SINANSON RIVER GAS FIELD P.^, Box 468 5oLOOTNA, AK 99669 .LOCATION: SECTION 5, TOWNSHIP 7 NORTH, RANGE 9 WEST, Consulting Group SEWARD MERIDIAN ALASKA JOB NO. 063023 MClx~n6 ~nC. eL 90'7.263.4278 FAX 9^7.283.32s5 Dwg: 063023 Date: 5/910fi SECTION LINE (NOT TO SCALE) 3~2.3~ 514 APPLICANT: uNOC,a~ ~~ 909 W. 9th Avenue Anchorage, AK 99519-7685 FIGURE..'[ ~~ ~ i UNOCAL ~~'~ UNOCAL BAKER Locatbn: Cook Inlet, Alaska (Kerei Penninsula) Sbt: SCU42-05X HUGHES Field: Soldotre Creek UnN WeN: 42-05X INTEQ Facll Secs T7N RAN/ WeNbore: SCU42-0SX -Soo <<u qz>'. c~ IPOlO~ ~ ¢ZB-os ~42~~9 ~ z(t -OS I(,I 03(0 '~ o q ~ ~ ,~ _ m " Easting (ft) 0.00' KOP 2.50' 2S0'/100ft 5.00' 7.50' 8.34' 9.77' 11.56' 2S0'/100it 1357' 15.72' T797' EOC 3.500 L a m O .2 4000 >r m m 2 a5oo 8.4f~~ EM of TangeMO 16.94' 15.44' xi.s4' 12.4x' 1o9a' 9.44' 1S0'/t00N 7.94' 6.44' 494' 3.44' 194' 0.44' ~ End of Drop 5500 6000 6500 7000 7500 scua2-0sx - 77-3 8000 7' Casing Production ~. Well Profile Dete con.1.nt w dl - non A: n rvo (ro (dwi w n on om omo osmo am om ~e a T smm omo i ssmo loom om e,n a e,ao Boom Tdoo ~ asmo 'roY.x sm JD Aro (~ xSld6 EAD/ DDlDE 110lm M1D0 r e d T (al axd+ E.~ ~ xleeE z~es~s aus JMpAT Dm0 3JldE 3"]Sm "66m 6b d T DMA7 Dm0 '~ 3DBDE BoTOm dim ,~Y,rs ~~, Y ilNtmt v~ ~ Tv resew bpi ~w ,MM~eY a vr..a n,c! IH~amD (Aio" O+I M~~ UNDO I iV Wr..e day ,.~..se a rwnne pn I~OD.I D~1 NwE A,bw: l,u a M~0 nNB (ut~ DEer b nr, r Me "~ w~1 tam T,u aWrs w (F.~ - BsS Tn{ nwry 0 1M dp+~ ~,. H Ar oee,ar r~ n r Mr~va n Ba orr p: ~urY n e ~ISend - a19los -~ TD SC1142-05X Vertical Section ~ "~" •'°°°" Azimuth 343.02' wkh reference 0.00 N, 0.00 E from wephead ~~ 750 700 850 600 s5o 500 450 aoo 0 9 350 300 250 200 100 so 0 _~ Planned Wellpath Report gp~~~ r u N OCA ` Wellpath: SCU42-OSX Ver 4 HU6NE~i Page 1 of 6 ~NTr'~.(,~ 'Operator ~, 1 1 v _ UNOCAL .~.~___.___~._ _______,.~.._.~n.__,___._w~ Slot SCU42-OSX -Area Cook Inlet, Alaska (Kenai Penninsula) ._w_... ._ __ ____________ Well 42-OSX Field Soldotna Creek Unit Wellbore SCU42-OSX !.Facility Sec.S, T7N, R9W ~C--a-lc-~u-l°a-t-i-on method Minimum curvature Planned RKB (42-05X) (RKB) to Facility Vertical Datum 174.00 feet I ~ ~.~.,_ _._____.._~~m.___. ~.__.~~.~.._..~____r___. __~ ..~... _._.~ ~,.._:.__.~. ~_______~,__._~~ ~_ ._____~____...____.__~. Horizontal Reference Pt Slot Planned RKB (42-05X) (RKB) to mean sea level 174.00 feet _n___ ~ ~._~____..__ Vertical Reference Pt Planned RKB (42-05X) (RKB) Facility Vertical Datum to Mud Line 0.00 feet __ MD Reference Pt Planned RKB (42-05X) (RKB) Section Origin _ ____ N 0.00,E 0.00 ft Field Vertical Reference mean sea level Section Azimuth 343.02° UNOCAL Planned Wellpath Report Wellpath: SCU42-OSX Ver 4 Page 2 of 6 ri~r BAKER NU6NES INTEQ Operator ,, ~ ~ UNOCAL ____ Slot 'SCU42-OSX ~~ ~ ____.. Area Cook Inlet, Alaska (Kenai Penninsula) . ® Well ~42-OSX _~..~.~ _~ ________._...~.__.~__ __....._.. .. _ _ __. ~_.__. _____. 'Field SoldotnaCreekUnit ..a _. _ ._ ._ _ Wellbore SCU42-OSX Facility ~ Sec.S, T7N, R9W ELLPATH MD DATA (89 Inclination ~ stations) ~ Azimuth ' =inter ola TVD ted/extra~ Vert Sect olated station _ North East Grid East Gnd North DLS Build Rate ~ ~ Turn Rate Path [feet] [°j [°] [feet] (feet] ~ [feet] [feet] ~ [us surve feet] [us survey feet] [°/100ft) [°/100ft] [°/100ft] Comment 0.00 ~ ~ ~ 0.000 T 35.000 r 0.00 ~ ~ 0.00 0.00 0.00 341805.22 Y~ r 2457852.09 0.00 ~ 0 00 ~ 0 00 100.00~' ~ 0.000 0.000 100.00 0.00 ~~0.00 0.00 341805.22 2457852.09 0.00 _ ~ 0 00 ~ 0 0 0 ~ ~ ~~µ 200.00f 0.000 0.00 _ 0 200.00 ~00 0.00 0.00 341805.22 _ ~ ~2457852.09 0.00 ~ ~ ~ 0.00 ! _ { 0 00~ ._...~. ____ O.000 ____ I~ 0.000 { 300.00: 0 00 0.00 0 00 ~~341805.22 ~ 2457852.09 __. 0.00 T 0.001 0.00+ --- - 4f10.00'` _-------_ 0,00{] , 0.000; _ 400A£2 ~ - _ U ~? ? _._ _ ..__ 0.00 ~t.(~0 - _.. _... _ ~418U5.<? i r- ____ _ 24578'' U9 ' _.. - - --- , 0 00 -- _ _ 0 00 _ ` 0.00: { ~ _ SU0,00 0.000 _ ~ ~ 35.000 _ -~ 500.00 ! ~ U.00 O.OU U.UO I ~ _~ ,_-~ 341805.22 C _ _____ ~~T2457852 09 ( 0 00 _ - _ I 0 00 _ ~ 0 OOI _ KOP 600.00' ~ _ __. ____ 2 000 ~ _`. _ 35.000 ~ _ 599.97 ~ 1.34 1.79 ~ 1.25 341806.9 4 2457853.86 2.50 2.50 ~ 0 00 _ 700.00 _ 5.00 .m_ 0 35.000 699.75 5.37 7.14 5.00 341810.32 2457859.17 ~ 2.50 ____-_ 2.50 ~ _ 0.00 800.00 7 500 35.000 799.14 12.08 16.06 11.25 341816.68 2457868.00 2.50 2.50 ~~~ O.OO ~aU~i.~O~ 8.342 + 17.832; -- 898.20 _ ____ ', ~~_OS ' Rid 17.21; :, 341 ~~2.b l , 24~7RR0. ]7 ~ 2.~0 ~ 0 84 -17.17; i 1000.00' _ __ 9.766 4.704 996.97 } 35.R9 ~ 43.68 { 20 13 I _ 341825.93 ~ 2457895.49 (~ 2.5 0 ~ 1.42 __ -13.13] 1100.OOj~ 1200.OOi- 11.557 ~~~----~---13.572 355.23 348.40 61095.24 81192.85 ~ _ ~ 53.57 62.11 19.99 75.04 83.59 16.80 ! 341826.04 341823.14 ~ 2457y13.92 ~~~ 2457935.44 _ _2.50 ~ ~...__ 2.50 ~ 1 79 ~~ 2.01 ~ 9 47~ _ _ .._ _.___6 8~ ~LL~Y~~~ 1300 00~'~ ] 5.725 343.'i66 ~ 100.28 108.08 10 56 341817.24 a 2457960 O1 ~ 2.50 I 2.15 5.01 { ' _ c ,~~ „ ! ~ ,~ ' ~. 3 , ~ 3 - 24~79ti7.~6 .:.~(i . 2.2-4 3 83 _ ~ ~ T I 85 r 14? ~ I 18.464 338.810 ~ ~ - - 1406.06 - <} ~ ~ ~ { i) ~ -- _ 136.04 ~ 141.90 I 1 1 _~1~ ~~ y8 ~ l ,u -_ _ __ _ _ 2 _~ , 28~t.UC 1421.85 I 18.464 338.815 ~ ~~ 1406.06 -~>>3 ~8 136.04 f 14L90 I . I 1 i 341 ~~ ~~ ~~') ~4~ << - - 1 ~ i 2 - ~ ~+ n {m 1500.OOj~ 18.464 338.81 5 1480.18 _ ~ ______ _ ,_ `! ;+~ ~~458017.17 160.73 + 164.97 I~i.~i~ ' X41 . __ M O.OU . -__.~~~ ~ f O uii ii n~i ______~.._ 1600.OOt 18.464 338.8151575.04 _ 192.31 1'~l.~n -~I ~ 3•klxr,.;l ~i>si~46.85~ ~!.~~~'~ O.~i!i !i+i~i --~ 17~1t).OUj~, 18.46=1'~ a ~8.81~; 16r~9.89 _ _ _ __ ~ 22.90 !. 22a.~:!3 -32 97 ; , ~~~t1775Z7 E 2458076.53 {~.~h~ ~ O.UU U.i10: j I ~ I tii iu u~ i 15.-10_-4, 338.815 ~ 1764.74 _~___ I~~~~i~ alit! I 18.464~~ 338.815 1859.59 ~ 255.4 2~3.~; -44.42 341764.22 ~ 2458106.21 OAO OAO 0 00 _ _~~ .._ __ _ i __ _ __._._ I { ~ _w ~~ OAO~ ~~ O.OOj 0 55.86 ~ 341753.18 ~ 2458135.89 0.00~ ~ 287.07 283.1 _ __u_ inniiiii I~ In 33RR10 1954.5 ~ _ ~ ~~ ~ _ ____. ..._..._. __ u.U_0 31_x, ~ 2. 65 57 _ __O.uU~ ~ ~~ . ~. _ M~ _ j -- k ~ (1~ E . - i ~,iu uu ~'` _ ~ ; ;, , I 1 -ii,~ ~ ~ 1: ~~ 204 ~ '0 ~ _ I ._ . . __._. , ' `._..:~ I n _ ___ ---- _ ___. _~ 0.0 _i~.iii_ 78 75 ' 245Rj 9S 2~ ~ ~ I , ` ~ ~ ~~ 3 ~ ~ ._____ !.__~_ r__..._..__ __~- _,,___._ _~_ - ~ 2UJ.(0~ 18.46-}' ~~R.BL, ..1-}-1.15 _ _ . --- -__.._._._.; , . --__ _.. -- - - ._~ _._.._~ - - ___ _..__ 0 i)u ____--- 0 -(f~l ~ -~ ~- ~ R 3 ~ i - ~ -k '?". 4 4 x U.U( 3 L8 .71.69.', y .~), 3 1~_l { ,;.: 2 _ ~'_~t 3 ?' 0.0 • uNOCa~~ Planned Wellpath Report Wellpath: SCU42-OSX Ver 4 Page 3 of 6 ~r,~~ - . BAKER NU6NE:~ INTEQ Operator ,. ~ ~ UNOCAL Slot SCU42-OSX ~__._ Area Cook Inlet, Alaska (Kenai Penninsula) Well 42-OSX w~...__..._._. __._____.~._____~.___~.__~_.._ ~.._.______..._ 7 Field Soldotna Creek Unit Wellbore SCU42-OSX k __. Facility Sec 5, T7N, R9W ELLPATH DATA (89 stations) fi =inter olated/extra olated station MD Inclination Aaimuth TVD Vert Sect North East Grid East Grid North DLS Build Rate [feet] [°] [°] ~ .[feet] [feet] [feet] [feet [us survey feet [us survey feet] °/IOOft] [°/100ft] 4~ 2300.00' ,18.464 338.815{ 2239.00 41.3.41 401.22 -101.64 341708.99 2458254.61 0.00 ~ 0.00 _ 338.815 2333.85 445.00 430.75 -113.09 341697.95 2458284.29 ~ 0.00 ~ 0.00 18.464 2 400.00 j' ____~ __. Turn Rate ath w[°/IOOft] ~ Co_m_ment 0.00 _ __. _ OA03~ _ ___.v_ _ ~ ~N2500.00~'3 _ 18.464 338.815 2428.71. 476.58 460.28 -124.53 _ 341686.90 2458313.97 0.00 ~ 0 0.0 ~ 0.00 _ I 2538.54+ _~~ _ 18.464 338.815 2465.26 488.76 471.66 -128.94 i 341682.64 2458325.41 , 0.00 ~~ _ 0.001 _____ ~O.OU~End of Tangent 25 ~3.Sa ~. 11s 444; X38 8i5~ 246.26 , 488 76 -k71.66 '~ -128.9a - - ~- --~ ~-11682.64 ~#5S3''>.41 ;. 0. 00 ; O.UU O.ui) 3 ~2600.uU~'~ _ 2700.OOj' 17.642_( ^338.8153^2523.71 ~ 507.70 ~ 16.042 338.8153• 2619.45 536.51 ...489.37 ( 516.31 -- -135.81 -146.25 _ X41676.02 ~ _ 2458343.21 ~ 1 50_` N _,__ 341665.94 2458370.28 1.50 `1.SU! U.Ouj TT ___ __.. 2800.OOj'3"!~ 2715.90 562.81 14.542 338.81 540.90 -155.78 ~ ~ 341656.743 2458395.00 ~ 1.50 3T -1.503 O.OO~v~_.__.____~ ______ _.__.___ ~ 2900.OOj' 5 13.042 338.815 2813.02 586.59 563.13 -164.39 ~ 341648 43 ~ 2458417.34 1.50 -1.50 0.00 _ 3ti~~aat~~~ _ 11.342 3;8.8[SI 2910.72 j 607.82. i ;8' ~8 s -172.ti9 ~. _ _ 24>84~7.29 I 1.50 ; ~ '>416-tt Ut~, _l.n 0.00, 3100.Un+~ 10.042 338.815 30ng.95 626.49 ' 600.44 I -178.85 j _ 341634 47 2458454.83 1.50 ~ 1.5(if 0 00 ----- 3200.Out~~ _ 3300.00j'~ ------ _ _ 8.542 338.8153 31u7.64 642.6(1 , _ 7.042 338.815 ]-~ 3206.71 3-656.12 i _ _615 49 ~ 181.69 ~ 189 59 628.13 - v _ _ 341628 84 ~ 2458469.96 _ ].50 ~ N _ 341624 11 ` 2458482.67 ~~ 1.~0 .. 1 Sul 0 00 _ ____.____ __. _ _. -1.50 0 00~ ~ ~~ a ~ _ _,._r 3400.00E 5.542 338.815 3306.10 C 667.0 ~ ~~_~8.35 i _ 19.55 . ___ _ _ 34162u?9 ~ 2458492.94 ~ I ->0 [~~ -1.50 ~ _ ~~ 0.00 ____. ~ ~ e -- u --_- -__ -- - _ _ _._ ._ ` - - _ _,.f ~4~~SOU.i7 , 1.~~) . _.__ ? _ ~8 1. "U , __ _ __ _ (i.OU _ _ _ . __ - ~ Ui' I 3buu. _ 3 3700.uu ~ -- - ~32i.ts1~ 3505.58 681.11 ~ 2.542 ~ 65Lw - 198.64 I ~ ~ _ ~ 341b1~ 24585ub. l ~ - 1.50 . ~___W _ _ 4 09 1.50 ~ ~ i~ 1 -1.~~i U.uu, __.__w._.r~- ____._____ 0.00' o _ __..~... ; ? ~~ _ _ ~ 3769.-4? r 0.000 338.815. 3675.00 ~ 684.85 ' 65~.~0 ~ ~ (i 200.00 1 ~ _ ._____ __ _ ~_ ~`" i i~ 24585 67 ~~ 1.50 ~ 341 ~ 1 - t -1. ~ i i _ ~. ~_ _ O.OU;End of Drop _ _ _ ~3~unnu~ _________ ~ ________ _ ~ _ 0.000 0.000 3705.5; r,s-1ti5~ ~655.00 _ _ -200-nOj - ----. __ . __ _ _ _-- 341~,I~.~~n; 2458~~w.67 u.n~) 0.~~~~ O.oU~ _~ 6 ___-.__ --__ 39u~~.(~Uf~~ _-._ __.__ ~l.Unti1~ O.tl~iu 38[x,.53 t t?Sa.85 , _ 6j;,00 ~ ~t10.~t~ ~ _ _.-_. _. ___ ~~LT614 0t~ ;. ~- Z1~35u9 67 ; (,x.00 ~ 0.00. _ ___ (1 t'it'i __ . __.4 4000.OOt 4100.00~'~~ O.000~ w 0.000 _ 39u> > i 6848 0.000 0.000 4005 53 684.85 ~ 655.00 655.00 -2UU.UU -200.00 341614 Ub 2452i50~ 67 ~ U.UO { ~ I 341614 06 ~ 2458509 67 0.00 O.UU 0.00~ U.uU~ ___. __ _ _ _._____ ~~ 0~00~ _ i 200.OO~j 0.000 41~ 84.85 0.000 - 655.00 - 200.00 341614.06 2458509.67 ~~ ~•00~ _ _._ _ _ OAii~ ~_ _ _ w ____. _.. . ~ _ 0 , - 655.00 -200.00 341614.06 2458509.67' 0.00 ___ -__~ __ ~ a=1t30.k701''. ~i.000 ~17.Q0U, $3u;.5 i ' 681.85 I 655 Un i -200,U(1 ; ---- .}41b14.f16 µ•}58e09.67 !, 0.00' - O.UI) - f~.U(li -i I uNOCa~~ Planned Wellpath Report Wellpath: SCU42-OSX Ver 4 Page 4 of 6 r~-rr BAKER ~u6NEs INTEQ Operator ~~ ~ ~ UNOCAL _ Slot SCU42-05X __.~-_~~~ .______~_ ___._ Area Cook Inlet, Alaska (Kenai Penninsula) Well 42-OSX Field Soldotna Creek Unit Wellbore .SCU42-OSX ~ ~ ____ ~~ Facility Sec.S, T7N, 1t9W ELLPATH DATA (89 stations) fi =inter ol MD Inclination Azimuth TVD 1° ~[°] [feet] [feet] ated/extra Vert Sect [feet olated station North ~ East Grid East feet [feet us survey feet] _ _ Grid North DLS Budd Rate Turn Rate Path us survey feet] [°/100ft] ~°/100ftJ ~ [°/100ft] Comment W _ 4500.00' 0.000 0.000 4405.53 684.85 655.00 -200.00 341614.06 2458509.67 ~ 0.00 ~ ` 0.00~~ 0.00 0.000 0.000 4505.53 4600.OOfi 684.85 655.00. -200.00 341614.06 6 2458509.67 ~ ~ ._._. 0.00 ~ m 0.0 0 ~~ ~ 0.00~ 4700.00' ~~ 0.000 ~ 0.000 ~ 4605.53 684.85 655.00 _ ~" 341614.0 -200.00 { 2458509.67 ~ 0.00 ~ ~~~ _ ~ 0.00~ ~ O.OO r 4800.OOt ~ O.000 h~ 0.000 (4705.53 684.85 F55 00 ; I -200.00 ! 341F14.OF 2458509.67 ~ 0.00 I - ~ 0.001 O.OOI ~ - ' 0.(?09 5 ~}HOS_5 ~ 68~l.~. __ i 655.G~0 _ 4~o,txr 3~~lUla.(1ti G - -_ 2Q585~19.67 } n.00 0 00~~ O tkl! -- 5000.00( 5100.00~' .....0.000 __ _ 0.000 ~ ~ 0.000 0.000 _ 4905.53 684.115 ~ 5005.53 684.85 655.00 655.00 ~ -200.00 ~ 341614.06 -200.00 341614.06 _ 2458509 67 ~ 2458509 67 _ ~~ u.u_U ~ ~ 0.00 0 uu1 _ _ 0 00~ 0 00 __ 0 00 ~ _._____..._.__. 5200.00' ~ 0.000 0.000 5105.53 684.85 655.00 -200.00 341614.06 2458509.67 ~ ` ___ 0.00 ~ _ 0.00 ~ _ O.OO ~M 5300.OOt 0.000 0.000 5205.53 684.85 655.00 -200.00 341614.06 2458509.67 0.00 (~ 0.00 0.00 `~ - ~4€tt).00~'. __ Oa~O _- j O:tlf10 ~ ,~~i1.53 ' 63.85 ! 6~5.oa -~Q~).(~Fi ~; 3-116]~1.U6 245509.67 - !~ : 0.00 ; _ 0.00; 0 00 _. r i SSOO.OOj' _ __ 0.000 0.000 . 5405.53 684.85 655.00 r -200.00 341614.0E ~ _ 2458509.67 ~ 0 00 ~ 0 00~ 0 00 5600.00fi 0.000 -----0.000 5505.53 684.85 655.00 -200.U0 341614.u6 ~ _ Y 2458509.67 ~ 0 00 0 00 0 00 ~ 5~ _ _ 0.000 r 0.00 _ ~ -200.00 341614.06 0 5605.53 684.85 655.00 ~ ~ 2458509.67 C ~ 0.00 ~ 0.00 0.00 __ j SROO.OOj~ 0.000 0.000 _ 5705.53 ~ 684.85655.00 -200.00 341614.06 r 2458509.67 ~ _ 0.00 ~ ~ 0.00~~ __ - 0.00 '~~300.Of1~; 0.000 ~0.000 ~ -SRt~S.>3 ` 68~3.A; b~5.t~( ~ ; -~,U(1.I?0 ~ ~ ~~~16t~.tlb ~ ''-158~uU X7 ~ 1- 0.00 -- - ©.00 0.00 _ - - -- __ - _ _ _ ~ - -- "II f'lr? _ _ _ ~ _- - G.uii U.00~ ~ 5.0 1- i 3416]4 06 9 9 7 ~ ( ~ t 6100.00 0.000 0.000 u 6005.3 684.85 65 u ~ -[iii r . , _S_u .o 0.00 i uu O.OU 6200.00 0.000 6105.53 684.85 ~ 65 ~ . i ~~ r 000~ 341614.06 ', ~ ~ ~~ ~ ! ~O j ~ X58509.67 0.00 O uu 0 00~ ~ ~ 6300.00 _ ~ ~ 0.000 0.000- 6205.53 684.85 ~»5.~~~~ ~V~ --uii.r~~i 3~lol~.iin ~ 9~ti~09.67 n-~~u; O.uu -T- _ 0.001~~ ~La40U.00j' O.OUO fl.Ol?(r °.6305.x3. , ~ C~$~#.&? ~.~ fi55,Ut~ i -20U.U0 ~ 34.1614.06 ( 2~585UJ.67 (1.0(1 O.OU 0.0(1; 6500.OOj' ` O.UUU, a uuu 6405.53 684.85 655.UU -X00.00 341614.06 ~ 2458509.67 ~ 0.00: _ _0.00 1 0.00 ~ 6600.OOfi ~0.000~~ ~!.~)00~ 6505.53 684.85. 655.00 I -200.00 341614.06 2458509.67 0.00 ~ _ _ _ 0.00 ~ 0.00 ~ 6700.OOj' ~ 0.000. 0.0001 6605.53 684.85 ~ 65> uu -~Ou.00 341614.06 ~ ~ 245850y.67 mmm 0.00 ~ m 0 00 mmm 0.00 800.001 un r,,.uu n 6705. 0.000 3 68485 -,~u%u0 39 ~ r, I~.u~, ~,~;u~~ i;7 _.~ _ _ 0.00 ' __ _ ._ __r __ O.uu ..._ _ s __ 0.00 ~ ,.--._._ _~i9E1O.(1©t : __ ` .__.._ --- - _._ ,-- ___._ ..-_ _ ___ Q OOD 680 „3 ` f~84 8~ b_5~ 00 ~?00.i)~'-- `, ~4~fi1+I 06 ' (1.UQU'' ~_ _- -----~------------ ----------_ -~---------------.._. ___._._- -_--- _ _. 24^~85tF~) 6r ; V..~.~ __.___-- _ _ ,-- 0.00 j -----_--__- _._ _._ 0.00 _._____.._...._....,-_ _ __,_. ._...___----- 000; -_.._._._s..e....--.._.__..__rs • uNOCa~~ Planned Wellpath Report Wellpath: SCU42-OSX Ver 4 Page 5 of 6 rr,.r BAI~CER I~I~t~'rHE~' `ir INTEQ Operator ,. ~ ~ UNOCAL Slot SCU42-OSX ____ ~~~~~ :Area Cook Inlet, Alaska (Kenai Penninsula) Well 42-OSX ~._ _.. ______. _... _____. _ .__._ ._ _.______._. _._ _ _ __,__n _ _ ______._.___ Field Soldotna Creek Unit _ __ _ Wellbore SCU42-OSX ~_~___ _______. _______ .._.. Facility Sec.S, T7N, R9W WELLPAT MD [feet] H DATA (89 Inclination [°] stations) 1' =inter plated/extra Azimuth TVD Vert Sect [feet [°] feet] plated station North East [feet] feet Grid East us survey feet] -__ Grid North [us survey [eet] _~__.__._ DLS [°/100ft] ___._______.____________.____.__..___~~ Build Rate Turn Rate Path [°/100ft] ~ [°/100ft] Comment 7000.OOj' ~~_ ~~ 0.000 __ 0.000 6905.53 684.85 655.00 -200.00 341614.06 2458509.67 ~ O.OO _ _ f 0.00, 0.00 7100.00 fi ~ 0.000 005.53 684.85 0.000 7 655.00 -200.00 341614.06 2458509 .67 0.00 _ 0.00~~ O OOj ~ ~~ ^ C~ 7200.00' ~ 0.000 _ 0.000 7105.53 ~ 684.85 655.00 -200.00 341614.06 _ 2458509.67 _ ~ 0.00_ v _ ._~___ ~~ ~rt 0.00 0 00~ ~~~ 7300.00 ~ 0.000 205.53 684 8 20000 655.00 341614.06 2458509.67 ~ 0.00 ~~ w w_~__ O.OOE~ 0.00( ' ..._._ 7~11)~.Ot)fi~ 1: 5 0.000--- - - ~ _ _._ ~ h55.Uk~;~ -2(10_fR3, _,__ _ _. ?dl(~14.06 -- _ f 24>8~0~ h7 ; O.tiU _ --- _._ O.OOi 0.00; __ I' ~7600.00~' _________v u ODU ~ ~~ O.000f T ._. __~._ __ 0.000 ~ 750.53 684.85 ~ ____ ~ 0 655.00 ( -200.00 ~ 655.00 -200.00 341614.06 341614.06 ~ 2458509 67 ~ 2458509 67 0 00 i ~ 0 00, 0 OOi 0.001 __ _.. 1_ , _ 0,00) rt 0.00__ __.______ _..__. 7700.OOt 7800.OOfi 0.00 000 0.000 7605.53 684.85 0.000 7705.53 684.85 655.00 -200.00 655.00 -200.00 341614.06 341614.06 2458509.67 2458509 6 0.00 0.00 7 ~ 0.00 0.00 ~ 0.00 0.00 i 7878.171'; , 0.000, ' _ ___. 338.315'. 77f1-1.x(1 . ~8a.8~ ~ , .__.. _ 6,~.Q6 -:.UUUt~ E "_ _ .... _ _ ,1161-1t16; _ ___._.__ __ ^~IiKSO9.67 j ~ _ 0.00 ~ .__._. .--_ _ 0.00; O.~iU ~,-> >and ~ ~ ( ~ ~ _ 341614A6 2458509 67 ( 0 00 ~ 0 00 0 00 000.00 f 8 ~~ 0.000 0.000 7905.53 684.85 655.00 200.00 341614.06 2458509 67 0 00 0 00 _____ 0 00 ~ _ _ _ 8100.OOj' _ ~ T ~ u~__0.000 _ ~ 0.000 8005.53 __ ~_ 684.85 _ 655.00 -200.00 341614.0 642458509 67 __ 0.00 ~ ~- ------~ - --_.____ 0.00 0.00 _ ~ ~/ 8164.47 _ 0.000 338.815 8070.00 684.85 655.00 -200.00 341614.06 2458509.67 0.00 ~. _ _ _ ------ 0.00 O.OOTD HOLE & CASING SECTIONS Ref Wellbore: SCU42-OSX Ref Wellpath: SCU42-OSX Ver 4 --- -_.___.__~________..__ _®_ String/Diameter _____ Start MD [feet] End MD [feet] Interval [feet] Start TVD [feet] End TVD [feet] Start N/S [feet] Start E/W [feet] End N/S [feet] End E/W [feet] 12.25in Open Hole 0.00 2500.00: 2500.00 0.00 _ 2428.71 0.00 0.00 460.28 -124.53 9.625in Casing 0.00 2500.00 2500.00 0.00 2428.71 0.00 0.00 __..___ 460.2 8 -124.53 8.Sin Open Hole 2500.00 8164.47• 5664.47 2428.71 8070.00 460.28 -124.53 _ _ _a ~ ~ 655.0 ,.~__~ _... 0 __.. -200.00. _ Tin Casing Production 0.00 8164.46' 8164.46 0.00 8069.99 0.00 __ __ _ 0.00. _ 655.00 __,. -200.00 • • uHOCa~~ Planned Wellpath Report Wellpath: SCU42-OSX Ver 4 Page 6 of 6 /,'rr BAKE Nuc~NE INTEQ .Operator ,. ~ UNOCAL __ Slot SCU42-OSX ~~~~ ____. ~~~ ~ ~ ~ ~~~ Area Cook Inlet, Alaska (Kenai Penninsula) Well 42-OSX ~ Field Soldotna Creek Unit Wellbore SCU42-OSX _____________~~______ .~____~ Facility Sec.S, T7N, R9W TARGETS ~ --------- -------_______ ~~ Name MD Meet] TVD [feet] North [feet] East [feet] Grid East [us survey feet] Grid North [us survey feet] Latitude ~ [°] Longitude ~ [°] Shape ~ 3 S 4 19/06 7788.00 ~ 662.98 -114.16. 341700.00 2458516.50 60 43 35.194N 150 53 03.196W ~ ------- polygon ~- SCU42-OSX - 77- and - / SURVEY PROGRAM Ref Wellbore: SCU42-OSX Ref Well ath: SCU42-OSX Ver 4 Start NID feet End MD ~feet~ Tool Type Positional Uncertainty Model __ Log Name/Comment Wellbore ~~-"~~~__ 0.00 ~ ~_.._. 2500.00 ...__._ ...._~~. aviTrak aviTrak(Standard) SCU42-05X 2500.00 8164.47 aviTrak aviTrak (Standard) SCU42-OSX • • ATTACHMENT1 - _ --- A028405 A028077 i r `----- ----- A028384 ~.---- - i r - - -- ' A028406 r A028399' i ~ i --_~ ~ A028990/ A028396' _._._. -._.J PROPOSED LOCATION 42-05X ~' j ~ i I i i _._..---._.._ ._._._.. 1 , A028997 A028996' • ---- - i _ _ ---- A029002 CIRI5810 _..__._________' A028993 Chevron 0 0.25 0. union oii Company SWANSON RIVER FIELD 5 ofCalifomia proposed Location 42-05x MilG9 • i ATTACHMENT2 r- I I I _.. ..l SN9W i 3 4 II 1 SCU 13-34 I I SRU 24-33 1 SCU 21A-Oa~~~~ -~ SCU a2-0a j ,~ ~_ 2-oa 1 ~ SCU 32A-O5 SCU 41-05 (,~~ 1 ~ SCU 12A-04 ~ ~, 6 ~.._..----.._.._.._.._.._~ 4 ~ j PROPOSED LOCATION j 42-OSX scu az-o5 ~ scu za3-oa _ * scu 2z-oa SCU 13-04 .~~...~ SCU 2438-Ga I SCUD 2A-05 j SCU 33-OS SCU 14A-05 -~ SCU 34-OS SCU 24A-OS ''~" SCU 314-04 SCU 34-04 ~ 'i r~ i ~. SCU 21A-09 7N9W: SCU 21-08t~L~~ SCU 41A-oe'~ ~~ `* .~ ' SCU 32-08 ~ SCU 312-09 1 SCU 31-08 `~' ~ I SCU 33A-08 ~ 8 •s:*.~ SCU 243-OS SCU 23A-09 j ~ ~~SCU 438-OS SCU 24A-09 1 ~ ,~ _ -~ j #- I } _.._.._.._.._.._..-----• j ~ 1~ I 10 II Chevron SWANSON RIVER FIELD Union Oil Company o Aso ., soo 3, o00 Pro osed Location 42-05x Feet of California P 1-mile Radius Alaska State Plare Zone 9, NAD27 ~ ~ ATTACHMENT3 ,. , ;* ,., ~- ,fix, ' r ~'~ :.~ ~. - '~ chevron SWANSON RIVER FIELD o so loo zoo Union Oil Company ofCalifomia Proposed Location 42-05x Feet Alaska State Plane Zone 9, NAD27 PROPOSED LOCATION 42-05X I PROPOSED LOCATION 42-05X TD ~: A 2" 3" To Shaker 3" Panic To Gasbuster '~ ~ 3 1 /8.. ~ ',~ ~ } ~ ~ r ~ ~,) ~ 2 1/16" \ ;" -' 2 1/16" °~~ -~ -'. ~ - r 1 21/16 21/16" - - rv I ~ ~ ~_ ;~ ll 31/8" J ~'~~ I ~ ~ '~ ~ N ~. ~~~ , ~-~ +O ~ l~ ~ ~~ ~' ' 21/16" 21/16" 1 Manual Choke ~ ~ Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16 5,000 PSI VALVES Kuukpik Drilling Rig 5 11 Choke Manifold Drawn By: L Ross Date: 8/1 /04 • ~ ~ 3" Mud Line from Mud Pumps to Rig Floor ~- 2" 5,000 psi threaded valve 2" 5,000 psi flanged hose Kiil Line Side 2 1/16" 5,000 psi rated manual valve g 2 1/16" 5,000 psi rated manual valve Drilling Spool 3 1/18" 5,000 psi Manual Valve 3 1/18" 5,000 psi Hydraulic Operated Valve Choke Line Side 3" Flanged Choke Hose To Choke Manifold inlet Kuukpik Drilling Rig 5 Choke and Kill Line Layout July, 2003 Drawn By L Ross • 13 5/8" 5,000 psi Annular Adaptor Spool 21 1/4" Diverter Spoc I~ Ive Kuukpik Drilling Rig 5 Diverter System with 13 5/8"Mnuler Date: 1/18/05 Drawn By: L Ross • ~ ~ k ~~ o s.~ ~F 1 ~, '1wui~ ~~ ® ~o _ ~ I f..,.:...~y i = L9 l~3 a • Kuukpik Drilling Rig 5 • Revised 2/3/06 • Union Oil Company of California Well SCU 42-05X Elev 153 Estimated Geologic Tops and Correlations RKB 174 SCU 42-05X Marker MD TVD TVDSS 69-7 Sand 7077 6997 6826 77-3 Sand 7865 7785 7614 TD 8164 8070 7899 • Chevron Swanson River Field Well SCU 42-05X Cement Program 13-3/8" Casing (Air Drilled to +/-70') Note: This string is only for structural support of the wellhead. 9-5/8" Casing (12-1/4" Hole to 2,500' MD): Cement volume based on open hole volume plus 50%, shoe joints and annulus. The job will consist of a lead and tail and cement will be brought to surface. The estimated total volume is as follows: Lead: 2,000' X 0.3132 cuft/ft (12-1/4" x 9-5/8") X 1.5 = 940 cuft = 475 sxs (1.98 yield) Tail: 500' X 0.3132 cuft/ft (12-1/4" x 9-5/8") X 1.5 = 235 cuft = 203 sxs (1.16 yield) 40' shoe joint X 0.4110 cuft/ft TOTAL: 940 + 235 + 17 = 1,192 cuft or 685 sxs 7" Casing (8-1/2" Hole to 8,164' MD): = 17 cuft = 7 sxs (1.16 yield) Cement volume based on open hole volume plus 30%, shoe joints and annulus. The job will consist of a lead and tail and cement will be brought to 4,000' MD. The estimated total volume is as follows: Lead: 3,164' X 0.1268 cuft/ft (8-1/2" x 7") X 1.3 = 522 cuft = 264 sxs (1.98 yield) Tail: 1,000' X 0.1268 cuft/ft (8-1/2" x 7") X 1.3 = 165 cuft = 142 sxs (1.16 yield) 40` shoe joint X 0.2148 cuft/ft = 8 cuft = 7 sxs (1.16 yield) TOTAL: 522 + 165 + 7= 694 cuft or 413 sxs Cementing Program SCU 42-05X 1 5/11/2006 • • Surface Hole Recommendations Mud Type: 6%KCI, EZ Mud Properties: Density Viscosity Plastic Viscosity Yield Point API FL ~H 0 - 1000' 9. ~, 60 - 85 7 - 16 30 - 40 N/C 8.5-9.0 1000-2500' 9. 9.2 50-75 8-16 30-40 <5 8.5-9.0 1d System Formulation: 6%KCI, EZ Mud if no used mud is available Product Concentration Water 0.905 bbl KCI 20 ppb (30K chlorides) KOH 0.2 ppb (9 pH) Barazan D 1.25-1.5 ppb (as required 35 YP) EZ Mud DP 0.75 ppb Aldacide G 0.1 ppb Baroid to a 9.0 ppg Baracor 700 1 ppb Barascav D 0.5 b add as the wells uds • Mix in order as listed • Add polymers slowly to minimize fisheyes. Production Hole Recommendations Mud Type: 6%KCI, EZ Mud Properties: Den Viscosit Plastic Viscosity Yield Point API FL ~H 2500 - TD' 11 2.5" 40-50 12-27 16 - 28 <5 8.5-9.0 An offset well require~a.A'2.5 ppg at TD. / System Formulation: 6%KCI, EZ Mud Product Concentration Water 0.905 bbl KCI 19.8 ppb (30K chlorides) KOH 0.2 ppb (9 pH) Barazan D 1.25 ppb (as required 35 YP) Dextrld 1-2 ppb EZ Mud DP 0.75 ppb Aldacide G 0.1 ppb Baroid as needed Baracor 700 1 ppb Barascav D 0.5 b maintain er dilution rate • Mix in order as listed • Add polymers slowly to minimize fisheyes Chevron Swanson River Field SCU 42-05X Drilling Waste Plan The water-base mud cuttings will be hauled from the SCU 42-05 Pad to the Swanson River Field Class II disposal well located on Pad SCU 243-4. A grind and inject facility will be mobilized and be located at the disposal well location ready to accept cuttings. The cuttings will be transported to the disposal well by vacuum trucks. In addition to the drill cuttings, excess water-base mud will be injected at the end of the project. The contingency plan in case the grind and inject facility would become inoperable for any reason is twofold. First, the cuttings may be loaded into tanks for storage until the grind and inject facility is operational. Second, the cuttings may be stored in the dedicated Swanson River Field Waste Cells. Drilling Waste Plan SCU 42-05X • • Maximum Anticipated Surface Pressure Calculation Swanson River Field SCU 42-05X Kenai Peninsula, Alaska Assumptions: 1. Based on offset drilling data, the maximum pore pressure gradient the drilling phase will be 0.624 psi/ft from 9-5/8" casing shoe to planned total depth at 8,070' TVD RKB. This is due to the presents of high pressure water sands found below 6,800' TVD. I have ran two cases, one with the 9-5/8" set at 2,428' TVD and a second with the 9-5/8" set at 3,206' TVD. 2. The M.A.S. P. during drilling operations will be governed by the 9 5/8" shoe frac gradient, and is calculated based on a full column of gas between the 9 5/8" shoe and the surface. 3. The M.A.S.P. during production/injection phase will be the estimated SIBHP minus the gas hydrostatic pressure between TD & the surface. The maximum gas pressure within the storage reservoir is designed to be 5,500 psi (0.687 psi/ft). M.A.S.P. During Injection Phase: Max. pore pressure at T.D. _ M.A.S. P. (tbg leak at surface) _ 8,070 ' VD x 0.687 psi/ft = 5544 psi 5544 psi - (0.096 psi/ft " 8,070 ft) _ = 4769 psi M.A.S.P. During Drilling Phase: ~~ ~0.~ 7~~I l~ ~~ Case 1 - 9-5/8" Shoe @ 2,500' MD/2428'.M6: , Max. Est. Frac pressure at 9-5/8" shoe = 2,428 ft. x 0;728,~si/ft = = 1768 psi M.A.S.P. during drilling = 1768 psi - (.096 psi/ft x 2,428 ft.) _ = 1534 psi ~ Case It - 9-5/8" Shoe @ 3,300' MD/3,206' ND ~p5 Max. Est. Frac pressure at 9-5/8" shoe = 3,206 ft. x 0.728 psi/ft = = 2334 psi M.A.S.P. during drilling = 2334 psi - (.096 psi/ft x 3,206 ft.) _ = 2026 psi ~2~3 Chevron Swanson River Field Kenai Peninsula Borough, AK 19-APR-06 MTL O:\Gas CFT\Openmind\Swanson\Soldotna Creek Unit North\SCU42-05X\Geology\SCU 42-05X Offset Wells.ppt CJ Chevron 2005 Drilling Noted Kicks in Offset Wells ^ SCU 33-05: • Took a 75 bbl salt water kick w/ 10.3 ppg mud at 7,116' M D; kill ed wit h a 10.7 ppg mud . ^ SCU 42B-05: • Took a gas kick w/ 10.5 ppg mud at 7,205' MD. • Weighted up to .12.4 ppg before killing it. ~ ^ QUESTION: • At what depth can we expect to encounter these same sands. Has the sand they took the kick in 426-05 been produced? Q Chevron 2005 Chevron • SCU 33-05 ^ Took a water kick after drilling through 69-7 sand Sand looks wet ~ Chevron 2005 SCU 42B-05 ^ Took a gas kick after drilling through 69-7 sand • Sand looks wet • Did it flow water? ©Chevron 2005 • SON-NEU convergence suggests low Sg SingleWell Viewer- MTL- MTL_SRF - weII:SCU 42B-05 ' View Tools • c 0 > a ~ ~~ V ~ ~ ~ ~ O ~ ~ , ~ nn ,, ~ O ~ W I~ .~ o ~' ~ ~ ~ L Q ~ O a.-~ ~ ~ .~ ~ ~ ~ ~ ~ ~ ~ Q (n ~ ~ ~ ~ _ ~ V ~ ~ Q ~ ~ ~ ~ ~ N L 0 ~ ~ 00 N L O ~ ~ ~ V ~ ~ ~ ~ \ tn N f~ ~ 0 ~ ~ ~ dl ~ ~ O . _ ~ ~ ~ ~ ~ ~ ~ ~ ra ~ ~ ~ X r~ p ~ ~ ~ ~ 0 "~ , ~ _ ~ ~'~ ~ ~ ~ Q N ~ ~ ~ ~ V ~ _ ~ ~ ~ o U ~ o ~ v ~- ~ (n F- I~ ~ ~ V ^ ^ ^ 0 0 N C Q i (U s U .. Chevron • LEAK OFF TEST PROCEDURE 1. Clean out the rathole below the shoe, and drill 20' of new hole. Circulate and condition mud. 2. Pull the drill string into the shoe. Rig up to observe annulus pressures. 3. Close the pipe rams and pump down the drillpipe at a slow rate (1/4 - 1/3 BPM) if exposed formation is permeable. Anon-permeable formation should be step tested to a predetermined pressure. 4. Measure the volume pumped and plot annulus pressure-vs-cumulative volume pumped. Compare annulus pressure to drill pipe pressure and confirm both are the same. Record and plot pressure versus volume pumped. The pumps should be shut down immediately upon indication of leak-off. Record the inital, shut down pressure and the pressure after 1, 2, and 3 minutes. 5. Release pressure and record the volume of fluid recovered in the trip tank. The point "B" shown in the attached graph at which the plot of drillpipe pressure stops increasing equally as the volume is pumped is called the P.I.T. limit, Leak Off, or pressure integrity test limit. The leak-off pressure is calculated as follows: Leak-off (EMW) = Mud weight in hole + P.I.T. (PSI) (0.052) X (shoe depth in TVD ft.) This equivalent mud weight should be made known to all drilling personnel to ensure it is not exceeded. See the drilling procedure for guidelines on expected LOT's or pressure integrity test limits for each casing shoe. SURFACE PRESS_ TYPICAL PIT PLOT [psi] NOTES: Point "A" will have some variance until the system begins to pressure up. Point "B" is the leak off and is abbreviated LOT. Point "C" is known as the injection pressure and is usually dependent on rate. Point "D" is known as the fracture closure pressure and may not stabilize if permeable formations are exposed. VOLUME PUMPED SHUT-IN-TIME [BBLSJ [MIN] P Calculation & Casing Design Factors Swanson River Field SCU 42-05X Kenai Peninsula, Alaska WELL: SCU 42-OSX FIELD: Swanson River DATE: 17-Apr-O6 DESIGN BY: Larry Buster Sect. 1 12 1/4" hole MUD WT. 9.2 PPG Sect. 2 8-1/2" hole MUD WT. 12.5 PPG TENSION MINIMUM COLLAPSE COLLAPSE WEIGHT TOP OF STRENGTH ~ PRESS @ RESIST. MINIMUM DESCRIPTION W/O BF SECTION TENSION BOTTOM w/o TENSION f MASP YIELD / SECTION CASING BOTTOM TOP LENGTH WT. GRADE THREAD LBS LBS 1000 LBS SF TENSION PSI* PSI SF COLL. PSI** PSI SF BURST 1 9 5/8" 2,500 0 2500 47 L-80 BTC-mod 117,500 117,500 1086 9.24 1068 4760 4.46 1534 5750 3.75 TVD 2,428 0 1a. 9 5/8" 3,300 0 3300 47 L-80 BTC-mod 155,100 155,100 1086 7.00 1411 4760 3.37 2026 5750 2.84 TVD 3,207 0 2 7" 8,164 0 8164 26 L-80 BTC-mod 212,264 212,264 519 2.45 2899 5410 1.87 4769 7240 1.52 TVD 8,070 0 * Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.44 psi/ft) for the 9-5/8" and 0.687 psi/ft for the 7". The casing will be completely evacuated for the 9-5/8". For the 7", we will assume 50% evacuation (0 psi/ft) and 50% with a 12.5 ppg mud (0.65 psi/ft). Notes: 1. All wellhead components are rated to 5000 psi working pressure. 2. Have ran two cases for the 9-5/8" casing setting depths. • • Chevron May 24, 2006 Timothy C Brandenburg Drilling Manager Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Revised Application for Permit to Drill SCU 42-05X, Soldotna Creek Unit Dear Commissioner, • Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com Enclosed for your approval is a revision of the recently submitted Application for a Permit to Drill (form 10-401) for the Swanson River Field SCU 42-05X Gas Storage Well. The application previously submitted was on an incorrect version of the form 10-401. / If additional information is required, please contact either myself or Mr. Larry Buster at 263-7853. Sincerely, ,-. ~ ~ Timothy C. Brandenburg Drilling Manager TCB:sk Attachment Cc: File Union Oil Company of California / A Chevron Company http://www.chevron.com • # Unocal- CNAEP CHECK DATE: 05/18/2006 PO Box 9034 CHECK N0: 0024477287 Chev~onTeX7E0 Concord CA 94524 PAYEE REF: 0010406649 COMPANY NO: 9198 MAIL CODE: 11 EC0 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100. ANCHORAGE, AK 99501 ADDRESS INQUIRIES TO; PO Box 9034, Concord, CA 94524-1.934 PHONE CONTACT: 925-827-7741 FAX CONTACT:. 925-680-3534 INVOICE DATE INVOICE #. OUR REFERENCE #. GROSS AMT. DISC. AMT. NET AMT: 05/1.7/2006 060517STA 0019003195 DRILL PERMIT SCU 42-05X $100.00 $100.00 DETACH AND. RETAIN THIS STUB FOR YOUR RECORDS CHECK # 0024477287 ATTACHED BELOW Unocal - GNAEP sz-zo NO. 0024477287 Sit th'evronTexaco ~o Bo ~9CA 94 2 5 4 05/18/2006 PAY TO ORDER OF STATE OF ALASKA ALASKA OIL & GAS CONSERVATION 1 ~ 1 ~ ' COMMISSION . 333.WEST 7TH AVENUE SUITE 100 Nor vauD aFrER ~ vEAR ANCHORAGE, AK 99501 One hundred anal 00/I00 Dollars ChevronTexaco - AUTHORIZED SIGNATURE ~~I CITIBANK DELAWARE, ONEPENN'S WAY, NEW CASTCE, l3E 19720 ~I i~'00 c44 7 7 2B 7-~' ~:D 3'i i00 209: 3869646 ill` ~)CXo - d ~7 ~ • .y... ~_._ ~ .~_ ' -=• FRANK H. MURKOWSKI, GOVERNOR ~I~t-7r~ OIL ~ u.W7 333 W. 7`" AVENUE, SUITE 100 CO11tSERQATIOI~T CODIIKISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 17, 2006 Kevin. Tabler Land and Government Affairs Manager Unocal Alaska PO Box 196247 Anchorage, AK 99519 `~ ~~ ~~~,~~ Re: Swanson River t (SR~j 42-OSX well Application for Spacing Exception Dear Mr. Tabler: Unocal Alaska requested by letter dated May 16, 2006 approval for a Spacing Exception for the above well. As we discussed this morning, this request is not necessary or appropriate for a gas storage injection well; so I am sending back the application. Please see 20 AAC 25.252 for the appropriate procedures for underground storage of hydrocarbons. If you have any further questions, please do not hesitate to call me at 793-1228. Sincerely, ~--~ Cathy . Foerster Commissioner TRANSMITTAL LETTER CHECKLIST WELL NAME .~C~ ~Z ^ U~~ PTD# Zb(o ~ d~t~ Development V Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If Iast 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 EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Com~anv NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C: \j ody\transmittal_checkl i st -_T _ WELL PERMIT CHECKLIST Field & Pool SWANSON RIVER, TYONEK GAS STOR_7728 Well Name: SOLDOTNA CK_t1NIT 42-05X _ _Program SEtt __ Well bore seg li PTD#:2060740 Company UNION OIL CO OF CALIFORNIA __ Initial ClasslType SER I PEND GeoArea 820..... Unit 5 1950 On/Off Shore On Annular Disposal Administration i1 Permit fee attached_ Yes . '~2 .Lease number appropriate- Yes ',3 Unique well name and number Yes '4 Well located'n a defined pool - No + ya^ek Undefined Gas pool, which is defined in SIO 6 as the 77-3 sandstone of the Tyonek Formation. - - 5 Well located proper distance. from drilling unit boundary_ Yes . Nearest property line across which landownership. changes is lease ADL 028396 (CIRI landowner) X1950' to west, 6 Well located proper distance from other wells Yes Nearby SCU 42A-05 &.426-05 are open to the Tyonek 77-3 sand but the sand. will be isolated prior to storage ops !~7 Sufficient acreage available in drilling unit Yes Only well open to the 77-3 sand within 114 mile radius within. this fault black. 8 If deviated, is wellbore plat included _ _ Yes _ _ _ 9 ~peralor only affected party Yes Nearest property line where landownership changes is X1950' to west where CIRI is landowner f Lease. A-028396)._ ',10 Operator has_approprate_bond in force Yes 11 Permit can be issued without conservation order Yes 12 Permit_can be issued without administ[ative approval Yes Appr Date i13 Can permit be approved before 15-day wait Yes SFD 5124/2006 X14 WelUocated within area and strata authorized byJnjection Order# (put 10# in comrnents)_(For_ Yes _ _ x'15 I All wellswithin.114-mile area of review identified (For service well only) Yes SCU 42A-05 & 42B-05 will be isolated from 77-3 sand prior to storage ops Well SCU 34-05 lies within 114 mile !16 Pre-produced infector;. duration ofpre-production Tess than_ 3 months_(For service well_ only) _ NA_ but is located across a fault that is known to be sealing. ', ACMP Finding of Consistency has been issued. for this pr_o)ect_ NA ACMP process does notaffect approval ofpermit to drill, -_ - - - _ 18 Conductor string.provided . Yes 13-318" @ 70'. • X19 Engineering ! Burface casing protects all known_ USDWs Yes 20 CMT vol adeguate_to circulate on conductor & surf_csg Yes Adequate excess. 1,21 CMT vol. adequate to tie-in long string to surf csg_ No_ ',22 CMT will cover-all known productive horizons_ - _ Yes - ',23 Casing designs adequate f_or C, T, B & permafrost_ Yes ~24 Adequate tankage or reserve pit Yes Kuukpik Rig 5. ',25 If a re-drill., has_a 10-403 for abandonment been approved . _ _ _ _ _ _ _ NA_ _ New well X26 Adequate wellbore separation proposed - - - - - - - _ . - - _ Yes _ _ ~ I27 If diverter required, does it meet regulations_ Yes 28 Drilling fluid.. program schematic & equip list adequate_ Yes Max MW 12.5ppg. Appr Date 1~~29 BOPES, do they rneet_regulation - Yes _ - WGA 5/25!2006 '',30 BOPE_press rating appropriate; test to-(put prig in comments).... Yes Test to 3000. psi. _M$P 1534 psi. '31 Choke_manfold complies wlAPI_RP-53 (May 84)_ - _ _ _ _ _ _ _ - Yes _ - 32 Work will occur without operation shutdown - Yes - . ~I33 Is presence_ of H2S gas probable _ _ _ _ _ . _ . _ _ _ _ _ .. - No_ _ Not an H2S area._ x,34 _Mechanicatcondition of wells within AOR verified (Fo[service well only) Yes - Cml records.of all AOR wells reviewed._ I,35 Permitcan be issued wlo_ hydrogen_sulfidemeasures - Yes _ - Geology ~,36 Data_presented on_ potential overpressure zones Yes Nearby.well SC11426-05 took a gas. kick with 10.5 ppg mud in the hale at 7205' MD.lttook12,4 ppg mud to. 37 Seismic analysis of shallow gas zones. NA_ kill the well. SIO 6, p.2 states the original resen!ojrpressuregradient is 0.61 psilft or 11.8 ppg EMW, Appr Date 38 Seabed condition survey (ifoff-shore) NA- - . .Mud program calls for theproduction hole to he d[illed with 11_.0 to_12.5_ppg mud. SFD 512412006 '39 Contact namelphone for weekly_progress reports(exploratory only] Yes Tim Brandenburg, 907-276-7600- • Geologic Engineering is Gas storage well: injection and production operations will occur involving the Tyonek 77-3 sand of the Tyonek Undefined Gas Commissioner: DiS Date: S~ ~~.~ Co issicner: l - - ____ Date ~~'~_ o stoner Date Pool. Offset wells SCU 42A-05 & 42B-05, which lie within 114 mile in the same fault block, will be abandoned in the 77-3 sand rior to onset of storage operations. OH logs from 93 to TD were obtained in 426-05 Mudlog and samples were obtained in - ----- - S'^30 -off • Well History File APPENDIX • Information of detailed nature that is not particularly gerniane 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 infom~ation, 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. • • • ~ `-~~`~ -~~ ~_.,~iil~ SCANNED N O V 1 4 2008 ~~ EPOCH Ch_ ev.on ~~ Union Oil Company of California - SCU-42-05x 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. LITHOLOGY AND REMARKS .............................. ........................................................5 3.2. SAMPLING PROGRAM AND DISTRIBUTION ..... ......................................................16 4. DRILLING DATA .......................................................... ......................................................17 4.1. DAILY ACTIVITY SUMMARY ............................... ......................................................17 4.2. SURVEY RECORD .............................................. ......................................................19 4.3. MUD RECORD ..................................................... ......................................................23 • 4.4. BIT RECORD ....................................................... ......................................................24 4.5. DAYS VS. DEPTH ................................................ ......................................................25 DAILY REPORTS APPENDIX I FORMATION LOGS APPENDIX II COMBO LOGS APPENDIX III DRILLING DYNAMICS LOGS APPENDIX IV • ~ EPOCH 2 • 1 MUDLOGGING EQUIPMENT AND CREW 1.1. EQUIPMENT SUMMARY :7 Parameter Equipment Type And Position Total Downtime Comments Electric Driven QGM Gas Trap Ditch Gas Mounted In Possum Belly; FID Total 0 Hydrocarbon Analyzer And Chromato ra h Rate of Penetration (ROP) Primary Drawworks Belt Driven 4 HRS Master computer rebooted stopping depth ques to Encoder On Drum Shaft Pason ( ) E och unit Pump stroke counter Externally Mounted Magnetic 0 Proximit Sensor Pason Hookload /Weight on bit (WOB) Hydraulic Pressure Cell (Pason) 0 Drill string torque Digital Signal From Top Drive (Pason) 0 Top drive rotary (RPM) Digital Signal From Top Drive (Pason) 0 Standpipe Pressure Hydraulic Pressure Cell (Pason) 0 Casing Pressure Hydraulic Pressure Cell (Pason) 0 Mud flow in /out (MFI / MFO) MFI Derived From SPM / MFO From 0 Flow Paddle Pason Pit volumes Ball Float Pit Sensors In All Pits And 0 Tri Tank Pason Driller's work station Explosion Proof Touch Screen (Pason) 0 Casing Pressure Hydraulic Pressure Cell (Pason) Company man's work station Pason 0 Toolpusher's work station Pason 0 Geologist's work station None on location 0 Pit's work station None on location 0 1.2. PERSONNEL Unit Number: ML032 Mudloggers Years Days Technician Days Sample Catchers Days Lees F. Browne Jr. 25 22 Steve Forrest 1 Mark Bietting 19 John Lundy 15 22 Howard Lamp 2 Robert Ferguson 17 • EPOCH Chevron Union Oil Company of California -SCU-42-05x • 2. GENERAL WELL DETAILS 2.1. OBJECTIVES SCU-42-05X is a gas storage well. The goal of this well is to isolate a high permeability sand interval for long term facilities use. The drilling plan is to achieve and maintain a low departure well path that increases to the horizontal in a tight turn just before the primary target zone. Formation damage and the hole problems that have affected nearby wells are to be avoided to ensure the long term success of the well. 2.2. WELL RESUME • Operator: UNION /CHEVRON Well Name: SCU 42-05X Field and Pool: Swanson River Unit, Tyonek 77-3 Sand State: County Alaska Kenai Borough Company Representatives: Steve Lawrence, Ron Lazenby, Ken Lucas Location: 1892' FNL, 509' FWL, SEC 5, T7N, R9W, SM Elevation: -Ground, -RKB 153' GL, 174' RKB Classification: Single zone service well. API #: 50-133-20561-00 Permit #: 206-074 AFE #: 165003 Rig Name /Type: KUUKPIK #5/ Land rig /Double with Tesco Top Drive Primary Target: Tyonek Primary Target Depth: 7869' MD / 7769' TVD Spud Date:-> Finish Date:-> 6/22/06 to 7/7/06 Total Depth: 8155' Total Depth Formation: Tyonek Mudlogging Company EPOCH WELL SERVICES MWD Company: BAKER HUGHES INTEQ Tools Run: Directional, Gamma Ray. Directional Drilling: BAKER HUGHES INTEQ Drilling Fluids Company: BAROID 2.3. HOLE DATA • Hole Maximum Depth T D Mud Deviation Shoe Depth Section MD TVD . . Formation Wei ht g (°inc) Casing MD TVD F.I.T. 12 %" 2635' 2553' Sterling 8.9>9.2 0>18 9 5/8" 2621' 2540' 15.5 8'/" 8155' 8055' Tyonek 9.0>12.5 18>1.2 7" 8130' 8030' - ~~ EPOCH 4 Ch Union Oil Company of California - SCU-42-05x 3. GEOLOGICAL DATA 3.1. LITHOLOGY AND REMARKS Sand (2635-2680') =very light gray to med gray; clast size ranges from medium lower to fine lower; moderate developed sphericity; subround to subangular; mod sorting; impacted texture; mature nature clean sand; slight matrix; grain support good porosity and permeability; no oil. Coal (2680-2800') =very dark gray to ray brown and black; firm to moderately hard; brittle; hackly in part; lignitic to sub bituminous; silty in part; no distinct conchoidal fracture noted; irregular lumpy to tabular fragments; some minor outgassing as sample warms. Sand (2700-2900') =medium to light gray to light gray with a slight bluish secondary hue; soft to firm to disconsolidated; moderately well to poorly sorted medium upper to medium lower grain predominates with some thin fine to very fine interbeds; generally clean grain supported sand, finer material tends to be very ashy/matrix supported; angular to sub angular clear to translucent quartz/volcanics predominates with abundant light to medium gray lithic grains and trace to common dark gray to black mafic mineral/lithic grains; trace to common coal fine grains, orange jasper/volcanics; blue gray and greenish gray lithics; trace to common coal fine inclusions; common thin coal interbeds; grades to tuffaceous sandstone/claystone and siltstone; very slightly to non calcareous; no oil indicators. • Tuffaceous claystone (2800-3000') =light to medium gray brown to light gray firm to soft; globular to irregular cuttings habit; dull earthy luster; clayey to slightly gritty texture; sandy and very gritty in part; trace micro-fine volcanic glass inclusions; trace micro thin carbonaceous laminations and fine coal inclusions; grades to and interbedded with associated sand and coal; very slightly to non calcareous. Sand (2900-3100') =medium to light gray to light gray with a slight bluish secondary hue; soft to firm to disconsolidated; moderately well to poorly sorted; fine lower to fine upper in the upper portion of the interval, becoming medium upper to medium lower grain as depth increases; finer material is matrix supported in a very light brownish gray clay/ash matrix which is very to moderately hydrophilic and easily washes away in water; medium grain sand occurs in samples as loose sand grains and appears to be primarily grain supported; occasional well indurated cuttings display very soft fluffy white ash matrix with phlogopite mica and glass shard inclusions; individual grains are predominately angular to sub angular clear to translucent quartz/volcanics with abundant light to medium gray lithic grains and trace to common dark gray to black mafic mineral/lithic grains; trace to common coal fine grains, orange jasper/volcanics; blue gray and greenish gray lithics; trace to common coal fine inclusions; common thin coal interbeds; grades to tuffaceous sandstone/claystone and siltstone; very slightly to non calcareous; no oil indicators. Tuffaceous claystone (3000-3200') =light to medium gray brown to light gray firm to soft; globular to irregular cuttings habit; dull earthy luster; clayey to slightly gritty texture; sandy and very gritty in part; trace micro-fine volcanic glass inclusions; trace • EPOCH 5 Chevron Union Oil Company of California - SCU-42-05x • to common to occasionally abundant micro thin carbonaceous laminations and fine coal inclusions; grades to and interbedded with associated sand and coal; very slightly too non calcareous. Sand (3100-3250') =medium to light gray to light gray with a slight bluish secondary hue; soft to firm to disconsolidated; moderately well sorted in the upper portion, becoming poorly sorted at the base of the interval, predominant medium lower grain at 3100', medium lower to coarse grain with trace very angular pebble fragments below 3200'; appears primarily grain supported with minority finer grain material grain and matrix supported in a very light brownish gray clay/ash matrix which is very to moderately hydrophilic and easily washes away in water; occasional cuttings display very soft fluffy white ash matrix with phlogopite mica and glass shard inclusions; individual grains are predominately angular to sub angular clear to translucent quartz/volcanics with abundant light to medium gray lithic grains and trace to common dark gray to black mafic mineral/lithic grains; trace to common coal fine grains, brown, red blue gray and greenish gray lithics; orange jasper/volcanics becoming abundant; trace to common coal fine inclusions; common thin coal interbeds; grades to tuffaceous sandstone /claystone and siltstone; very slightly to non calcareous; no oil indicators. Tuffaceous claystone (3200-3400') =light to medium gray brown to light gray firm to soft; globular to irregular cuttings habit; dull earthy luster; clayey to slightly gritty texture; sandy and very gritty in part; trace micro-fine volcanic glass inclusions; trace to common to occasionally abundant micro thin carbonaceous laminations and fine coal • inclusions; grades to and interbedded with associated sand and coal; very slightly to non calcareous. Sand (3250-3600') =medium to light gray to light gray with a slight bluish secondary hue; soft to firm to disconsolidated; moderately well sorted in the upper portion, becoming poorly sorted at the base of the interval, predominant medium lower grain at 3250', medium lower to coarse grain with trace to occasionally common small dark gray moderately rounded pebbles and very angular pebble fragments below 3350'; appears primarily grain supported with minority finer grain material grain and matrix supported in a very light brownish gray clay/ash matrix which is very to moderately hydrophilic and easily washes away in water; occasional cuttings display very soft fluffy white ash matrix with phlogopite mica and glass shard inclusions; individual grains are predominately angular to sub angular dark to medium gray lithics/dark mafic mineral grains with abundant clear to translucent quartz/volcanics grains; trace to common coal fine grains, brown, red blue gray and greenish gray lithics; orange jasper/volcanics becoming abundant; trace to common coal fine inclusions; common thin coal interbeds; grades to tuffaceous sandstone /claystone and siltstone; very slightly to non calcareous; no oil indicators. Coal (3480-3700') =very dark gray to black; hard to moderately hard; thin flat tabular fragments predominate; thinly bedded/interbedded with carbonaceous shale, tuffaceous siltstone/clay stone and sands as above described; sub-bituminous to lignitic; hackly in part; dull earthy to resinous luster; no outgassing noted. Tuffaceous claystone/siltstone (3400-3700') =light to medium gray to medium gray brown; • very firm to soft; irregular angular eroded to soft globular cuttings habit; dull earthy luster with a marked "micro-sparkly" appearance in harder better indurated fragments; clayey to slightly gritty texture; sandy and very gritty in part; trace micro ~~ EPOCH 6 Ch_ evron ~~ Union Oil Company of California - SCU-42-05x • fine volcanic glass inclusions; common to occasionally abundant micro-thin carbonaceous laminations and fine coal inclusions; grades to and is interbedded with associated sand and coal; non to very slightly calcareous. Sand (3600-3800') =medium to light gray to light gray with a slight bluish secondary hue; soft to firm to disconsolidated; moderately well to poorly sorted medium upper to medium lower grain predominates with some thin fine to very fine interbeds; generally very ashy/ash supported sand, finer material grades to tuffaceous siltstone/claystone; individual grains continue to be predominantly dark to medium gray lithics; minority angular clear to translucent quartz/volcanics; trace to abundant dark gray to black mafic mineral grains; trace to common bluish gray, greenish gray, orange, and brownish red grains; trace to common coal fine inclusions; common thin coal interbeds; interbedded with and grading to associated tuffaceous claystone/siltstones; no fluorescence or other oil indicators noted; non to very slightly calcareous Tuffaceous claystone/siltstone (3700-3800') =light to medium gray to medium gray brown; very firm to soft; irregular angular eroded to soft globular cuttings habit; dull earthy luster with a marked "micro-sparkly" appearance in harder better indurated fragments; clayey to slightly gritty texture; sandy and very gritty in part; trace micro fine volcanic glass inclusions; common to occasionally abundant micro-thin carbonaceous laminations and fine coal inclusions; grades to and is interbedded with associated sand and coal; non to very slightly calcareous. . Tuffaceous claystone (3800-3910') = medium light gray; very soft; lumpy to clumpy; clustered to clotted; some mushy to pasty; non cohesive; very slightly adhesive; amorphous fracture and habit; dull earthy luster; colloidal texture; massive homogeneous bed of hydrophilic clay; scattered loose coarse sand grains interbedded carbon shale and hard silt lamina; becoming dirty in parts. Sand/Conglomerate sand (3910-3970) =medium dark gray and various hues; clast size ranges from very coarse lower to fine upper matrix sands; subround to subanuglar smaller grains; scattered angular bit impacted fragments; moderate developed sphericity; very poor sorting; polished to pitted to chip textures; immature to submature nature; slight silica cement; silt and clay structured matrix in parts; both grain and matrix supported; appears a graywacke; with increased matrix support with depth; poor to occvasional moderate porosity and permeability; no show of oil. Conglomerate Sand/Conglomerate (3970-4060') =medium light gray and various hues of gray; some pale yellowish green hues noted throughout; clast size ranges from pebble to medium grain matrix sand; subround to angular bit impacted fragments; low to moderate developed sphericity; very poor sorting; polished to pitted to impacted to chipped textures; immature to submature nature; very slight silisic cement; both grain and matrix support; matrix is loosely attached and very hydrophilic; appears as a sub graywacke; fair to mostly poor porosity and permeability; no show of fluorescence or oil cut. Conglomerate Sand (4060-4150') =medium dark gray to medium light gray with hues of pale yellowish green throughout; clast size ranges from very coarse upper to medium lower; • subround to some angular bit impacted fragments; low to moderate developed sphericity; very poor to poor sorting with coarse sands with medium matrix sand; polished to pitted to impacted to chipped textures; immature mature nature; non to very slight silisic cement; both grain and EPOCH Chevron Union Oil Company of California - SCU-42-05x • matrix support; matrix clays hydrophilic and going into solution; appears as a sub graywacke; poor estimated porosity and permeability no show of oil. Tuffaceous Claystone (4150-4220') =very light gray to light gray; very soft; lumpy to clumpy; clustered to clotted; non cohesive to very slight adhesive; amorphous fracture and habit. Conglomerate Sand/Conglomerate (4150-4300') =light gray to medium light gray clast size ranges from pebble/cobble to medium lower as matrix sands; angular bit impacted fragments to subround medium grains; low to moderate developed sphericity; very poor sorting with two factions; coarse/very coarse and medium; polished and chipped coarse grains to impacted medium grains; immature to sub-mature nature; some conglomerate sandstones; non calcareous; non to very weak silisic cement; grain supported with secondary matrix support loosely attached; hydrophilic; appears as a sub graywacke; poor to fair porosity and permeability; grading to tuffaceous claystone. Tuffaceous Claystone (4300-4400') =yellowish gray; soft; slightly malleable sectile; mushy to pasty; tacky to slimy; non to slight cohesive; slight to moderate adhesive; earthy fracture; sub- nodular habit; moderate earthy luster; clayey to silty texture; going into solution; hydrophilic; massive uniform clays with minor coal and very carbon shale beds; composed of 70% clay, 30% silt. Conglomerate/Conglomerate sand (4300-4580') =light to medium gray to light greenish gray; • hard to moderately hard; poorly to very poorly sorted overall; sample consists of coarse sand size bit derived pebble/cobble fragments and medium lower to medium upper and fine grain sand; pebble fragments are primarily angular, some show slight to moderate stream erosion; commonly lightly coated in residue of very light gray to white ash/clay matrix; sand fraction consists primarily of clear to translucent white and light gray white volcanics/quartz grains with minority medium and dark gray to black volcanics/dark mafic mineral grains; matrix consists of mixed sand as described and very hydrophilic very light gray to yellowish gray to white ash/clay; grades to interbedded tuffaceous sand/claystone/siltstone; occasional thin carbonaceous shale and poorly developed coal interbeds; non to occasionally very calcareous; no fluorescence or other oil indicators. Ash/Tuff (4350-4600') =very light gray to white to yellowish white; soft; very hydrophilic and easily washed away in water; slightly adhesive; slightly to moderately cohesive; occurs as matrix in massive conglomerate/conglomeratic sands and as thin interbeds; trace fine phlogopite series mica flakes; non to occasionally very slightly calcareous Tuffaceous Claystone (4300-4500') =light to very light gray to light and medium brownish gray to occasionally brown; soft to slightly firm; dull earthy luster overall, some cuttings show micro- sparkly highlights due to included volcanic glass shards and minute mica flakes; slightly adhesive; moderately to slightly cohesive; very to moderately hydrophilic; easily washed away in water; trace minute black/gray mineral inclusions; very ashy; non to occasionally trace calcareous; no fluorescence or other oil indicators. Tuffaceous Sandstone (4580-4700') =light to very light gray with a slight brownish secondary hue; soft to firm; moderately well sorted; fine lower to very fine upper grain predominates; trace medium lower and fine upper grains; dull earthy luster; clayey/gritty texture; ~~ EPOCH $ Chevron Union Oil Company of California - SCU-42-05x • uniformly matrix supported in a very light to light brownish gray to white ash/tuff matrix; trace dark mafic mineral/volcanic grains give an overall salt and pepper appearance in cleaner appearing cuttings; matrix imparts a very clayey appearance to cuttings and is moderately adhesive /slightly to moderately cohesive; individual grains are predominantly clear to translucent white and gray (smoky) quartz/volcanics; sub angular to angular to sub spherical; largely unweathered volcanics; matrix is moderately to very hydrophilic; easily washes away in wash water/mud circulation; trace to common thin coal interbeds and minor, thicker shaly coals throughout; trace hard clear amber with inclusions; grades to and interbedded with associated tuffaceous claystones and ash/tuffs; non calcareous; no fluorescence or other oil indicators noted. Tuffaceous Claystone (4500-4900') =light to very light gray to light and medium brownish gray to occasionally brown; soft to slightly firm; dull earthy luster overall, some cuttings show micro- sparkly highlights due to included volcanic glass shards and minute mica flakes; slightly adhesive; moderately to slightly cohesive; very to moderately hydrophilic; easily washed away in water; trace minute black/gray mineral inclusions; very ashy; non to occasionally trace calcareous; no fluorescence or other oil indicators. Tuffaceous Sandstone (4700-5000') =light to very light gray with a slight brownish secondary hue; soft to firm; moderately well sorted; fine lower to very fine upper grain predominates; trace medium lower and fine upper grains; trace angular bit shattered pebble fragments in sample at 4800';micro-sparkly to earthy luster; clayey/gritty texture; uniformly matrix supported in a very light to light brownish gray to white ash/tuff • matrix; trace dark mafic mineral/volcanic grains give an overall salt and pepper appearance in cleaner appearing cuttings; matrix imparts a very clayey appearance to cuttings and is moderately adhesive /slightly to moderately cohesive; individual grains are predominantly clear to translucent white and gray (smoky) quartz/volcanics; sub angular to angular to sub spherical; largely un weathered volcanics; matrix is moderately to very hydrophilic; easily washes away in wash water/mud circulation; trace to common thin coal interbeds and minor, thicker shaly coals throughout; grades to and interbedded with associated tuffaceous claystones and ash/tuffs; non calcareous; no fluorescence or other oil indicators noted. Tuffaceous Claystone (4500-4900') =light to very light gray to light and medium brownish gray to occasionally brown; soft to slightly firm; slightly gritty to very clean clayey texture; dull earthy luster overall, some cuttings show micro-sparkly highlights due to included volcanic glass shards and minute mica flakes; slightly adhesive; moderately to slightly cohesive; very to moderately hydrophilic; easily washed away in water; trace minute black/gray mineral inclusions; very ashy; grades to and interbedded with above tuffaceous sandstone and thin brownish to light greenish gray non tuffaceous claystone; non to occasionally trace calcareous; no fluorescence or other oil indicators. Coal (5130-5200') =black to very dark gray; hard to firm; brittle to hackly; thinly bedded/interbedded with carbonaceous shales and siltstones; sub-bituminous to lignitic; harder fragments are thickly fissile/tabular; upper and lower contacts on these thinly bedded (1/4") thick fragments are smooth and lightly rippled; trace reddish brown siltstone on contacts; trace very poorly developed conchoidal fracture; trace Clete on fracture surfaces. Tuffaceous Sandstone (4700-5000') =light to very light gray with a slight brownish ~ EPOCH 9 Ch Union Oil Company of California - SCU-42-05x • secondary hue; soft to firm; moderately well sorted; fine lower to very fine upper grain predominates; trace medium lower and fine upper grains; in the interval 5230-5260', 40 to 80% of sample medium upper to medium lower dark gray to black to light and medium gray and clear angular sand with trace orange brown and bluish gray grains in clay/ ash/tuff matrix; micro-sparkly to earthy luster; clayey/gritty texture; uniformly matrix supported in a very light to light brownish gray to white ash/tuff matrix; trace dark mafic mineral/volcanic grains give an overall salt and pepper appearance in cleaner appearing cuttings; matrix imparts a very clayey appearance to cuttings and is moderately adhesive / slightly to moderately cohesive; individual grains are predominantly clear to translucent white and gray (smoky) quartz/volcanics; sub angular to angular to sub spherical; largely un weathered volcanics; matrix is moderately to very hydrophilic; easily washes away in wash water/mud circulation; trace to common thin coal interbeds and minor, thicker shaly coals throughout; grades to and interbedded with associated tuffaceous claystones and ash/tuffs; non to very slightly calcareous; no fluorescence or other oil indicators. Ash/Tuff (4850-5400') =very light gray to white to yellowish white; soft; very hydrophilic and easily washed away in water; slightly adhesive; slightly to moderately cohesive; occurs as matrix in massive sands and as thin interbeds trace fine phlogopite series mica flakes; non to occasionally very slightly calcareous. Tuffaceous Claystone (5400-5470') =yellowish gray grading to yellowish brown at 5440'; very soft; lumpy to clumpy; clustered to clotted; amorphous fracture and habit; dull earthy luster; colloidal to ashy texture; gradational beds of tuffaceous clay, silt and minor beds and lamina of • very carbonaceous shale and coal. Carbonaceous Shale (5470-5530') =brownish black grading to black occasional dusky yellowish brown; firm; earthy luster; smooth to matte texture; irregular to planar fracture along shale partings; visible bleeding gas in lignitic cuttings; composed of very carbonaceous shale and clays grading to sub lignitic coal. Tuffaceous Claystone (5530-5560') =yellowish brown; very soft; lumpy to clumpy; clustered to clotted; amorphous fracture and habit; very hydrophilic and going into solution; dull earthy luster; colloidal to ashy texture; uniform bed of clay composed of 80% clay 20% silt w/various detrital material; scattered thin beds of coal and carbon shale. Carbonaceous Shale and clay/coal (5560-5620') =brownish black mottled black and various hues of both; becoming dark yellowish brown in carbonaceous clay; brittle to firm; earthy mottled resinous luster; matte texture; irregular to hackly to planar fracture along carbon shale partings; composed of very carbonaceous shale and clay with thin beds of lignitic coal; visible bleeding gas in coal fragments. Tuffaceous Claystone (5620-5680') =pale yellowish brown; very soft; lumpy to clumpy; clustered to clotted; mushy to pasty in parts; non to slight cohesive; slight to moderate adhesive; amorphous fracture and habit; hydrophilic; moderate earthy luster; colloidal to ash texture; massive gradational beds of tuffaceous clay, devitrified ash, silt and minor beds of medium grained sand; appears reworked in parts. • Tuffaceous Siltstone (5680-5750') =pale yellowish brown; poor induration; brittle; crumbly; lumpy to clumpy; clustered to clotted; mushy to pasty; non to slight cohesive; slightly adhesive; earthy to amorphous fracture and habit; moderate earthy luster; silty EPOCH 10 Chevron Union Oil Company of California - SCU-42-05x • to ashy texture; very obviously detrital silt. Tuffaceous Siltstone (5750 -5820') =pale yellowish brown; very soft; lumpy to clumpy; clustered to clotted; gelatinous; mushy to pasty; tacky to slimy; non to slight cohesive; slight to moderate adhesive; earthy to amorphous fracture; amorphous to subnodular habit; moderate earthy luster; colloidal to ashy/silty texture; massive reworked section of silt, very fine sandstone, and devitrified ash. Tuffaceous Claystone (5820-5860') =yellowish gray; very soft; lumpy to clumpy; clustered to clotted; gelatin; mushy to pasty; various consistency and tenacity; non cohesive; slight adhesive; very hydrophilic; amorphous fracture and habit; moderate earthy luster; ashy to colloidal texture; interbedded with fine grain sand, silt and very carbon shale and coal; overall obviously detrital Sand (5870-5930') =very light gray; clayt size ranges from coarse lower to fine upper; no abundant faction; sub angular to subround; moderate developed sphericity; moderate sorting; impacted texture; submature to mature nature with depth; very weak silisic cement; non calc; dominant grain support with slight clay/ash matrix loosely attached; composed of 90% quartz, 10% chert and various lithic fragments; arenaceous; good porosity and permeability; no oil indicators. Tuffaceous Claystone (5930-5970') =yellowish gray to pale yellowish gray; very soft; brittle; lumpy to clumpy; clustered to clotted mushy to pasty; tacky to slimy; slight cohesiveness; • moderate adhesiveness; earthy to amorphous fracture; amorphous habit; moderate earthy luster; silty to ashy to clayey texture; massive reworked silts and clays grading to sand at 5965'. Sand (5970-6040') =very light gray; clayt size ranges from coarse lower to fine grains; scattered very coarse; no abundant faction; subround; moderate developed sphericity; impacted texture; submature nature; non to very slight silisic cement; non calcareous; slight to moderate clay/ash loosely structured matrix; hydrophilic; general grain support with secondary matrix; composed of 90% quartz, 10% various lithic fragments fair porosity and permeability; no oil. Tuffaceous Sandstone (6060-6190') =very light gray; soft to disconsolidated to firm cuttings; moderately well sorted in the fine lower to very fine upper to fine upper sand size range all matrix supported in a very light gray to nearly white volcanic ash/tuff matrix; sand is primarily clear to translucent white to very light smoky gray volcanics with minority stream derived quartz grains; volcanics display marked heat rounded appearance; trace dark gray to black mafic mineral grains; trace phlogpite series mica flakes; no fluorescence or other oil indicators, non to very slightly calcareous. Conglomeratic Sand/conglomerate (6190-6300') =light to very light gray to medium gray; samples are collected as loose disconsolidated sand/pebble fragments imbedded in a mixture of finely ground clay/ash matrix material and material derived from interbedded tuffaceous Claystone/siltstones; grain size varies from fine upper to medium lower to very fine in the upper portion to pebble conglomerate at the base; conglomeratic material consists of pebble and larger clasts in a matrix of medium upper to medium lower to coarse sand and fine to very fine sand, clay/ash supported in part; sand is primarily clear to translucent white to smoky volcanics/quart about evenly divided between angular bit derived fragments, angular volcanic glass shards and heat altered spherical to sub-spherical grains abundant dark gray to black, ~~ EPOCH 11 Chevron Union Oil Company of California - SCU-42-05x • angular mafic mineral/lithic grains/pebble fragment primarily matrix supported; grain supported in part; non to very slightly calcareous; abundant dark brownish black viscous liquid mud additive (baranex)mixed with polymer) at 6250 sample; no fluorescence or other oil indicators. Coal (6240-6340') =black to very dark brownish black; hard to very hard; mod tenaceous to brittle in part; coarsely fissile; slightly shaley; hackly in part dull resinous luster on bedding surfaces; bright vitreous luster on fresh fracture surfaces; clean conchoidal fracture normal to bedding; slight cleat on softer cuttings; below 6310 material becomes very softer and very lignitic; no oil indicators. Sand/conglomerate sand (6340-6390') =very light gray; clast size ranges from coarse lower to fine upper; subround to subangular; moderate developed sphericity; scattered discoidal grains; moderate to poor sorting; no abundant faction; impact texture; submature nature; non to very slight silic cement; non calcareous; moderate clay matrix; loosely attached and hydrophilic; both grain and matrix support; composed of 90% quartz; fair to poor porosity; no oil. Tuffaceous Claystone (6400-6475') =pale yellowish brown to dark yellowish brown and various hues of both; very soft to soft; lumpy to clumpy; clustered to clotted; gelatinous; mushy to pasty; non to slight cohesive; slight adhesive; earthy to amorphous fracture; sub nodular to amorphous habit; dull to moderate luster; grading to carbon clay. Tuffaceous Sandstone (6550-6600') =very light gray; soft to disconsolidated to firm cuttings; • moderately well sorted in the fine lower to very fine upper to fine upper sand size range all matrix supported in a very light gray to nearly white volcanic ash/tuff matrix; sand is primarily translucent white to clear to light smoke gray volcanics with trace stream bed erosional quartz grains; individual grains are subangular to sub-spherical to angular; volcanics are commonly heat rounded; trace dark gray to black mafic mineral grains; trace phlogopite series mica flakes; trace to common calcareous tuff grades to very thin calcareous tuff interbeds; closely bedded/interbedded with tuffaceous claystones. Coal (6515-6565') =black & brownish black lignitic to sub-bituminous; slightly to very silty; hackly; brittle; irregular to slightly tabular cuttings habit; dull resinous luster; trace to common poorly developed conchoidal fracture; common cleat. tuffaceous siltstone (6570-6670') =pale yellowish brown; poor to some moderate induration; some noted pdc soft sediment deformation; slightly crumbly to brittle mushy to pasty; tacky to slimy; slight cohesive; moderate adhesive; earthy fracture; subnodular habit; dull earthy luster; silty to ashy texture; massive gradational silts interbedded with clay, ash and carbon shale with thin coal. Carbonaceous Clay and shale/Coal (6670-6730') =moderate brown to dark yellowish brown and various hues of all; soft to firm; earthy to sub resinous luster; clayey texture; earthy fracture; composed of moderate carbonaceous clay mottled with carbonaceous shale, silt and minor sub lignitic coals. Coal/Carbonaceous Clay and shale (6740-6780') =brownish black mottled black some dusky • yellowish brown at contacts; soft in carbon clays to firm in coals; earthy mottled resinous luster; clayey to matte texture; earthy fracture in clay to planar fracture along shale partings to hackly in coals; visible bleeding gas in coal cuttings. ~~ EPOCH 12 Ch Union Oil Company of California - SCU-42-05x • Carbonaceous Clay, shale and coal (6780-6820') =black mottled brownish black grading to dark yellowish brown at clay contacts; generally firm with some coal being hard; resinous mottled earthy luster's; matte textured; hackly fracture in coals to sub-planar fractures along carbonaceous shales; abundant visible bleeding gas in lignitic coals. Tuffaceous Siltstone (6830-6920') =light brownish gray to light gray and various hues of both; poor induration; brittle; crumbly; mushy to pasty; non to very slight cohesive; slight to moderate adhesive; earthy fracture; sub nodular habit; moderate earthy luster; silty to clayey/ashy textures; massive bed of homogeneous silt composed of 60% silt, 30% clay, 10% ash and detrital material. Sand (6920-6970) =very light gray to yellowish gray overall; clast size range from medium upper to fine upper; sub-round; moderate sphericity; moderate sorting; impacted texture; submature to mature nature; non to very weak silic cement; dominant grain support with possible secondary matrix in thin zones; sub arenaceous; clean overall; composed of 90% quartz, 10% chert, meta greenstone and various lithic fragments; good to fair porosity and permeability; no show of fluorescence or oil cuts. Conglomerate Sand/Conglomerate (6980-7035') =very light gray; clast size ranges from pebble to medium lower in matrix sands; angular coarse bit grains to subround medium grains; low to moderate developed sphericity; very poor sorting; chipped coarse grains to impacted medium grains; submature nature; non to very slight silic cement; non calcareous; dominant • grain support to 7000' becoming grain and matrix with increased clay/ash content; composed of 90% quartz, 10% chert, meta, greenstone; fair to good porosity and permeability to 7000 becoming poor to fair after. Tuffaceous Siltstone (7040-7090') =yellowish gray mottled very light gray to white (ash); very poor induration; brittle; mushy to pasty becoming clotted to clustered in parts; slight cohesive; moderate adhesive; earthy fracture; sub nodular habit; moderate to bright earthy luster's; silty to ashy texture; composed of 60% silt, 30% clay, 10% ash. Tuffaceous Claystone (7090-7150') =pale yellowish brown mottled very light grayish white (ash); soft; mushy to pasty; tacky to slimy; slight cohesive; moderate adhesive; very hydrophilic; earthy fracture; subnodular habit; moderate earthy luster; clayey to colloidal texture; composed of 50% clay, 50% silt, ash and very fine to fine grain sand interbedded. Tuffaceous Siltstone (7160-7200') =pale yellowish brown to light brownish gray; poor induration; crumbly; slightly sectile; mushy to pasty; slimy; slightly cohesive; slight to moderate adhesive; earthy fracture; subnodular habit; dull earthy luster; silty to clayey texture; massive gradational beds of silt, clay, ash and micro laminae of carbon material becoming sandy with depth. Tuffaceous Sandstone (7200-7300') =very light gray to very light yellowish gray; sample is generally soft to firm; moderately indurated to disconsolidated; moderately well sorted; fine upper to fine lower; spherical to sub spherical to angular and subangular; clear to translucent white quartz/volcanic sand in fluffy white to very light gray to yellowish gray ash/clay matrix; matrix also appears as micro-thin interbeds, is moderately to very hydrophilic and easily washes ~ EPOCH 13 Chevron Union Oil Company of California - SCU-42-05x • away in water; trace thin, mica flakes trace dark gray to black, mafic mineral grains; trace greenish gray lithics; very slightly calcareous; no fluorescence or other oil indicators. Coal (7200-7400') =black to very dark brownish black to dark brown; firm to moderately hard; brittle; hackly; irregular angular to tabular cuttings habit; dull earthy to sub resinous luster; shaly to silty; sub bituminous to lignitic; poor conchoidal fracture; common cleat; vigorous outgassing when fresh; Tuffaceous Siltstone (7200-7400') =pale yellowish brown to light brownish gray; poor induration; crumbly; slightly sectile; mushy to pasty; slimy; slightly cohesive; slight to moderate adhesive; earthy fracture; subnodular habit; dull earthy luster; trace microthin carbonaceous laminations and inclusions; silty to clayey to sandy texture; grades to similar tuffaceous claystone and sands; common thin to occasionally massive coal Coal/Carbonaceous Shale (7400-7450') =black mottled brownish black; brittle to firm; earthy mottled resinous luster's; matte texture; hackly fracture in coal to sub planar along carbon shale partings; visible bleeding gas from lignite. Tuffaceous Siltstone/ash (7460-7480') =very light gray mottled white (ash); poor induration; brittle; crumbly; mushy to pasty; non to slight cohesive; slight to moderate adhesive; earthy fracture; subnodular habit; moderate to bright earthy luster; ashy to silty texture; thick to massive gradational beds of reworked silt and devit ash. • Tuffaceous Siltstone (7490-7540') =very light gray mottled yellowish gray; very poorly indurated; brittle; crumbly; mushy to pasty; non to slight cohesive; slight to moderate adhesive; earthy fracture; subnodular habit; moderate earthy luster; gradational silts and ash reworked and redeposits interbedded sand and thin coals. Sand (7540-7590') =very light gray; claat size ranges from medium upper to fine upper; subround; moderate developed sphericity; moderate sorting; impacted texture; submature nature; non to very weak silic cement; non calcareous; dominant silt/ash matrix support; grades to silt and ash in parts; interbedded sands; poor to fair porosity and poor permeability; no show of oil. Tuffaceous Siltstone (7200-7400') =light gray white to yellowish gray to light brownish gray; crumbly; slightly sectile; mushy to pasty; slimy; slightly cohesive; slight to moderate adhesive; earthy fracture; subnodular habit; dull earthy luster; trace micro thin carbonaceous laminations and inclusions; mottled appearance due to micro lamina of darker mineral material; silty to clayey texture overall; occasionally slightly to moderately sandy; grades to tuffaceous sandstone; interval between 7630 and 7670' grades to partially grain supported conglomerate sand with a very ashy matrix; thin to moderately thick to occasionally massive coal interbeds; occasional thin carbonaceous shale intervals; non to trace calcareous; no fluorescence or other oil indicators. Tuffaceous Sandstone (7590-7800') =very light gray to very light yellowish gray; sample is generally soft to firm; moderately indurated to disconsolidated; moderately well sorted; fine upper to to fine lower; spherical to sub spherical to angular and subangular; clear to translucent • white quartz/volcanic sand in fluffy white to very light gray to yellowish gray ash/clay matrix; matrix also appears as micro-thin interbeds, is moderately to very hydrophilic and easily washes away in water; trace thin, fine phlogopite series mica flakes trace dark gray to black, mafic ~~ EPOCH 14 Ch_ evron ~~ Union Oil Company of California - SCU-42-05x • mineral grains; trace greenish gray lithics; grades to medium to coarse grains ashy conglomerate sand at 7825-7835'; non to trace calcareous; no fluorescence or other oil indicators. Tuffaceous Claystone (7840-7870') =light to medium gray with a slight bluish secondary hue; firm to soft to moderate firm; tabular to irregular circulation eroded fragments; dull earthy luster; clean clayey to slightly silty texture; moderately adhesive; slightly cohesive; moderately indurated; non calcareous; no oil indicators. Sand (7870-7900') =light to very light gray; soft to slightly firm in samples; fine lower to fine upper to medium lower grain clear to translucent white to light to medium smoky volcanics/quartz sand; ash and silt matrix support; grain supported in part; estimate 20% of sample shows visible porosity; matrix is fine white to very light gray ash/clay; very hydrophilic and easily washed away in water; grades rapidly into similar tuffaceous siltstone as depth increases; non to trace calcareous; no oil indicators. Tuffaceous siltstone (7900-7990') =light gray to yellowish gray to light brownish gray and various hues of all; poor to moderate induration depending on ash content; crumbly to crunchy; mushy to pasty; some stiff; slight to moderate cohesive; slight to moderate adhesive; amorphous to earthy fracture; colloidal to subnodular habit; dull to moderate earthy luster; silty to ashy to gritty texture; gradation and reworked beds of silt, ash, clay and sand. Coal/carbon shale and Carbon Clay (7990-8030') =brown mottled black to brownish black; • thinly laminated layers of coal, carbonaceous shale and carbon clays; planar fracture along shale partings; earthy luster's; brittle; no visible bleeding gas from cuttings. Tuffaceous siltstone (8040-8080') =continued silts as from 7900' to 7990': light gray to yellowish gray to light brownish gray and various hues of all; poor to moderate induration depending on ash content; crumbly to crunchy; mushy to pasty; some stiff; slight to moderate cohesive; slight to moderate adhesive; amorphous to earthy fracture; colloidal to subnodular habit; dull to moderate earthy luster; silty to ashy to gritty texture; gradation and reworked beds of silt, ash, clay and sand. Tuffaceous Sandstone (8040-8122') =very light gray to very light yellowish gray; sample is generally soft to firm; moderately indurated to disconsolidated; moderately well sorted; fine upper to fine lower; spherical to sub spherical to angular and subangular; clear to translucent white quartz/volcanicsand in fluffy white to very light gray to yellowish gray ash/clay matrix; matrix is hydrophilic and easily washed away; trace fine phlogopite series mica flakes and dark mafic mineral grains; non to very slightly calcareous; no oil indicators. Sand (8122-8155') =very light gray; clayt size ranges from medium upper to medium lower with some fine grains; moderate sorting; moderate sphericity; subangular to subround; loose grain support with secondary matrix support in parts; poor to fair porosity and permeability; no shows of oil. • ~~ EPOCH 15 €hevron Union Oil Company of California - SCU-42-05x 3.2. SAMPLING PROGRAM AND DISTRIBUTION CJ • Set T e and Pur ose Interval Fre uenc Distribution 30' Unocal -Alaska Resources 14 Washed and Dried 2635' to 8155' through 77-3 909 West 9t" Avenue Envelopes sand Anchorage, AK 99501 Attn: Tony Hillegeist 30' Unocal -Alaska Resources B Washed and Dried 2635' to 8155' through 77-3 909 West 9t" Avenue Envelopes sand Anchorage, AK 99501 Attn: Tony Hillegeist BOX Washed and Dried 30 Unocal -Alaska Resources '" 1 Envelopes 2650' TO 4210' SAMPLES Avenue 909 West 9 Anchorage, AK 99501 BOX Washed and Dried 30 Unocal -Alaska Resources t" 2 Envelopes 4210' TO 5800' SAMPLES Avenue 909 West 9 Anchorage, AK 99501 BOX Washed and Dried 30 Unocal -Alaska Resources ~" 3 Envelopes 5800' TO 6910' SAMPLES Avenue 909 West 9 Anchorage, AK 99501 30' AND 10' Unocal -Alaska Resources BOX Washed and Dried 6910' TO 8155' SAMPLES g09 West 9t" Avenue 4 Envelopes THROUGH Anchorage, AK 99501 77-3 SAND E~ EPOCH 16 Chevron Union Oil Company of California - SCU-42-05x 4. DRILLING DATA 4.1. DAILY ACTIVITY SUMMARY June 22, 2006 Nipple up, drift bell nipple and diverter with test plug. Test diverter and change savor sub and load BHA on to pipe rack. Nipple up diverter line and pick up BHA, DC and repair the rig tongs. Make up bit and BHA and run into the hole. Tag bottom at 96' and check for leaks. Drill formation from 96' to 114' and pull out of the hole to check bit and BHA because of poor ROP. Everything looks OK, run in to bottom (Trip Gas = 0) and drill to 166'. Abundant pea gravel on shakers. June 23, 2006 Drill to 410' and pump a Hi-Vis sweep with a small increase in cuttings at the shakers. Make a gyro run and POOH and P/U the kick-off assembly. TIH with no problems and R/U and run gyro to orientate the tool. Begin to slide and rotate when needed. June 25, 2006 Drill and slide formation. June 26, 2006 Drill and slide to 2558'. Noticed a bad spot on the drill line and circulated and cut new drill line. Drilled ahead to 2635' and pumped out of the hole to 500'. Tripped into the hole to bottom and pumped a hi-vis walnut sweep to gauge the hole. The hole took 18 bbls over a calculated hole volume indicating a fairly gauged hole. Pumped out of the hole to run 9 5/8" casing. Wiper gas = 60 units with no problems. June 27, 2006 Finish pumping out of the hole and lay down BHA and rig up and run 9 5/8" casing. Land casing with shoe at 2621'. Circulate and pump a walnut flag and circulate out 17 units of trip gas • and cement casing. June 28, 2006 Finish cementing 9 5/8" casing with cement returns to surface. Pump all pits out, rinse and begin building new mud. Nipple down the diverter and nipple up the BOPS. Begin testing the BOP's. June 29, 2006 Finish testing BOPE and pick up 8.5" BHA and 50 joints of drill pipe. Trip in the hole and wash 2 stands to bottom and tag cement at 2536'. Drill cement, float equipment, shoe and 10' of new formation. Displace the active mud system with KCL/POLYMER mud. Circulate bottom's up with no trip gas recorded. Perform F.I.T with a good test of 15.5 ppg. Pull up into casing and begin building volume while waiting on traction motor for the #2 mud pump. June 29, 2006 Finish repairing mud pump #2 and begin drilling formation to 4000' and begin to weight up to 9.7 ppg. Drill to 4218' and lost pump #1, pump a dry job and pull into casing. June 30, 2006 Circulate on trip tank while working on mud pump #1 (24 hrs) July 1, 2006 Finish working on mud pump #1. Trip in the hole and wash the last 60 feet and resume drilling (WG = 71 units). Drill to 4500' and weight up to 10.5 ppg and pumping hi-vis sweeps with a moderate increase of cuttings noted at the shakers. At 5500' system was weighted up to 11.5 ppg and drilling ahead. July 2, 2006 Drill and slide to 6300' and weight up to 12.3 ppg. Drill to 6350' and weight up to 12.4 ppg and drill ahead. July 3, 2006 Drill formation to 6475'. Condition the mud, monitor the well, pull 5 stands and pump a dry job. Pull out of the hole. Work tight hole by back reaming and pulling 20-25K over pulls. Pull out of the hole and change drill bits and run in the hole with the drill collars and work on the IBOP. July 4, 2006 Finish working on IBOP and trip into the hole to bottom and drill formation. Trip Gas = 142 units. Drill formation and work stuck pipe (half hour) at 6588' and drill ahead. E~ EPOCH Ch Union Oil Company of California - SCU-42-05x • July 5, 2006 Drill formation to 7403' and work on top drive swivel and then pull a wiper trip to 6430'. Hole tight tripping out. Trip to bottom with 19' of fill and drill formation. Wiper Gas = 208 units. July 6, 2006 Drill formation to 7572'. Change out swab in pump #2 while circulating. Drill formation to 7984' and circulate and change out swab and liner in pump #2. Drill formation. July 7, 2006 Drill formation to 8122' (TD). Circulate and condition the drilling mud with bottoms up X3. Pull five stands out and pumped the next ten stands out to 6900'. Pipe is differently sticking. Pump out of the hole from 6500' to 5900'. Hole was tight at 6408'. Pull out of the hole to 2578' and cut new drilling line and tube the rig. Begin to trip back to bottom. July 8, 2006 Ran in the hole and wash and ream to bottom. Tagged fill at 8101' (21' of fill). Circulate and condition the mud. Wiper Gas = 435 units. Pump a carbide lag (73 bbls over). Circulate and condition the hole. Pull out of the hole to the shoe and monitor the well. Pull out of the hole and lay down the BHA and drill bit. Rig up and run electric logs. July 9, 2006 Finished running wire line logs. Unload source material from down hole and rig down Schlumbergers logging tools. Pick up BHA and make up bit and new BHA. Change out jars and run in the hole with the HWDP. Run into the hole to the shoe (2618') and tube the rig. Run into the hole to 4411' and hit a bridge. Temporally detained with no rotation =jar loose and worked free. Ream the hole from 4401' to 4462'. Run in the hole from 4462' to 5477'. Temporally detained at 5477' and worked free. Reamed the hole from 5447' to 5693' and ran in the hole from 5693' to 5939' and reamed the hole from 5939' to 7000'. July 10, 2006 Reamed the hole to 7100' and circulate and conditioned the mud through bottoms up. • Pulled out of the hole and laid down the stabs and broke off the bit. Tested the BOP equipment and made up and ran in the hole the BHA and new bit (#5). Reamed the hole from 7100' to 7365' and received a maximum gas of 154 units. July 11, 2006 Reamed the hole to 8122' and drilled formation to 8155'. Circulated and conditioned the hole and pulled a wiper trip to 7000'. Wiper Gas = 216 units. Circulated and conditioned the hole on bottom and pumped a carbide flag = 92 bbls/over. Circulate and pump ahigh-vis sweep and pull out of the hole laying down drill pipe. July 12, 2006 Finish laying down pipe and BHA and nipple up to test BOPE. Test BOPE and rig up to run casing. Run 7" casing to 8130' and cement. • ~~ EPOCH ~$ • • ~ 4.2. SURVEY RECORD Measured Depth Inclination Azimuth TVD Vertical Section +NS- +EW- Drilled Distance Course Len th DLS ft de de ft ft ft ft ft ft de 1100 ft 100 0.13 269.43 100.00 0 0 0.11 W 100 100 0.13 200 0.24 309.56 200.00 0.13 0.13N 0.39W 200 100 0.16 300 0.45 313.76 300.00 0.54 0.54N 0.83W 300 100 0.21 362 0.25 299.26 362.00 0.77 0.77N 1.13W 362 62 0.77 400 0.38 317.26 400.00 0.90 0.90N 1.29W 400 38 0.43 500 1.51 14.90 499.98 2.42 2.42N 1.17W 500 100 1.35 536 2.66 24.42 535.96 3.64 3.64N 0.70W 536 36 3.33 600 4.98 27.10 599.81 7.47 7.47N 1.18E 600 64 3.63 654 6.97 30.07 653.52 12.39 12.39N 3.89E 654 54 3.73 700 8.10 28.73 699.12 17.65 17.65N 6.84E 700 46 2.49 750 8.29 29.68 748.61 23.87 23.87N 10.32E 750 50 0.47 800 9.17 27.35 798.03 30.54 30.54N 13.93E 800 50 1.90 850 10.35 23.39 847.30 38.20 38.20N 17.55E 850 50 2.71 900 11.46 19.19 896.40 47.01 47.01 N 20.96E 900 50 2.73 950 13.20 10.80 945.25 57.31 57.31 N 23.67E 950 50 4.99 1000 13.77 6.95 993.87 68.83 68.83N 25.46E 1000 50 2.13 1050 13.86 4.10 1042.43 80.71 80.71 N 26.61E 1050 50 1.37 1100 14.01 2.50 1090.95 92.73 92.73N 27.30E 1100 50 0.83 1150 13.94 358.58 1139.48 104.80 104.80N 27.41E 1150 50 1.90 1200 14.70 354.93 1187.92 117.14 117.14N 26.70E 1200 50 2.36 1250 16.07 354.45 1236.13 130.34 130.34N 25.47E 1250 50 2.75 1300 17.99 354.88 1283.93 144.92 144.92N 24.11E 1300 50 3.85 1360 18.14 354.46 1340.98 163.45 163.45N 22.39E 1360 60 0.33 1392 18.40 355.00 1371.36 173.44 173.44N 21.46E 1392 32 0.97 1453 18.00 355.50 1429.31 192.42 192.42N 19.89E 1453 61 0.70 1513 17.90 354.60 1486.39 210.85 210.85N 18.29E 1513 60 0.49 1575 18.10 354.30 1545.36 229.91 229.91 N 16.44E 1575 62 0.36 1637 17.60 354.60 1604.37 248.83 248.83N 14.60E 1637 62 0.82 1697 17.70 354.20 1661.55 266.94 266.94N 12.82E 1697 60 0.26 ~~ EPOCH • Chevron • • Union Oil Company of California - SCU-42-05x Measured Depth Inclination Azimuth TVD Vertical Section NS EW DRILLED DISTANCE Course Len th DLS ft) de de (ft) (ft) ft ft (ft (ft) de 1100ft) 1760 17.80 354.50 1721.55 286.05 286.05N 10.93E 1760 63 0.22 1820 17.60 353.90 1778.71 304.20 304.20N 9.09E 1820 60 0.45 1881 17.50 354.10 1836.87 322.49 322.49N 7.17E 1881 61 0.19 1943 17.40 354.40 1896.02 340.99 340.99N 5.30E 1943 62 0.22 2004 17.50 353.90 1954.21 359.19 359.19N 3.44E 2004 61 0.30 2067 17.80 355.70 2014.24 378.21 378.21 N 1.71E 2067 63 0.99 2128 17.90 358.20 2072.31 396.87 396.87N 0.72E 2128 61 1.27 2190 18.00 357.70 2131.29 415.97 415.97N 0.03E 2190 62 0.30 2251 17.70 358.30 2189.35 434.66 434.66N 0.62W 2251 61 0.58 2314 18.30 359.60 2249.27 454.12 454.12N 0.97W 2314 63 1.15 2375 18.80 1.40 2307.10 473.52 473.52N 0.80W 2375 61 1.25 2438 18.70 1.70 2366.76 493.77 493.77N 0.25W 2348 63 0.22 2499 18.80 0.90 2424.52 513.37 513.37N 0.19E 2499 61 0.45 2560 19.00 1.10 2482.23 533.12 533.12N 0.54E 2560 61 0.34 2684 16.60 358.80 2600.16 571.43 571.43N 0.93E 2684 62 2.81 2745 16.50 358.60 2658.63 588.80 588.80N 0.52E 2745 61 0.19 2806 14.60 358.80 2717.39 605.15 605.15N 0.15E 2806 61 3.12 2866 13.40 359.00 2775.61 619.66 619.66N 0.13W 2866 60 2.00 2929 11.50 359.10 2837.13 633.24 633.24N 0.36W 2929 63 3.02 2989 10.70 0.30 2896.00 644.79 644.79N 0.42W 2989 60 1.39 3051 10.70 1.70 2956.92 656.30 656.30N 0.22W 3051 62 0.42 3113 9.20 356.50 3017.99 667.00 667.OON 0.35W 3113 62 2.82 3175 8.50 353.40 3079.25 676.50 676.50N 1.18W 3175 62 1.37 3236 8.70 352.20 3139.57 685.55 685.55N 2.32W 3236 61 0.44 3298 8.80 351.10 3200.85 694.88 694.88N 3.69W 3298 62 0.31 3360 8.00 357.40 3262.18 703.88 703.88N 4.62W 3360 62 1.97 3421 7.10 3.80 3322.65 711.88 711.88N 4.57W 3421 61 2.02 3483 5.70 3.20 3384.27 718.78 718.78N 4.14W 3483 62 2.26 3606 3.10 2.50 3506.89 728.20 728.20N 3.65W 3606 123 2.11 3667 1.40 6.00 3567.84 730.59 730.59N 3.50W 3667 61 2.79 ~~ EPOCH 20 • Ch~vran • • Union Oil Company of California - SCU-42-05x Measured Depth Inclination Azimuth TVD Vertical Section NS EW DRILLED DISTANCE Course Length DLS ft de de ft ft ft ft ft de de 1100 ft 3729 0.50 2.30 3629.83 731.61 731.61 N 3.41 W 3729 62 1.45 3853 0.30 203.90 3753.83 731.86 731.86N 3.52W 3853 124 0.63 3976 0.40 176.70 3876.83 731.13 731.13N 3.63W 3976 123 0.16 4099 0.30 210.10 3999.83 730.43 730.43N 3.77W 4099 123 0.18 4221 0.50 255.00 4121.83 730.01 730.01 N 4.44W 4221 122 0.29 4347 0.40 246.50 4247.82 729.70 729.70N 5.38W 4347 126 0.10 4471 0.50 233.70 4371.82 729.20 729.20N 6.21 W 4471 124 0.11 4593 0.50 215.60 4493.81 728.45 728.45N 6.95W 4593 122 0.13 4716 0.50 211.90 4616.81 727.56 727.56N 7.54W 4716 123 0.03 4836 0.60 211.10 4736.80 726.58 726.58N 8.14W 4836 120 0.08 4953 0.50 232.40 4853.80 725.74 725.74N 8.87W 4953 117 0.19 5076 0.20 255.90 4976.80 725.36 725.36N 9.50W 5076 123 0.27 5197 0.20 303.50 5097.79 725.43 725.43N 9.88W 5197 121 0.13 5312 0.30 56.30 5212.79 725.71 725.71 N 9.80W 5312 115 0.37 5443 0.40 32.90 5343.79 726.28 726.28N 9.26W 5443 131 0.13 5573 0.70 58.50 5473.79 727.08 727.08N 8.34W 5573 130 0.29 5698 0.90 52.60 5598.77 728.07 728.07N 6.91 W 5698 125 0.17 5822 1.30 61.20 5722.75 729.34 729.34N 4.90W 5822 124 0.35 5945 1.40 68.30 5845.72 730.57 730.57N 2.28W 5945 123 0.16 6068 1.50 54.60 5968.68 732.06 732.06N 0.42E 6068 123 0.29 6192 1.40 79.80 6092.64 733.27 733.27N 3.24E 6192 124 0.52 6315 1.30 106.60 6215.61 733.13 733.13N 6.05E 6315 123 0.51 6376 1.10 123.40 6276.59 732.61 732.61 N 7.21E 6376 61 0.66 6499 1.30 105.20 6399.57 731.60 731.60N 9.54E 6499 123 0.35 6622 0.80 97.30 6522.54 731.12 731.12N 11.74E 6622 123 0.42 6684 0.90 16.50 6584.54 731.53 731.53N 12.30E 6684 62 1.78 6806 1.30 356.30 6706.52 733.83 733.83N 12.49E 6806 122 0.45 6929 1.40 0.80 6829.48 736.73 736.73N 12.42 6929 123 0.12 7054 1.40 358.10 6954.45 739.78 739.78N 12.39 7054 125 0.05 7177 1.60 10.40 7077.40 742.97 742.97N 12.65 7177 123 0.31 ~~ EPOCH 21 i thn • • i `~"' Union Oil Company of California - SCU-42-05x Measured De th Inclination Azimuth TVD Vertical Section NS EW DRILLED DISTANCE Course Len th DLS ft de de ft ft ft ft ft de de /100 ft 7302 1.40 19.00 7202.36 746.13 746.13N 13.46E 7302 125 0.24 7420 1.60 17.80 7320.32 749.06 749.06N 14.43E 7420 118 0.17 7544 1.90 21.70 7444.26 752.62 752.62N 15.72 7544 124 0.26 7669 1.90 31.30 7569.19 756.32 756.32N 17.57 7669 125 0.25 7795 1.90 39.20 7695.13 759.72 759.72N 19.97 7795 126 0.21 7913 1.80 41.20 7813.06 762.79 762.79N 22.37 7913 118 0.10 7973 2.10 48.40 7873.03 764.23 764.23N 23.82 7973 60 0.64 8036 2.10 43.20 7935.98 765.83 765.83N 25.47 8036 63 0.30 8074 2.00 44.60 7973.96 766.81 766.81 N 26.41 8074 38 0.30 8155 2.00 44.60 8054.93 768.01 768.01 27.59 8122 48 0.02 EPOCH 22 i Chevron 4.3. MUD RECORD Contractor: MI Drilling Fluids Mud Tvne: Snud Mud. Gel/Water • Union Oil Company of California - SCU-42-05x • DATE DEPTH MW VIS PV YP GELS API FL CAKE API SOLIDS OILIWATE SAND MBT pH CI" Ca 6/23/06 460 8.9 64 16 34 16/25/0 7.2 2/0 4.2 0/95.5 0.25 12.5 10.5 1600 80 6/24/06 2260 9.1 55 13 37 19/26/0 6.0 2/0 5.7 0/94.0 2.00 10.0 9.8 1200 80 6/25/06 2635 9.2 49 17 23 11/16/0 6.0 2/0 6.2 0/93.5 0 10.0 9.4 1100 80 6/26/06 2635 9.2 52 20 25 10/15/0 0 2/0 4.7 0/95.0 0 10.0 8.8 900 80 6/27/06 BUILD NEW MUD 6/28/06 2645 9.0 49 11 18 7/10/0 4.5 1/0 1.6 0/96.0 0 0 10.8 29000 160 6/29/06 4218 9.7 47 14 18 6/8/0 4.4 1 /0 4.8 0/93.0 0 3.0 9.60 27000 200 6/30/06 4218 9.7 43 11 18 5/8/0 4.4 1/0 4.8 0/93.0 0 3.0 9.50 27000 120 7/1/06 5681 11.5 46 25 22 6/15/0 4.0 1/0 10.8 0/87.0 0 7.0 8.4 29000 400 7/2/06 6377 12.5 49 32 21 5/14/0 4.2 1/0 15.9 0/82.0 0 7.5 9.1 30000 200 7/3/06 6475 12.4 46 28 19 3/8/0 4.0 1 /0 16.0 0/82.0 0 7.0 8.7 28000 320 7/4/06 6783 12.4 48 28 14 3/9/14 3.8 1/0 15.6 0/82.0 0 7.5 9.9 34000 320 7/5/06 7213 12.4 51 30 15 3/14/20 3.8 1 /0 15.6 0.5/81.5 0 7.5 9.0 34000 400 7/6/06 8007 12.4 53 42 18 3/11/19 3.4 1/0 15.6 0.5/81.5 0 7.5 8.8 34000 400 7/7/06 8122 12.4 51 33 14 3/8/13 3.4 1/0 15.6 0.5/81.5 0 7.5 8.8 34000 400 7/8/09 8122 12.4 54 36 20 4/11/18 3.4 0/0 15.6 0.5/81.5 0 7.5 8.8 34000 400 7/9/06 8122 12.4 56 38 16 3/14/22 3.4 1/0 15.6 0.5/81.5 0 7.5 8.8 34000 400 7/10/06 8122 12.4 51 24 16 2/6/10 3.6 1/0 15.9 0.5/81.5 0 7.5 8.6 30000 400 7/11/06 8155 12.5 55 37 18 4/0/0 3.6 1/0 15.6 0.5/81.5 0 7.5 8.8 34000 400 7/12/06 8155 12.5 50 28 14 4/12/21 3.6 1/0 0 0.5/81.5 0 7.5 9.3 34000 380 EPOCH 23 • Chevron • • Union Oil Company of California - SCU-42-05x 4.4. BIT RECORD BIT NO SIZE MAKE TYPE S/N JETS/TFA IN OUT FEET HOURS ROP WOB CONDITION 1 12.25 SEC EBXSC1S 10886676 4X15 96' 2635' 2539' 28.0 156 9.4 2-2-WT-A-E-1/16-CT-TD 2 8.5 SEC FS2653 10414701 3X13, 1X18 2635' 6475' 3840' 42:2 161 7.4 6-6-RO-A-X-I-BT-PR 3 8.5 SEC FM2661 10586239 5X13, 2X15 6475' 8122' 1647' 53:3 58.1 13.4 8-4-WT-A-X-I-BT-PR 4 8.5 HTC MXC1 6018848 3X16, 1X10 8122' 8122' 0 0 0 0 Ream hole to 7700' 5 8.5 HTC MXL-1 5084243 2X16, 36, 8122' 8155' 33' 2.2 26.4 10.9 0-0-NO-NA-E-1-NA-TD EPOCH 24 +Chevron • • Union Oil Company of California -SCU-42-05x 4.5. DAYS VS. DEPTH '~ UNION OIL COMPANY OF CALIFORNIA -SCU 42-05X ~ EPOCH DAYS VS. DEPTH 0 -1000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 ~ry~`~ ~~~ ~ry~O6 ~ry~~ 6~ry~~ ~ry~~ ~ry~`O6 ~ry~~ ~ry9`o6 ~~`ob 1~~`O6 1`~O6 ~`~06 ~`~06 1`~O6 1`~O6 1`06 ~`~ob ~`~`061~~~`061~^~`~1~~~061~~~06 DATE ~~ EPOCH 25 UNION/CHEVRON DAILY WELLSIT E ~~~~~ REPORT • SCU-42-05X REPORT FOR LAWRENCE/HARNESS DATE Jul 13, 2006 DEPTH 8155.00000 PRESENT OPERATION RUNNING CASING TIME 00:01:00 YESTERDAY 8155.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 2618' DEPTH INCLINATION AZIMUT H VERTICAL DEPTH SURVEY DATA 8155' 8054.91' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5" HTC MXL-1 5084243 2X16,36,10 8122 8155 33 6:37 0/O-E-NA TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS RY RPM '' @ @ RPM ~ P PRESSURE @ @ 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 17 8 @ RUN CSG 5 @ RUN CSG 25 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 15 PENTANE (C-5) @ @ H ROCARBON SHOWS ~ RVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish laying down drill pipe and rig up casing crew. Begin to run casing to bottom. EPOCH PERSONNEL ON BOARD Browne, Lundy DAILY COST $2870 REPORT BY LEES F BROWNE JR. C] • • UNION/CHEVRON DAILY WELLSITE REPORT EI~Q~H SCU-42-05X .cF'ORT FOR Lawrence/Harness DATE Jut 12, 2006 DEPTH 8154.00000 PRESENT OPERATION Lay Down Drill Pipe TIME 00:01:00 YESTERDAY 8122.0!0000 24 HOUR FOOTAGE 32' CASING INFORMATION 9.625" @ 2618' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8155' 8054.91' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5" HTC MXL-1 5084243 2X16, 36, 10 8122 8155 33 2.2 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 98.3 @ 8130.00000 4.1 @ 8149.00000 25.7 38.97000 FT/HR SURFACE TORQUE 13 @ 8146.00000 11 @ 8149.00000 10.0 12.55000 AMPS WEIGHT ON BIT 19 @ 8144.00000 5 @ 8153.00000 11.0 6.36000 KLBS ROTARY RPM 109 @ 8149.00000 56 @ .8122.00000 81.0 92.98000 RPM PUMP PRESSURE 3416 @ 8122.00000 2140 @ 8153.00000 1761.0 2145.91992 PSI ING MUD REPORT DEPTH 8155' MW 12.5 VIS 55 PV 37 YP 18 FL 3.6 Gels 4/0/0 CL- 34000 FC 1/0 SOL 15.6 SD 0 OIL 0.5/81.5 MBL 7.5 pH 8.8 Ca+ 400 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY HIGH LOW AVERAGE (units) DITCH GAS 185 @ 8152.00000 30 @ $154.00000 62.3 TRIP GAS 375 @ 8122 CUTTING GAS 0 @ 8154.00000 0 @ 8154.00000 0.0 WIPER GAS 234 reaming CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 35285 @ 8152.00000 5759 @ 8154.00000 11591.9 C ONNECTION GAS HIGH ETHANE (C-2) 38 @ 8152.00000 0 @ 8133.00000 4.9 AVG PROPANE (C-3) 14 @ $152.00000 0 @ 8141.00000 1.5 CURRENT BUTANE (C-4) 0 @ 8154.00000 0 @ 8154.00000 0.0 CURRENT 2 BACKGROUND/AVG P TANE (C-5) 0 @ 8154.00000 0 @ 8154.00000 0.0 OCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SAND STONE, SAND, ASH, SILT PRESENT LITHOLOGY 8155' = 40% SAND, 30% TUFFACEOUS SANDSTONE, 20% SILT, 10% ASH DAILY ACTIVITY Ream hole to 8122' and drill formation to 8155'. Condition mud and circulate hole. Short trip to SUMMARY 7000 WG = 216 units. Circulate and condition mud on bottom. Pump carbide flag.Circulate and condition mud Pump Hi-Vis Sweeps. Pull out of the hole and lay down drill pipe •H PERSONNEL ON BOARD Browne, Lundy DAILY COST $2870 REPORT BY LEES F. BROWNE JR. • • UNION/CHEVRON DAILY WELLSITE REPORT EPOCH SCU-42-05X ~.~ORT FOR LUCAS/HARNESS DATE Jul 11, 2006 DEPTH 8122.00000 PRESENT OPERATION REAM HOLE @ 7350' TIME 00:01:00 YESTERDAY 8122.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 2618' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8122' 2.00 44.60 8021.93' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" HTC MXC1 6018848 3X16, 10 8122 8122 0 REAMING 5 8.5" HTC MXL-1 5084243 2X16,36, 10 8122 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM ~" PRESSURE @ @ PSI ~ LING MUD REPORT DEPTH 8122' MW 12.4 VIS 56 PV 38 YP 16 FL 3.4 Gels 3/14/22 CL- 34000 FC 1/0 SOL 15.6 SD 0 OIL 0.5 MBL 7.5 pH 8.8 Ca+ 400 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 154 @ REAM 5 @ REAM 25 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 31 PENTANE (C-5) @ @ HYDROCARBON SHOWS IN RVAL LITHOLOGY/REMARKS GAS DESCRIPTION OLOGY PRESENT LITHOLOGY DAILY Ream hole to 7100' and circulate and condition the hole. Pull out of the hole and lay down stabs ACTIVITY and break the bit. Test BOP equipment and make up and run in the hole with BHA and new bit to SUMMARY 7100'. Ream hiole from 7100' to 7365' Maximum gas to 7365' (tripping into the hole) is 154 units. EPOCH PERSONNEL ON BOARD Browne, Lundy DAILY COST $2670 • REPORT BY LEES F. BROWNE JR. U UNION/CHEVRON DAILY WELLSITE REPORT EI'O~H SCU-42-05X ~L~PORT FOR LUCAS/LAZENBI' DATE Jul 10, 2006 DEPTH 8122.00000 PRESENT OPERATION rEAMING HOLE TO BOTTOM TIME 00:01:00 YESTERDAY 8122.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 2618' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8122' 2.00 44.60 8021.93' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" HTC MXC1 6018848 3X16, 10 8122'. 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 ~ING MUD REPORT DEPTH 8122' W 12.4+ 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 182 (REAMING) @ 7000' 5 @ REAM 15 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 10 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LOGY r ENT LITHOLOGY Finish wire line logging. Unload source material and lay down logging tools. Rig down Schlumberger and pick up BHA. Make up bit and BHA. Change out jars and run in the hole with HWDP. Run in the DAILY hole to the shoe (2618') and lube the rig. Run in the hole to 4411' and hit a bridge. Temporally ACTIVITY SUMMARY EPOCH PERSONNEL ON BOARD Browne, Lundy REPORT BY LEES F. BROWNE JR. • detained with no rotation =jar loose and work free. Ream hole from 4401' to 4462'. Run in the hole from 4462' to 5477'. Temporally detained at 5477' and worked free. Ream from 5447' to 5693'. Run in the hole from 5693' to 5939', Ream from 5939' to 7000'. Maximum gas readings to 7000' was 183 units DAILY COST $2670 r: UNION/CHEVRON DAILY WELLSITE REPORT EPQC~I SCU-42-05X r PORT FOR LUCAS/LAZENBY DATE Jul 09, 2006 DEPTH 8122.00000 PRESENT OPERATION E-LOGGING TIME 00:01:00 YESTERDAY 8122.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 2618' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8122' 2.00 44'.60 8021.93' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" SEC FM2661 10586239 5X13, 2X15 6475 8122 1647 54:34 8/4-X-BT 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 LLING 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 HIGH LOW AVERAGE (units) DITCH GAS 435 @ 8122 25 @ 8122 35 (WIPER) TRIP GAS CUTTING GAS @ @ WIPER GAS 435 @ 8122 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 ,PROPANE (C-3) @ @ CURRENT 0 II BUTANE (C-4) @ p~ CURRENT 0 BACKGROUND/AVG P NTANE (C-5) @ @ ROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY Run in the hole and wash and ream. Tag fill at 8101' (21' of fill). circulate and condition mud WG = ACTIVITY 435 units. pump carbide flag (est.73 bbls/over) circulate and condition hole. Pull out of the hole to SUMMARY the shoe and monitor the well, pull out of the hole and lay down BHA & bit. Rig up wire line logs and begin to log at 19:30 hours -~- ~ LOCH PERSONNEL ON BOARD Browne, Lundy DAILY COST $2670 REPORT BY Lees F. Browne Jr. • • UNION/CHEVRON DAILY WELLSITE REPORT EPQCH • SCU-42-05X rcEPORT FOR LUCAS/LAZENBY DATE Jul 08, 2006 DEPTH 8122.00000 PRESENT OPERATION WIPER TRIP @ TD TIME 00:01:00 YESTERDAY 8002.00000 24 HOUR FOOTAGE 120' CASING INFORMATION 9.625" @ 2618' DEPTH INCLINATION. AZIMUTH VERTICAL DEPTH SURVEY DATA 8122' 2.00 44.60 8021.93' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" SEC FM2661 10586239 5X13, 2X15 6475 8122 1647' 54:34 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 61.5 @ 8084.00000 4.0 @ 8022.00000 19.6 13.37000 FT/HR SURFACE TORQUE 15 @ 8101.00000 11 @ 8012.00000 13.5 12.54000 AMPS WEIGHT ON BIT 17 @ 8029.00000 11 @ 8122.00000 14.9 11.30000 KLBS ROTARY RPM 66 @ 8032.00000 46 @ 8099.00000 58.9 56.96000 RPM PUMP PRESSURE 3601 @ 8048.00000 3115 @ 8117.00000 3403.9 3416.52002 PSI ING MUD REPORT DEPTH 8122' MW 12.4 VIS 54 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 162 @ 8002.00000 22 @ 8019.00000 46.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 31171 @ 8002.00000 4291 @ 8019.00000 8942.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 20 @ 8116.00000 0 @ 8068.00000 2.8 AVG 0 PROPANE (C-3) 0 @ 8122.00000 0 @ 8122.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 8122.00000 0 @ 8122.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 8122.00000 0 @ 8122.00000 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, COAL, CARBONACEOUS SHALE, SAND PRESENT 8122' = 40% TUFFACEOUS SANDSTONE, 10% SAND, 30% SILT, 20% ASH LITHOLOGY DAILY Drill formation to 8122', condition and circulate the hole three times bottoms up, pulled 5 stands ACTIVITY out, pumped ten stands out to 6900' differentialy sticking, pump out of the hole from 6500 to 5900' SUMMARY tight @ 6408', pull out of the hole to 2578', cut drilling line and tube the rig and begin to run in the hole to TD 8122' ~CH PERSONNEL ON BOARD Browne, Lundy DAILY COST $2670 REPORT BY LEES F. BROWNE JR. • • UNION/CHEVRON DAILY WELLSITE REPORT EPQ~H •SCU-42-05X REPORT FOR DATE Jul 07, 2006 DEPTH 8002.00000 PRESENT OPERATION DRILLING TIME 00:01:00 YESTERDAY 7460.00000 24 HOUR FOOTAGE 542' CASING INFORMATION 9.625" @ 2618' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7795' 1.90 39.20 7695.13' SURVEY DATA 7669' 1.90 31.30 7569.19' 7544' 1.90 21.70 7444.26' 7420' 1.60 17.80 7320.32' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" SEC FM2661 10586239 5X13, 2X15 6475 44:49 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATI ON 190.0 @ 7574.00000 2.0 @ 7984.00000 44.5 8.8$000 FT/HR SURFACE TORQUE 20 @ 7951.00000 7 @ 7578.00000 13.7 0.00000 AMPS ~~~HT ON BIT 18 @ 7845.00000 0 @ 7654.00000 13.9 14.00000 KLBS RY RPM 75 @ 7901.00000 7 @ 7578.00000 60.0 0.00000 RPM PUMP PRESSURE 3670 @ 7871.00000 956 @ 7984.00000 3365.1 0.00000 PSI DRILLING MUD REPORT DEPTH 8000' MW 12.4 VIS 54 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 608 @ 7613.00000 20 @ 7565.00000 91.1 TRIP GAS CUTTING GAS 0 @ 8002.00000 0 @ 8002.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 111299 @ 7613.00000 3931 @ 7565.00000 17828.5 .CONNECTION GAS HIGH 0 ETHANE (C-2) 236 @ 7613.00000 0 @ 7573.00000 23.3 AVG 0 PROPANE (C-3) 59 @ 7883.00000 0 @ 7503.00000 6.9 CURRENT 0 BUTANE (C-4) 0 @ 8002.00000 0 @ 8002.00000 0.0 CURRENT 34 BACKGROUND/AVG ANE (C-5) 0 @ 8002.00000 0 @ 8002.00000 0.0 HYDROCARBON STORAGE ZONE SHOWS INTERVAL LIT HOLOGY/REMARKS GAS DESCRIPTION 7869' TO 7901' 32' SA ND AND TUFFACEOUS BEFORE 38 FINE LOWER TO FINE UPPER SOME TOTAL SANDSTONE WITH INTBD MAX 319 MEDIUM LOWER; ASH AND SILT SILTS AND CLAYS AFTER 65 SUPPORTED VERY HYDROPHILIC; NOT A REAL CLEAN SAND; POOR TO MODERATE ROP THROUGH ZONE LOGY ASH, SILT, CLAY, SAND, SANDSTONE, COAL, CARBONACEOUS SHALE PRESENT LITHOLOGY 8000' = 50% SILT, 30% SAND, CLAY 10%, TUFFACEOUS SANDSTONE 10% DAILY ACTIVITY Drill formation to 7572', change out swab in #2 mud pump, drill formation to 7984' circulate SUMMARY and change out swab and liner in #2 mud pump, drill formation. EPOCH PERSONNEL ON BOARD Browne, Lundy, Bietting, Ferguson DAILY COST $3350 REPORT BY LEES F. BROWNE JR. • • UNION/CHEVRON DAILY WELLSITE REPORT EPUCH • SCU-42-05X REPORT FOR DATE Jul 06, 2006 DEPTH 7460.00000 PRESENT OPERATION DRILLING TIME 00:01:00 YESTERDAY 6831.00000 24 HOUR FOOTAGE 629' CASING INFORMATION 9.625" @ 2618' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7302' 1.40 19.00 7202.36' SURVEY DATA 7177' 1.60 10.40 7077.40' 7054' 1.40 358.10 6954.45' 6929' 1.40 0.80 6829.48' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 SEC FM2661 10586239 5X13, 2X15 6475 25:36 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 284.7 @ 6987.00000 6.7 @ 7379.00000 83.3 23.00000 FT/HR SURFACE TORQUE 26 @ 7353.00000 10 @ 6969.00000 13.3 0.00000 AMPS ~GHT ON BIT 17 @ 7168.00000 2 @ 7101.00000 13.1 12.00000 KLBS ARY RPM 76 @ 7282.00000 52 @ 7058.00000 61.3 0.00000 RPM PUMP PRESSURE 3619 @ 7058.00000 2897 @ 6915.00000 3303.1 0.00000 PSI DRILLING MUD REPORT DEPTH 7460' MW 12.4 VIS 51 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 549 @ 6914.00000 22 @ 7448.00000 83.5 TRIP GAS CUTTING GAS 0 @ 7460.00000 0 @ 7460.00000 0.0 WIPER GAS 208 @ 7399 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 106078 @ 7217.00000 4449 @ 7448.00000 16123.9 CONNECTION GAS HIGH 0 ETHANE (C-2) 192 @ 6914.00000 0 @ 6945.00000 5.8 AVG 0 PROPANE (C-3) 24 @ 6914.00000 0 @ 7174.00000 1.4 CURRENT 0 p NE (C-4) 0 @ 7460.00000 0 @ 7460.00000 0.0 CURRENT 50 BACKGROUND/AVG h-t TANE (C-5) 0 @ 7460.00000 0 @ 7460.00000 0.0 HYDROCARBON SHOWS NO SHOWS COAL GAS ONLY INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SANDSTONE, TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, COAL, CARBONACEOUS SHALE PRESENT 7450' = 50% ASH, 50% TUFFACEOUS SILTSTONE LITHOLOGY ACTIVITY Drill formation to 7399', replace top drive swivel, monitor the well for ten minutes, wiper trip SUMMARY to 6430', trip in the hole to bottom, 19' of fill, drill formation. EPOCH PERSONNEL ON BOARD Browne, Lundy, Bietting, Furguson DAILY COST $3350 REPORT BY LEES F. BROWNE JR. • • UNION/CHEVRON DAILY WELLSITE REPORT EI'~CH SCU-42-05X ,.CF'ORT FOR LUCAS/LAZENBY DATE Jul 05, 2006 DEPTH 6831.00000 PRESENT OPERATION DRILLING TIME 00:01:00 YESTERDAY 6475.00000 24 HOUR FOOTAGE 356' CASING INFORMATION 9.625" @ 2618' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6831' 6731 (proj) SURVEY DATA 6622' 0.80 97.30 6522.54' 6499' 1.30 105.20 6399.57' 6376' 1.10 123.40 6276.59' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 SEC FM2661 10586239 5X13, 2X15 6475 11:54 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 163.8 @ 6477.00000 3.6 @ 6560.00000 47.2 34.34000 FT/HR SURFACE TORQUE 15 @ 6831.00000 0 @ 6624.00000 9.2 15.57000 AMPS W~HT ON BIT 25 @ 6684.00000 1 @ 6617.00000 12.5 12.00000 KLBS RY RPM 90 @ 6544.00000 0 @ 6559.00000 52.3 58.19000 RPM PUMP PRESSURE 3369 @ 6735.00000 2623 @ 6475.00000 3027.8 3358.37988 PSI DRILLING MUD REPORT DEPTH 6831' MW 12.4 VIS 36 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 653 @ 6818.00000 14 @ 6619.00000 70.9 TRIP GAS 142 @6475 CUTTING GAS 0 @ 6831.00000 0 @ 6831.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 116642 @ 6817.00000 2745 @ 6619.00000 13328.9 CONNECTION GAS HIGH 0 ETHANE (C-2) 179 @ 6818.00000 0 @ 6611.00000 5.8 AVG 0 PROPANE (C-3) 61 @ 6818.00000 0 @ 6806.00000 1.5 CURRENT 0 R' NE (C-4) 0 @ 6831.00000 0 @ 6831.00000 0.0 CURRENT 125 BACKGROUND/AVG rt TANE (C-5) 0 @ 6831.00000 0 @ 6831.00000 0.0 HYDROCARBON SHOWS NO SHOWS. COAL GAS KICKS ONLY INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY COAL, CARBONACEOUS SHALE, CCARBONACEOUS CLAY, CLAY, SILT PRESENT 6810' = 50% TUFFACEOUS,CLAY, 50% TUFFACEOUS SILT (SCATTERED THIN LITHOLOGY COAL) D~ ACTIVITY L ARY Finish working on IBOP and trip in the hole to bottom and drill formation. Trip Gas = 142 units. Drill formation and work stuck pipe half hour at 6588', drill ahead. EPOCH PERSONNEL ON BOARD Browne, Lundy, Bietting, Ferguson DAILY COST $3350 REPORT BY LEES F. BROWNE JR. • C UNION/CHEVRON DAILY WELLSITE REPORT EPtJ~H SCU-42-05X ,.~ ORT FOR LUCAS/LAZENBY DATE Jul 04, 2006 DEPTH 6475.00000 PRESENT OPERATION TRIP FOR BIT TIME 01:38:25 YESTERDAY 6436.00000 24 HOUR FOOTAGE 39' CASING INFORMATION 9.625" @ 2618' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6475' 6375.55' (proj) ,BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5 SEC FS2653 10414701 3X13, 1X18 2635 6475 3840 42:21 6/6-X-BT PR 3 8.5 SEC FM2661 10586239 5X13, 2X15 6475 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 122.3 @ 6436.00000 7.1 @ 6463.00000 57.9 11.94000 FT/HR SURFACE TORQUE 18 @ 6444.00000 10 @ 6472.00000 12.7 10.69000 AMPS WEIGHT ON BIT 16 @ 6436.00000 9 @ 6437.00000 11.6 11.79000 KLBS ROTARY RPM 89 @ 6475.00000 74 @ 6459.00000 79.0 89.35000 RPM ~" PRESSURE 2920 @ 6436.00000 2465 @ 6470.00000 2665.4 2623.78003 PSI ~ LING MUD REPORT DEPTH 6475' MW 12.4 VIS 46 PV 28 YP 19 FL 4.0 Gels 3/8/0 CL- 28000 FC 1/0 SOL 16.0 SD 0 OIL 0 MBL 7.0 pH 8.7 Ca+ 320 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 122 @ 6475.00000 30 @ 6468.00000 62.3 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 23223 @ 6475.00000 5804 @ 6468.00000 12111.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 12 @ 6475.00000 0 @ 6461.00000 1.6 AVG 0 PROPANE (C-3) 0 @ 6475.00000 0 @ 6475.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 6475.00000 0 @ 6475.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 6475.00000 0 @ 6475.00000 0.0 HYDROCARBON SHOWS NO SHOWS IN VAL LITHOLOGY/REMARKS GAS DESCRIPTION ... ~ LOGY SAND, CONGLOMERATE SAND, ASH, SILT, CLAY, CARBON SHALE, COAL PRESENT 6475' = 30% COAL, 20% CARBON SHALE, 10% CARBON CLAY, 10% TUFFACEOUS LITHOLOGY SILT, 30% TUFFACEOUS CLAY. DAILY ACTIVITY Drill formation to 6475'. Condition the mud and monitor the well, pull 5 stands and pump a dry SUMMARY job. Pull out of the hole working a tight hole, back reaming and pulling 20-25K over pulls. Pull out of the hole and change bits. Run in the hole with drill collars and work on the IBOP. E~CH PERSONNEL ON BOARD Browne, Lundy, Bietting, Ferguson DAILY COST $3350 REPORT BY LEES F. BROWNE JR. UNION/CHEVRON DAILY WELLSITE REPORT ET'C.~CH SCU-42-05X ~ . ORT FOR LUCAS/LAZENBY DATE Jul 03, 2006 DEPTH 6436.00000 PRESENT OPERATION DRILLING TIME 00:00:54 YESTERDAY 5718.00000 24 HOUR FOOTAGE 718' CASING INFORMATION 9.625" @ 26.18' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6192 1.40 79.80 6092.64 SURVEY DATA 6068 1.50 54.60 5968.68 5945 1.40 68.30 5845.72 5822 1.30 61.20 5722.75 5698 0.90 52.60 5598.77 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" SEC FS2653 10414701 3X13, 1X18 2635' 41:15 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 251.3 @ 6242.00000 1.9 @ 6378.00000 101.1 122.30000 FT/HR SURFACE TORQUE 21 @ 5877.00000 0 @ 5808.00000 12.3 15.01000 AMPS ~HT ON BIT 33 @ 6320.00000 0 @ 6203.00000 9.3 16.31000 KLBS ROTARY RPM 98 @ 6139.00000 1 @ 5876.00000 74.4 81.76000 RPM PUMP PRESSURE 3029 @ 6012.00000 2177 @ 5931.00000 2762.5 2920.63989 PSI DRILLING MUD REPORT DEPTH 6430' MW 11.5 VIS 46 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 380 @ 5847.00000 2 @ 6322.00000 119.2 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 75411 @ 5847.00000 467 @ 6322.00000 22987.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 37 @ 5847.00000 0 @ 6321.00000 7.0 AVG 0 PROPANE (C-3) 11 @ 5833.00000 0 @ 5721.00000 0.2 CURRENT 0 BUTANE (C-4) 0 @ 6436.00000 0 @ 6436.00000 0.0 CURREN T BACKGROUND/AVG 50 ^r ANE (C-5) 0 @ 6436.00000 0 @ 6436.00000 0.0 r ~ OCARBON SHOWS NO OIL OR GAS SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LiTHOLOGY TUFFACEOUS CLAY, TUFFACEOUS SILT, ASH, SAND, CONGLOMERATE SAND PRESENT LITHOLOGY 6430' = 30% SAND, 30% CLAY, 30% ASH, 10% CONGLOMERATE DAILY ACTIVITY SUMMARY DRILL FORMATION LAST 24 HRS EPOCH PERSONNEL ON BOARD Browne, Lundy, Bietting, Ferguson DAILY COST $3350 • REPORT BY LEES F. BROWNE JR. L~ r~ U UNION/CHEVRON DAILY WELLSITE REPORT El'CJ~H SCU-42-05X c ORT FOR LUCAS/LAZENBY .. DATE Jul 02, 2006 DEPTH 5718.00000 PRESENT OPERATION DRILLING TIME 00:01:00 YESTERDAY 42.18.00000 24 HOUR FOOTAGE 1500' CASING INFORMATION 9 5/8" @ 2618' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5718' 5618' SURVEY DATA 5573' 0.70 58.50 5473.79' 5443' 0.40 32.90 5343.79' 5312' 0.30 56.30 5212.79' 5197' 0.20 303.50 5097.79' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" SEC FS2653 10414701 3X13, 1X18 2635' 23:03 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 332.0 @ 4279.00000 7.7 @ 5299.00000 147.4 92.94000 FT/HR SU$FAGE TORQUE 17 @ 4578.00000 8 @ 4669.00000 12.3 10.85000 AMPS HT ON BIT 18 @ 5648.00000 1 @ 4824.00000 9.5 8.77000 KLBS ROTARY RPM 104 @ 4456.00000 50 @ 5299.00000 81.9 87.85000 RPM PUMP PRESSURE 2838 @ 5072.00000 1183 @ 4225.00000 2351.6 2639.33008 PSI DRILLING MUD REPORT DEPTH 5718' MW 10.5 VIS 42 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 1407 @ 5396.00000 11 @ 5415.00000 144.5 TRIP GAS CUTTING GAS @ @ WIPER GAS 42 $ 1 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 264860 @ 5396.00000 2400 @ 5415.00000 28016.8 CONNEC TION GAS HIGH 0 ETHANE (C-2) 300 @ 5606.00000 0 @ 5484.00000 14.5 AVG 0 PROPANE (C-3) 55 @ 5396.00000 0 @ 4806.00000 2.9 CURRENT- 0 ~NE (C-4) 27 @ 5288.00000 0 @ 5359.00000 0.3 CURRENT 135 BAC KGROUND/AVG PENTANE (C-5) 0 @ 5718.00000 0 @ 5718.00000 0.0 HYDROCARBON SHOWS NO SHOWS COAL GAS KICKS ONLY INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE, TUFFACEOUS SILTSTONE, COAL, CARBONACEOUS SHALE PRESENT 5818' = 40% COAL, 60% CARBONACEOUS SHALE LI~OLOGY ACTIVITY Finish work on pump #1, Trip in the hole and drill (WG = 71 units) drill formation to SUMMARY report time. EPOCH PERSONNEL ON BOARD Browne, Lundy, Bietting, Ferguson DAILY COST $3350 REPORT BY LEES F. BROWNE JR. • UNION/CHEVRON DAILY WELLSITE REPORT ~P(~~K SCU-42-05X ~ EPORT FOR DATE Jul 01, 2006 DEPTH 4218.00000 PRESENT OPERATION WAIT ON RIG REPAIR TIME 00:01:00 YESTERDAY 4218.00000 ' 24 HOUR FOOTAGE 0' 'CASING INFORMATION 9 5/8" @ 2618' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4218' 4118' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" SEC FS2653 10414701 3X13, 1X18 2635' 9:43 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 ~ING MUD REPORT DEPTH 4218' MW 9.7 VIS 43 PV 11 YP 18 FL 4.4 Gels 5/8/0 CL- 27000 FC 1/0 SOL 4.8 SD 0 OIL 0 MBL 3.0 pH 9.5 Ca+ 120 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 MUD CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION ~~LOGY r ENT 421 8' = 40% CONGLOMERATE SAND, 40% TUFFACEOUS CLAYSTONE 20% , LITHOLOGY CONGLOMERATE Pull out of the hole into the shoe (2596'). Repair the rig: work on pump #1, clear space to spot back DAILY up pump, build berm, spot back up pump, undress back up pump, work on pump #1. dress back up ACTIVITY pump with 5" liner, change valve seats, make up kelly hose with- unions f/ shock hose. Rig up pop- SUMMARY off line, rig up suction manifold and line. Dress swabs and install. Clean out rod wash box and check pop-off pin pressure. Work on control lines f/ back up pump. Install isolation valve on back up pump and continue to work on pump #1. ~r~CH PERSONNEL ON BOARD Browne, Lundy, Bietting, Ferguson DAILY COST $3350 REPORT BY LEES F. BROWNE JR. • • UNION/CHEVRON DAILY WELLSITE REPORT E~'QCH SCU-42-05X ,.CF'ORT FOR LUCAS/HARNESS DATE Jun 30, 2006 DEPTH 4218.00000 PRESENT OPERATION POOH TIME 00:01:00 YESTERDAY 2645.00000 24 HOUR FOOTAGE 1573' CASING INFORMATION 9 5/8" @ 2618' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4218 4117.83 (PROJ) SURVEY DATA 3667 1.40 6.00 3567.84 3606 3.10 2.50 3506.89 3483 5.70. 3.20 3384.27 3421 7.10 3.80 3322.65 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" SEC FS2653 10414701 3X13, 1X18 2635' 9:43 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 382.5 @ 3916.00000 17.8 @ 2930.00000 204.5 139.39999 FT/HR SU~FAGE TORQUE 16 @ 4191.00000 0 @ 3740.00000 7.5 9.64000 AMPS HT ON BIT 14 @ 2938.00000 0 @ 3246.00000 4.5 0.00000 KLBS ROTARY RPM 110 @ 2686.00000 0 @ 2918.00000 75.1 78.06000 RPM PUMP PRESSURE 2125 @ 4188.00000 690 @ 4218.00000 1612.3 690.45001 PSI DRILLING MUD REPORT DEPTH 4218' MW 9.7 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 478 @ 2700.00000 0 @ 2646.00000 140.2 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 95555 @ 2700.00000 120 @ 2646.00000 28824.8 CONNECTION GAS HIGH 0 ETHANE (C-2) 14 @ 4217.00000 0 @ 4.181.00000 0.1 AVG 0 PROPANE (C-3) 0 @ 4218.00000 0 @ 4218.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 4218.00000 0 @ 4218.00000 0.0 CURRENT BACKGROUND/AVG 0 "'- ANE (C-5) 0 @ 4218.00000 0 @ 4218.00000 0.0 n OCARBON SHOWS NO SHOWS MINOR GAS KICKS IN DIRTY SANDS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CONGLOMERATE SAND, CONGLOMERATE, SAND, CLAY, SILT PRESENT 4218' = 50% TUFFACEOUS CLAY, 30% CONGLOMERATE SAND, 10% LITHOLOGY CONGLOMERATE, 10% TUFFACEOUS SILTSTONE DAILY ACTIVITY Repair rig install traction motor on,pump #2. Drill and slide formation to 4218'. Circulate out SUMMARY samples and pump a dry job. Monitor the well for 10 minutes and begin to pull out. ~CH PERSONNEL ON BOARD Browne, Lundy, Bietting, Ferguson DAILY COST $3350 REPORT BY LEES F. BROWNE JR. • UNION/CHEVRON DAILY WELLSITE EI'QCH' • REPORT ~ SCU-42-05X REPORT FOR LAWRENCE/LAZENBY DATE Jun 29, 2006 DEPTH 2645.00000 PRESENT OPERATION WAIT ON TRACTION MOTOR TIME 00:01:00 YESTERDAY 2635.00000 24 HOUR FOOTAGE 10' 'CASING INFORMATION 9.625" @ 2618' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2635 18.00 1.10 2553.36' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" SEC FS2653 10414701 3X13, 1X18 2635' 0:04:58 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 212.7 @ 2636.00000 124.9 @ 2641.00000 188.4 150.98000 FT/HR SURFACE TORQUE 8 @ 2640.00000 6 @ 2636.00000 7.1 6.50000 AMPS WEIGHT ON BIT 4 @ 2640.00000 1 @ 2645.00000 2.1 1.02000 KLBS P RY RPM 59 @ 2638.00000 30 @ 2635.00000 61.1 56.93000 RPM . ~I~GIP PRESSURE 1457 @ 2635.00000 11..20 @ 2636.00000 1390.1 1273.50000. PSI DRILLING MUD REPORT DEPTH 2645'. MW 9.0 VIS 49 PV 11 YP 18 FL 4.5 Gels 7/10/0 CL- 29000 FC 1/0 SOL 1.6 SD 0 OIL 0 MBL 0 pH 10.8 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 10 @ 2635.00000 1 @ 2636.00000 4.1 TRIP GAS 0 @ , 2635 CUTTING GAS 0 @ 2645.00000 0 @ 2645.00000 0.0 WIPER GAS CHROMATOGRAPHY',(ppm) SURVEY METHANE (C-1) 2095 @ 2635.00000 283 @ 2636.00000 795.7 C ONNECTION GAS HIGH ETHANE (C-2) 0 @ 2645.00000 0 @ 2645.00000 0.0 AVG PROPANE (C-3) 0 @ 2645.00000 0 @ 2645.00000 0.0 CURRENT BUTANE (C-4) 0 @ 2645.00000 0 @ 2645.00000 0.0 CURRENT 0 BACKGROUND/AVG ANE (C-5) 0 @ 2645.00000 0 @ 2645A0000 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 10 ' DRILLED = 80% CEMENT IN SAMPLES 20% SAND AND SILT PRESENT LITHOLOGY FINISH TESTING BOPE, P/U 8.5" BHA AND 50 JTS OF DP. WASH 2 STANDS IN AND TAG DAILY CEMENT @ 2536'. DRILL CEMENT, FLOAT EQUIPMENT, SHOE AND 10' OF NEW A(~j,IVITY FORMATION. DISPLACE ACTIVE SYSTEM WITH KCL/POLYMER MUD AND CIRCULATE ARY BOTTOMS UP. TRIP GAS = 0. PERFORM F.I.T. GOOD TO 15.5 PPG. PULL INTO CASING BUILDING VOLUME WHILE WAITING ON TRACTION MOTOR FOR THE #2 MUD PUMP. EPOCH PERSONNEL ON BOARD Browne, Lundy, Bietting, Ferguson DAILY COST $3350 REPORT BY Lees F. Browne Jr. • UNION/CHEVRON DAILY WELLSITE EI'O~H • REPORT SCU-42-05X REPORT FOR LAWRENCE/LAZENBY DATE Jun 28, 2006 DEPTH 2635.00000 PRESENT OPERATION NIPPLE UP TIME 0:01:00 YESTERDAY 2635.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @2621' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2635' 18.00 1.10 2553.36 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" 2635' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ''~RY RPM @ @ RPM PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH build new mud 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 @ @ 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) @ @ NY OCARBON SHOWS ~VAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLE COLLECTION BEGINS UNDER SURFACE CASING PRESENT LITHOLOGY Finish pumping 160 bbl lead cement @ 12.8 ppg, pump 46 bbl tail cement @ 15.8 ppg, drop plug, pump 10 bbl H2O, bump plug @ 3200 psi w/ 174.7 bbl 9.2 ppg mud, hold 3200 psi on plug for 30 mins., bleed off check floats, R/D Schlumberger manifold + hoses, pull landing joint, wash well head DAILY and lay down tool, pull rotatary table, remove flow line + bell nipple, pressure wash, clean sand trap, A IVITY R/U P/U slings, nipple down diverter line, remove knife valve, lift diverter & remove DSA, remove ~IIARY diverter spool, break bolts on spool below.. diverter, clean mud pits and fill with H2O, nipple up preventer, double gate, mud cross, single.. gate, riser spool, choke line, kill line, bell nipple, flow line and begin building drill mud. Set rotate table P/U mouse hole, rig tongs and remove 4"annulus values, P/U running joint, M/U pac-off EPOCH PERSONNEL ON BOARD Browne, Lundy, Bietting, Ferguson DAILY COST $3350 w/ sample catchers REPORT BY Lees F. Browne Jr. • UNION/CHEVRON ~ DAILY WELLSITE REPORT E~~~~ SCU-42-05X REPORT FOR LAWRENCE/LAZENBY DATE Jun 27, 2006 DEPTH 2635.00000 PRESENT OP ERATION CEMENT CASING TIME 00:01 YESTERDAY 2635.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 98' 9 5/8" @ DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2635' 18.00 1.10 2553.36 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOU RS T/B/C PULLED 1 12.25" EBXSC1 S 10886676 4X15 96 2635 2539 28 2/2-E-CT TD 2 8,5" 2635 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS ~ HT ON BIT @ @ KLBS ARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2635' ~, MW 9.2 VIS 49 PV 17 YP 23 FL 6.0 Gels 11/16/0 CL- 1100 ', FC 2/0 SOL 6.2 SD 0 OIL 0 MBL 10.0 pH 9.4 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 17 T G @ 2635 4 circ @ 2635 7 circ TRIP GAS 17 CIRC CSG 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) @ @ OCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLES START UNDER SURFACE CASING PRESENT LITHOLOGY DAILY PUMP OUT OF THE HOLE, L/D BHA, MWD & BIT, R/U CASING TOOLS, RUN 9 5/8" CSG, M/U ACTIVITY HANGER, LANDING JOINT, PUMP IN SUB, CIRC HOSES AND WASH DOWN, HANGER SUMMARY SHOE @ 2621', CIRC BOTTOMS UP (17 UNITS TG) AND CIRCULATE FLAG AROUND BUILD MUD PUSH. CEMENT EPOCH PERSONNEL ON BROWNE, LUNDY, BIETTING, BOARD FURGUSION REPORT BY LEES F. BROWNE JR. • DAILY $3350 W/ 2 SAMPLE COST CATCHERS UNION/CHEVRON DAILY WELLS ITE EI'C~CH • REPORT SCU-42-05X REPORT FOR LAWRENCE/LAZENBY DATE Jun 26, 2006 DEPTH 2636.00000 PRESENT OPERATION TRIP OUT FOR CASING TIME 0:00 YESTERDAY 2281.00000 24 HOUR FOOTAGE 355' 'CASING INFORMATION 13.375" @ 98' DEPTH ~ INCLINATION AZIMUTH VERTICAL DEPTH 2635' 18.00 1.10 2553.36 SURVEY DATA 2560' 19.00 1.10 2482.23 2499' 18.80 ' 0.90 2424.52 2438' 18.70 1.70 2366.76 2375' 18.80 1.40 2307.10 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" EBXSC1 S 10886676 4X15 96 2635 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG OF PENETRATION 312.9 @ 2502.00000 18.6 @ 2626.00000 148.1 188.03999 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 35 @ 2626.00000 SLIDE @ 2556.00000 12.5 0.00000 KLBS ROTARY RPM 78 @ 2551.00000 30 @ 2636.00000 49.7 30.66000 RPM PUMP PRESSURE 1803 @ 2451.00000 1055 @ 2633.00000 1478.2 1457.63000 PSI DRILLING MUD REPORT DEPTH 2635' MW 9.2 VIS 49 PV 17 YP 23 FL 6.0 Gels 11/16/0 CL- 1100 FC 2/0 SOL 6.2 SD 0 OIL 0 MBL 10.0 pH 9.40 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY HIGH LOW AVERAGE (units) DITCH GAS 424 @ 2496.00000 10 @ 2636.00000 166.2 TRIP GAS CUTTING GAS @ @ WIPER GAS 60 @ 2635 CHROMATOGRAPHY',(ppm) SURVEY METHANE (C-1) 83294 @ 2496.00000 2095 @ 2635.00000 32719.7 CONNECTION GAS HIGH 0 ~NE (C-2) 0 @ 2636.00000 0 @ 2636.00000 0.0 AVG 0 rr~' PANE (C-3) 0 @ 2636.00000 0 @ 2636.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 2636.00000 0 @ 2636.00000 0.0 CURRENT 0 BACKGROUND/AVG PENTANE (C-5) 0 @ 2636.00000 0 @ 2636.00000 0.0 HYDROCARBON SHOWS NO GAS KICKS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLES CAUGHT UNDER SURFACE CASING. '-ENT LITHOLOGY DRILL AND SLIDE TO 2558', NOTICED A BAD SPOT ON THE DRILLING LINE, CIRCULATE DAILY AND CUT DRILL LINE, DRILL AND SLIDE TO 2635', PUMP OUT OF THE HOLE TO 500', TRIP ACTIVITY IN THE HOLE, PUMP A HI-VIS WALNUT SWEEP AROUND @ 20 PPB TO GAUGE THE HOLE, SUMMARY TOOK 18 BBLS OVER CALCULATED HOLE VOLUME INDICATING A FAIRLY GAUGED HOLE. PUMP OUT OF THE HOLE TO RUN 9 5/8. EPOCH PERSONNEL ON BOARD BROWNE, LUNDY, BIETTING DAILY COST $2670 REPORT BY LEES F. BROWNE JR. • • UNION OIL CHEVRO N DAILY WELLSITE ET'~-CH ~ 'REPORT SCU-05X REPORT FOR LAWRENCE/LAZENBY DATE Jun 25, 2006 DEPTH 2281.00000 PRESENT OPERATION DRILLING TIME 00:04:16 YESTERDAY 562.00000 24 HOUR FOOTAGE 1719' CASING INFORMATION 13.375" @ 98' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2190 18.00 357.70 2131.29' SURVEY DATA 2128 17.90 358.20 2072.31 2067 17.80 355.70 2014.24' 2004 17.50 353.90 1954.21' 1943 17.40 354.40 1896.02' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" EBXSC1 S 10886676 4X15 96' 32:23 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG OF PENETRATION 250.3 @ 1439.00000 16.6 @ 2279.00000 102.4 98.12000 FT/HR SURFACE TORQUE 10 @ 1399.00000 SLIDE @ 924.00000 2.4 0.00000 AMPS WEIGHT ON BIT 27 @ 910.00000 SLIDE @ 1325.00000 7.1 0.00000 KLBS ROTARY RPM 68 @ 717.00000 2 @ 1202.00000 26.1 0.00000 RPM PUMP PRESSURE 1775 @ 910.00000 1263 @ 960.00000 1003.4 0.00000 PSI DRILLING MUD REPORT DEPTH 2260' MW 9.1 VIS 55 PV 13 YP 37 FL 6.0 Gels 19/26/0 CL- 1200 FC 2/0 SOL 5.7 SD 2.00 OIL 0 MBL 10.0 pH 9 .8 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 308 @ 1773.00000 1 @ 1528.00000 86.4 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 61654 @ 1773.00000 253 @ 1528.00000 17790.7 CO NNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 2281.00000 0 @ 2281.00000 0.0 AVG 0 ~ANE (C-3) 0 @ 2281.00000 0 @ 2281.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 2281.00000 0 @ 2281.00000 0.0 CURRENT 175 BACKGROUND/AVG PENTANE (C-5) 0 @ 2281.00000 0 @ 2281.00000 0.0 HYDROCARBON SHOWS NO GAS SHOWS GROUND UP COAL IN SPOT SAMPLES FROM MUD MOTOR INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLE COLLECTION BEGINS UNDER SURFACE CASING PRESENT LITHOLOGY ACTIVITY SUMMARY DRILLING AND SLIDING'AND SURVEY HOLE LAST 24 HRS EPOCH PERSONNEL ON BOARD LEES BROWNS, JOHN LUNDY DAILY COST $2670.00 REPORT BY LEES F. BROWNS JR. • .. UNION CHEVRON DAILY WELLSITE REPORT EhQCI~ SCU-05X ~ . ORT FOR LAWRENCE/LAZENB DATE ,lun 24, 2006 DEPTH 562.00000 PRESENT OPERATION DRILLING TIME 24:00 YESTERDAY 166.00000 24 HOUR FOOTAGE 396' CASING INFORMATION 13.375"@ 96' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 362' 0.25 ' 299.26 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" EBXSC1 S 10886676 4X15 96' 19.54 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 257.5 @ 512.00000 5.3 @ 166.00000 75.4 95.47000 FT/HR SURFACE TORQUE 15 @ 256.00000 SLIDE @ 551.00000 1.9 2.29000 AMPS WEIGHT ON BIT 13 @ 546.00000 SLIDE @ 344.00000 2.9 5.44000 KLBS ROTARY RPM 191 @ 387.00000 36 @ 218.00000 57.5 60.22000 RPM PUMP PRESSURE 1547 @ 551.00000 724 @ 217.00000 1042.8 1513.04004 PSI ING MUD REPORT DEPTH 460' MW 8.9 VIS 64 PV 16 YP 34 FL 7.2 Gels 16/25/0 CL- 1600 FC 2/0 SOL 4.2 SD 0.25 OIL 0 MBL 12.5 pH 10.50 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY HIGH LOW AVERAGE (units) DITCH GAS 45 @ 538.00000 0 @ 174.00000 15.0 TRIP GAS @ 410 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 9098 @ 538.00000 98 @ 198.00000 2918.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 562.00000 0 @ 562.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 562.00000 0 @ 562.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 562.00000 0 @ 562.00000 0.0 CURRENT 25 BACKGROUND/AVG PENTANE (C-5) 0 @ 562.00000 0 @ 562.00000 0.0 uOCARBON SHOWS NO SHOWS VAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLES BEGIN UNDER SURFACE CASING PRESENT LITHOLOGY DRILL TO 410', PUMP HIVIS PILL AROUND, WITH SMALL INCREASE IN CUTTINGS AT DAILY ACTIVITY SHAKERS, MAKE GYRO RUN, POOH, P/U KICK OFF ASSEMBLY, TIH WITH NO SUMMARY PROBLEMS, R/U AND RUN GYRO TO ORIENT TOOL, BEGIN SLIDING AND ROTATING E~CH PERSONNEL ON BOARD LEES BROWNE JOHN LUNDY DAILY COST $2670 REPORT BY LEES F. BROWNE JR. • • UNION OIL CHEVRON DAILY WELLSITE REPORT El'fJ~~-I SCU42-05X ~.CPORT FOR COMPANY MAN DATE Jun 23, 2006 DEPTH 1'66.00000 PRESENT OPERATION DRILLING TIME MIDNIGHT YESTERDAY 96.00000 24 HOUR FOOTAGE 70' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" EBXSC1 S 10886676 4X15 96' 5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 38.0 @ 162.00000 2.5 @ 139.00000 4.1 5.35000 FT/HR SURFACE TORQUE 9 @ 142.00000 1 @ 160.00000 0.9 2.53000 AMPS WEIGHT ON BIT 4 @ 150.00000 0 @ 143.00000 0.5 3.07000 KLBS ROTARY RPM 80 @ 146.00000 48 @ 149.00000 28.2 64.35000 RPM PUMP PRESSURE 783 @ 166.00000 659 @ 163.00000 302.1 783.53998 PSI DRILLING MUD REPORT DEPTH 23:30 HRS ~W 8.7 VIS 75 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 5 @ 163.00000 0 @ 96 0.2 TRIP GAS 0 @ 144' CUTTING GAS 0 @ 166.00000 0 @ 166.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 100 @ 163 0 @ 96 0 TO 5 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 166.00000 0 @ 166.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 166.00000 0 @ 166.00000 0.0 CURRENT 0 BUTANE (C-4) 0' @ 166.00000 0 @ 166.00000 0.0 CURRENT BACKGROUND/AVG 0.5 PENTANE (C-5) 0 @ 166.00000 0 @ 166.00000 0.0 HYDROCARBON SHOWS NO SHOWS' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY GAS AND ROP LOG TO SURFACE CASING ENT LITHOLOGY SAMPLES COMMENCE UNDER SURFACE CASING DAILY NIPPLE UP, DRIFT BELL NIPPLE +DIVERTER W/ TEST PLUG, TEST DIVERTER, CHANGE ACTIVITY SAVOR SUB AND LOAD BHA ONTO PIPE RACK, NIPPLE UP DIVERTER LINE, P/U BHA, DC, SUMMARY REPAIR RIG TONGS, M/U BIT AND BHA AND RIH, TAG BOTTOM AT 96', CHECK FOR LEAKS, DRILL FORMATION FROM 96' TO 144', POOH TO CHECK BIT AND B HA, EVERYTHING OK, RIH TO BOTTOM (TG = 0) AND DRILL TO 166' ABNT PEA GRAVEL OVER SHAKERS. EPOCH PERSONNEL ON BOARD LEES BROWNE, JOHN LUNDY DAILY COST $2670 • REPORT BY LEES BROWNE JF2.
