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184-136
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:Brooks, Phoebe L (OGC) To:Brandon Bauer Cc:Regg, James B (OGC) Subject:RE: 232-09 MIT results Date:Monday, October 20, 2025 5:01:29 PM Attachments:MIT BRU 232-09 09-30-25 Revised.xlsx Brandon, Attached is a revised report changing the BBL Pump/Return to 3.8/3.5 (I believe gallons were included previously). Please update your copy or let me know if you disagree. Thank you! Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brandon Bauer <bbauer@hilcorp.com> Sent: Tuesday, September 30, 2025 11:32 AM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: 232-09 MIT results Phoebe, Here are the results from the MIT today with EPA’s form also attached. Thanks Brandon Bauer Beluga River/Westside Lead Operator Office 907-263-3905 Cell 907-395-7171 Alternate:Brian Woolley Hilcorp Alaska, LLC %HOXJD5LYHU8QLW 37' revised report changing the BBL Pump/Return to 3.8/3.5 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. Submit to: OOPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1841360 Type Inj N Tubing 1301 1183 1155 1128 Type Test P Packer TVD 3404 BBL Pump 3.8 IA 13 3011 2957 2931 Interval O Test psi 3000 BBL Return 3.5 OA 0 0 0 0 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 Beluga River / BRU / BRU 232-09 Pad Waived - EPA Witnessed Brandon Bauer 09/30/25 Notes: Class I Disposal Well - Annual MIT with EPA witnessing. Test result is PASS. EPA requires test to 3000 psi. Notes: Notes: Notes: 232-09 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)2025-0930_MIT_BRU_232-09 9 9 999 99 99 9 9 $2*&&UHTXLUHGWHVWLVSVL MEU -5HJJ ORIGINATED TRANSMITTAL DATE: 1/27/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5256 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5256 2W-13 50029212520000 Production Profile (PPROF) 20-Jan-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 184-236 T40022 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.28 10:09:14 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com per, (Vie 2 Gttii:iL- 7-3z -(I -b W413r o Regg, James B (OGQ From: Casey Morse <Casey.Molhilcorp.com> Sent: Wednesday, October 30, 2024 8:49 AM To: Regg, James B (OGC); DOA AOGCC Prudhoe Bay, Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Subject: MIT BRU 232-09 (PTD 184136) Attachments: MIT BRU 232-09 2024-10-21.xlsx 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. Please see attached report of successful EPA witnessed MIT performed on BRU 232-09 (Class I disposal well) on 10/21/24. This test was performed per EPA Underground Injection Control Permit No. AK11014-B and followed EPA test procedures. Thankyou, Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907)777-8322 The information contained in this email message is confidential and maybe 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. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to iim. reaa0alaska.aov: AOGCCJnsoec1ors0aiaska.aoy: phoebebrooksatialaska. aov OPERATOR: Hilcorp Alaska LLC FIELD / UNIT / PAD: Beluga River / BRU / BRU 232-09 Pad i DATE: 10/21124 OPERATOR REP: AOGCC REP: chns.wallace(Maaska aov Well 232-09 ' Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTO 1841360 Type Inj N - Tubing 548 - 499 495 490 ' Type Tast P Packer TVO 3404 BBL Pump 2.5 IA 47 3097 3063 i 3045 i Interval 0 Test psi 1500 BBLRetum OA 1 0 0 1 0 1 0 Result P Notes: Class I Disposal Well -Annual MIT with EPA EPA requires last to 3000 psi. BBL Returned was not recorded as this was witnessing. Test handl is PASS. not required by the EPA. 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 Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnl Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTO Type Inj Tubing Type Test Packer TVD BBLPump to Interval Test psi BBLRetum OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBLPump IA In Test psi BBL Return OA Result holes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBI-Pumpj IA Interval Test psi BBL Return OA Result Notes Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTO Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBLRetum OA Result holes: TYPE INJ Ca4es TYPE TEST Cures INTERVAL Codes Result Codes W=water P=Pressure Test 1=treat Test P=Pose G=Gas O= GNer sescnM In Notes) i=Four year Cycle F=Fail S-sli v=Regoeed by Wei I=ncondows I e Ind verse WeMewata o= Other ldeecnbe In notes) N =Not In)Mng Form 104M Revised 01/2017) MIT eau 232-092024-10.21 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/6/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240306 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-19RD 50133205790100 219188 12/9/2023 AK E-LINE CBL BRU 232-09 50283200750000 184136 10/30/2023 AK E-Line PT/CALIPER MPU B-19A 50029214510100 223123 2/26/2024 HALLIBURTON Jewelry Log MPU I-12 50029230380000 201163 1/30/2024 HALLIBURTON Coilflag MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON Coilflag PBU N-11D 50029213750300 223083 2/13/2024 HALLIBURTON RBT Please include current contact information if different from above. T38597 T38598 T38599 T38600 T38601 T38602 BRU 232-09 50283200750000 184136 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.06 12:00:22 -09'00' 1 Regg, James B (OGC) From:Casey Morse <Casey.Morse@hilcorp.com> Sent:Monday, November 6, 2023 4:58 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Subject:MIT - BRU 232-09 (EPA Class 1 Disposal Well) 10/26/2023 Attachments:MIT BRU 232-09 10-26-23.xlsx AƩached is the report of successful EPA witnessed MIT performed on the Beluga River Unit 232‐09 Class 1 Disposal Well on 10/26/23. This test was conducted per EPA Underground InjecƟon Control Permit No. AK‐1I014‐B and followed EPA test procedures. 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. Some people who received this message don't often get email from casey.morse@hilcorp.com. Learn why this is important 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. Beluga River Unit 232-09PTD 1841360 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1841360 Type Inj N Tubing 513 507 503 499 0 0 Type Test P Packer TVD 3404 BBL Pump 3.9 IA 80 3056 2976 2943 Interval O Test psi 1500 BBL Return OA 0 0 0 0 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: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Beluga River / BRU / BRU 232-09 Pad Brandon Bauer 10/26/23 Notes: Class I Disposal Well - Annual MIT with EPA witnessing. Test result is PASS. EPA requires test to 3000 psi. BBL Returned was not recorded as this was not required by the EPA. Notes: Notes: Notes: 232-09 Form 10-426 (Revised 01/2017)2023-1026_MIT_BRU_232-09 J. Regg; 3/12/2024 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/25/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BRU 232-09 (PTD 184-136) GPT Caliper 09/09/2021 Please include current contact information if different from above. 10/26/2021 g2u. 27,'2 —U I Reqq, James B (CED) From: Holly Tipton <hotipton@hilcorp.com> ' C Sent: Thursday, September 5, 2019 10:46 AM To: Regg, James B (CED); DOA AOGCC Prudhoe Bay; Broo s, Phoebe L (CED); Wallace, Chris D (CED) Subject: MIT Beluga River 08-21-19 Attachments: MIT Beluga River 08-21-19.xlsx Good morning, Please see attached for official report of the successful MIT performed and witnessed by the EPA on the Beluga River Class I disposal well BRU 232-09 on 8-21-2019. Thank you, Holly Tipton Regulatory Tech - CIO Asset Team Hilcorp Alaska, LLC 0:(907)777-8330 1 m:(281)543-8964 e: hotipton@hilcorp.com The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. 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. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iimream&alaska aov: ADGCC. Inspectors®alaska aov. phoebe Drookst&ala.ka.aov OPERATOR: Hilcom Alaska LLC FIELD / UNIT I PAD: Beluga River Field / BRU I BRU 232.09 Pad DATE: 08/21/19 OPERATOR REP: Amy Peloze ADGCC REP: waived chriswallacisMalaska. aov Well TYPE TEST Cosee BRU 232-09 Result COEes Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. F=Fait a=slurry PTD 1841380 Type Inj N Tubing 359 316- 309 303 - Type Test P Packer TVD 340488LPump 1 3.5 IA 300 3088 - 3052 3034 Interval O Test psi 1500 BBL Return 1 2.5 OA 0 0 - 0 - 0 Result P Notes: Class l well on annual MIT with EPA wiNessing-EPA deemed PASS. Well Pressures'. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD EEL Pump IA Interval Test psi BBL Return OA ResuR Note.: Well Pressures: Pretest Ini 15 Min. 30 Min. 45 Min, 60 Min, PTD Type Inj Tubing Type Test PackerND BBLPump IA Interval Test psi BBL Return OA Result Notts: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Pecker ND BBLPump IA I al Test psi BBL Return OA Result Nobs: Well Pressures'. Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. PTD Type Inj Tubing Type Test PackerND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. PTD Type III Tubing Type Test Packer WD BBL Pump IA Interval Test psi BBL Return OA Result Note.: Well Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. PTO Type Inj Tubing Type Test Packer NO BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures'. Pretest Initial 15 Min. 30 Min. 45 Min. 80 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Nobe: TYPE INJ Co4ec TYPE TEST Cosee INTERVAL cook. Result COEes W=Water P=Prnwre Test 1=initial TM P=Pau G=Ga. 0= Me, (onsi in Notes) 4=Four Year Cycle F=Fait a=slurry V- Pancras! Ey Variance 1=Inconclusive I = IMuatlial wa6Nwater 0 =other leescrice in notes) N =Not IMeMing Form 10426 (Revised 01/2017) MIT Beluga River 0841-19 M Prb i 4I3‘,c Regg, James B (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> 63lzc1i Sent: Tuesday, August 29, 2017 1:29 PM 6 l To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA);Wallace, Chris D (DOA) Subject: MIT Beluga River 08-03-17 Attachments: MIT Beluga River 08-03-17.xlsx Gentlepeople Here is the official report of the successful MIT performed with EPA witnessing on the Class I Beluga River well BRU 232- 09 on 8/03/17. Thank you Larry SCANNEDr6. 2 tki t_04, a • • . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.resatSalaska.aov: AOGCC.Inspectors(dalaska.gov phoebe.brooks(Qalaska.aov chris.wallace(aalaska.dov I OPERATOR: Hilcorp Alaska LLC i�I (e(vq(`-7 FIELD/UNIT/PAD: Beluga River Field/BRU/Bru 232-09 Pad DATE: 08/03/17 OPERATOR REP: Amy Peloza AOGCC REP: waived per Jim Regg 7/25/17 Well BRU 232-09 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1841360, Type Inj W Tubing 498 459 450 442 432 Type Test P Packer TVD 3404 .. BBL Pump 1.5 ' IA 453 2203 ' 2170 ' 2152 - 2140" Interval 0 Test psi 1500. BBL Return OA 2 2 2 2 2 Result P Notes: Class I well on annual MIT with EPA witnessing by Tim Mayers. No record of bleed down return volume. 7 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 Notes: 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 Notes: 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 Notes: 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 Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: 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 Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT Beluga River On-03-17 . • • RECEIVED UNITED STATES ENVIRONMENTAL PROTECTION AGENCY i Ank T REGION 10 APR 2 5 2016 g , 1 1200 Sixth Avenue, Suite 900 <a 11/4tror v . Seattle WA 98101-3140 AOGCC 41.FRoceP APR 2 1 2016 OFFICE OF COMPLIANCE AND ENFORCEMENT Reply to: OCE-101 CERTIFIED MAIL—RETURN RECEIPT REQUESTED kpok 31 Mr. David Wilkins SCANNED 0261 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Re: Transfer of Permit No. AK-11014-A Class I Well Beluga River Unit from ConocoPhillips Alaska, Inc. to Hilcorp Alaska, LLC. Dear Mr. Wilkins: The U.S. Environmental Protection Agency(EPA)has reviewed the Application to Transfer Permit that You submitted on February 10, 2016, the Surety Performance Bond that you submitted on March 15, 2016, and the Standby Trust Agreement that you submitted on April 20, 2016, for approval of the transfer of owner and operator of the subject well, and has found them acceptable for approval and transfer. In accordance with 40 C.F.R. § Section 144.41(d), enclosed are minor modifications to the permit that acknowledge the transfer and change of ownership from ConocoPhillips Alaska, Inc. effective on the date signed by the Director. The well name and applicable permit number are as follows: Well Name Permit Number 232-09 AK-11014-A The EPA requires 45 days advance notice of plugging and abandonment (P&A) operations and submittal of a proposed P&A procedure with the notice. Financial assurance amounts are also subject to periodic reviews and updating for actual P&A costs as those estimated costs change over time. 11yoi have any questions about the transfer approval, please contact Tim Mayers at (907) 271-3410, or email at mayers.timothy@cpa.gov. Sin .0.ely, Edwar . Kowalski „.... 22i,/ _de, ....-- , fie.e2 Director Enclosure i., cc: Chris Wallace t/ Alaska Oil and Gas Conservation Commission-Anchorage • 0 MINOR MODIFICATION TO PERMIT (No. AK-11014-A) ISSUED TO HILCORP ALASKA, LLC In accordance with 40 C.F.R. § 144.41(d), it is understood and agreed that this permit has been transferred frons ConocoPhillips Alaska, Inc. to Hilcorp Alaska, LLC effective on the date signed below by the Director. Wherever the name "ConocoPhillips Alaska, Inc." appears herein,it is amended to "Hilcorp Alaska, LLC." I Hilcorp Alaska, LLC has provided a Surety Performance Bond (No. 106391696), issued by Travelers Casualty and Surety Company of America in the amount of$465,500.00, and has established a Standby Trust Fund to satisfy the financial assurance responsibility conditions of the permit at Part 1.G. This minor modification to become effective on: oil 3°fid dward J. 1 , a15k1 Director I Enclosure cc: Chris Wallace Alaska pil and Gas Conservation Commission-Anchorage Marc Bentley Alaska 3epartment of Environmental Conservation-Anchorage Gerry Brown Alaska'Department of Environmental Conservation-Anchorage 1 • • SEAN PARNELL, GOVERNOR 555 Cordova Street Anchorage, Alaska 99501 g OFn S n Phone: (907) 269 -6258 Fax: (907) 269 -3487 DEPARTMENT OF ENVIRONMENTAL CONSERVATION www.dec.state.ak.us DIVISION OF WATER WASTEWATER DISCHARGE AUTHORIZATION PROGRAM July 14, 2011 DEC File No.: 2337.48.005 Mr. Darren Meznarich ConocoPhillips Alaska Inc. P.O. Box 100360 .d _it �?' 2.111't Anchorage, AK 99510 -0360 Re: Authorization 2010DB0001 - 0022; Beluga River Unit, Well BRU 232 - 09 Dear Mr. Meznarich: The Alaska Department of Environmental Conservation has completed its review of the Notice of Intent for the Beluga River Unit UIC, Well BRU 232 -09 and is issuing authorization 2010DB0001 -0022. $ y —V3'a The department has both an informal review process and a formal administrative appeal process for final permit decisions. An informal review request must be delivered within 15 days after receiving the department's decision to the Director of the Division of Water at the following address: Director, Division of Water Alaska Department of Environmental Conservation 555 Cordova Street Anchorage, AK 99501 -2617 Interested persons can review 18 AAC 15.185 for the procedures and substantive requirements regarding a request for an informal department review. See http: / /www.dec. state. ak.us /commish/ReviewGuidance.htm for information regarding appeals of department decisions. An adjudicatory hearing request must be delivered to the Commissioner of the department within 30 days of the permit decision or a decision issued under the informal review process, whichever is later. An adjudicatory hearing will be conducted by an administrative law judge in the Office of Administrative Hearings within the Department of Administration. A written request for an adjudicatory hearing shall be delivered to the Commissioner at the following address: Commissioner Alaska Department of Environmental Conservation 410 Willoughby Avenue, Suite 303 Juneau, AK 99811 -1800 • • Interested persons can review 18 AAC 15.200 for the procedures and substantive requirements regarding a request for an adjudicatory hearing. See http: / /www.dec. state. ak .us /commish/ReviewGuidance.htm for information regarding appeals of department decisions. This authorization became effective on May 18, 2011 and expires at midnight on April 21, 2015. You must reapply for an authorization on or before January 21, 2015, 90 days prior to the expiration date. If you have any questions concerning this authorization, please contact Marc H. Bentley at 907.269.6287, marc.bentleyaalaska.gov or Adele Fetter at 907.269.7235, adele. fetter(7a,alaska. gov. Sincerely, Michelle Bonnet Section Manager Enclosure: Permit No. 2010DB0001 Authorization 2010DB0001 -0022 cc: Marc Bentley, DEC, Division of Water, Anchorage Tom Maunder, AOGCC, Anchorage Thor Cutler, EPA, Seattle • • STATE OF ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION Division of Water AUTHORIZATION NUMBER 2010DB0001 - 0022 UNDER CLASS I INJECTION WELL DEC File Number: 2337.48.005 General Permit Number 2010DB0001 See this General Permit for additional permit requirements The following responsible party is authorized to discharge in accordance with the terms of general permit 2010DB0001, the information provided in the Notice of Intent, and any site specific requirements listed in this authorization: RESPONSIBLE PARTY: First Name: Darren Last Name: Meznarich Company: ConocoPhillips, Alaska Inc. Phone Number: 907.263.4810 Mailing Address: P.O. Box 100360 City: Anchorage State: Alaska Zip: 99510 -0360 Email: Darren.L.Meznarich @conocophillips.com ON SITE CONTACTS: First/Last Name: Mike Knight Phone Number: 907.263.3930 Jay McKee Phone Number: 907.263.3930 FACILITY: NAICS Code: 213111 (Formerly the Standard Industrial code SIC: 1311) Facility Name: Beluga River Unit Phone Number: 907.776.2021 Mailing Address: P.O. Box Drawer 66 Fax Number: 907.776.2095 City: Kenai State: Alaska Zip: 99611 PHYSICAL ADDRESS: Physical Location: Mile 21.5 Kenai Spur Highway City: Kenai State: Alaska Zip: 99611 GENERAL DESCRIPTION OF THE PROJECT: Well BRU 232 -09 is to serve as a Class I Industrial waste disposal well; and, become a critical back -up to the existing Class II disposal well BRWD #1. Injected wastes will be produced water, non - exempt unused drilling fluids, some camp wastewaters, small volumes of non - exempt, non - hazardous industrial wastes, and possibly limited amounts of drilling slurry/cuttings. AUTHORIZED DATES OF DISCHARGE Beginning Date: May 18, 2011 Ending Date: April 21, 2015 EPA CLASS I INJECTION WELL PERMIT NUMBER: AK- 11014 -A Beginning Date From: August 1, 2009 Ending Date To: July 31, 2019 • ESTIMATED INJECTION FLOW RATES AND VOLUME: Average: 75,600 Gallons per Day Maximum: 205,632 Gallons per Day Estimated Total Discharge Volume: 210,000,000 Gallons over 5 years AUTHORIZED LOCATION OF DISPOSAL Area(s): Beluga River Unit Name of formation; depth(s): Sterling Formation, approximately 3316 feet total vertical depth subsea Name of Well: BRU 232 -09 Latitude/Longitude of Injection Point(s) in decimal degrees NAD 83 Well: BRU 232 -09 Latitude: 61.1460264 Longitude: - 151.063566 ADDITIONAL SITE SPECIFIC PERMIT REQUIREMENTS UNDER THIS AUTHORIZATION: No condition of this permit is waived. Injected fluid is required to be reported on the annual report specifying the volume of drilling wastes, desalination wastewater, and sanitary and domestic wastewater, deck drainage /storm water, and miscellaneous non - hazardous wastes. The DEC Class I UIC Annual Report form is located at http: / /www.dec. state. ak. us /water /Compliance /permittee.html or by requesting the form at dec- wgreporting @alaska.gov The current annual negotiated fee for this discharge type has been determined to be $275.00 per year. This fee amount was calculated in accordance with the negotiated fee section of the regulations (18 AAC 72.959) SIGNATURE: 4 Signature Date Michelle Bonnet Section Manager Printed Name Title 23~-~~ Page 1 of 1 Regg, James B (DOA) I ~~~ - ~ 3~ From: Phillips, Jim (ASRC Energy Services) [Jim.Phillips@contractor.conocophillips.com] 2C~~~(2SI~v Sent: Tuesday, August 24, 2010 12:21 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Subject: State testing results for NCIU A-13 and BRU 232-09 Attachments: Copy of CPAI's NCIU A-13 MITIA Aug xx 2010 (2).xls; Copy of CPAI's BRU 232-09 MITIA Aug xx 2010 (2).xls All, Attached is the MITIA test results on 08/18/10 for NCIU A-13, and BRU 232-09 on 08/17/10. These were waived by Jim Regg. If you have any questions let me know. Jim Phillips Acting Problem Well Supervisor rl;U C.j-e~ :~i•. 8/25/2010 United States Environmental Protection Agency a.~- Region 10 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553-1673 e-mail: cutler.thor@epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility Well Permit No. PTD No. CPAI -BRU BRU 232-09 AK-1I014-A Injector MIT Type Test Type Test Date Class I T X IA Std. Annular Pressure Test (SAPT) Aug xx, 2010 Req'd Test Fluid Type(s) used to Packer Depth (ft, Test Interval /Comments Presssure (psi) test TVD) 2,000 Diesel/50-50 wtr/glycol x,xxx' One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel pumped in annulus during test. T START TIME: RECORDED PRESSURES (PSI) RESULT E 00:00 am/pm PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN P/F S TUBING T INNER ANNULUS OUTER ANNULUS 1 COMMENTS: T START TIME: RECORDED PRESSURES (PSI) RESULT E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING PASS/ T INNER ANNULUS FAIL OUTER ANNULUS 2 COMMENTS: T START TIME: RECORDED PRESSURES (PSI) RESULT E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING PASS/ T INNER ANNULUS FAIL OUTER ANNULUS 3 COMMENTS: MISC COMMENTS: Initial MITIA as Class I well on 8/28/09 (witness T.Cutler/Tim Mayer), Temp Surveys - 8/29!09 Converted from watered-out gas producer to Class I well (8129/09). Caliper survey/tbg - 8/25/09 (pollard) NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure Toss in last 15 minutes must be less than 33% of total loss Start MIT over i£ 1) Total loss exceeds 10 2) Loss during last •15 minute period = or > 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on-site decision per Inspector). 0 0 0 -- E-mail this MIT Test Data Form to EPA Region 10 -Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Talib Syed, P.E./ Thor Cutler z . • Page 1 of 24 ISSUANCE DATE AND SIGNATURE PAGE U.S. ENVIRONMENTAL PROTECTION AGENCY UNDERGROUND INJECTION CONTROL PERMIT: CLASS I Permit Number AK- 1I014 -A c In compliance with provisions of the Safe Drinking Water Act (SDWA), as amended, (42 U.S.C. 300f- 300j -9), and attendant regulations incorporated by the U.S. Environmental Protection Agency (EPA) under Title 40 of the Code of Federal Regulations, ConocoPhillips Alaska, Inc. (CPAI) (Permittee) is authorized to inject non - hazardous industrial waste utilizing up to one (1) existing, sidetrack or new /replacement Class I injection well at the onshore Beluga River Unit (BRU) gas field, in accordance with conditions set forth herein. The Alaska Oil and Gas Conservation Commission (AOGCC) in a letter dated May 13, 2009, has ruled that injection into Sterling Formation A and B zones at well BRU 232 -09 will not jeopardize the loss of any hydrocarbon resource. Based on information submitted by CPAI, EPA ruled on March 23, 2009, that the Sterling Formation in the interval between 3,495 feet MD and 4,390 feet MD and within one -half mile radius of the well BRU 232 -09 welibore qualifies for "aquifer exemption" for Class I injection as per 40 C.F.R. 146.4. Injection of hazardous waste as defined under the Resource Conservation and Recovery Act (RCRA), as amended, (42 USC 6901) or radioactive wastes (other than naturally occurring radioactive material — NORM from pipe scale) are not authorized under this permit. Injection shall not commence until the Permittee has received written authorization from EPA Region 10 Director of the Office of Compliance and Enforcement (Director) to inject. All references to Title 40 of the Code of Federal Regulations are to regulations that are in effect on the date that this permit is issued. Figures and appendices are referenced to the well BRU 232 -09 Development Project Underground Injection Control (UIC) Class I Permit Application dated June 15, 2009. This permit shall become effective on August 1, 2009, in accordance with 40 C.F.R. § 124.15. This permit and the authorization to inject expire at midnight, July 31, 2019, unless terminated. Signed this /d day of July, 2009. %, //,,/ 10 VIVA& dward J alski, irector Office • compliance and Enforcement V U.S. Environmental Protection Agency Region 10 (OCE -164) 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 . . f 5 i •� r A SARAH PALIN, GOVERNOR ALASKA SKA OIL AND GAS �` 333 W. 7th AVENUE, SUITE 100 CONSERVATION CONSE COMMISSION �, ANCHORAGE, ALASKA 99501 -3539 1� i� xi •s ►7 PHONE (907) 279 -1433 FAX (907) 276 -7542 May 13, 2009 John C. Braden, PE Cook Inlet Asset ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -360 Re: ConocoPhillips Alaska, Inc.'s Request for Concurrence Concerning Class I Injection into Sterling A and B Zones through Well 232 -09, Beluga River Unit. 155— Dear Mr. Braden: This letter responds to ConocoPhillips Alaska, Inc.'s (CPAI) request of March 26, 2009, as orally amended on April 20, 2009, asking the Alaska Oil and Gas Conservation Commission (Commission) to concur with CPAI's opinion that Class I injection into the Sterling A and B zones through well 232 -09 of the Beluga River Unit (BRU) will not waste resources. According to CPAI, the Commission's concurrence is a prerequisite to submitting a Class I disposal injection permit application to the U.S. Environmental Protection Agency (EPA). In the Commission's opinion, the data support CPAI's opinion that Class I injection into the Sterling A and B zones through well BRU 232 -09 will not waste resources; also, such injection . is not expected to impact freshwater, as defined by 20 AAC 25.990(27). This opinion is based upon the following findings made after reviewing public well and production records, and information submitted by CPAI with its March 26, 2009 request. 1. In the vicinity of BRU 232 -09, the Sterling A and B zones contain 8 -foot to 33 -foot thick sandstone intervals that are interlayered with beds of siltstone and clay. Net sand thickness within the Sterling A and B zones is about 90 feet and 70 feet, respectively. Upper confinement will be provided by an 11 -foot to 13 -foot thick interval of clay and coal that formed the top seal for the gas accumulation within the Sterling A zone, before the zone was depleted. This top seal appears to be continuous throughout the area. Lower confinement will be provided by several continuous siltstone, clay and coal layers that, within the lower portion of the Sterling B zone, are from about 4 feet to 13 feet thick. 2. The Sterling A and B zones are not defined by the Commission as a separate pool, but are a portion of the many stacked sands that comprise the Beluga River Undefined Gas Pool. BRU 232 -09 is located very low on the flank of the Beluga River Unit anticline. Well log data and drill -stem tests conducted during 1985 demonstrate that the Sterling A zone was the only productive interval in this well. John Braden • • May 13, 2009 Page 2 of 2 3. The Sterling A zone is the only zone open to BRU 232 -09. This zone produced 17.7 bcf of gas from 1987 until it watered out in 1997. During February 2009, after being shut -in for 12 years, BRU 232 -09 was opened to a tank. Pressure within the well dropped to 0 psi in 10 minutes, and did not increase over a 24 -hour period. The water level was found at 870 feet measured depth. Accordingly, the Commission concludes as follows: 1. the Sterling A and B zones are not capable of significant production in BRU 232 -09, 2. using BRU 232 -09 for Class I disposal in the Sterling A and B zones will not waste hydrocarbon resources, and 3. continuous upper and lower confining intervals and properly constructed wells will ensure that Class I wastes injected through BRU 232 -09 into the Sterling A and B zones remain in those zones and will not impact freshwater. Please call Mr. Steve Davies at 907 - 793 -1224 if you have questions. (, 11. Daniel T. Seamount, Jr. Cathy Foerster • , No,�l Chair Commissioner • missioner '�' . , cc: Greg Gould, ADEC(6 3Y4 • ` Thor Cutler, EPA 40 ;N rt_a.'s.' RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(6), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • . .. Art E. Copoulos ConocoPhillips Senior Engineer Alaska, Inc. 700 G Street, 99501 P.O. Box 100360 — Suite ATO 934 Anchorage, Alaska 99510 -0360 Phone (907) 263 -4094 Fax (907) 265 -1441 art e.copoulos@conocophillips.com March 28, 2009 Steve Davies Petroleum Geologist MAR 2 7 2 0 5 witi Jim Regg a Irr� Petroleum Engineer fc rtrem Alaska OH & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 1 S 6 L1 \ c, Dear Mr. Davies and Mr. Regg, Thank you for meeting with Conoco Phillips Alaska Inc., (CPAI), yesterday to discuss our plans to apply to the U.S. Environmental Protection Agency (EPA) for a Class I disposal injection permit. CPAI is proposing to inject wastes into a depleted Sterling -A geologic interval in well 232 -09 via existing perforations from 4154 — 4166'MD (3327- 3337 TVDss) and 4218 — 4237'MD (3381 -3397 TVDss) with future back -up in an overlying saline aquifer from 3830 feet MD to 4118 feet MD (3069 feet TVDss to 3297 feet TVDss). CPAI requests Alaska Oil & Gas Conservation Commission (AOGCC) concurrence that Class I injection in these intervals will not waste Beluga River Unit (BRU) resources. An AOGCC concurrence would be a component of CPAI's EPA Class II disposal injection permit application. 232 -09 would back -up to BRWD #1, the only water disposal well in the BRU. Over half of the BRU's production now includes water and could be shut -in if BRWD #1 unexpectedly failed. Having a back -up disposal well reduces the potential for shut -in production and associated lost recovery, or waste, and helps ensure a continuous gas supply to local markets. BRWD #1 is a Class II disposal well. Having 232 -09 as a Class I disposal well would eliminate environmental impacts associated with shipping Class I wastes to Lower -48 disposal sites and the need for Class I amendments to the BRWD #1 Class II permit. Utilization of well 232 -09 will minimize surface environmental impacts associated with trucking by providing for water disposal on both ends of the field, will protect fresh waters by disposing waste in a deep, confined, sand, and will utilize a depleted interval that is very low on structure and has no potential to produce. I have enclosed a copy of CPAI's application to the U.S. EPA for an aquifer exemption in well 232 -9, and EPA's March 23, 2009 approval. The application provides Sterling Director, Alaska Division of Oil and Gas March 27, 2009 Page 2 interval total dissolved solids data as requested, and an explanation of why the proposed injection intervals are not a suitable source of fresh water. Sincerely, C t') Art opoulos Cook Inlet Senior Engineer Cc: Mary Mae Aschoff EDEIVED ~~RED~ATFS UNITED STATES ENVIRONMENTAL PROTECTION AGENCY z~ A y„ REGION 10 o ~`~/'J 1200 Sixth Avenue, Suite 900 Z~~,~oa` Seattle, Washington 981 01-31 40 2T'9< PROZE~'~ NOV ~ 8 ~~~~ Reply To: OCE-127 CERTIFIED MAIL -RETURN RECEIPT REQUESTED Ms. Mary Mae Aschoff Environmental Coordinator ConocoPhillips Alaska, Inc. P.O. Box 100360 *ti~~~~~~k E~E.~~~ ~ ~ Zd~~ 700 G Street, ATO 1756 Anchorage, Alaska 99510-0360 ~~1s a ,~ ~~09 Alaska Oil 8, Gas Cans. Commission Anchorage t~~_ ~~~ Re: Final Approval to Inject into UIC Class I Beluga River Unit (BRU 232-09) Well, Underground Injection Control (UIC) Permit No. AK1I014-A Beluga River Unit (BRU) Gas Production Field, Cook Inlet, Alaska Dear Ms. Aschoff: The United States Environmental Protection Agency (EPA) Region 10 has witnessed the mechanical integrity tests (MIT) conducted o ConocoPhillips Alaska, Inc.'s (CPAl) Beluga River Unit Gas Field well numbe BRU 232-09. ' On November 9, 2009, EPA received and reviewed your final well schematic, waste analysis plan, WSR historical records. and temperature log interpretation report for Class I disposal well BRU 232-09 confirming the success of the MIT tests. EPA concurs with your findings. Based on your report and the observations by Thor Cutler, Timothy Mayers and Talib Syed, EPA grants final approval to inject under EPA UIC Permit No. AK-1I014-A at CPAI BRU 232-09 Class I well. This document authorizes the referenced facility to inject to the subsurface as indicated in the permit. The permit and the authorization to inject will expire at midnight July 20, 2019, unless terminated. We appreciate the cooperation of your staff during the planning, permitting; testing, and operating phases of the well. Please call Thor Cutler of my staff at (206) 553-1673 if you have any questions or need additional clarification. Your continued efforts to coordinate the scheduling of tests are appreciated. Edward J.~alski, Director Office of Compliance and Enforcement cc: Dan Seamount, AOGCC, Anchorage Shawn Stokes, ADEC, Anchorage Printed ort Recycled Paper • STATE OF ALASKA _ ~rGA- • OCT 1 5 2(~~°~2aoq ALASKA OIL AND GAS CONSERVATION COMMISSION ~1eska Oii & Gas Cons. COfYHY11SS10R REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ^ Repait Well ^ Plug Perforations ~ Stimulate ^ Other ~ ~pnvert to Class 1 Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ injector Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: Permit to Drill Number: COnOCOPhillips AlaskB, InC. Development ^~ Exploratory ~ 184-136 / 3. Address: Stratigraphic ^ Service ^ API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-283-20075 C3~i' . Elevation (ft): Well Name and Number: GL 91', KB 109' BRU 232-09 8. Property Designation: 10. Field/Pool(s): ~~~~~~' ~~S ~ ADL 1 8 ~ ~~ ;~.ti_ Beluga River Field / -Beluga Gas Pool ~~' ~~ 11. Present Well Condition Summary: Total Depth measured `V 7992' feet ~ ' true vertical 7179 feet Plugs (measured) 4428', 4690', 4820', 5835' Effective Depth measured 4256' feet Junk (measured) true vertical 3524' feet Casing Length Size MD ND Burst Collapse Structural Conductor 67' 30" 96' 96' Surface 366' 20" 394' 394' Intermediate 3908' 13-3/8" 3935' 3259' Production 6634' 9-5/8" 6658' S845' Perforation depth: Measured depth: 4154'-4166', 4218'-4237' true vertical depth: 3438'-3448', 3492'-3508' Tubing (size, grade, and measured depth) 2-7/g~~, N-80, 4205' MD. Packers & SSSV (type & measured depth) 2 Otis pkrs 4115', 4214' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicab/e Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation Subsequent to operation 14. Attachments . Well Class after work: Copies of Logs and Surveys run _ ~` Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact ~j nnis @ 265-1544 Printed Name nnis ~' Title Ph 265 1544 welis Engineer `~ j~,, ~,~ D t Signature one: - a e Pre ar b r n A su -Drake 263-4612 ~~ ~~ ~ ~ Form 10-404 vised 04/2006 Submit Original Only BRU 232-09 Well Events Summary DATE SUMMARY 7/11/09 MIRU BJS PUMP UNIT. TEST ~FACE EQUIPMENT 4,000 PSI. LOAD R~ FOR-RENT TANK WITH 360 BBLS PRODUCT WATER. INJECTIVITY TEST IN PROGRESS. 7/12/09 PERFORMED INJECTIVITY TEST ON LONG STRING.PUMPED TOTAL OF 360 BBLS PRODUCED WATER. INITIAL WHP 900 PSI, AFTER 60 BBLS AWAY WELL ON VACUUM. PUMPED REMAINING WATER @ 3 BPM 250 PSI. INJECTIVITY TEST COMPLETE. 8/25/09 WORK STRING DETAIL: RS, KJ, Stem, Stem, KJ, OJ, SJ 6" 8" 5' S' 8" 3 1/2' 6'DEBRIS LEFT IN HOLE: NONE SUMMARY OF WORK: Tag fill at 4,229' KB, run temp survey & run PDS 8/28/09 RU BJ for EPA witnessed MITIA. PT lines 3000 psi, OK. Initial T/I/O 1000/10/0. PT IA 2000 psi. Found tbg gauge would not go below 300 psi. Bleed IA to zero & replace tbg gauge. Tbg 680 psi. PT IA 2000 psi. Zero time T/I/O 690/2014/0. 15 minute T/I/O 690/1977/0. 30 minute T/I/O 690/1962/0. Passed MITIA witnessed by Thor Cutler & Tim Mayers w/ EPA. - Bled IA to zero. Final T/I/O 690/0/0. 8/29/09 Attend BRU morning safety mtg. Change BJ pump lines from IA to tbg wing. RU Pollard lubricator on swab w/ PDS memory temperature logging tools inside. PT BJ lines 3000 psi, OK. Open wing & PT Pollard lubricator 2500 psi, OK. Open master valve & establish rate w/ produced water down tbg @ 1 BPM. Displaced tbg w/ 20 bbls wtr, well on vac. Increased rate to 2 BPM on vac until 100 bbls wtr away, then bumped to 3 BPM @ 8 psi. Well back on vac shortly thereafter. Pumped total of 500 bbls ~55 deg F produced water. Finished at 3 BPM on vac. SI BJ pump. Open swab & RIH w/ PDS @ 100 fpm. Tag @ 4220' WLM, 4237' KB. Log up to 3950' WLM @ 30 fpm. Wait 1 hr. RIH to 4220' WLM, log up to 3950' WLM @ 30 fpm. Wait 1 hr. RIH to 4220' WLM, log up to 3950' WLM @ 30 fpm. POOH @ 100 fpm. Download PDS sonde good data. RD Pollard & BJ. Move BJ pump to barge landing for demob. PDS field prints indicate all injection staying in/below perfs @ 4154'-4166' KB. Injectivity & temperature surveys were witnessed by Thor Cutler & Tim Mayers w/ EPA.' MD Scale 18 4,111 4,129 4,147 4,165 4,183 4, 200 4,218 4, 236 4, 254 4, 272 4, 290 4, 308 4, 326 4, 344 4, 361 4, 379 4, 397 4,415 4,433 4,451 4,469 4,487 4, 505 4, 522 4, 540 4, 558 4, 576 4, 594 4,612 4,630 4,648 4,666 4, 683 4, 701 4, 719 4,737 4, 755 4,902 5,049 5,196 5, 344 5,491 5,638 5, 785 5, 932 6, 079 6,226 6, 374 6,521 6,668 6, 815 6,962 7,109 7,256 7,403 7,551 7,698 7,845 • ~ ~ ~ Conoco Philli ps BRU 232-09 API# 50-283-20075-00 Gas Producer Annulus Fluid: Diesel Sing/e Comp, t HeaterSt~ing Max Hole Angle: 53° @ 2,900' Spud Date 9/12/85 ~ Sect. 9, T12N, R10W, NW 1/4 RKB to Ground: 17.' Last Completion 11/25/85 ASP @ Beluga: 2,612,578; 313,467 RKB to SL: 109.' Schematic Rev. 8/li/09 CASING & TUBING Ho% by ]]E Description OD Btm. Weiaht Grade Thread Size Cement Conductor 36" 96' 1" Wall Welded Driven Surface Csg. 20" 394' 94. # H-40 Buttress 26 490sx "G"+6% gel +2% CaClz 133. # K-55 Buttress Full returns to surface Intermediate 13 3/8" 413' 72. # N-80 Buttress 17 1/2" 2340sx "G"+6% gel+2% Caq~ 13 3/8" 3,935' 68. # K-55 Buttress 17 1/2" Bump plug @ 2000# Prod. Casing 9 5/8 3,699' 40. # N-80 Buttress 12 1/4" 9 5/8 6,658' 43.5 # N-80 Buttress 12 1/4" Heater 5~^~~~~~ 2 3/8" 1,3~39' 4J ~ I'J ~8~1 Buttress Tubing 2 7/8" 4,205' 6.4 # N-80 Buttress Lbl. Top 1EWELRY& FISH Length ID OD Z 25' ~~~ 0,7~' Y 39H~ ~~~~N~;,_, ,_~~_ _ 1.15 X 1,38~ Mule Shoe Guide OJ5' a 25' XO Crossover 3-1/2" x 2-7/8" Buttress 2.84' 2.441" 4.21" b 489' "X" Nipple, Otis type 1.36' 2.313" 3.75" c 4,111' SS-XA Sliding Sleeve, Otis 3.26' 2.313" 3.77" d 4,115' Pkr Packer, Otis RH Hydraulic w/ 2, 2-7/8"x3.5" XOvers 6.87' 3.00" 8.58" e 4,153' Blast Joint, 8RD 19.29' 3.70" f 4,206' Shear Safety Joint, Brown, EUE 2.51' 2.441" 3.70" g 4,210' SS-XA Sliding Sleeve, Otis Open 11/22/85 3.22' 2313" 3.77" h •------ 4,214' ------------- Pkr ----------- Packer, Otis RH Hydraulic w/ 2, 2-7/8"x3.5" XOvers --------------------------------------------------------- 7.87' ------------ 3.00" -------------- 8.38" ------------- I 4,221' SS-XA Sliding Sleeve, Otis Open 3.25' 2.313" 3.77" j 4,224' "XN" Nipple, Otis type 1.26' 2.205" 3.75" k 4,226' Blast Joint, 8RD 25.' 3.70" L 4,251' Collet Catcher Sub, Otis 0.95' 2.40" 3.68" m 4,252' Wireline Re-entry Guide 0.55' 2.441" 4.29" 1 6,531' Drilled up retainer 10/30/85 Pressure Datum: Sterling 3450' SS: 4,299'MD Beluga 4000' SS: 4,900'MD PERFORATIONS~ FILL & PLUGS Net ~ncline Zone MD SS Depth Status Date SPF Ft. Anale WSO 4148' - 4150' 3322' 3324' Sqz & resqz., test to 1500 psi 10/85 4 35° A 4154' _ 4166' _ 3327'_: 3337'_DST 66: ~as, DST 6A_ Failed __ _ - ------ li/85 ___12 12' -------- 35° ------- A 4218' - 4237' 3381' - 3397' Plug set in XN, DST 6B: gas, DST 6A: Failed 05/97 12 19' 33° PBTD 4,256' 3,413' Halliburton EZSV @4256 with 100sx "G" cmt bel 11/85 33° WSO 4257' - 4258' 3414' - 3415' Sqz & resqz., test to 1500 psi 10/85 4 33° A 4264' - 4316' 3420' - 3465' Sqzd, DST #5: very low gas, water 11/85 5 33° WSO 4339' - 4340' 3485' - 3486' Sqz & resqz., test to 1500 psi 11/85 30° PLUG 4,428' 3,564' Halliburton EZSV @4428 with 100sx "G" cmt bel il/85 28° WSO 4518' - 4519' 3645' - 3645' Sqz & resqz., test to 1500 psi 11/85 25° B 4522' - 4534' 3648' - 3659' Sqzd, DST #4: 12 MCF @ 86#?, water, some sa li/85 8 25° C 4593' - 4630' 3713' - 3747' Sqzd, DST #4: 12 MCF @ 86#?, water, some sa 11/85 8 25° WSO 4648' - 4649' 3764' - 3765' Cmt sqz w/ 63 sx, test to 1500 psi 10/85 4 23° PLUG 4,690' 3,802' Halliburton EZSV @4690 with 100sx cmt below. 11/85 D 4734' - 4758' 3844' - 3866' Sqzd, DST #3A-tool plugging, DST #3B: sand, v 11/85 8 21° PLUG 4,820' 3,924' EZSV @4820 with 100sx cmt below. 11/85 D 4902' - 4946' 4002' - 4044' Sqzd, DST #2: gas, LPR tool leaked, high CI-, ar 11/85 8 19° WSO 4950' - 4951' 4047' - 4048' Sqz w/ 100sx, test failed 10/85 4 19° PLUG 5,835' 4,911' Packer of unknown type, sqz SOOsx li/85 . F 5868' - 5947' S639' - 5641' DST #1: very weak flow, no gas, sqzd 100sx 11/85 1 8° Y FC 6564' - 6566' Csg shoe @ 6658' l0/85 ~ TAGS 5/20/97 4224'RKB Set PXX Plug in nipple 10/6/96 4z96'WLM 1.5" bailer ~ May 97 Set PXX plug in XN nipple after retesting lower A. ~ occ-9~ Unloaded upper A to tank. Made 1.6-2.8 MMscfd & 200-500 BWPD with significant sand production. y Aug-98 Pull wellhouse for use at 212-35T = May-OS SITP and casing pressure both 0 psig BRU 232-09 (PTD 1841360) ~'IA Regg, James B (DOA) • Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, March 24, 2009 3:30 PM ~~ ,?~Z~~2~.~.7~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA) Cc: Knight, Mike G; Copoulos, Art E Subject: BRU 232-09 (PTD 1841360) MITIA Attachments: MIT BRU 232-09 03-18-09.x1s Tom, Jim, Bob Attached is the MIT form for a diagnostic MITIA done down in Beluga. Please let me know if you have any questions. ~ ~~- «MIT BRU 232-09 03-18-09.x1s» ~~; ~~~ -~-~ ~~-~~ T Brent Rogers/Martin Walters ~ Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 3/24/2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.Fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. `CCc~°~r~ ~~Z~Qj~Z~'J 1 FIELD /UNIT /PAD: Beluga / BRU / 232-09 DATE: 03/18/09 OPERATOR REP: Ives - AES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 232-09 Type Inj. N TVD 3,403' Tubin 0 0 0 0 Interval O P.T.D. 1841360 T pe test P Test psi 1500 Casin 1,540 2,530 2,530 ,530 P/F P Notes: Diagnostic MITIA for Class 1 disposal application OA 0 0 0 0 Well T pe Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. 7VD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Wate r TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 2009-031 8_MIT_BRU_232-09.x1s ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Mark H Wittow Preston Gates & Ellis 420 L St Ste 400 Anchorage, AK 99501-1937 Re: Z-Energy Spacing Exception Request Dear Mr Wittow~ In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit . 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. Chairman ~~ ~ .... jo/rpc~z~nergy ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 D A Grove, BRU/Kup Staff Mgr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Grove: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. David W Johnston Chairman ~.~_...~ jo/rpc~z~nergy ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Rosanne M Jacobsen, Atty ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Jacobsen: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit' 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insuffiCient. _Da. v.id W Jol~nston \ ,-'- ~ Chairman ~ jo/rpc~z-energy ALASKA OIL AND GAS · CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR ~._ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Paul Craig, President Z-Energy Inc 2900 Boniface Pkwy ~10 Anchorage, AK 99504-3132 Re: Z-Energy Spacing Exception Request Dear Mr Craig: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hOle well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission Dav!d w Johnston \ -~ ~ Chairman ~ jo/rpc~z-energy SOUiHCENTRAL REGIONAL OFFICE 360~ C STRET~ SUIT~ 1350 ANC..ORAG~., AK 99503 . 1988 May 5, Mr. Pete Hellstrom ~-I~>~ ARCO Alaska, Inc. P.O. Box 10360 Anchorage, AK 99510-0360 RE: Beluga Reserve Pits, Final Closure: BRU 232-9 = 8423-BA013 and BRU 211-3 & 224-34 = 8~23-BA005 Dear Mr. Hellstrom: Thank you for sending me the photographs cf the closed reserve pits at Beluga. I would like to point out that there was an error in the permit identification number of pit BRU 211-3 on the photographs. Pit BRU 211-3 was assigned permit number 8~23-BA005 and not 8~23-BA005 as indicated on the photos. Please make these corrections on your copies to prevent future confusion. Again, thank you for the final closure photographs of the reserve pits. Sincerely, He~y Friedman Regional Solid Waste Program Manager HF:h CC~ Leste~.Leatherberry, ADEC - Scldotna ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering TRANSMITTAL COMPANY: ~ ~ ~ ~_~ COMPANY' DATE' ~ f~ ~ J~'~ WELL NAME' Transmitted herewith are the following° PLEASE NOTE' BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy Receipt Acknowledgment' Return Receipt to: A1asi.',a Oil & Gas Oons. · ARCO Alaska, Inc. AT.TN' dudy Boegier AT0:$79 Po§~ Office Box 100360 Anchgrage, AK 99510 --~ Precision Wireline P.O. Box 3905 ~ Soldotna, AK 99669 TIME DEPTH PRESSU RE TEMP. Field I.D.~~..~,.~(,.,~,. ~,,G"¢/,.~. I0~',~'~_... ~~~' I~~. j~ ~ .{ Well I.D. ~ Z-~ C~ %~'Gq , . ~o:~ ~0o ~~. ~ ~; 03 Tubing PSI ~ ~~;~ ~ O001 ~ ~; ~ ~.~ Casing PSI ~ ~ t ~ ~0 ~ 1%~0. ~ 0 ~. ~0 Depth of Instrument ~~' 0'. ~5 ~ leO' f qU%,q % ~ %, ~ c~~ ~ " Date No. 2 t-~_~ Inst No. 1 ~~q~ Inst No. 2 ~%-%~ At Depth (Date/Time) ~% ~ [~]¢~ Off Depth (Dateffime) ¢Z~/¢~ ~ q', ~ Shut in (Date~ime) ~--~ Precision Wireline P.O. Box 3905 ~ Soldotna, AK 99669 TIME DEPTH PRESSU RE TEMP. Company ~ ~¢~.¢~ Casing PSI Depth of Instrument Tu ,n Date No. 1 Date No. 2 ~_~~ Inst No. 1 Inst No. 2 ~~ At Depth (Date/Time) Off Depth (Date/Time) Shut in (Date/Time) ~8~ - Remarks: -, Cook ARCO ALASKA, INC. Inlet/New Ventures TRANSNITTAL Engineering TO: C e~~;~~'~-) FROM: COMPANY- /ZIc-~P~C C COMPANY. DATE: ,.~.- ~ -~°7 WELL NAME: ./q- o Transmitted herewith are the following' PLEASE NOTE' BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy RECEIVED Rece i pt Acknowledgment' MAR- 4 1987 /~//~ ~~' ''~ Alaska °il & Gas c°ns' c°mmlssl°rl.~._~..~ ~.,~...¢~ / : Return Receipt to- ARCO Alaska, Inc. ATTN' Judy Boegler AT0.-579 Po§~ Office Box 100360 Anchorage, AK 99510 ' la. TEST: STATE OF ALASKA .7~.. .. //'- ' ~_ ..-, , t~ cCb ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT INITIAL [] lb. TYPE TEST STABILIZED [] NON STABI LIZED/~} ANNUAL [] MULTIPOINT [] CONSTANT TxlME SPECIAL [] OTHER ISOCHRONAL 2. Name of OPerator 7. Permit No. ARCO Alaska, Inc. 84-0136 3. Address P.O.-'Bex 100360, Anchora.qe, AK 99510-0360 4. Location of Well Surface 1814' E & 302' S of NW Corner Section 9, TI2N, RIOE, S.B.&M Top of Producing Interval 3045' E & 1812' S of NW Corner Section 9, TI2N, RIOE, S.B.&M 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease Designation and Serial No. G.L. = 91', K.B. = 109' [ ADL - 17592(BHL); A-O29656(Sur 12. Completion Date 113. Total Depth 114. Plugback T.D. 11-25-85 .I 7992 I 4256 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. 9 5/8 43.5 8. 755 6658 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 2 7/8 6.5 2. 441 42:52 18. Packer'set at ft.4115; 4213 119' GOR cf/bbl'-- t20]PI Liquid HydrOcarbOns f · o . .X/.~-d~fb~e r vo, r~T e m p. F. Csg. [] ":': 73°F ¢/ 4200' 22. Producing thru: Tbg. I~ 8. APl Number 5o- 283-20075 9. Unit or Lease Name Beluaa Riv~.r Ilnit 10. Well ~umber RRU 232-9 11. Field and Pool Beluga River - Sterling ace) I15. Type Completion (Describe) Sinale String Ga~ Pr~d,Jcer Perforations: From To 4154 - 4166 4218 - 4237 21. Specific Gravity Flowing fluid (G) .556 Mean Annual Temp. o F. Barometric Pressure (Pa), psia 33°F 14.65psia 24. Flow Data Tubing Data Casing Data Prover Meter ~Meter Duration of Pressure Diff. Iemp. Pressure Temp. Pressure Temp. Line X Qr, ifice Flow ...K haT8 psig Read ing o F. psi~ o F. psig o F. No. Size (in.) b~ze ~n.r hlJ Hr. 1. 4. 026 x 2.5 845 3.0 64 1308 70 N/A N/A 2 2. 4.026 x 2.5 850 4.1 68 1281¢ 71 " " 2 3. 4.026 x 2.5 845 15.45 [ 69 1244 69 " " 2¢ 4. 4.026 x 2.5 84516 5 ! 66 1202 68 " " 2 ' r Basic Coefficient ! Stat i c Flow Temp. Gravity Super Comp. (24-Hour) hu pu Read ing Factor Factor t Factor Rate of Flow Ft Fg! Fpv Q, Mcfd No. Fb or Fp * PIJ 1. 148.89 19,95 6.65 .996 I .341 . I .064 422 I 2. I 148.89 27.47 6.7 ~ .992 i I. 341 ! I. 064 5789 3. , 148.89 36.24 6.65 .992 4. 148.89 43.23 6 .65 . 994 (l~ :'.34][ ~ "V~ ~"'1L/~064 9129 * Includes Meter Constan+ (M) = , , ,,v , uv~.~,.~ i- i,~../ I ~/i UUll.: i C]ll i -- . ~'"/ '~ */~ ~ AI&~I<C 0U ~ ~,,~:~ O0~S, ~:~;~eparator for Flowing Temperature ..... ?, ...... .~, Gas Fluid No. ~ ' Gg G ~. I .51 524 I .53 .885 2. I ,55 528 I ,54 ,884 3. 1.31 529 1.54 .885 Critical Pressure 673 psi 4, I , 31 526 I , 53 ,883 Critical Temperature 3430 R Form 10-421 CONTINUED ON REVERSE SIDE Submit in duplicate Rev. 7-1-80 . Pc I ~4-~ Pc2 pf 1467 Pr2 2 152. I '1 No. Pt Pt2 Pc2 Pt2 Pw pw2 Pc2 - Pw2 Ps I Ps2 x l0 Pr2 . Ps2wl O 1. 1456 2119.9 32.2 2. 1450 2102.5 49.6 3. 1442 2079.4 72.7 4. 1436 2062, I 90.0 5. 25. 0.743 AOF (Mcfd) 95,000 n Remarks' Gas composition from offset producer, Bottom hole pressures obtained at settin9 depth - of 4200.' MD (34.77,' TVD) MCFD/p I hereby:certify that the foregoing is tr~/~ncl correct totl~e oest OTm~/ kneow~ecl~ 879 s ia2 / / ~") '// Date ~/~/:-/r'~'~2,~, ~ AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure .. opposite the producing face were reduced to zero Psia. Basic orifice factor Mcfd/-x/hwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility. factor=-x/1/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air=1.000), dimenSionless Specific Gravity of separator gas (air=l .00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back--pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual Of Back-Pressure Testing Of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 BRU 232-9 Four Point Back Pressure Test 1/28-29/87 ~1 1( I ~ 3 '1 9 z- 4 __ .~ . __ 10 1,000 4 5 6 7 8 910 2 $ 4 5 6 7 8 9]0 ~o,ooo ' -~0~'~ :Q(MCFD) 3 4 5 6 7 8 9]0 ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering TRANSHITTAL TO' COMPAItY- DATE' ,b ~ -~ FROM: COMPANY: WELL NAME Transmitted 'herewith are the following- PLEASE NOTE' BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy · Date: Recei pt Acknowledgment ~a~a Oil & Gas Oons. Commission Anchorage Return Receipt to: ARCO Alaska, Inc. ATTN: Judy Boegler AT0~579 Po~ Office Box 100360 Anchorage, AK 99510 Form 3160--5 (November 1983) (Formerly 9--331) UNI~D STATES SuB,,IT IN ~a,P,. .... ~. (Other instructions re- DEPARTMEk OF THE INTERIOR verse~Jde) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) Form approved. BUdget Bureau No. 1004--0135 Expires_ August 31, 1985 5. LgAfig DESIGNATION AND BELIAL NO, ADI 17658 6. IF INDIAN, ALI~)TTEI OR TilBI NAME OIL ~] GAS ~] WELL WELL OTI~ER NAME OF OPERATOR ARCO Alaska, Inc. 3. ADDRESS OF OPERATOR P.O. Box 100360, Anchorage, AK 99510-0360 LOCATION OF %VELL (Report location clearly and in accordance with any State requirements.* See also.space 17 below.) At surface 1814' E. 302' S. T12N, R10W, SB&M' of the NW corner of Section 9 14. PEBMIT NO. I 15. ELEVATIONS (Show whether DF, RT, OR, etg.) 84-136 G.L. = 91' K.B. = 109' UNIT AGREEMINT NAME Beluga River Unit 8. fARM OR LEASE NAME 9. WBI[~L NO. BRU 232-9 10. rllgLD AND FOOL~ OR WILDCAT Beluga River - Sterling 11. file., T., R., M., Oa ~,K. ~ Sec 9, T12N, R10W, SB&M 12, ~UNTY OR P~ISH] 13. 8TATI Kenai [ AK 16. Check Ap0ropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I [ PULL OR ALTER CASING ~'RACTURE TREAT MULTIPLE COMPI.ETE SHOOT OR ACIDIZE ABANDONs REPAIR-WELL CHANGE PLANS (Other) (NOTE: Report results of multiple completion on Well ion Completion or Reco~apletion Report and L~g form.) I7. DESCRIP. E PROPOSED OR COMPLETED OPERATION~ (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any nentPr°P°s~to thisW°rk'work.)If* well is directionaJly drilled, give subsurface locations and measured and true vertical depths for all markers and ~ones peril- This is to notify that BRU 232-9 commenced production January 18, 1987. 18. I hereby certif7 .that the foreggiag isleT'de and correct SIGHED ... . TITLE (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: · ~ska Oil & Gas Oort$. Commission *See Instructions on Reverse Side ~cflorage Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering TRANSMITTAL TO~ B-warn ~M~ 5 FROM. COMPANY' ~ 0 ~ C 0 COMPANY- DATE: / ~_-/~_- ~/~ WELL NAME' Transmitted herewith are the following- PLEASE NOTE' BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy Receipt Acknowledgment: Return Receipt to' ARCO Alaska Inc ATTN' Jud~ Boeg~ ~'~T0~579 Po~t Off~ce Box 1003~0 Anchorage. AK 99510 ARCO Alaska, Inc. Post Office'~ .x 100360 Anchorage, Alaska 99510-0360 Tele n Mr. Bill MacClarence Alaska Department of Environmental Conservation #37 "E" Street, Second Floor Anchorage, AK 99701 RE: Gas Well Testing, Beluga River Field Dear Mr. MacCiarence: As discussed during our October 22, 1986 telephone conversation, ARCO Alaska~ Inc. has assumed responsibility for operation of both the Swanson River (including the Soldotna Creek Unit) and Beluga River fields. As part of this new responsibility, we will be conducting equipment and well testing to verify the..status of the equipment that is located in both fields. The specific reason for my call was to discuss and provide notification of four pianned gas well tests. During our conversation~ I indicated that these tests could began as early as Friday, October 24, 1986. The open burning is now scheduled to begin on or after Wednesday, October 29, 1986 and will be conducted at various flowing rates with sufficient volume to clean up any brine or water that may be in the wells. After the wells have been cleaned up, flowing will continue in order to gather well rate/capacity information. The flow duration during clean up and testing is unknown and is dependent on the producing capacity of each well. The estimated flow period is six to twelve hours with an estimated maximum of 2q hours. The maximum expected producing rate is 2 MM scf/d. Each well clean up/test could require two to four days to complete. The estimated Btu/scl is 1000. After the clean up and testing, the wells will be gas producers for the Beluga River field. .- ~ The wells to be tested are: BRU 232-9 BRU 22q-3# BRU 211-3 BRU 2ql3q Because these are gas wells, the open burning should not produce black smoke. Should black smoke occur in excess of 20% capacity, the flow will be pinched back or the well will be shut in as needed. This planned activity is regulated by 175 AAC 50.030 and because black smoke will not be produced a permit is not required. This letter and the attached map are sent for your information. Should you have a question, please cai! me at 26.5-6176. Sincerely Peter N. Hellstrom Sr. Environmental Coordinator PNH/pw Attachment cc: C. Chatterton, AOGCC OCT 3 1 1986 0il & Gas Cons. Commission /~chorage ~-fiCO A.asKa :~c -s a C~ubs'drary oi Al'anHcR,c':,t~-: cCornpar~ ! 8ELUGA RIVER BRIDGE PRETTY CRE~ TI3N._,~_.IOW.~R __ _ _ i i · ! ! I ! i i o 2Z4-13 -- -- _ BELUGA ~. z: RI VER UNIT i PRETTY 6 OCT 3 t 1966 Oil & GaS cons. Commission Anchorage CREE .._~r~BRU 211-3 & 224-34 i I STATE OF ALASKA ' AL/~ .,\ OIL AND GAS CONSERVATION CC ~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Operation shutdown C Stimulate Alter Casing ~ Other 2. Name of Operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, .Anchorage, AK 99510 4. Location of well at surface 1814' E & 392' S of NW Cor. Sec. 9, 12N, 10W, SB&M At top of productive interval 3045' E & 1812'8 of NW Cor. Sec. 9, 12N, 10W, SB&M At effective depth 3065' E & 1863' S of NW Cor. Sec. 9, 12N, 10W, SB&M At total depth 3175' E & 2331' S of NW Cor. Sec. 9, 12N, 10W, SB&M 5. Datum elevation (DF or KB) K.B. = 109 6. Unit or Property name Beluga River Unit 7. Well number BRU 232-9 8. Approval number 9. APl number 50-- 283-20075 10. Pool Sterling Feet 11. Present well condition summary Total depth: - measured 7992 feet true vertical 7179 feet Effective depth: measured 42,56 feet true vertical 3524 feet Casing Length Size Cemented Structural Conductor 65' 30" Driven Surface 366' 20" 490 Sks Intermediate 3908' 13 3/8" 2340 Sks Production 6634' 9 5/8" 1100 Sks Liner Perforation depth: measured 4154'-4166' 4218'-4237' Plugs (measured) See Attached Junk (measured) Measured depth 96' 394' 3935' 6658' true vertical 3438'-3448 3492'-3508' Tubing (size, grade and measured depth) 2 7/8" 6.5# N-80 4252' 2 3/8" 4.6# N-80 1389' Packers and SSSV (type and measured depth) Otis: RH 4115', 4213' True Vertical depth 96' 394' 3269' 5880' 12. Stimulation or cement squeeze summary See Attached Intervals treated (measured) Treatment description including volumes used and final pressure 13. NA Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~¢.~--~-- Title Acting Area Operations Supe rint endentDate/f//d/7-~ Form 10-404 ~Re~. '12-~-85 Submit in Duplicate Drilling Morning Report CC-Morn. Well ~0 23~ 9 Ch Code Field Dam Page Depth ~ MD ~l~ TVD ( ~ ~& PBTD) Proposed TD ~0~/ MD 7~ TVD .~ DOL DFS Hrs Total Rm Hrs ~ ~ Days Hrs. ~ ~ Days . ~ Torque Drag Rot Wt P/U Wz Slack Off Wt L~s~ c~,,~ s,z~ ~/g s.~ ~ G ~ g MD S ~ TVD S,o, ~,~ EMW .~ Cum Rot Hrs ~ Depth Worst Wear % Rem ~ On C~s ng '7 ~ ]Since Las~ Cai Liner Set ~ MD TVD - TOP 0 MD / TVD Wt CO Type FV PV ~ Pm Pf/Mf CL CA ~me El Stab Wt Material Gel Caust,c bg gait CaCI~ Ither ~ ~vg Dnlhng ~ax Onlhng Corm Trip ~p Chlorides Remarks M D Angle D~rect~on TVD/~ Coordinates V S O LS No S~ze type / Ser No Jets In Out Feet Hrs WOB RPM T B Fotal Length (H.W.D.P.: ) Consists of . Pu~ bner Stroke SPM Pressure GPM Jet Vel Ann Vel Bit HHP Pump HHP Hfs O~erat~ons Cavenn~ 24 Hours [agm~ ~ ~,~m~ht $ Daily Mud . Cum Mud /~Y~g5 Da,ly Tangible _ Cum Tanglble38z~. Daily Well Drill H~O Pat H~O Fuel Bulk Wt Bulk Cmt JTotal Appr R,g ~~e~'~ S~ RlgPh°ne~0'~' 7~"~7~ grdhngRe,p~ ~~ Acc,dents GO 12H (CD 3 851 Printed m U S A CC-Morn. Drilling Morning Report Proposed TO Depth ~q~ MD '7 / S~ TVD ( ~ ~ PBTD) ~ ~ / MD '7~ TVD DOL DFS Hrs Total Rot Hrs ~3 Days -- Hrs. ~ 7 Oays - . Torque ~ Drag ~ Rot Wt _ P/U Wt _ Slack Off Wt _ Last Cas,rig S,,, ~ ~73 Set ~ ~ ~ MD ~ TVD Shoe Test ~ EMW '.urn Rot Hrs ~ Depth Worst Wear % Rem Liner ~ Set ~ - MD TVD - TOP ~ - MD ~ TVD wt CO Type FV PV YP 3el WL HT HP FC Sohds % 0~i % Sand MBT PH ~m Pf/Mf CL iCA Ex Lime El Stab ~t Material Gel Caustic bg CIs /~" Salt CaCI~ Avg Onlhng Max Dnlhng Conn Trip ~ndes Remarks M D Angle D~rect~on TVD ~ ~ Coordinates V S DLS No S~ze Type // Ser No Jets In Out Feet Hrs WeB RPM T B G . Total Lengzh ~~ (,.W.O.,.: ) Cons,sts of / Liner Stroke SPM Pressure GPM Jet Vel Ann Vel 8~t HHP Pump HHP Pump / Hfs Operations Covering 24 Hours End,ng ~ M~dmghI Da~ly Well ...... Cum Well Da,ly Mud -_ Cum Mud /~43~ Da,ly Tang,ble ~ Cum Tang,ble ~~ I S ~7~ H~O ~ Pm H~O Fuel Bulk Wt Bulk Cm~ jTot, J Appr GO 1211 (CD 3 851 Pnnted ~n U S A cc..o,.. Drilling Morning Report ~ DOL DFS Tomm ~ol HFS · ~ ~ Days -- Hrs. Last Cas,no S,ze ~ ~/~ Set 0 ~GS~' MD ~ ~0~ TVD Shoe Test _ EMW ._ Depth Worst Wear % Rem ~ CUmon CaslngR°t Hrs ~/~ ]Stance Last Cai Lmer -- Set ~ -- MD ~ TVD- TOP ~ -- MD TVD Wt CO Type FV PV YP Gel WL HT HP FC Sohds % Od ~ MBT PH ~ Pm Pf/Mf CL CA ~ Ex brae El Stab ~ /Caustic bg ~ ' Salt CaCI~ Wt Materml Gel Other Avg Dnmlmng Max Drmlhng Corm Trip ~ Trmp Chlormdes Remarks M O Anole Dmrectmon ~ Coordmnales V S D LS No Smze Ty~~ Ser No Jets In Out Feet Hfs WOB RPM T B G . P~ Linnet Stroke SPM Pressure GPM Jet Vel Ann Vel Bmr HHP Pump HHP / Hfs Operatmons Covenng 24 Hours Endmng ~ M~dnmght ~ Ia,my Mud --. Cum Mud /O ~ g S~ Da,my Tangible Dr,il H,O _ Pot H~O - Fuel RIg~/~(~ ~ Rig Phone ~0 7 - 7~ - ~ 7~ ~ grdlmng Rep AbACi GO 1211 lCD 3 85) Primed iff U S A CC-Morn, Drilling Morning Report Depth 7~ MO 7j ~$ TVD ( ff)~ ~TD} Pr°posedTD ~.5-t MD ~Oq TVD .~ DOL DFS Hfs Total Ro~ Hfs 81Days Hrs. 7 ~ Days · ~ ~V ~ ~ Torque Drag Rat WT P/U Wt Slack Off WT Last Casing Size ~ Cum Rot Hrs Depth Worst Wear % Rem '~ On C,s~ng Js~n~e L~st Cai bner Set ~ MD TVD - TOP ~ MD TVD ~t CO Type FV PV YP Gel WL HT-HP FC Sol,ds % Od % Sand MBT PH ~ Pm Pf/M[ CL CA Ex L,me El Stab WT Mater,al Gel Caustic LiD CIs Salt CaCI~ Other Avg gnll~ng Max Drilling Conn Trip Trip Chlorides Remarks M D Angle g,recTmn TVD Coordinates V S g LS No S~ze Type Ser No Jets In Out Feet Hrs WOB RPM T B G Total Length (H.W.D.P.: ) Consists of Pump bner Stroke SPM Pressure GPM Jet Vel Ann Vel B~t HHP Pump HHP . Hrs Operatmns Covering 24 Hours Ending ~ M~dmght ~ Daffy Well ~ Cum Well Drill H~O ~ Pot H~O ~ Fuel ~ Bulk Wt Bulk Cmt Jl°tai~App~/¥~,. ~ ~0~/ - - GO 1211 (CD 3 85i Pnnted in U S A CC-Morn. ~' '~ Drilling Morning Report DOL - DFS Hrs Totem Rot Hfs ~0 Days Hrs. ~ '/ Days . ~/ Torque Drag Rot Wt P/U Wt Slack Off Wt 5~ ~ ~" ~ Shoe Tes~ Last Cas,ng S,ze ~ -~/~ Set ~ J Z~_~ ~ MD~j ~ ~ 0 TVD EMW Cum Rot Hrs Depth Worst Wear % Rem On Casmg IS,nee Last Cai Lmner Set ~ MD TVD - TOP ~ MD TVD ~t CO T~po FV, PV Gel WL HT HP FC Solids % Omi % Sand MBT PH Pm P~/Mf CL CA Ex brae El STab Wt Material Gel Caustic Ug Cms Salt CaCI~ Ither Avg Drmlhng Max Onmhng Corm Tr~p Trip Chlorides Remarks M D Angle Direction TVD Coordinates V S DLS No S~ze Type Set No Jets In Out Feet Hfs WOB RPM T B G lotal length {H.~.D.P.: ) ~ons~sts of Pump Liner Stroke SPM Pressure GPM Jet Vel Ann Vel Bit HHP Pump HHP Hfs Operations Covering 24 Hours Ending ~ M~dnmght . / Daffy Mud ~ Cum Mud/~.~ / ~' ~ Daily Tangible Cum Tangible [Oamly~]z~ ~ ~(~~ell .-, .. / Cum~.Well ~ H~O Pot H~O Fuel Bulk Wt Bulk Cmt ITotal Appr z Dnlhng Rep " . Accidents GO 1211 lCD 3 85) Primed in U $ A CC-Morn. '""-~" ~ Drilling Morning Report Oiv~s~on ~ Proposed TD Oep[h 7~ ~ ~ MD 71 ~ '3 TVD ( 7,2~ PBTD) ~0~/ MD 7~? TVD OOL gFS Hrs Tmal Rot H~s Torque Drag Rot Wt P/U Wt Slack Off Last Cas,ng S,ze ~_~g Set~ ~ ~' ~ MD ~0 TVD Shoe Test EMW Cum Rot Hrs Deplh Worst Wear % Rem On Cas*ng IS~nce Lasl Cai brier 8et $ M~ l~a - lOP $ MC 1~ Wt CO Type FV PV YP Gel WL HT-HP FC Sohds ~/o Od % Sand MBT PH Pm PffMf CL CA Ex brae ~l Stab Wt Material Gel Causuc bg CIs Salt :aCl~ Other [~ Cdhn~ ~ax Crdhn~ Corm ln~ lno Chlorides ~omarks M O Angle O~rectmn TVD Coordinates V S BLS No S~ze Type Ser No Jets In Out Feet Hrs WOB RPM T B Total keng[h (H.W.D.P.: ) Consists of ~ump bner Stroke SPM Pressure GPM Jet Vd Ann Vel B~I HHP Pump HHP ~rs O~erat~ons Coverm~ 24 Hours ~nOm~ ~ Mdm~ht ~,~ 5L-,'"~,;~ ~(.E~,~ ~ H,O Pot H~O ~' &/~ BFuel Bulk Wt Bulk q~3, 8q 7~ / GO Printed ~n U S A ,,.,o,,. Drilling Morning Report Rag,on D,v,s,on ~ L¢,¢~. [~_,,4 W~l~¢~.) ~'~--~ Ch Code F~ Da~e -- ~ Page ' Proposed TO ~ Depth ~ ~ MD ~/~ TVD ( z/~ ~( ~ °PBTD) ~0 ¢~'/ MD ~ TVD DOL DFS 7~ Days P/U Wt · Wt Torque ~ ~ Days Drag Hrs. Roi Slack Off Wt LastCas,ngS,ze ~ ~¢ Set~ dp& ~ MO ~0 TVD Shoe Tes[ Cum Rm Hfs Depth Wars[ Wear % Rem On Casing Ismce Last Cai bner Set ~ MD TVD - TOP ~ MD TVD Wt CO Type FV PV YP Gel WL HT HP FC Sohds % Od % Sand MST PH Pm Pf/Mf CL CA Ex brae El Stab Wt Material Gel Caustic Ug CIs Salt O~her Aug Ordhng Max Dnlhng Conn Trip Trip Chlorides Remarks M D Angle D~rect~on TVD Coordinates V S BLS No S~ze Type Sar No Jets In Out Feet Hfs WOB RPM T 8 O Total Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel Ann Vel B~t HHP Pump HHP Hrs Operations Covenng 24 Hours Ending ~ M~dmghI Daily Tan¢le Cum Tan¢le Dady W~)0 Cum Well H~O Poi H,O ~ Fuel Bulk Wt Bulk CmtI ~2~%/L/o~lT°tal App~ ~ ~ ~ . R,g.~ ~ R,g Ph~e. Dr,lhng Rep , ¢ Acc,dents 60-1211 lCD 3 Prmled ~n U S A CC-Morn. Drilling Morning Report Depth ~ MD ~/ ~ TVD ( ~~ P~D) Pr°p°sedTD~o~/ MD 2~ TVD DOL OFS Hrs Total Rot H~s ? ~ Days Hrs. 7 1 Days . Torque Drag Rot Wt P/U Wt Slack Off Lasl Cas,ng Size ~ ~ Set ~ ~ O S' ~ MD ~' ~ ~0 TVO Shoe Tes, EMW Cum Rot Hfs Oeplh Worst Wear % Rem On Casing ]Since Last Cai Uner Set ~ MD TVD - TOP ~ MD TVD ~el WL HT HP FO Sohds % Od % Sand M~T PH ~m Pf/Mf / CL~ ~ ~ CA ExL~me EiStab ~t Material Gel Caustic Ug ~ CIs Salt CaCI~ Other Avg Drdhng Max Dnlhng Corm Trip Trip Chlorides Remarks M D Angle D~rect~on TVD Coordinates V S D LS No S~ze Type Ser No Jets In Out Feel Hrs WOB RPM T 8 G Total Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel Ann Vel Bd HHP Pump HHP Hfs Operations Covering 24 Hours Ending ~ M~dmghz ~all~ Mud~ Cum Mud~ ~ Dally Tangible Cum Tangible Dall~ Well~ [~lCum Well H,O Po, Fuel Bulk Bulk Acc~denls~ GO 1211 Printed ~n U S A CC-Morn. Drilling Morning Report Weft Ch Code hel Dar / ._J Page ~ Proposed TD Depth ") ~a~. MD "7/ ~' ~ TVD ( ~~ PBTD) ~O~l MD 7~ TVD ~ DOL DFS Total RD' Hfs '~ 7 ~ Days Hrs. ~ ~ Days Hrs. ~ ~ Torque Drag Rot Wt P/U W~ Slack Off Wt Las~ Cas,nD S,ze ~ ~/~ Set ~ (~ ~ ~ z MD ~~ TVD Shoe Test EMW .~ Cum Rot Hfs Depth Worst Wear % Rem ~ On Casing ]S~nce Last Cai Lmer Set ~ MD TVD - TOP ~ MD TVD Wt CO ~ . FV PV YP Gel 9, ~ WL ~ ~-H" FC Type ~/10~S~ ~'~0~ ~% ~Sand MBT~ 'H ~ Pm Pf/Mf / CL~ ~ ~ CA Exbme ~tStab Wt Material Gel Caustic Ug / CIs Salt ~aCl~ Other Avg Drdl~ng Max Drdhng Conn Trip Trip Chlordes Remarks M D Angle D~recz~on TVD Coordinates V S DLS No Size Type Ser No Jms In Out Feet Hfs WOB RPM T B G Rump Liner Stroke SVM Pressu[e GPM Jet Vel Ann Vel Bit HHV Pump HHP Hfs Operatms Covenng 24 Hours Ending ~ M~dnlght Dml~ Mud ~ Cum Mud Dady Tan¢le Cum Tan¢le Daffy Well Cum Well ' Fuel Bulk Wt Bulk Cm, JTot~Ap~ Dr,Il H,O Pot H,O R,g P~ . Or,Ii,nD Rep / · Acc,dents' GO 1211 l£D 3 Printed ,n U S A cc.,o,,. Drilling Morning Report g,pth ~ MO )1 ~ TVD ( ~'0 PDT~ ProposedTD ~O~-t MD ~0~ TVD DOL DFS Hrs Total Rm Hrs )~ Days Hrs. Torque Drag Rot Wt P/U Wt Slack Off WI Last Cas,ng S,ze ~ Set~ ~~' MD ~'ff~O TVD Shoe Test EMW Cum Rot Hrs Depth Worst Wear % Rem On Casing JS~nce Last Cai [mer Gel WL HI HP FC Sohds Pm Pf/M~ CL ~0 ~ ~ CA Exbme 3Stab Wt Maenal Gel Caustic Ug CIs Salt }aCl~ Other Avg Dnlhng Max Dnlhng Corm Trip Tnp Chlondes Remarks M D Angle D~recuon No S~ze Type Ser No Jets In Out Feet Hfs WOB RPM T B G Total Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel Ann Vel B~I HHP Pump HHP Hrs Operations Covering 24 Hours Ending ~ M~dmght ~ K,LL Cum Mud Daily Tangible Cum Tangible Daily Well Cum Well H~O Pot HzO ' Fuel Bulk Wt Bulk Cm~,~ JTot~App~ ' Rig Phone Dr,Il,rig ~ Pnnted m U S A ,cc.,o,,. Drilling Morning Report Company ~__,.Jq¢i,J/"OrJU.S'A k/zs~¢r~ F,e~d Al/~ We Ch Code Regmn D~ws]on ~ Proposed TD ~ ~ Depzh ~ ~ MD ~ ~ TVD ( ~ PBTD) ~/ MD ~ TVD DOL ~ Days Hrs. ~ Days DFS Hrs. Tmal Rm Hrs ~ ~ Torque D[ag - Rm W~ -- P/U Wz - Slack O~W~ Cas,ng Size 9 ~'~ i, i · Shoe Tesl . Set @ ~, .~'~ MD ..~"~..~"0 TVO EMW Cum Ret Hrs Oepth Worst Wear % Rem On Camng - ISince Lest Cai ' ' Liner '" Set @ MD ' TVD - TOP @ ' MD ' TVD C 0 .,~'~?1~0 Type /~/~::~ ~-~/ ~:~/"'1/"~ FV P V Y P ~'--/ ~ I Gel Pm WL HT-HP FC Sohds % Od % Sand MBT PH //. ~ Pf/Mf / ilLg ilAs Ex bme El Stab Gel Caustic ~ O~, ~ Salt CaCl~ Matenal Drilling Max Dnlhng M D Angle D~rectmn TVD Corm Trip Trip Chlorides Remarks Coordinates VS Type Ser No In Out Feet Length (H.W.D.P.: ) Consists of SPM ~P Pressure GPM Jet Vel Ann Vel B~t HHP Pump HHP Operatmns Covenng 24 Hours Ending @ M]dmght le. ^; ~ A ; Mud /.5=~ ~ Cum Mud /~ ~ ~ ~3 Dady Tang,hie - Pot H~O - Fuel- Cum Tanmble Dmly Well Cum Well Bulk Wt Bulk Cmt.~c~ ~0 JTotal A}~ Or,lhng Rep ~0~ Acc,denis ~/~ 60 1211 (CD 3 851 Pnnred m U S A ~CC*Morn. Drilling Morning Report Company Well Depth '799Z usa MD DOL 74- Days Torque Ch Code Regmn 71~3 TVD ( held ~%luq,~ ~'.,~' Date ,,hs/a.r Pago z of z PB~D) Proposed TO ~0~/ ' MD 7Z~9 TVD Hrs Total Rot Hfs Drag Hrs. DFS Rot Wt P/U Wt. Slack Off ' Shoe Test _q'~.~O TVD ' Depth Wors'[ Wear % Rem Casing Size Cum Rot Hrs On Casing Set @ MD Is,nee Last Cai EMW bner Set @ MD TVD- TOP @ MD TVD CO Type FV PV YP ~m Material WL Pf/Mf Ge HT-HP Caustic FC Sohds % Oil % Sand MBT PH Ex Lime Sa t El Stab CaCl2 Avg Dnlhng Max Orllhng No Size Total Length Conn Trip Trip Chlorides Remarks M O Angle Direction TVD Coordinates V S Type Ser No 0 ut Feet (H.W.D.P.: ) Consists of SPM Pressure GPM Jet Vel Ann Vel Bit HHP Pump HHP Operations Covering 24 Hours Ending ~ Midnight o$ I Zoo ;o /1~o :oo ~0 14. /8 ~ ,8 ZZ ,~70 K. oq2 z& ~o ~0 Drill H~O R~g Fuel Dally Tangible Bulk WI Z3/O Bulk Cmtz ~ ~0 Acmdents GO 12ll (CD 3 Prmred in U S A CC-Morn. Company Chdr~, U.lr/l Depth 7qqz MD DOL Torque Last Casing Size q % # Cum Rot. Hrs.: On Casing Liner Set @ . Wt. Pm WL Wt. Material Ither Field 7/82 ' TVD ( ~Z~& PBTD) [Proposed TD DFS Hrs. ~ ~ Days IDrag Rot. Wt. P/U Wt. Drilling Morning Report Pr/Mr Ge O~v~s~o. AIaska Set @ ~ Depth Worst Wear [Since Last Cal. ~ MD TVD- TOP ~ - ~v IHT-HP FC Solids %0il i%m /Caustic q ~/~ O0 Salt Oate/j//7/~..G' Page J of Z ~;~ 0,5' / MD 7,~0~ TVD Total Rot. Hrs. Hrs. ISlack Off Wt. TVD Shoe Test EMW I% Rem. MD "' PV YP MBT TVD El Stab CaCb Drilling MD Total Length Max. Drilling Angle Direction Type Ser. No. TVD ,nI Consists of (H.W.D.P.: ) Coordinates Out Feet VS S PM Pressure GPM Jet Vel. Operations Covering 24 Hours Ending @ Midnight Ann. Vel. I Bit HHP Pump HHP ,¼ ~o/ 4- ,~//-/, ho' __ [ Daily Tangible Daily Mud 0 ICum MuSz- ~a~ 7 - ible Bulk Wt. ]ulk Cmt. Drilling Rep. ~ f'dd f'/ Cum Well o83 £ ~"/,¢, z40 ,0~0 Accidents 60-1211 16D-3-85) Prinled :n U.S.A. CC-Morn. IRegion Drilling Morning Report Company Well zZZ- Ct Depth iDOL 7..? Torque Last Casing Size Cum Rot_ Hrs.: On Casing Liner Gel Pm Set @ PItMf Wt. Material Gel Other ICh. Code MD 7/~..~ ' TVD ( Days Hrs. IDFS IDrag IRot-wt- Set @ ISince Last Cal. IField ~BTD) ]Pr°p°sed TD ~0~1' MD Total Rot. Hrs. Hrs. Days MD PiU Wt. Depth Worst Wear Page Z of ~' 7 ZOC~ TVD Slack Off Wt. TVD JShoe Test EMW Rem. IHT-HP / ICau~tic MD JFC IType TVD -TOP @ MD Solids %0il I% Sand [MBT ICL ICA Tx Lime [I Stab Lig. CIs. Salt CaCI~ TVD Avg. Drilling Max_ Drilling Jconn. ITrip M D Angle Direction TVD V S Trip Chlorides IRemarks Coordinates DLS j~ Total Length Type Ser. No. (H.W.D.P.: ) ,nI Consists of Out Feet SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending @ Midnight FoN + Re,."./' .,~uns d~bl no~L ~ke, make., re 6~ I I Daily Mud~ Cum Mud/~,,,?~, ~'7 Daily Tangible_ Drill H~O - IPot H~O , IFuel .' Rig ~t~tn~.er~~ ,tj_~..8 Rig Phone ~07- 78~ - -~ ICum Tanoihl~'~:~Zt .~',~1~ Daily Ic.mWell ~ ~/~,~o JBuJk Cmt. JBulk Wt.z ~7~ ~ ~0 Appr~/ JDrilling Rep. ~~ JAccidems GO 1211 lCD-3 851 Primed ~n U S.A. CC-Morn. Company ~hevron U_fA We Depth ~ 7~,,~ MD 7 ~ Days Torque I Drag I Casing Size ~ ~" Cum Rot. Hrs.: On Casing Liner Wt. ICh. Code Region ~/r¢'~"~~'~ I,,,,A N 4jz.4~ Set @ TVD ( Hrs. DFS Rot. Wt. Set @ [Since Last Cal. MD ' IField MD Drilling Morning Report Oivision J IProposed ID PBTD) Days P!U Wt. i Depth Worst Wear ,,q la~ ka IDatej///~/~_~· IPage i ~OS"t MD Total Rot. Hrs. Hrs. Slack Off Wt. of % TVD Shoe Test TVD - EMW % Rem.-- MD ' TVD TVD- TOP @ Type A,/'O. C/' ~:~;//1F--- FV PV YP J Solids % Oil % Sand MBT PH Gel Pm Wt. Material Ither Avg. Drilling Length I CO WL JHT-HP PflMf Gel / Caustic IFC Max. Drilling M D Angle Type Ser. No. Conn. ITrip Trip Chlorides ]Remarks Direction TVD Coordinates V S In Out Feet (H.W.D.P.: ) Consists of bondle SPM Pressure GPM Jet Vel. Operations Covering 24 Hours Ending @ Midnight XS~' 4 " .ros ,reA., ~ Ann. Vel. Bit HHP Pump HHP I Daily Mud Drill H20 ¥o ,.. z7 dee · ,ffl~d o,cic zo ~oo el' 4o l~bl.~ I~.ooc., C/" 10 ' 3o bbh zgooo'cl' so ~1~' iz,~ l~&Bf[m4OY'~OMud [ Dail~%bl~~j~ /7/ G~o ~/-Icom Tanaible ~ Daim~ j ',urn Well (30-1211 lCD-3 851 Printed in U.S.A. CC-Morn, Drilling Morning Report Company B/ru z~ z-,::/ Depth =' 'OOL '7 g q Z ~[ 7z ~ Torque I Last Casing 'Size Cum Rot. Hrs.: On Casing Liner Wt. Gel Pm Wt. Material Other IAvg. Drilling Region Division roposeO 1~ MD 7/BJ TVD ( PBTD) ~ f/ MD 7JO ~ TVD Days Hrs. ~ Days . Set $ ~8 MO ~0 TVDJ EMW ~Depth Worst Wear J% Rem. JSince Last Cal. Set @ MD TVD-TOP @ MD TVD PfiMf Gel Solids ]% Oil Angle Direction TVD Coordinates i g lTotal Length (H.W.D.P.: ) Consists of VS SPM Pressure GPM Jet Vel. Ann. VeL Bit HHP Pump HHP Operations Covering 24 Hours Ending @ Midnight 60-1211 lCD3 851 Printed in U.S.A. CC-Morn. lCompany ~h~ro~ Well Depth 7~/9z MD DOL Ch. Code 7 ! Days Torque . I Drag Last Casing Size 9 ~ n Set @ ~,..~'"~:~ ' Cum Rot. Hrs_: On Casing - ISince Last Cal. Liner Set @ " MD Pi/Mr '~ Pm Wt. Material Other' J5 Avg. Drilling / Gel Caustic Drilling Morning Report Division 4 PBTD) Proposed TD ~Og MD J Tolal Rot. Hrs. Days Hrs. Rot. Wt. Wt. . Slack Off_Wt. · Shoe Test MD ,5"~'~"0 TVD JDepth Worst Wear J% Rem. /of/ TVD- TOP @ MD TVD Type J~J'a ~// ~%-~/4~ ISolids t% Oil Lig. Cms. FV ~Z IPv Z. o I%s"'d IMBT - Ex Lime El Stab Salt CaC 2 Max. Drilling Conn. Trip Trip Chlorides IRemorks Angle M D Direction TVD V S I Type Ser. No. YP / Coordinates InIout Feet (H.W.D.P.: ) Consists of SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP EMW TVD mai Length -- Operations Covering 24 Hours Ending @ Midnight m/u pst ~ ~' Daily Mud Drill H~O __ Tangibl~ Cum Mud Daily Tangible ~ic,m . , IDaily Wel~ ~_ Cum Well H,O _ Fuel - Bulk Wt.=XT* ]Bulk Cm,.~O IT°iai App', ~¢*000 fiO-12!l ~D 3 85l Primed m USA. CC-Morn. Drilling Morning Report JCompan, ~hev'r°~ uS'A Reg,o. /,Vg.r4ern e,v,s,on " ~ { Proposed TO Depth ~Z MD 7/~ TVD ( ~&~ PBTD) ~¢~J MD ~ZO~ TVD DOL io,s Hrs [Total RoL Hrs. Days Hrs. ~ Days . Set ~ ~ ~ MD ~~ TVD - EMW Cum Rm. Hrs.: _ ~Depth Worst Wear ]% Rem. On Casing ISince Last Cal. Liner '"' Set @ o MD " TVD- TOP @ ' MD ' TVD 6el I~/¢ WL /k,~/~.. HT-HP .. FI; < ! Solids I% Oil O % Sand MBT o -- IPH Material Gel ~ CIs. Other Avg. Drilling MD Angle Direction TVD Coordinates V S , ITotai Length I.~ Ser. No. In Out Feet Bit HHP Pump HHP (H.W.D.P.: ) a~n3'. ~r~ ~.,'~o Ae~d. X~ xo oo~¢ed 46° x~ xo.'pk~, ~0, p~e~' ~og OOerations Couerin~ ~4 Hours [ndin~ ~ Midni~h~ Consists of g.~., *O~'rr~ ~v~dle eorOdr: XO: 5'~hJum/:~r~r 6:10. i - i · · · ~-DP Vo/ .;'ome ~a$ cu4~ t, nne, Unpeg- pkr~ ZT.'o-~. d~?~ ~u. ~ JOailyMud' 0 CumMu;~ Fuel IDailyfangible }ig Phonej -- . IDrilling Rep. I Cum Tangible_ Daily Well Cum Well 2 3~ 8~ ~' 3, 42o, ~ ? 6 Primed m U S A. CC-Morn. Veil Depth 7q~z MD Ch. Code 7/E? TVD ( Hrs. IDFS Drilling Morning Report Field ~:~/Uq~L ~//Y'¢/"' lDate. / J /lilZl~ i of 1 _ , u J Proposed TD 4~ PBTD) I ~0~/ MD 7~0 ~ TVD Total ~oL Hrs. ~ Days Hrs. ~ ~ DOL Torque (,,9 DaYs Drag Last Casing Size Cum Rot_ Hrs.: On Casing Set @ JSince Last Cal. MD IRot. Wt. P/U Wt. Slack Off Wt. Shoe Test MD .~'~S'O TVD ' EMW - Depth Worst Wear % Rem. ... TVD -TOP @ - MD - TVD Wt. Pm Wt. Material Other CO Pf/Mf Gel '.~'~ ~:o IHT-HP Caustic iFC Oil ]FV Y P TY P ~/~'~:::] ~(olids ~/~'~"';/"~ ~ % %Sand IPV MBT IPH c z .o icA ~xLime ElS[ab L g. CIs. Sa t CaC ~ Drilling MD Length Max..Drilling Conn· Trip Trip Chlorides Remarks Angle Direction TVD Coordinates V S Type Ser. No. (H.W.D.P.: ) Consists of · iXo · Puml , ;fo, 2.-DL, . (o, Z'O_, SPM PressUre GPM Jet Vel. Operations Coverin( 24 Hours Ending @ Midnight Ann. Vel. Bit HHP Pump HHP ' of zoo/roo~ '?sc. -/o (_~ t~' Or~ ._Cc J~ /o trl b eroe f Mud Cum M~ ~ (~:~ 7 Drill H2O ._ Pot H20 -- Rig ~r~,~/~er/~£f ~ J,ig Phone Daily TangibLe IFuel ... Cum Tangible Daily Well Cum Well I 3'8Z. S'4"(,, $/, Z87 ..?,Z96, 5'71 IBulk Cmt. JTotal Appr= GO 1211 lCD 3-851 Printed m U.S.A. CC.Morn. Drilling Morning Report Comp,ny C-/~.v,,'"o~ U.s'A IRegion k/g.~-/¢ rfl Well Depth 7 ~qz MD OOL Days / of/ TVD 7/8.~ Tva ( ~ ~, ~"~ PBTD) 80,~'/ MD 7zoq - Hrs. ~ Days - , Set @ ~ ,.~'~ MD ~'-~'o TVD i Cum Rot. Hrs.: Depth Worst Wear I% Rem. On Casing -- ISince Last Cal. I Liner - Set @ - MO - TVD -TOP @ ' MD EMW TVD Pm Wt. Material ther PflMf / Gel ICaustic lex Lime El Stab Salt CaCI2 Avg. Drilling MD Total Length Angle Direction Type Sar. No. TVD Coordinates In Out Feet VS (H.W.D.P.: ) Consists of SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Coverim 24 Hours Ending @ Midnight ~ rCsJ'or¢ ~ p Daily Mud20,.~, Mud 7 [Daily Tangible Drill H20 -- Pot H20 Fuel IDaily Well_ Cum Well ICum TangiblzyZ, ,5""~'~, ~'4 0~0 60-1211 tCD-3-85) Prmled in U.S.A. CC-Morn. Last Casing Size Cum Rot. Hrs.: DOL IProposed TD Depth -.[q~ MO '"/, ~ ~.~ D FTsV D ( ~-J'~ ~.0 PBTD) HrJ ~s~TOt~I' MD ~~ TVD Rot. Hrs. ~ / Days -- . ~ ~ Torque ~ Days~ -- Hrs. Rot. Wt. _ P/U Wt. _ ]Slack Of Wt. ~ Drag _ - I I ~ ~/~ Set ~ ~ ~ MD ~o TVD ]Shoe Test EMW ]Depth Worst Wear ]%Rem - ]Since Last Cal. - -- ~ On Casing Liner Wt. Drilling Morning Report Region {.,~F...C.~...~./~,,,~j ]Division A~,~X,/j[ ~ ~,,~ I~'~'~ ~-~ ~,~ I"~,,/,,/~ I'~ ~o, ~ Set @ MD TVD - TOP @ -- MD TVD Gel Pm Pr/Mr Ge ITrip ,,,.~/ Trip Chlorides Wt. Material Ither Max. Drilling IConn. IRemarks Coordinates Angle Direction Avg. Drilling MD Set. No. I IJets In ] Out Feet (H.W.D.P.: ). Consists of VS oral Length :/: .- Puml Hrs. SPM Pressure GPM Jet Vel. Operations Coverin( 24 Hours Ending @ Midnight Ann. Vel. J Bit HHP Pump HHP , CC-Morn. Wel · IRegion Pm Pt/MI Gel ]Since Las[ Cal. Wt. Material hher Avg. Drilling MD Max. Drilling · Angle ~ !Tota! Length/ Conn. Direction Set. No. Caustic Drilling Morning Report cx.,,~'~;--r_,~£,,J JD~v~s~on ...~ Proposed TD TVD ( ~O~(~C PBTD) ~O~i MD ~0~ TVD }DFS ITma, RoL Hrs. Hrs. ~ 0 Days ~ Hrs. ~ ~ ~ ~ ~ MD ~ ~0 TVD ]Shoe Test ~ EMW JDepth Worst Wear ~ % Rem. MD - TVD - TOP @ --.-- MD '"' TVD ]Type LiD. CIs. (H.W.D.P.: ) Consists of Ex Lime I[I Stab Salt ICaCI2 Trip Chlorides [Remarks Coordinates V S Out Feet S PM Pressure GPM Jet Vel. Ann. Vel. Hrs. Operations Covering 24 Hours [riding @ Midnight Bit HHP Pump HHP ~6L ~/~ ~/u,~G -7go~ H~ ~ IDai'¢'u~''' ~'7 Cum Mud/~~ Tangible -- . Tangible~,~~ 60-12!1 (CD-3-85 Prmted in U.S.A. CC-Morn. Company We Depth DOL IRegion 7gf~ MD T/gA Days Torque Last Casing Size ff ~ Rot. Hrs.: On Casing 7j ~ Liner - Set @ ~vt.ct-_q; co ~el WL Drag Material Other ~,vg. Drilling TVD ( Hrs. OFS Set @ ~ 6~.~ ~ ISince Last Cal. -- MD HT-HP FC Pf!Mf I Ge ICaostic CoAn. Max. Drilling Drilling Morning Report IDivision I Field /~ ~'/U 6.4 JJ-~ 0 ..~,C~/.. PBTD) Proposed TO ,,.~' ~ Days -- Rot. Wt. ~ PtU Wt. MD ~ ~',.'.'.'~ ~,.~, Depth Worst Wear TVD- TOP @ Type Solids % Oil Lig. CIs. JTrip 1 Trip Chlorides M D Angle Oii'ection TVD Total Length // jFv Remarks Ser. No. (H.W.D.P.: ) Consists of 0 u t Fe et ~'0 51 MD 7~, (::)~ TVD Total Rot. Hrs. Hrs. ~ ~ "IZ, ]Slack Off Wt. ~ TVD Shoe Test ~ EMW % Rem. _ MD - TVD PV Sand MBT Ex Lime Salt YP PH El Stab CaCI~ VS Puml / Hrs. Liner Stroke SPM Pressure GPM Jet Vel. Operations Coverim 24 Hours Ending @ Midnight Ann. Vel. I Bit HHP Pump HHP bsT Ld,O.O, --- cAcc ~££v Pi'dgsroCE .soeu£y '/,~,C'o & ~-u~cc,Ar~b x4~_ CC-Morn. Company Wel Depth DOL Torque '7~qz IRegion ICh. Code MD "7 1 ~ TVD ( Days IDrag Last Casing Size ~t '~/~ Set @ Cum Rot. Hrs.: On Casing '"'/I /,~ )Since Last Cal. Liner Wt. Gel Hrs. DFS - 'l Rot. Wt. --- Set @ q -Z; IC° lwt IH,-HP FC P m I PfiMf 1 Wt. Material IGel Other Avg. Drilling Max. Drilling IConn. Total Length M D Angle Direction /./-' Drilling Morning Report Oivision I Proposed TO ~'-~ PBTD) ~,~' I MD '7'ZO q TVD I Total Rot. Hrs. ,'~ Days -- Hrs. IP/U Wt. __ ISlack Off wt-_ IDepth Worst Wear _ ]% Rem. _ MD - TVD - TOP @ "-' MD .... TVD /Caustic Lig_ - CIs. Salt iTrip ITrip Chlorides ]Remarks Coordinates TVD / IOut Feet Type Set. No. IJets I In VS (H.W.D.P.: ) Consists of SPM Pressure GPM Jet Vel. Ann. Vel. I Operations Coverin( 24 Hours Ending @ Midnight Bit HHP Pump HHP CC-Morn. Company ICh. Code Depth OOL ~ '~ Days Torque _ Drag Last Casing Size Cum Rot. Hrs.: On Casing IRegion set @ Drilling Morning Report ]]Division A iof~ TVD Rot. Wt. Proposed TO '"~'>Q i TVD PBTD) Y-~ 0:~";~ / MD x ~- Total Rot. Hrs. ~ 7 Days - Hrs. ~ ,~ ~ ~ _ P/U Wt. _ ]SlacLOff Wt. MD :~z' .'_~-, TVD ISh°e Test Depth Worst Wear_ % Rem. Set @ Hrs. JDFS Liner TVD- TOP @ MD ]Since Last Cal. MD I WL HT HP FC · EMW --- TVD Gel Pm Wt. Material Pf/Mf Gel ICaustic Type A/o C' [ ~ ~,/~,,/.~/? FV PV Solids % Oil % Sand MBT PH LiD. CIs. Salt CaC ~ Avg. Drilling !Max. Drilling Conn. M D Angle Direction I No. Size Total Length Type Set. No. ITrip Trip Chlorides Remarks Coordinates TVD Jets } !-4 T"-- ' ~ ~ (H.W.D.P.: Consists of VS Liner Stroke SPM Pressure Bit HHP Pump HHP Hrs. -- GPM Jet Vel. Ann. Vel. Operations Coverin[ 24 Hours Ending @ Midnight Daily Mud __~ ~ ~ JCumMud ) lc, i Z t.,~ Drill H~O ~ I Pot H~O ~ Rig ,,~ .,~ ~.,, Rig Phone .'c-~t~ /~' ,'dE I~ I'I 0 T? ~ .~ CC-Morn. ch.code Company We i Depth Last Casing Size '"7 q q 7~ MD ~ t g'.,3 TVD ( Days - Hrs. ]DFS IOrag IR°t- Drilling Morning Report Division .A'L 4.s,~c,'t J Proposed TD ~ C) ~ PBTD) .... t MD "7~ C) q TVD Total [lot. Hrs. Days -- Hrs. ,~' ~ ~: Wt. IPiU Wt. _ J slack of~ Cum RoL Hrs.: ]Depth Worsz Wear On Casing ~ i ~ Isi.~, Las~ Cal. - Liner ~ - Set ~ MD - TVD-TOP ~ / ~L Mamdal Causfi~ Lig Max. Drilling PfiMI Ge Gel ~m ~,vg. Drilling M O Angle No. Size J Type ! IConn. ,~ ]Trip Chlorides /' TVD TVD Shoe Test ..-- EMW % Rem. ~ MD TVD PV I Set. No. ~ Jets In ~ ~"k' i iZ o 0 PE,v c~ cE.,q~ (H.W.D.P.: ) Consists of J% Sand JUBl YP PH JEx Lime lEI Stab Salt IgaCl~ IRemarks Coordinates VS Out '~t Feet 7" C. 4- ,t'6 ;" J . SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending @ Midnight C V DaiLy Mud Drill H~O Cum Mud /~0 ~ 2'. ~' Daily Tangible IPotH,O _ JFue, - ~ _~-~,,/ JRig Phane q 0'7- 7~" ~ 7,]"~ JCum Tangible~ ¢~ ~ ~ ~' IBulkWt- ,~)-?~ IBulk Drilling Rep. Oa,y we,~/~ o o ? JCur. Well _~ o 6 ~ 60-1211 lCD 3-85) Pnnmd in U.S.A. CC-Morn. Company Depth DOL Torque -7q q.2I,- MD Days Last Casing Size Cum Rot. Hrs.: On Casing Liner -- Set @ Wt_ c/'.5 IC° Gel Ch. Code Pm Region Wt. Material ,Avg. Drilling _/ ] No S ze Type Drilling Morning Report IDrag ~ Set @ TVD ]Since Last Cal. Hfs; DFS G (_,z58 MD WL HT HP IFc Division Field ( ..~ 7~C PBTD) IPr°p°sed TD Days IRot. Wt. IP/U Wt. MD Depth Worst Wear TVD- TOP @ Date Jl/,~/'~,~ J~ge i of t ~, o 5 j MD '7~o9 TVD Hrs. ]Total Rot. Hrs. TVD JShoe Test J% Rem. Slack Off Wt. ~ EMW Pf/Mf I Gel -Caustic Max. Drilling Solids i% Oil Lig. Is. MD TVD ]Conn. ]Trip ~.....~ip Chlorides Direction :/~ IYP Sand MBT PH Ex Lime Salt IRemarks Coordinates Set. No. Jets In I °ut Feet (H.W.D.P.: ) VS SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending @ Midnight (7~ ~'2 ,go' Mud Cum Mud Drill H~O Pot H~O Rig "~,(',/A,',(~--£#OFF t~, ~-.~ CC-Morn. ICompany Well Depth ~ DOL ,.-- '"' Torque Last Casing Size ~ Cum Rot. Hrs.: ,i ~ On Casing Drilling Morning Report 7 f~ MD ~i~ TVD ( ~7~ PBTD) ]Proposed TO ~0 ~l MD ~0~ TVD Iof ( ~ ]DFS - ]Totat Rot. Hrs. Days Hrs. .~ ~ Days Hrs. ~.. ~ q. i~ q'% s~t~ ~.~-.~~ ~so ~v~'1m Test . - EMW _ ~Oepth Worst Wear _ % Rem ~ 7 :~ JSince Last Cal.. -- Set ~ -- MD - TVD - TOP ~ ~ MD .~ TVD , ] Liner Gel ~/t. Material WI HT-HP Other ~,vg. Drilling Total Length Max. Drilling M D Angle ',onn_ Direction Solids % Oil Lig. CIs. Salt Ser_ No. In ] Out Feet (H.W.D.P.: ) Consists of IYP El Stab CaCb VS Hrs_ SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Operations Coverin[ 24 Hours Ending @ Midnight Pump HHP DailyMud .~_ 0 ~'- Ic"mMud 1~-7~( Drill H~O .,.___. J pot H~O ~ CC-Morn. Company Well C:..i. IEUPo~ (' ~ A' Code Region Oepth 'Tq'q~ MD -7 Torque Las, Casing Size Cum Rot. Hrs.: ' Liner Set @ MD Gel [WL HT-H P ~,,~,,,,., FC Pm IPf/M~..~ / Wt. Material ~ ]Caustic Other j _.~...>/,( ~cI~J Max. Drilling Conn. TVD ( Hrs. tDFS Rot. Wt. 6~.S9o Drilling Morning Report L-CJ ~",.~"7~'~'/~,X) DiviSion .~ L 4 ~ k'4 ~7_5~. (~C~BTD) JProposed TD m gO,S'Y MD '7~Of TVD Total Rot. Hrs. ~ ~ Days - Hrs. ~ ~/~ ~ I iP/U W [I / Slack Off Wt. _ I Shoe Test -- MD .~o TVD EMW IOepth Worst Wear ~ % Rem. Avg. Drilling M D Angle Direction ..: No. Size Total Length Type TVD- TOP @ - MD - TVD I N cL %0il %Sand IMBT ]PH i. Ex Lime El Stab Salt CaCb Solids Trip I Trip Chlorides I I Remarks Coordinates VS (H,W.D.P.: ) Consists of Out Feet SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending @ Midnight d .... / ' Bally Mud C~05 ICum Mud ~.~ 7~.~/~ I Daily Tangible.__ CC-Morn. Company We Depth DOL Ch. Code 7qqot MD 7i83 Days IDrag Last Casing Size Set @ Cum Rot. Hrs.: On Casing s Set @ ISince Last Cal. Gel Wl HT-HP Pm PflMf Wt. Material Caustic Drilling Max. Drilling Angle JConn. Direction Ser. No. Hrs. £ JRegion TVD ( IField ~ ?.~/ PBTD)'lPr°p°sed TD Hrs. DFS JRot. Wt. Days IPtU Wt. MD ._~ ~_~o JOepth Worst Wear _ Drilling Morning Report Division .~ ~...~,.~,~ '-- Hrs. Total Rot. Hrs. Slack Shae Test TVD J % Rem MD JType .AJ~ C~ -- TVD- TOP @ - MD /~/~A..'I=" FV j P v Solids % Oil J% Sand I CA Ex Lime TVD FC JMBT JCL Lig. ITrip TVD Chlorides Remarks Coordinates In Out Feet VS (H.W.D.P.: ) Consists of SPM Pressure I GPM J Jet Vel. i Operations Covering 24 Hours Ending @ Midnight Ann. Vel. Bit HHP Pump HHP ! Drill H~O Depth DOL MD Days -/q qz. ~7 iTorque I Orag I ~ast Casing S~e ~% Sot ~ IRegion ICh. Cod~vv~ ~ ~ z ~ TVD ( Hrs. IDFS Rot. Wt. Cum Rot. Hrs.: On Casing ]Liner Set @ MD Wt. ]Since Last Cal. IDivision ~'~1 PBTD) IPr°p°sed TO Days ._ jP/U wt. Drilling Morning Report Hrs. JTotal ROI. Hrs. ISlack IDePth worst wear _ _I% Rem- - TVO. TOP @ MD - EMW TVD Gel Pm Wt. Material Other ICO Pf/Mf 'Gel Avg. Drilling i~,z: o IHT-HP Caustic IFC ISolids )%Oil ICL )CA Lig. CIs. El Stab Salt CaCI~ Max. Drilling Ic°nn- ITrip IRemarks M D Angle Direction ,, ,~ Total Length/ Set. No. TVD Coordinales IJets Out Feet I Hrs. I WI (H.W.D.P.: ) Consists of SPM Pressure GPM Jet Vel. Ann. Vel. VS DLS Operations Covering 24 Hours Ending @ Midnight Bit HHP Pump HHP GO-!211 (CD-3-85I Printed m U.S.A. .,, nDrilling Morning Report Company ., \ _ Region ..... D'v's'o .4,., _ . Well Ch. Code Field "'/,-, ,2 Date . ..-- Page Dep.h - Proposed TD . ~, [ ~ffq~ MD 7 ~ TVD ( 6~3 ~ PBTD) [ 9 ~5 i . MD 7~9 TVD .s [~OL ]DFS · ~ . Total Rot. Hrs. ~ ] _~ ~ Days Hrs. [ ~ 0 Days Hrs. = ITorque . ~ Drag ' I' 'R°tWt _ }P/UWt. - ISackOflW, Last Casing Size ' ~ ~/ _ ~ ~ ~ ~ ~ [Shoe Test = ~ ~ Set ~ ~ ~ MD ~0 TVD J -- EMW ~ Cum Rot. His.: ~ i Depth Worst Wear % Rem · - Set ~ -- MD - TVD -TOP ~ ~ MD - TVD WL ~ ~. ICO ~ Type .... ~ ~ ]FV PV YP Gel WL /~T~P--- '_l FC Solids % 0,1 %Sand MBT PH [ ~ Pm ~r~'' CL CA ExLime EIStab Drilling - MD Max. Drilling _ [Conn. I Angle L Direction TVD Coordinates VS No. Size Type To!al Length ~.~.-7...5~, I Set. No. J Jets 2 ~,~ 05 ~ I 0~.~' (H.W.D.P.: I In Out } Feet I Cons= o~ ~,~ "8, r/q';/, 'c,'~,.~. SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Liner J Stroke Operations Covering 24 Hours Ending @ Midnight D,,,y M.d ~qe5 JC.m M,d i SS; ~S J Oai,~ Tangible Drill HzO I Pot HzO -- I Fuel Rig 4.~i~?/ttt/(y;../~lO.l~..j- .~ JRig Phone q'07 CC-Morn. Company Well ICh. Code Torque IRegion TVD ( '7qq 2.- MD '7/~3 Drilling Morning Report ' IProposedTD ~...~' ~; PBTD) ;~C>S / MD '7,~?C'~ ~ TVD I Total Rot. Hrs. Hrs. Slack Off Wt. _ TVD ]Shoe Test Days Last Casing Size q ._,~/.~ Hrs. IDFs Drag Set @ JRot. Wt. Days MD P/U wt. EMW Cum Rot. Hrs.: o, Cas~.g S 7 ~ lsd,ce Last Cal. Liner Set @ Pm Crt. Material )ther ~ IWL ~2~ -(,, - HT-HP PfiMf 2 ' ~J Ge ICaustic MD IFC IType t JDepth Worst Wear TVD-TOP @ ISolids i% Oil LiD CIs. JFV I% Rem. MD /'fi IPv [%Sa°d-'r~ I~T '5 Ex Lime Salt - TVD IYP i 5 El Stab CaCI~ Avg. 0tilling MB Max. Drilling_ Conn. Angle Direction _ ITrip Trip Chlorides _ Remarks TVD - Coordinates VS (H.W.D.P.: ) . ., . SPM Pressure _~oo/~,5c~ ~ - o/c Operations Covering 24 Hours Ending ~ Midnighl --' O lc c:. t..b-A,v o.-t,, i- ~ .~iG9 c.?c gw~LS c~ P )CoW Daily Mud 0 Cum Mud I ""'~'S '70 Daily Tangible ..--. Cum Tangible 3 ~'~'.5 ~ ~ Dai~ .~l~.7 'L Cum We~ ~ _7..~[ (-/ '~"", Drill H,O __ [Pm H,a~ iF.e, ~ )Bulk wL a~7G Jeulk Cmt. ~,..5C.' IT0ta, Appr...~. ? ~ ~. C,,-C.,-O · 1 2 ~ e~n 60-1211 160-3-851 Primed m U.S.A. - CC-Morn. Well ~rCd ,2&2-¢ ich. Code Depth '7'?~ MB Drilling Morning Report Region ~/~' ~_,,...~ ~,-~,~,~,,4,,/ Division _.,,/J//~ R'~ , . ' Page Proposed ID ~/~ TV_D ( ~~ PBTD) ~0~{ MD TVB DFS DOL 5 ~ Days "-- Hrs. ~ ~ Days Torque _ JOrag ._ jRot. wt. ~ Last Casing Size 9' ~/~ Set @ (~ ~Z '~ MD Cum Rot. Hrs.: On Casing 5/4 ~'.- Jsince Last Cal. Liner Set @ ~ MD Total Rot. Hrs. -~ Hrs. ~'~'~"/f ~ IPIU Wt- _- ,~ ~CC,. TVD Shoe Test ~ EMW '~ TVD- TOP ~ -- MD ~ TVD wt. q,.~ + co Im(o JAvg. Drilling MD JSolids ~ Pm .--,. Pf/Mf ,"~' ~ / .~' J4- CL i0, C,~J Wt. Material ~0 Ge ~ ,~ Igaustic Lig. JFV ~5 PV / ~ jYP ~ ._ Max. _ _ tRemarks _ Drilling ~ IConn. _ Trip JTrip Chlorides . - Set. No. t Pure) J Liner Stroke ' SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending @ Midnigh! ~OOH O~elccuo~o ~Evm~,~ ,~ lO-aDAm - t g .~7/~,,~ ,",Jx,,v; c/a- r'a) (,.,.~5Pm rs. f ?. ,~ q .il+ 60-1211 lCD-3 851 Primed ~n U.S.A. ,c..o,.. Drilling Morning Report IDOL ~ JTotal Rot. Hrs. ~ ~- z i/ ~ ~ Days Hrs. ~DFS ~7 Days Hrs. J ~ ~ . Torque Drag Last .asing Size ~~ Set ~ ~~ MD ~~0 EMW ~Cum Rot. Hrs.: ~ Depth Worst Wear I% Rem ~ jori Casing ~0 JSince Las, Ca,. -- I '- I TVD Set @ MD TVD-TOP @ MD Material J Ge Caustic Lig. CIs. Avg. Drilling JMa×. Drilling Conn. Trip I Trip M D ] Angle Direction ' TVD ~ 'Total Length (H.W.D.P.: ) Chlorides tRemarks ODor inales Consists of G, IPH IJ.q r=~ SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP £'o ~e,t - - Operations Covering 24 Hours Ending {~ Midnight Drilling Morning Report cc-~o,.. . Proposed TO MD PBTD) ~~/ MD ~~ TVD Depth Z_~Z 7j~',~3 TVD ( ~i~r ~',lll~ IDFS ToJal Flm. Hrs. OOL .~__~__ Days H,Si ~ Days Hrs. Last Casing Size ~~ Set ~ ~6~8 MD ~~0 TVD Shoe Test Cum Rot. Hrs.: [Depth Worst Wear % Rem On Casing ~ 2 ~ JSince Last Cal. Liner Set @ MD TVD- TOP @ MD EMW TVD VS Avg. Orilling Max. Drilling Conn. Trip Trip Chlorides Remarks M D Angle Direction TVD Coordinates Tolal Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM - Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending @ Midnight . Mud .o/~- Daily Tangible..,... Cum ' I - GO: 1211 lCD 3-B5l Primed in U.S.A. CC-Morn. Company_ Depth Drilling Morning Report MD TVD ( Hrs. IOFS IRot. Wt. IProposed TO V~t~ _.~ PBTD) ~'<:~ ~""/ MD 7~? TVD Total Rot. Hrs. ~ Oays Hrs. ~ ~ ~ Torque Last Casing Size IOra9 Cum Rot. Hrs.: On Casing J Oepth Worst Wear JSince Last Cai. Liner Set @ MO TVO- TOP @ TVO Ish°e Test EMW Rem. MD TVD Wt. Material Gel Drilling Max. Drilling ' }Conn. M O Angle Direction Trip TVO Trip Chlorides Remarks Coor( inates I JetsL In / Out ] Feet ~ Hrs- I W ) Consists of [I Stab Cafil2 VS lB ] RPM J T ' BLS SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending @ Midnight Daily Mud Orill H~O Cum Mud . Tangibl~:~) Pot H20 ...... I Fuel Cum Tangible Daily Well Cum Well Bulk Wt..,,.,, ~ ... Bulk Cmt.., ...... ITotal AppL .,,, .~ - Drilling R~ ........ ~ ~Ac~idems ..' . _ ' G0-1211 1~3 85~ Primed in U S A. CC-Morn, Drilling Morning Report - ./'6/2 DOL - - . Rot. Hrs. ~ ~ ~ Torque ~0 "ays ~Orag H,s.,JR°t' Wt. ~ y "~yS IP/U Wi' ~Sbck Off Wt. ~asin~ [Since last Cal. Liner Set ~ MD TVD TOP ~ MD TVD i CL Ex Lime El Stab Other Avg. Drilling Max. Drilling Conn. lTrip Trip Chlorides Remarks M D Angle Direction TVD Coordinates V S DLS ~Tetal Length Consists of (H.W.D.P.: ) / I Liner I Stroke I '2.- 1 ,",~ Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Coverin[ 24 Hours Ending @ Midnight . ~ Drill H20 .---, el ..-.- Cum Bulk Wt. Bulk Cmt. Well 601211 lCD 3 851 Printed in U S.A CC-Morn. I Compan~I, Drilling Morning Report ,,~.,/'zs,,.',,~ / o~ / Depth Proposed TD [ ~ ~t ~1~ Z. MI) "~/~ ~ TVD ( /'//~/,,~ PBTD) ~'~ ~" / MD ~' ~' ~ ~ TVO iDOL ' ~ DFS * . ~ ITotal Rot. Hrs. ] [Torque ' [Drag IRoI. Wt. P/U WI_ ISlack Off WL I Last Casing Size Shoe Test ~~ Set ~ ~~ MO ~~0 TVD EMW i~u~ Roi. Hrs.: ~ lDep~h Worst Wear ~% Rem On Casin~ / ~ ISinc~ Last Cal. I Liner ' I Set ~ MD TVD- TOP ~ MD Pm -- Pf/Mf . -- -- ~' gL - ~ CA / ~ .__ ExLime IE Stab Other ~ ~ ~ ~ ~ Avg. Drilling MD Max. Drilling Angle ;onn. Direction TVD Coordinates VS . DLS Total Length (H W O P · ) Consists of / l~"~,,l~'n,I.~0~ ~ I~=,~r ~ ~,w,. ~,n.~,. ,,,,~- ~,~,,,~ Operations Cover[n( 24 Hours Ending (~ Midnight Daily Mud Drill HiO ICum Rot. Hrs.: Ion Cas~.g /~ '~'~, Liner Set TVD (~'/ Hrs. IDFS vz iDrag JRot. Wt. Days Wt. Hrs. IT°tal Rot. Hrs. ISlack Off I Depth Worst Wear JSince Last Cal. MD TVD- TOP @ TVD JShae Test Rem. MD EMW TVD jPV ~ vP PH JEI Stab CaCI~ M D Angle Direction TVD Coor ]inates j 1T° al '-'~ ,~Z~ ,~' (H IWIDIP ': ' ' ~O~SJs's O[ SPM Pressure GPM Jet Vet. Ann, Vel, VS lB J RPM J T DLS I Bit HHP Pump HHP Operations Covering 24 Hours Ending @ Midnight Daily Mud Drill H20 7~ JCum ~ud~q~ ~l~ ~I1~ IJOaily Tangible JPot H~O --.---- el -b IC.m Tangibl~.,,~lZt~,lrl/~ [Dail~ijl~a.~7 ]CL~IIV~ ~ ~/Z 'j 60-1211 lCD 3-851 Primed in USA. CC-Morn. Drilling Morning Report Vlud Drill H~O Last Casing Size Cum Rot. Hrs.: On Casing .iner r ~.vg. Drilling M D Angle Direction TVD Coordinates V S Pure! Hrs. No. Size Type Ser. No. '- I Total Length (H.W.D.P.: I Jets In Out Feet I~-'/& Consists of SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending I~ Midnight Max. Drilling Conn. ITrip Trip Chlorides Remarks Mud Pr~med Jn U.S.A. IDrag Set @ ~ I~ ~"'~ MD ~""'~~ TVD Shoe Test Set @ MD TVD-TOp @ MD TVD EMW Division Veil I MO 7~~ TVO · = Hrs. ISlack Off Wt. ~ ~ Days Hrs'~DFS iRo,.W ~ ' ITo[que I CC-Morn. IC°mpan¥ ~l~h~lron Drilling Morning Report Well )OL ,torque Last Casing Size zzz-e Cum Rot. Hrs_: On Casing Drag Region ICh. Code/,~/A A,/~ ! Z 4- ~' 7t,g3 Liner Set @ TVD Hrs. ]DFS 5/,O Set @ ISince Last Cal. Field Days PBTD) IPr°p°sed 'rD Days PiU Wt. IDa[e/o/~'//{~' IPage J of Z ~'05'1 MD 720q TVD Pm IPf/MI/, ~. Wt. Material IGel 7~. Z.~ MD L ,~.. ~ JHT-HP -- FC Coon. tRot. Wt. JOepth Worst Wear Hrs. JT°tal R°t' Hrs' Z. ~-,~ TVD JShoe Test J% Rem. lther Avg. Drilling Max. Drilling ISlack Off Wt. EMW TVD - TOP @ MD TVD Tri~ Solids ,~. ,.~ J% Oil TVD PV io IYP ~'-,/~ 1MBT /5" JPH /~.~ JEx Lime tel Stab SaLt CaCl~ VS MD Angle Direction Type Ser. No. ~ ITmal Length JCaustic (H.W.D.P.: i JCL iCA .Lig. CIs. I ~ 1%Sand I Jets JTrip Chlorides JRemarks Coordinates In j Out Feet I Consists of SPM ,,~ 20/ Pressure I GPM J Jet Vel. I i Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending @ Midmght ~oo cu~z e~4 76& ,s~. Id Y mtn. S~6 ~ 04. _~ever~. Z DP volumea Daily Mud Drill Cum Mud ]Daily Tangible P°t H'O _ IFuel _. Cum Tangible Jgaily Well Cum Well ~8z,$'4~ ~ .~1~144 I Z: _~z~.., 7ql JTotal Aopr._ jDrilling ~,d~/A,,,,~ ~tAccidents -- 60-~2H ~0-3-851 Pr~n~ed ~n U.S.A. CC-Morn. ICompany ~h~/ror~ U ..~'A ICh' C°de IRegi°n ~/~J~I[~F/Q Depth ~ I 7g~Z MD 7/~5.~' TVD ( DOL ,,~ ~ Days Hrs. IDFS Torque ]Drag IRot. Wt. Last Casing Size ~ % ~' Set @ (~ ~, ~8 ' MD Cum Rot. Hrs.: On Casing Liner lSince Last Cai_ Set @ MD Wt. ICO ]Type Gel ]WL IHT-HP IFC Solids Other Drilling Drilling ]Conn_ ITrip Drilling Morning Report Io'v's'°n ,4/as&z Proposed TD PBTD) ~0 ~1 MD 7Z0 ~ TVD Total Rot. Hrs. Days Hrs. ~ ~"',~ ~ P!U Wt. I Slack Off Wt. ~ ]Shoe Test 5"~-~-~ TVD IDepth Worst Wear I% Rem. EMW TVD - TOP @ MD TVD FV PV YP %Oil %Sand IMBT [PH J C A lEx' Lime El Stab i CIs. ISah CaCl~ I Max. M D Angle Total Length Direction TVD ITrip Chlorides ]Remarks Coordinates Type Set. No. Jets I , In i Out Feet (H.W.D.P.: Consists of VS S PM Pressure GPM .Jet Vel. Ann. Vel. I I 8it HHP Pump HHP Po l4. Operations Covering 24 Hours Ending L~ Midmght ,..r V ~ 'oo ~ /7.'Og. C/P & /8 Daily Mud _ ICum Mud /~"~ ~'00 Daily Tangible_ Dril, H~O IPot H,O IFueI Daily Well Cum Well - GO 1211 lCD 385i Primed in U.SA_ CC-Morn. We, B'A"'U Z 3' Z - ~ Oepth DOL Days Torque Casing Size Cum Rot. Hrs.: On Casing iner Set @ Wt. Pm MD Drilling Morning Report Region Division~- la.s'k~ Code Field ... , 7/~ TVD ( ~q/~ PBTD) ProposedTD ~0~1' MD 7ZO~ Hrs. ~ Days · Wt. Material ]ther IDrag IRot. Wt. P/U Wt. Set @ ~ ~, .~"~ ' MD .S"8 ~"0 Depth Worst 'Wear Isince Last Cal. CO ~..rr~ ¢0 WL //, ~' IHrHP Pf/Mt , 7 Gel ISlack Off Wt. TVD Shoe Test % Rem. MD TVD- TOP @ MD FC / polids 8.~;~ %0i, FV "SandPV o I C L ~C A lexLime El Stab /Caustic/' ~ , Lig.~ 0o0 Os. /Z~ sam~ cacm, YP ~ of ! ' TVD EMW IPH /Z.~ TVD Avg. Drilling Max. Drilling M D Angle Direction Coordinates V S No. I Size Type Total Length TVD Ser. No.Il' J~ts I inII ou, Feet Consists of (H.W.D.P.: SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Coverin( 24 Hours Ending L~ Midnight -fl-,._' ? %" c~-o ,vi4-'~" z~w~' F//4~ '- ~ 4?. Cum Well Drilling Rep. ~ Accidents -- 6o-~2]~ icg 3-85~ Primed m U.S.A. CC-Morn. lCompanv ~J~e V ro n usa Drilling Morning Report Depth · 7~/~z MD Rot. Wt. Days Torque Casing Size i Region Ch. Code WA/N/41Z.4,4~, Cum Rot. Hrs.: o. Casing 7 ~'~ IDrag I TVD Hrs. IDFS MD P/U Wt. Depth Worst Wear FV ~'0~'/ MD 7ZOq TVD Hrs.]Total Rot. Hfs, Z~'~- TVD ISh°e Tesl % Rem. 7183 Days Set @ ~, JSince Last Cal. Liner Set @ MD Pm CO Wt. Material Ither IType IField TVD- TOP:@ ISlack Off Wt. EMW MD TVD PV IYP [ /s' WL 1/. ¢ ]HT-HP - IFC / /.ZY Caustic % Sand T/,~ MBT /z,¢ CaCI~ Avg. Drilling Max. Drilling IConn. Trip M D Angle Direction fVD V S I' Jets I. Trip Chlorides JRemarks Coordinates No. ' ' Size 110181 Length Type Ser. No. In [ Out Feet (H.W.D.P.: ) Consisis of SPM Pressure I GPM J Jet Vel. i Operations Covering 24 Hours [riding @ Midnight Ann. Vel. Bit HHP Pump HHP q bbb ,'~ 'z4hr.,J ~ ~. Daily Mud Drill H20 ICum Mu:,.~., t~t~) JDaily Tangible.., 60 1211 ICO 3-851 P6med m U S.A. CC-Morn. Company We /3'/'('u Region IField Drilling Morning Report Division Depth 7qqz ld~ s tern DOL Days TVD ( $7 MD Wt. Torque I Drag MD pBTD) Proposed TD ~o~'1 MD Total Rot. Hrs. Days Hrs. PiU Wt. I Slack Off Wt. ~ Shoe Test .S-B g-~ TVD lDate j ~ IPage 10//18/8,_~'' / of / Depth Worst Wear _ i% Rem. _ ICh. Code · 7183 Last Casing Size ~ ~.~ u Set ~ ~, ~, ,.S-8 Cum Rot. Hrs.: On Casing 7 YZ ]Since Last Cal. liner . Set @ - MD Hrs. DFS TVD - TOP @ - MD - Avg. Drilling Max. Drilling Coon. Trip [Trip Chlorides IRemarks M D Angle Direction TVD Coordinates V S Total Length Type I In I Out Feet Consists of TVD EMW TVD (H.W.D.P.: ) SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP I I I Operations Covering 24 Hours Ending L9 Midnight I Daily Mud Drill H~O ICom Mud,/, ,,~..~ ~00 IDaily Tangible_ ]Pot H,O - IFuel _ c/07- 7,..q ¢ - ,g 75z Cum Well Drilling Rep. GO 1211 lCD-3-85] Pnnted in U.SA. CC-Morn. Drilling Morning Report Company Chevron u ,jw~ u~u z~z.9 Depth 7q~Z MD Torque Las~ Casing Size On Casing 7 J~ Liner Set @ JRegion ' ~ PBTD)JProposefl TO 7 / aa TVD ( DFS Hrs. ~ Days J ~ot. WL P/U Wt. J Oepth Worst Wear JSince Last Cal. - JDrag - MD Wt. /0. I '~ jco :Z'mco ~e, z/~ IWL Pm p. Material ,~,S ii~f' JHT-HP Avg. Drilling MD Type . FC I ICaustic Max. Drilling Jconn. Total Length //00, /0 Angle Direction TVD- TOP @ Ser. No. (H.W.D.P.: jTrip TVD Jets J In J 880. qZ ) Consists of Division z&,ooo I ,~/~X--~ Hrs. JTo,,al Roi. Hrs. of I TVD JSlack Off Wt. JShoe Test TVD -- EMW J % Rem. - MD ' TVD 1!v I 7 Ex Lime El Stab Salt CaCl~ Trip Chlorides Remarks Coordinates Oul Feet VS DLS . S?M Pressure Bit HH? Pump HHP PumI / Hrs. , ] Liner J Stroke J J ~," I ,,a'l I~' GPM J Jet Vel. I , Operations Covering 24 Hours Ending k~ Midnight Ann. Vel. I ~ & ~8 ' do ~rm · ,~8 'Pt~q Daily Mud Drill H~O .., Cum Mud I Tangibl~ Daily Well _ Cum Well PoIH,O _ IFue, _ ]Bulk Wt. ]Bulk Cml..~.. 7,~' I.TotaJ A~: ~,,, 000 GO 1211 IC0-3-851 P, nred m U.S.A. CC-Morn. ICompan¥ DepJh Torque Region IField U~'A · 7 ~/ ~/ Z MD Days ./ 4 AI,C/ Z 4.4- JCh. Code / 7/$-Y TVD ( Hrs. joFs Drag JRot. Wt. 4,4,5'E MD On Casing Liner JSince Last Cal. Set @ '- MD Wt. Pm Wt. Material WL /0.~) JHT-HP PflMf · ~ Gel . FC / /.5" ICaustic. Type Drilling Morning Report Division PBTD) JPr°p°sed TD Days P/U Wt. Depth Worst Wear TVD- TOP @ JOate/~/j~/~._~. JPage ! of / I ~fOS'l MD 7z~c~ TVD Hrs. JT°ta~ R°t' Hrs' ,~,_~-,,~ ,,~ Slack Off Wt. TVD JShoe Test .-. EMW % Rem. - FV l' /,?'. $ m o CL ica j Lig. CIs. I - MD [PV /~, % Sand ~r MBT YP Ex 'Lime Salt El Stab CaC ~ Avg. Drilling Max. Drilling Conn. Trip i Trip Chlorides Remarks M D Angle Direction TVD Coon linates No. Size Type Ser. No. Jets J In j Out Feet z/4o87 zuo~l£I j VS Total Length /'l O~) , 1 0 (H.W.D.P.: TVD SPM Pressure GPM Jet Vel. Ann_ Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending L~ Midnight ~ d e/o e,,~¥ t=/c~sz- ~~, · ,;'c lz/u. ?oi.-/ l~ii;' /~ond 4 7,o0 '- ~ ,~C,o · Poor Daily Mud ~;~,, JC.m Mud /~"~ 0 7& Daily Tangibl.~e _ JPmH,O _ IFuel . Drill H20 ~ / ° o ? ' o ~. ~,s'a " .~ ',- ~v ro ~ ~ ~ ~7~ · J Cum Tangible Daily Well Cum Well fDrilling Rep. ~rd~n {Accidents 60-1211 lCD 3~851 Pnnted m USA. CC-Morn. Company De~SU I U~A Ch. Code Drilling Morning Report # 7/~',.~ TVD ( PBTD) JProposed TO ~0.~/ MD IPage I of 7 7ZO~ TVD DOL Torque Days IDrag Last Casing Size DFS Hrs. ,~' ~" IRot. Wt. · Set @ ~ ~"8 MD I To',al Rot. Hrs. Days Hrs. IP/U W!. ]Slack Off WL , IShoe Tesl ~8 ~'o TVD Cum Rot. Hrs.: On Casing ISince Last Cal. Liner Set @ wt. /0.7 Wt® Ither MD - TVD- TOP @ EMW MD ' TVD Sand /7.,_~'~ 1PH IFC /.'7 ~aus,'.ic IcA Avg. Drilling Max. Drilling IConn. Trip ]Trip Chlorides M 0 Angle Direction TVD Rum! Hrs. I Remarks Coordinates VS DLS Out ] Feet ' I Liner I Str°ke J I I I Ix, I SPM Pressure GPM Jet. Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending L9 Midnight 7'esl Drill Daily Mud /~. ~. o ro o o o/o Ao ,"d -IComMud Daily Tangible /3z, ~4'..s- I / 7., 2~'~ IPotH~O . {Fuel IRig Phone~lO 7'-784 - Cum Tangible 5"77~' IDrilling ~ r~O x] ' Rep. Daily Well Icum Well q-4._Sq-,_T I Z, Zl.~.. JTotal Appr. _ ~ ?8_% ~u~s~d middle G01211 Primed m U.S.A. CC-Morn. Compaoy Weft Depth DOL Torque u~'A 799Z ~9 IRegion I~eSi~e~¥) ICh. Code ~/A N ~' / Z 4 4- MD '7/8..~ TVD ( DFS Days Hrs. ~-~' IField Drilling Morning Report O~v~s,on d ia~ ka Proposed TD PBTB) ~0~/ MB ~Z~ TVB Days Hfs. TotaI Rot. Hrs. IDrag IRot. Wt. P/U Wt. Last Casing Size ~:~ ~,~" ' Set @ ~, ~:' MD .~"~ Cum RoL Hrs.: Depth Worst Wear On Casing - Isince Last Cai. - Liner Set ~ - MD ~ TVD-TOP ~ ,m 0 Ge~/M~ 0 /~/. Z CLz~. O0~ IC^ Material '~A ~" ~/~'A/~'~' ~ '~. ~/., CIs. Other JSlack Off Wt. TVD Ish°e Test _ EMW % Rem._ MD - TVD 4'~ IPV '~1~ )YP %SandT/"' IMeT /7.,~ IPH E~i~e El Stab Salt Z'7.,~ ~ O0 CaO~ Il 7.~ Drilling No. MD -,-~ ITota! Length Max. Drilling lCD... ITrip Trip Chlorides Angle Direction TVD Type Ser. No. (H.W.D.P.: ,nj Consists of Feet I Remarks Coordinates VS ~I 4- L/Z) /z SPM Pressure GPM Operations Coverin[ Jet Vel. 24 Hours Ending @ Midnight Ann. Vel. Bit HHP Pump HHP d~,~l¢ ~ r~, Z-~'O 0 ~lu o ~ Z~oo p~ . ~ "' '~ -Ye IOoo Daily Mud Drill H~O ICum Mud IOaily Cum Well /~Z//~?,-~" I Daily Tangible_ Cum Tanmble Well Zo5-, ~gZ 3&~ zo? ~Z~,/3 7 Z, ZTO, - z~Z ~7~5 I 60 1211 iCD-3,85) ~re~eod CC-Morro ICompany Well IDepth Last Casing Size Cum Rot. Hrs.: On Casing Liner wt. I0, ! ~qqz MD Days Set @ JCO ,el,~/ / WL Drilling Morning Report IRegian J.~A,.)~'S '~4~ Ioivisi°n Code ~A~U ,6'z4,¢, ~'"'~ ~z~A ~/~ ~/g~ TVD ( ~ PBTD) MD DFS Hrs ]Torsi Rot. Hrs. - Hrs. 3~ Days -- . Set ~ ~ ~ MD ~ ~ TVD ]Shoe Test I Oepth Worst Wear % Rem. JSinceLast Cal. "'"" ~ of / Wt. Material '"' MD -- TVD -TOP @ MD TVD Other JPV /(..~ JYP lq · ~ ,~ HT-HP ~ FC / ISolids ~ I%Oi, ~ H/Mt OlI.Z Angle Direction TVD _ / Coon inates V S g LS ' SPM Pressure GPM Jet Vei. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending L9 Midnight Drill CC-Morn. ICompany Well Depth DOL 7~q ~- MD Drilling Morning Report I Region l,.,,IJ ~ ~---i~/J ]Division ~ TVD ( '"" PBTD) IPr°p°sed TO DFS Hrs. ~ I Days ~J~]~"~l MD 7~,~¢;~ TVO Total Rot. Hrs. Hrs. 2 ,..~ ~ Torque Last Casing Size ,/~'~ Set @ Cum Rot. Hrs.: On Casing 117/t ISince Last Cal. .inet IRot. Wt. _.. I PiU Wt. ._._ I Slack Off Wt. _.... ,~,.~(.j.~' TVD Shoe Test I Oepth Worst Wea.~_. % Rem. 17"Z, EMW Set @ ----' MD --- TVD- TOP @ -- MD ---- TVD CO Solids /1~ ]% Oil 0 I ther &vg. Drilling m Max. Drilling _.. Conn. ~ Trip ~ Trip Chlorides ~ ]Remarks ,~0 ~, ~ M D Angle D~recJon TVD J Coordinates V S D LS I SPM Pressure Ann. Vel. Bit HHP Pump HHP S"o GPM Jet Vel. Operations Covering 24 Hours Ending @ Midnight rTr~OO t4 Daily Mud Drill H20 ~ '77l CumMud /28.(:}78 J Daily Tangible -- IcumTangib'e JSq,~J7 DailyWel, 2~OZ/I~ CumWel, ~SZ~,~,~, GO 1211 160-3 851 Primed m USA. CC.Morn. Ch. Depth 7~ MO DOL Days Torque -... I Drag Code IRegion TVD Hrs. ]DFS Rot. Wt. Drilling Morning Report I Proposed TD PBTD) ~( MD 7~ TVD JTotal Rot. Hrs, Days Hrs. ,~4 ~ J P/U Wt. ~-- -Slack Off Wt_ _ ~.~' TVD ]Shoe Test J'~'~"~ EMW Last Casing Size 13"'%/~ Set @ MO Cum Rot. Hrs.: On Casing 11'7 e/Z- ISince Last Cal. Liner .-- Set @ ,wt i 0 WL 7'2 I ~JC C~ JType Depth Worst Wear ~ J% Rem. Material ther HT-HP -- JEt / Pf/Mf or/.4 TVD I¢ Avg. Drilling Max. Drilling M D Angle Type X3/I Length Conn. ~ Trip Direction TVD Set. No. (H.W.D.P.: Jets ITrip Chlorides SPM ~5 Pressure GPM Jet Vel. O~e~atinns Coverim 24 Hours [riding ~ Midni§ht Ann. Vel. Bit HHP Pump HHP Daily Mud /¢7,t, Cum Mud Z,~ '~/~O'Z Daily Tangible __ JCum Tangible I~.~i:;J',~"J 7 Daily Well ;JJ44 ]Cum Well ]. ~ ~j 4J~ 60-1211 160-3-85l Primed ~n USA CC-Morn. Company 4g~o ~,~1.- q Code Drilling Morning Report I Field Date I I , o,, Proposed ID TVD ( ~ PBTD) ~/ MD ~~ TVD DFS Hfs Total RoL Hrs. Hrs. ~ ~ Days ~ . JPiU MD Depth DOL 7~q'.a- MD 3 5 Days "- _ ]Drag ..-. Torque Last Casing Size J ~, '"~" Set @ Cum Rot. Hrs.: On Casing 11'7 1£ IS~nce Last Cal. 3q ?:,5 Liner Set @ -- MD wt. 10 · 0 ]co /~¢0 Gel~/~7/~"~ Wk 7'~ HT-HP __ FC Pm Wt. Material Other .., IRot. Wt. 0 PfiMf ....- Gel _ Caustic TVD Shoe Test Slack Off Wt. -~. J"7' 2 EMW jType 5 Avg. Driiling_ Max. Drilling_ Conn. ,.., ITrip M D Direction Angle TVD Depth Worst Wear --.. ~ TVD- TOP @ I JSolids ,/0 % OilC) CL 30,~ iCA ,,20~ L g. _ J CIs. -.-, I Rem. ~ MD TVD IPV /'7 ]YP I% Sand~,~ MBT /7'~'" JPH 7"~ I CaCb -- oral L~......~ (H.W.D.P.: Rum Hrs. -- ITrip Chlorides . Remarks Coordinates I In J Out Feet I I Consists of VS ~~,~. J Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending L9 Midnight Daily Mud 0 Cum Mud l ~, ~'63~ I Daily Tangible .-.. Drill H,O --- iPot H,o IF.el Rig /~j~l/i,j~,~j~O~,~, '~ ~ Rig Phone ~ .~ ~. ~ 7~ Z Cum Tangible/~,,..~ ~.,/7 IDaily Well '~,Z44 ~ Cum Well Wt. JBulk Cmt. ~__ ~ ITotal Appr. ~ _ Drilling Rep. ~ ~ ~ ~ci~el~ b~JJ~ ~' - Pnn~e~ ~n U S.A. CC-Morn. Drilling Morning Report I Proposed TD Depth "7~- MD 71g~ TVD ( '"" PBTD) ~:),,~ J MD "7,~C)q TVD Torque J..~ ',~S 0 -- ]Rot. Wt. Orag P~U Wz. ~ Shoe Tesl iLas, Casing Size l~ Set~ ~~ MD 32~ TVD ]7'Z EMW On Casing I J~ ISince Last Cai, -- Liner "" Set @ - MD TVD - TOP @ ~ MD ----- TVD Other ..,,.. M D Angle Direction TVD 'k~ Coordinates ~ V S D LS No. Size ~ Type Ser. No. GPM 3g? Jet Vel. Operations Covering 24 Hours Ending ~ Midnight Bit HHP Pump HHP ,, 06 cro W~u/u/,li,u 6 .~ c~ ~. jCum Tangible / ~'"~ S,I '7 ]Daily Well 4 ¢'70 ( JCum Well / 7ZJ~Z Wt. JBulk Cmt .... ~....%,.,,._ J Total IBulk IDrillingRep.~,.~q~S I~~ IAccidems Appr.~,~~~/~ G0 ]211 lCD3 B51 Prmted ~n U SA. CC-Morn. tCo~pany ~ ~ £ U ~'0~ Ch. Code Depth DOL "~.~ Days I,,~O Drag' --,, Drilling Morning Report Proposed TD G~ffO TVD ( ~ PBTD) ~1 MD 7~0E TVD BFS ~ ]Total Rot. Hrs. Hrs. ~ ~ Days Hrs. ~ ~ i~ Last Casing Size Cum Rot. Hrs.: On Casing I 0 ~ ~ ISince Last Cal. Liner Slack Off Wt. Shoe Test o ~:~ ~3 6 MD ~ ~ ~ TVD I 7 EMW ~ Depth Worst Wear ~ ~o/~ Rem. Set @ -- MD -' TVD - TOP @ m MD -- TVD CO wt. I0 Pm Wt. Material Ither Avg. Drilling = Max. Drilling .--., ]Conn. .-.-., Trip ,._,, TVD No S ze Type Ser. No. Jets In' Out Feet II ~ Total Length 172g' oD(H.W.D.P.: ~o~l~r~ t~ c/x-ol ~lz ~l~~ /z ~ ~1~~i ~1 I Pure Hrs. jo Liner Stroke SPM ~ IS sO Trip Chlorides.....~ Flemarks "~VO ~ ~.~ . Coordinates V S Pressure GPM Jet Vel. 2ooo :~g 7 I 37o 70 I Operations Covering 24 Hours Ending @ Midnight 7305' .-1',0 745~' 6 Ann. Vel. j) ¢,..,. Bit HHP 2~o IPump HHP / /~0(~,3~ Daily Tangible_._.~ Cum Tangible /s~ ~'/ 7 Daily Well ~ Well // 70~ Drill H~O ~ JPot H~O ~ Fuel ~ Bulk Wt .... Bulk Cmt .... ~_ JTotal Appr. 601211 lCD 3 Pnnled ~n US A. CC.MOrn, Drilling Morning Report ]~°~"~"~ c~u~o~ usa ~,o. ~,~,~.~._~,~ /v,~,on ~~ JDepth 7~ MD ~~ TVD ( ~ PBTD) Proposed TD ~O~J MD ~0~ TVD iDOL ~ ~ DFS ~_ Tmal Roi. Hrs. ~ ~ ~ll ~ Days. ~ Hrs. J , , ~ Days , -- Hrs. J ~ ~ '~. lTorque ~ Jgrag iRm W ~j.~ ~ JP'UW' ~~ JSlackOflW~ ~ ILast Casing Size / ~ ~/o w ~ ~ ~ .~ ~ ~. ~ IShae Test I~ ~ ~ Set ~ ~m MD ~7 TVD J l¢'~ EMW Cum RoL Hrs.: Depth Worst Wear % Rem On Casing ~0 ~ JSince Las, Cal. -- -- -- Liner ~ -- Set @ MD TVO - TOP @ -- MD -'"'-- TVD Other Avg. Drilling ... Max. Drilling -- Conn. ~ Trip ~ Trip Chlorid~_, Remarks M O Angle Direction TVD Coordinates V S J OLS / I I P i L'eI ~,,0~. I ~,M I ~,.s,,,. ~'~ i ~,~W,.i b~ ~.,. W,. ~ I~,, HHP I PumpHHP II I , I I Opermions Covering 24 Hours [n.ing ~ MidnighJ CC-Morn. Company DOL Torque Last Casing Size Ch. Drilling Morning Report Proposed TD MD ~7~ TVD ( ~ PBTD) ~ ~1 MD 7~~ lVD Total Rot. Hrs. -- Hrs. -- DFS ~ ~ Oays P/U WL ~~ Days ~~ fi~_~rs. i,~,. w,. ~~ · ~~o /3~ s~ ~ 3~~ ~ ~~ Tw EMW Cum Rot. Hrs.: On Casing Liner Set ~ --' MD --- TVD - TOP @ -- MD ~ TVD ~v,. fi,7 icc /~e~.- Type ~0/.¥ ~ZZ(S 1< Ev 4~ PV / z. ]YP '~/ ~',~l,sl~z w~ ~.~ ,:_,, - '~ ~ ~o"" ~., 1%0" o ]~'~n'--m 1~' '?'~ I'" '~'" Other . i ~ IA~,. ~,,,,,.,_ IU,x. ~,,,,,~ mconnm T,, Trip Chlorides Remarks ~0 ~A~ I M D ] Angle Direction FVD Coordinates V S ~ D LS No. I SizeI Type I S~[' NO-I J,,~I ,, o,, I F~~, m Hrs.I WOB I RPM IT BIG I I ' sPM Pressure GPM Jet Ve~ = b p A"" a Ve~ m b ~ Bit HHP Pump HHP I 7.~ i Opera[ions Coverino 24 Hours Ending L9 Midnight Daily Mud ~0~7 Cum Mud /O~'~t IDaily Tangible ---- CC-Morn. MD ,~;~1 TVD ( ~ 3~ Days Drag '~' Torque [Last Casing Size /'..~,.~ ~ Set@ .~ fCom Rot. Hrs.: ~ On Casing ~/~ ISin~,_L~ Cal. Liner Hrs. DFS IRot. Wt. Drilling Morning Report JProposed TD ~ 7 ~ PBTD) ~&& MD TVD Total RoL Hrs. MO 3~'~'~ TVD ISh°e Test Depth Worst Wear -.. % Rem. MD TVO- TOP @ -'" MD FV ~ PV Slack Off Wt. 6~,~(0~) / 7',~ EMW TVD po .y pLc~ k' Avg. Drilling MD Max. Drilling ._ Angle -,,, FC / ] Isol'ds ,~.~, l% Sanc Conn. .,,. ITrip Trip Chlorides.,,.. ]Remarks /Vo ~;A$ , Direction TVD $ Coordinates VS TYpe Ser. No. ] Jets ~ ) Consists SPM Pressure Out Feet I I GPM I Jet Vel. ~),, p,, Ann. Vel. ~. C · Bit HHP Pump HHP Operations Covering 24 Hours Ending L9 Midmgh! Drill H~O ~ Pot HzO Daily Tangible Fuel _. [Cum Tangible/.,,,,~,~/?IDaily We,I $5;[;'$ I-- ICum Well IIDrilling flep,~~ I j / [Accidl~nts Primed m Lj S A. CC-Morn. Company Well Depth (~, (~:)~ MD DOL ~ Days Torque Last Casing Size l ~"~"/~ Set @ Cum Rot. Hrs.: On Casing inet Set @ Drilling Morning Report ]Region ~,.~,~,.,..~,~...~,~/ Division .,~~~ J Proposed TD ~~ Tva ( ~ PBTD) ~ ~ ~ MD 7~7 TVD DFS Total RoL Hrs. Hrs. ~ 3 Bays Hrs. / ~ 7 Drag ~ ~oLWL/~~ jP/uw,. ~~ s~kO, W,. ~~. 3 ~5 MD 3~q TVD Shoe Test 17'~ EMW J Oepth Worst Wear % Rem JSince Last Cal. ~ ~ ~ MD ""' TVD - TOP @ '--' MD '-- TVD ITvPe ~oLY ~L~ lC Fv ~0 jPV I~ YP j Solids ~ '0 %Oil 0 I% Sand ~1~' MBT Z~. '~/' Drilling,,..,_ Max. Drilling ~ Conn. MD 5772, Angle Type Direction Trip __ Trip ChloridP,;~.. Remarks Coordinates TVD .5, ~, vs Set. No. 8; I In Out Consists of i S PM Pressure 55 170o Feet ~PM JetVe,. J De I Operations Covering 24 Hours Ending L9 i.Midn]ght #2--12 Ann. Vel. ~C. .Bit HHP Pump HHP /Go ! AtJ~£ J~o ? Daily Mud J24 ~(,~ Cum Mud f(~ 13~ Daily Tangible ,---, Cum Tangible / GO 121! !CD 3 85i Pamed 1il U.S.A. CC-Morn. ICompany Well Drilling Morning Report I°~vis'°n Dep,b 5" 73~ MO ~<~ ~Z . TVD ( Torque i~'~ ..~0 I~~ ~I/U ,2(.~0 ]Roi. WI_ Las, Casing Size /,~)~ Set @ ,~ Cum,or. ,rs_: On Casing JSince Last Cal. Proposed TD PBTD) 7qS.~ MD 7207 Total Rot. Hrs. Days Hrs. 176 Vz MD 32(m ~ TVD ]Shoe Test Depth Worst Wear ~ [% Rem. ,...,,. Liner q'7 Set @ '"" MD CO l/llcO Ce,12/4~ WL ff-o Pm Wt. Material Other Avg. Drilling MD PfiMI / ~mb IMax. Drilling Angle '" TVD -TOP @ -* MD "' _Conn. _ IT~,o _ Trip Ch,oddes _ J~emarks Direction TVD Coordinates TVD EMW VS 13&7 2 $1o $..~o $Io~ $IOE. 4'f.27 46;7Z 47qE Jets ~1~ Length ll.6~j.$~. Type Sar. No. .lc. 7/'/ (H.W.D.P.: tqlq 1371 1377 2~6q l q43 /3~Z 1975 In j Out 4q17 573' Consists of ~1 Feet 2414. TVD 7.8 SPM Pressure GPM Jet Vel. ~:).¢, Ann. Vel. 62. I 3(.,5- 7o I , Operations Covering 24 Hours Ending L~ Midnight Bit HHP IJo 70 Pump HHP / 41A),,~96.¢. co-oeA~lqgs ~ ,glo. v$ }Dai,y We,,$ 8'6/,3 Daily My,~, 0 ~.~ ICom M,d 77~&z ]Dally Tan?~. JCum Tangible JB.Ik Cra,. 72 &~sx JTota, App,~,~ 9~,,~000' ~ Accidents /V,/{i~¢;, JC.m Well GO 1211 lCD 3-85) PHnted ~n U.S A. CC-Morn. TVD ( Drilling Morning Report. PBTD) ~Proposed TO 7~5~ MD 7~o7 DOL ~7 Da~ Torque 1 f.,/,~D IlO _ [Drag Las'( Casing Size Hrs. IDFS Rot. Wt. Cum Rot. Hrs.: On Casing I.~ ~/~ s.~ 373~; ,~,.~ ~Z, [Since Last Cal. Days IDepth Worst Wear JToJal Rot. Hrs. Hrs. iS,ack Shoe Test TVD / '7' ,~. I % Rem EMW Liner Wt. Set @ -" MD -- TVO- TOP @ -- MD ~ TVD Type i "'" I%°" o CL 30t0D,D CA L g' I C!S' ~e,15/41/,~7 WL Pm Wt. Material 8,(~ HT-HP _ FC Other Max. Drilling ~ IConn. Angle - Avg. Drilling MD z/870 007 2 xN~lb¢ Direction Type Ser. Ne. x3n Z ~. 718 Trip 0 [Trip Chlorides TVD .4 4.~4 771 Jets in I Out 3'¢/4 J 4 7.~4 . 4 q t 7 Sx/xI ~tt7 j (H.W.D.P. ) Cons~s,s o, 12~. SPM Pressure Coordinates V S J DLS I 13~+4. 2217 13:~Z 2236 · 13~ I 2277 I ~o~ ~ ~ ) ~'~ I ~o/ I GPM Jet Vel. 37c,. I $~ 70 ! Operations Covering 24 Hours Ending L~ Midnight Ann. Vel. b~ IlO Bit HHP Pump HHP 2 7o HoLE ~,o. OC, oo.~ b(ttc Daily Mud ~3&~ Cum Mud G~.~'~' Daily Tangible -- Cum Tangible J~?,,~'/"7' ion,iv Well &6~'~O Cum Well 1~4a3~4o GO-1211 lCD 3-85) Primed in US.A. CC-Morn. ICompany ~ ~" U ~C~mJ ~S ~ Depth 4 75~' DOL ~ & Days Drilling Morning Report ther Torque MD "~ ~ 7.~, TVD ( iDFSHrs. ,~0 Days IR°t' wt' c~.% IProposed TO PBTD) '7 ~Z3 MD TVD Total Rot. Hrs. Hrs. TVD ~s,o~ T,~ 17' ~ EMW J % Rem IDrag J Depth Worst Wear JSince Last Cal. MD TVD -TOP @ MD TVD M D Angle ] Direction TVD Coordinates V S ] O LS ' 4~3~ 31'~ ] 82~E ~o~ lf~o /~4& iq'TG J ILength : "~ 0'-~Z ' · onsists I , l i~ SPM ~0 Press.re j/?c~ 3 (,:, 1 GPMJJ' Jetvel. j 0{' Ann.jVel. '~0 7o J Operations Covering 24 Hours Ending @ Midmght Bit HHP ,~00 Pump HHP bl?l~.t/~u6 Ai4EAB i:£ord 3qgo ~-4'154' ..--/'It~,o' cz. AY ,~,/ ¢_o,qL / o £u,euEY /nO 4c~54 kuc. c~' 2Z-~ ~.0. O&oo - (.o~."£t="cT /~v¢ HoLE b,~Ec~ /o/v ~./ ,t3y, vAOl¢/z~ .x i ~ ° B~T ~ vd ,*lb 474= Afo~,~.g 20.Z b~' S Z~.zIE Oai,~ Mud ,4 772 grill H~O IPot H~O JRig Phone JDail,/Ta,gible ~ Cumfangible ;s%</7' °ail'Webq,2qt JC.mWe,, /..4477C0 G012t! lCD 3 851 P,,imed m USA. CC-Morn. ICompany Well Drilling Morning Report Division ../~ L A & ic A ~$ Days Hrs. Torque ~Drag Rot. ]LaSt Casing Size 1Field '/'~'/"C)~,4 .//~'~i~' IDale C~ /~01[~-.~ PBTD) IPr°p°sed TO '7 i~..~ J MD ~0'7' TVD iq Days Hrs. ITOtal ROL Hrsl ~//"~ Cum Rot. Hrs.: On Casing ,Z~ JSince Last Cal. Liner Set @ MD Gelc~/./i l j,.~ WL 7' ¢ ,,-,, ._ j~ Wt. Material I P/U w ~ I I Slack O, Wt. I ~ Shoe Test MD -.~ 2 ~ dj TVD t 7- Other ~,vg. Drilling Depth Worst Wear % Rem. EMW TVD- TOP @ MD TVD ~7 Max. Drilling JConn_ ITrip ITrip Chlorides Remarks M D Angle Direction TVB ~ Coordinates I~' V S I D LS 41o 7 35 ~to.~£ 2,4 oo 14~;6q /~t-o~ ~qoq SPM Pressure GPM Jet Vel_ ~ ? Ann. Vel. ~) ~ Bit HHP Pump HHP I Operations Covering 24 Hours Ending L~ Midmght Daily Mud (_.j ~5 i I Drill H~O I Pot H~O Rig /~¢t&Jf( e~~-C''~'E ~ ~i IRig Phone I Daily Tangible _ Cum ~,¢,, 15~ s ~ 7 ida,,, Well ; S.~'~ 7C Ic"m Well 6 '~ ! ~ Z ~ G0 12!1 !CD 3 851 Primed m U S.A CC-Morn. Company ICh. Code Depth ~ ~ ~ 0 MO DOL Torque Last Casing Size Cum Rot. Hrs.: On Casing Liner I"e~°" w~/e? TVD ( Days Hrs. IDFS IOrag IRot- wt- JSince Last Cal. Set @ MD Wt. CO WL Pm .1 I HT-HP . Pr/Mr .Z Gel / Causti~ Material Other Drilling Morning Report °'v's'°" A l,u-k,, I~"'" ~h~/~s [,,,e , o,/ PBTD)U ]Proposed TD 7q35 MD 7Z07 TVD ITotal Rot. Hrs. I 8 Days Hrs. IP/U Wt. lSlack OH W'- MD ..~ Z~ ? ' TVD ISh°e Test IDepth Worst Wear I% Rem. EMW TVD - TOP @ MD TVD Solids IFC Z Lig. IFV -~-3 ~Z ~ ~ PV IY P I,o,, ,:, J%Sand IMBT ZO Avg. Drilling Max. Drilling M D Angle Conn. JTdp J Trip Chlorides JRemarks Direction TVD Coordinates Type Ser. No. Out J Feet - /. VS (H.W.D.P.: ~Ooq ~, ' ) SPM Pressure GPM Jet Vel. ~,p Ann. Vel. ~(.. Bit HHP Pump HHP Operations Coverinl! 24 Hours Ending @ Midnight 75' /1_~ ~oe~'. T~-ted 4/~" p,~e rams ,. choke . ~+ a+~p+ % ~~ ~t t2~" Cs~ ~ /soo -~~ I~- t~0 psi ,lb lo m,~ -- . drill 3°, of ne~ hole ~/39~o'- ~98o~ ).4om/~ated mud + ¢reo~ m~d ,A p/l~. ~,~ , c~ Y.Y/PSz PHP) &'mW /Zz pPJ. Grame~d 0.8'9(=, ?~/£~' Drill HzO '43 CF--,(°' r,~,. ,~, JDaily Tangible Cum fanqible I /5-% ~'/7 I Bulk Wt. G0-1211 iCD-3-85) Primed ,n U S A. CC-Morn. Drilling Morning Report Depth M'D TVD ( PBTD) [Pr°p°sed TD 7~2~~ MD 7ZdT' TVD DOL [DFS al Rm.'Hrs. ~ ~ Days Hfs; / ? Days Hrs./ / ~ ~ On Casing JSince Last Cal. Liner Set ~ MD TVD - TOP ~ MD TVD Gel ~/~ WL J/- HT-HP . iFC ~ ISolids ~, ~ %0il 0 [%Sand ~ MBT~.~ ]PH ~ Pm PI/Mr C[ CA Ex Lime El Stab Wt. Ma[erial Gel jca.s,ic Lig. CIs. Salt CaCI~ Other j Avg. Drilling Max. Drilling JConn. ITrip Trip ChloriOes M D Angle Direction TVD · Coordinates V S BLS No. Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM T B G Total Length (H.W.D.P.: ) Consists of ~um~ liner S~roke SPM Pressure G~M ~et Vel. ~nn. Vel. 8i~ HHP Pump Hrs. O~erotions Coverin~ 24 Hours [ndin~ ~ ~idni~h~ head. 60 ]211 ~CD 3 85 Pnnted m U.S.A. CC-Morn. Drilling Morning Report Company Depth C. hecron uSA Torque Oays MD Region J/~'~' ~,At441 z 44 TVD ( Division PBTD) IPr°p°sed TD Last Casing Size I Cum Rat. Hrs.: On Casing Set @ ICh. Code 14, Days IDepth Worst Wear IOrag IRot. Wt. Liner Hrs. IDFs Set @ 3 ~ ~ ~' ISince Last Cal. MD . CO TVD-TOP @ MD Hrs. IT°,"' Ro~. Hr-s. t.~ 9 , JShoeTest TVD EMW I% Rem. MD TVD zz 34, Solids ICL Avg. Drilling Max. Drilling Conn. ITrip M D Angle TVD V S Direction ITrip Chlorides IRemarks Coordinates Length Type Ser_ No. ,n .j (H.W.D.P.: ) Consists of ' SPM Pressure GPM Jet Vel. Out Feet Ann. Vel. Operations Covering 24 Hours Ending @ Midnight Bit HHP Pump HHP Daily Mud Drill HzO 0 Icum MudZ'~,.~ ~, "~J IDaily Tangible JPot H~O IFuel I Cum Tangible JBulk Wt. JOrilling Rep. D~iLY' PROGRESS OF DRILLING WELLS ,'ro-562 DRILLING DAYS / ~' CUM. ROTATING HRS. WELL NO. DEPTH FROM gEtJ 23z-q 3 ~5~ ,T/~--~ BIT NO. B IT NO. FT. TO FIELD ~/~/J& J'~l I,/e~ CONTRACTOR SIZE MAKE-TYPE Fi:ET SIZE MAKE-TYPE FEET FT. FT. I N H RS. DRILLING SETUP WT. ON BIT / /' HOURS JETS / / HOURS JETS 1000# SPEED CONDITION CONDITION RPM LAST CASING PUMP OUTPUT DRLG. FLUID SURVEYS SIZE AT GPM FORMATION DEPTH ANNULAR VEL. MUD CO. ~/100 SQ. FT. YIELD PT. PPM % CHLORIDE OIL TYPE CC WATER LOSS PPM CA pH PUMP PRESS. FT./MIN. (D.P.) NOZZLE VEL. PSI@ FT./SEC. PCF SEC. WEIGHT FUNNEL VISC. PLASTIC rISC. CC /32 % HToHP WATER LOSS FILTER CAKE SOLIDS SAND ALK GALS (% MIN.) OTHER REMARKS SPM CPS · 3o - c)o .' .7o zooo ps i. Had ~- 3-~ bgl~ cl i'~ ? surl'a~e, Float5 held. _~4ar~t m~'~ c iP e oo: /q, Dratn 19 '.40. CUMULATIVE MUD COST CUMULATIVE Z ~-: /- 7 / DALLY cOST // Z~//744 3'zz.7 Da'~ly z zz, 4.~c~ DRILLING REPRESENTATIVE RIG PHONE NO. ~90'~)- 784 - ~ 7..~Z- Pro-562 (CD-4-78) Printed in U.S.A. PROGRESS OF DRILLING WELLS ,-ro-562 DRILLING DAYS /~' CUM. ROTATING HRS. _~;~ o&oo ?/z7 · WELL NO. DEPTH FROM ~Ku z3z-q 3'7490 ~-uD B IT NO. FT. TO FT. DRILLING SETUP FIELD ~/UJ~ ~F~i ~/f / CONTRACTOR IZ"~4" '/" ~ 17/z ~cu~/TY 18/Z zg,S SIZE MAKE-TYPE FEET HOURS SIZE MAKE-TYPE FEET HOURS FT. IN HRS. 1000# JETS CON D ITl ON' / / WT. ON BIT JETS CONDITION RPM SPEED LAST CASING /.~ ~" ' AT ~ ~,~' FORMATION SIZE DEPTH PUMP OUTPUT GPM ANNULAR VEL. DRLG. FLUID SURVEYS MUD CO. TYPE Z 7 #/1 O0 SQ, FT. l Z, ~ CC YIELD PT. WATER LOSS PPM (~ % 4-0 PPM . CH LORI DE OIL CA pH PUMP PRESS. FT./MIN. (D,P.) NOZZLE VEL. PSI@ FT./SEC. ~'~' PCF ~_~ WEIGHT FUNNEL VlSC. -- CC .~ /32 HT-HP WATER LOSS FILTER CAKE /W /- -/ /z Z. ALK GALS (% MIN,) SEC. Z_.~ PLASTIC VISC. SOLIDS SAND OTHER REMARKS SPM CPS 06:30 - J &: $ o / 19:30-0o:3o b ~'lu H~o. t4allTb~r4on.' Tcs¢ i,6~.~ ~ z.s'oo ps,'. P,.,~ped /o /:,k,I ('res/-, ml~¢d + P~mped Icad slurry o l~ zoz...,¢ s~ (;~3~'i ~c¢~) c/ass cUMULATIVE MUD COST Cs'z/ 3'zz~ ~/ 4,% d~y 9el e 11.9 ppJ s/orr/ o ,C class ' C. ' cemen4' ~,,/ ~ 7. dry jcl .' Z~,/o pp_~ . ~l~ dl:~pJaced w/5'7_~ ~bl rnvd. CUMULATIVE DRILLING REPRESENTATIVE, DALLY COST J I Z~,/I .~4/.~ '- Da;/y zzz, 4~o RIGPHONENO. ff~07)- 78&-~ 7~Z Pro-562(CD4-78) Print~ in U.S.A. D.ILY PROGRESS OF DRILLING WELLS Pro-562 DRILLING DAYS J3 CUM. ROTATING HRS. o6o0 9/zs' WELL NO. ~J~'O DEPTH 3~-~'O 7'~) ~ NO. Z _.? z 8 o "F V D -mT NO. I IZ~" "" SIZE MAKE-TYPE SIZE MAKE-TYPE CONTRACTOR / ozz /&. 5- FEET HOURS ~ ZT.~ FEET HOURS ?o~.lT' JETS CONDITION JETS CONDITION FROM Zi3Z~ FT. TO _~l~O FT. /ozZ FT. IN /~.~-HRS. ZO 1000# ~70 WT. ON BIT SPEED RPM ORILLINGSETUP bu/J nose; iz /4 "z lT'/z " hole ope~t,.'.. .1~, i LASTCASING ZO" AT 37~ FORMATION ~¢]/C/~/~a~ PUMP PRESS. SIZE DEPTH ' pump OUTPUT ~~ GPM ANNULAR VEL. ~ - FT./MIN. (D,P.) NOZZLE VEL. - FT./SEC. SPM DRLG. FLUID MUD CO. .~'~ #/100 SQ. FT. YIELD PT. -~"O~) PPM /'~ % CHLORIDE OIL SURVEYS TYPE J ;Z. I cc WATER LOSS CA pH 9- I PCF {~1 SEC. WEIGHT FUNNEL VISC. PLASTIC VISC. - CC --~ /32 ~ % HT-HP WATER LOSS FI LTER CAKE SOLIDS SAND ALK GALS (% MIN,) ' OTHER REMARKS cPS (~!~/' . .' eo - 11'$o ' Ir'oM. 03:2o-o4:Jo o~: 20 - O ~ .'oo /v q" ~e /d r-a 4e, Treaded t zoq~ - om. /z~" ;~ole ~ /7~" ~,Pehole ~ Opm iz ~ ~ ~o/e I O oen IZ ~ " hole ~'~ ~ ~ ' up. CUMULATIVE MUD COST CUMULATIVE DA~LY COST 25'71 Da;ly .~/, q ~" lz ' DRILLING REPRESENTATIVE ~Y~ r'~ -- RIG PHONE NO. (qO'7)-- ~-~,73,Z. Pro-562 (CD~-78) Printed in U.S.A. D~IL¥ PROGRESS OF DRILLING WELLS Pro-562 DRILLING DAYS /~- CUM. ROTATING HRS. WELLNO.. ~'~'0 Z~Z""q FIELD ,~'~JC/Oa ~'lV~*g" CONTRACTOR ~ Z ~0 ¢~ SIZE MAKE-TYPE FEET BIT NO. HOURS JETS CONDITION / / SIZE MAKE-TYPE FEET HOURS JETS CONDITION FROM ,~/~0 FT. TO ,,~-~ FT. 77~) FT. IN /3 HRS. Z~:~ 1000# ~0 RPM WT. ON BIT SPEED 17 '/z s'-)-ab, LAST CASING SIZE DEPTH PUMP ouTPUT ~ ~ GPM ANNULAR VEL. _~ FT./MIN. (D.P.) NOZZLE VEL. -- FT./SEC. DRLG. FLUID FORMATION eOQ/ k///~"~MPUMP PRESS. J 'TO0 PSI@ SURVEYS C~...~ ~' PCF --?:~ SEC. WEIGHT FUNNEL riSC. PLASTIC riSC. " CC ~ /32 c:~ % HToHP WATER LOSS FILTER CAKE SOLIDS SAND ALK GALS (% MIN.) ' OTHER REMARKS MUD CO. TYPE Z~ #/100 SQ. FT. / ~, ~ CC YIELD PT. WATER LOSS' ~'~)0 PPM ~) % ~,~O PPM CHLORIDE OIL CA pH SPM CPS DETAIL o1:oo - OE.'oo ~' c, f_.,'"o la/¢ ~- cond Po/-/, Lay m] D P ,,,:od ~r 4ol CUMULATIVE MUD COST zZ, ~-4-8 1.5'00 CUMULATIVE DAILY COST · DRILLING REPRESENTATIVE ,..~/~d~ ~ .-- RIG PHONE NO. Pro-562 (CD-4-78} Printed in U.S.A. I.,..,LY PROGRESS OF DRILLING WELLS ,-ro-562 o~oo ~/~ o~oo ~/z~ DRILLING DAYS J Z CUM. ROTATING HRS. WELL NO.. ~KU Z3Z-q FIELD DEPTH ZJ3~ ~NO. I ~Z~'~ J~ SIZE MAKE-TYPE FEET CONTRACTOR ZT._~ HOURS JET8 BIT NO. ! ! SIZE MAKE-TYPE FEET HOURS JETS FROM ]z{o'~ FT. TO ~---/-~8 FT. ~7~r' FT. IN P-O HRS. ]~' 1000# WT. ON BIT SPEED CONDITION CONDITION RPM DRILLINGSETUP ~O// no_~e, iZ~"X i-I~" hoJ~ opener..g%, Z-8"OC, _~L~/~: 8' DC, XO, XO , LAST CASING ZO AT .~, FORMATION c/ay/S~~/PUMP PRESS. /8OO PSI@ ~0 SIZE DEPTH PUMP OUTPUT ~ C~ GPM ANNULAR VEL. ~ FT./MIN. (B.P.) NOZZLE VEL. - FT./SEC. SPM DRLG, FLUID MUD CO. TYPE 33 #/100 SQ. FT. //. B CC YIELD PT. WATER LOSS SURVEYS · ~'00 PPM (~ % ~'~ PPM CHLORIDE OIL CA pH q. O ~' PCF ~ ~ SEC. ~--~ WEIGHT FUNNEL VISC. PLASTIC rISC. -- CC ~-~ /32 ,,, ~ %. ~/'~j~ -HT-HP WATER LO~ FI LTER CAKE SOLIDS SAND ~ ~/z~ ~. z~ ALK GALS (% MIN.) OTHER REMARKS CPS DETAIL 06 :oo -07:o0 o7:oo - 1Z,'O0 \ I Z :O0 - I Z : oo j~:oo - z ~:o0 ' .... z i:O0 - Z. ZI o0 ZZ :oo - O~.'oo --o ¢ x ?o14 ~- kx ydo~ n ,/ Ope~ /~ / 7 ~ " z q 4~ -/~'78. ~v /pcr 4r,p up CUMULATIVE MUD COST .! CUMULATIVE /q:$77 DAILY COST q 7 4, oq4- DRILLING REPRESENTATIVE RIG PHONE NO.' Pro-562 (CD~,-78) Printed in U.S.A. G..,Y' PROGRESS OF DRILLING WELLS _ ,'o-562 o~oo 9/zz DRILLING DAYS /~) CUM. ROTATING HRS. WELL NO. ~'j~'[J Z~Z-~ FIELD l~el~jo. DEPTH ~0 ~0 BIT NO. ~ ~ ~ / S~ZE MAKE-TYPE 3Z~O ~D BIT NO. ~ /Z~ HTC-X3A SIZE MAKE-TYPE FROM ~Sq~ FT. TO ~~ FT. ~1 FT. IN Z.~ HRS. CONTRACTOR ~::~'~'.--..-~ Zl FEET FEET WT. ON BIT HOURS JETS CONDITION HOURS JETS CONDITION 1000# 70 RPM DRILU.NG SETUP J Z ~/~" bi'P/ /V~ .5'~Ob_t ~O1 LAST CASING ZO" AT 394 FORMATION C/~y /S~g~UMP PRESS. /~ SIZE DEPTH PUMP OUTPUT ~J~ GPM ANNULAR VEL. ~ FT./MIN. (D.P.) NOZZLE VEL. SPEED col/or.. ~Im sja b. ~-e]eeo ~n , .vms~. z ~1 PSI@ ~8 SPM FT./SEC. DRLG. FLUID ~McO Cg~l' Gele.~ MUD CO. TYPE Z ~ #/100 SQ~ FT. ,[ lo "/ CC YIELD PT. WATER LOSS ~00 PPM 0 % '~ PPM 7.0 CH LORI DE OIL CA pH ZZ ~3'. '-/ PCF SEC. WEIGHT FUNNEL rISC. PLASTIC ¥1SC. -- CC 3 132 ~' % ~;[ HT-HP WATER LOSS FILTER CAKE SOLIDS SAND ALK GALS (% MIN.) ' OTHER REMARKS ..7Z.5"9./~ -~'C t801, ..?~' CPS I # · f · I o6.:oo - · D,F c/r,/I + so rye? lz ~" 1.~o/¢ F/zSq'~ - .egz q ~, n~dHli. 15:.~o - 18: $0 /~/M. T'/~h)- ~_ 3q 78. ~e.a~ ciyrlo, cir,'lJ run ?/$47B '- .9929 ' 1 ?: oo - 2o :oo zl '$0 Z3:~O -c~Z:3o ~)~' drrlJ 4- s'ur~ey IZ,~" hole F/Seze'- oz :30- - O~: O0 CUMULATIVE MUD COST F/3 q q-O - S zoO DRILLING REPRESENTATIVE . R,G PHONE No. Pro-562 (CD~-78) Printed in U.S.A. CUMULATIVE ]7~ q~'o DAILY COST z z~7 Dd, ly ~-(,,,'lz~. b,-,ILlf PROGRESS OF DRILLING WELL~ r'ro-562 DRILLING DAYS il CUM, ROTATING HRS, WELL NO,. DEPTH FROM EKu zzz- ? tq_c~ 7'D ~ NO. $Z80 B IT NO, I lZ2~ ~17/~" ~'.¢cui~/r/ S~ZE MAKE-TYPE FEET FT. TO JZ{~' FT. S~ZE MAKE-TYPE FEET 7~ ~Z- FT. IN ..~,~' HRS, CONTRACTOR HOURS JETS CONDITION / / HOURS JETS CONDITION 1000# ~ ~:~ RPM WT. ON BIT SPEED LASTCAmN~ ZO" AT. 3~4 FORMATION ~J~z/~/c~aJ.uMPPRESS. SIZE DEPTH PUMP OUTPUT ~ 8~ GPM ANNULAR VEL. DRLG. FLUID T/~(-~ MUD CO. TYPE ,~:) #/100 SQ. FT. YIELD PT. WATER LOSS /~00 PSI@ ~0 SPM SURVEYS COO PPM 0 % 4° PPM 7°0 NJ/ CHLORIDE OIL CA pH FT,/SEC, FT./MIN, (D,P,) NOZZLE VEL, -- WEIGHT FUNNEL VISC, PLASTIC riSC, CC - CC 3 132 S % ~ % HT. HP WATER LOSS FILTER CAKE SOLIDS SAND · /o/~ ~- ~7. ~ ALK GALS (% MIN,) ' OTHER REMARKS CPS DETAIL d&:oo- 16 .'oo IB:Oo-I~.'~o ~/ J.~/ do~n heu,'wa~ pF .1 ~;3o - Zz.'3o Z z ;30 - o I ~oi; 30 CUMULATIVE MUD COST ', CUMULATIVE DALLY COST DRILLING REPRESENTATIVE ,,.~/~d~/~ -- RIG PHONE NO, Pro-562 (CD-4-78) Printed in U.S.A. L,.aLY PROGRESS OF DRILLING WELLb ero-562 6~oo o&oo DRILLING DAYS q CUM. ROTATING HRS. 75',g WELL NO. - 8 J~_ 0 Z- 3Z, - ? CONTRACTOR / FIELD geluqa J~lver' SIZE MAKE-TYPE FEET HOURS BIT NO. ~~ /Z ~ ~T~-X~ ~ I8.~ ~T. O~ ~IT lb//~/¢ - JETS CONDITION 141141/Z .~- :Y - ~- JETS CONDITION / ,,~ (::2} RPM SPEED _~ r~ne/ DC.., LAST cASING ZO AT SIZE PUMP OUTPUT _~/3 GPM DRLG. FLUID MUD CO. DRILLING SETUP IZ~" /Ql'fl Dvnadr,7/, . Z° J~en4 ~o/~, }ead co I/ar; lj ~ I-I w D P ; x o ; j n rs : x O ; I q j l ~l w Z) P , 4 '/z "DP .o~,-' FORMATION C.]C.4//-q¢::113~11 PUMP PRESS. DEPTH ' ~t'J/ ANNULAR VEL. 78 FT./MIN. (D.P.) NOZZLE VEL. PS,e q- 8 SPM FT./SEC. PLASTIC VISC. TYPE WEIGHT FUNNEL VlSC. .,~0 #/1 O0 SQ. FT. I/, ~ CC -- CC --~ 132 ,~ YIELD PT. WATER LOSS HT, HP WATER LOSS FILTER CAKE SOLIDS SAND , ~00 PPM " % ~ PPM 7,8 hll~. 8/3~ CHLORIDE OIL CA, pH ALK , GALS (% MIN.) .' OTHER REMARKS · . CPS DETAIL O& :oo - O7:30 07:30 "I 7 '00 ~ F/3&Z~'- 3486' ~.,/mud i..7:00 - OZ : DO mod mo-lo,,-5 -mid /Z Y~" b,-/ ,¢.5- + 2' be,~,/- .so&. .si%-~ ~,/ 7%/e¢o ~ /izo.' O,"~e;,,~ dy~,~d,,',l/ ~ Dvna Lube_ CUMULATIVE MUD COST 7/3 ~'75' CUMULATIVE DAILY COST ~:~/: ~' DoiJy Zq, 7oz DRILLING REPRESENTATIVE ~-~/'~d(~n .-- RIG PHONE NO. (C107)- 78(0 - (o75Z Pro-562 (CD4-78) Printed in U.S.A. b..,L¥' PROGRESS OF DRILLING WELLS~'~."o-562 DRILLING DAYS 8 CUM. ROTATING HRS. 'TAu," ,Se~.t' I ? 49 8.5' · .eLL NO. ' ~'/~.J Z3Z'-- q' DEPTH ,.~ ~' BIT NO. FIELD ~e]~lJO, J~lt/er CONTRACTOR ~ ~' /4 I Z Y¢ ~"rC- .,v'3,4. 183 B. 5 S~ZE MAKE-TYPE FEET HOURS BIT NO. ~r' I Z ~ J'/7'C- X-9~ Z / q ~' SIZE MAKE-TYPE FEET FT. TO .~5 FT. /4//u/z - JETS CONDITION IZ liZll.~ z- z-.~ HOURS JETS CONDITION FROM 3~Z ~ 4-'~Z FT. IN /,~.-~" HRS. /~"'Z~) 1000# /~ -/~0 RPM WT. ON BIT SPEED ~.,~,.~s~v~. /z~" bi+, 6r, l~ m~a m~. l~'beMsv~. sub.; 3monelflc, xo, xo, 154 n~bP, x°, Jars: xo, zo" ' G AT 394FORMATION ~and PUMP PRESS. /~00 PSI~ ~ SPM SIZE DEPTH PUMP OUTPUT ~-/~,~ GPM ANNULAR VEL. 78 FT./MIN. (D,P.) NOZZLE VEL. FT./SEC. DRLG. FLUID .._. _ .Z. rlJdO MUD CO. 4'a~ #/100 SQ. FT. YIELD PT. 70C~ PPM - % SURVEYS CH LO RI DE 3301, 3~ c~l-Gelex 8. ? PCF 8B SEC. ~ CPS TYPE WEIGHT FUNNEL VISC. /0. ~- CC -- CC 3 /32 WATER LOSS HT-HP WATER LOSS FILTER CAKE SOLIDS 4-0 PPM 7,5' . /viz. OIL CA pH ALK GALS (% MIN.) ' / · / PLASTIC VISC. SAND OTHER REMARKS '~-C 15-70. zi ,YouTH 11S3.0.E EAZT' 10~.70 DETA I L o/-:oo- 1/:.9o ;1:30' 13:00 1..?: oO ~ Z t ~.30 p'/.~zo$-3z$$. D/'r dr,Y/ 4 sur'aey Cl~Jeoo+ 7-~leco ~wo. tala brjle~ mad 1 ',/z * bea-~ suj~. /~1~4. Took 7% leco cAeck s~o-i- ~- //4z.' zl:3o-O~:oo ~"'". D,'r' dr,Il + survey IZ~"4" hole. CUMULAT ,VE CUMULATIVE MUD COST J ~ [~g DALLY COST .~174 Pa,'ly DRILLING REPRESENTATIVE ~or'dar~ -- RIG PHONE NO. Pro-562 (CD~,-78) Printed in U.S.A. D~,,LY PROGRESS OF DRILLING WELLS rro-562 DRILLING DAYS '~ CUM. ROTATING HRS. o~oo q'//q k/~d Scpf /~ WELL NO. - 'PTH FIELD l~el¢~o, J~ilJ~ t"' CONTRACTOR ER'IJ _~ Z. 3,~ BIT NO. B IT NO. -- I ZTl~l,.~ - HOURS JETS CONDITION SIZE MAKE-TYPE FEET SIZE MAKE-TYPE /F~jT~ HgU~S FROM ZT~ FT. TO ~Z~ FT. ~ FT. IN 7 HRS. ZO 1000~ ~ JETS WT. ON BIT SPEED CONDITION RPM LoC. kE'D UP ~ LAST CASING ~)~ AT .~- FOR MAT IO N C O~ J/.$'O-~/O//~-/~V'PUMP PR ESS-. SIZE DEPTH PSI@ .~"._~ SPM PUMP OUTPUT a~'~ GPM ANNULAR VEL. ~:~' FT./MIN. (D.P.) NOZZLE VEL. ~'/~a FT,/SEC. DRLG. FLUID Tl'3q(_.O C~.l - ~,ele.x ~. q PCF / Z ~ SEC. Z ~ MUD CO. TYPE WEIGHT FUNNEL riSC. PLASTIC riSC, ~ ~/100 SQ. FT. 11.~ CC - CC ~ /32 ~ % ~ YIELD PT. WATER LOSS HT-HP WATER LO~ FILTER CAKE SOLIDS SAND ' CHLORIDE OIL CA pH ALK GALS (% MIN.) ' OTHER REMARKS CPS DETAIL O&.'d~ - Oq :~0 ~'' D;'r dr) 11 + ,.~urve,,v I z 2"4-" / I1.'oo - iz,:oo ' Poll. Ha~d 8reaLS, Drop drill ?Old. FlU 87. $Z3~, ~.~.'oo - ' /zY hol 3zos' Cp wd- I oo, ro~ ~q 7z, 0oo ~ , ~7t .5-~'_.000 /~ CUMULATIVE CUMULATIVE MUD COST I I,q&4- DALLY COST 18 't-S l: a i l y 7q.5, z-~4 31, 1 85' RIG PHONE NO. ~qO?)- 78~'~7ZZ Pro-562 (CD~,-78) Printed in U.S.A. i...dLY PROGRESS OF DRILLING WELL~, .;ro-562 DRILLING DaYS ~ CUM. ROTATING HRS. ~-~' WELLNO. ~"U Z~'Z'''(~ FIELD ~E./UyO, }~'I/.,/E'/"' CONTRACTOR SIZE MAKE-TYPE FEET HOURS ~ ' S~ZE MAKE-TYPE FEET HOURS FROM /~Z? ._ ET. TO ZT~ FT. /~ FT. IN /~.~HRS. ~-~ 1000~ WT. ON BIT /_~ //3/ J F -- JETS CON D ITl ON JETS CONDITION ~ ~:7 RPM SPEED ,, , /~/y LAST CASING ~O AT ~q~ FORMATION ~//~rV PUMP PRESS. /700 PS,~ -~. ~O SPM SIZE DEPTH PUMP OUTPUT ~/ GPM ANNULAR VEL. 7~ FT./MIN. (D.P.) NOZZLE VEL 3~ FT./SEC. DRLG. FLUID .J~'m~..O C~i/&ele'Y q. / ~' PCF /O..~ SEC. Z7 CPS MUD CO. TYPE WEIGHT FUNNEL VlSC. PLASTIC VISC. ~'J #/100 SQ. FT. / ~-- CC -- CC Z. 132 ~. / % / % YIELD PT. WATER LOSS HT-HP WATER LOSS FILTER CAKE SOLIDS SAND J 3 ~)~) PPM -- % ~0 PPM ~.0 '~ /,3'/-%"~ ~//?'/.c .//..~ CHLORIDE OIL CA pH ALK GALS {% MIN.) ' OTHER REMARKS ~(.:~0-~7:30 /' ~.~rc6/~1¢ + cond mud ~ ~,rei,~ ~urv~7, 'i ~8:oo- /9:00 .-" ~//c ~ cond mud. F//32~- Z/75, /e'oo-z/:oo PoN ~w~l. z/ :oo - z4.'oo - o& ' ~/u locked up BH,4 ~ IZ~" b,'4 ~.~ ~- iV//-/. 7'._~-/ed 7-ele¢o ~O ~ ItZO. ok- h/a&~ -~ reamed F/z/5'~ - z/73 ":"~ D,rec~lt'~ml/~ dr,'// + Jurvev IZ/+ hol.~. F'/Z/73-Z74c/ (E 6A/~l · ~./- ~ ~ 7'0,0oo ~/ CUMULATIVE MUD COST Z '- .i c~ .,:. CUMULATIVE DAILY COST D~,'i/ DRILLING R EPRESENTATIV E ."~r'd~] ~ -- RIG PHONE NO. {~O-/)- 78&- &73Z Pro-562 (C D-4-78) Printed in U.S.A. PROGRESS OF DRILLING WELLS, to-562 DRILLING DAYS .~'' CUM. ROTATING HRS. WELL NO., DEPTH / ~ Z ~; / BIT NO. ~ -~ /~-/~ ~ ~ ~ SIZE MAKE-TYPE BITNO. ~ ~ ~ /~ ~,~ S~ ~ SiZE MAKE-TYPE FROM .... ~ 7 FT. TO /~Z ~ FT. ~ O FT. IN ~ ~ ~RS. ~'/~ 1000~ WT. ON BIT CONTRACTOR .Z~/Z//-,'~-"~-,,~O.,~'' ~ FEET FLOURS JETS CONDITION /4/ FEET HOURS JETS CONDITION ~' ",~ c5 RPM SPEED ' LAST CASING :Z,(,.3 AT SIZE PUMP OUTPUT .~' ~ ~ GPM DRLG. FLUID MUD CO. YIELD PT. WATER LOSS ¢ i / . SPM DEPTH ANNULAR VEL. O' ~ ~0 ~ / T./MIN. (D.P.) NOZZLE VEL, ~/~ FT./SEC. - /~,/~/~ O~~ ~, ~ PCF //O SEC. / ~ CPS ~YPE. , WEIGHT FUNNEL VISC. PLASTIC VlSC. CC -- CC ~ /32 ~ % / % ~ HT-HP WATER LO~ FILTER CAKE SOLIDS SAND . pH ALK GALS (% MIN,) ,z%' 'q~(:3~ PPM ' % Z~ O PPM '"':' CHLORIDE OIL CA OTHER REMARKS CUMULATIVE MUD COST 7¢oo CUMULATIVE DA I LY COST DA~ DRILLING REPRESENTATIVE RIG PHONE Pro-562 (CD4-78) Printed in U.S.A. b,-,~LY PROGRESS OF DRILLING WELLS rro-562 DRILLING DAYS ? CUM. ROTATING HRS. WELL NO.. DEPTH ;Z ~ ~.-~ FIELD SIZE SIZE FROM ~ Z, O FT. TO' ,~'~ ~ FT. DRILLING SETUP ..JZ ~/~V ~/ FT. CONTRACTOR MAKE-TYPE FEET HOURS JETS MAKE-TYPE FEET HOURS JETS IN ,~'/~/- HRS. ~"'/'~:3 1000# ONDITION CONDITION RPM WT. ON BIT SPEED LAST CASING ~, ~ AT ~cf ~[ FORMATION ~/-y ~j.j PUMP PRESS. / ~ ~ ~ PSI~ ', _ ~ O SPM SIZE DEPTH PUMP OUTPUT__~ ~ GPM ANNULAR ~EL. 73 / ?~ FTJMIN. (D.P.) NOZZLE VEL ~q 0 FT./SEC. DR LG. F LUI D /~ ~ ~/~~ ~. ~ ~ PC F ~ ~ SEC. ~ % CPS MUD CO. ~YPE WEIGHT FUNNEL VlSC. PLASTIC VISC. 3 ? #/100 SQ. FT. ~Z,'~, CC '" CC ~ /32 2, ,~' % , ¢~ YIELD PT. WATER LOSS HT~P WATER LO~ FILTER CAKE SOLIDS SAND CHLORIDE OIL .CA pH - ALK' GALS (% MIN,) ' OTHER REMARKS . o : CUMULATIVE MUD COST /:~-'.~_~- ,~, :2, ~,.. ~ 4o'- CUMULATIVE DAILY COST DRILLING REPRESENTATIVE RIG PHONE NO. ~,~7 C73'~ Pro-S62 (C D~,-78) Printed in U.S.A. D.ILY PROGRESS OF DRILLING WELLS ~'ro-562 FIELD DEPTH ~/~, O BIT NO. BIT NO. FROM FT. TO FT. SIZE MAKE-TYPE SIZE FT. FEET MAKE-TYPE FEET IN HRS. / / HOURS JETS CONDITION / / HOURS JETS CONDITION 1000# RPM WT. ON BIT SPEED DRILLING SETUP LAST CASING ~. (~ AT ~¢1 ~t FORMATION · SIZE DEPTH PUMP OUTPUT GPM ANNULAR VEL. PUMP PRESS. PSi@ SPM FT./MIN. (D.P.) NOZZLE VEL. FT./SEC. DRLGo FLUID MUD CO. ~YPE "~ ~ #/1 O0 SQ. FT. '~.,,"~.. YIELD PT. WATER LOSS ~'"~C;3 PPM --- % //~..3 PPM__ CH LORIDE OIL CA CC pH ~. ~ PCF ~ ¢,/ SEC. WEIGHT FUNNEL riSC. PLASTIC riSC. - CC ~/32 ~- (- % HT-HP WATER LO~ FILTER CAKE SOLIDS SAND GALS 1% MIN.) OTHER REMARKS CPS CUMULATIVE CUMULATIVE MUD COST '~/~ <~ DAILY COST DR~ ILLING REPRESENTATIVE RIG PHONE NO. ~O 7- ?e & - ¢7~ ~- Pro-562 (CD4-78) Printed in U.S.A. b.tLY PROGRESS OF DRILLING WELLS ero-562 ' DRILLING DAYS "~ CUM. ROTATING HRS. WELL NO. /f~/~ (f ~.3 ~.-9 DEPTH <~/7_ (~ BIT NO. FROM B IT NO. FT. TO DRILLING SETUP SIZE MAKE-TYPE FEET SIZE MAKE-TYPE FT. FT. IN HRS. CONTRACTOR FEET WT, ON BIT / / HOURS JETS CONDITION / / HOURS JETS CONDITION 1000# RPM SPEED LAST CASING PUMP OUTPUT SIZE AT GPM FORMATION DEPTH ANNULAR VEL. PUMP PRESS. FT./MIN. (D.P.) NOZZLE VEL. PSI@ SPM FT./SEC, DRLG, FLUID MUD CO. #/100 SQ. FT. YIELD PT. PPM ~ :~<~ -3;o~ CH.~)ORI DE TYPE CC WATER LOSS % PPM OIL CA pH PCF SEC. CPS WEIGHT CC HT-HP WATER LOSS ' FUNNEL VISC. /32 FILTER CAKE ALK GALS (% MIN.) ! PLASTIC VISC. % SOLIDS SAND OTHER REMARKS ,47 2.: Y',l~m. CUMULATIVE MUD COST CUMULATIVE DA I LY COST DR'L,,NG REPRESENTATIVE RIG PHONE NO. Pro-562 (CD-4-78) Printed in U.S.A. D~,LY PROGRESS OF DRILLING WELLS rro-562 DRILLING DAYS ~- CUM. ROTATING HRS. /.7 19~J~ WELL NO.. DEPTH B IT NO. FROM FT. TO DRILLING SETUP /') ~ ?~'/:~ FIELD CONTRACTOR <~/'/~',"/o,'~'~ --~ SIZE MAKE-TYPE FEET SIZE MAKE-TYPE FEET FT. FT, IN HRS, 1000# WT. ON BIT / / HOU RS JETS / / HOURS JETS CONDITION CONDITION RPM SPEED LAST CASING 20 AT 3 ~ FORMATION ~~o~/PUMP PRESS. SIZE DEPTH ~ Q ~ PUMP OUTPUT ~/O GPM ANNULAR VEL. ~ ~ FT./MIN. (D.P.) NOZZLE VEL. DRLG. FLUID /~C~ ~ ~ ~~ ~. ~ PCF MUD CO, ~YPE WEIGHT FUNNEL VlSC, ~ // #/100 SQ. FT. . YIELD PT. WATER LOSS HT-HP WATER LOSS CHLORIDE OIL CA pH GALS (% MIN.) ' PSI@ FT,/SEC. SEC.. PLASTIC rISC, CC ~ /32 y % 3/~/ FILTER CAKE SOLIDS SAND OTHER REMARKS SPM CPS DRILLING REPRESENTATIVE /.'$o '3:Oo CUMULATIVE MUD COST CUMULATIVE DAILY COST RIG PHONE NO. ~ '~ V~'~'' ~ 7..~ ~ Pro-562 (CD-4-78) Printed in U.S.A. D,.,dLY PROGRESS OF DRILLING WELLS ,-ro-562 DRILLING DAYS J CUM. ROTATING HRS. WELL NO. DEPTH FROM BIT NO'. B IT NO. FT. TO ~/ZO FT. FIE LD B,~¢'/-. 4./~"~ ~/~,,/~--~ SIZE MAKE-TYPE SIZE MAKE-TYPE FT. IN ~ ¢~- HRS. CONTRACTOR FEET HOURS JETS CONDITION ~EET / / HOURS JETS CONDITION O~'--/o 1000 # WT. ON BIT o~,o -/~Q RPM SPEED LAST CASING .~ <.~ '/ AT ~(~ ' FORMATION C4.~"7/~ O~ / PUMP PRESs. ~7 5-(5 SIZE DEPTH / / ;7//~.,~/~ PUMP OUTPUT '~47/~' GPM ANNULAR VEL. (~ ~// FT./MIN. (D.P.) NOZZLE VEL. PSI@ FT./SEC. SPM -DRLG. FLUID //,~'¢O ~-~¢.~//~-~¢,./~:? MUD CO. [ TYPE / '2,. #/100 SQ. FT. ~. (~ YIELD PT. WATER LOSS ¢7<3 c30 PPM " % //~0 PPM CHLORIDE OIL CA SURVEYS ~. C PCF [/C3 WEIGHT FUNNEL rISC. CC -- CC ~-- /32 HT-HP WATER LOSS FI LTER CAKE pH AI'K GALS ((MIN.) SEC. SOLIDS PLASTIC VISC. SAND OTHER REMARKS CPS CUMULATIVE CUMULATIVE MUD COST j' ~ o O DAILY COST DRILLING REPRESENTATIVE ~/~' J/~/~-~"~'~ ~ RIG PHONE NO. ~ 7 '~' ~' ~S ~ Pro-562 (CD~-78) Printed in U.S.A. D.tLY PROGRESS OF DRILLING WELLS r'ro-562 WELL NO. DEPTH BIT NO. BIT NO. FROM FT. TO DRILLING SETUP SIZE MAkE-TYPE FEET SIZE MAKE-TYPE FT. FT. I N H RS. CONTRACTOR / / HOURS JETS / / CONDITION FEET WT. ON BIT HOURS JETS CONDITION 1000# RPM SPEED LAST CASING ~0 AT SIZE FORMATION DEPTH PUMP OUTPUT GPM ANNULAR VEL. DRLG. FLUID /'/~, *,4. ~..~ MUD CO. TYPE 2 #/100 SQ. FT. ~ t CC YIELD PT. WATER LOSS /~/~°0 PPM ' % /~0 PPM ~ CHLORIDE OIL CA pH SURVEYS PUMP PRESS. PSI@ SPM FT./MIN. (D.P.) NOZZLE VEL. ~-~_ ~ PCF' WEIGHT FT./SEC, SEC. ~" CPS FUNNEL VISC. ~' /32 FI LTER CAKE PLASTIC VlSC. t % o % SOLIDS SAND -HT-HP WATER LOSS ALK GAL~ (% MIN.) ' OTHER REMARKS DETAIL CUMULATIVE MUD COST CUMULATIVE DA I LY COST DRILLING REPRESENTATIVE ~ RIG PHONE NO. ~"'~7 v'~l~C. Pro-562 (CD4-78) Printed in U.S.A. WELL NO, ~/~/~¢j~ ~, ~'~-~ DEPTH FROM DRILLING SETUP b.lLY PROGRESS OF DRILLING WELLS ~ro-562 ~S ~ CUM, ROTATING HRS. BIT NO, B IT NO. FT. TO FIELD SIZE MAKE-TYPE FEET SIZE MAKE-TYPE FT, FT, IN HRS, CONTRACTOR / / HOURS JETS / / CONDITION FEET WT. ON BIT HOURS JETS CONDITION 1000# RPM SPEED LAST CASl NG PUMP OUTPUT SIZE At GPM FORMATION DEPTH ANNULAR VEL. PUMP PRESS, FT,/MIN. (D.P.) NOZZLE VEL. PSI@ SPM FT[/SEC, DRLG. FLUID MUD CO, #/100 SQ. FT, YIELD PT. PPM % CHLORIDE OIL SURVEYS TYPE WATER LOSS PPM CA PCF SEC. CPS CC CC . WEIGHT FUNNEL VISC. PLASTIC VISC. /32 % HT-HP WATER LOSS FI LTER CAKE SOLIDS SAND pH ALK GALS (% MIN.) OTHER REMARKS DETAIL Z ~ ' ~-~J'~ CUMULATIVE MUD COST CUMULATIVE DA I LY COST DRILLING REPRESENTATIVE ._~'~,/~' RIG PHONE NO, ~"~'~ ~'~ Pro-562 (CD4-78) Printed in U.S.A. D.ILY PROGRESS OF DRILLING WELLS ¢ro-562 ~DAYS ~/~'/~ CUM, ROTATING HRS. WELL NO,_ ~.~~ ~ ~ ~"~:~ DEPTH BIT NO, B IT NO. FROM FT. TO / / SIZE MAKE-TYPE FEET HOURS JETS CONDITION / / SIZE MAKE-TYPE FEET HOURS JETS CONDITION FT. FT. IN HRS. 1000# RPM WT. ON BIT SPEED DRILLING SETUP LAST CASING PUMP OUTPUT SIZE AT FORMATION DEPTH GPM ANNULAR VEL. PUMP PRESS. PSI@ SPM FT./MIN. (D.P.) NOZZLE VEL. FT./SEC, DRLG. FLUID MUD CO. #/100 SQ. FT. YIELD PT, PPM % CHLORIDE OIL SURVEYS DETAIL TYPE WATER LOSS PPM CA PCF SEC. CPS WEIGHT FUNNEL VISC. PLASTIC VlSC. CC CC /32 % HToHP WATER LOSS FI LTER CAKE SOLIDS SAND pH ALK GALS (%MIN,) ' OTHER REMARKS CUMULATIVE MUD COST CUMULATIVE DA I LY COST DRILLING REPRESENTATIVE..__ '~'""¢ ~ '~'~'~"",~'~,~_ RIG PHONE NO. Pro-562 (CD~-78) Printed in U.S.A. DAILY PROGRESS OF DRILLING WELLS Pro-562 ~'~ y_~cu ~DAYS__~f_ M. ROTATING HRS. c_~ WELL NO.. DEPTH BIT NO. FROM BIT NO. DRILLING SETUP FT. FIELD S I Z E MA KE-TYPE F E ET FT. TO SIZE MAKE-TYPE FT. IN HRS. CONTRACTOR FEET WT. ON BIT / / HOURS JETS CONDITION / / HOURS JETS CONDITION 1000# RPM SPEED LAST CASING PUMP OUTPUT SIZE AT GPM FORMATION DEPTH ANNULAR VEL. PUMP PRESS. FT./MIN. (D,P.) NOZZLE VEL. PSI@ SPM FT./SEC. DRLG. FLUID MUD CO. ' #/100 SQ. FT. YIELD PT. PPM % CHLORIDE OIL SURVEYS TYPE WATER LOSS PPM CA PCF WEIGHT CC CC -HT-HP WATER LOSS SEC. pH ALK GALS (% MIN.) FUNNEL VISC. PLASTIC VISC. /32 _% FI LTER CAKE SOLIDS SAND OTHER REMARKS CPS OETA'L ~ ~ ~~~ CUMULATIVE MUD COST CUMULATIVE DALLY COST .Z.,J/'~,,,, ~ (::~,¢:3 DRILLING REPRESENTATIVE ~. RIG PHONE NO. ~(-~'7 "~-~ Pro-562 (CD-4-78) Printed in U,S.A. DALLY PROGRESS OF DRILLING WELLS Pto-562 [;NaI~L=i~N~. DAYS --~UM. ROTATING HRS. WELL NO. ~:[.k~ ~..-~ ~2_. ¢~. FIELD ~.~'~l.,.l~(.~I'~- ~,~..~,,. DEPTH BIT NO. BIT NO. FROM FT. TO FT. SIZE MAKE-TYPE FEET / / HOU RS JETS / / S~ZE MAKE-TYPE FEET HOU RS FT. IN HRS. 1000# WT. ON BIT CONDITION JETS CONDITION RPM SPEED DRILLING SETUP LAST CASl NG PUMP OUTPUT SIZE AT GPM FORMATION DEPTH ANNULAR VEL. PUMP PRESS. FT./MIN. (D.Po) NOZZLE VEL. PSi@ FT./SEC. DRLG. FLUID MUD CO, #/100 SQ. FT. YIELD PT, PPM % CHLORIDE OIL SURVEYS TYPE WATER LOSS PPM CA PCF WEIGHT FUNNEL VISC. CC CC /32 HToHP WATER LOSS FI LTER CAKE pH ALK GALS (% MIN.) SEC. SOLIDS PLASTIC VISC. % SAND OTHER REMARKS SPM CPS DETAIL. CUMULATIVE MUD COST CUMULATIVE DA I LY COST DRILLING R EPR ESENTATIV E'~"- ~ , ,/~, L~' )"'~'(b ~ RIG PHONE NO. Pro-562 (CD-4-78) TRANSMITTAL AND ACKNOWLEDGEMENT .OF RECEIPT OF CLASSIFIED MATERIALS Alaska Oil & Gas Conservation Commission Attn: Mr. W.M. Van Alen 3001 Porcupine Dr. Anchorage, AK 99501-3192 DATE: WELL NAME: We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. J. L. Weaver Chevron U.S.A. Inc. 3001C Street Anchorage, AK ggs03 ii COMPANY: ~ ~ DATE' -~-:~ · ~i Senders' Ins transmittal sheets are made on NCR {No Carbon Required) paper wi sheets per set. Retain one copy for originator's file. Include one with transmitted material. Send original under sepa- rate cover to addressee. (If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this form. EXP-180-8 (CD-3-82) Printed in U.S.A. '' . '~*~" STATE OF ALASKA ~-, R~ ECEIVED ALASKA , ~AND GAS CONSERVATION C(L .MISSION WELL COMI LETION OR RECOMI LETION REI OR 1. Status of Well Classifi~[~,~ c~e~i~l~/e~, ~ OIL [] ' · GAS EX S'usPENDED [] 'ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Chevron U.S.A. Inc. 84-0136 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 50-283-20075 4. Location of well at surface 9. Unit or Lease Name 1814'E & 302'8 of NW Corner Sec. 9, T12N, R10W, S.B.&M. Beluga River Unit At Top Producing Interval 10. Well Number 3045'E & 1812'S of NW Corner Sec. 9, T12N, R10W, S.B.&M. BRU 232-9 At Total Depth 11. Field and Pool 3175'E & 2331'S of NW Corner Sec. 9, TI2N, R10W, S.B.&M. Beluga River Field - 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Sterling G.L. = 91' K.B. = 109'I AD][. ~ A?~q& ~, 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 9-12-85 10-9-85 11-25-85I NA feet MSL 1 17. To~a, Depth (MO+TVD)18.PlugBackDepth(MD+TVO)19. Oirectiona, SurveY7992,; 7179' 4256'; 3524' YESl~ NO [] I2°' aepthwheresssvsetNA feet MD [ 21.Thickness of PermafrostNA 22. Type Electric or Other Logs Run DIL, 8'FL, SP, GR, DLL, MSFL, BHC Sonic, CNL-LDTs SHDT, PML, CET, CBL, VDL, CCL, RFT, SWS's 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30 29' 96' 'Driven 20 94 H-40 28' 394' 26" 490 sks "G" +6% Gel (;t 13.9 PPG 13-3/8" 68 K-55 27' 3935' 17½" 2340 sks "O" +6% Gel (FI 13.9 PPG 9-5/8" 40 N-80 24' 3717' 12¼"' " 1100 sks "G" (Fi. 15.3 PPG 9-5/8" 43.5 N-80 3717' 6658' 12¼" 24. Perforations open to Production {MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) -' ' ' -' - SIZE DEPTH SET (MD) PACKER SET (MD) 4154'-4166'; 3438'-3448' 144 holes 2'7/8" 4252' 4115', 4213' 4218'-4237'; 3492'-3508' 228 holes 2-3/8" 1389' None (12 - ½" JSPF) 26: ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED -, '~ - : :'~ :" ~ See Attached · . .. 27. < PRODUCTI°N TEST Date First Production ¥¢ell shHt in I Method of Operation (Flowing, gas lift, etc.) pending',~urfaCe eqpt. "''1 FloWing ' : Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF ' WATER-BBL CHOKE SIZE [GAS-OILRATIO 11-18-85 7 hrs. TESTPERIOD * 0 1220 0 30/64"J NA Flow-Tubing ,Casing PreSsure' : CAECULATED~:-~ oIL-BBI~ ' GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press.- t1,-50: - ' 0' : 24-HOUR RATE~ 0 - -6,764 0 NA , 28. :~ ': '' ',: " ' :' ' CORE DATA " Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 64 SWS (sidewall samples) were attempted. 53 SWS were ·recovered, ranging in depth from 720' to 7,373'. 37 SWS were unconsolidated sand, typically fine to medium grain, gray, moderately to well sorted, porosities ranging from 19 - 38% (usually 30 - 35%). Remaining samPleS were 'clay and silt~ clay, gray in COlo~, loTM porosity and extremely low perme- ability. No hydrocarbon shows of any type. No conventional cores cut. ;~ 5,. : . :' '-- - . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ' '- : ' ' : -.'; "'~ 2~(:-- ~- : ~-,': - ~, , :.. ~ : L~ '' ':: ' ': -GEOLOGIC MARKERS - FORMATION TESTS N~,~Ufl~°{:~:' Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH 'GOR, and tim~' of each phase. Top Sterling Fm 1754 1690 SEE ATTACHED PAGES Zone A 4134 341-8 - B 4382 3632 . C 4552 3784 ToP Beluga Fm D 4692 3913 E 4985 4186 F 5372 4563 G 5963 5146 : · .. : [ : . : 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Area Operations Signed Title SuoerintendeBt Date INSTRUCTIONS General ThiS form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' ClassifiCation of Service Wells: Gas injection, water injection, steam injection, air injection, salt 'water disposal, water supply for injection, obseryation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. -. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF 9-5/8" CSG shoe ~ 6658' Perfs 4950'-4951' Perfs 4648'-4649' Perfs 4518'-4519' Perfs 4339'-4340' Perfs 4257'-4258' Perfs 4148'-4149' Perfs 4148'-4150' Perfs 4148'-4150' & 4257'-4258' Perfs 4950'-4951' Perfs 5947'-5928' & 5884'-5868' Perfs 4946'-4938' & 4910'-4902' Perfs 4758'-4734' Perfs 4630'-4593' & 4534'-4522' Perfs 4316'-4308' & 4300'-4264' 100 sks C1 "G" ~ 15.8 Below RTNR ~ 6545' 100 sks C1 "G" ~ 15.8 PPG Below RTNR ~ 4910' 150 sks C1 "G" ~ 15.8 PPG Below RTNR ~ 4600' 75 sks C1 "G" ~ 15.8 PPG Below RTNR ~ 4480' 100 sks C1 "G" ~ 15.8 PPG Below RTNR ~ 4300' 100 sks C1 "G" ~ 15.8 PPG Below RTNR ~ 4220' 100 sks C1 "G" ~ 15.8 PPG Below RTNR ~ 4100' 150 sks C1 "G" ~ 16.0 PPG Below RTNR ~ 4053' 150 sks C1 "G" ~ 16.0 PPG Below RTNR ~ 4050' 150 sks C1 "G' ~ 16.0 PPG Below RTNR ~ 4862' 100 sks C1 "G" ~ 15.8 PPG Below RTNR ~ 5756' 100 sks C1 "G" ~ 16.0 PPG Below RTNR ~ 4820' 100 sks C1 "G" ~ 15.8 PPG Below RTNR ~ 4690' 100 sks C1 "G" ~ 15.8 PPG Below RTNR ~ 4428' 100 sks C1 "G" ~ 15.8 PPG Below RTNR ~ 4256' MTLS USED PPG RECEIVED mamm & co . ' 30. Formation "~-'~· ~ Page 1 of 6 BRU 232-9 DST's 1-6 (done il/85) DST ~1 (11/2/85) ! Interval 5884'-5868' (16') - (F) 5947'-5928' (19') - (F) 1 JHPF, 418 Charges Tubing conveyed (potential frae zone) (Tested w/715 psi brine cushion estimated underbalance 1800 psi) Test Results: 5 minute flow - no blow I hour shut-in Final Flow- weak blow began 27 min. after tool opened, no change through remainer of test. Annulus losing fluid through final flow (believe upper squeeze holes are leaking). Lost total of 8 bbls. from annulus. Shut-in well after a final flow period of 3 hours 51 minutes. No gas rates measured at surface. Final Shut-in - 6 hours. Pulled test tools and recovered 80' + of sand above APR valve. Evaluation: (see chart) - APR appears to have leaked during test (note pressure drop when packer set). It appears that sand created a partial plug that could be flowed through. Interval squeezed. RI CEIV£D M 2s 1985 Alas~ 0il & Gas Cons. Comn~ission An~o~age 30. Forruation ;~ k Page 2 of 6 BRU 232-9 DST #2 (11/7/85) Interval 4946'-4938' (8') 4910'-4902' (8') Lower D Sand 8 JHPF - 41B Charges Tubing conveyed perforating Tested w/615 psi cushion (brine) approximate underbalance 750 psi Test Results Initial Flow: Initial Shut-in: Final Flow: Final Shut-in: Open tool ~ 14:55, Shut-in ~ 15:02 (7 minute flow). Had medium blow, total F.L. rise of 327'. Shut-in ~ 15:02, open tool ~ 16:00 (58 min.) Note: T.P. continued to build after APR valve closed believed it may be leaking so well SI at surface for remaining 40 minutes of SI period. 16:00 16:06 17:30 17:50 18:22 19:00 19:40 20:16 20:55 21:15 Open tool Gas to flare on 8/64" bean F.L. 0 1720', T.P. = 128~, Q = 35 mci/D, 8/64" bean F.L. ~ 1854', T.P. = 135~, Q = 35 mci/D, 8/64" bean F.L. ~ 1754', T.P. = 111~, Q = 85 mci/D, 12/64" bean F.L. ~ 1484', T.P. = 56#, Q = 64 mci/D, 12/64" bean F.L. ~ 1309', T.P. = 579, Q = 52 mci/D, 12/64" bean F.L. ~ 1251', T.P. = 42~, Q = 64 mci/D, 14/64 bean F.L. ~ 1190', T.P. = 209, Q = 51 mcUD, 18/64" bean SI, F.L. ~ 1190' (Total rise 2190') SI APR and at surface. 9 hours. Pulled tools and recovered 25' of sand above APR. F.L. ~ 2328' (Net rise 1052') T.P. = 198). No significant change in chlorides when reversing out. 30. Formation ~ Page 3 of 6 BRU 232-9 DST ~3B (11/11/85) Interval 4758'-4734' (24')- D Sand- 8 JHPF 4lB Hyperjet II Tubing conveyed. Tested w/approx- imately 1000 psi underbalanee (brine) Flow: 15:02 15:30 15:43 15:50 16:40 17:35 17:55 Shut-in- 17:5 Open tool medium blow T.P. = 2it T.P. = 3~, medium blow F.L. 0 1552' (Net rise 115') Gas to flare 8/64" bean F.L. ~ 1283', T.P. = 2#, Q = immeasurable, 8/64" bean F.L. ~ 1471', T.P. = 3#, Q = immeasurable, 6/64" bean Changed beans from 8/64", 16/64", 22/64" w/essentially no change in F.L., T.P. or Q F.L. ~ 1458', T.P. = 2#, Q = immeasurable, 22/64" bean ' S.I. LPR for 4 hours 5 Final F.L. ~ 1514' (Net 1041') , Recovered 91' sand fill in collars, change in chlorides when circulating this well. RECEIVED IVI 2 8 1986 011 & ~as Cons. Commission Anc~ra~e Formation Test .ge 4 of 6 BRU Z3Z-9 DST ti4 (11/14/85) Intervals Flow: 4630*-4593* (37*) 4534'-4522' (12') C-Sand 49' 8 JHPF - 4lB Hyperjet II Tubing Conveyed - Underbalaneed w/Nitrogen cushion 300# underbalance 9:45 10:31 11:00 11:34 11:45 11:57 1:00 1:34 2:23 2:45 3:25 Open LPR/Fire guns, T.P. 1190~, on 4/64" bean F.L. ~ 3653' (Net rise 788'), T.P. = 1000it, 12/64" bean F.L. ~ 2466', T.P. = 645#, 12/64" bean Gas to flare, F.L. ~ 1175', T.P. = 336~, 12/64" bean Q = 376 mef/D Fluid to surface, T.P. = 79~, flare dying Q = 29 reef/D, still unloading fluid (Rathole volume 11.3 bbls.) Recovered 8 bbls. fluid Recovered 18 bbls. fluid Recovered 27 bbls. fluid, Q = 12 mcr/D, T.P. = 51# SI LPR for 7 hours. Recovered 27 bbls. fluid Fluid samples Chloride (ppm) 1 bbl. 94,000 3 { bbls. 100,000 8 bbls. 64,000 12 bbls. 46,000 18 bbls. 34,000 25 bbls. 30,000 27 bbls. 28,000 Pulled testing tools and recovered 15' of sand above LPR. RECEIVED Mh,q 2 819 6 Alaska ~ & Gas Cons. commJs~on 30. Formation ~i Page 5 of 6 BRU 232-9 DST #5 (11/16/85) Intervals: 4316'-4308' 4300'-4264' A-Sands (8') (36') 44' 5 JHPF, 51B Hyperjet II (Deep Penetrating) Tubing Conveyed- Underbalanced w/Nitrogen cushion 300 psi underbalance Nitrogen Cushion 1096) ~ surface, 1229# ~ LPR, Rat hole volume = 6 bbls. 300#, underbalanced Flow: 9:09 9:29 9:39 10:04 10:34 10:53 11:36 12:23 13:11 Open LPR/Fire guns, 6/64" to separator T.P. = 1120~, F.L. ~ 3750', 6/64" bean T.P. = 1028~, F.L. ~} 3532' (Net rise 659'), 10/64" bean T.P. = 819it, F.L. ~ 2609' (Net rise 1582'), 14/64" bean Gas to flare, T.P. = 312~, F.L. ~ 889' (Net rise 3302'), 14/64" bean Fluid to surface, T.P. = 359, Q = immeasurable T.P. = 0#, Recovered 5 bbls., no change in chlorides, no flare T.P. = 0#, F.L. ~ surface, no flare, appears well has killed itself SI well for 3 hours. Pull well. F.L. ~ 187', reversed out and took chloride readings. 5 bbls - 100,000 ppm 10 bbls - 100,000 ppm 15 bbls - 40,000 ppm 20 bbls- 24,000 ppm 25 bbls - 18,000 ppm 30 bbls- 20,000 ppm 35 bbls - 17,000 ppm 40 bbls - 18,000 ppm 45 bbls - 14,000 ppm 50 bbls- 12,000 ppm 55 bbls - 10,000 ppm 30. Formation' c Page 6 of 6 BRU 232-9 DST ~6A (11-18-85) Intervals 4237'-4218' (I9') 4166'-4154' (12') ,, A-Sand -31' 12 JHPF - 41B Hyperjet II Tubing Conveyed - Underbalanced w/Nitrogen Cushion 300 psi underbalance Nitrogen Cushion- 1052# ~ surface, 1180# ~ LPR Rat Hole Volume - 6 bbls. 300 psi underbalance Flow: 9:17 9:25 9:43 10:09 14/64" - 18/64" - 22/64" - 26/64" - 30/64" - 16:03 Open LPR/Fire guns T.P. = 1262#, F.L. ~ 3324', 6/64" bean T.P. = 1279#, F.L. ~ 3230', 10/64" bean Gas to flare Stabilize Flow Rates. 1588 mef/D- 1280tt T.P. 2779 mef/D- 1270~ T.P. 3970 mcf/D- 1245# T.P. 5194 mcf/D- 1200# T.P. 6764 mcf/D - 1150~ T.P. total fluid recovery less than 1 bbl. SI for 8 hr. buildup. Gas breaking past fluid SUB-SURFACE DIRECI'IONAI. 8URVEY [~JUIDANCE [~ONTINUOUS [~OOL RECEIVED Alaska OJj & Gas Cons. Cor,'lrrlissiorl Aachorat:je CHEVRON CLASSIFIED Company c~wo, Well Name sRu 232-9 (2038, E. 296, .% Yrnm ~. $9, TI?w- R10W Field/Location ~;~,r.A ~W~. r.~A~, Job Reference No. 70891 Loaaecl 8~ MURTLAND Oate. 2 l-OCTOBER- 1985 Computed CUDNEY $CHbUMBERGER CUSTOMER LISTI[NG FOR BRU BEbUGA RIVER SURVEY DATE~ 16-0C?-e5 ENGfNE~R) ~. MURTbAND M£THOD8 OF COMPUTATION ?OOb 40CAT)ON: TANG~NTIAbm averaqed deviation and azimuth ~NTEPPOb~T)ON: !,,INEAR VFRTICAL SECTIOn: HORIZ, DIST, PROJECmED ONTO A TARGET AZIMUTH DF SOUTH B~U 232'9 8EbUGA RIVE~ KENAI,ALASKA INTERPOI.,A?ED VALUES FOR T~U~ SUB~SEA COUR$~ V'ER~ZC.AE DOGbEG MEASURED V~R?ICAL VE~?~C.A~ DEVTA?ION AZZ~U~H SECTION SE~ER~' DEPTH DEP?H DEPTH D~G ~TN D~G ~TN F~E? DE~/20 Rt~C~ANGUb~R NORTH/&OU?H 0.00 0.00 'I07.00 0 0 ~ 0 I00,00 i00,00 '~ ..oo ~00,00 ~O0..,O0 93,00 0 10 ~ 63 .00 0 3 $ 6 28 500,00 $00~00 9~.00 0 10 S 71 3? ~ ~00*0.0 599,98 492,98 2 17 $ 65 50 ~ 700,00 699,78 592,78 4 46 S 6.2 7 £ ~'00,.00 799221 69 6. S 50 '79~210 7 2 41 mO:.O,O0 897,9q '99 10 26 $ 43 24 ~ 1000 O0 liO0 O0 1~'00 O0 ilO0 O0 1400 O0 I~,00 O0 1~00 O0 1700 O0 18:00 0'0 1900 O0 200O 2100 2~OO 2300 403 ?0~ 280, 290t 3000. 3100, 3200. 3300', 3400. 3500. 3600. 3700. 3800. 3900, 995,78 888 78 1.3 4~ 1.092.,30 98~ 30 16 16 1287,76 1080 76 18 20 1282,:11. 1375,3, I~ i467,.02 1360 1556.9! 1449 1729,63 162~ 1811.33 1704 O0 I889. O0 19.63, :00 2034, O0 ~193, O0 2170, O0 2236. O0 2300 O0 ~363 O0 2424 O0 24~4 S 44 ~ 41 49 E S 37 41 E 31 22 17 S 57 i3 02 24 44 S 37 47 91 ~716 S 38 38 ..68 30 6 .63 33 30 .33 36 55 56.90 43 38 o 50 225~ 50 51 53 39 ~3 0 04 2 4 ~3 2 S 39 4~ ~ $ 40 52£ 841 57 E $ 33 E $ 45 4 056 O0 2544 .46 O0 2610 O0 O0 2761 O0 2838 O0 2916, O0 2995 O0 3074 O0 ~1~3 O0 2437,46 51 24 6 250.3"46 45 39 9 2576,79 40 q 31 2654.31 9 1~. 61 2731.6! 9 2'~ 38 2~0~,.38 38 3 4~ 288~ 49 37 45 45 2967 45 ~7 59 35 3046 ~5 37 54 44 312~ 44 39 23 0 00. 30 ,8:3 51,36 10 ,53 13~,53 175,6 215,~6 258'95 358,82 415*79 611 682 , 7'55 O6 029 98 90. 97~ 35 45 77 O0 $ 44 32 E 1212 8 42 48 E 1286 S 4O 54 E1353 S 40 5~ E 1426 $ 40 52 E 1478 S 37 50 E 1541, S 33 59 E BO~e 28 4 E 1725+ S 23 i E 1787e 65 51 61 15 92 29 O! 0,00 O, 2'6 O, 22 2,92 ,0 $ _1,79 .I $ 0 ~ 0 75 0 ,# W :¥ W ¥ COMPUTATION DATE'= 21-0CT-8.5 FOR gVEN lO0 fEET OP'NEASUR!ED D~P?H HEASURED VERTICAL VERTICAb D~VZATION AZIMUTH DEPTH D~PTH DEPTH DEG MTN VERTtC:'Ab DOC,_b,'EG, R~C?ANG'UbRR SECTIOH SEVERITY NO, R?H/&OU?H F~ET DEC)/I:O0 o~ ,3~e)'03 ~4 57 ~ ~0 27~ ~906,18 1.5 3366,I5 32 32 $ 20 56 E 1960'52 74, 3,45~ 4 29 35 $ 2~ I1E 201~,24 , 4 ~7 4I ~ 2~ 27 g 205§,18 1~ 3~20~3 23 t9, $ 26 37 E 214~,,47 ,63 4,i8 2'44 4000,00 3309 410:0 00 33;90 i 00 3473 O0 4400 ~558 646 4500 4600, 4700, 4800 4900 :00 O0 O0 O0 3736 O0 38,27 O0 39~9 O0 40,1B3 O0 410 234~,.98 550.0,00 4688,.15 4581,15 36 S 2386,87 5600,00 4786'63 4679..63 5.".00.,'"0 4885,48 4?7",48 I~! i ~ ~ ~2416,772402"94 5900,00 5083,73 4976,73 7 S £ 2440.9'5 6ooo oo 650( O0 56~ 6600 00 578~:~7 6640 O0 58~2,67 5076'07 517~,78 5~7~,73 537~ 71 5475 69 5~75 68 5675 67 5715 67 .56 2018,,29' I 27 2019,44 O0 ,o,0 5 39 S 6 33 E 2451 2 40 5 1 16 W 2457 I 25 5 19 58 W 2460 I ~ $ 36 15 W 2461 1 0 ~ 40 4 ~ 246! 0 5~ S 44 51 W 2462 0 46 S 60 56 W 246~ 0 46 ~ 60 56 ~ 246~ 9 2 0 lO 0 69 0 O8 O4 0 CHEVRON USA 8RU 23'2-9 BELUGA RIvE~ KENAI,AhASKA. COMPUTATION DATE: 21.-0C?-95 SURED VERTXCAt VErTiCAL DgV~ATION AZf~U?H ~EDEP~H DEPTH ~EPTH DEG MIN DEG .M~N DATE ENG~NEERt: G,', ' :R:URIL~ND I~TERPO[.,ATBD VALU~& FOR EVE'~I I000 FEET OF M'EASURED D'EPT VERT~CA~ D~GbEG REC~ANGU'bAR S~CTION SEVERIT~ NORtH/SOUTH FEET PEG/.100 FEET, 0,00 0~00 1000,00 995,~78 2000.00 1B~9~5~ 3000,00 2544,46 4000.00 33.09~43' 5000;00 4202~$~ -I07,00 0 0 51 4 ...43 ,771 95.85 17 ~O ~76.07 5 '15,67 0 46 ~ 0 0 E 0.00 S 44 I0 E 51.,{6 $ 4~ 13 E 47~,'~! $ 10 ? E 22~6.8 KENAZ,,AI, ASKA 0,,00 0,00 -107,00 0,00 NN ?.oo ?,oo ~ ~ ~ ~ ~ ~ ~.oo o.oo ,00 0,'00 tO?',O0~07,,00 -~0~,00 ,o?.oo ~.o~,oo ~o ~ ~ ~ 42 -0' ~ ~o?,.oo ~o .oo ~ ~ ~ ~ ~ ,~ : '~ o .oo ,.oo : ,o?..,~ ~o7',oo ?oo.oo ~ ~?4o ~[ [ ~ :~ . ,. :*? ~,'i 1434 . 4 O0 900 1107 O0 I000 I207, O0 10 1407 O0 1300 1507;00 400 1607,,0'0 ~800 1707 '00 0 10 4] $ 43 Ii E 3~,53 O0 16, 36 $ 40 E 81,29 S ~ 2~ E 112.94 ~0 1~.'~! ~oo ~3, 5 si l'e ~ t8e',,36 O0 l~ 36 , 344.,4 O0 1~00 O0 O0 ~0 O0 30O O0 400 O0 2~00 ,oo ~ oo ~ k 0 0 O0 ? E ,02 0.0 52 41 S 45 O0 45 57 ~ 42 55 E O0 39 12 S 40 48 ~ O0 39 24 S 41 4 E 1 O0 2800 O0 O0 200~ O0 O0 300 O0 O0 310o O0 3~00 O0 0 oo II~o O0 3500 O0 3600 O0 3700 38 11 S 38 25 E O0 39 1 S 2:4 ~ 0000 37 4il ~ ii19 ~ 38 2! $ O0 23 40 $ 26 19 ~ 1846 ~7 1917 2039 38 2088 ! 10' 16et ~907 57 3007 )i 3107 40 3207 94 3507 09 3607 7~ 3707 O1 ~807 348'8 07 361~ 374 3996 4120 4239 4355 4467 457~ CHEVRON USA INC BRU 2)2'9 KENAI,ALASKA D~G iq:l:.N ?~U~ O',E~N DEPTH ~EP?~ DRG. MIN 4~86,,,96 390?'00 3800,0 21 33 ~,,'g~ 4~07,~00 ~000,,,0 · ,~'b 4207,00 4100,0o ~7 25 5~0§~6 4~"00,0 t5 5~f~,i:1 4307,00 4407,00 4~00,,0~ I4 40t? 5~I5,,00 4507,00 4400'~0 12 5'6 5'620 4807,00 4700.0 ' O0 4800 O0 4900 O0 5000 ,~oo 5!oo O0 5200 O0 5)00 O0 5400 O0 5900 O0 5600 O0 5?00 ~4 490]00 $ 28 34 'E 2t76.19 $ 13 4 E 2246,,'_&8, S ,,0 , £ 22.7?,72 8 I0 $ £ 2{04 $ ~ 5, OE' 5 10 34 R2{9 8 !0 26'£ 5 9 4? ~ 2405,92 S9 8 0 0 5 9i~E ~419 ~ 8 g 24~I, $ 8 ~ gW 244) 8 4 5 E 2453, 5 4 I 245,8, 8 )g ! ~ 246~ S 48 5 . 24,61, 5 48 II W 2462. 5 60 56 W 2462. O0 8 2 O0 7 26 O0 6 58 O0 4 5~. 00 2 O0 I 20 O0 1 5 O0 0 56 O0 0 49 00 0 46 0 46 ~ 60 56 W 246~,04 ,o! 19 19 O, 0 .00 6640,00 .'5822,6'7 5715.67 0.00 ! 9 20 20'~ 20~ K~NAI, A,I:,ASK A ~ARK~R COMPU?A?ION D.A/'E= 2~.,0CT-~5 INTERPOLATED VA[JUE$ FOR CHOSEN HORIZONS 6640,00 ~ARK~R 6640,,00 K E::t,b ¥ FROM KB SUBeiSE. A 5 B 2 2,6 7 '$ 71. 5 ,,,6 ? 2,O,~e,,so, s 'I'I~U(~ SUB.,SEA DEPTH D~PTH DEPTH '6640,00 5822,$7 57t5,6'? GREAT LAND DIRECTIONAL DRILLING INC. REF'ORT OF SUB-SURFACE DIRECTIONAL SURVEY CHEVRON U.S.A. C 0 iv! P A N Y BRU -- S,=--9 I.,..I E L.. !... N A F! E :BELUGA RIVER FIELD L O C A ]" ]: O N AMD85D27 MWD & SINGLE SHOT 10-10-85 Il IfTI ~ F' ,.! 0 ti".', b ...... E, L':. t:;.'. T Y F' E S U R V E Y D A T E BYRON OVERSTREET DIRECTIONAL SUPERVISOR (~ ~ N A P! E 'f' I T I... IF S I G N A'.r U R E 500 FT 7992 FT I)EI::'TH ]:N'Y't!i:F~VAI... F:'ROM TO 10--1-85 10-9-'85 DA'¥'lii: SURVEY TAKtZN F'ROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINEO A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE., At_L COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. RECEIVED NOV 0 4 i98S Alaska Oil & Gas Cons. Commissior~' Ar~chora¢ GREAT LAND DIRECTIONAL DRILL~NG, INC Client ' CHEVRON U.S.A. We1] ................ : BRU 232-9 C]omu~e O~rect~on...: S 32.44 E MognetJc Declination: 24 deg 30 m~n E (Well RECORD OF SURVEY ossL, n',ed vert~co] Computot~on: Survey date- Method ..... : RKB Height.: to 500.0l RADI'US OF CURVATURE ].0-].0-85 MWD & MAGNETIC S.S. ].09.0 ft NEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG MN DEPTH DEPTH DIST SOO 0 0 ,SO0.O0 39]..00 SS3 ] 0 SS3.00 444.00 655 3 30 654.9] 545.9I 744 S 30 743.63 634.63 839 8 IS 837.94 728.94 932 1]. 1S 929.S9 820.S9 1056 iS 0 10S0.33 941.33 1153. 17 IS 1141.58 1032.58 1240 ].9 30 122~.04 ].1].7.04 3.469. 23 4S 3.438.87 1329.87 ].626 27 45 1580.25 1471.25 1780 32 1S 1713.59 1~04.59 193~ 37 0 ]841.92 3.732.92 2093 43 0 ].962.13 1853.13 2271 4~ 0 2089.08 1980.08 2426 48 0 2194.78 2085.78 2581 SO 0 2296.47 2]87.47 2736 S2 0 2394.0~ 228S.01 2892 53 0 2488.97 2379.97 3057 49 30 2592.23 2483.23 3182 42 30 2679.01 2570.01 330]. 39 0 2769.15 2660.15 3393 39 30 2840.39 2731.39 3553 38 0 2965.17 2856.17 3647 38 0 303~.24 2930.24 0.00 0.45 4. ].2 10.30 o]. 07 36.52 64.28 90.36 3.18.32 202.58 270.55 347.02 434.76 S34.23 656.66 767.53. 881.68 999.25 1120.05 ].246.09 ].334.94 1412.01 ].469.65 ].569'.12 1626.92 DIRECTION ANGLE 0.00 S 4'7.00 E S 64.00 E S S6.00 E S 46.00 E S 41.00 E S 43.00 E S 39.00 E S 35.00 E S 36.00 E S 38.00 E S 40.00 E S 41. O0 E S 43.00 E S 44.00 E S 45.00 E S 45.00 E S 45.00 E S 45.00 E S 43.00 E S 39.00 E S 40. O0 E S 41.00 E S 37.00 E S 33.00 .E RELATIVE COORDINATES FROM WELL-HEAD 0.00 0.00 0.32 S 0.34 E 2.58 S 3.63 E 6.06 S 9.67 E 3.3.2]. S 18.49 E 24.63 S 29.33 E 4S.SS S 48. ].7 E 65.46 S 65.47 E 87.86 S 82.35 E 3.56.SS S 13:I..35 E 2].1.01 S 172.39 E 270.83 S 220.83 E 338.21 S 278.38 E 413.17 S' 34S.87 E 503.86 S 431.74 E S84.S1S Sl1.19 E 667.22 S S93.90 E 752.39 S 679.08 E 839.90 S 766.59 E 932.45 S 855.~6 E ' 1000.2S S 9].4.90 1.060.18 S 964.30 1104.45 S ].002.11 1182.26 S 106S.12 1229.6S S 1098.30 E E E E E CLOSURE DISTANCE DG MN S 0.00 0 0 0 0.46 S 47 0 0 E 4.45 S S4 37 9 E I]..41 S 57 54 2]. E 22.73 S 54 27 41E 38.30 S 49 S8 43 E 66.29 S 46 35 S9 E 92.58 S 45 0 24 E ].20.42 S 43 8 S1 E 204.35 S 39 S9 S2 E 272.47 S 39 14 S2 E 349.45 S 39 3.1 36 E 438.04 S 39 27 27 E. S38.83 S 39 SS 60 E 663.38 S 40 36 ].3 E 776.5]. S 41 10 19 E 893.25 S 41 40 22 E 1013.53 S 42 4 S E 1137.14 S 42 23 13 E 126S.?S S 42 33 3 E ].355.56 S 42 26 53 E 1433.13 S 42 17 1.9 E 1.491.31 S 42 ].3 7 E 1S91.29 S 42 0 S9 E 1648.73 S 41 46 14 E deg/.,.' 0.000 .887 2. 452 2 ..o ~ .903 3. 232 3. 026 2. 397 2. S77 I. 857 2. S63 2.9~ 3. 867 .73.0 1. 339 ].. 290 1. 290 O. 641 2. 234 S. 787 2.960 0. 699 1. 333 1. 613 232-9 lO-lO-a's RECORD OF SURVEY MEAS DRIFT DEPTH DG MN 3739 38 0 3863 39 0 389S 3~ 46 3~23 40 30 39S0 40 30 4107 36 0 4232 3], 30 4324 27 0 444? 26 30 4642 24 30 4667 22 0 4808 19 0 4870 17 0 5007 17 30 B130 J.B 0 5224 14 0 S360 12 30 S476 10 30 S~O0 9 0 S¢63 8 16 S772 7 30 S896 7 0 S9S~ 6 30 60S4 3 4S 6117 2 0 TRLIVERT SUBSEA SECTION DIRECTION DEPTH DEPTH DIST ANGL. E 3:111.74 3002.74 ].683.66 S 32.00 E 3208.78 3099.78 1760.67 S 26.00 E 3233.52 3124.52 ],780.68 S 23.00 E 32S4.93 3].4S.93 2,798.42 S 2]..00 E. 327S.46 3].66.46 18].S.61 S 21.00 E 3399.SS 3290.SS 1909.78 S 2]..00 E 3604.07 3396.07 1976.9S S 21.00 E 3683.S# 3474.64 2022_62 S 23.00 E 3694.16 3686.16 2080.01 S 24.00 E 3778.09 3669_09 2119.76 S 27.00 E 3892.93 3783.93 2].68.94 S 29.00 E 4024.98 3916.98 2217.8S S 21.00 E 4083.60 3974.60 2237.3S S 2.4.00 E #22.3.7]. 42.0#.72. 2277.67 S 11.00 E #331.79 4222.79 2309.S9 S 10.00 E 4422.79 43].3.79 2331.S0 S ].2.00 E 4646.43 4436.43 2368.47 S 11.00 E 466?.92 4668.92 2381.74 S 12.00 E 4791.11 4682.11 2401.46 S 10.00 E 4863.40 4744.40 2410.18 S 10.00 E 4961.37 4862.37 2423.93 S 9.00 E S084.37 4976.37 2438.34 S 10.00 E S146.94 S037.94 2446.16 S 9.00 E S241.SS S132.SS 2462.'61 S 1.00 W S304.47 S196.47 2466.17 S 6.00 W RELATIVE COORDINATES FROM WELL-HEAD 2.277.42 S .1344.90 S 1363.38 S 1380.10 S 2.396.48 S 12,28.74 E I. :[66.14 E 1174.56 E 1.].82,.32 E 1187.60 E ].486.17 S 1SSO.1S S 1693.12 S 2.646.49 S 2.682.62 S ~,222.04 E ].246.69 E 1263.96 E 2.287.:I, 6 E 2.304.39 E 2.726. 18 S 1770.89 S '1,790. _'!.3 S 1832.01 S 1866.8B S 1327.SS E 1348.40 E 1364.47 E 1363.76 E ].370.03 E 1888.96 S ],917.26 S 1941.67 S 1962.46 S ].971.76 S 1374.62 E 1380.27 E 1386.24 E 1389.28 E ].390.92 E 1986.48 S 2001.91 S 2009.22 S 2017.6T S 2020.82 S 1393.39 E 1396.97 E 1397.2.9 E 1397.78 E 1397.69 E CLOSURE DOG L.EG DISTANCE DG MN S deg/lO0 1704:66 S 42, 27 SO E 0.412 1780.07 S 40 SS 41 E 2.079 .1.799.SS S 40 44 43 E J1 ].816.66 S 40 33 44 E 4 ~. 1833. 2.8 S 40 22 44 E 0.000 1924.08 S 39 2S 46 E 3.S03 1989.21 S 38 48 19 E 2.800 2033.62 S 38 26 41E 2.766 2089.90 S 38 I 1E 2.006 2129.00 S 37 47 0 E 2.22~ 2177.64 S 37 33 46 E 2. 013 222S_81 S 37 2.7 2.2 E 2_ 211 2244.82, S 37 '6 44 E 1. :197 2283.88 S 36 39 B1 E 1. 113 23.1.4.81 S 36 17 19 E 2.033 2336.11 S 36 2 31 E 1.0",'~1~i ~ 2362.41 S 36 46 4 E 1 2386.16 S 36 30 19 E 1..600 2404.43 S 36 17 46 E 1.201 2412.98 S 36 12 0 E ]..190 2426.44 S 36 2 SO E 0.688 2440.67 S 34 S3 19 E 0.403 2447.26 S 34 48 S2 E 0.794 2464.SS S 34 42 47 E 2.896 2467.03 S 34 40 3 E 2.778 7992 1 0 7178.80 7069.80 2442.20 N 30.00 W 2028.SS S 1361.26 E 2442.96 S 33 S1 49 E 0.063 3RU 232-9 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH MEAS. DEPTH TRU VERT DEPTH SUB SEA MD-TVD DEPTH DIFF. VERTICAL,, CORRECT RELATIVE COORDINATES FROM WELL-HEAD 1.09 1.09 0 0 0 0.00 0.00 2,09 209 1.00 0 O O.O0 0.00 309 309 200 0 0 0.00 0_00 409 ~09 300 0 0 0.00 0.00 509 SO9 400 0 0 0.01 N 0.01. 609 609 SOO 0 0 709 709 600 0 0 4.1.3 S 7.I. 9 81.0 809 700 :I, 1. 9.82 S 1.6.04 911 909 800 2 :l 21.11S 27.2S 1.01.4 1.009 900 S 3 37.80 S #I.0S 1109 1209 1309 1.409 111.7 1.222 1.329 1437 1S47 1.000 8 3 11.00 1.3 S 1.200 20 7 1.300 28 8 1400 38 1.0 ISO0 SO 1.2 1600 66 1.6 1.700 87 21. 1800 11S 28 1.900 1S0 3S 1.6S9 1775 1.896 2024 21S9 1609 1.709 1809 1.909 2009 2300 21.09 2000 1.91 2448 2209 2100 239 2601. 2309 2200 292 2761 2409 2300 3S2 2924 2S09 2400 41S 41. 48 S3 63 S7 #1 30 28 3081 2609 2S00 472 3222 2709 2600 S13 33S2 2809 2700 3#81 2909 2800 S72 3609 3009 2900 600 S7.40 S S9.72 E 82.26 S 79.87 E 1.13.20 S 100.22 E 146.18 S 123.8S E ].82.7S S 1S0.73 E 223.3S S 182.10 E 268.66 S 219.02 E 320.2S S 262.8S E 379.17 S 31.4.d9 E 446.18 S 376.86 E S18.80 S 446.41. E S9S.92 S S22.60 E 678.03 S 604.71E 766.13 S 692.81 E 8S7.83 S 784.64 E 94S.66 S 868.4S E 1020.76 S 931.61 E 1084.97 S 98S.30 E 114S.60 S 1039.29 E 1209.17 S 1.086.28 E 3RU 232-9 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 10. IO-E;S MEAS. I'RU VERT SUB SEA MD-TVD VERTICAL. DEPTH DEPTH DEPTH DIFF. CORRECT 3736 3109 3000 627 27 3863 3209 3100 654 27 3992 3309 3200 883 29 41].8 3409 3300 709 26 4238 3509 3400 729 20 4353 3809 3500 744 IS 4465 3709 3800 758 12 4576 3809 3700 787 ]I 4684 3909 3800 775 8 479:!. 4009 3900 782 7 4897 4109 4000 788 8 S002 4209 4100 793 S S106 4309 4200 797 4 S210 4409 4300 801 4 S3].3 4509 4400 804 3 S415 4609 4500 808 2 S5].7 4709 4600 808 5618 4809 4700 809 5719 4909 4800 810 1 S820 S009 4900 811 S921 S109 SO00 812 1 602]. S209 SIO0 8].2 0 6].22 S309 S200 813 1 8222 S409 5300 813 0 6322 SS09 S400 8].3 0 6422 S609 SSO0 813 0 6522 S709 S600 813 0 6822 S809 S700 813 0 6722 S909 S800 813 0 6822 6009 S900 813 O' RELATIVE COORDINATES FROM WELL-HEAD 1275.11S 1].28.37 E · 1345.06 S ].188.22 E 1421.81 S 1197.33 E ].492.20 S 1224.35 E 1552.93 S ].247.88 E 1605.83 S ].269.38 E :1.653.14 S 1290.16 E 1694.86 S ].3].0.70 E i731.73 'S 1330.69 E 1763.06 S :[351.07 E ].798.50 S 1358.80 E 1830.04 S 1365.50 E 1859.63 S 1369.33 E 1885.56 S :].373.80 E 1909.].1 S 1378.93 E ].930.46 S ].382.90 E ].948.9]. S 1386.83 E ].965.20 S 1389.77 E ].979.49 S 1392.32 E ].992.59 S 1394.38 E 2004.85 S 1398.50 E 2015.15 S 1398.48 E 2020.98 S ].397.57 E 2024.#2 S 1397.47 E 2027.74 S ].397.8]. E 2030.90 S 1398.60 E 2033.84 S 1399.78 E 2036.S0 S 1401.32 E 2038.85 S 1403.18 E 2040.86 S 1405.31 E 3ru 232-~ DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 10-10-85 MEAS. DEPTH 6922 ?022 7].22 ?222 ?322 7#22 7522 7622 7722 7822 7922 TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DIFF. CORRECT 6:].09 6000 8].3 0 6209 6].00 8].3 0 6309 6200 8~3 0 6409 6300 8:1.3 0 6509 6400 8].3 0 6609 6500 8].3 0 6709 6600 8].3 0 6809 6700 8~3 0 6909 6800 8~3 0 7007 6900 813 0 7:1.09 7000- 8].3 0 RELATIVE COORDINATES FROM WELL-HEAD 20#2.#8 S ].407.6# E 2043.7:1. S ].4].0.14 E 2044.52 S ].4].2.74 E 2044.93 S 14~5.38 E 2044.92 S ].4].8.0:1. E 2044.52 S ~420.56 E 20,43.74 S :[423.00 E 2042.6~ S 1425.27 E 204]..].5 S 1427.32 E 2039.#2 S ].#29.12 .E 2.037.44 S ].430.64 E BRU 232-c2 DATA INTERPOLATED FOR EVEN 1000 FEET OF MEASURED DEPTH ].0-10-8S MEAS. TRU VERT SUB SEA DEPTH DEPTH DEPTH 1000 996 887 '2000 1892 1783 3000 2SS6 2447 4000 33].4 320S SOO0 4207 4098 6000 5188 70 O0 cA ].87 5079 cA078 RELATIVE COORDINATES FROM WELL-HEAD 35.45 S 367.91S 899.27 S 142cA.24 S 1829.45 S 38.92 E 304.57 E 827.32 E 1199.03 E ~.365.32 E 2013.36 S 2043.47 S 1398.01 E 1409 59 E Notes: All values lin feet. Depths shown are TVD. Closure: 2443 ft at S 33 d~g 51 rain E Bottom hole: TVD 7179 TMD 7992 Magnetic declination: 24 deg 30 min E HORIZONTAL VIEW CHEVRON U.S.A. BRU 232-9 RADIUS OF CURVATURE MWD ~ MAGNETIC S.S. SCALE; I inch : 400 feet DRAWN: 10-10-B5 D [ft x ¢00 ) 0.40 0.80 !.20 i.80 2.00 2.40 2.80 3.20 3.80 4.00 4.40 4.80 5.20 5.80 8.00 6.40 8.80 7.20 -0,40 VERTICAL SECTION CHEVRON U.S.A. ..... ~ BRU 232-9 ) .RADIUS OF CURVATURE J' "I MWD ~ MAGNETIC S.S. SCALE: ! inch = BOO feet __ . DRAWN' 10-10-85 · . · ...... i I PR)POSEDJ. WELL "'-'-"- AC[UAL w!-LL DR![LLED , j TVa, 7179 [ j ' i ' TMQ '7992 j .... J___.__L_ 0 O. 40 O. 80 t. 20 t. 60 2. OD 2.40 2. BO 3.20 3. iS0 4. O0 4.40 gepaptupe ( ftx ~.ooo ) . Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, 'WELL NAM~ AND ~ER- - Reports and Materials to be received by: /~-~ ~--- Date Required Date Received Remarks Completion Report y~__~,_~ Well History ,, Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Rep°rts Production Test Reports Digitized Data ...... STRATIGRAPHIC HIGH RESOLUTION DIP METER LOCATED IN THE APPENDIX "- ,-: ~,-. STATE OF ALASKA .---- ALASKA iL AND GAS CONSERVATION C~ .?IMISSION MONTHLY REPORT OF DRILLING AND WORKOVER · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Chevron U.S.A. Inc. 84-136 3. Address 8. APl Number P.O. Box 107839, Anchorage, Alaska 99510 50- 283-20075 4. Location of Well atsurface 302'S & 1814'E of NW Corner Section 9, T12N, R10W, S.B.&M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. G.L. = 91' K.B. = 109' ADL 17658 9. Unit or Lease Name Beluga River Unit 10. Well No. BRU 232-9 11. Field and Pool Beluga River - Sterling For the Month of. November ,1985 .12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks TD = 7992', PBTD: 4256', No footage drilled. Rig released 1:00 A.M. 11-25-85. 13. Casing or liner run and quantities of cement, results of pressure tests NA 14. Coring resume and brief description NA RECEIVED 15. Logs run and depth where run NA Alaska 011 & Gas Cons, C0mmlssi0, Anchorage I 6. DST data, perforating data, shows of H2S, miscellaneous data DST #1: 5947'-5928', 5884'-5868' (35' 1 JSPF) No commercial recovery of hydrocarbons. ~ Set retainer at 5756' and squeeze off perforations with 100 sks C1 "G" at 15.8 PPG. DST #2: 4946'-4938', 4910'-4902' (16' 8 JSPF). No commercial recovery of hydrocarbons. Set retainer at 4820' and squeeze off perforations with I00 sks C1 "G" at 16.0 PPG. DST #3A adn #3B: 4758'- 4734' (24' 8 JSPF) No commercial recovery of hydrocarbons. Set retainer at 4690' and squeeze off perforations wtih 100 sks C1 "G" at 15.8 PPG. DST #4: 4630'-4593', 4534'-4522' (49' - 8 JSPF) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,/7/.~'~1~~./]~/~'"~'/~J~ Area Operations SIGNED .......... TITLE Superintendent (cont'd. on attached page) NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Chevron U.S.A. Inc. Permit No. 84-136 API No. 50-283-20075 (Cont'd. from #16.) No commercial recovery of hydrocarbons. Set retainer at 4428' and squeeze off perforations with 100 sks C1 "G" at 15.8 PPG. DST #5: 4316'-4308', 4300'-4264' (tlR'- 5 JSPF) No commercial recovery of hydrocarbons. Set retainer at 4256' and squeeze off perforations with 100 sks C1 "G" at 15.8 PPG. DST #6: 4237'-4218', 4166'-4154' (31' 12 JSPF) Flowed 6.764 MMCF/day on 30/64" choke at 1150 PSI FTP. RECEIVED JAN 0 6 1986 AlaSKa 0il & Gas Cons. Commissior~ Anchorage TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS Ao6cc ALe. AltCNolP.,A~E., AK. ~Fi5Ol WELL NAME: ~ELdGA ~m~EP. We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. J. L. Weaver Chevron U.S.A. Inc. 3001C Street Anchorage, AK 99503 ! , ! RECIPIENT PLEASE ACKNOWLEDGE COMPANY: BY: · DATE: Senders' Instructions:- These transmittal sheets are made on NCR {No Carbon Required) paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send original under sepa- rate cover to addressee. (If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this form. EXP-180-79 (CD-2-85) Printed in U.S.A. .--. STATE OF ALASKA --- ~ ~ ALASKA" .'AND GAS CONSERVATION CC /MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS// 1-~ Drilling weIl~-- ~-~o-~er ~ ~ 2. Name of operator 7. Permit No. Chevron U.S.A. Inc. 84-136 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 50-283-20075 4. Location of Well at surface 302'S & 1814'E of NW Corner Section 9, T12N, R10W, S.B.&M. 5. Elevation in feet (indicate KB, DF, etc.) G.L. = 91' K.B. = 109' 6. Lease Designation and Serial No. ADL 17592 · For the Month of. October ,1985 9. Unit or Lease Name Beluga River Unit 10. Well No. BRU 232-9 11. Field and Pool Beluga River, Sterling 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth = 7992', Drilled 4012', No fishing jobs, No directional drilling problems. Set retainer in bottom of 9-5/8" csg after cleaning out to TD of 7992' with 8-1/2" bit. Dispose of 13,639 BBLS of fluid below retainer. Squeeze of bottom of 9-5/8" csg below retainer at 6545' with 100 sacks Class "G" at 15.8 PPG. 13. Casing or liner run and quantities of cement, results of pressure tests Ran 70 its of 9-5/8" 43.5# N-80 BTC csg and 90 its 9-5/8" 40.0# N-80 BTC csg = total of 6660' set at 6660'. Cement 9-5/8" csg to estimated 3435' with 1100 sacks of Class "G" + .8% Halad 9 3% KCL at 15.3 PPG. CIP at 9:30 P.M. 10/14/85 with 2500 PSI. 14. Coring resume and brief description N/A Alaska Oil & Gas Cons. Commission Anchorage 15. Logs run and depth where run DLL-MSFL-SP-GR 7922'-3935' SWS's 33 Interval 7922'-3935' BHC-Sonic 7922'-3935' CET 6635'-3400' CNL-KDT-GR 7922'-3935' CBL-VDL-CCL-GR 6635'-3600' SHDT 7922'-3935' Gyro 6600'-0' PML 7922'-3935' CET 5000'-4000' RFT's 32 Interval 7922'-3935' A 6. DST data, perforating data, shows of H2S, miscellaneous data Squeeze holes 4950'-4951', 4648'-4649', 4518'-4519', 4339'-4340', 4257'-4258', 4148'-4149', 4149'-4150'. All holes squeezed, drilled out, and tested to 1500 PSI. Confirm squeezes with CET 5000'-4000'. Area Operations SIGNED,'~ ~-'/~_-~ ~~ TITLE Superi_nrandant DATE NOTE--Re~r~ on this form is required for each calendar month, regardless of the status of operations, and must be f~ied in duplicate with the Alaska Oil and Gas[~bnservation'' Commission by the 15th of the succeeding month, unless otherwise directed· Form 1040~, Submit in duplicate TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS · · WELL NAJ~E: ~ vE~ 2 z- We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. j. L. Weaver Chevron U.S.A. Inc. 3001 C Street Anchorage, AK 99503 RECIPIENT PLEASE A,CKNOWLEDGE COMPANY: BY: DATE: Development G Se.nders~ Instructions:- These transmil~tal She&ts are made on NCR (No Carbon Required) paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send original under sepa- rate cover to adUressee. {If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this form. EXP-180-8 (CD-3-82) Printed in U.S.A. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I~ COMPLETED WELL [] 2. Name of Operator 7. Permit No. CHEVRON USA, INC. 84-136 3. Address 8. APl Number P.O. Box 107839 Anchorage, AK 99510 50- 283-20075 9. Unit or Lease Name 4. Location of Well at surface: 302' S & 1814' E of NW corner Section 9, T12N, R10W, S.B. & M. 5. Elevation in feet (indicate KB, DF, etc.) G.L. = 91' K.B. = 109' 12. ADL 17592 OTHER [] I 6. Lease Designation and Serial No. BeluEm River Unit 10. Well Number BRU 232-9 11. Field and Pool Beluga River - Beluga Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other IX Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Propose to perforate and individually test the following intervals MD: 5947'- 5928' 4946'- 4938' 4758'- 4734' 4630'- 459Y 4316' - 4308' 4250'- 4218' 5884'- 5868' 4910'- 4902' 4534'- 4522' 4300'- 4264' 4166'- 4154' 1-1/2" JHPF 8-1/2" JHPF 8-1/2" JHPF 8-1/2" JHPF 5-1/2" JHPF 12-1/2" JHPF Intervals that are not commercially productive will be squeezed off with sufficient C1 "O" cement below a retainer set 100'+/- above the top perforation. Sas 00ns. O0mm~ssi0~ Anchorage Signed ,,,~xLX---/(,/'(~_~_/f~)~,~"a--;'---~-~ Title Area Operations Superintendent I I Conditions o~ Approval, if any: Date Approvea Copy Returned · B~ LO~II~i£ C. $1/!illt By Order of Approved by' COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS DATE: II- 5- WELL NAME' We are sending the material tabulated below. Please acknowledge receipt and return one copy to- ~) ~ Mr. j. L. Weaver 'J Chevron U.S.A. Inc. 3001 C Street Anche~'aqe, AK 99503 / ,, ,, ,, ,,,, 1 ! II ! ! II I' ~ II Il It RECIPIENT PLEASE ACKNOWLEDGE COMPANY' BY' DATE: Development~Geol ogi st f~OV 0 6~ Alaska Oil & Gas Cons, Commission Anchorage Senders~ Instructions:- These transmittal sheets are made on NCR (No Carbon Required) paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send Original under sepa- rate cover to addressee. {If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this form. EXP-180-8 (CD-3-82) Printed in U.S.A. OF TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS DATE: 1~-5-8~ WELL NAME: B~d- · We are sending the material tabulated below. Please acknowledge receipt and return one copy to' 1 Mr. j. L. Weaver Chevron U.S.A. Inc. 3001 C Street An. chorag .~ AK 99503 " ~ "Z' "' ~. 5" P.. y 6e e L° o~ ,, '2_ " g ,,.,\5 ~ ~ w .¢. o . ~, ~,Pr" " 5" xe. t)-r,, RECIPIENT PLEASE ACKNOWLEDGE COMPANY' BY' DATE: Development ~ologist ~-' ~; '~:,,,,' ~,., Cas Cons. Commission ..,.a:;a,,,'., ~ .... ~ s Anchorage Senders~ Instructions:- These transmittal sheets are made on NCR (No Carbon Required) paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send Original under sepa- rate cover to addressee.. (If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this form. EXP-180-8 (CD-3-82) Printed in U.S.A. TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS i , DATE- II-- 4- E)E; WELL N.aJ4E · We are sending the ~terial tabulated below, Please acknowledge receipt and return one copy to: Mr, j. L. Weaver Chevron U.S.A. Inc. 3001C Street Anchorage, AK 99503 / RECIPIENT PLEASE ACKNOWLEDGE BY: , , COMPANY: BY: DATE: , ,RE - I Alasl(a Oil & Gas Cons. Commissio, Anchorag~ 59pdem~ Instructions:- These ~ansmitta1 sheegs a~e made on NCR (No Carbon Required)' paper with three sheegs per se[. Re~ain one copy fo~ o~g~nato~'s ffle. Include one copy wJth transmitted ~te~ia1. Send o~Jginal under sepa- rate cove~ ~o addressee. (If sending by air freight, pu~ air bill numbe~ on backside of.envelope.) Please use bal,-point pen when filling out [h~s fora. EXP-180-8 (CD-3-82) Printed in U.S.A. STATEOF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL l~ COMPLETED WELL [] 2. Name of Operator 7. Permit No. Chevron 'U.S.A. Inc. 84-136 OTHER [] 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of Wel~ at surface: 302'S & 1814'E of NW Corner Section 9, T12N, R10W, S.B.&M. 5. Elevation in feet (indicate KB, DF, etc.) G.L. = 91' K.B. = 109' 6. Lease Designation and Serial No. ADL-~'"J'8 /?~'~ ~ 8. APl Number 50- 283-20075 9. Unit or Lease Name Beluga River Unit 10. Well Number BRU 232-9 11. Field and Pool Beluga River Field - Beluga 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] Well Survey [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). SEE ATTACHED RECEIVED OCT :e 2 Alaska Oil & Gas Cons. Commission Anchorages 14. I hereby ceos true and correct to the best of my knowledge. Signed /~g~l~ ~_~ Title Area Engineer The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate WELL SURVEY Pro~3t2 COUNTY OF CITY OF ELEVATION: GROUND CONCRETE HAT DERRICK FLOOR SURVEYED LOCATION MOVE ,SKETCH OR RENARK$ NORTH SOUTH 8TAT ~ O~ C~C~_ D IV-_ E~!GR. kECEIVED OCT 2 -219~ DiST,~C[ i $1~E AlasKa Oit & Gas Cons. CommissJoD PATE ,..---,~. STATE Or: ALASKA J--'- ~g._.~ ALASKA iLAND GAS CONSERVATION C,. ~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION ZDrillingwel'~ ~roperat r~ ------ 9. Name of operator 7. Permit No. Chevron U.S.A. Inc. 84-136 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of Well at surface 302'S & 1814'E of NW Corner Section 9, T12N, R10W, S.B.&M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. G:T.: = 91' ~:R:- 109'I ADL 17658 8. APl Number 50- 283-20075 9. Unit or Lease Name Beluga River Unit 10. Well No. BRU 232-9 11. Field and Pool Beluga River - Beluga For the Month of September ,1985 2, Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at end of month = 3980'; drilled 3962'; no fishing jobs; no directional drilling problems; spur at 1:00 pm, 9-12-85'. Conduct leak off test below 13-3/8" casing at 3980' to EMW of 17.2 PPG. 13. Casing or liner run and quantities of cement, results of pressure tests Ran 397' of 20" OD 133# K-55 and 94# H-40 BTC casing set at 394'. Circulfite cement to the surface with 490 sks C1 "G" + 6% gel + 2% CaCI2 at 13.6 PPG. Ran 3949' of 13-3/8" OD 72# and 68# K-55 BTC casing set at 3935'. Circulate cement to the surface with 2025 sks C1 "G" + 6% gel at 13.9 PPG.. Tail in with 315 sks C1 "G" + 6% gel + 2% CaC12 at 13.9 PPG. Nippled up 13-5/8" - 5000 PSI BOP's. Test rams, manifold, surface valves, and safety valves to 3000 PSI. Tested annular to 2500 PSI. -14. Coring resume and brief description NA 15. Logs run and depth where run DIL-SFL-SP-GR 3940'-394' BHC Sonic - GR-CAL-SP 3940'-1000' 24 SWS Interval 3870'-720' .1 6. DST data, perforating data, shows of H2S, miscellaneous data NA RECEIVED OCT 6 Alaska Oil & Gas Cons. Commission 17.1 hereby certify that t;foreTg ii true SIGNED //~~ and correct to the best of my knowledge. TITLE Area Engineer Anchorage NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be flied in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CL~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL iXi COMPLETED, WELL [] OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 84-136 3. Address 8. APl Number P.O. Box 107839, Anchorage, Alaska 99510 50- 283-20075 4. Location of Well at surface: 302'S & 1814'E of NW Corner Sec. 9, T12N, R10W, S.B.&M 5. Elevation in feet (indicate KB, DF, etc.) G.L.=91' KB= 109' 6. Lease Designation and Serial No. ADL 17592 12. 9. Unit or Lease Name Beluga River Unit 10. Well Number BRU 232-9 11. Field and Pool Beluga River - Beluga Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing ~ ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.} 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Propose to set 9-5/8" casing as follows: From 6600' MD to 5000' MD: 1600' of 9-5/8" 43.5# N-80 BTC From 5000' MD to Surface: 5000' of 9-5/8" 40.0# N-80 BTC Cement the 9-5/8" casing back to 3400'_+. Drill the cement and float equipment. Dispose of 20,000 bbls. of drilling fluid below retainer set at bottom of 9-5/8" casing. Place 200' of cement below retainer adh place 50' of cement above retainer. Verbal approval was given in telephone conversation with Mr. Blair Wonzell of AOGCC on 10/14/85. RECEIVED' oct 6 Alaska Ojj & Gas Cons. Con, lrnisslot~ Anchorage 14' I hereby cs~tif;tha~the f,°reg°ing is true and c°rrect t° the best °f mY kn°wledge. ./.~,~/;2~ I~/E4 Area Operations Signed //~,/~ Title Superintendent The space below for Commission use Conditions of Approval, if any: Form 10403 Rev. 7-1-80 APproved Co,py J~eturnecl By Order of the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS DATE- I o-'Z3- ~ WELL NAME' ~E L u~A ~ cER We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. j. L. Weaver Chevron U.S.A. Inc. 3001 C Street Anchorage, AK 99503 P,p, , De ve 1 opmen t/Geo 1 ogi s t Senders~ Instructions:- These transmittal sheets are made on NCR {No Carbon Required} paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send original under sepa- rate cover to addressee. {If sending by air freight, put air bill number on backside of envelope.} Please use ball-point pen when filling out this fo~. EXP-180-8 (CD-3-82) Printed in U,S,A, CHEVRON U. i.A. INC. . TRANSMITT~!' 'i_~ND ACKNOWLEDGEMENT OF RECEIPT · MATERIAL - (ALASKA) FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. RECEIVEO BY Aiaska_ (_;il ..~ i":;~: :'r,-iZ' [:Oiil,Ttis$iO,q REMARKS ON OTHER SIOE, THIS SHEZT BY ~ON U.S.A. INC. BOX 7.839 ANOe2H~GE, ALASKA 99510 STATE OF ALASKA f" ALASKA (.,iL AND GAS CONSERVATION CO,,,,VllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 84-136 3. Address P.O. Box 107839, Anchorage, Alaksa 99510 4. Location of Well 302' S, 1814' E of the NW Cor., Section 9, T12N, R10W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 91' GL 6. Lease Designation and Serial No. ADL-17658 8. APl Number 5o- 283-20075 9. Unit or Lease Name 10. Well Number BRU 232-9 11. Field and Pool Beluga River Field - Beluga 12. (Submit in Triplicate) Perforate [] Alter Casing [] t Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.} Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Revision to original drilling program A) Blowout Prevention Equipment: 20" Casing set at 400': Surface hole diverter system containing a 20" annular preventer and a 6" flow diverter. B) Step 4 of Program: Install and test a 20" surface hole diverter system as per AOGCC Regulations and API RP53. (See attached schematic.) 14. I hereby certify that the fo~rrect to the best of my knowledge. Signed ~. c~.~ Title Area Engineer The space below for Commission use Date Conditions of Apprdval, if any: Approved by. COMMISSIONER Approved Copy By Order of / the Commission Date ~a~e Submit "lntenti i Form 10-403 Rev. 7-1 ~0 and "Subsequent Reports" in Duplicate 20" ' ~000 ~i ANNULAR PREVENTER BLANKED OFF 2"' 5C~0 ps~,~ 2C"'2CCC ps, N P 20" HYDRAULIC REMOTE CONTROLLED VALVE 6" DIVERTER LINE 3' ' 5CCC. ps, CASING Alaska Oil & Gas Cons. Commission Anchorage CHEVRON U.S.A. BRU 232-9 REVISED 20" DIVERTER SYSTEM REV. 12-14-84 November 30, 1984 Mr. J. L. Weaver Area Operations Superintendent Chevron U.S.A. Inc. P. O. Box 107839 Anchorage, Alaska 995-10-7065 Re: Program Discrepancies Beluga River Unit Wells No. 224-23, 232-9, 223-26, and 232-26. Dear Mr. Weaver: On November 28, 1984 our Petroleum Inspector, Ed Sipple, went to. your BRU 224-23 location to witness pressure testing of your 20 inch blowout preventer equipment (BOPE). As a result of this visit, we found that the installed BOPE consisted of an annular preventer and a single gate (blind ram). This did not conform to state regulations and appears to be significantly different than the approved drilling program submitted with your application for a Permit to Drill or Deepen. The applicable state regulation is 20 AAC 25.035(c)(1)(A). API 2M, 3M, and 5M stacks must have at least three preventers, including one equipped with pipe rams that fit the size of drill pipe, tubing, or casing being used, one with blind rams, and one annular type. Since the BOPE drawing you furnished with your application for a Permit to Drill or Deepen showed one annular preventer and a double gate with.blind rams and pipe rams, we assumed you planned to comply with state regulations and we therefore approved your application for a permit to drill, Our on-site inspector did approve drilling below the cemented 20 inch casing in violation of regulation after first consulting with a member of the Commission. Considering all facets of the situation the consensus was that drilling ahead to the the next programmed casing point with the BOPE already installed did not constitute an undue risk and therefore the extended delay in operations required to change out the BOPE was not warrented. Please be aware that our action in this matter constitutes a one time exception only. We have no intention of letting the excep- tion establish a precident for future drilling operations in the Beluga River area. Accordingly, you may wish to encourage your Mr. J. L. Weaver Page 2 November 30, 1984 drilling representative and contractor to become kn0wledgable of Alaska-law so these types of situations will not again be encoun- tered. It is our practice to administer violations of our regulations in accord with AS 31.05. 150. Should you have questions regarding the foregoing, please do not hesitate to let us know. Sincere 1~, C. V. Ch-~tt~er~o~ Chairman be: 1.K. CH Attachment August 31, t984 Mr, J. L. Weaver Area Operations Superintendent Chevron U.S.A. Inc. P. O. Box 107839 Anchorage, AlaSka 99510-7065 Re: Beluga River Unit BRU 232-9 Chevron U.S,A. Inc. Permit No. 84-136 Sur. Loc. 2038'E, 296'S of NW cr Sec. 9, T12N, R10W, SM. Btmhole Loc. 3150'E, 2380'S of N%7 cr Sec. 9, T12N, R10W, SM, Dear I~. Weaver: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC '25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter su~eys. Many rivers in Alaska and their dralnsge systems have been classified as important for the spawning or migrate_on of anadromous fish. OPerations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is Prohibited by AS 46, Chapter 3, Article 7 and the ~e~alations promuls~ed thereunder (Title 18, AlaSka A~nistratlv~ Code, Chapter /0) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Envi~o~ental Conservation. wv j L Weaver Beluga River Unit BRU 23~-9 August 31, !984 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout Prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. %~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours ~ V. z ' ~'-t~-:y' C. V. Chatterton Chai~an of Alaska Oil and Gas Conservation Comission BY ORDER OF THE CO~ISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Chevron Chevron U.SA. Inc. P.O. Box 107839, Anchorage, AK 99510 · Phone (907) 786-6600 J.L. Weaver Area 0i~erations Superintendent Production Department 3uly 27, 1984 State of Alaska Permit To Drill BRU 22tl-23, BRU 232-26, BRU 232-9 & BRU 223-26 Beluga River Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 Gentlemen: Chevron U.S.A. Inc., on behalf of itself, ARCO Alaska, Inc., and Shell Western E&P, !nc., proposes to drill BRU .224-23, BRU 232-26, BRU 232-9, and BRU 223-26. BRU 232-26 is being permitted as a contigent well depending on the results of the first three wells. The subject wells are shown on the attached plats Nos. AB-139, AP-D~643, and AP-D-644. For your consideration and approval we submit, in triplicate, the State of Alaska Oil and Gas Conservation Commission Permit To Drill, Form 10-401 for each of the four subject wells. Also enclosed is our check in the amount of $400.00 for the four applications. As shown on the attached plats, the proposed wells lie within the following leases: Well BRU 224-23: Surface Location: + 2459 ' E. 667' N from the SW corner of Section 23, T13N, RIOW. SM. Lease: ADL 21127. Bottom Hole Location: + 2350' E, 150' N from the SW corner of Section 23, TI3N, RI0W. SM. Lease: ADL 21127. Well: BRU 232-26 Surface Location: + 2535' E, 580' N from the SW corner of Section 23, TI3N, RIOW, S.M. Lease: ADL 17658. Bottom Hole Location: + 3098' E, 1618' S of the NV/corner of Section 26, TI3N, RIOW, SM, Lease: ADL 17658. RECEIVED Well: BRU 232-9 J U L 3 0 1984 Surface Location:_+ 2038' E, 296' S from the NV/corner of~laska 0il & Gas Cons. Commission Section 9, TI2N, R IOV/, SM. Lease: A-029656. Anchorago Bottom Hole Location: + 3150' E, 2380' S from the NV/corner of Section 9, TI2N, RIOV/SM. Lease: ^DL 17592. Alaska Oil & Gas Conservation Commission 3uly 27, 1984 Page Two Well: BRU 223-26 Surface Location: + 2271' E, 1418' N from the SW corner of Section 26, TI3N, RIOW, SM. Lease: A-029657. Bottom Hole Location:+ 2271' E, 1418' N from the SW corner of Section 26, TI3N, RIOW, SM Lease: A-029657. All the surface locations and bottom hole locations fall within the boundaries of the Beluga River Unit. Pursuant to the Alaska Oil and Gas Conservation Regulations and the applicable statutes of the State of Alaska, Chevron U.S.A. Inc., as Unit Operator, hereby requests the Alaska Oil and Gas Conservation Commission to issue an order allowing exception to Title 20, Alaska Administrative Code, Section 25.055 to permit the drilling of BRU 224-23, BRU 232-26, and BRU 223-26. BRU 232-9 does not require a spacing exception as it is the first well on Section 9 and is more than 3000' from the nearest well. The spacing exception is needed to efficiently drain the Beluga Pool and to develop sufficient deliverability to meet the new Shell Western E&P, Inc./Alaska Pipeline Company gas contract. BRU 224-23 will be the second well on Section 23 but will be +_ t~900' from the other well, BRU 221-23. BRU 232-26 will be the first well on Section 26. It will be_+ 1700' from BRU 224-23 but will be completed in different intevrals than BRU 224-23. BRU 224-23 will be completed in the upper three zones of the Beluga gas accumulation while BRU 232-26 will be completed in the lower six zones. Contingent well BRU 223-26 would be the second well on Section 26 and would be + 2550' from the other well, BRU 232-26. Again, however, these two wells would be completed in different intervals. BRU 223-26 will be completed in the upper three zones while BRU 232-26, as already noted, will be completed in the lower six zones. Chevron U.S.A. Inc., ARCO Alaska, Inc., and Shell Western E&P, Inc.~ each owns an undivided one-third (1/3) interest of the subject leases and are the sole owners of all leases on the sections directly and diagonally offsetting the sections to where the wells BRU 224-23, BRU 232-26, and BRU 223-26, are to be drilled. ARCO Alaska, Inc., and Shell Western E&P, Inc. were notified of this application with a certified copy of this letter. There are no other working interest owners or operators which would be affected by granting the spacing exception on the subject wells: BRU 224-23, BRU 232-26 and BRU 223-26. Pursuant to the Oil ang Gas Conservation Regulation Title 20, Section 25.035, Chevron U.S.A. Inc., hereby requests the Alaska Oil and Gas Conservation Commission to issue an order allowing a waiver of the surface hole diverter system based on Chevron's experience in drilling at Beluga River. 3UL 3 0 IBB Alaska 0il & Gas Cons. Commission Anch0ra§o Alaska Oil & Gas Conservation Commission 3uly 27, 198# Page Three Below is list of the wells drilled at Beluga River and the conditions found while drilling the surface hole. ._ Well Depth of Surface Hole Mud Weight Oil & Gas Shows BRU 232-4 302' 9.9 ppg None BRU 244-4 310' 9.1 ppg None BRU 224-13 423' 9.5 ppg None BRU 212-18 411' 9.7 ppg None BRU 221-23 414' 9.7 ppg None BRU 212-24 365' 9.9 ppg None BRU 212-25 288' 9.9 ppg None BRU 233-27 303' 9.3 ppg None BRU 241-34 405' 10.0 ppg None BRU 212-35 129' 9.5 ppg None BRU 214-35 410' 10.4 ppg None Chevron U.S.A. Inc, as the Unit Operator, believes that the Permit To--.Drill Applications and the two exceptions that have been requested are necessary and desirable in order to efficiently drain the reservoir. The gas that the new wells will produce is needed to continue to meet our obligation to Chugach Electric Association, Inc., and to meet Shell's new commitment to Alaska Pipeline Company, a subsidiary of Enstar Natural Gas Company, which is building a 20" gas transmission line from Beluga River to Anchorage. The line should be completed this fall. :3AC:sj Very truly yours, ~.L. Weaver Attachments: (1) Four (4) AOGCC Permit To Drill Applications (2) One (1) BLM Permit To Drill Application (3) Drawings: AB-139, AP-D-643, AP-D-644 CC: ARCO Alaska, Inc. (Certified Mail No. P 200 285 876) Attention: Mr. John C. Havard P.O. Box 100360 Anchorage, Alaska 99 510 Shell Western E&P, Inc. (Certified Mail No. P 200 285 877) Attention: Mr. B. E. Barnard P.O. Box 527 Houston, Texas 77001 RECEIVED J U L o t984 Alaska Oil & Gas Cons. gomrnissior~ Anchorage STATE OF ALASKA THIRD 3UDICIAL DISTRICT ) ) ss ) 3. L, ~/eaver, being first duly sworn, upon oath deposes and says that he is the Area Operations Superintendent, Production Department, employed by Chevron U.S.A. Inc., and to the best of his knowledge and belief that the facts stated herein and shown on the accompanying plans are true, and that the accompanying plats are drawn to scale and correctly rei~lect pertinent and required data. Subscribed and sworn to bel~ore me this ~"~-~ day of c-{.---...I , 1984. Notary Public in an{_~or the State of Alaska ~L~ q ~,~-~'~- RECEIVED J U L ~ o ]cjg4 Alaska Oil & Gas Cons. Commission Anchorage "--' STATE OF ALASKA -- ALASKA O;~ AND GAS CONSERVATION COb iSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~ MULTIPLE ZONE [] 2. Name of operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, Alaska 99510 4. Location of well. at surface ~ 2038'E, 296'S of the NW corner of Sec. 9,T12N,R10W,SM At top of proposed producing interval ~ 2920'E,1949'S of the NE corner of. Sec. 9, T12N, R10W, SM At total depth ~ 3150' E, 2380' S of the NW corner of Sec. 9,T12N, R10W, SM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 108 KB Surface.- A-029656 Bottom Hole TD: ADL 17592 12. Bond information (see 20 AAC 25.025) TYpeAOGCC Blanket Bond Surety and/or number U80-61-55-22 13. Distance and direction from nearest town Northeast 10 miles 16. Proposed depth (MD & TVD) 7933' MD 7209' TD feet 14. Distance to nearest property or lease line 1700 feet 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE SIZE Casing Weight 30" 1" wa 20" 94 13-3/8" 68 9/5/8" 4O 9-5/8" 43.5 Hole 30" 126" !.17~" 12¼" 12¼" 22. Describe proposed program: 17. Number of acres in lease 1364.18 20. Anticipated pressures 45 ° (see 20 AAC 25.035 (c) (2) Proposed Casing, CASING AND LINER i Grade / Coupling / Length! 11 wel~ed 7' 1 80 H40 ]Butt / 400 K55 I'BUtt / 3900. N80 ~Butt / 5000 NS0 1Butt ~ 2933 .iner and Cementing Program SETTING DEPTH MD TOP TVD 0 I 0 0 ~ 0 O ~ 0 I 0 ~ 0 5000 ,4285 9. Unit or lease name Beluga River Unit 10. Well number BRU 232-9 11. Field and pool Beluga River Field, Beluga Amount $200,000 15. Distance to nearest drilling or completed we, BRU 244-4 4000 feet 18. Approximate spud date Januarv 1: 1985 2 ~ 0'0 psig@ _ Surface ___2_8_Q0_psig@ 7207 .ft. TD (TVD) MD BOTTOM TVD 80I 80 40~ ~00 39001 3300 5000I 4285 79331 7207 QUANTITY OF CEMENT (include stage data) Dr~vmn 5OO SX 2500 S× 900 1st stage 400 2nd stage See the attached drilling program. RECEIVED J U L 01984 Alaska Oil & Gas Cons, Commission Anchorage 23. I hereby certify that the for,egoing is true and correc'~ to the best of my knowledge SIGNED %/~~//~ TITLE Area Operations . The space be~ for Commission us~ Superintendent · CONDITIONS OF APPROVAL Samples required Mud log required []YES ~0 []YES Permit number Approval date Directional Survey required []NO I APl number i;~ES ~o- z 8 Z ~ ~ ° ~?~r~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE August 31, 1984 by order of the Commission Rev. 7-1-80 Submit in triplicate PROPOSAL FOR WELL OPERATIONS PRO 316-1 FIELD: Beluga River PROPERTY AND WELL: Beluga River Well No. 232-9 SURFACE LOCATION: (Proposed) + 2038 feet east and 296 feet south from the n-orthwest corner of Sec. 9, T12N, R10W, S.B.&M. BOTTOM HOLE LOCATION: 3150 feet east and 2380 feet south from the northwest corner of Sec. 9, T12N, R10W, S.B.&M. at -7100' VSS. ELEVATION: Estimated K.B. elevation of Brinkerhoff 58 is 107 feet. Ground level to K.B. is 18 feet. BLOWOUT PREVENTION CONSIDERATIONs: 1. POtential Problems i. Gas and water entries; No high volume gas flows are expected above 3000'. Coal seams can be encountered anywhere from the surface to T.D. A controlled penetration rate and degasser should eliminate any gas encountered while drilling coal seams or through the productive interval. No water flows are expected. Be Lost Circulation: Lost circulation is not expected with the programmed . mud weights. C. Stuck Pipe: Coal seams should be drilled and reamed with care. De Precautions: Ail kicks should be handled by normal procedures' Drilling crews should be made aware of these methods prior to spudding. Kick and BOP drills should be practiced at regular intervals and noted on the tour sheets. An adequate supply of weight materials should be at the well at all times. . Maximum Anticipated Formation Pressure: 1521 psi 9.2 ppg 0.48 psi/ft' 2789 psi 9.2 ppg 0.48 psi/ft. Maximum Anticipated Surface Pressure: 2500 psi. + 3093' + 5740' 4. Blowout Prevention Equipment: 20" casing - Class H B 2000 psi BOPE with 3000 psi choke and kill line. 13 3/8" and 9 5/8" easing - Class IH 5000 psi BOPE (BSI Rig 58 has 13 5/8" 5000 psi BOPE as standard equipment). Nipple up and test as per AOGCC Regulations and API RP 53. R E C E[V E D J U L 0 1984 Alaska Oil & Gas Cons. Commission Anchorage BRU~.-~ Section.q~o .T12N R10W S.B.&M. Beluga er, Alaska PROPOSAL FOR WELL OPERATIONS PRO 316-1 DIRECTIONAL CONSIDERATIONS: Direetionally drill to within a 200 ft. radius of the top target at 2920 ft. east and ~[949 ft. south of the northwest corner of Section 9 T12N, R10W of SM at a vertical sub-sea depth of -3290 ft. and a bottom hole target of 3150 ft. east and 2380 ft. south of the northwest corner of Section 9 T12N, R10W of SM and a vertical sub- sea depth of -7100 ft. as per the following proposed directional program and attached plats: 1) Drill a straight hole to near 500 ft. TMD, 393 ft. VSS. 2) On a course of S28OE, kick off at 500 ft. TMD, build hole angle at 3 degrees per 100 ft. to a total hole angle of 45 degrees to near 2000 ft. TMD, -1743 ft. VSS, 559 ft. Drift. 3) Hold the 45 degree hole angle to near 2893 ft. TMD, -2375 ft. VSS, 1191 ft. Drift. Drop the hole angle at 1~ degrees per 100 ft. to near 5993 ft. TMD, -5161 ft. VSS, 2362ft. Drift. 5) Hold the hole angle at zero degrees to intersect the proposed target near a depth of 7933 ft. TMD, -7100 ft. VSS, 2362 ft. Drift. 4) RECEIVED J U L 01984 Alaska Oil & Gas Cons. Commission Anchorage PROGRAM BRU232-9 Sect. 9 ~'~N R10W S.B.&M. Beluga. er, Alaska . . Drive 30" eonduetor pipe as deep as possible (+_ 80') Drill for 20" easing to + 400 feet. Run and cement 20", 94#/ft., H-40,-SflSfr~ casing as follows: A. Use a guide shoe with a stab-in duplex float collar one joint up. B. Thread lock the bottom two joints. Ce Use three Centralizers on bottom two joints and one every other joint to surface. De Circulate two hole volumes. Precede cement with 20 bbls' of fresh water. E. Mix and pump Class "G" cement with 2% prehydrated gel by weight of water (or 6% dry gel by weight of cement). a. Slurry weight - b. Mixing Water - c. Yield - d. Compressive strength - 13.9 ppg. 8.56 gal. water/SX cmt. 1.655 CF/SX cmt. 600 psi after 24 hours' F. Use 30% excess cement. Perform a "top job" if cement returns are not obtained. Install a 20" - 2000 psi Class II B BOPE with a 3000 psi or greater kill line and choke manifold. Install and test per AOGCC Regulations and API RP 5.$. C!,,~ ~T~'~.,"!' qnd ~OGCC ?~ ho,~r n~?e to ,.,:~+~-~ ~'~P~ ~:t, 6' . Log and take SWS as per Formation Evaluation Program. This program to be provided. Wellsite geologist to witness logs and specify SWS depths. l S Run and cement~ 68#/ft., K-55 buttress casing on bottom as follows: A. Use a float shoe with a stab-in duplex float collar one joint up. B~ Centralize the bottom 4 joints, dog legs' and at the 20" casing shoe' C. Cireulate two complete hole volumes' D. Mix and pump a pr,flush of 10 bbls. fresh water, 20 bbls. of 2% caustic water (by weight of water), 5 bbls. of fresh water. RECEIVED JUL 0 Oil & Gas C,~ns. CoiTImJ~.~ion . 9' 10. 11. 12. 13. 14. 15. BRU232-9 Sect. 9 TI~-~R10W S.B.&M. Beluga Ri: , Alaska E. Mix and pump Class G cement with 2% prehydrated gel by weight of water (or 6% dry gel by weight of cement). a. Slurry weight - b. Mixing Water - e. Yield - d. Compressive strength ' 13.9 ppg. 8.56 gal. water/SX cmt. 1.655 CF/SX cmt. 900 psi after 24 hours. F. Use 50% ex,ess in open hole section. Cut the 13 3/8" casing and weld on a 13 5/8", 3000 psi X 13 3/8" SOW casing head such that the top flange of the tubing spool is 1" to 2" above G.L. Install a Class HI, 5000 psi, BOPE as per AOGCC Regulations and API RP 53. Give BLM and AOGCC 24 hour notice to witness test. Test to 3000 psi. Install mud loggers. Drill to within 10' of the shoe. Test casing to 1500 psi. Drill out the shoe plus 30" Perform a leak-off test. Drill a 12¼" hole to 7933' + 40' MD (-7100' VSS). Directional requirements as per attached PRO 316-1. -Obtain a ~ gal]on mud sample just prior to POOH for logs. Log and take SWS as per Formation Evaluation Program. This program to be provided. Wel]site geologist to witness logging and specify SWS depths. Run and cement 9 5/8" casing on bottom as follows: A. Use 43.5#/ft., N-80,' Buttress casing from 6600' to 5000', and 40.0#/ft., N-80, Buttress casing from 5000' to surface. 8, ~un ~ ~l.o~t ~hoe and f!oat eo!~qr two ~o~nt~ ~nart ~,nd ~,ea~ lock. E. F. Circulate two complete hole volumes. Keep the mud plastic viscosity and yield point as low as possible. Cement 9 5/8" casing in two stages as follows: 1st stage: 1. Mix and pump a pr,flush of 20 bbls. of fresh water' 20 bbls of 2% caustic water (by weight of water), and 5 bbls. of fresh water. 2' Mix and pump class G neat cement with friction reducers, fluid loss additives, and retarders as needed. Volume to be calculated from caliper log to bring cement top to the stage collar (no excess). RECEIVED a. Slurry weight - b. Mixing water - (~ Yield - 15.6 ppg 5.2 gal. water/SX cm t. ,] U k ~ 0 19~ 1.18 CF/SX cmt. ~a 0il & Gas Cons. Commissio~ 16. 17. 18. 19. 20. 21. 22. 23. BRU232-9 Sect. 9 T12~R10W S.B.&M. Beluga Ri~ Alaska Ge 2nd stage: le e Drop bomb, open stage collar, and circulate a minimum of two hole volumes. Mix and pump preflush as in 1st stage. Mix and pump class G neat cement as per 1st stage' Volume to be calculated from the caliper log plus 30% excess to bring cement top + 500' up in the 13 3/8" casing. Work the casing throughout circulation and 1st stage cementing if possible. H. Keep the cement in turbulent flow, if possible, while pumping. Land 9 5/8" casing in the 13 3/8" SOW casing head. Install a 13 5/8", 3000 psi x 11", 5000 psi tubing head. Test secondary packoff to 5000 psi. Nipple up a Class III, 5000 psi BOP. Test to 5000 psi as per AOGCC Regulations and API RP 53. Clean out cement to the float collar using a bit and tandem scrapers. Test casing to 1500 psi. Run a gyroscopic survey from T.D. to surface. Run a cement bond, GR-neutron log from PBTD to the 13 3/8" casing shoe. Testing and/or completion program will be provided. JBL:mw M'K. Rieken RECEIVED J U L 01984 Alaska Oil & Gas Cons. Commission Anchorage BRU232-9 Section 9 T121w-~10W S.B.&M. Beluga River, !ska DRH.Ln~G MUD DETAH. SHEET Lightly Treated Chrome-Free Lignosulfonate With KCL for Clay Inhibition Optimum Mud Properties Mud Type Density Funnel Viscosity (See) Plastic Vis. (CPS) Yield Point (#/100 ft.2) Initial Gel (#/100 ft.2) 10 min. Gel (#/100 ft.2) Ph Ca. (mg/1) Cl. (rog/l) Fluid Loss (ee. API) Spud Gel - Water 8.6 - 9.2 17 ~" Hole 12 ¼" Hole 9.2 - 10.2 9.2 - 10.5 + 35 + 35 6 - 12 6 - 13 21 - 8 21 - 7 1-5 1-5 4 - 10 4 - 10 9 - 11.5 9.5 40 - 200 40 - 200 5000 + 30000 5-7 Optimum mud properties are not required until the cement in the 13 3/8" casing string is drilled and treated out. RECEIVED J U L 01984 Alaska 0il & Gas Cons, Commission A~chorage Chevron ANNULAR PREVENTER ,~ s/8': -coc p,i 2"-5000 psi KILL LINE 2"-5OOO psi t5/8"-5OOO psi DOUBLE GATE PIPE RAMS BLIND RAMS MUD CROSS SPOOL 13 5/8"-5OO0 psi 13 5/8"'5000 psi 3"- 5000 ps i ~,3"- 5000 psi TO MANIFOLD BULL PLUG "~ SOW 13 5/8 "- 3000 psi ~,.2 "-3OOO psi BLIND FLANGE CEMENT CLASS .Iii BOP (B) CHEVRON U.S.A. BRU 232 -9 NPB 20"- 2000 psi ~NNULAR PR~¥ENTER I I 20"'2000 psi WP P;PE RAMS BLIND RAMS DOUBLE GATE ChEvron KILL LINE 2"- 5000 psis, 20"-2000 W.P. 20" 3"-5000 psi $"-5000psi TO MANI FOLD 20" 0 D CASING CEMENT CLASS ]~ BOP (A) 8RU CHEVRON U.S.A. ECEIvEb JUL 3 o i$&I ~la~ka Oil 2 3 2 - 9 OnOrage NPB ' 2"- 5000 psi KILL LINE [hevmn CHEVRON · · · · · · U.S.A. ANNULAR PREVENTER I S5/8''- 5000psi e--IS 5/8 "-5000 psi IS 5/8 "- 5000 psi DOUBLE GATE 2"- 5000 psi P~PE RAMS BLIND RAMS ~--IS 5/8"-5000 psi TUBING HEAD a~' 11"-5000 psi S"-5000 psi TO MANIFOLD BULL PLUG I I I I SOW ,~5/~"-sooo :5000 ps i BLIND FLANGE 95/8'' ~8" CEMENT · ' l' il e · I I I I ' ' , I~ ,1 , ~n" i I ! ~1 '"'" so" CLASS TrT BOP (C) BRU NPB -- Notes: Al! values In feet. Depths sho~n are TVD. . Closur~ 2362 ft at S Z6 deg 4 m[n E Bottom hole: TVi) 7206 THO 7933 Hagnet~c declination: 24 deg E HORIZONTAL VlEit CHEVRON U.S.A. BRU 222-9 RADIUS OF CURVATURE HELL PROPOSAL SCALE: t inch = 500 feet D~NN: 7-t8-84 FI Cons. Cornrnis~ Anchorage On T ( fi: X 200~ M.D. ! ^¥erage ^rig' Sti ~rt o' · 3398 V. 1874 De VERTICAL SECTION CHEVRON U.S.A. BRU 232-9 FL~IUS OF CURVATURE NELL PROPOSAL SCALE: i inch = tO00 feet DRAIdN: 7-t7-84 ! End o~ Drop 9.00 -0..f0 0 -"i !.00 I I 2.00 2.50 _ 3.00 4.00 (1) Fee (2) Loc (21- thr~ 2'~) ~' ) 2', 3. 4. 5. 6. 7. 8. e I0, 11. .12. .13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. "'?~:'. .,~.,,. ~:_ :,¥. -, -" . ~i~. . . " .'' · "...~).: ~. -:, ~:¥i -: '".. .' attached ,'. · . Is the permit fee ' Is well to be-located in a defined pool ....... , ..................... Is well located proper distance from property line ............... ... Is well located proper distance from other wells .................... Is sufficient undedicated .acreage available in this pool ............ Is well to be deviated and is well bore plat included ............... Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. Is a conservatiOn order needed ...................................... / . ' Lease &"~ell!i . . ~EMARKS Is administrative approval needed .' ................................. Is conductor'string provided ........................................ Is enoUgh cement Used to circulate on Conductor and surface ......... Will cement, tie in surface and intermediate or production strings ... Will cement coVer all known productive horizons ..................... Will surface casing proteCt fresh water ZoneS .... ' ................... Will all casing give adequate safety in collapse, tension and burst.. Is this well tO be kicked 'off from an existing wellbore .......... ~.. Is old wellbore abandonment procedure included on 10-403 ............ /~/,/~, Is adequate well bore seParation proposed ................ ' ........... ~--~ '' Is a diverter system required .......................... ' ....... ' ....... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test t~z~z~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) ........... . ....... ~/DT- fp~/~/.7~?-~-~ Additi 1 q ir oma re u ements ... ........................................ Additional Remarks: Geology: EngiBe~ ering: HWK ----' ~cs 7'~)~-' ~EW WVA~ ~HJH~jAL- rev: 12/08/83 6. CKLT ' 'INITIAL 'GEO. '"' UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE o ~ ~ s'~ o 0~*..~ I-~ ~ v o ~-o ~'~ o ~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. S?RAT~GRAP'HIC V~I~H R~SObUTiION D~P~E?ER MSD ~OMPUTAT~ON$ COMPANY CHEVRON USA COUN~RY I USA RUN ) DAT~ ~O'GG~D I I2 - OCT REFeReNCE t 5~59 BR0232 - ********************************************** DEPTH ,6¸' 6 ~8 1 13'9, ~ot 'ORR. 5 2'5 i 5 23 5 :69 ~980~40 "'"!° 6q90. 6994. 699' ,' ' , ,' D~P DEr D~V DZAM DIA~ Q ~' uSA ,~.,:'. 2:{2'-.-,..~***,******** PA,;; s.r,' .~,,,; ~ ************************ DZ'P O'ZP ~E~ P'~V '~ZhH ~Z,,AH O ~", ?O60 ~? '70 ( ,,,ili,, ! i 1 1 1 i; I: ,! { 12,6 ! 2 '.,'6 **,**,************,****.******************,**.*********,,,,****,**,***** ,'6 $3 4, 309 1 '5 ,' ~ B B A A A O B A AC 08 ~R oeRae $o i' 235 ~O'RR 8 199 ~ 0 :6 A C 'B B A, B A ~ DEPT~ ~JP DTP DEV DEV I)IAM I~Z,,~,lq.: ,Q' * · , , ',.01 ~: ~ A' , ' ,~32.00 3'B. 4, ' A ~. ~,. · B B · ' B ORR · 99 NO O~R * · ?$91.;99 NO ~ORR · 7697,~,9 5,2' 72 A · ?:~9g~9',g NO'CORR · *********************** ******************************* '~ ~'EP~H O~P DYP D~V DEV DZ~M D~'~ O e~ ************************************************************************************************ ~8 N~ CORR. · ~8 R $ C: A "~ B' ",: "$ ' A ,. ,,,. , ' *********************************** O' ,, Lq ~ 6',5 :~9i ~rJ ~'O~R2 NO C'OI~R ~1~, $ ~ORR ORR ************************* ,! SO k A B B A~ J~ B ¢ D $. at. *.. I~,. $ 7i~7 2~ 94 3, l?ll · : i 4'1 41, 3!45' 340 3:~ 343 347 148 I'~ I 94 ~ B B A' C. B ..v,o~*********************,::,. ******************************************s.u" ,****, ~ ' ~ .'.'~. :~:4 *' ~*. ********************************************* , ?O.p ,t 69'0:0~7000 ~.000~~ 7~00 ?I00" 7200 7'300"'7400 ,?~oo-,:?,soo ?'6Oo' ~'900- 7969 300 3,30 a! 30 ! ! · I 1 I 2 1 I I 1 60 ! I 5 6 9 ~o, 4, ~5,~ .9, 6' 5' 4 .,.7 210 $900'~ 7000 ~'2oo,~3oo ~4oo*75oo 7500-~600 ~6oo' ??,oo ~?oo',. 78oo 7800- ~900 ~ 300 330 ~ 30 60 ~ ! i :2~. 2 ! I 2 % 3 120 2 ! 4 ! 2 tSO 4 4 9 2 5 220 4 1, 4 1 &gOO- ~000 ~000-'7100 9100-' ~200 ~oo',~oo ~oo'~Oo '?~00"7600 ~700- ?800 4 4 ?800' 7900 I :2 9900-' ?959 '~2 120 i50 S 2'i0 .240 5 6 .3 4 4 3 6 2 9 I0 4 3 3 2' 4' :6 2 5 t 3 2 4 ? ,2 2 :~oo ~ao ! ,t 2 3¸0. ~900-9000 ~0,00' 9100 ?I, 00" ~200 ,7200- ?~00 ,7400-TSO0 . 9oO.?eoo .?~O0- ??00 :7800.:T900 7900-, 7969 6O 2'10 240 $, 5 2, 5 3'00 ! 1 I. ! 2 2: 3O ! 2 .eHgV.O..sA h, eU 232., SU.NA,Ry t 6900,.50 9,? 57,.: 0 9 2{2,.. i2,4 I~,,4 .* 7969,~4 ~8 4 40 0°9 3531, 1{,,5 10,9 ~': *' ¢OON~ ~ USA RUN '2 DAT~ LOGG~D. I 12-:O~T * 8~ WIAGNI~'I']:~ f)F.,Cb1:NA?]~O, ~0 hATZTI,,IDI~ 60'8 DF'GREF.$ BOR~HO~£ AZtlqOTH ~OIqRI~C'i"ED POR NA~ 3HDT 4X2X]O MSD ,S, 208 NOO.I 74 168 ~ '68 A, B D B A A B A A ~7 R N~CORR 5 C ,.,.,,,,,,..,,,..,,.,.,,,,,,,.,,,,,,,,, * DKPT~ D'~P D~P DE'V D~V DZ~ D~A~ ~ , AZ~ . ~ 1~3 2-,4 . ~li ~ '~' I'~ * 0 ~'~ :o~. N.~' CORR ~ .t 32,6 21'6: ~***~ ,~, i~ 600~ ~ 6001 A A A ,A A A C :l C A 'A A A A A A ,C D A A '60 ',60 60 6 0 60~ 6 0,26 60~ 6t 61 6~ 6i ~6 9 N~ ~ORR '0 NO ~ORR R 60941,94 6096*94 ~ ~0: 609g,~5 30 6t0~,96 ! ¸, JIF i:,.7 I;7' 4,'0 4,0 . 4,'0 .9, 6 $ 618 '~ 616 · * 6 ! 8 ,$ ,.,~ '~' *****, *************************************** ~ DEP'?H DZP DZ'P DEV' D'~V DZAN ********************************************************** !,$O, '~ ,20' .e A B A B B, B B A B B C A A B B A i. $, I ~1. Ill. ******************************** ******************************************************************* ~EPTH' DXP D~P. DEV 'DEV' D~AM D~M, g' ~' , ****.4141.***** 41 ********************************************** *************************** 6 I ,41 6~ * 41. $ 6 *¸7 1~,~0R 9 6 't ,01 A 2O ~ B ~ORR 12-8 B ~ DEPTH ~'P D~P, ~gV O~V 'O~A~ ~Z~K G 8. 6 6! 128 1!{9 CORR 4 214 A, B i" A C, C A ************************************** ,,***. , ~K~ A~. ~:~,3 * ************************************************************************************** ,$ 24] ,'! 240 CORR.. t 21: ~ ************************************* · ~ 'DEPTH DIP D'~P. D',E~ D'EV D':~AM :D'~RH' G ¸6: ~O~R NO ~ORR' NO B C . . ************************************ ************************ *********************************************************************** * 4 B A A A 'C C CC' A A B. C C:: A' A B *********************************** 665" tS"/ 6,6 241 A A B B A .B B 'iii: ,. "1~. ,, 6 208 , 167 'ORR 3 2Si 4 D B B ,,,,.,,,,,,,,L~,,~,,,iQL,~ ***************************************************** DEPTH DIP .D~P 'DEV' D'EV DX~M "DXA~ · g '~' "~ $ ,$ $, $ 15.o 125 l,,.O ~,~ 178 1,0 4 7.5 172 1.0 2' 3 S.,~ 206 l,o 2 3 3.0 1~9" 1,0 2 2~ i"t. !!' 2,6 3,46 t.0 ,6.0 13'2 1,' 1 94 7,.2 2 1,.~ 8,9 2{'6 I.t 2 ?,l 259 t,.i. 12~4 8,3 IS! i,..i 2~:1 8,4 148 i,:1 273 27.2 130 1','I ?4 i1',8 2mi i,O 28'8 25.0 8'6 1,0 i !i ' ""' 2:: t ': 2,4 ,1.,~ ~,9 1~9 t,..O ~',q 48.5 169 ,*****,*****,, ,~ A B A A B' A BB C B. B B B A A B B $ ;'$ ~E:PT'H ~':XP D~P DEV D~V DXAM D%AM O ~ 2~4 1 1 o..'~ I' OeR 4 5 C B ~,, C A k' *************************************** , .?uP . ,, ,. 5'e9~,~5 s~.t s~.. ,...~ ~ee,, ~2~5 ~,~, A,~, , 300 :t30 ~, 30 60 ~20 tS0 210 6700° $800 SSo,o*:$90o 69.oo,,6oo,o 6000'",6100 62000.* ~300 '6 3':00"6400 6400' 6500 ,'6500~ 6600 6600- '6700 670'0' 6800 6800' 6900 6900' 69~9 1 ! '2' ,2 ! 9 2~ 4 9' 6 3 2 4 ¸2. 1 S700- 5800 seo, o, oo S Oo, soOo :$Ooo, ~loo ~tO0- ~2~0 $200~ 6300 $300~ 6400 :640'0' 6500 '650'0~ 6600 '$700~6eO0 $900' DIPS , ,.** 300 :330 ~I 30 60 2 ! I t 120 9 4 7 1 150 5 2 5 7 7 9. 5 4 4 4 5 6: 2 2. ~9oo,~ooo ',GO00- 6100 '6100"6200 elOO, 6~o,o ~4oo,'e5oo .'$5Oo"~eeoo. eeoo.' 67oo. ~oo, eeoo e~Oo. ~9oo E 1~0 i_50 $ 210 240 4 2 4 2 2 4 2 2 2 3 3O 2 S69~0 57o0' S?Oo' ssoo S'800': ~9'00 $:9'00': ~000 '$000' ~lO0 6tO0' ~200 ~200' ~300 ~3:00'' ~¢00 ~400- ~500 :6'500' ~600 '~600' 6?00 ~800'~900 $900' 60 ,g t~O ~50 $ 2~.0 240 ~ 6 3 3 ? ~oo ~3o 2 I 2 ! ! 4 2~ ! i {0 e,,~'v,:o~,~.~ ****************************** ~ D~'P?H e DIP DZP, ~ $69~.~15' ~.! ', ~2~.,~ ~.s ~.~.,~ ~..~ ,' ********************************************************************************* D!:,PME.~'ER" C'D.MPA~¥ i CHeVrON USA W~bb ~ BRU 232 -'9 rZ'E~O i BEbUGA RZV~R RUN i 2 R'~r~R~NC~· I 5~59 MAGNE:?]:C: OECLZNAT~ON ~0 DEGREE8 bAT1~TUD'r' 6008 D'EGRE~$ ~HO~ 4x2x~o 4~7 458 4~,9 28,.'8 83 2.,~ ~ 2 1'18 1,4, 8 :NO 'eORR ~4' NO ~ORR EORR ' ' 240 2,:; ,,i** 14¢ ~1,2 146 ! 12, ~ D,EP~'H~%P D~P 'DEVD"~VO'ZR.M :DZAM Q' * I' ~ il~ t~:' ~'~ ~ , 6 93 43 ! 14,6 e 4' ~2', 47 ! 14 A ,'SO ., I~ ~., ~,, 'iL ', Ii e 41 ,2 {8 ,9 '* 41 CORR .0 '* ,6 144 ,3 158 9 O ~: I4,6 C' * 14,0 B 136 ~ 16 ,9¸ B A A A1 A A A A B A D iB D B A C C A A , , $ * ..iii. l jJJjl J]Jll JlJ' ',: ii#.. ~JJ~. ~ljJ ,l *. JjJ. j~l ,l ill. A A 64 '$7 R8 * er. ************************ . ~ **********~,~**~;~t**;· ********************************************************** 4,9'9'9 $ ORR A A A C A A A A ,., ~', . $ ,,,g VRON SA ~RU2'~'~- ~ ' ~'~G' *'"r' ':~ A~ A~M ~ ~'3 2~"~ '$' 6,6' .'~9 N~ ¢O~R1 1: · 4'0 I7,4 98 6.~ 16,6' 42 ~ ,6 I66 :tO6 ~,' ,3 ,. 8 i i3'~6 C' A B A A B. C B A: A A C C A A C B C A A A B A A B ~'6~.:$? ~! ~ORR$ 3'4 5~6 NO 5~,7.~ 156 , 8 C A C A B A A A C B A A A C A C ********************************************** ,,,0~ , .94 2'8 7 B '$' ..94,i'.,i ~ 165 '3 B I. 5,~ ,',94,2~'" ' 16' ?' "C 64 A 28i , N~ CO~ ~" ~' A ***************************************************************************************** 199 :~ 1aa.. ~ORR 'O~R 164 1,66' B. B B A A A C e, C B A 'A. A A A A A A A A A B C C. A A C C B **************************************************************************************** DiP ~.. :'540S.~, 2 2~. gO 47 ~47 N C ,0ORR 2'0 li,'t 20,0 NO CORR 1154 i '5: 2 i64 6' 4 .. ..4 i ~E'PTH DZP D~P DE'V D~V D]AM' DZ~M Q i, * A~M A~M :*'3~,, 2*4 548 548 54! 549 .4 200 ,4 CORR A44 q4 C C B B A B A A A A A ¢ A A B A A $ $. ,I i. A A. ~,i::~o.!1~ NO CO~R NO ~'ORR 163~ 165! 165 1,8' ** I2'5 i{,i'~. A 12,5 ! C:B I2'5 B 'A C. D: D: A ********************************** ***************************************** 563 85 I?,5 145 9,g' 166 13,6 564 85 i¢,:I 142 '9"~,~ I67 '13,4 564 85 28,8 1~9 '9,:::~,' 66 565{ $5 9,2 lm6 9',2~' 167 { 13,5 5653 84 6,1 210 ~,2' 168 i{,~ 5655 84 4,4 193 9,2: 168 ,4 13 5 56'61 84 iS,] 125 ~,;0 166 t{ 0 556 84 8,2 144 5~7' 84 6,~' 59 ' ~9' 5,6'8: 84 8,~, 1~6 I65 568' 84 i8,3' 204 '" { Ii 569 84 21.9 165 8.$ 167 5 I2 Si 94 11,0 I..?~ ~4 i~,o lm~ fi'Ill lllll{$$lll$1ll{l$1, ~l 1'67 140 149 117 OWR ,** 4,678'4700 4700'. 4800 4800W4900 4900~ 'SO00 ~ooo- ,5iOo~ 52oo '53o0. S400 240' 300 330 ~ 30 60 1. 2 1 2 2¸0 150 4 8 5 5 9 4 8 4 ? lO ,4 4 2 7 4?00. 4800 ¢800. 4900 4900. 5000 5000. 5100 $~00~ 5200 ~200. 5300 ~400,. $500- ~'600-* 5700 tv 300 1 2 ~0 ! 4 t 4 8 6 8 5 6 6 I6 ? '/ .'5 2 4 4 4 4679* 4700 4700" 4800 ,4800' 4900 4900. 5000 5100' 520,0 S2oo-s3oo 5300- 5400 ~400;' 5500 "$500" ~600 s~oo, ~7oo t20 150 8 210 240 5' 10 5, 8 2 5 10 ¢ 6 4 9 ~ 4 3 3 8 1. 3 2 4' 4 7 3 3O I, 4678- 4700 4700' 4800 4800' 4900 4900"~000 ~,OOO-~ 5~00 ~t°o. ~2oo "~2oo~ ~oo ~Oo~. ~4oo Ssoo's~oo 2 2 1 ! 300 2 :33,0 r'! M. 3¸0. r2 ! 1 2 ~H~V'~ON T.~SA , ~RU.:2~2 SU~MARY.~' . , BOT?O. '8 tS*OCT-eS -' 2 ~'t~ ~ ~ ~. ~ CORPAN¥ t CH~VRO~ USA ~bb BRU23~ rZEhD ! BElUgA R~VER COUNTRY I usA RI, IN I 2 DA~,~ ~O~G~O ~ ~2 .OCT -,:SS R~REN~: t 5159 ORR, NO'~OR,~ NO CORR NO ~ORR NO 18.0 NO ~ORR C C C: C C : 4026,$0 NO ~ORR ,02~8,!'! NO CORR NO COLOR 40{4,63 NO ~O. RR 403,8,64 NO ~ORR ~.:~ 40.t6_.,,64 6,8 141 · 4040,65. 20,! I. R2: : ?., , NO ~ ORR '1 'I'. NO ~Olqlm ~" NO COtmR " i!{i,,~ i ~ i'],,,W '*' 19., 4 i · . 8 10,:1 196 · 9 2~t ,2 · 9 N,O tO. mR · 0 NO CORa 408 {, · 4'096; 4 NO ~OWR · 4099; 5 NO CORR ,l 4I~90, 5 4,5 332 ,~ 4tO~,, 6 Nn CORR~ '$ 4104.1~7 20.7 · ********************* DEPTH DIP D~P D,EV DEV i2,5 12,5 ..~.,..~.~, I,, It:~ '2'5 IW5 12,7 12,5 "'"I::! i!i:[' , ~,, $, '~. : i!~ B A A A A DIP DIP A~. ************************* .$ * * .$ $ ,. 418 419 4~0! * 4 $ 4 :lS"N~ ~'ORR :j6 N~ 8 NO CORE $' NO eORR N'~ ORR l&, N~ O~R ~, ~ORR 9 NO ORR C , IS S D D i'','' *' ,t.~ ~ ,, t2i,$ A ~ I1::~'c , ************************************ 2, S9 o'~ ~? 5 6 ,4 ,4 1 B A A B B B A A A A A A B $ $ ,$ $ $ ~ DEPT~ D~P D~~ ~V DEV' D'~AM 44, '~' 44: 44,6' .$ ORR ORR ORR NO ~ORR 12,0 69 I N CO R ! 4 ~6.~ 49 4~ ,5 5 ' P'A: 6~r" ******************************************************************* ********************************************* ************************************ 1,46 4? 1,46 ii. A 8, A B A C A O B' A A B B D B, 148 ,6 B D B 'i ************************************************************************************** 4000* 4100 4100',4200 ,4300- 4400 4400' 4500 4500-4600 4600" 47'00 4700' 47t5 300 330 1~ :30 60 . :tO tO 2 4 2' 1 2 2 t9,46- 4000 4000" 41;00 4t0,0' 4200 a2:00" 4300 4300" 4400 4400" 4500 .45.0:0- 4600 4~0',0- 4700 4?00- 4715 ! ! 2 $0 1:~o ts,o, 4 4 210 ~9'46~ 4000 4000' 4100 4100- 4200 4200. 4300 4300- 4400 440'0- 4500 4500-4600 4600- 4700 ¢?00-4715 30 60 E 1~0 1.50 $ 210 240 W ]00 ]30 1. 2 2 2 3 6 ! 2~ 10 2 1 1 10 4 2 I 3o 19,16~~ 4000 4000., 4100 4t00-4200 4200`, 4300 4300"' 4400 4400", 4500 45P0'' 4600 4000," 4700 120 150 $ 210 240 7 6 I 10 ~ 5 I 8 10 5 2' 9 16 2 ~7' 10 2 i 4 2 12 13' 2 2 · ,DE~?H * D~P D~P ~ DEV D'EV D~A~ D[A~ *' OUA~ ***************************************************************************** · , '* ?OP , · ' 3946,~33 56.S 318,, 40 ! 1~8,~ 13,,,0 ~2,9 D * ********************************************************************************* EN~ ~F L~F ,, VERS~OlU 007,g05 OATE OR~G~N~ CONTTNUAT~ON # COmMeNTS :~CM~I,,I~ERG~E W~E~ SERVICES PROpRiETARY F T, E~D ERVTC~ ~A~E A?E :~5/10/~1 ?AP~ NAM~ CONTTNUA?ZON # :01 BREV~OU$ TAPB ~O~M~NT~ ~CH~UMF~GRR ~[, $~V~CE$ P~OPRI~?AR¥ ~T~tD PILE NAM~ I'~CT ,001 VERSTON # : DATE : ~AXIMUM T,,ENGTH : 1024 rILE TYP~ : PR~V~Otl$ FTBE ~NEM CONTENTS CN : CHEVRON USA ~NC WN I BEt! ~N : BELUGA R~V~R RANGI lOW TOWN~ SECT: 9 COl.)N: KENA! STAT: AbASKA MNFM CONTENTS 000 000 015 065 000 000 009 000 000 012 0~5 000 000 003 065 000 000 003 065 oooooo 000000 000 000 006 06 000 000 003 065 000 000 001 0,65 T,,VO 0IO,HO~ VEr~I~'ZCA?ZON LISTING A~$KA COMPUTING C~'NTE~ C~MPANY = CHEVRON U$~ WELL = RRU F)ELD = BEi..,UGA RIVER COUNTY = KENA! AI.,ASK~ ~ jOB NUMBEP, AT ,ACC= 70891 CA,$).N~ = 20,000" m )94' C~$~N~ =9~6~5"' ~ 6680' AZIMUTH OF' PLANNED VE~TIC~ P'LANE~ 147,27 *********** * DEFINXTIONSI * GDEP~ ~¥RO DEPTH * VDEP= ?RUE V~RTICAL DEPTH * ~$DRa NORTH OR SOUTH DEPARTURE , ~WDR= ERST OR WEST DEPARTURE * DGL =' DO~ LEO (CURVATURE OF THE *_DATA FORMAT RECORD .** N?RY ~LOCKS TYPE SIZE REPR CODE ENTRY 2 I 66' 0 4 I 66 255 8 4 73 60 16 I 66 0 1 6~ 0 DRTU'M SPeCiFiCaTION BbOCKS MNE~ $~RVlCE SERVICE UNiT APl ~P! APl ~PI FIbE SIZE ID ORDER # bOG TYP~ CbA$8 ~OD NO. O0 000 O0 DEPT rT. 0 0 4 ~DEP 6C? FT 9g 000 O0 0 0 4 YDEP ~CT FT O0 000 O0 0 0 4 NbAZ GCT PEG' O0 000 O0 0 0 DEVI ~CW DEG g9 620 tl 0 0 4 NSDR gCT FT O0 000 O0 0 0 4 ~WDR OCT WT O0 ~00 O0 0 0 4 DGL GCT r~ O0 000 O0 0 0 4 SPb. REPR 6,8 00000000'0'00000 00000000'000,000 68 O000000'PO'O0'O00 O000000OO00000 68 0000000000'000'0 68 00000000000000 68 00000000000000 68 00000000'000000 [.VP OIO.HO~ VERIFICATION 5TSTING PAGE' 4 DEpT OEVI BEPT nEVI DEr! BEV! DEPT DEPT DEVI DEVi DEPT DEV! DEPT DEV! B. EPT 65536 O0 GDEP oo,.oooo 0.2019 6570~,,0000 ,6122 'NS~R 65800,0000 GDEP 26,5707 65900,0 0 ~6000,0000 66'i00,0000 .28,~113 NSDR 66~00. 0 l].~O 0 GDEP 9?4 o ,:oooo 0901 ~!SDR 66]96.5000 GDEP 0~79ql 26,4000 VDEP 0o0000 EWDR 18~.~999 VDEP .3210 EWDR ,.~997 VDEP 72~,4714 ~DR' 1573,0994 VD£P -188,4087 EWDR 2511.4990 VD~ 't]' .661! ~WDR .4357,~9~9 VDEP -1595,.6235 EWDR · 525~.39'84 VDEP -i88 ,.8176 EWDR -2 1 ,8374 ~DR 6594 8477 VD~P -2020:2046 ~DR 26,4000 0 .00'00 388 DGL , ~ DGL. ,ts 2, {6 ~.,,A 2873,54'00 1047,.~596 3609.3823 H~AZ 1 ~ 8 ?., 9 4 53 D.GL 4444, 5306'~627 1415, ,4116 DG.L 5771,5186 FIt,~ NAME ~GC~ ,001 TC~ ~AXI~UM LENGTH : 1024 FILE TYP~ EOF ** TAP~ TR~XGER ** SERVICE NA~E :GCT BATE :85/10/21 ORIGIN ~0000 TAPE NAME :0891 CONTINUATION # :01 NEXT TaP~ NA~E { CONM~NT$ :SC~bUMBERG~R WELL SE~.VTCES PROmRIETARY FTELD TAPE 41'67 24~.2491 ,9266 8~R NA £ ~C~ OR~G~N REE~ NA~ . ~R ~EPTH ~01 COMMENTS LiS 'v' ~_ R l ~:.T. C ~ T l C N L.ZSTZNG L~i~I!Ii'i) ii, ii! [NI LVP OlO.d02 VERIFICATION ti.STINg m,~GE 1 SERVICE N~'& M E : £'DIT D.,~ T E :85/11/13 ORIGIN : REEL N~IMf : CONTINU~TION ~ :01 PREVIOUS ~EEL : COMMENTS ; ..'<-. ::=. T A P E H E ~ D 'E R SERVzC_ NAME DAT= :85/11/13 ORIGIN :FS1A TAPE, NAME CONTINUATION ~R EV IrJ, US TAPE CO~IIqENTS : : E D I T FILE NAME :EDIT .00! SE'RVICE N,~;4E VERSZON m MAXIMUM LENGTH FILE TYPE : °REV!OUS FILE );~,"'-,- iNFORM&TiON 024 R ,.r. COR DS , .... CONTENTS UNiT TYPE CATE SiZE CODE ;;:;:': COMM:'-'NTS ....... -,-,.,- LVP 019 eO2 V=~I:ICATiCN LIST.ING -,- .aLASKA G~3NPuT.ING CENTER ~:-. COMPANY = CHEVRON USA ~LL = ~RU 232 - 9 =I:LD, = g,~LUGA R!V'~R_ STA'TE = ALASKA JOB NUHGER A.T ACC: 70339 RUN ~ON= D,~TE LG.,gG~D" 22 LD?: HOi~ARS SOLA. M CASING = 20,.000 ~ 394.0' TY~E FLUID = GEL GELLEX DENSITY = 9.3 L3/S PH = 7,0 FLUID LOSS = I,I.7 C3 SIZE = 1Z.25" TO 3950.0' RH = 8.010 ~ 78.0 ~M= = &.480 5 80.0 RNC = 4,.370 S 80.0 OF R~ AT BHT : 5.383 ~ 86.0 TOP LGG INTERVAL iS 1,000 ~E;:T D T:D PR~L!EMNITH SOFTW,AR~:-i..,: LVP 0!0.I'i02 V~RI~iC,~Tit}N LTSTiN,~ PaG',;: 3 LOGS INCLUDEO WI'TH THIS ~AGNE'T~C TAPE: iN~UCTitDN SPH~R~CALLY ~,D.~U.~ .... O LOG (DZL) ~',~ ZLA'BLE: 3930.0' T OMPENSATED LOG (BHC) &VA.IL&BLE: 3938.0' TO !000.3' ;:-' S CH LU MiT, E R G E R ~:~ ',' ,~LASKA COMPUTZN .r.,' :", .<: .'-k :7 ;:: ~-' ;:: ;;: -I: ~;-* ~.,: :'= -.": ;;: :': ~': .~': -.';.'. ;'~. <: ;:.: ...... ;:: ................ "' ...... , ~, , . , , ..................... ,- COMPANY = CHEVRON WELL = 8RU 23:? - :ZELD = BELUGA RIVER COUNTY = ST,ATE = ALASKA JOB NUMBER ~T ~CC: 70e19 RUN ~2~ D~TE LDP: HOWARD CASING 'TYPE FLUID DENSITY VISCOSITY r=-LUI 0 LOSS = 13.373" ,~ 39:35..0' - ~!,IT SIZ'£ = 12.5" 'TO 7992.0' : ?~,LY PLUS-K : 10.0 Li~/G RM = .169 i~ 67.0 = 52.0 S R~qF : .124 ~. 53.0 DF = 7.5. R,MC : .26'7 ~, 67.0 DF = 7,5 '53 RM AT BHT :: ,.i03 E1 114.: OF ELECTRONIC SPLICE ON DUAL LATERiLOG DUE POW:ER SURGE @ 59t0.0' DUE TO HOLE DEVIATION AND I2.:25 INC" ~n H B~REH:OLE~ MICRDLOG PAD DOES NGT M&KE CI]NTACT WIT~ THE FSRMATi~N ,~BOVE 5800.0' DUE T3 CA,LI.PRX L~='GGG;.,:.D ,AT DI'F-FERENT SAMPLING RATE~ THE DATA IS DZSPLAYEO IN ~ SE?,&RATE IL:. LVP OlO.HOZ V2RIF-iCATION LISTING PASE- 5 LOGS ~,'rNCLUD~D_ WITH THIS MAGN=_TZC 3932.0' 3938.0' 3900.0' TAPE: ;;: ¢,.' ...... D&TA FORMAT ENTRY 5LOCKS RECOR"' ...... TYP'E SIZE ..... NTRY 2 1 ,65 0 8 a 73 50 '9 ~ 65 .lin u 1 56 0 DATUM SPECIFiCATZDN MNEM SERVICE , ~V~- ID CROER OEPT SFLU DiL ILM DIL ILO OIL SP OIL ~iL SP BHC DT 3HC GR 6HC RNRA LOT 8LDCKS UNIT API API AP1 AP1 FiL~ SI.ZE LSG TYP~ CL~S.S MOD NO. FT O0 000 O0 0 0 4 I]dMM O0 220 Ol 0 0 4 OHMM O0 120 44 0 0 6 QHMM O0 120 ~6 0 0 4 MV O0 0!0 Ol 0 0 ~ GAPi O0 310 O1 0 0 4 MV O0 010 01 0 O 4 US/= 30 520 80 0 0 ~ GAP! 00: 310 Oi 0 0 4 O0 000 O0 O 0 4 SPL REPR oROCES. S CODE (OCTAL) i 6B OOO00000030OO0 i 68 O0000000000OO0 I 6~ 00000000000000 1 68 O000OOOOO00000 1 6~ OOOO000000000:O 1 58 00000000000000 I 68 DO000000000000 I 58 O000000000OO00 1 68 00000000000000 1 68 O0000000OOOOO0 [V'P OiO.HO2 VERIFiC~ATION LISTZNS PAGE 6 t-' CNL LOT NCNL LDT NRA'T LDT NDHZ LOT CAt ! LOT D=F LOT QLS LDT QSS LDT RHU~B LDT 3RHO LDT GR LDT '5 R D L L CAtS DLL LtD DLL tLS DLL SP DLL MS,=L DLL CPS O0 330 30 0 CPS O0 330 31 O0 420 O1 0 PU O0 990 O0 IN O0 280 Ol 0 O0 358 ,~1 0 O0 000 O0 0 O0 000 O0 0 G/C3 O0 350 02 0 G/C3 O0 356 Ol 0 Ga~I O0 310 O1 SA.mi O0 3!0 O1 0 i N 0 0 000 00 0 2'4 ,~M O0 220 O M M M 00 220 09 0 t,~ V 00 0 i 0 O i GHMM O0 270 04 0 ...... DATA OEPT SP G R NR~,T tLS O':PT SP GR NR,&T QLS GR tLS SP NRaT QLS GR tLS Of.PT SP G R NRAT ,~ L S G R tLS CEPT 8014.0000 S~LU -999.2500 JR -999.2500 RNR~ -9'99..25 O0 NPHI -99~ ~:00 '~'SS 1435.5217 S~ 3000.000P.., .qF~ U_ -999.2500 GR 7~.5098 RNRA -999.2500 NPtti -999.2500 ~SS -'999.2500 GR 6.6801 Sm 7900.0000 SFLU -999.2500 GR 90.3398 RN~.& 3.3811 NPHZ 0.009~ ~SS 83.4023 GR 10.339~ Sm 7800.0050 SFLU -999.2500 GR 74,2,Ia$ RNR~ 3.3~20 NPHI 0.00i$ 2SS 74.5893 GR 12.17~4 SP 7700.0000 SFLO -999.£500 -999,2500 -999,2500 '-999,2500 -999.2500 72.7773 -~)1.901'~ -99S.2500 -999.2500 -9'99.2500 -999.2500 -999.2500 72.7773 -21.9170 -999.2500 -999,2500 3.4612 36.865.2 -0.0122 76.5998 -27.4482 -999. 2500 -999,2500 3.4385 36.1,316 O, 006~ 74,1523 -24. 4326 ILM SP FCNL C AL 'I RHO3 CAtS MS~L I LM Se FCNL CALl CALS M S F t iLM SP FCNL CALI RH9~, rALS MSF--L SP FCNL CALl RH,~j3 CAtS MSFL 0 a t 0 4 1 0 4 I 0 a 1 0 4 1 0 a I 0 4 i 0 4 1 0 4 I 0 ,4 I 0 4 1 -999.2500 ILD -999.2500 OT -999.2500 NCNL -999.2~00 PEF -999.2,509 DRMC 2.4905 LtD 0,2,290 '-999.2500 ILO -21,9170 OT -999.2500 NCNL -999,2500 PSF -9'99.2500 ORHO 2.4905 LLD 0.2290 -999.2500 ILO -27,4482 DT 3.50,1406 NCNL 12.5176 PEF 2.424! ORHO 12.4395 LLO 4.8835 -'999.2500 iLO -24.3232 OT 372.8906 NCNL 12.4082 PSF 2.3~7 ORH'~ 1.2.5410 LLO ~.3375 -999.2500 ILO 68 00000000000000 oooooooooo 6868 OODO000000 O00OOOOO0000OO 68 ODO0000000000C, 68 OOO00000OO0000 68 O000OO00000OO0 68 OOOOOO00000000 68 OOO00000000000 ,58 O0000000OOOOO0 68 O00000OO000000 5,~ ODS00000000000 68 00000000000000 68 O000OO00OO0000 68 O00OOOO0000000 68 O0000000OO0000 68 O000000000OO00 -999.2500 -999.2500 -999.2500 -999.2500 -'999.2500 886.8411 -999.2500 101..~0.23 -999,2500 -999.2500 -999.2500 8,4120 -999.2500 89.5273 1383.5875 2.19807 --0,0137 13,9825 --999.2500 93.9023 1453,6875 3.5334 0,0146 15.9180 -999.2500 L~"~ i'11 ! i m i ] ~I~] ii,_] [~]I LVP 010.;~02 V~R!FiCAT!ON LiST'ING PAGE 7 SP GR NRA T QLS GR t L ,S D~PT SP GR NRAT QLS GR tLS DE'mT NR~T GR LL$ OEmT GR NRfiT QLS LLS OEPT SP GR NR~T QLS GR LLS gEPT SP NR~T QLS GR LLS OEPT SP 5 R NR~T QLS GR tLS -999.2500 GR 78.3,398 4.2468 NPHI 0.0103 ~SS 76,90.23 15,1i57 7600.0000 S:LU -999'2503 G~ 78.5898 RNa& 4.0769 NmHI -0.0!,17 OSS 74.7773 GR 9.7556 SP 7500.0000 S:LU -999.2500 GR 70.3398 RNR& 3.7131 NPH! -0.0161 QSS 75.0898 GR 7400.0000 SFLU -999.2500 GR 60.5055 RNa& 3-4436 NmHi -0.0015 Q,SS 58.6992 GR 11.4137 Sm 7300.0000 SFLU '-999.2,500 GR 70..~64~ RNR& 4.0532 NP~i -0.0575 QSS 68,0273 GR 9,2013 SP 7200.0000 SFLU -999.2~00 GR 70.0273 3.5096 0.0132 66,5273 9.C323 S? 7!00.0000 S,=td -9'99. 2300 GR ~0.9023 3.6264 N P m I -0.0093 "~SS 74,71~8 OR 10,9016 S0 -999,2500 SP ?.3667 FCNL ~2,6855 CALl -0.0145 RHO5 '75,6523 CALS -29.1982 MS=L -9'99.2~00 IL~,I -999.2500 SP 4.2703 =CNL 49.5117 CALl 73.0'898 CALS -32.3008 MS~L -999.2500 ILM -939.2500 SP ~ O~Z+~ r-~NL ~3,. 0664 CO, Li 0.0220 .R~O3 68. 6523. CALS -30.4639 MSSL -999.2500 'ILM .-9~9.2500 SP 3.5881 gCNL 38.23,2-4 CALl 0.0200 RH06 64'46~8 CALS -12,7246 MSFL - 99 '9 · 2 ..5= 0 O I t M -999.2500 SP 3.5'999 FCNL 49.4141 CALl - 13.0.1 i ,~ R H 0:3 71.7'773 C~ALS -22,4014 MSFL -999.2500 iLM -999,2500 SP 3. 9729 FCNL ~I ,0156 CALl 0,0146 RdO~: 6...9,8398 CALS -~ 0.~' ' ,., '~ .P iv~ S =~ L -999,2500 iLM -999,2500 S? 3.8479 mCNL 45,0195 C&LI 0,0146 ~HO5 74,214~ CAL$ -24, 19':~po. M$FL -29,1982 DT 263.8906 NCNL 12,5645 PE~ 2,3030 DRHO 12. 5645 LLD 10.5020 -999.2500 -32-1133 DT 2'42.9375 NCNL '12.'7207 2,2854 DR~O 12.6895 LLD 3,3010 -999.2500 ILD -30.5i07 DT 3-35.3'905 NCNL 12'22:85 PEF 2.3323 DRHS 12.~473 LLO 9.0332 -999.2500 ILO -11-5137 OT 359,6406 NCNL 9'~ ' PE 11.'o63 ; 2.3420 DRHO 12.I550 LLD 2.5,586 -999.2.500 !LD -20.6514 DT 24'7.9375 NCNL 12.3926 PEF 1,9874 DRHO 12.0020 LLD 3.8264 -99'9 2~0~ ILO -30.3,232 ST 376.8905 NCNL 12.6191 PE= 2.3772 ORHO 12,4941 LtD 5.387,5 -999.2500 iLO -.23.5420 JT 328.3905 NCNL 12.4082 P'EF 2.398'7 DR~C 12.3613 LLD 4.3253 88,9648 1261.68'75 2.8088 -0.0020 !8.3577 -999.2500 113.8395 1089.5875 Z.7659 0.0313 !1,2784 -999.2500 92.7148 1350.6875 2.93:7'7 J.0185 15.2048 '-999,2530 94.1523 .1379.6875 3.6'935 0,0347 14,9794 -999.2500 108.902,3 1090.6875 2.1819 -0.0073 12,0616 -999.2500 10'3,9648 1310,5875 3.0627 0,0005 '11,4881 -,ac,= 2500 ~, ~ ~ . - 99.3398 12,63.,5875 2.9924 0.0127 12,7102 LVP OlO,M02 VER.I:IC&TiON LISTING PAGE DEPT SP GR NRAT QLS GR LLS DEOT SP N R AT QLS GR LLS DE~T GR NRAT QLS GR LLS DEPT SP GR NRAT QLS GR LLS DEPT SP NR~T QLS GR LLS 9EPT SP Gq NR~T QLS GR LLS DEPT SP NRAT QLS 7000.0000 S~LU -999.2500 GR 71..~7773 RNRA 3.9045 NPHI -O.03JB QSS '74'7!48 GR 5.7893 SP 6'900,0000 SFLU -999,2500 GR 78,9023 RN'R.& 3,~749 NPHZ -0.0205 QSS 71,9648 GR 9,~210 S~ 5800,0000 SPLJ -999.2500 GR 71.8398 PNR& 3,7327 NPHI 0,0.254 QSS 65.5273 GR 11.5'779 SP 6700.0000 SFLo -999.2500 GR 65.8:398 RNRA 3,~Z60 NPHI -0.0205 QSS 72,33'98 GR 6500.0J00 SFLU · -999.2~00 GR 76.4023 RNRa 3,5002 NPH! -0 026'9 '~SS 73,0898 GR 7.9445 SP 5500,0000 SFLU -999,2500 Gq 71.059S RNRA 3,9905 NPHI -0.007~ ~SS 72,5273 GR 8,6~76 .SP 6400.0000 SFLU -999,2500 GR 71.954~ RNR.i 4,2273 NPHi -0.0,361 ',iSS -999.2500 iL"'1 '-999.2500 SP! 4.4539 FCNL 46.3379 CALl -0.0044 ~H08 71.5898 CA:LS -,34.0505 MSFL '-999,2500 -999,2500 SP a,146'7 38'7695 CALf O.,OZO0 RHJ8 65.5898 u LS -1~,,62'30 MS'=L -999.2500 ILM -999.2500 SP 4.0789 FCNL 43,.2:6~7 :CALl -O,.O04a R~06 74.7148 CALS -22,7295 MSFL -999.2500 ILM -9:99.2500 SP 3. 754~ 'FCNL 37.7441 CALl 0.00~9 ~03 67.!523 C.&LS -27..6201 MSmL -999.2500 iLM -999,2500 SP 3.7542 FCN~ 39,1113 'C~LI -0.0039 RMOB 66.7773 CALS -Bi.9170 MSFL -999.2300 -999.2500 SP 4.442i FCNL 4=~. 1445 r&LI -0.0107 84.4648 C~LS -32.7070 MSFL -9'99,2500 ILM -999.2300 SP ~.0~ ~ NL 52.4902 CALl 0.9103 RHOS -9~9.2500 ILO -33.42 58 ST 256.1405 NCNL 12 · 7207 P E F 2.3284 DRHO t2.2129 LLD 2.1292 -999.2500 ltd -14.380'9 :OT 305.1406 NCNL t2.1191 PEF 2.4221 DRHO 12.2207 LLD 2.7483 -999.2500 ILD -22'8232 D'T 287.6406 NCNL 12.6191 PEF 2,4338 DRHO 12.4'707 LLD 3.36~0 -999.2500 iLS -30-5264 DT 341.3905 NCNL 12.4052 PEF 2,39.28 DRHO 12,3145 LLD -999.2500 ILD -32.0820 DT 3,54.3906 NCNL 12.4082 PEF 2.3948 DRMO 12,3770 LLD 5,521~ -999.2500 ILO -32.4570 DT 28 B. 6406 NCN L 12.2988 PEF 2,3310 DRHC 1,2· 3 ., ~ 7 '9 L L O 4.4265 -999.2503 !LD -31.4795 DT 254.6875 NCNL 12.2520 PE~= 2.2014 DRHO -999,2500 103,:4023 1140,6875 ,3?4436 -0.0034 7.0124 -999.2500 94:'2773 1253,5875 3,5920 0,0449 15.0802 -999.2500 1:02.0898 1245.6875 21.9534 -0.0059 13.7034 '-999.2500 106,9023 1252.6875 2.9690 0.0034 13,2562 -999.2500 103.9023 1265.6875 3.0862 -0.00~4 11.2984 -999.2500 111.3398 1202.6875 2,7151 -0.0049 10 =284 -99'9.2500 112.7148 1018.8125 2.2600 0.0029 LV° OIO.H02 VERiFICATZ!3U LISTING LL£ L)EPT SP GR NR A'T ~L$ GR LLS '= p ~,E T SP GR NR&,T QLS GR LLS DEPT SP GR NR&T gLS L,_S DEPT NR~T QLS GR LLS me: PT S? GR N R ,~ T LLS S P GR NRAT GLS GR LLS '-' ~- PT 6.6.65,23 G R 6300,0000 SFLU -999. 2500 GR 4.1570 NPHZ -0.0229 QSS 65,2773 GR 10,3709 S~ 5200.0000 SFLU -999,2500 GR 60.9805 RNa& 4,2273 NPHi -0,003~ ~SS ~5,~023 GR $,o736 S~ 6100.0000 SFLU -999,2500 ~5.6680 6.3015 0,0083 ~SS 52,5055 GR 16.3932 SP 5000,0000 S~LU -999,2500 GR 58,8867 3,74~4 NPHI -0,0093 51.6680 GR 7.91~2 S° 5900.0000 SFLU -999.2500 GR 71.7773 RNR~ 3.8928 NPHI -0.0363 ~SS 56,&548 GR 5.8~39 S? -999.2500 GR 57.7617 3.30~9 NPHi 0,0-C. 63 ~'SS 5!,0430 GR 6,7103 SP 5 '7'0 O. 000 '''~,,, S ,=LU -'999 .ZSO0 GR 59. ~930 RNR,A 68.9648 CALS -3 '! . .5 B 2,5 M S ,: L -9~9.2500 ILM -999,2500 SP 3.5,323 FCNL ~! .1719 C~LI 66,3398, C.fiLS -26. 4639 MSFL -99'9.2500 ILM -999,Z500 SP 4,6453 FCNL 52,3926 CALl u.,O_.4 xHu6 62,5992 CALS -,35,7070 MSFL -999.2500 II_M -999-2500 S° 5..Z781 FCNL 53.8086 CALI -0.037,1 RHOB 48'7930 CALS -33.1133 MSFL '-999,2500 ILM -999. 2300 Sm 3.=,_~,~2n~:., ;CNL 42,2363 CALZ 0.0093 R~O3 63.3242 C~LS -30,3.~ 5'7 MS:L -999,2500 !LM -999.2500 SP 4. 2820 FCNL 45.1426 C.~LI -0,0005 RHCe, 54.6523 CALS -13.5449 MSFL -999.2500 ILM -999.2500 SP 3 . 6292 =C NL 35.5957 C,~LI -0.008~ 63.7617 CALS -21.55B9 MSFL -999. 2500 iLM -999.2500 SP 3.3733 F,S t,l L .,~)7 LLO 4.2976 -q99,2500 ILD -25'4639 DT 252.31.2.5 NCNL 12.2988 PEF 2.1877 DRHD 12.2363 LLD 5.8523 -999.2500 ILD ,-36-2,3:83 BT 259.8905 NCN'L 12.4'082 PEF , ~ 2..40~6 DRHO 1'2.3145 LLD 2.6331 -999.2500 ILO -32.8633 D'T 256.1406 NCNL 12-3613 PEF 1..?$10 DRHC 12-3301 LLD 2.9651 -999.2500 ILO -30,3857 DT 291.3906 NCNL 15,197,3 PEF 2.~045 DRHg 14.8926 LLD 2,3870 -99'9.2500 ILO -12.9824 DT 315.8906 NCNL 1:2.6191 PEF 2,2600 DRHD 12,4961 LLO 1.7i78 -999.2590 '-21.5989 OT a51.6~05 NCNL 12.298.5 PEF 2,25,73 12,3145 LLD -9'99,2500 ILD -20,6.570 DT 390,3906 NCNL 8.0656 -99'9.2500 111.65,!3 1135.5875 2.9651 0.0146 14,3157 -9~9.2500 113.8398 1207.6875 3,2834 -0.0010 7.9807 -99~,2500 125,9023 1230.6875 2,0940 -0.0195 23.5078 -999.2500 95,5273 i212.6875 4.55'93 0.0127 12.4992 -999,2500 11'7.0,273 1326.6675 2,8967 0.0103 9.1547 -999.2500 108.1523 1675.6875 2.7327 -0.0054 9.0580 -999,2500 1t0,~023 1337.5875 L'~ I'll! I i il iI~l[_! ['~ LVP NRAT '2 LS GR LLS DC. PT SP fi R A T QLS GR LLS DFOT SP GR NR A'T QLS GR LLS NRAT QLS GR LLS NRAT QLS GR LLS SP GR NRAT GR LLS OEmT NRAT GR LL$ OE~T OlO.P, O2 VE~ i=-'!C~ TiON 3.381! NPHI -0.0254 60.8242 5.165a S$ 5600.0!]00 SFLU -999.2500 GR 79.6523 RNRA -0.0285 ~SS 62.5t17 GR ~.~674 SP 5600.0000 SFLU -999.2500 G~ 61,0117 RNR,A 3.6095 NPHI -0.0200 QSS 5.7'969 S~ 5~00.0000 SFLU -999.2503 GR 39.6,580 RNR~ $.0046 NPHi -0.0.503 QSS 38.9t80 GR 22.8~14 SP 3300.0000 S~LU -999.2500 GR 75.7773 RNRA 4.2820 NmHI -0.0i~2 QS5 66.~39B GR ~.598i S° 5200.0000 SFLtJ -999.2500 GR 56.'71~8 RNRA 3.9377 NPHI -0.0137 QSS 70.7773 GR 5.~823 SP 5100.0000 SFLU -999.2500 JR 62.5~30 RNRA 3. 912~ NPH! "~ 33 1 ~2 'S S 61.5~30 'GA 7,445t SP 5000.OCO0 SFLu LISTING .,36.9,1~1 C,ALi 0.0288 RH35 60,32~2 gALS -19.9170 MSFL -999. ='300 ILM -9~?o2500 SP 3.8Sll FCNL 54,783.2: CALl 0.0034 RHLq5 74.0273 gALS -27.7295 MSFL -999. ?_500 .ILM -999.2500 S 4.278! FCNL ~0,.8203 CA. LI 0,,0093 RHO3 66. 7148 CAI. S -?_2.6826 MSFL -999.2500 iLM -'999.2500 SP 5.2585 $CNL 66. 0645 CALl -0o0z~64 39.5117 gALS -27 !9¢~,'~ . .~. 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999.25 O0 ,2SS -999. 2500 GR '-999.,~503 SP 2800.,OOOO SPLU 55,074.2 GR -999,2503 NPni -999.2500 QSS -999.2500 GR 2700.0000 SPLU 54.7305 -999.2500 NPHi -999,2500 OSS -999.2500 -999.2500 2500.0000 SFLU 56.6055 GR 41.9805 RNR.~ -999.2500 NP~i -999.2~00 -999,2~00 GR -999.2500 SP 2500,0030 SFLu 49,9805 3R 39,6580 RNR& -999,2503 NPHi -999.2500 QSS -999,2500 GR -999.2500 SP 2400,0000 SFtU 53,4492 GR 40,636'7 RNR.& -999,2500 NPHI -999,2~00 SSS -999,2500 GR · -"999.2500 SP 2300.0003 '$~LU '-999.2500 -999.2500 -999.2500 -999.2500 22.9380 44.2305 -999.2500 -999.2500 -;9~.,~00 999,2500 -999.25O0 26.7080 42.6367 -9~9.2500 -999'2500 -999.2500 -999.2500 -999.2500 ;2 B,. 08 30 40.1055 - 9'.~ 9. 2500 -999,.23 O0 -999. 2300 -999.2500 -999. 2500 £5.5~30 41,9805 -999,2500 -999.2300 -999.2500 -999,25.00 31.7705 39.6680 -9~'9.2500 -999.2500 -999.2500 -999,2500 26.3543 40.6367 -99g.2~00 -999.2500 -9'99.2500 -999,2500 -999.2500 i 5.317~ CALI RHDB C~LS MSFL iLM SP FCNL CALl R~3.3 CALS MS=L ILM SP FCNL CAL ! RHi.' 3 CA L .S MSFL I~f.1 SP FCNL CALI RH03 CALS MSFL ILM Sm ~CNL CALI CALS ~SFL iLM SP ~CNL CALi RH05 CALS MS~L ILM SP FCNL CALi CALS MSFL -999.2500 DRHO '-999.2500 LLD -999.2500 24.2236 ILD 55.4180 DT -999.2500 NCNL 999.2500 PEF -999,2500 DR~O -999.2500 LLD -999.2500 ~7.3018 iLO 55'0742 OT -999.2500 NCNL -999. 2500 PEF -999.2503 DR~C -999.2.500 LLD -9'99.2500 28.1611 iLD 54.7305 DT -999.2500 NCNL -999.2,500 PEF -999. 2500 DR'HO -999.2500 LLD -999.2500 23.2080 ILD 56.6055 DT -999.2~00 NCNL -999.2500 PEF -99'9.2500 OR~g -999.2500 LLD -999.2500 31.8799 IL3 ,49.9805 DT -999.2500 NCNL -999.2500 PEF -999.2500 DRHD -9'99,2500 LLD -999,2500 27,6299 ILD 53,g492 DT -999,2500 NCNL -999,2500 PEF -999.2500 DRH3 -999,2500 LLD -999.2500 23.4111 iLD -999.2500 -999.2300 -999.2500 26.9424 13'7,8125 '-999,2500 -999,2500 -999,2500 '-999,2500 31.8018 137.6875 -999.2500 -999.2500 -999.2500 -999,2500 3!.95~0 137.8125 -999.2500 -999.2500 -9'99.2500 -999.2500 2~.5518 -999,2500 -999..2500 -999.2500 -999,2500 36.6055 138,8125 -999,2500 -9'99,2500 -999,2500 -999,2500 33.1055 142.8125 -999,2500 --999,2500 -999,2500 --9'99,2500 25.1924 LVP 010.Ht3~_ V=R=FZCATZaN~- .~ -, LISTiNS o;~E~- '~5- SP GR NRAT QLS GR LLS Sm NRAT LLS SP GR NR AT QLS LLS r',., '= p T SP GR NR.~ T WLS GR LLS DE.mT SP GR NR 4T ~:~LS GR LLS ,~ F: p T SP NR~T QLS GR LLS DEPT SP Gq NR,&T ,-~ GR LLS 69,46~8 GR 47,8555 -999,2500 NPHZ .-999.. 2500 -999.2500 GR -299.2500 2200.0000 SFLU 53.7305 GR 35.4505 RNRA -99'9.2'500 NPHZ -999,.2500 QSS -999..2500 GR -9'99.2530 Sm 2100.0000 SFLU 50.~180 GR 39.~!80 RNRA -999.2500 NPHI -999.2500 QSS -999.,2500 GR -999.2500 Sm £000o0000 S,~LU -52.5680 Gq 38.4805 RNRA -999.,2500 NPHI -999.2500 QSS -999..2500 GR -999.2500 Sm 1900.0000 SFLd 50.3242 42.0117 -999.2500 NPHZ -999.2500 QSS -999.2500 GR -99'9.2500 S? 1803.0000 S:LU 67.0898 GR 50.~242 RNRA -999.2500 NPHi -999.2500 QSS -999.~,500 G~ -999.2500 SP i700.0000 SFLU 38..3857 ,GR 49.9150 -999.2500 NPHI -999.2500 -999.2500 GR -999.250? 4'7.8555 SP -99'9. ?500 FCNL -999. 2500 CALI -999. 2500 RHO~3 -9~9.2500 CALS -999.2500 MSFL 34.2930 ILM 35.4805 S? -99q.2500 FCNL -999.2500 CALZ -9~9.2500 RH08 -999.2500 C~LS -999.2500 MSFL 33,1367 iLM 39,4180 SP -999.2500 FCNL -999.Z,500 CAL! -999,2500 RH05 -999,2500 CALS -999,2500 MSFL 35.2930 ILH 38.48:05 SP -999.2500 FCNL -999. 2500 CALl -992.2:500 RH,3!B '-999.25 O0 CALS -999.2500 MSFL 3t,9805 ILM 42,0117 :SP -999,2500 FCNL -999,2500 CaLl -999.2500 RH23 -999.2500 CALS -999.2500 MSFL 1,5.~ ~770 ILM 50.5242 SP -999.2-500 FCNL -999.2500 CALI -999,2500 RdS3 -999.2500 CALS -999.2500 MSFL 3~ 5!~7 49.9180 SP -999.2500 FCNL -999.2500 CALi -999.2500 ~H~'' -999.2500 CALS -99a.2500 ~SFL 69.4648 DT -999.2500 NCNL -999.2500 P8= -999.2500 DRHD -999.2500 LLO -999.2500 55.,Ib80 iLO -53,730'5 D'T -999,2500 NCNL -999,2500 PEF -999.2500 DRH] -999.2:500 LLD -999,2500 34.5580 !LD 50,4180 DT -9'99.2500 NCNL -999.2500 PEF -999,2500 OReO '-999,2500 LLD -999,2500 35.2930 ILO 52.6680 DT -999. 2500 NCNL -99:9'2500 PEF -999.2500 9RH~ '-99:9, 2500 LLO -999.2'500 33.6357 ILO 50.3242 OT -99'9.2-500 NCNL -999.2500 PEF -999.2500 DRHO -999.2500 LLO -999.2500 I:.,. 9082 ILD 57.0898 DT -999.2500 NCNL -999.2500 PEF - 999.2.500 D'RHO -9'99,2500 LLD -999.2'500 31.5,299 iLD 38.3867 OT -999.2500 NCNL -999.2500 PSF -999.2500 DRHZ -999.2500 LLD -999.2503 130:.4375 -999.2503 -9'99.250:0 -999.2500 -999.2500 43.9805 141.1875 -999,2500 -999.2500 -9'99,.2500 -999,'2500 44.1055 130.8125 -999.2503 -999.2500 -999.2500 -999.2500 46.0742 146.3125 -999,2500 -999.2500 -999.2500 -999.2500 44,19'92 !46,.8125 -999.2500 -999.2500 -999.2500 -999.2500 18.5049 143.55o,5~ -999.2500 -9'99.2.500 -999.2-500 -99'9.2500 38,5357 146.5625 -999.2500 -999,2500 -9'99.2500 -999.2-500 L'I'"~ I'11 ! I i il ii:-] i[~ [qil~ LVm OIO.HJ2 VERIFICATION LISTING OAGE 16 D~PT SP NRAT QLS LLS DE,UT SP NRAT QL S LLS OEPT ,~ - NR,~T QLS GR LLS 3EPT SP GR NRAT QLS GR LLS SP NRAT QLS LLS DEPT SP '3 R NRAT ,~LS L~$ GR NRAT QLS lSO0.OOO0 S:LU 44.2517 GR ~0.7930 RNRA -'999.2500 NP~I -999,.2500 QSS -999,2~00 GR -999.25~0 Sm 1500.0000 S~LU 4'9,9605 GR 38.386'7 RNRA -999,2500 NPHI -999.,2~00 QSS -999,2500 GR -999.2500 SP 1400.0000 SFLU 50,6055 GR 42,07a2 -999,2500 NPHi -9'99.2500 ~SS -999,2500 GR -999,2500 SP 1300.0000 SF.LJ 55.0,430 GR 37,1680 RNR.A -999.2500 NPH! -999,2500 GR -999.2~00 S~ 1200.0000 SFLU 39,7930 GR 32.8555 RNRA -999,2500 NPHI -999.2500 DSS -999,2500 GR -999,2500 SP llO0.OOOO SFLU 3~.2305 GR 40.i05~ RNRA -999.2500 NPHI -9'99.2~00 QSS -999.2500 GR -999.2500 SP lO00.O000 SFLU 22.5049 GR 43.~492 RNR.A -999.2500 NPHi -999.2~00 .2SS 68.5898 iLM ~0.7930 SP -999.2500 FCNL -999.2500 CALl -999.2500 RHD5 -999,2'500 C~L$ -999,2500 MSFL 82,5523 ILM 38,3857 SP -99'9,2500 FCNL -999,2500 CAL'I -9'99.2500 2HOB -999,2500 C&LS -999.2500 MS=L '125,7148 ILM 42,0742 -'999.2500 FCNL -999,2500 CALI -999,2500 C~LS -939..2500 MSFL 140.4375 I.LM 37,1680 SP -999.2500 FCNL -999.2500 CALl -99~,2500 -999,2500 CALS -9;~9.2500 MSFL 134.0625 ILN 32.8555 SP -999.2500 FCNL -999.2500 CALl -'9~9,2500 RH~B -999,2500 CALS -9'9'9,2500 MSFL 100,6323 iLM 40.1055 SP -'99'9.2530 FCNL -999.2500 CALl -999,2500 ~HO~ -9~9,2~00 CAL$ -999,2500 MS=L 42.7930 ILM 43,9492 SP -9'99.2500 FCNL -999.2500 CALl -999.2500 RH25 54. 2617 ILO 44,261 7 DT -999.2500 NCNL -999,2500 PEF -999,2:500 DRH!] -999,2500 LLD -999.2500 5i,1~55 ILD 49,9805 DT -999.2500 NCNL -999,2500 PEF -999,2.500 DRHO -,99,z500 'LLD -999.2500 73,5273 ILO 50,60:55 DT -999,2500 NCNL -999,2500 PEF -999.2,500 DRHO -999.2500 LLD -999.2500 7'7.4023 ILO 55.0~30 DT -999.2,500 NCNL -999.2500 PEF -999.2500 DRHC -999.2500 LLD '-999,.2:~00 82.9023 ItC, 39.7930 DT -999.2500 NCNL -9'99.2500 PEF -999,2500 DRH~ -999,2500 LLO -999.2500 51,7.517 35.2305 gT -999,2500 NCNL -999,2500 OEF -99'9,2500 -999.2500 LLD -9'99.2500 3'9.23 O 5 I LD 22. 5049 DT -999.2500 NCNL - 999. 25 O0 P~.:F -999. 2500 ORHO 103,5273 131.9375 -999,2500 -999,2500 -'999.2500 -999.2500 125,9023 137.5625 -999,2500 -999,2500 -999,2500 -999,2500 194.9375 125.0273 -999.2500 -999.2500 -999.2500 -999.2500 Z03.~i25 136.6875 -999.2500 -'999,2500 -999,2500 -999.2500 224,1B'75 130,8125 -999.2500 -99:~.2500 -99'9.!500 -999,2500 133,3125 142,4375 -999,£500 -999,2500 -999,2500 .-999,2500 5~.g645 t35,0625 -999,2500 -999,2500 -999,2500 LV° OiO.HOZ VER!=ZCATZ3N LISTING D&GE 17 GR LLS DEOT .S P GR NR A'T CLS G R LLS O~OT SP SR NRAT QLS GR LLS DEOT SP GR NR'~T QLS GR LLS SP GR NRA T ..~, L S SR LLS D~PT SP GR NR~T LLS D~PT SP NRAT GR JEPT SP -999 ~-00 SP 900,0000 S=LU 2~,2393 GR -999,2500 RNR,& -999,2.500 NPHI -999,2500 QSS -'999,2500 G~ -999.2~00 SP 800,.0000 SCLU 20.3799 G~ -999.2500 NP, HZ -°99. .~SnO~ ~SS -999,2500 S? '700.0000 S~LU 28.5830 GR -999.2500 RNRq -999.2500 NPHZ -999.2500 ~SS -999.2500 GR -999.2500 SP 600.0000 SFLU 23.2080 GR -999.2503 RNRA '-99'9.2~00 NPnZ -999.2500 ~SS -999.2500 G~ -999.2500 SP 5"0~ .~nOOO SSLJ -999,2505 RNRA -99'9.2500 NPHI -999.2500 ~SS -999.2500 SR -999,2500 Sm ~.O0,OOOO SFLJ 32,1680 GR -9'99.2500 R,h R -999.2500 NPHI -999,2500 GR -999. Z 500 SP 359,5000 S~LU 71 3~98 GR -999.2~00 RNR~ -999,2500 CALS -999,2500 MSFL 105.90'23 ILM 41.5,117 SP -999.2503 =CNL -999.2500 CALI -999,2500 RH32 -999,£500 CALS -9~9.2500 MSFL 131,1575 39,1055 SP -9'g9.25 O0 =CNL -999. 2500 CALl -9'39.2500 R',ri S B -999..2'500 CALS -999,2500 MSFL 158,91.25 ILM 38,0742 SP -999.2500 FCNL -999,2500 CALI -999.2500 RH03 -999,2500 CALS -999.2500 MS:L 52.9i80 iLM ~?.B555 SP -999.2500 FCNL -999.2500 C&LI -999.2500 RHO~ -999.2500 CaL,S -999.2500 MSFL ~3,~*'~x~ ILN~ ~2.82~2 SP -9'99.2500 FCNL -9'99.2500 CALi -999.2B00 RH'36 -999.2~00 CAL$ -999.2~00 MS=L 28.3330 !LM 35.4130 S? -999.3500 FCNL -999.2~00 CALI -999.2500 RH2B -999,2500 CALS -999,2500 MSFL n 759~ TLM 25.6611 SP -999.2.500 =CNL -999.2500 LLD -999.2500 71.27'73 ILD -999.2500 DT -999.2500 NCNL -999,2500 PEF -999.2500 DRHD -999.2500 LLD -999.2500 55.5898 iLD -999-2500 DT -999.2'500 NCNL -999.2500 PEF -999.2500 DRHC -999.2500 LLD .-999.2500 9,2.9023 ILD -9:99,2500 DT -999.2500 NCNL -999,250:0 PEF -999,2500 O~HO -9'99.2500 LLD -999.2500 39,8857 iLD -999,2500 DT -9'99.2500 NCNL '-999.2500 PEF -999.2500 DRHO -9'99,2500 LLD -~99.£500 21.7235 iLD -999.2300 DT -999.2500 NCNL -999.2500 PEF -999.2500 DRHO -999.2500 LLD -999.2~00 ZO· 1~99= ILD -999,2500 ST -999,2500 NCNL -999,2500 PEF -999.2500 DRH~ -999.2500 LLD -999.2530 1.0526 iLD -999.2500 DT -999.2500 NCNL -999,2500 179.8125 -999.2500 -999.2500 -999.2500 -999.2500 -99'9,2500 203.4375 -999.2500 -999.2500 -999.2500 -~99.2500 -999.2500 277.3906 -999,,2~00 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 30.8799 -999.2500 -9'99.2500 -999.2500 -'9'9'9.2500 -999.2500 50,2930 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -99 g. 25 O 0 LVP 010.H02 VERIFiC~Ti2N LiSTTN,,] P~GE i8 NRAT -999.2500 NPHI :?LS -999.2500 ,~SS GR -999.2500 GR LLS -999.2500 Sm -999.2500 -~99.2500 -:7'99.2500 C~LS MSFL .......-,,-,- ~!L~ TRAILER FIL'~ N,~ME :~DIT .OOl SERVICE NAME : VERSi,3N ~ : D~T E : MAXZHUM LENST~ : iOZ ~!L~ TYPE N~XT F~LE N~,~E ~ '=~'L.E NAM£.'~Oi'T SERVICE NAME VERSION ~ : ~TE : q,~X~MUM L~NGTH mIL~~ TYPE : PR~ViGUS FiL~ MNEM CON'TENTS CN : CHEVRON US~ WN : -3RU 232- 9 mN : BELUG~ RIVER RANG: 10W SECT: CL1UN: KENAi STAT: ALASK2 CTRY: US~ MN~M C3NT~NTS PRES: ...... D~TA F'ORH.~T RECORD ~NTRY -~LOCKS TYP6 2 4 SiZ= 1 i REPR CODE 55 66 73 -999.2500 PEP -999.2500 DRHO '-999.2500 LLD -999.2500 UNI'T TYPE CATE -999.2500 -999.2500 -999.250,0 SIZE CODE 000 000 012 0,55 000 000 012 0,55 OOO 000 012 065 000 000 004 065 000 000 004 055 OOO 300 OOZ 065 003 000 006 065 000 000 006 065 000 000 004 055 UNIT TYP~ C~TE SiZE CDD~ OOO 000 001 065 ENTRY 0 1 12 LVP OlOoH02 VERi:'iCA'TiCN L!STiN3 P~GE DATUM SPECIFICATION ~NEM SERVICE SERVICE ID URSE~ ~ SEPT RNRA LOT FCNL LOT NCNL LOT NRAT LOT NPHI LOT CALZ LOT PEF LOT ~LS LOT QSS LOT RHOS LST ORHO LOT GR LOT 9 16 0 fLOCKS UNTT_ API L3G 'TYPE FT O0 000 O0 000 CPS O0 330 CmS O0 330 O0 420 ?U 00 890 ?N '30 28n O0 358 '30 CO 000 G/C3 O0 350 G/C3 O0 356 G~l O0 310 ,56 66 .1 1 lq ! 0 hPl .&PI =iLE SiZE CLASS M,3D NO. 00 0 O ,+ 00 0 0 /--, 30 0 0 3"' 0 Ol 0 0 O0 0 0 4 0 ! 0 0 0 ! 0 0 00 0 0 4 00 0 0 4 O Z ,~ 0 4 O1 O 0 4 O1 ,: 0 4 SPt REPR CODE 1 68 1 68 1 68 i 68 i 6;3 I 68 1 68 1 63 :1 68 1 68 mROCESS (OCT.&L) 00000000000000 00000000000000 00000003000000 O00000000OO000 OOOOO000000000 00000000000000 00000000000000 00000000000000 0000O000000000 O00000OO000000 0000000000C000 OOOO0000000000 00000000000000 NRAT QLS GR OEPT NR~T ~LS GR SEPT NRAT QLS SR SEPT N R ~ T QLS GR NR,~T · ~L S GR DEPT NRAT ~LS GR DEmT 8001.7'998 3.8772 -0.0254 83.46&g 8000.2998 3.8772 -3.0254 83.4648 7900.2998 3.3264 ~7.4648 7000.299S 3.6350 -0.0225 67.8398 7700.299S 3.2520 -0.0039 88.2'773 7500.2993 4.3~34 -0.0~39 74.5273 7500. RN:R A NPH I r.~SS RNRA NP H I QSS RNR~ N P H 'i QSS RN NPH i .':.~ S S RNRA NPH.i ,QSS RN ~,A NPHI QS S 4.0984 56.7383 56.73'83 -0.0059 3.5295 35.S398 -0.0171 4. ,414,8 41. 5527 0.0181 3.5002 34.6191 0.0093 5. 223,~ 5 ,~. 58 '9 5 0.0322 3. ,5643 FCNL CALl RHS6 FC NL C,AL l R H,., '~ 3 FCNL C&LI RHOB F C'NL CALl RHO 5 FCNL RHO5 ?CNL C .A t I qHOS FCNL 39'9.1406 2.7151 I. 5~0 399.1406 2.7151 1.7520 38'7.3906 12.5098 2.4182 28~.3906 12.4082 2.4,1~3 364.6405 12.5191 2.5178 215.1875 12.5645 2.1155 343. 8905 NCNL PEF DRHO NCNL PE= 'O R H 0 N CN,L DRHO NCNL .~EF NC N L PEF DRHO NCNL PEF D Rri3 NCNL 163'5.687:5 ~ ~9 -0.0220 1635.6875 3.4514 -0. 02~0~ 136'7.6875 3.0764 -0.0161 1273.6875 3.5920 O. 01~7.,. 1276.6875 3.1604 0.0093 1129.6875 3.3533 0.0532 1260.6875 LV,° 010.~02 VEi~IF!C"~TiO'N L!STIN,$ P&GE 20 NP, AT QLS GR DEPT NR~T QLS NRAT ',_S DEPT NRAT QLS NR~T ~LS D'=pT,_ NRAT QLS O~LPT NR&T r',, NRAT CLS DEPT NR AT QLS ~R D'--mT NR~,T QL S DE~T NRAT QLS GR 3.7854 NPHZ -3.0.~5~ ~SS 78.5898 7400,2998 RNRA 3.6292 NPHr -0'0396 OSS 56.7617 '7300,2998 RNR& 3,4475 NPHt -0,0146 DSS 62,3555 7200.2998 RNRA 3.4983 NPHi -0.0010 ~SS 68.714~ 7,100.2990 RNRA &.0710 NPHZ 0.0107 QSS 73.2773 7000.2998 RNRA 3.5~19 NPml -0.0283 DSS 54 :273 8900..2998 3.2913 NPHI -0..0112 5'7.3398 6830.2998 3.2698 NPWI _o.on~8 ,.,.. 73,21~ 6700.2993 3.8i47 NPHZ 0.0103 PSS 60.7930 6500.2998 RNR& 3.~527 NP~I O.OtSS ~SS 5500.2993 RNR& 4.5984 NPHZ -0.035,5 ,~SS 85.9023 44.4336 -0.0059 4.0750 ~1.6F04 3.5627 38,2813 0,0107 3.8555 38 · 96,4 -O' 01:1 ~ 3,9.280 49 'B652 -0.0200 4.0750 42 t"~8 0,0210 3.CO0* 3.5.400~ 0.0259 3.2483 34.7656 0.0127 44,7754 -0,0195 3.1~58 33.76~5 4,2705 5'9,2773 '3,0561 C~Li FCNL CALl RH~5 =CNL CALl PHD5 FCNL C~LI RHO5 '= C N L 'CALI FC NL CA. LZ RHOB =C NL ',., &L I RHO~ $CNL C ALI RH05 FCN L C.~ L i ~CNL CALl RHO9 FCNL C,~ ti RH2E i2.2051 2.2874 3.28.1406 11.9941 2.2385 3.54.6406 12,1035 .2,3459 341.8906 12.6191 2.3987 322,B906 12.7520 2.3909 299,640.5 12,9160 2,3069 400,1406 12.10,35 2.3:538 367,8906 12,6191 2..4397 3,68.8906 1'2.5098 2,4241 i ~ 2.41,53 252.~i25 2 '988 2346 NC N L P E: N C N L PEF ORHO N ~, N L PEF ORHO NCNL PEF ,DRHO N CNL D RH,D NCNL PEF DRr~i3 NCNL PEF DRHO N C li L P: F N C N.L P E F DRH2 NCNL P E ~ · 2RH 3 3.6584 0 .. 02,49 !337,8875 3,1545 0.0053 1299.58'75 4,0476 0.0171 1321,5875 3, .2776 -0,0122 1268.5875 3,4709 O.OOOO 1221,5875 2,9417 0,0103 1.2,30.6875 3o9241 0.0215 119'5,6875 ~.87 ~ 0.0342 1291,6875 3.33,52 -0,0181 t175,6875 3,4,590 -O,0O24 1080,6875 3,5252 .3.0015 LVO 010.H02 VF:RiFIC~TZON LISTING P,~LiF__] 21 OEPT NR AT QLS DEOT NRAT ']~LS GR DEPT NRA, T Q L S GR DEOT NRAT ALS GR DE~T NR .~I T CILS NRAT ~LS GR D=pT N R AT QLS GR SEPT NR AT ~LS NR AT QLS NR,~T QLS GR NR AT QLS GR 6400.2995 RNRa ~.039~ NPHI -0.0342 QSS 63.7~17 3,6467 NPHZ -0,0~00 QSS 65.7773 6200.2998 RNRA 3,55'77 NPWI -0,0151 QSS 65,0895 6100,2998 RNRA 5,3523 NPHI -0,0522 ~SS 50,4150 6000,2995 RNRA 3,0920 NoHI -0,0151 6~=. 5~30 5900.2998 RNRA 4.~45 NOHI 0.0.127 QSS 67.277,3 5BOO.299B RNR& 3,3594 NPHi -0,0i7.5 ~SS 6!.3555 5'700.2998 RNRA 3,4475 NPHI -0 0156 r~SS 68.5.273 5600.299B RNR& 4,0007 -0,0176 QSS 67,2773 3.990S NPHI 0.010'7 QSS 60,~492 5400,299'8 RNRA 5.1052 -0,0762 QSS 39 3.7249 a9,0.234 0,0518 3.6135 41. 7480 0. C. 1 '76 3.6135 ~5. 505.5 0. 0049 5.1218 72.9980 0.0010 3- 2.346 30 · 7129 4.8i71 51. 1719 -0.0210 2.9514 36.7188 -0,0'181 3.4534 38,1348 -0,0234 4.0007 47.7539 0,0103 4.7859 47.S516 -0.0145 5,1.257 65.0664 -0,0269 FCNL CAL~. ~' FCNL "' T FCNL C&Li :'HOB :CNL CALl FCNL CALl RHDE FCNL CALI RHOS FCNL C.~I~ RHO5 mCNL CALl RHO$ FCNL C~Li RHO5 FCNL CALl FCNL RHOE. 295.3906 12.~052 2'4338 .298.890~ 12.4160 2.4056 314.1406 !2.4082 2.2209 192.8125 12,4082 1.8057 409,6406 15.3770 2,3362 265.1406 12,6191 2,2092 563.B125 12,2985 2.2600 531.8125 12.3691 ~.27!7 313.390.5 !3.4~363 2.1721 354.3906 12,8613 2.2815 183.9375 13.3,5'91 1.3878 NCN~ PEP NCNL NCNL 'D=F DRHO NCNL PEF DRHD NCNL N C NL PEF NCNL PEF DRH~ NC N' P E F ~RHO NCNL DRHO N C N L PEF DRHO NCNL P~F DRHO 1100.6875 0.0532 1080.6875 3.1038 0.0598 1135,6875 i. 9006 -0. 0146 987,8125 2.49.24 -0.0083 1325.6875 2..9690 0,0234 1277.6875 2.6877 0,0073 1664,6875 2.7424 -0.0107 1836.6875 2.7405 -0.0073 1253.6,875 2.7795 0,03B6 1696,6575 2,7249 -0,00~3 942,8!25 1.4366 -0.0054 LVP OtO.H02 VERi=ICATiJN LISTING PAGE OEPT N R A T ~L S GR DEP'T NRAT Q'L S GR DEPT NR ,67 GR 9EPT NRAT QLS GR NR ,~, T "~R A T ~LS G R DEBT N R ,'.17 QLS GR OE PT NRAT ,.ILS DE~T N R ~ T OF-PT QLS OF_mT N R ,6 T :~L S 5300.2998 RNRA 3.6174 N?HI -0.0039 QSS 75.2773 5200.2998 RNRA 4.1'335 NPMi -0.005,~ Q$5 59.5742 3.B284 NPHi -0.0107 QSS 59.9492 5000.2993 RNR,~ 3.7209 NP~I -0..0117 ~SS 55.8398 &900.299~ RN2A 3.5~91 NPHI -0.0273 QSS 85.7148 4,800.2998 RNRA 3.591.7 NPHZ 0.0 t 56 Q S S ~ 1 ? 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I ~-0-5 13.7051 2..2131 578.3125, 12.2051 2.2502 12.4082 2.1584 241.5625 ~4.~957 2.1663 508.39O5 12.4707 2.146'7 NCNL PEF NCNL ORHO NCNL P EF DRHO NCNL P E F DRHO NCNL PE: DRHJ NCNL ORHO NCNL PEF DRH'3 NCNL PEF DRHO NCNL PEF DRHO NCNL DRHj NC NL PEF DRHO 1208.6875 3.4670 3.0449 1204.5875 2.6018 0.0132 1328. 6875 2.7092 14,47 ,. !5.,"375 2. 818,5 0..0601 1770.5875 4.7156 0.0415 1333. 687.5 2.8655 0.02,39 "42 '~ 6875 2.84,.20 0.0327 !710.,58'75 3. 0754 0.0693 1570.6575 2.9182 i 422.6875 3. 023'7 0.0581 15S5.5575 3.3713 LVm OIO.H02 VERIFICATION LISTING PAGE 23 GR 65.0898 DEPT 4200.2.998 RNRA ?tR&T 5.0437 NPMI QLS -0.0381 QSS GR 58.4C23 '7,0007 !56,4053 0.0098 F C N L CALl DEFT 4100.2'998 RNRA NR~T 3,5452 N~Hi QLS -0.0049 QSS GR $8,~023 3.9Ji9 39,9~0g -.0.00~ FCNL C~LI RHOS OEPT 4000,2998 RNRA NR&T 3,2'795 NPHI QLS -0,0269 QSS GR 3.8108 35.1562 0.0068 FCNL CALI RHOB DE'PT 3922,4995 RNR4 NR~T 5,4031 NDHI ~L5 0,0435 ~$5 GR 31.8486 5.426~ 7,4'0.234 -0.16,31 :CNL CA LI :iLE NAME ::EDIT · Ol SERVICE N&ME : VERSION m : OAT E : MAXIMUM L,~NGTH : 1024 FILE TYPE : N'=XT. ='TLE_ NAME : ,'-:-':;: FILE HEADER FiLE NAM2 "EDIT SERVICE NAME : VERSION ~ : DATE : MA X.ZMU,M L ~'N.GT H FILE TYPE : OREVIOUS FILE : .001 1024 ......,-,-.,. 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PT ~ PT D~PT DEPT DE~T D~PT DEPT D~PT OEPT DEPT OEPT DEnT DE~T ~EOT DEPT D~PT DEPT OE~T 5800.1070 MNCR 5700. 1670 6500.16'70 '5500. 1670 MNOR 5aO0. 1670 5300.1670 MNCR 6200.1570 6100.i67J 6000. 1670 MNSR 5900.1~70 MNOR 5800.1570 MNOR 5700.1670 MNJR 5500.16'70 MN3R 5500.t670 MNGR 5400.1670 t',iN O R ~300.1570 MN3R 5200. 1570 5100.1570 5000.1570 4900. 1570 4800. 1670 MN~R ~700.1570 ~500.1570 ~,'~N 9 R 4500.1670 ~400.1570 4300. 1570 MNOR ~200.1670 0.9,209 1.1280 !. 1,231 1.0840 t. 4?78 1.0587 1.2'755 1..2540 0.9922 0.6/43'1 0.6553 0.6035 0. 444,3 0.5415 0.4,355 0.4854 O. &5'14 0..3&13 0.4521 0.8291 0.4922 0.51~7 0.-~4,58 O.~94'~ 3.315~ 0.5854 0.6099 0,.613B 0.7358 0.9365 0.8037 0.5923 0.3925 0.3935 0.3594 O. 2 O. 2822 0.2,527 0.2402 0.251 5 0.2437 0.18!2 0.239B 0.5083 0.2754 0.~C, 97 0.2749 0.1904 0.2599 0.1':)97 PROX PROX ~ R,'3 X PROX PROX PRDX PROX mRBX PRCX PROX PROX oROX PROX PR'3X oROX PROX PROX PROX PR3X PROX PRSX PROX PROX PRiX PROX ~ROX 4..2859 4.5593 3.8937 6.0398 5.4109 11.6815 3.3674, 3.7991 2.2 '7 '76 3.012.0 1.7530 1.5079 !. 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