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Home My WebLink About181-0401. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 5,450 5,392 Casing Collapse Structural Conductor Surface 1,540psi Intermediate 4,760psi Production 7,020psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Eric Dickerman Contact Email:Eric.Dickerman@hilcorp.com Contact Phone:(907) 564-4061 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng CO 93B Trading Bay Middle Kenai B Oil Same 4,266 3,517 2,721 757psi N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018731 181-040 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20226-01-00 Hilcorp Alaska, LLC Trading Bay St A-24RD Length Size Proposed Pools: N-80 TVD Burst 4,124 8,160psi MD 6,870psi 3,090psi1,044' 1,514' 1,075'13-3/8" 9-5/8"1,695' 1,075' 1,695' 3,515 - 5,050 5,450' 2,719 - 3,927 4,265'7" Other: CTCO, Patch, N2 10/24/2025 2-7/8" Se schematic See schematic 5,450' Perforation Depth MD (ft): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:18 am, Oct 07, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.10.07 05:49:48 - 08'00' Dan Marlowe (1267) 325-607 CT BOP test to 3000 psi A.Dewhurst 15OCT25 DSR-10/15/25 10-404 BJM 10/15/25 X 10/16/2025 TBU A-24RD Fill Clean Out and Patch Page 1 of 2 Well Name:TBU A-24RD API Number:50-733-20226-01 Current Status:Shut in Permit to Drill Number:181-040 Estimated Start Date:10/24/25 Rig:Fox Coil Unit 9 Regulatory Contact:Juanita Lovett Estimated Duration:4 days First Call Engineer:Eric Dickerman Cell Number:307-250-4013 Second Call Engineer:Casey Morse Cell Number:603-205-3780 Current Bottom Hole Pressure:1,100 psi at 3,431 TVD. Nodal analysis from July 2025 gas lift survey. Max. Potential Surface Pressure:757 psi (Based on 0.1 psi/ft. gas gradient) Last Shut-in WHP:440 psi (from gas lift) Min. ID:2.313 2-7/8 X nipple Max. Deviation:53 at 1,900 Pool:Middle Kenai B, no pool change during operation. Brief Well Summary: A-24RD was originally completed in May 1981 as a B zone only producer, with the following intervals frac packed: 3515 3535 / 24-6 sand 13k# 100 mesh, 67k# 20-40 sand. 3720 3735 / 26-7 sand 13k# 100 mesh, 80k# 20-40 sand. Well dead post frac. 3945 3960 / 28-6 sand 13k# 100 mesh, 80k# 20-40 sand. Well flowing post frac. 4375 4405 / 31-8 sand 13k# 100 mesh, 67k# 20-40 sand. Screened out on 10 ppg. Well dead post frac. 4530 4550 / 33-6 sand 13k# 100 mesh, 80k# 20-40 sand. Well flowing post frac. The 44-7, 41-8, and the 40-4 sands were added in January 1985 and the 33-6 and 31-8 were re- perforated. A RWO in August 1989 squeezed off the 28-6 and then installed a gravel pack completion. In June 2014 the upper B zone perforations were added through the tubing. In July 2025 a flowing pressure survey showed the well was lifting from the GLM at 1,025 md and tagged at 3,517 , above top perf. On 8/29/25 slickline replaced the gas lift valve at 1,025 multiple times, however this did not move the lift point downhole and indicates the possibility of a hole in tubing around this depth. After setting a patch the well should be able to lift from the GLM at 3,435, increasing drawdown. The well passed an AOGCC witnessed No Flow Test on September 20, 2015. Objective: Coiled tubing fill cleanout down to ± 5,050. Set patch to restore tubing integrity and move the gas lift point to the orifice gas lift valve at 3,435 (the ID of the tubing patch is too small to perform the coiled tubing cleanout through, that is the reason to perform the cleanout first). TBU A-24RD Fill Clean Out and Patch Page 2 of 2 Coiled Tubing Procedure: 1. MIRU Fox Energy offshore Coiled Tubing #9 and pressure control equipment. 2. Pressure test BOP and PCE to 250 psi low / 3,000 psi high. a. Provide AOGCC with 48 hr BOP test witness notification. 3. MU cleanout BHA. Dry tag top of fill, then begin cleaning out down to ± 5,050. a. Working fluid will be 3% KCl in Filtered Inlet Water (8.5 ppg). b. Take returns to surface up the CT x tubing annulus. c. Add foam and nitrogen as necessary to carry solids to surface. 4. RDMO CT. Slickline Procedure: 5. MIRU. Pressure test PCE to 250 psi low / 2,000 psi high. 6. Confirm leak depth with holefinder. Test tubing above and below leak. 7. Set 2-7/8 tubing patch across tubing leak. a. Suspect leak around GLM at 1,025. 8. To test patch, pressure up tubing and IA with lift gas. Supply pressure is ± 1,000 psi. Once tubing and IA are pressured up, bleed off the IA pressure and confirm that the tubing does not track with IA. b. The ID of the patch is too small to pass a slickline plug, necessitating the alternate testing method. 9. RDMO Slickline. Operations Procedure: 10. Perform No Flow test within 14 days of returning to production. c. Provide AOGCC with 48 hr no flow test witness notification. Attachments: 1. Wellbore Schematic - Current 2. Wellbore Schematic - Proposed 3. CT BOP schematic (Fox Energy) 4. Standard nitrogen procedure _____________________________________________________________________________________ Updated By: EPD 7/10/2025 SCHEMATIC Trading Bay Field Well: A-24RD Last Completed: 08/25/1989 PTD: 181-040 RKB to TBG Hngr = 39.80 PBTD =5,392 TD =5,450 BZN 26-7 BZN 26-7 3/8 7 9-5/8 Total Sand in Place 91 sacks of 20-40 Mesh Ottawa Sand 120% of Theoretical BZN 28-6 6 3 BZN 24-6 B 1 2 8 9 4 5 7 11 10 10 X CASING DETAIL Size Wt Grade Thread ID Top Btm 13-3/8 61# J-55 Seal Lok 12.515 Surf 1,075 9-5/843.5# N-80 BTC 8.755 Surf 438 43.5# N-80 Seal Lok 8.755 438 1,695 7 29# N-80 6.184 Surf 5,450 TUBING DETAIL 2-7/8 6.4# N-80 Butt 2.441 Surf 4,124 9-5/8 Window 1,695 KOP 1,700 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 322 322 2.313 3.85 Otis Ball Valve X Lock Mandrel w/ BXE-23100 2 1,025 999 2.347 4.75 GLM CAMCO KBMG (Dummy installed 10/17/2015) 3 2,470 2,033 2.347 4.75 GLM CAMCO KBMG (Dummy installed 10/16/2015) 4 3,435 2,661 2.347 4.75 GLM CAMCO KBMG 5 3,472 2,688 2.313 3.75 Otis XA Sleeve 6 3,492 2,702 3.25 6.0 Otis VST Packer w/ seal bore extension 7 4,058 3,127 2.313 3.75 Otis XA Sleeve 8 4,090 3,152 2.313 3.24 Otis X Nipple 9 4,124 3,177 4.00 5.812 Baker SC-1L Packer 10 4,217 (top) 3,248 2.992559 of 3-1/2, 9.2#, 8rnd, J-55 WWS .0124,776 (btm) 3,698 2.992 11 4,777 3,698 3.25 5.68 Baker Model D Permanent Notes Junk @ 5,392 ETD Float Collar @ 5,404 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status BZN 24-6 3,515' 3,550' 2,719' 2,746' 35 06/06/2014 Open 2, 6 SPF, 60 deg BZN 26-7 3,698' 3,745' 2,857' 2,892' 47 06/06/2014 Open 2, 6 SPF, 60 deg BZN 26-7 3,788' 3,810' 2,924' 2,940' 22 06/05/2014 Open 2, 6 SPF, 60 deg BZN 28-6 3,930' 3,975' 3,031' 3,065' 45 06/05/2014 Open 2, 6 SPF, 60 deg B 4,280' 4,298' 3,297' 3,311' 18 08/19/1989 Open Gravel pack, 4-1/2 8 spf B 4,320' 4,342' 3,328' 3,345' 22 08/19/1989 Open Gravel pack, 4-1/2 8 spf B 4,350' 4,466' 3,351' 3,443' 116 08/19/1989 Open Gravel pack, 4-1/2 8 spf B 4,513' 4,565' 3,481' 3,523' 52 08/19/1989 Open Gravel pack, 4-1/2 8 spf B 4,580' 4,595' 3,535' 3,547' 15 08/19/1989 Open Gravel pack, 4-1/2 8 spf B 4,720' 4,757' 3,651' 3,682' 37 08/19/1989 Open Gravel pack, 4-1/2 8 spf 5,030' 5,050' 3,911' 3,927' 20 Open 2-1/8 4 spf, 0 Phase FILL 1.75 bailer run to 3,517 kb 7/8/2025 See attached email. A.Dewhurst 15OCT25 B _____________________________________________________________________________________ Updated By: EPD 10/02/2025 PROPOSED SCHEMATIC Trading Bay Field Well: A-24RD Last Completed: 08/25/1989 PTD: 181-040 RKB to TBG Hngr = 39.80 PBTD =5,392 TD =5,450 BZN 26-7 BZN 26-7 12 3/8 7 9-5/8 Total Sand in Place 91 sacks of 20-40 Mesh Ottawa Sand 120% of Theoretical BZN 28-6 6 3 BZN 24-6 1 2 8 9 4 5 7 11 10 10 X CASING DETAIL Size Wt Grade Thread ID Top Btm 13-3/8 61# J-55 Seal Lok 12.515 Surf 1,075 9-5/843.5# N-80 BTC 8.755 Surf 438 43.5# N-80 Seal Lok 8.755 438 1,695 7 29# N-80 6.184 Surf 5,450 TUBING DETAIL 2-7/8 6.4# N-80 Butt 2.441 Surf 4,124 9-5/8 Window 1,695 KOP 1,700 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 322 322 2.313 3.85 Otis Ball Valve X Lock Mandrel w/ BXE-23100 2 TBD 2-7/8 Tubing Patch 3 1,025 999 2.347 4.75 GLM CAMCO KBMG (Dummy installed 10/17/2015) 4 2,470 2,033 2.347 4.75 GLM CAMCO KBMG (Dummy installed 10/16/2015) 5 3,435 2,661 2.347 4.75 GLM CAMCO KBMG 6 3,472 2,688 2.313 3.75 Otis XA Sleeve 7 3,492 2,702 3.25 6.0 Otis VST Packer w/ seal bore extension 8 4,058 3,127 2.313 3.75 Otis XA Sleeve 9 4,090 3,152 2.313 3.24 Otis X Nipple 10 4,124 3,177 4.00 5.812 Baker SC-1L Packer 11 4,217 (top) 3,248 2.992559 of 3-1/2, 9.2#, 8rnd, J-55 WWS .0124,776 (btm) 3,698 2.992 12 4,777 3,698 3.25 5.68 Baker Model D Permanent Notes Junk @ 5,392 ETD Float Collar @ 5,404 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status BZN 24-6 3,515' 3,550' 2,719' 2,746' 35 06/06/2014 Open 2, 6 SPF, 60 deg BZN 26-7 3,698' 3,745' 2,857' 2,892' 47 06/06/2014 Open 2, 6 SPF, 60 deg BZN 26-7 3,788' 3,810' 2,924' 2,940' 22 06/05/2014 Open 2, 6 SPF, 60 deg BZN 28-6 3,930' 3,975' 3,031' 3,065' 45 06/05/2014 Open 2, 6 SPF, 60 deg B 4,280' 4,298' 3,297' 3,311' 18 08/19/1989 Open Gravel pack, 4-1/2 8 spf B 4,320' 4,342' 3,328' 3,345' 22 08/19/1989 Open Gravel pack, 4-1/2 8 spf B 4,350' 4,466' 3,351' 3,443' 116 08/19/1989 Open Gravel pack, 4-1/2 8 spf B 4,513' 4,565' 3,481' 3,523' 52 08/19/1989 Open Gravel pack, 4-1/2 8 spf B 4,580' 4,595' 3,535' 3,547' 15 08/19/1989 Open Gravel pack, 4-1/2 8 spf B 4,720' 4,757' 3,651' 3,682' 37 08/19/1989 Open Gravel pack, 4-1/2 8 spf 5,030' 5,050' 3,911' 3,927' 20 Open 2-1/8 4 spf, 0 Phase FILL ± 5,050 ctm STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. 1 Dewhurst, Andrew D (OGC) From:Eric Dickerman <Eric.Dickerman@hilcorp.com> Sent:Wednesday, 15 October, 2025 09:18 To:Dewhurst, Andrew D (OGC) Cc:Rixse, Melvin G (OGC) Subject:RE: [EXTERNAL] Trading Bay St A-24RD Sundry (325-607): Question Attachments:A-24RD 1 to 500 Log CET 10-15-25.pdf Mr. Dewhurst and Mr. Rixse, We have con rmed that the perforated interval from 5,030 5,050 is in the Middle Kenai B pool. Our correla on log is a ached, and I will make sure our wellbore schema c is updated in our records. Thank you, Eric Dickerman Hilcorp CIO Ops Engineer Cell: 307-250-4013 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Tuesday, October 14, 2025 8:51 AM To: Eric Dickerman <Eric.Dickerman@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] Trading Bay St A-24RD Sundry (325-607): Question Eric, I am reviewing the Trading Bay St A-24RD sundry and have a question about the deepest perforated interval: The perforated interval from 5,030 to 5,505 MD does not have a zone label. Which pool does it belong to? If it is interpreted to be in the Middle Kenai B pool, would you please send a log correlation panel as support? 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 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. • of ryi.� THE STATE Alaska Oil andGas ww��\��%%%�� ofALAS KA Conservation Commission ul��.tx _ 333 West Seventh Avenue e, Alaska 99501-3572 Anchorage,GOVERNOR BILL WALKER Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov November 5, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit A-24RD SCANNED PTD 1810400 Dear Mr. Golis: On September 20, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit A-24RD located on the Monopod Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Trading Bay Unit A-24RD prior to the test. The well performance was monitored for three hours with resulting flow rates (oil and gas) below the regulatory limits, passing the no-flow test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit A-24RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Monopod Platform. Sincerely, 1/ James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg deem 11I. '15 DATE: 9/20/2015 P. I. Supervisor I FROM: Matt Herrera SUBJECT: No Flow Test Petroleum Inspector TBU A-24RD (Monopod Platform) Hilcorp PTD 1810400 9/20/2015: On arrival to Monopod Platform I met with Hilcorp's Senior Operator Mike Foust. We discussed how the no-flow meter was rigged up and how I wanted to test it. They told me that well A-24RD had been opened to atmosphere for over 24 hours. The pressure gauge and - the flow meter were rigged up to an atmosphere bucket. Asked operator if well had issues bleeding down periodically or bringing up small amounts of fluid —there were none. Test equipment consisted of an ArmorFlo flow meter with range 0-20 SCFH (Serial # 062532; last calibrated 11/2014); and SSI Test Digital pressure gauge with range 0-30psi (Serial # - 1506240057; last calibrated 8/14/2015) The following table shows test details: Pressures' Flow Rate Time Remarks (psi) Gas - scf/hr Liquid - gal/hr 11:00 0/66/0 0 0 Initial; well shut in 11:30 7/66/0 1500 0 Open well; bled to 0 SCFH in < 1 min (< 1000 SCFH in 0.5min) 12:30 11.76/66/0 2000+ 0 Open well; bled to 0 SCFH in < 2min (< 1000 SCFH in 1 min) 13:30 13.42/100/0 0 0 . Shut in 14:30 15.32/110/0 0 0 Shut In 15:30 33.0/135/0 2000+ 0 Open well; bled to 0 SCFH in < 2min (< 1000 SCFH in 1 min) 1 Pressures are T/IA/OA Summary: During each flow test period, the well exhibited initial gas flow rates up to approximately 2000 SCFH and quickly bled down to 0 SCFH withn 2 minutes. There were no liquids produced at surface during the no flow test. Not sure why IA pressure increased during the flow test (from 66 psi to 135 psi). Test results for TBU- A-24RD appear to meet the no flow test criteria for removal of the subsurface safety valve. Attachments: none SCANNED JUL 1 8 2016 2015-0920 No-Flow TBU A-24RD rnh.docx Page 1 of 1 Ima~Project Well History File Coven ~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. L ~ L- 0 ~'4~D Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Diskettes. No. Other, No/Type BY: BEVERLY ROBIN VINCENT ~ARIA WINDY [] Maps: Other items scannable by large scanner OVERSIZED (Non,Scannable) [] Logs of various kinds J Other Project Proofing .. BY: ~OBIN VINCENT SHERYL FVIARIA WINDY Scanning Preparation ~ x 30 = BY: BEVERLY ROBIN Production Scanning Stage 1 Stage 2 BY: (sCANNING I$ COMPLETE AT THIS POINT UNLESS $PECIAL ATTENTION I$ REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAySCALE OR COLOR IMAGES ) PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES ~NO IF NO IN STAGE 1 ~ PAGE(S) DISCREPANCIES WERE FOUND: ~ YES NO III IIIIIIIIIII II III ReScanned (individual page [,~pecial attetttiott] ~ca~ning completed) F~ESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd I \ } ---- 3;)3 Se\,erth .r" ,, LT y " .':AI's � Anchors-ce Alaska 9950i 3572 \Ol awa�wa F SCANNED JUL 2 9 2014 Ted Kramer � � �� Sr. Operations Engineer U Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai B Oil Pool, Trading Bay State A-24RD Sundry Number: 314-310 Dear Mr. Kramer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair -- DATED this /' day of May, 2014. Encl. RECEIVED STATE OF ALASKA MAY 12 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION 075 5/j' .R, APPLICATION FOR SUNDRY APPROVALS 9'`OGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill 0 Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend 0 Plug Perforations❑ Perforate El• Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC ' Exploratory ❑ Development 04 181-040• 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service CI6.API Number: Anchorage,AK 99503 50-733-20226-01 • 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 936 Will planned perforations require a spacing exception? Yes ❑ No 0/ Trading Bay State/A-24RD . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 , Trading Bay Field/Middle Kenai B Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 5,450. 4,265 • 5,392 • 4,217 ° N/A 5,392 • Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,075' 13-3/8" 1,075' 1,044' 3,090 psi 1,540 psi Intermediate 1,695' 9-5/8" 1,695' 1,514' 6,870 psi 4,760 psi Production 5,450' 7" 5,450' 4,265' 8,160 psi 7,020 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic • See Schematic 2-7/8" 6.4#/N-80 4,124' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): , Otis"VST",Baker SC-1L,Baker SC-1L Packers&Otis SSSV • 3,492'(MD)2,702'(TVD);4,124'(MD)3,177'(TVD);4,777'(MD)3,698'(TVD)&322'(MD)(322'(TVD) 12.Attachments: Description Summary of Proposal 0. 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/20/2014 Oil 0• Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer(a hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature "l'lti Phone (907)777-8420 Date 5/9/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \LC- 3\•co Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: .qiRBDMS MAY 16 2014 Spacing Exception Required? Yes ❑ No WI/ Subsequent Form Required: /0.. Y 0-1 214.7 ? 99..&"4----- THPROVED BYApproved by: COMMISSIONER THE COMMISSION Date: 5 -/6 --If ,aka 41/11 /litZ4 f S./2'Pr( �__ Submit Form and Form 10-403(Revised 10/2012) Approves _RaloG T 'A jnths from the date of approval. Attachments in Duplicate • Well Work Prognosis 14 Well: A-24RD Date: 5/09/14 Hilcorp Alaska,LLC Well Name: A-24RD API Number: 50-733-20226-01 Current Status: Producer Leg: NA Estimated Start Date: May 20, 2014 Rig: NA Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 1810400 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 750-0747 (M) Last Bottom Hole Pressure: 7/18/2009 -1143 psi @ 3485'ND (mid perf) Last downhole intervention: 10/31/2012 Routine WL paraffin/scale check,tag @ 4468'KB (fill)w/2" GR -sticky from 3000'to 4096'w/2.25" GR. Maximum Anticipated Surface Pressure- 1,297 psi.Assuming a naturally pressurized gradient and a gas gradient of.044. Brief Well Summary i Well A-24RD is an active gas lifted producer in the Trading Bay Field Middle Kenai B-Zone Oil Pool. The lower B-Zone zone is completed with a gravel pack completion. Latest well test on 4/01/2014: 64 bopd, 29 bwpd, .467 MMscf lift gas used vyith minimal gas production. New perforations are proposed in the upper Middle Kenai B pool with a slick line paraffin check prior. A-24RD has had a history of wax buildup but has sustained a flat decline for several years. There is potential for a full rig workover in the future. Estimated Rate Add^ 40 bopd Procedure: 1. Skid Rig#56 over Well. . 2. MIRU wire-line/Slick line Combo unit. 3. RU Lubricator and test to 1,500 psi. 4. MU 2.25"GR and RIH on Slickline drifting to 4,000'. 5. MU Gamma Ray on E-line to 4,000'. Run Gamma Ray log from 4,000'to 9-5/8"casing shoe at 1,695'. Send log into the Geologist for possible depth correction.- 6. Pick up E-line guns and RIH with Gamma Ray/CCL and log on depth. Perforate intervals 3,515- 50,3,698-3,745',3,788-3,810,and 3,930-75'with 2"guns. 7. Monitor well in test separator. 8. POOH with Guns. 5L4 9. Return well to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Trading Bay Field ii Well: A-24RD • SCHEMATIC Last Completed: 08/25/89 Bacon,Alaska,LLC PTD: 181-040 RKBto73GHngr=39.80 CASING DETAIL 1 Size Wt Grade ID Top Btm 13-3/8" 61# J-55 Surf 1,075' 9 5/8" 474 N-80 Surf 1,695' 7" 29# N-80 Surf 5,450' Surf 4,124' t1 2 TUBING DETAIL 2-7/8" 6.4# N-80 9-5/8"Window 1,695'-KOP 1,700' JEWELRY DETAIL No Depth ID Item I 1 322' Otis Ball Valve L 2 1,025' GLM 3 3 2,470' GLM I 4 3,435' GLM 5 3,472' Otis XA Sleeve 6 3,492' Otis"VST"Packer 7 4,058' Otis XA Sleeve n 4 8 4,090' Otis"X"Nipple I 9 4,124' Baker SC 1L Packer 10 4,217'-4,776' 559'of 3-1/2",9.2#,1-55 WWS.012" �1tr 5 11 4,777' Baker SC-1L Packer 6 iii 7 M PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status [ 8 B 3,515' 3,550' 2,719' 2,746' 35 Cmt Sqz IB 3,698' 3,745' 2,857' 2,892' 47 Cmt Sqz 9 B 3,788' 3,810' 2,924' 2,940' 22 Cmt Sqz B 3,930' 3,975' 3,031' 3,065' 45 Cmt Sqz y= = B 4,280' 4,298' 3,297' 3,311' 18 Open :_ = Total Sand B 4,320' 4,342' 3,328' 3,345' 22 Open 10 _ _ --, F Place-91 sacks B 4,350' 4,466' 3,351' 3,443' 116 Open EEE .&' of 20-40 Mesh Ottawa Sand B 4,513' 4,565' 3,481' 3,523' 52 Open I -'"= y� •' 120%of B 4,580' 4,595' 3,535' 3,547' 15 Open ' = _" ': Theoretical B 4,720' 4,757' 3,651' 3,682' 37 Open V. A 1s- , = 5,030' 5,050' 3,911' 3,927' 20 Open -_ - a, Notes 11 Junk @ 5,392'ETD Float Collar @ 5,404' Y Oh V 4 1 PBTD=5,392' TD=5,450' Updated By:1LL 05/09/14 Trading Bay Field • Well: A-24RD PROPOSED Last Completed: 08/25/89 Hilcory Alaska,LLC PTD: 181-040 RKB to TBG Hngr=39.80 CASING DETAIL 1 Size Wt Grade ID Top Btm 13-3/8" 614 J-55 Surf 1,075' 9-5/8" 474 N-80 _ Surf 1,695' 7" 294 N-80 Surf 5,450' nit TUBING DETAIL L 2-7/8" 6.44 N-80 Surf 4,124' 9-5/8"Window 1,695'-KOP 1,700' JEWELRY DETAIL No Depth ID Item 1 1 322' Otis Ball Valve L 2 1,025' GLM • 3 3 2,470' GLM 4 3,435' GLM 5 3,472' Otis XA Sleeve 6 3,492' Otis"VST"Packer 7 4,058' Otis XA Sleeve 4 8 4,090' Otis"X"Nipple 9 4,124' Baker SC-1L Packer 10 4,217'-4,776' 559'of 3-1/2",9.2#,1-55 WWS.012" 000 5 11 4,777' Baker SC-1L Packer 00 7 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) (Np) FT Date Status 8 BZN 24-6 ±3,515' ±3,550' ±2,719' ±2,746' 35 Future Cmt Sqz BZN 26-7 ±3,698' ±3,745' ±2,857' ±2,892' 47 Future Cmt Sqz BZN 26-7 ±3,788' ±3,810' ±2,924' ±2,940' 22 Future Cmt Sqz i:; .... . - " � 9 BZN 28-6 ±3,930' ±3,975' ±3,031' ±3,065' 45 Future Cmt Sqz • x B 4,280' 4,298' 3,297' 3,311' 18 Open • '', '' Total Sand in B 4,320' 4,342' 3,328' 3,345' 22 _ Open 10 + ' Place-9l sacks B 4,350' 4,466' 3,351' 3,443' 116 Open r, of 20-40 Mesh ;' ¢ Ottawa Sand B 4,513' 4,565' 3,481' 3,523' 52 Open , tisk 120%of B 4,580' 4,595' 3,535' 3,547' 15 Open 't Theoretical B 4,720' 4,757' 3,651' 3,682' 37 Open '<- v 5,030' 5,050' 3,911' 3,927 20 Open Notes 11 Junk @ 5,392'ETD Float Collar @ 5,404' It V 4 I PBTD=5,392' TD=5,450' Updated By:JLL 05/09/14 ALASKA OIL AND GAS CONSERVATION CO~HSSION TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dwight Johnson'.'~' Chris Myers Unocal Field Superintendents 260 Cavair Street Kenai, Alaska 99611 May 20, 2002 RE: No-Flow Verification TBF Well A-24RD, PT~¢~ Gentlemen. On April 18, 2002 our inspector Jeff Jones witnessed a "no-flow test" on UNOCAL's Trading Bay Field well A-24RD. Mr. Jones arrived on Monopod Platform and found the well isolated to an atmospheric vessel. The well was observed over a three (3) hour period using a recently calibrated Armor-FIo gas flow meter. Gas was produced at about 240 SCF/hr at 3.5 psi with only a trace of oil noted. Trading Bay Field well A-24RD (181-040) meets the criteria of a "no-flow" performance test and as such, is considered incapable of unassisted flow to the. surface. As proscribed, at 20 AAC 25.265 (A), it is not required to have a fail-safe automatic SSSV, however, the pilot and SSV must be maintained in satisfactory operating condition. If for any reason the well again becomes capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well file on board Monopod. Thomas E. Maunder, 'PE Sr. Petroleum Engineer MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Camille O. Taylor, ~'~ Chair Tom Maunder, ~~~~-~. P. I. Supervisor DATE: April 18, 2002 FROM: Jeff Jones, SUBJECT: Petroleum Inspector No-Flow Test Prudhoe Bay Field Unocal/King Salmon A~24RD/TBU April 18, 2002: I traveled to Unocal's Cook Inlet Platform Monopod to witness a No-FlOW test on Well A-24RD. On arrival I checked the status of well A-24RD and found it open and flowing to an atmospheric vessel and blocked in to the production header system. An Armor-FIo model 3461-0310 flow meter (180 - 1800 SCFH span) was installed to measure flow from the well. This flow meter had been sent to the IISCO instrumentatio-n-shopfor-calibration--on/he'-previous.day and was fl°w tested with results of +/- 5% accuracy. The initial indicated well flow from A-24RD was 250 SCFH of gas and producing no measurable amount of crude oil at 4 PSI. I monitored the flow and pressure for 3 hours taking readings every 30 minutes. 30 minutes: 240 SCFH @ 4 PSI; no crude oil produced. 60 minutes: 240 SCFH @ 3~5 PSI; no crude oil produced. 90 minutes: 240 SCFH @ 3.5 PSI; no crude oil produced. 120 minutes: 240 SCFH @ 3.5 PSI; no crude oil produced. .... 150 minutes: 240 SCFH @ 3.5 PSI; trace amount of crude oil produced. 180 minutes: 240 SCFH @ 3.5 PSI; trace amount of crude oil produced. I spoke,with Gary Smith (Upgrade Platform Supervisor) regarding the test results, informing him that in my judgment well A-24RD qualifies for a no-flow determination under AOGCC guidelines (< 900 SCFH / 6.3 gals. flow in 3 hrs). Summary: I witnessed a successful No-Flow test on Unocal's Monopod Platform well A-24RD in the Trading Bay Unit. Attachments: none CC: NON-CONFIDENTIAL No-Flow TBU A-24RD 4-18-02 JJ.doc MEMORANDUM TO: THRU: Julie Heusser, Commissioner Tom Maunder,/3'~ P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 5, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Monopod Platform Trading Bay Field Thumdav. April 5, 2,00!: I traveled to UNOCAL's Monopod Platform and witnessed the semi annual safety valve system testing. Lead operator Gary Smith conducted the testing today; he did a thorough job and was a pleasure to work with, As the AOGCC Safety Valve System test report indicates lwitnessed the testing of 18 wells and 53 components, with four :failures;.~The pilot on well A-02 tripped at 26 psi and was repaired and passed a retest. This well has had the SSSV removed for repair since 2/24/00 and has not been re-installed. Well A-11 has had the SSSV removed for repair since 11/7/99 and has not been re-installed, lindicated to Mr. Smith that these SSSV's must be repaired and re-installed and successfully tested in a timely manner or the two wells shut in. Well A-06 SSSV failed to close and will require maintenance. Wells A-13 and A-21 have been certified as "no flow" status and do not have SSSV's installed. While on location I inspected the platform and found it very clean and it appeared to be in excellent condition. Summary: I witnessed the semi annual Safety Valve System testing at Unocal's Monopod Platform in the Trading Bay Field. Monopod Platform, 18 wells, 53 components. 4 failures, 7.5% failure rate. Platform inspection conducted. Att~..chment: svs TBF Monopod Platform 4/5/01 JJ NON-CONFID,, ENT,,,IA,L, SVS TBF Monopod Platform 4-5-01 JJ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: UNOCAL Operator Rep: Gary Smith AOC~C Rep: Jeff Jones Submitted By: Jeff Jones Date: Field/Unit/Pad: Trading Bay .Field Monopod Separator psi: LPS 65 HPS Well Pemit Separ Set ~ T~t T~t T~t Date ~ WAG, G~J, Number Number PSI PSI Trip Code Code Code Pass~ GAS or ii i i ii i i A-01~ 1901470 65 45 42 P P P O~ ~2 1660490 '65 45 26 3 'P ~';~3 ' 4/5/01' OiL: A-03~3 1971300 ' 65 45 42 P ' " P' P ~ OIL , , ~ , ., A-~ 1670020 ~06 , 1670250 65 45 '45: P ,,p :;~43' , , 61L. A-07 1670460 65 45' '42: P " P P ' OIL . A-09 8 0360 ,, . , ,, , ~ , ,~ , , , , ,, , , ~ , A- 10 1670760 M~I. ' ~' 17~240 ' 655 ' ~5 '43 P ' ' P ~;~: ' 'OIL , , , , , , , ,, a ~ , , A-13 1680020~ 65 45 41 P P OIL · , , A. 14" '1686270 ' '~-15' "168033~ 65' 45'" 45' P P P " O~L '~-16~ " 1880386 ...... 65 '45 41/42 P' '~ 'P ........ OIL A-l'7~ ' 1810670 65 "45 43 P .... P P ...... OIL A-18" 1680760 6~ "45 47 " P" ' P ~ ........... OIL A-21 1700470 65 ' ~45 ' 46 P P .... . ' OiL X-22' 17003'i0 "65 45 ' ~4 ' P P' 'P ....... OIL~ X_23, 7o059o .......... A-23DPN 1720200 ........... _"_(2~;~ --~18i0400 ' ' 65 ' 45" ' 4'1 P P P OILi A-27~1 . 1970630 65 45 '43 P P' P OIL A-28~ "1890920 .... 65 ' ' '45 ' '45' P" 'P P ...... OIL A-30 '1730140 .......... A-32 ' 1770180 65 45 ' 44 'P" P P ' 'OIL Wells: , ,. 18 Components: 53 Failures: ~4." Failure Rate: 7.5% I"100t>ay Remarks: .A' ! 3 & A-21 repo ,rt, ed as No-Flow wells. , SS.SV's removed for repair: A-02 ,OUt ,;ip..Ce,2,'~/:'.42(i0'.'A-1 i ~ui"since 11/7/99. ~.r0,2 pil0t repaired and retested "OK". A-06 SSSV failed to Close. ' ......... A-16 RD is a dual co_.mpl~ti~'h. ' ................... 4/9/01 Page 1 of 1 SVS TBF Monopod Platform 4-5-01 JJ Unocal North Americajl~' Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was Unable to locate any plats from a registered surveyor but I hope this will meet your needS. Yours very truly, Gar~S.(3~ush . Regibnal Drilling Manager GSB / lew CONDUCTOR 1 2 3 4 5 6 7 8 9· l0 ll 12 13 14 15 16 17 18 19 20, 21 22 22__ .:~. 24 25 26 27 28 29 30 31 32 MONOPOD CENTER FROM .SOUTHEAST CORNER~ SECTION 4, TgN, R13W "Y" = 2,523,126 "X" = 218,871 "Y" COORD. 2,523,134.3 2,523,130.2 2,523,125.7 2,523,121.7 2,523,118.2 2,523,114.4 2,523,113.2 2,523,113.2 2,523,114.8 2,523,117.7 2,523,121.8 2,523,126.4 2,523,130.3 2,523,133.8 2,523,137.6 2,523,138.8 2,523,138.8 2,523,137o.2 , . 2,523,132.8 2,523,129.4 2,523,132.0 2,523,128.4 .2,523,_1.2~. 8 2,523,133.9 2,523,120.9 2,523,131.4 2,523,118.1 2,523,127.2 2,523,123.6 2,523,120.0 2,523,122.6 2,523,119.2 "X" COORD. 218,880.9 218,883.2 218,883.9 218,883.2 218,881.3 218,876.8 218,873.0 218,869.0 218,864.6 218,861.1 218,858.8 218,858.1 218,858.8 218,860.7 218,865.2 218,869.0 218,873.0 218,877.4 218,875.7 218,878.6 218,870.8 218,873..9 218,867.0 218,878.1 218,863.9 218,875.0 218,865.1 218,868.1 218,871.1 218,863.4 218,866.3 WELL # FSL A-28 1621 A-25 1617 A-30 1612 1608 A-27 1605 A-23 .1601 A-21 and RD 1600 A-22 1600 A-14 1601 A-13 1604 A-17 1608 A-8 1612 A-15 1616 A-24 and RD 1620 A-29 1624 A-9 and RD 1625 A-19 1625 A-18 1624 A-11 1619 A-3 1616 ,, A-1 1618 A-7 1615 A-4 i611 A-6 1600 A-32 1607 A-12 and RD 1617 A-20 1604 A-2 1613 A-16 1610 A-26 1606 A-10 1609 A-5 and RD 1605 1 &2 FEL 554 551 551 551 '553 557 561 565 57O 573 576 577 577 574 570 566 562 558 559 556 564 561 558 :568 556 571 559 570 566 563 571 568 ~./",, STATE OF ALASKA ~-~'~'"'. ~ ~? .,-~ OIL AND GAS CONSERVATION COMM JN REpO 'OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator / 5. Type of Well: · Development x_.._ Onion O~ 1 C~mp~ny nf ~1 .;-F~,-n~ {nwr~_~L) Exploratory__ 3. Address ! Stratigraphic_ ?.O. Box 190247f Anchf &k.~ 99519-024~ Service__ 4. Location of well at surface Monopod Platform Conductor #14 1620' N & 574' W f/SE cor., Sec. 4, T9N, R13W, S.M. At top of productive interval 4280' MD, 3297' TVD, 1071' S & 2196' W from ·Surf. Loc. ~effectivedepth 5392' MD, 4217' TVD, 1256' S & 2790' W from Surf Loc. Attotaldepth 5450' MD, 4256' TVD, 1263' S & 2821' W from Surf Loc. Perforate ~_ Pull tubing ~ Other __ 6. Datum elevation (DF or KB) 7. Unit or Property name Trading Bay Field 8. Well number TBS A-24 RD 9. Permit number/approval number 81-40/9-058 10. APl number 50--733-20266-01 11. Field/Pool Tyonek "B" Zone 12. Present well condition summary Total depth: measured true vertical 5450 ' feet Plugs (measured) 4265 ' feet Effective depth: measured true vertical 5392' feet Junk(measured) 4217 ' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented *7507 1075' 13-3/8" 1350sx (1695') 9-5/8" 1300sx 5450' 7" 1225sx *Window in 9-5/8" csg@ 1695' measured See attached Measured depth 1075' 7507'* 5450' true vertical 2-7/8", 6.4#, N-80 @ 4124' Tubing (size, grade, and measured depth) Otis "VST" pkr @ 3492', Baker SC-1L @ Packers and SSSV (type and measured dept~ssv @ 322 · True vertical depth 1049' 5080' 4265' RECEIVED feet OCT z 1989 Alaska 0il & Gas Cons. C0mmlssl( Anchorage 4124' & 4777' 14. 13. Stimulation or cement squeeze summary Cement squeezed Intervalstreated(measured) 3515'-3550', 3698'-3745', 3788'-3810', 3930'-3975' ¢,, / Treatment description i ncl~,~/[;lg volumes used and final pressure Tubing Pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mci~ Water-Bbl Casing Pressure Prior to well operation 0 0 0 0 162 365 203 1087 · 75 235 16. Status of well classification as: Oil x Gas Suspended Service Date ] 0/19/89 SUBMIT IN DUPLICATE Subsequent to operation . 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ~ 17. I hereby certify that the foregoing is true and correct to the best of mY knowledge. Si ned (/ ,-.,,~--'-- Title Environmental Engineer Fogrm 10-404 Rev 06/15/88 Roy D. Robert .. 4~9B' . ~466 ~350' ' . ~565 ~5~3 ' ~595' 45B0' ~ ~37' 47~0' . 5050' 5030' 3~97' ' 3345' 35~3 ' 3535' 355%' 365%' ~ 39~9' 39%0' RECEIVED OCT 2 ~ ]989 Naska Oil & Gas Cons, Commission .... .~,~ ~chorage ~3-3/8" 6~ J-55 1075' 9-5/8" 47~ N-80. WINDOW 1695'- 1758' KOP O 1700' TOTAL SAND IN PLACE 91 SACKS OF 20-40 MESH OTTAWA SAND 120% of THEORETICAL 7" 29# N-80 ti~ 5450' 1 J2 J 3 5 8 TUBING DETAIL 2-7/8", 6.4#, N-80 TBG BT&C. 1) OTIS BALL VALVE AT 322' 2) 6LM AT 1025', 2470', 3435' .3) OTIS XA SLV AT 3472' 4) OTIS "VST" PACKER AT 3492' 5) OTIS XA SLY AT 4058' 6) OTIS "X" NIPPLE AT 4090' 7) BAKER SC-1L PACKER AT 4124' 8) 559' 4217'-4776' OF 3-1/2", 9.2#, J-55 WWS .012" 9) BAKER SC-IL PACKER AT 4777' °'B" ZONE SQUEEZED WITH CEMENT 3515'-3550' 3698'-3745' 3788'-3810' 3930'-3975' "B" ZONE INTERVAL 4280'-4298' 4320'-4342' 4350'-4466' 4513'-4565' 4580'-4595' 4720'-4757' 5030'-5050' JUNK ~ 5392' ETD FLOAT COLLAR ~ 5404' WELL TBS A-24RD PRODUCER WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL)I DRAWN: CLL SCALE: NONE DATE: 8-25-§9 UNOCAL DRILLING REC¢ ALASKA REGION PAGE NO. 1 of 4 LEASE Trading Bay State WELL NO. A-24 RD FIELD Tradinq .Bay State DATE E.T.D. 08-08-89 5398' 08-09-89 08-10-89 4572' 08-11-89 " 08-12-89 5405' 08-13-89 3530' 08-14-89 3998' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Accept rig @ 1200 hrs 08-08-89. Rig up Myers wireline & test to 3000 psi. Pull ball valve. Run 2.25" swedge to 3600' & POOH. RIH with pulling tool and attempt to latch gas lift valve with negative results. Rig up Schlumberger & RIH with perf gun #1. Perforate tubing 3436' - 3438' with (7.) holes. POOH. Attempt to circulate with negative results. Rig up Schlumberger & RIH with perf gun #2 & attempt to perf 3236'. POOH, misfire. Rewire gun & change shooting module. RIH with perf gun #2, perforate 3236'. Change well over to FIW 3%KCL set BPV and remove tree. Install BOP & test. Pull seals from packer & CBU. POOH. Laydown 2-7/8" tubing & production equipment. Change upper & lower pipe rams to 3-1/2". Test all BOPE. RIH with packer retrieving tool & tag Baker Model "D" packer at 3501'. Mill over & retrieve packer. RIH with 6" bladed mill & boot sub. Tag sand/junk @ 4122'. Clean out 4122' - 4572'. Unable to clean out past 4572'. POOH. RIH with reverse circulating junk basket and mill overjunk 4572' - 4575'. POOH, no recovery. RIH with 6" bladed mill and mill on junk at 4572' with no progress. RIH with 5-3/4" wash pipe to 4572' Wash over junk to 4598' circulate clean and POOH. RIH with roller dog overshot on bottom of wash pipe to 4572'. Circulate bottoms up & set down at 4596'. POOH, no recovery. RIH with 6" mill and clean out sand & junk 4596' -5405'. Circulate clean. POOH. RIH with 7" casing scraper to 5390' and circulate bottoms up. Rig up Schlumberger and run CBL/VDL/GR from 5220' - 3508'. RIH with junk basket & 5-3/4" gauge ring to 4100'. POOH. RIH to 3998' DIL with EZSV bridge plug & set. Rig up HOWCO & test lines to 2000 psi. Mixed and pumped 110 SX "G" cement with 0.5% HALAD-344, 0.2% CFR-3, .03% LWL at 116 PCF (15.6 PPG). Cement in place at 1330 hrs. POOH. Well taking fluid more than calculated fill. Decided not to bradenhead squeeze. RIH with 6" bit to 2500'. Wait on cement. Tag cement at 3530'. WOC. Attempt to test casing - negative. Clean out cement 3530' - 3990'. CBU. Attempt to test casing - negative. POOH. Rig up HOWCO & test lines to 1500 psi. Mixed and pumped 115 SX equalized plug "G" cement with additives (as 08-13-89) across upper "B" perfs. POOH to 2780' & bradenhead squeeze 2.7 BBL's cement with 500 psi. Cement in place at 1330 hrs. Wait on cement. RIH tag top of cement at 3395'. Test casing to 1500 psi, bled from 500-50 psi in 5 minutes. UNOCAL DRILLING ALASKA REGIOh PAGE NO. 2 of 4 LEASE Trading Bay State WELL NO. A-24 RD FIELD Trading Bay State DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 08-15-89 3999' Clean out cement 3395' - 3999'. Attempt to test casing, negative. Rig up HOWCO and test lines 1500 psi. Mixed and pumped 120 SX equalized plug of "G" cement with additives (as 08-13- 89). POOH to 2809' and bradenhead squeeze 3.5 BBL's @ 1200 psi. Cement in place 1130 hrs. Wait on cement. 08-16-89 5395' Clean out cement 3410' - 3575'. Pressure test the casing to 500 psi for 30 minutes, OK. Clean out cement 3575' - 3760'. Pressure test to 550 psi and bleed to 460 psi in five (5) minutes. Clean out cement 3760' - 3900'. Pressure test to 500 psi and bleed to 250 psi in five (5) minutes. Clean out cement 3900' - 3990'. Pressure test to 500 psi and bleed to 390 psi in five (5) minutes. Clean out cement to EZSV at 4010'. Circulate bottoms up. Change well over to clean FIW with 3% KCL. Drilled out retainer at 4010'. RIH to 5395'. CBU. 8/17/90 8/18/89 8/19/89 POOH. RIH with 6" bit, 7" casing scraper and 7" wire brush to 5395'. Circulate and filter fluid. POOH. RIH with Baker 4-1/2" TCP gun assembly. Bottom of guns stopped at 4290' with Baker packer at 3727'. Free up the hole, stopped solid at 3727' down. POOH. Perform weekly BOP test, replaced Hydril element and tested, OK. RIH with 6" bit, boot basket, drill collar, 5-1/4" x 6" watermelon mill and dress 7" casing 3730' - 3802'; 3956' - 4018'. POOH. Make up TCP gun assembly. RIH with TCP guns. Rig up Schlumberger and ran GR/CCL depth log, positioned guns and set packer, relogged interval, OK. Dropped the bar, no indication guns fired. RIH with wireline to catch firing bar, found bar on ported disc, attempt to retrieve bar when guns fired. Perforated "B" Zone: 4280'-4298'; 4320'-4342'; 4350'-4466'; 4513'-4565'; 4580'-4595'-, 4720'-4757' DIL. Retrieve firing bar, unseat packer, CBU and 20 PPM H25 on bottoms up. POOH. RIH with bit and scraper to 5395' circulate and filter fluid POOH RIH , · · with 7" Baker "K-i" drillable bridge plug to 4880'. UNOCAL DRILLING RECO ALASKA REGION PAGE NO. 3 of 4 ,, LEASE Trading Bay State WELL NO. A-24 RD State FIELD Tradinq Bay DATE E.T.D. 08/20/89 4615' 08/21/89 4520' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Broke circulation, dropped setting ball, pressured to 2000 PSI and B.P. set at 4880'. Unable to shear off B.P. Worked string loose and POOH. RIH with open ended 3-1/2" tubing and spot 15 sacks of 20-40 mesh sand, top of sand at 4816'. RIH with Baker "EA" packer and tubing tail set at 4649' and 4687' respectively. Obtained injection rate of 11 BPM at 3750 PSI, total 47 BBL pumped. Pumped 50 BBL's of 70 PCF gelled pre pad (400 cps) at 12 BPM and 3750 PSI. Pumped 25 BBL's (80 sacks 20-40 mech Ottawa sand) of 12 PPG slurry at 12 BPM and 3500 psi. Displaced tubing with 34 BBL's of 70 PCF gelled after pad at 12 BPM and 4000 psi. ISIP = 2500 psi, FSIP = 700 psi after 1 hour. Total 73 sacks of sand in place. POOH. RIH with O.E. 3-1/2" tubing, tagged sand at 4735'. Spot 21 sacks of sand and tagged top of sand at 4615'. POOH; RIH with Baker "EA" packer and set at 4493'. Obtain injection rate, negative, communication above packer. Reset packer at 4480', 4475', and 4470'. Communication above each set. Released packer, 30M# over pull while working to 4440'. Lost 20M# string weight. RIH feeling for possible fish, NEGATIVE. POOH. Tubing string and packer intact, lay down Baker packer, releasing mechanism bad. Wait 2-1/2 hours for HOWCO RTTS packer. RIH with RTT$ packer attempt to set 4485', 4475', NEGATIVE, communication above each set. POOH. RIH with O.E. tubing and spot 31 sacks sand (20-40 mesh Ottawa). 8/22/89 4880' Tagged top of sand at 4520'. POOH. RIH with 7" RTTS packer and set at 4239' with tubing tail at 4250'. Obtained injection rate of 13 BPM at 3250 psi, total 36 BBL's pumped. Pumped 100 BBL of 70 PCF gelled pre pad (400 cps) at 12.5 BPM and 3000 psi. Pumped 50 BBL's (160 sacks 20-40 mesh Ottawa sand) of 12 ppg slurry at 14 BPM and 2800 psi. Displaced tubing with 31 BBL's of 70 PCF gelled after pad at 15 BPM and 3000 psi. ISIP = 1050 psi FSIP = 675 psi after 2 hours. POOH. RIH and tagged top of sand @ 4386'. Actual sand in place 131 sacks. Cleaned out sand 4386'-4880'. UNOCAL DRILLIN~ RECC ALASKA RE~ION PA~E NO. , 4., . of 4 LEASE .... Trading Bay State WELL NO. A-24 RD State FIELD Trading Bay DATE E.T.D. 8/23/89 5392' 8/24/89 8/25/89 5392' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Drilled out bridge plug at 4880'. Continued to clean out to 5392'. Spot hi-viscous sweep and changed wellover to clean FIW with 3% KCL. POOH. RIH and set Baker model "D" (7" x 3.5") sump packer on tubing at 4777' DIL. POOH. Make up and run 17 joints, i pup joint (total 559') of 3 1/2" 9.2#, J-55, .012" wire wrapped screen liner, with Baker "SC-iL" (7" x 3.5") packer assembly on 3-1/2" tubing with 2-1/16" CS Hydril tubing tail pipe (concentrically within 3-1/2" liner). Snap in and out of sump packer @ 4777'. Break circulation, snapped into packer, wire wrapped screen 4218'-4777' DIL and Baker SC-iL packer at 4124', set the packer and hydraulically release from the packer. Rigged up and tested B.J. lines to 3000 psi, OK. Pumped 10 BBL's gelled pre-pad (350 cps), 31 bbls of 10 PPG slurry (90 sacks 20-40 mesh Ottawa sand) at 3 BPM, 5 BBL's gelled after pad. Displaced with FIW with 3% KCL at 0.5 BPM and 2200 PSI. Reversed out approximately 12 sacks sand, 79 sacks sand in place, 105% of theoretical. Wait 3 hours and tested pack at 3 BPM and 550 PSI. Re-pack $1, pumped 3 BBL's pre-pad, 7 BBLS of 10 PPG slurry (20 sacks) at 2 BPM, 3 BBL's gelled after pad. Displaced tubing, final pressure 2450 psi at 0.25 BPM. Reversed put approximately 8 sacks sand, total sand in place 91 sacks, 120% of theoretical. Waited 2 hours, test pack to 1800 psi, closed and tested port collar to 2000 psi for 5 minutes, ok. POOH. Ran Schlumberger Photon log 4050'-4825' DIL, no voids. Make up and set Baker 4" x 2.3" seal assembly at 4124', "X" nipple at 4090', "XA" sleeve at 4058' and Otis "VST" packer at 3492'. Tested packer and annulus to 1000 psi for 5 minutes, ok. POOH. Ran 2-7/8" production tubing and equipment, stabbed into "VST" packer and landed production string as follows: seal assembly 3492'-3504', "XA" sleeve at 3472' GLM at 3435', 2469', 1024' and ball valve at 322' with BPV in place. Remove BOPE, install 3-1/8" x 10" -SM CIW tree and tested to 5000 psi for 15 minutes, ok. Released rig at 2400 hrs. Well atp '¢ R~O ~ U,.¢ Kelly / ~ e,~ pr.lure ~~ ' ~oke'mlnlfold ~ 'T.~ Oretsure~% ~ ---._ .: ~-. .. · ~ ' ' ldJUl~ibll ohoke~ ~ Oil & GaS Cs~s. OCn~sslO~ STATE OF ALASKA COMIC" .~ION A~': .~KA OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Name of Operator ~ 5. Type of Well: _~ 2. Union 0il Company of California (UN(~CAL) D_evel.°Pment"~ · ~xploratory __ Address ! Stratigraphic ~ 3. P.O. Box 190247, Anch, Ak., 99519-0~47 Service__ 4. Location of well at surface 1620'N & 574'W from SE cot., Sec. 4, TgN, R13W, SM At top of productive interval 895'S & 1726'W of Surface Location; 3515' MD, 2719' TVD At effective depth 1257'S & 2795'W of Surface Location; 5398' MD, 4221' TVD At total depth 1263'S & 2821'W of Surface Location; 5450' MD, 4265.. ' TVD Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Pedorate .~ Other 6. D'"-'--atum elevation (DF or KB) RT 101' MSL 7. Unit or Property name Trading Bay Field 8. Well number 'lBS A-24 RD 9. Permit number 81-40 10. APl number 50-- 733-20266-01 11. Field/Pool Tyonek "B" Zone 12. Present well condition summary Total depth: measured true vertical 5450 ' feet Plugs (measured) 4265 ' feet feet Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 5398 ' feet Junk (measured) 4221 ' feet Length Size Cemented '7507' measured true vertical 1075' 13 3/8" 1350 SX 1695') 9 5/8' 1300 SX 450' 7" 1225 SX *Window in 9 5/8" csg ~ 1695' See Attached ~bing(size, grade, and measumdde~h) 2 7/8", 6.4#, N-80 ~ 3505' Pac~rsandSSSV~ypeandmeasuredde~h) Baker Model "D" Perm Packer $ 3495'. 13. Attachments Measured depth True vertical depth 1075' 1049' 7507'* 5080' 5450' 4265' Description summary of proposal , CEI.VED . DJ/.& Gas Cons. Otis "DK" Ball Valve ~ 288' Detailed operations program ~ BOP sketch X 14. Estimated date for commencing operation ~ 15. Status of well classification as: February, 1989 16. If proposal was verbally approved Oil ~ Gas __ Suspended __ Name of approver Date approved~ the foregoin;]om~g~m u /~ /~./.~/__..~i~ th.e best of my knowledge. 17. I hereby certify that '~2~', ~~~..~'''~ Environmental Engineer Date 01/17/89 Conditions of approval: Notify Commission SO re'-"~resentative may witness r i Approval No. ,~ _ Plug integrity __ BOP Test __ Location clearance __ /, _ ~/ Mechanical Integrity Test __ Subsequent form required 10- ~ App,oved Copy Returned ORIGINAL SIGNED BY ~ Approved by order of the Commission~0NNIE C, SMITH Commissioner Form 10-403 Rev 06/15/88 Date SUBMIT IN TRIPLICATE IV 24.-6 _26-7 28,6 3 .8 33-6 ~1-8 'd qU£O± CASING & ABANDONMENT DETAIL I.) Rotary Table MeaaUtement at O.00' II.) Tublng Hanger at 3?.25° IlL) 13 318% 614% J-55 Casing at 1075' .IVJ Window in 9 618', 47~, N-80 Casing from 1695' to 1758' with KOP at 1700' V.) 7', 29~,° N-80 Casing at $450' TUBING DETAIL 2 7/8~ 6.4-~, N-80 TUBING 1.) 2 7lB' Otla 'DK' Ball Valve at 288.41° 2.) 2 718' Camco 'KBMG' Gas Lift Mandrel at 2472.10' ~3.) 2 7/8' Camco 'KBMG' Gas Lift Mandrel at 3466.66' 4.) Locater Sub at 3493.95' 6,) Baker Model 'D° Packer wi[h Seal Assembly · from 3495.00' to 3503.03' 6.) Bottom of Mule Shoe at 3505.65' 'PERFORATION RECORD INTERVAL . 4530'-4550° 4375°-44O5. . 3945'-3B60' · 3720'-3735' 3515°-3535' · "5030'-5050! 4720'-4757' 4580'-4595"' ', 4513'-4560' e · DA TE 5129/81 §/~0181 5/31/81 6/01/81 110918S 1/09/85 1/09185 ~09/85 , . -'1.te9-/8'~! ,~-~o.~7 CONDITION Frae-Packed 33-6 Sand J=rac-Packed 31-8 Sand Frac-Packed 28-6 Sand Frae-Packed 26-7 Sand Frac Packed 24-6 'Sand Production 44-7* ·Sand Production 41-8 .Sand Production 40-4 S.,,,nd · Reperf 33-6 Sand ' · WELL TBS A-24 FiD WELL SCHEMATIC UNION--'OIL COMPANY OF CALIFORNIA ICHOKE MANIFOLD !sEE DRAWING ANGLED FILL UP LINE -. HYDRIL HYDRAULIC ' PIP,E, RAMS GATE } GATE GATE ~ KILL LINE OM MUD PUMF TO MUD PUMPS & CEMENT UNIT ,: : ': & CEMENT UN ~ ~0 BLIND RAMS · -'- --~ NTRA C TOR FURNISHED OPERA TOR FURNISHED WELL NAME: RIG CONTRACTCR: RIG: STACK PRESS URE RATING: CHOKE LINE SIZE & · NOTE: ALL CHANGES MUST HAVE WRITTEN AFPROVAL BY THE DISTRICT DRILLING SUPERINTENDENT NOTES: 1. HYDRAULIC VALVES OPEN AUTOMATICALLY WHEN DIVERTER IS CLOSED. 2. FLEX HOSE (///) IS TO BE user IF NECESSARY WITH DDS" APPROVAL. ...... .-- '-, .....- :-- DEPT. APPROVAL B_=~A ._~, ~; 6/:7186 ., 135/8: EOFE STACK 5M O.R IOM ALL WORKOVEF, OPERATIONS UNION OIL COIv..:.', .':' OF CALIFORNIA Attachment Trading Bay State TBS A-24 RD Description Summary of Proposal 1. Move in and rig up. 2. Kill well. 3. Install BPV's, remove tree, install and test BORE. 4. Pull and lay down existing 2 7/8" completion. 5. Hill over and recover permanent packer set at 3495'. 6. Isolate and squeeze cement the following perforations: 3515' - 3550' 3698' - 3745' 3788' - 3810' 3930' - 3975' Clean out squeeze and test. Continue cleaning out to TD at 5398'. 7. Tubing convey perforate the existing perforations at 8 SPF. 4280' - 4298' 4320' - 4342' 4350' - 4466' 4513' - 4565' 4580' - 4595' 4720' - 4757' 5030' - 5050' 8. RIH with a sump tacker and set at 4780'!. Set 3 1/2" wire wrapped screen centralizers and production packer from 4780' to 4240'. 9. Gravel pack the zone through a bypass tool, squeeze pack and repeat squeeze as necessary. 10. Clean out to TD 5398'. 11. Run a single production string of 2 7/8" tubing and packer. 12. RDMO. Place well on production. Note: Anticipated SBHP is 1300 psi. 0019n/103 MD 3515'- 3550' 3698' - 3745' 3788' - 3810' 3930' - 3985' 4280' - 4298' 4320' - 4342' 4350' - 4466' 4513' - 4565' 4580' - 4595' 4720' - 4737' 5030' - 5050' TBS A-24 Perforation Record TVD 2719' - 2746' 2857' - 2892' 2922' - 2940' 3031' - 3072' 3297' - 3311' 3328' - 3345' 3351' - 3443' 3480' - 3523' 3535' - 3547' 3651' - 3581' 3910' - 3927' 0019n/102 STATE OF ALASKA ALA ,, OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS /' 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 190247, Anch, Ak., 99519-0247 4. Location of well at surface 1620'N & 574'W from SE cor., Sec. 4, TgN, R13W, SM 5. Datum elevation (DF or KB) RT 101' MSL Feet 6. Uniter Property name Tradinq Bay Field 7. Wellnumber TBS A-24 RD Attop ofproductiveinterval 895'S & 1723'W of Surface Location Ateffective depth 1257'5 & 2795'W of Surface Location AttotaldeDth 1263'S & 2822'W of Surface Location 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5450' feet 4265' feet 5398' feet 4221' feet Plugs (measured) Junk (measured) 8. Approval number 9. APl number 50-- 733-20266-01 10. Pool Trading Bay "B" Casing Length Structural Conductor Surface 1075' Intermediate 7507' Production 5450 ' Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size Cemented 13 3/8" 1350 sxs 9 5/8' 1300 sxs 7" 1225 sxs *Window at 1695' Measured depth True Vertical depth See Attached Packers and SSSV (type and measured depth) 1075 ' 7507' * 5450 ' 1049' 5080' 4265' 12. Stimulation or cement squeeze summary RECEIVED 2 7/8", 6.4#, N-80 $ 3506' O0mmissi0a 'Naska 0il .& 6as Cons. ,.~! Anchorage Otis Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 0 0 0 89 156 17 Casing Pressure Tubing Pressure 115 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~~' R/~~oy D. Roberts Title Env±ronmental Engineer Datt~6/Z1/88 Form 10-404 Rev. 12-1-85 Submit in Duplicate ~, Nov. 12, 1987 Nov. 13, 1987 Nov. 14, 1987 Nov. 15, 1987 Nov. 16, 1987 TBS A-24RD WORKOVER HISTORY MoveO in coil tubing equipment. Rigged up lubricator and BOPE. Tested all equipment to 300 and 4000 psi. Made up 2 1/4" bit and 1 3/4" dyna-drill and ran in the hole to the bottom of the tubing at 3505'. Pumped diesel at 1/2 BPM and POOH. Laid down bit and Dyna-Drill. Made up 2 1/4" wash nozzle and RIH to 3505'. Plugged the production choke and lost returns. POOH and unplugged choke. RIH with 2 1/4" wash tool and tagged fill at 4625'. Cleaned out fill to 5100' with diesel and poly-vis sweeps in 100' intervals. Circulated 25 bbl sweep at 5100' Circulated bottoms up and POOH. Shut in well overnight t~ monitor production and fill. RIH and tagged fill at 4679'. Cleaned out to 5398' with diesel and poly-vis sweeps. Found a hole in the coil tubing at 5350'. Pulled to 5185' and circulated bottoms up. POOH while circulating. Rigged down lubricator, BOPE and coil tubing . Rigged up wireline unit, RIH and tagged fill at 4641'. Ran 2 1/4" gauge ring to 3300'. RiggeO down wireline unit. Rigged up coil tubing unit, BOPE and lubricator. Pressure tested the equipment. RIH and cleaned out fill from 4560' to 5398' with diesel and poly-vis sweeps. Surface equipment plugged with sand. POOH and removed 2 1/4" wash nozzle. RIH and found fill at 4550'. Cleaned out to 5398'. Found hole in the coil tubing and POOH. Coil tubing posted at 5250'. Recovered coil tubing in the well. Rigged down the lubricator and shut well in. Rigged down and moved coil tubing unit off the platform. RIH with wireline and tagged fill at 4450'. Rigged down wireline unit. 2617p/59 MD · , 35!5~ - 3550' 3698' - 3745' 3788' - 3810' 3930' - 3985' 4280' - 4298' 4320' - 4342' 4350' - 4466' 4513' - 4570' 4580' - 4595' 4655' - 4665' 4703' - 4780' 5030' - 5050' TBS A-24 RD Perforation Record 2719' - 2746' 2857' - 2892' 2922' - 2940' 3031' - 3072' 3297' - 3311' 3328' - 3345' 3351' - 3443' 3480' - 3527' 3535' - 3547' 3597' - 3605' 3636' - 3701' ~10 - 3927 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate EkOther]~l 2. Name of Operator Union Oil Company of California 3. Address P. O. Box 190247 Anchorage, AK 99519-0247 4. Location of well at surface 1620'N & 574'W F./ S.E COR., SEC 4 T9N, R13W, S.M. At top of productive interva~ 95 'S .& 172~'W of surface location teffect,ve aei:)~ h 257 'S & 2795'W of surface location t total depth !263'S _~ 2822'~7 of _~,_,rf=_ce location 11. Present well condition summary Total depth: measured feet true vertical feet 5. Datum elevation (DF or KB) RT 101 ' MSL feet 5450 ' 4265 ' Effective depth: measured feet true vertical 5398' feet 4221 ' Casing Length Size Structural Conductor Surface Intermediate Production Liner *~9~o~ ~9~.' measured Plugs (measured) 6. Unit or Property name Trading Bay Field Junk (measured) 7. Well number m~ ~ ~A ~ 8. Permit number true vertical 9. APl number 50-- 10. Pool Cemented Measured depth True Vertical depth 1075' 13-3/8" 1350 SX 1075' 1049' 7507' 9-5/8" 1300 SX 7507'* 5080' 5450' 7" 1225 SX 5450 4265' SEE ATTACHED RECEIVED Oc, 0 ? 1987 Tubing2_7/8.(size,, grade6.4# and, N-80measured@ 3506depth)' Alaska 0il & (]as Cons. Commission Packers and SSSV (type and measured depth) Anchorage Baker Model "D" Perm Packer @ 3495'. Otis "DK" Ball Valve @ 288' 12.Attachments Description summary of proposal K] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 14. If I~'~l~G~as"'Ger~y' approved Form No. ~Dated ~_/~.~ Name of approver Date approved 15. I hereby certify that the foregoing is true an~ c,~rr~ct to the best of my knowledge Signed KD/~×/y~'. ~/~' %Witle Enviro=ental Engineer ~ ~ ' w ~ommission Use Only Roy D. Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance ~-- 7~' d Approved by Form 10-403 Rev 1[~4-8~ by order of the commission Date / ~ "..~--~:~ 7 Submit in triplicate TBS A-24 RD Perforation Record 3515' - 3550' 3698' - 3745' 3788' - 3810' 3930' - 3985' 4280' - 4298' 4320' - 4342' 4350' - 4466' 4513' - 4570' 4580' - 4595' 4655' - 4665' 4703' - 4780' 5030' - 5050' 2719' - 2746' 2857' - 2892' 2922' - 2940' 3031' - 3072' 3297' - 3311' 3328' - 3345' 3351' - 3443' 3480' - 3527' 3535' - 3547' 3597' - 3605' 3636' - 3701' 3910' - 3927' 0384N RECEIVED OCT 0 ? 1987 Alaska Oil & Gas Cons, Commission Anchorage TBS A-24 PROCEDURE: 1. Retrieve ball valve with slickline. 2. Clean out fill using viscosified diesel and coiled tubing. at 4378' (1020' of fill). 3. Reperforate existing intervals with thru-tubing guns. 4. Return well to production Fill is TIME: 6 Days 0384N RECEIVED OCT 0 7 1987 Naska Oil & Gas Cons. Commission Anchorage Union Oil and Gas ~ ion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone- (907) 276-7600 unl,l n January 3, 1985 Mr. Chat Chatterton Alaska Oil & Gas Conservation Commission 3001Rorcupine Drive Anchorage, AK. 99501 SUNDRY NOTICE TBS A-24RD Dear Mr. Chatterton: Attached for your approval is a Sundry Notice to Rerforate A-24RD, Trading Bay State. The attached work is scheduled to commence on Oan 8, 1985. Rlease return the approved Sundry Notice to the undersigned. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL TECHNICIAN LOC/tj Attachment RECEIVED Alaska Oil & Gas Cons. Commission Anchorage K~[ ..... STATE OF ALASKA g,]'i ALAS ~,~L AND GAS CONSERVATION 41MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator UNION 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4, Location of Well 1620'N & 574'W of SE Corner, Sec. 4, TgN, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) KB 101' MSL 12. 6. Lease Designation and Serial No. ADL 18731 7. Permit No. 81-40 8. APl Number 50- 733-20266-01 9. Unit or Lease Name Trading Bay State 10. Well Number TBS A-24RD 11. Field and Pool Trading Bay Field Middle Kenai 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). Perforating Procedure: 1. Rig up lubricator over well. Pressure test to 2000 psi. 2. Shut-in welI to run the 20' 2-1/8" hollow carrier guns to bottom and locate guns across proposed interval. 3. Rlace well on production for 15 minutes prior to perforating. Shut-in well 5 minutes after ~guns have fired. P.O.H. 4. Perforate the following intervals with 4 HPF; 0° phasing. Sand Interval Length 44-7 5050'-5030' 20' 41-8 4757'-4720' 37' 40-4 4595'-4580' 15' 33-6 4560'-4513' 47' 31-8 4466'-4350' ll6' TOTAL 235' 5. Rig down lubricator and return well to production slowly. Signed LAWRENCE O. CUTTING Title ENVIRONMENTAL TECHNICIAN The space below for Commission use Date 01/03/85 Conditions of Approval, if any: Approved by l~J L~,~!E C. $11rl'l COMMISSIONER Approved Copy Returned __/- 7 By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Gas ~,~.ision: Western Region Union Oil Company b~ t.,alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 DOCUMENT TRANSMITTAL union January 14, 1983 Hand Delivered TO: Ms. Fran Sones LOCATION: 3001 Porcupine Drive Anchorage, AK 99501 FROM: R.C. Warthen LOCATION: Alaska District Transmitting: REFERENCE: Monopod A-24 RD One (1) directional survey, dated May 26, 1981 - job #4768 PLEASE ACKNOWLEDGE R~EIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL THANK/~f~IU ./-- ~ ~ m r, ,.= RECEIVED BY. DATED: ,,.., ....... ,-,,,,~,~ u. ~ ~as Cons. Cornn]iSsion ~chorage 'A(',' STATE OF ALASKA ~I', ALASK '~' AND GAS cONSERVATION C '''~llSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. UNION OIL CONPANY OF CALIFORNIA 81-40 3. Address 8. APl Number P0 BOX 6247 ANCHORAGE AK 99502 5o- 733-20266-01 4. Location of Well 1620'N & 574'W of SE corner, Sec. 4, TgN, R13W, 5. Elevation in feet (indicate KB, DF, etc.) KB 101' MSL 6. Lease Designation and Serial No. ADL 18731 9. Unit or Lease Name TRADING BAY STATE 10. Well Number TBS A-24 RD 11. Field and Pool TRADING BAY HIDDLE KENAI 12. 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). The coordinates of the TBS A-24 RD well should be corrected as follows: Location of well at surface: 1620'N & 574'W of SE corner, Sec. 4, TgN, RI~W, SH. At Top Rroducing Interval: 72~'N & 2~O0'W of SE corner, Sec. 4, TgN, R13W, SH. At Total Depth: · 357'N &'3396'W of SE corner, Sec. 4, TgN, R13W, SM. RECEIVED DEC 0 2 ]982 Alaska 0il & Gas Cons. Commission Anchorage 14. I here,l~ certify that the foregoing is true and correct to the best of my knowledge. Signed Title/9 District Drlg Superintendent Date The since bel°w f°r C~mmissi°n use C~/r) tions of ApproVal, if any: 11/24/82 By Order of Approved by COMMISSIONER the Commission Form 10-403 Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate GAS CONSERVATION ISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG ., 1. Status of Well Classification of Service Well · OIL [] GAS;[~ SUSPENDED [] ABANDONED [] SERVICE I-l. 2. Name of Operator 7. Permit Number UNION 0I! COMPANY DF CAI TFflRNTA 81-40 3. Address 8. APl Number ~ 909 W. 9TH AVE., ANCHORAGE, ALASKA B0-733-202,66-01 4. L°cati°n°fwellatsurface]620'N & 574' W of S.E., Cor. Sec 4, T9N, 013 9. Unit or Lease Name W, S.M. Trading Bay State At Top Producing lnterval 820'N & 2240'N of S.E. Cor. Sec 4, T9N, R13W, lO. WellNumber S.M. TBS A-24RD At Total Depth 510'N & 3320'W of S.E. Cor. Sec 4, T9N, RI3W, ~. Field and Pool S.M. Trading Bay - Middle 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kenai 101' KB above MSL APL #18731 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 5-16-81 5-22-81 6-3-81 62' feet MSLI 1 · 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 5450 MD HA67 ~ 1700 MD YES)~]] NO[] :2.88 feetMD --- 22. Type Electric or Other Logs Run CBL-VDL GR w/ CCL, DI~L-SP-GR, FDC-CNL-GR, BHC-Sonic-GR, & CBL-VDL-WF w/GR & CCL. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD · CASING SIZE WT..PER FT. GRADE TOP .. BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED '13 3/g,, 61# KJ-55 surface 1075 c~ 5/g" ,- ,47~ N-gO Surface 1695 7,, 29" N_80 Surface 5450 8 1/2" 1225 sxs . Milled ~indow in 9 5/8" casing 169!;'-1752' - K.0.P. 1700' 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) 4530'-4550' 2 7/8" 3505' 3492' 4375'-4405' 3945'-3960' 26~ ' '~;' ACID, FRACTURE, CEMENT SQUEEZE, ETC. 3720' ' -3735. · DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ' ,' 3515'-3535' ' '~530"~4550' 13000# ·Mesh S.d' 80000#.~20.40._S 4375'-4405' ' " " '" 67000# '" " .... ....... 3945'-3960' " " " 80000# " " ' ..~ 3720'-3735' '" '" " 80000# "''~ " 27. PRoDUc'TIONTEST 3515-3535' 93000# sd Date First Production ,, '~1 Method of Operation (Flowing, gas]ift, etc.) 6/4/81 -I Gas' Lift . Date of Test Hours Tested PRODUCTION FOR OI L-BBL GA$-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO I 6/15/8] 8 . ~, TEST PERIOD I~ .43 40 0 47/64 931 Flow lZubjng, ,, Casing Pressure CALC'ULATED' OIL-BBL GA'S-!VtCF WATER-BBE OIL GRAVITY-APl (corr) ].Press. 233 ~ 500,-' 24'HOUR RATE I1~: 130 121 0 21 7 28. CORE DATA · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.· : ' ', ,,.-. - - ' RECEIVED . ,' ....... AUG 1 4 198] "A~aska 'Oil & Gas Cons. Commission . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T/24-6 3485 2717 T/26-7 3695 2871 T/28-6 3919 3047 T/31-8 4320 3357 T/33-6 4508 4609 * TVD calculated from single ~hot. 31. LIST OF ATTACHMENTS 32. I hereby ~'~that the foregoing is true and correct to the best of my knowledge ~ / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which el'evation is used as reference (where not otherwise shown) for depth measurements. given in other spaces on this'form and in any attachments. ':": Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 , UNiCa-,: ©II.. CO. WELl_ I :[zcORID ,. ,,^¢'h' TradinqL Bav State V/ELI, NO. A-24RD :'f.C!,D Tradinq Bay ,OCATl©N1620' N & 574' W of S.E. Corner Sec. 4, T9N, R13W, S.M. SI-I Ei:T A " PAG[.: NO.__ .. .. SPUI) DATE 5-16-81__ COMP. DATE 5-22-81 CO?,FUI~AC'FOi~, P~k~ RIG NO ....... TYPE UNiT 860 Oilwell ,., ,;,~- ,, ,,-, - 7" 19~ g_8-135 DRII..,L Pi~ ~ D,,oCt,If I ION 7" q- ELEVATIONS: %VATEI[ DEFI'iI 62' -~Ei'~MI'£ NO. 81-40 SFRIA.L NO. ADL 18731 IL T. '.to OCEAN FLOOR 174' I'.D. 5450 ~D T.V.D. 4250 VD II.T. TO },ILI, W 112'. ,. n.'n'ro, mut,n Dzgf'l DEVI,\TION (B.If.L.) It.'I. iO I'R,~J,:i~!'l"l'~mw:~-/ 40.82"/// ,'1/ ,, '40.8 -,n.~,mx.~,v w.N~I-.,EER Watson-Boulware tel ,nw [O~,~._,. V ~ o X ~ T~ r. CA,>I~IG ,.~ TLBING } RADE DEl*TI{ REMAilKS :__S_LZ.s .... ~i., ~ ~ c. ~'r . w. a_-iT-r,,x v ___q 13 3/8' 61# . J-5 9" 5/8' 47# N-8 -' 7" " 29# Buttress N-8 ~iilled Window"'i~ 9 5/8 Casi %g 2_7~_~!~''' .6.. 4#" '_~uttress. N-8 . ..-.-~--.-.-. _.-- .... .-,-..~-. ~1 1075 1695 5450 1695'-1' 3505 See Previous History See preVious History Ont'd w/1225-SXS "6" plus additives ~52' - K.O~P. 17007: :Pkr. at 3492' ". · ' . PERFORATING RECORD ;-27z81 4530'-4550' Product!pn . ~rac-Packed 33~6 snd. i-2-~-8--T 4375"440~''- Production Frac-Packed 31-8 snd. · .. , , i-30-81 3945'-3960' Product_ton Frac-Packed 28-6 snd. ','31-81 3720'-3735' Product, ton Frac-Packed 26-7 snd. ' ;-01-8.1 3515'-3535' - " ''-~roduct_ton Frac-Packed 24-6 snd.' , , , , .... · . , , · DATE L-15-81 TYPE:~_ . IIITERVAI, CUT l on,,.ml N_E. T__C I L _ 130 0 I 21 .7 I 500 INITIAL PRODUCTION' 2_33 ~7/~4 W E_L.L H _EAD _A_S~Z~_J)zI B_ I.~Y 930 '8 b_~: test CASING HEAD: CASING HANGER:_ CIW ·12" x. 7" CASING SPOOL:: 12" 3000 x 12" 3000 TUBING HEAD: .CIN 12" 3000' x 10" 5600 psi DCm CIW 3 1/2" Single TUBING ttANGER:_ 3 1/2"8 md. TUBING tlEAD .TOP' MASTER VALVES' ~. 9.~16'' . . RECEll/EI MAR 1 9 I982. Alaska Oil & Gas Cons. Commission UiilOI.l OIL CO~:P/~Y ~ CALIFORRIA ~£LL RECORD S~;EET D LEASE Tradinq Bay St. t~ELL H0, x-~ FIELD Trading Bay DATE ETD I DETAILS OF PPEP&TI.OItS, DESCRIpTIOI!S ~ ,RESULTS I Fr~ID 3505.65 35'05.03 3495.00 3493.95 3463.58 3456.68 2479.00 2472.10 290.41 288.41 · 38.75 38.00 37.25 To 3505.03 3495.00 3493.95 3463.58 3456.68 2479.00 2472.10 290.41 288.41 38.75 38.00 37.25 --0-- 10.05 JTS 1.05 " 30.37 1 ' 6.90 9,77.68 32 6.90 2181,. 69 72 2.00 249.66 8 .75 .75 Tubing Detail Description !~ule Shoe Baker M~del "D" Pkr. & Seal Assbly. Locator Sub. 2 7/8" Butt. 6.4# N-80 Camco KBMG GLV 2 7/8" Butt. 6.4# N-80 Camco KBMG GLV 2 7/8" Butt. 6.4# N-80 Otis Ball Valve . _ 2 7/8" Butt. 6.4~ N-80 ir d XO 2 7/8 butt. x 3 1/8 8 Rnd. Cameron 3 .1/2 8rd. Hanger U[ilOI.l OIL Cg~P/~IY OF CALIFOR~.IIA ~ELL RECORD S~:EET D P^~E ~b, LEASE'_ Trading Bay St. DATE ETD ~ELL NO, ~-~-~m FIELD Trading Bay DETAI..L,S OF OPEPATIOf:tS, DESCRIP. TIOI-!S ~ .RESULTS 7- Casing. Detail Frc~ 5450.00 5448.13 5405.95 5404.20 38.00 To 5448.13 5405.95 5404.20 38.00 --0-- 42.18 1 1.75 · 5366.20 133 Description Shoe 7" 29# N-80 Float~ Collar 7" 29~ N-80 DATE A-24RD O! 9 5/8" 7505' 7" 9190 2 7/8" Ball Valve 288' · 13 3/8" 1075' Il l 9/8 Window 1695'-1752 nt Ret 1792' lm Camco EBMG 247~ Camco KBMG 3457 )cator Sub 3494 Pkr. 3495 ~ule Shoe 3505 7" 5450' Well Schematic Trading Bay Field A-24RD DRAWN __ CKD. APP'D. SCALE '~one D^~ 5--22--81 FORM 24? IN£W 5/66) UNION OIL COMPANY OF CALIFOP. NIA LEASE ADL 18731 UHIOI.I OIL Cfl'PA 'N OF CALIFOPJ.iIA WELL RECORD. . ELL HO, TBS A-24 RD FIELD StEET D PAGE ih, .... TRADING BAY FIELD DATE 1 5/12/81 DAILY cosT' ACC COST' AFE AMT' 2 5/13/8] · DAILY COST: ACC COST: AFE AMT: 3 5/14/81 DAILY COST' ACC COST' AFE AMT' 4 5/15/81 DAILY COST: ACC COST' AFE AMT: 5 5/16/8l DAILY COST' ACC COST: AFE AMT: 6 5/17/81 DAILY COST: ACC COST: AFE AMT' ETD 9200' TD 1792' ETD (Ret) 9 5/8" C. 7507' 7" L. 9190' $ 26,.862 $ 26,862 $2,050,000 1200' TD 1792' ETD (Ret) 9 5/8" C. 7507' 7" L. 9190' 63 PCF 350 SEC $ 32,028 $ 58,890 · $2,050,000 )200' TD 1792' ETD (Ret) 9 5/8" C. 7507' 7" L. 9190' 63 PCF 275 SEC $ 30,047 $-88,937 $2,050,000 9200' TD 1792' ETD (Ret) 9 5/8" C. 7507' 7" L. 9190' 71 PCF 70 SEC $ 27,251 $ 116,188 $2,050,000 1778'/83' 9 5/8" C. 7507' 7" L. 9190' 71 PCF 48 SEC $ 44,201 $ 160,389 $2,050,000 2191'/413' 9 5/8" C. 7507' 7" L. 9190' 71 PCF 45 SEC $ 35,716 $ 196,105 $2,050,000 DETA.IkS OF OpERATILOHS, DESCRIPTIOI.!S & RESUL.TS Commenced Operations O0:O1 hrs 5/12/81. In- stalled & tested BOPE to 2500 psi - ok..RIH w/ 8 1/2" bit to tag cmt @ 1707'. Circ & tes~ BOPE to 2500 psi - ok. CO cmt f/ 1707' to ret 792' rc c C L@BI_vDLCGRCi lean &~OOH. RU GO WL & ran f/ 1792' to surface. Log showea good. bonding. -RIH w/ 8 1/2" bit & prep to change over to ~ud. NOW' Mixing mud. Mixed gel mud and displaced hole w/ gel mud. POOH. RIH w/ Servco section mill #1. Cut section in 9 5/8" csg f/ 1695' to 1712'. POOH. RIH w/'mill #2. Recur section f/ 1710' to 1712'. Cut section f/ 1712' to 1722'. POOH. RIH w/ mill #3 and ream f/ 1717' to 1722'.- Cut section f/ 1.722' to 1724'. NOW' Milling's~ctiofi @-1724i.' Continue to mill window f/'1724' to 1726'. Trip for mill #4. Mill window f/ 1726' to 1734'. Trip for mill-#5. .Recut window f/ 1730' to 1734'. Mill window f/ 1734' to 1737'. Trip for mill #6. Recut window f/ 1736' to 1737'. Mill window f/ 1737' to 1740'. o NOW: Milling section ~'1740'.' Milled section f/ 1740' to 1752' Trip for mill - stopped @ 1750' -couid not get into stub. POOH. RIH w/ OEDP to 1767'. Circ & dropped vis of mud to 70 sec. Spotted 117 sx cl "G" cmt w/ 2% CaC12 and 5% sand. CIP @.17-00 hrs 5/15/81. Pulled to 1400' and rev out. POOH. Changed out drilling spool. RIH & tagged cmt @ 1500'. CO cmt to 1550' & tested BOPE - ok. CO cmt f/ 1550' to 1700'. Mixed and displaced gel-xc mud. POOH. RIH w/ dyna-drill & oriented 900 left of HS. Directionally drilled 8 1/2" hole f/ 1700' to 1778'. POOH w/ D/D. RIH w/ follow-up assembly - had slight ledge @ 1761'. Worked through. Directionally drilled 8 1/2" hole f/ 1778' to 1918'. POOH. RIH w/ bit #4 on BHA #5 (lO' pendulum) and dir. drilled 8 1/2" hole f/ 1918' to 2040'. POOH. RIH w/ bit #5 on BHA #6 (30' pendulum) and di~. drill f/ 2040' to 2191'. POOH. NOW' Repair shaker motor. LEASE S EET D U['IIOI.l OIL CC '?AIN OF CALIFOR{'iIA . · WELL RECORD PAGE ih....2 ADL 18731 'ELL NO, TBS A-24 RD FIELD TRADING BAY FIELD DATE 7 5/18/81 DAILY COST' ACC COST' AFE AMT' 8 5/19181 DAILY COST' ACC COST' AFE AMT' 9 5/20/81 DAILY COST' ACC COST: AFE AMT' 10 5/2]/8] DAILY COST' .ACC COST: AFE AMT' 11' 5/22/81 DAILY COST' ACC COST: AFE AMT' ETD 9200' TD 1792' ETD (Ret) 9 5/8" C. 7507' 7" L. 9190' 71 PCF 44 SEC $ 31,081 $ 227,186 $2,050,000 3223'/1032' 1700' KOP 9 5/8" C. 1695' 7" L. 9190' 72 PCF 40 SEC $ 28,269 $ 255,455 $2,050,000 3584'/361 ' 1700' KOP 9 5/8" C. 1695' 7" L. 9190' 73 PCF 40 SEC $ 41,408 $ 296,863 $2,050,000 ~276'/692' 1700' KOP 9 5/8" C. 1695' 7" L. 9190' 74 PCF 46 SEC $ 30,589 $ 327,452 $2,050,000 4918'/542' 1700' KOP 9 5/8" C. 1695' 7" L. 5450' 76 PCF 46 SEC $ 25,521 $ 352,973 $2,050,000 .DETAILS. OF OPERATiOHS, DESCRIP_TIO_~.!S & RESUI~TS RIH to shoe of 9 5/8" csg. Cut drlg line. Lost shale shaker motor. Replaced motor. New motor no good. Changed out motor 2 more times ' bolCh new motors no good. Sent 4 motors in for re- pairs. NOW' Instal. ling repaired motor. Finished installing new. shaker motor. RIH & directionally drilled 8 1/2" hole f/ 2191,' to 2821'. · Trip for bit #5. Directionally dril- led 8 1/2'.' hole f/ 2821' to 3223'. NOW' Drilling @ 3223'. Directionally drilled 8 1/2" hole f/ 3223' to~ 3353'. Trip for BHA. RIH w/ bit #7 on BHA #8 (30' pendulum). Directionally drilled 8 1/2" hole f/ 3353' to 3415' Trip for dyna-drill. RIH & oriented'dyna-dri]l 120° rt of high side. Dyna-drilled 8 1/2" hole f/ 3415' to 3476'' POOH. RIH w/. bit #9~6~ BHA #10' (30' belly). Reamed dyna-drill run f/ 3415' to 3476'. Di- rectionally drilled 8 1/2" hole f/ 3476' to 3584'. - NOW' Drlg @ 3584'. ' Directionally drilled 8 1/2" hole f/ 3584' to 3741'. Trip for BHA change. RIH w/ bit #10 on BHA #11 (locked up assembly) and direction- ally drilled 8 1/2" hole f/ 3741' to 4234'. POOH for BHA change. RIH w/ bit #11 on BHA #12 (13' pendul'um) and directionally drilled ~1/2" hole f/ 4234' to 4276'. : NOW' Drlg @ 4276'. · Directionally drilled 8 1/2" hole f/ 4276' to 4614'. POOH. RIH w/ bit #7 RR #1 on BHA #13 (30' pendulum) and directionally drilled 8 1/2" hole f/ 4614' to 4681'. POOH. RIH w/ bit #11 on BHA #14 (locked up assembly) and directionally drilled 8 1/2" hole f/4681' to 4918'. UI'IIOI.I OIL cg';PA ' Y · CALIFOg'iIA £LL RECORD S}[EET D PAGE ih. ---3 LEASE .Agl 1 8731 DATE 12 5/23/81 DAILY COST: ACC COST: AFE AMT: DAILY COST: ACC COST' AFE AMT: 14 5/25/81 DAILY COST: ACC COST: AFE AMT: , , 15 5/26/81 DAILY COST: ACC COST: AFE AMT: ·. 16 5/27/81 . DAILY. COST' ACC CO. ST' AFE AMT- 5450'/532' 1700' KOP 9 5/8" C. 1695' 7" L. 5450' 76 PCF 43 SEC $ 29,165 $ 382,138 $2,050,000 5450'/0' 1700' KOP 9 5/8" C. 1695' 7" L. 5450' 76 PCF 43 SEC $ 76,247 $ 458,385 $2,050,000 5450'/0' 1700' KOP 9 5/8" C. 1695' 7" L..5450' 76 PCF 43 SEC $ 221,443 $ 679,828 $2,050,00O 5450' TD 5398' ETD {FC) 9 5/8" C. 1695' 7" L. 5450' FIW $ 30,677 $ 695,729 $2,050,000 5450' TD 5398' ETD (FC) 9 5/8" C. 1695' 7" L. 5450' KCL F1 uid $ 37,023 $, 732,752 $2,050,000 . 'ELL NO, TBS A-24 RD FIELD TRADING BAY FIELD Dg..TAI[,S OF p?ERATiOIIS, DESCRIPTIO~.IS.~ RESULTS Drilled 8 1/2" hole f/ 4918' to 4993'. POOH. RIH w/ bit #12 on BHA #14 and directionally' drilled 8 1/2" hole f/ 4993' to 5306'. POOH RIH w/ bit #13 on BHA #14 and directionally drilled 8 1/2" hole f/ 5306' to 5450'. Circ clean. Made short trip. POOH. RU Schlumberger and ran DIL-GR, BHC-Sonic, and FDC-CNL-GR logs. Made clean out run. Had slight drag f/ 5077' to 6235'. Made short trip. POOH laying down DP. Finished laying down DP. Rigged up and ran 134 jts of 7" 29# N-80 buttress casing. Set shoe @ 5450' FC @ 5404'. Worked csg while circ mud. Cementing head developed a leak. Could not move csg after repaired head. Cemented csg w/ 725 sx .cl "G" w/ 1.5% pre- hyd gel followed by 500 sx. cl "G" w/ 1% D-29 .5% D-31, .5" D-19,3% A-2, and .1% D-6. Bumped plug w/ 4000 psi. Floats held ok. CIP @ 17:30 hrs 5/25/81. (Note: Began to see cement stringers back to surface and then lost returns during final portion of displacement). Landed csg in slips. Cut off 7" csg. Installed and tested 12" 3M x lO" 5M "DCB" spool. NOW' Installing BOPs. Installed and tested BOPE - Ok. RIH w/ 6" bit on 7." csg scraper. Tagged FC @ 5398'. .Circ and displaced mud w/ FIW. POOH. RU SDC and ran gyro f/ 5391' to surface. RD SDC. RU GO WL. Ran CBL-SIG-GR - showed good boDding across frac intervals. ° NOW' RIH w/ 6" bit. RIH w/ 6" bit and changed over to KCL WO fluid. POOH. RU GO WL and per.fed 33-6 sd f/ 4530' to 4550' DLL. Hole began making some fluid. RIH w/ RBP and set @ 4600'. Set ret-o-mat'ic squeeze tool @ 4470'. NOW: Offload frac equip. OIL · CALIFOF ,iIA ELL RECORD S EET D PAGE ih. -.-4 [~2~SE . ADL 18731 . DAT_E ETD 17 5/28/81 5450' TD 5398' ETD (FC) 9 5/8" C. 1695' 7" L. 545O' KCL F1 uid DAILY COST: $ 31,303 ACC COST: $ 764,055 AFE AMT: $2,o5o,ooo 18 5/29/81 5450' TD 4460' ETD (RBP) 9 5/8" C. 1695' 7" L. 5450' 67 PCF 42 SEC KCL Fluid DAILY COST: ACC COST: $ 97,194 $ 877,126 AFE AMT: $2,050,000 WELL NO, TBS A-24 RD FIELD TRADING BAY FIELD Wait on and offload Dowell equip. Changed out load line on crane - line still twisting.. Sent out correct line and installed on crane. Offloaded.remainder of Dowell equip. Mix frac fluid. NOW: Mixing. frac fluid. RU Dowell and mixed, frac fluid. Broke down 33-6 perfs f/ 4530' to 4550' DLL w/ 2700 psi. Pumped in w/ 40 CFM @ 3000 psi. Frac'd 33-6 sd w/ 13,000 lb of lO0 mesh sd & 80,000 lb of 20-40 sand. Had final rate of 7 BPM @ 2800 psi. Frac in place @ 03:46 hrs 5/29/81. Held press 8 hrs. Released sqz pkr - well was flowing. Raised mud wt to 67 PCF to kill well. Rev out. sand & ret RBP @ 4600'. POOH. Perfed the 31-8 sd f/ 4375' to 4405' DLL. RIH w/ RBP & sqz tool. Set RBP @ 4460' & test to 2500 psi - ok. Set sqz tool @ 4316'. RU Dowell & broke down perfs w/ 1400 psi. Pumped in w/ 42 CFM @ 2550 psi. Frac'd the 31-8 sd w/ 13,000 lb of lO0 mesh sd & 67,000 lb of 20-40 sd. Perfs screened out while disp l0 ppg sd. Rev out 32 bbls of 10 ppg sd (frac in place @ 22:36 hrs 5/29/81). 19 5/30/81 DAILY COST: ACC COST: AFE AMT: 5450' TD 4030' ETD 9 5/8" C. 1695' 7" L. 5450' 67 PCF 33 SEC KCL Fluid $ 144,675 $1,021,801 $2,050,000 Shut-in & held pressure for 8 hrs. Continued holding pressure on frac. Pressure bled to 0 psi. Released press and rev out sand. Ret RBP @ 4460' & POOH. Perfed the 28-6 sd f/ 3945' to 3960' DLL. RIH w/ RBP & sqz tool. Set RBP @ 4030' and tested to 2500 psi - ok. Set sqz tool @ 3886'. Mixed frac fluid & offloaded boat. Bird caged load line on crane. Repaired' same. Broke down 28-6 zone w/ 1900 psi. Pumped in w/ 44 CFM @ 2450 psi. Frac'd 28-6 zone w/ 13,000 lb of 100 mesh sd and 80,000 lb of 20-40 sd. Had final pres- sure of 2650 psi @ 8 BPM. Frac in place @ 17:35 hrs 5/30/81. 20 5/31/81. DAILY COST: ACC COST: AFE AMT: 5450' TD 3867' ETD (sand) 9 5/8" C. 1695' 7" L. 5450' 67 PCF 33 SEC KCL Fluid $ 35,711 $1,057,512 $2,050,000 · . . Held press on frac for 8 hrs Had 900 psi on DP. Bled press to 0 psi - well flowing. Shut in and built to 700 psi. Reversed out sand and light film of oil. Shut in and built to 400 psi. Flowed well & rev out sand to RBP @ 4030'. Ret RBP & reset @ 3892'. Spotted 5 sx of sand on RBP - tagged sd @ 3867'. Perfed 26-7 sd f/ 3720' to 3735' DLL. Set sqz tool @ 3640' Broke down perfs w/ 2000 psi. Pumped in w/ 3~ CFM @ 2800 psi. Frac'd 26-7 sd w/ 13,000 lbs of 100 mesh sd and 80,000 lb of 20-40 sd. Had final rate of 7 BPM @ 2100 psi. Frac in place @ 13:46 hrs 5/31/81. Held pressure for 8 hrs. Had 350 psi on DP. Bled press to 0 psi - well flowing. Shut-in - no pressure. Opened well - well was dead. Released sqz tool & POOH. NOW: POOH w/ DP. UNION OIL Cg'P/ N OF CALIFORHIA · WELL RECORD SHEET D PAGE ih, LEASE ADL 1873] ~'ELL NO, TBS A-24 RD FIELD TRADING BAY FIELD DATK 21 6/1/81 DAILY COST' ACC COST' AFE AMT' 22 6/2/81 DAILY COST: ACC COST' AFK AMT' 23 6/3/81 DAILY COST' ACC COST' AFE AMT' ETD 5450' TD 5398' ETD (FC) 9 5/8" C. 1695' 7" L. 5450' KCL F1 uid $ 149'1 63 $1,190,798 $2,050,000 5450' TD ' 53'98' ETD .(FC) 9 5/8" C. 1695' 7" L. 5450' $ 81,566 $1,272,364 $2.0~n.ono 5450' TD 5398' ETD.(FC) 9 5/8" C. '1695' 7" L. 5450' $ 29,062 $1,301,426 $2 ,o5o,Qoo _DETAILS _OF OpERATIOHS, DESCRIp,TIOIi!S & RESUL,T,S Perfed 24-6 sd f/ 3515' to 3535' DLL. Set sqz pkr @ 3454' & BP @ 3600' Broke d°wn.24-6 sd f/ 3515' to 3535' DLL w/ i900 psi. Frac'd' the 24-6 zone w/ 93,000 lbs of sand. Held pressure 8 hrs. Retrieved BP f/ 3600' & POOH. Tripped & retrieved BP f/ 3892'. RIH & CO- sand to 5398' w/ 6" bit & 7" csg scrpr. · NOW' Circ clean. Circ clean. POOH. Set Baker "D" pkr @ 3492' on WL. RIH & tested pkr. POOH. Ran single 2 7/8" tbg assy..Removed BOPE, installed & tested tree. NOW' InStalling flow lines. Installed flow line Ran CCL-GR f/ 4500' to 3000: thru tbg. Released rig @ 24'00 hrs 6/3/81. SCIENTIFIC DRILLING INTERNATIONAL 1111 East 80th Street, Anchorage, Alaska 99502 · 9071349-3541 · Telex: 09025364 (SDC AHG) Subsidiary of AMF INCORPORATED May 26, 1981 Job #4768 Monopod Enclosed please~ find our Gyro Survey on Monopod A-24 Redrill along with our Vertical Section and Horizonta1 View maps. If any other information is needed please call 349-3541. Thank you for using Scientific Drilling International and please call again. Sincerely Manager RECEIVED JAN 1 ? 1983 Alaska 0il & Gas Cons. Commission Anchorage C~ETION REPORT 'UNION OIL OF CALIFORNIA GYROSCOP!C SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FM LINDSEY G ASSOC 19 AUGUST 81 MONOPOD A-24 REDRILL KB ElEV 101, FT, JOB NO 4768 RECORD OF SURVEY TRUE MEA$, DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M . DEG, 0 0 0 100 0 0 100.00 200 0 0 200.00 300 0 0 300,00 400 5 O' 399.87 500 9 0 499.10 600 1~ 0 597.25 700 15 0 694.27 800 17 0 790.39 900 21 0 884.92 1000 25 0 976.96 1100 29 0 1066.04 0.00 -101.00 S O.OOW '0.99 S74.93W 99.00 $74.66W 199,00 298.87 S79.11W 398.10 $75.86W 496,25 S67e76W 593,27 $62.71W 689.39 S63.51W 783.92 875.96 965,04 $64.81W 1200 32 15 1152.08 1051.08 $66.45W 1300 36 0 1234.85 1133.85 568.80W 1400 40 0 1313.63 1212.63 S69.38W 1500 45 0 1387.33 1286.BB S68.48W 1600 50 0 1454.87 1353.87 $69.63W 1700 52 90 1517e46 1416,46 $66,93W 1800 52 0 1578.68 1477.68 S60,48W 1900 53 0 1639.56 1538.56 S60e63W 2000 52 30 1700.09 1599.09 $60.50W 2100 52 0 1761,31 166.0,31 S60,36W 2200 49 0 1824.91 1723.91 $59.78W 2300 49 0 1890.51 1789.51 $59.73W 2~00'49 0 195§,12 1855mlZ $59,70W TOTAL COORDINATES C L O S.U R E S DISTANCE ANGLE D M S 0.00 $ 0.00 W 0,00 S 0 0 0 W 0.!00 S 0.00 W ~ 0.00 S 0 0 0 W 0'00 S 0.00 W 0.00 S 0 0 0 W 0,:00 $ 0.00 W 0.00 S 0 0 0 W 0'99~S :~.,. 4e2~ W 4,35 S 7& 45 30 W ~6.70 S 109.91 W 64.19 S 144.86 W 83.95 S 185.71W 104.96 S 232.10 W 126,~1 $ 283,97 W 1~8.28 S 341.47 W 172.55 S 404e49 W 198e90 S 473.33 W 227.75 S 545.77 W 262.75 S 616.62 W 301.75 S 685,71W 340e86 S 755.03 W 379.88 $ 823.81 W 418.37 $ 890.67 W 456e38 S 955.87 W 494.44 S 1021,0~ W ~5.56 S 74 21 48 W 59.56 S 70 40 22 W 86.96 S 68 17 3 W 119.42 S 66 58 46 W 158.a3 S 66 6 49 W 203.80 S 65 40 29 W 254.73 S 65 39 ~9 W 310.79 S 66 1 11W 372.27 S 66 31 38 W 439.76 S 66. 53 48 W 513.42 $ 67 12 25 W ~91.38 S 67 20 56 W 670,27 S 66 55 12 W 749.17 S 66 14 51 W 828,41S 65 42 9 W 907.18 $ 65 14 38 W 984.0a S 64 50 21 W 1059.23 S 64 28 40 W 11~,~6 S ~4 9 41 w DOG LEG SEVERITY DEG/iOOFT 0,000 0,000 0,000 0.000 5.000 4.001 4,021 2.028 2,001 4.000 4.000 4.013 3,28~ 3,837 4.007 5,020 5.045 3,023 4,036 1.005 0.507 0.507 3,018 0,038 O,OZ~ ssc T ~ o~.~ DISTAN(. 0.00 0.00 0.00 0.00 4.27 16.20 39.16 59.34 86.87 119,40 158.43 203.80 254.73 310.7~~ 372,24 439.68 513.26 591.17 670.14 7~9e14 828,41 907.13 983.90 1058.95 1134,00 UNION NON.A-24 RD. GYROSCOPIC SURVEY JOB NO 4768 ).9 AUG 8). RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB SEA DRIFT DIREC DEG, TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M DOG LEG SEVERITY DEG/IOOFT SECTION DISTANCE 2500 48 0 2022.38 1921,38 S58.08W 533.13 S 1085.17 W 2600 48 0 2089,29 1988.29 $58.55W 572.16 S 1148,41 W 2700 48 0 2156,21 2055,21 $59.90W 610e19 S 1212,25 W 2800 47 30 2223,44` 2122.44 S59'78W 647,37 S 1276,26 W 2900 48 O' 2290,68 2189,68 S59.83W 684.60 S 1340.24 W 3000 47 0 2358e24 225'7.24 S60.31W 721.38 S 1404,13 W 3100 4`6 0 2427,07 2326,07 S60,13W 757,~0 S 1/+67.09 W 3200 47 0 2495.91 2394,91 $60,25W 793'~6 5 1530.03 W 3300 46 0 2564.74 2463,74` S60,61W 829'i~5 S 1593.12 W 1209,06 S 63 50 7 W 1283,05 $ 63 30 58 W 1357,16 S 63 16 53 W 1/+31.06 S 63 6 13 W 1504,96 S 62 56 30 W 1578.60 S 62 48 28 W 1651.07 S 62 /+1 4,0 W 1723,54 ,5 62 35 21 W 1796.03 S 62 30 7 W 3400 45 0 2634.83 2533.83 S61.58W 863';~2~&-, .....1655.57 W 1867,33 5 62 26 54` W 3500 ~1 0 2707.95 2606.95 S67.63W 892.9~ii'>$~'<~17~71~ili~i~iiWii<"C1935e44 S 62 31 28 W 3600 41 0 2783,42 2682'42 S68,03W 917.~:$:!>'ii%:777::~i89!>W: 2000.77 $ 62 41 54 W 3700 42 30 2858.03 2757,03 568.41W 942,~:.&~/~i8~9;~311'imi~.~2067'06 S ~2 52 34 W 3800 41 0 2932.63 2831,63 $69,63W 966.23~'S?~ 190i'~0~"i:~::~%~2133,27 '5 63 4 3 W 3900 41 0 3008.10 2907.10 570.05W 988,84 5 1963,~9 W 2198,43 ,5 63 16 9 W 4000 41 0 3083,57 2982,57 $69.71W 1011.41 5 2025,09 W 2263,61 $ 63 27 38 W ~100 41 0 3159,0~ 3058.04 570,71W 1033.61 5 2086,82 W 2328,78 5 63 39 2 W 4200 40 0 3235,08 3134.08 S71,25W 1054.77 $ 2148,22 W 2393.20 $ 63 50 56 W ~300 39 0 3312.24 3211.24 S71.80W 1074,93, $ 2208.55 W 2456,25 5 6/+ 2 4`9 W 4400 38 0 3390.50 3289.50 S71.58W 1094.48 $ 2267,65 W 2517.97 $ 64 14 8 W 4500 36 30 3470.10 3369.10 $71,41W 1113.69 S 2325.05 W 2578.02 5 64 24 20 W 4600 35 0 3551.26 3450.26 S70,alW 1132,79 S 2380.26 W 2636.07 S 64 32 58 W 4700'33 30 3633.91 3532,91 $7Oe21W 1!51.75 S 2433,25 W. 2692.07 S 64 40 12 W 4800 33 0 3717.5~ 3616.5a S72,~6W 1169.29 S 2485.20 W 2746,53 S 64` 48 10 W 4900 33 0 3801,41 3700e41 573,30W 1185,32 5 .2537,25 W 2800,47 S 6/+ 57 34 W 5000 33 0 3885.28 3784,28 573,25W 1200,99 5 2589,~1W 2854,37 5.65 7 3 W 5100 33 0 3969,14 3868,14 $74,06W 1216,31S 2641.67 W 2908.24 5 65 16 37 W 5200 32 0 4053.48 3952,48 $75,03W 1230,63 5 2693,46 W '2961.28 5 65 26 40 W 5300 32 0 4`138,29 4`037,29 S75,00W 12~4.33 S 2744.65 W 3013.55 S 65 36 4`3 W 1,341 0,347 1,003 0.501 1.033 1,004 1.002 1.018 1.111 4`,773 0,262 1.510 1.589 0,273 0.219 0.656 1,02~ 1.023 1,003 1.501 1,536 1,501 0,834. 0.454 0,027 0.445 1,036 '0,018 1208.35 1282.~ 1355,g 1429.4`7 1503,09 1648,64 1790,83 1793,05 1932,27 2064,3? 2130,85 2196,29 2261,73 2327,14 2391,8(2..~ 2517.03 2577.26 2691,55 2746.12 2800.17 2854,17 2908.12 2961,22 3013e53 UN~:ON MON.A-2Z~ RD. GYRO,sCOp!c SURVEY JOB NO 4768 AUG 81 RECORD OF SURVEY TRUE MEA$. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA D];REC DEG. TOTAL COORDINATES 5400 32 0 4223.09 4122.09' $76.61W 1257.32 5 2796.02 W 5450 32 0 4265.49 4154.49 $76,38W 1263,50 5 2821.79 W BOTTOM HOLE CLOSURE 3091,75 FEET AT $ 65 52 43 W CLOSURES DI&TANCE ANGLE D M 5 DOG LEG SEVERITY DEG/iOOFT 3065.71 S 65 47 14 W 3091.75 S 65 52 ~3 W 0.857 0,247 SECTION DISTANCE 3065.71 3091 UNION MON.A-24 RD. GY'ROscOP!C SURVEY H~ASURED DEPTH AND OTHER DATA'FOR EVERY EVEN 100 JOB NO 4768 FEET OF SUB SEA DEPTH. 19 AUG' 81 MEASURED DEPTH TRUE VERTICAL SUB HD-TVD DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATE5 20i 301 401 502 604 707 811 917 1027 1140 1259 1383 1520 1673 1836 2001 2163 2316 2468 2617 2766 2915 3062 3207 3352 3491 3623 3758 3890 4O23 4155 4285 4~13 4538 4660 201. 301, 401. 501, 601. 701, 801. 901, 1001. 1101, 1201, 1301. 1401, 1501. 1601. 1701. 1801. 1901. 2001. 2101. 2201. 2301. 2401. 2501. 2601. 2701. 2801. 2901. · 3001. 3101, 3201. 3301. 3401. 3501. 3601. 100 200 300 400 500 600 7O0 800 900 1000 1100 1200 1300~ 1400 1500~ '1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 0 0 0 0 2 5 10 16' 25 39 57 82 118 i72 235 300 362 415 .467 516 565 614 661 ?06 751 790 822 857 889 922 954 984 1012 1037 1059 0 O. 0 O. 0 1. 0 3, 2 9. 3 20. 5 33. 6 49. 9 69. 14 92. 18 117. 52' 520, 49 578, 49 635. 49 690, 47 743, 45 796, 45 84~. 39 891. 32 923. 35 956. 32 ' 986. 33 1016. 32 1045. 30 1072. 28 10~7. 25 1121, 22 1144. O0 O0 O1 71 92 56 65 51 50 8~ 97 87 22 97 26 66 59 97 84 38 32 94 02 70 37 74 96 72 40 08 07 43 S. 0.00 S 0,00 S 4.32 S 16.42 S 35.04 S 57.80 S 83.69 S 115.43 $ 155.11' $ 203.56 S 261.87 5 331.14 S 417.73 S 525.82 S 641.25 S 755.72 S 866.20 S 966.21 S 1064.61 S 1159.13 S 1254.19 S 1349.79 S' 1443.20 S 1534.46 S 1625.42 $ 1711.22 S 1791.93 $ 1875.75 S 1957e19 S 2039.19 $ 2120.60 $ 2199.42 S 2275,20 S 2346.25 S 2412.2~ W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W UNXON MON.A-24 RD. ' GYROSCOPIC SURVEY JOB NO 4768 19 AUG 81 INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH. TRUE HEASURED VERTICAL DEPTH DEPTH SUB · SEA TOTAL COORDINATE5 1000 2000 · 3O00 4000 5000 976. 1700. '2358. 3083. 3885. 875. 1599. 2257. 2982. 378~... 64.43 S 341.55 S 722.02 S 1011.82 $ 1201.24 S 1~.72 W 754.6~ W 1403.76 W 2024.94 W 2589.33 W UNION NON.A-24 RD. - ~ GYROSCOPIC SURVEY JOB NO 4768 ' ' 19 AUG B1 HEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF ,SUB SEA'DEPTH~ MEASURED, DEPTH TRUE VERTICAL SUB ~tD'TVD DEPTH ,SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 4780 /+899 5019 5138 5256 5374 3701, 3801, 3901, 4001, 4101, 4201, 3600 1079 3700 1098 3800 1118 390,0 .1137 4000 !155 4100 1173 20 19 20 19 18 18 1166,19 S 1185,50 S 1Z03,96 S 1221,91 S 1238,31S 125~,22 S 2~7~,73 W 2536,62 W 2599,18 W 2661,43 W 2722,12 W 2782,56 W i HORIZONTAL VIEW _.UNLON .OIL.DE_ CALIFORNIA MONOPO0- A 24 RE:DRILL GYROSCOPIC SURVEY ..... RADIUS OF CURVATURE CAL E : ¢%-=- IOOO'- . -:.'i ._ .:'-; : ._:_A_U~.us'r---~9.~_- ::!S~~ : ................ i ................ F · . .................... ? ..... { ' ' .... . I - i ........ AUGUST I~ - - - VERTICAL PROJECTION ...................... UNION-' 'OIL OF- CAUFORNIA .... -- * ........ MONOPOD A 24 ~REDRIL~ ......... ' GYROSCOPIC- SURVEY ..... RADIUS_ OF. CURVATURE '-~---SCALE- I ". -'* I0(X)'- 1981 - 400 80o . ~. ; ....... : ...... : 1200 ......................... 1600 -- ~ -- ALL-* DEPTHS- SHOWN* ARE TVD , " Check Foun for timely c~:'pli~ce with ou~- r~ulations. O[~rator, Well i~,~e and Reports and Katcrials to he receivcd by- Completion Rcport Wel 1 History San~ples aud Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Rc~lui red Yos Yes Date Received ,#o Rem:ar}ts Production Test Reports Logs Run Yos Digitized Log Data MONTHLY I Drilling well 2. Name of operator UNION OIL C( ;3. Address PO BOX 6247 4. Location of Well at surface 1620'N Sectior 5. Elevation in feet (indica iOl' RT abo~ 112. Depth at end of montlr 5450' TD 13. Casing or liner run and None 14. Coring resume and briE None 15. Logs run and depth wE CCL-GR from 16. DST data, perforating Perfed 24-6 17. I hereby certify that tt / NOTE--~eport on this fo Oil and Gas Conservation, Form 10-404 Rev. 7-1-80 (Rv Do( 3ent Transmittal Uni~, .)il Company of California unlen ,,, DATE SUBMITTED ACCOUNTING MONTH 7-28-81 TO FROM Mr'. Harry Kugler R.C. Warthen . A ~ .... ~ 6247 ^AK. 0ii a bas Cons. Cu,u,. AT ruud,, Anchorage, AK Anchorage, AK 99502 TELEPHONE NO. TRANSMITTING ThE FOLLOWING: ~llI TRADING BAY STATE A-24 REDRI.L: 1 ea, of the following; (blue ine & s(pia)' COreD. neutron-formation der sity 2" Comp. formation density log .... ~ ' ' RnrPhnl¢_ compen ;ated so~ ic lo(. 2" dual laterolog .5" dual laterol.og 2" Borehole compersated sorbic lo~ 5" crimp, fmrmatior density 1.o.q I ea Magnetic tape ..... PI FAq;F ,,~GN AND.EFTIIRN ONE coPY DATE' R E C E!V F D ,Jut,. 2~ 198t~ -- FORM 1-2M02 (REV. 11-72) PRINTED IN U S,A. ' STATE OF ALASKA ' ALASKA 0~AND GAS CONSERVATION CO~IISSION ~'- MONTHLY REPORT O-I= DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~'l Workover operation ~ 2. Name of operator 7. Permit No. " UNION OIL COMPANY OF CALIFORNIA §7-14 //--' 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well at surface 1620'N & 574'W from SE Corner, Section 4, T9N, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc,) l(ll ' ET above MSL 6. Lease Designation and Serial No. ADI 1R7.~l 5o-733-20226-01 9. Unit or Lease Name TRADING BAY STATE 10. Well No. TBS A-24 RD 11. Field and Pool TRADING BAY - MIDDLE KENAI For the Month of JUNE , .19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drillin~ problems, spud date, remarks 5450' TD Perfed the 24-6 sand and frac'd, Cleaned out frac sand and ran 2 7/8" completion assembly, Released rig @ 24:00 hfs 6/3/81. 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run CCL-GR from 4500, to 3000' thru tubing, 16. DST data, perforating data, shows of H2S, miscellaneous data Perfed 24-6 sand from 3515' to 3535' DLL. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 'SIGNE TITLE DIST DRLG SUPT DATE "7/15/81 .OTE--I~ePor, on this fOrm ,, recuired for each calendar month, regardless of the status of operations, and must be fii'e~:l in duplicate with the Alaske Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duPlicete Rev. 7-1-80 ALASKa("" )L AND GAS CONSERVATION C( "/IMISSION ' ~' MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well I~ Workover operation [] 2. Name of operator 7. Permit No. UNION 0IL COMPANY OF CALIFORNIA 81-4b 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well at surface ] 620'N & 574'W from SE Corner Section 4, T9N, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. lOl' RT above MSL ADL 18731 8. APl Number so- 733-20226-01 9. Unit or Lease Name TRADING BAY STATE 10. Well No. TBS A-24 RD 11. Field and Pool TRADING BAY - MIDDLE KENAI For the Month of MAY ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 5450' TD, 5398' ETD (FC). Milled window in 9 5/8" casing from 1695' to 1750'. Laid KOP. Commenced drilling off KOP @ 1700' on 5/16/81. Drilled to 5450' TD. 13. Casing or liner run and quantities of cement, results of pressure tests 7" casing @ 5450' Cemented with 725 sxs cl expanding cement. "G" followed by 500 sxs cl "G" 14. Coring resume and brief description None 15. Logs run and depth where run CBL-V'DL GR. w/ CCL from 1782' to 700' (In original 9 5/8") DLL-SP-GR, FDC-CNL-GR & BHC-Sonic-GR from 1725' to 5398' CBL-VDL-WF w/ GR & CCL from 5.398' to TOC. RECEIVED JUN ].. 9 t~81 i6. DST data, perforating data, shows of H2S, miscellaneous data SAND' 24-6, 26-7, 28-6, 31-8, 33-6 Al3ska 0il & Gas Cons. C0mmJssi0n Anch0rag9 PERFS (Resp to sand)' 3515-3535' 3720-3735' 3945-3960' 4375'-4405' 4530-4550' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNEE~/~, ~~~' TITLE DIST DRLG SUPT. /--, DATE 6/15/81 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 Rev. 7-1-80 STATE OF ALASKA ALASKA(~IL AND GAS CONSERVATION C( .dMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA 3. Address PO BOX 6247, ANCHORAGE AK 99502 4. Location of Well 1620'N & 574'W of the SE corner, Section 4, T9N, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) !0!' KB above MSL 12. COMPLETED WELL [] OTHER 7. Permit No. 81-4 8. APl Number 50- 733-20226-0] 9. Unit or' Lease Name TRADING BAY STATE 10. Well Number TBS A-24 RD 11. Field and Pool 6. Lease Designation and Serial No. TRADING BAY - ADL 18731 MIDDLE KENAI 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 X~ 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). .The'window depth and kick off point on well A-24 RD, Monopod Platform, were changed as follows' 1. Cut a section in the 9 5/8" casing f/ 1695' to 175i2' and spotted KO plug. 2. Kicked off at 1700' and directionally drilled 8 1/2" hole to 5450' MD TD. VERBAL APPROVAL BILL VAN ALEN 5/12/81. "~ RECEIVED MAY 2 8 1981 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed The space be~w for Commission use Title DIST DRLG SUPT. Date 5/26/81 Conditions of Approval, if any: Approved by. COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate March 24, 1981 Mr. Robert T. Anderson District Land Manager Union Oi I Company of Ca li fornia P. O. Box 6247 Anchorage, Alaska 99502 Re: Trading Bay State TBS A-24RD Union Oil Company of California Permit No. 81-40 Sur. Loc.: 1620'N, 574'W fr SE cr Sec 4, T9N, R13W, SM. Bottomhole Loc.~ 510'N, 3320'W fr SE cr Sec 4, T9N, R13W, SM. Dear Mr. Anderson: Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS ' 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the ~abitat 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 regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. Robert T. Anderson Trading Bay State TBS A-24RD -2- March 24, 1981 commencing operations you may be contacted by a representative of the Department of Environm~ntal Conservation. To aid us in scheduling field work, we would appreciate your no~ifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance, notification so that we may have a w~tne ss present. Very truly yours, Chairman of OF Alaska Oil & Gas Conservation Commission Eno 1 o sure cc.' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/eric1. ~H~be ALASKA OIL AND GAS CONSERVATION COMMISSION JAY S. #A¥¥OND, ~OV£RNOR 300I PORCUPINE DR/VE-ANCHORAGE, ALASKA 99501 March 23, 1981 ADMINISTRATIVE APPROVAL NO. 93.4 Re: Application of Union Oil Company of California, to redrill, complete and produce the Trading Bay Unit A-24RD well. Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Anderson: The referenced application was received on ~arch 23, 1981 and stated that the subject well will provide an effective "B" zone withdrawal point in the II-A fault block. The request was made pursuant to Rule 5 (c) of Conservation Order No. 57. This order was recinded by Conservation Order No. 93 on July 31, 1970. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion of the referenced well pursuant to Rule 9 of Conservation Order No. 93. Yours very truly, Harry W. Kugler Commi s sione r BY THE ORDER OF THE COMMISSION Union Oil and Gas Divison: Western Region Union Oil Compa .)f California P.O. Box 6247, AnShorage, Alaska 99502 Telephone: (907) 276-7600 Robert T. Anderson District Land Manager December 19, 1980 Mr. Hoyle Hamilton State of Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska Permits to Drill TBS A-9 Rd. and TBS A-24 Rd., Monopod Platform, Trading Bay Field ADL-18731 (8-86-71-5575-601353) Dear Mr. Hamilton: Enclosed for your further handling are three (3) copies each of the above captioned Permits to Drill. Also enclosed are our checks, numbers 19077 and 19078, each.in the amount of $100.00 to cover the required filing fees. Upon approval, we would appreciate executed copies for our files. Thank .you. Very truly yours, sk Enclosures RECEIVED Alaska Oil & Gas Cons, Commission Anchorage ~'l ~ STATE OF ALASKA ( .... ~ ALASKA AND GAS CONSERVATION CO~. VllSSION PERMIT TO DRILL 20 AAC 25.005 ~i ~,' la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHI~:D [] REDRILL ~ DEVELOPMENT OIL [] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator UNION OIL COMPANY OF CALIFORNIA 3. Address P.O. BOX 6247, ANCHORAGE, ALASKA 99502 <,,,~ . '.~ 4. Location of weH at surface 1620'N & 574'W of the S.E. Cor., Sec. 4, 9. Unit or lease name TRADING BAY STATE T9N. R13W. S M, 10. Wellnumber Attop0~prbposecrpr6duci'ng~nterval 820~N & 2240'W of the S,E, Cor,, Sec. 4, T9N, R13W, S.M. TBS A-24RD _ 11. Field and pool At total depth 510'N & 3320'W of the S.E. Cor., Sec. 4, T9N, R13W, S.M. TRADING BAY - MIDDLE KENAI 5. Elevation in feet (indicate KB, DF etc.) I .6. Lease designation and serial no. 101' KB abo.v.e MSLI ADL #18731 - 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number United Pacific Ins. Co, Amount ~]00_ Dr)CI_ r) 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to near~st drilling or completed 27 air miles North of miles A; 770-1~R feet well 350 feet _ 16. Propos~'c~'cT~th (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 5880' MD 4670 TV~et .3,8A0.03 A~. .1/15/81 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures ~].~J/5 psig@ Surface KICK OFF POINT feet. MAXIMUM HOLE ANGLE o (see 20AAC25.035(c) (2) **1500 psig@3400 ..ft. TD(TVD) .... . 2~ *Assumes gas gradient to surface. ~¢*Existing Reservoir data. Proposed Casing, Liner and Cementing Program .. SIZE CASING AND LINER SE ~ ~ lNG DEPTH QUANTITY OF CEMENT ., Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 8½" 7" 29# N-80 Butt. 5380., ,~SurfaceI F_5380'~. 4250' 700 CF I I ,, ~ I I I 22. Describe proposed program: .. Move rig over conductor #14, TBS A-24, and rig up. ).. Install and test BOPE. ~. Clean out cement f/+_ 1600' to 1700' and squeeze 9 5/8" x 12¼" annulus @ +__ 1680' and + 1620'. ~. C--ut section in 9 5/8" cSg. f/+ 1600' to 1660' and spot K.O. plug. 5. Directionally drill 8½" hole ~/+_ 1600' to +__ 5380' MD TD. 6. Run logs. 7.. Run and cement 7" casing f/surface to TD. 8. Run CBL and Gyro (squeeze as needed for zone isolation). ). Frac. pack the "B" zone oil sands as justified. LO. Complete well with single 2 7/8" production string and place on production. 23. I hereby certify that the fo.regoing is tr,~e and c~orrect to the best 9~ my knowledge The sp~'e below f~'r Comr~i~s~on use "" -/ ' Robert T. Anderson / ' f CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number I--lYES [~O [[]YES [~0 ~'ES [-]NO[ 50- 7$~-'Lo'z-~..to-O'~ ' Permit number . Approval date ~ ~ -~f~ ~'/- ~o n~/24/81 I SEE COVER LETTER FOR OTHER REQUIREMENTS ~' - ~' ~' - by order of the Commission Form 10401 Rev. 7-1-80 Submit in triplicate TYPE LOG A-9,A-5 TOP "B" 250O ~IONOPOD A-24 RD A-22 A-25 REC. 0 1000 FEET 33-6 ',3500 TOP "C" 4,000-- TRADING BAY FIELD TOP 33-6 SAND B ZONE ii HY£r~IL CHECK . VALVE · · LO-TOt~U£ GATE CR LO-TOR~IE 8A TE VAL V£ GATE VALV£ REQUIRED ~ ** PIPE ~At~S ~ V£N T ~ °o · · · · · ' :-.-'-". ':"'.''. BUBBLE. TANK .. ' .-Ol~ tlO/,IE MADE DEGA$$Et~ -. . ~ = .. ~ · . . L.£ VALVe' . . o . · . . · · 'e · . · . . · · · L P. VALVES POSll7VE CHOKE ADJUST,~BLF CHOKE · Un/on ~ill furn/sh NOTE __ · o .. ! //INI?,fU?,/, STAI/Di~£O dHOKE I.!,41.'iFOLD ASSEt, I£LY ALL CHANGES hlUST HAVE ¥,I~ITT£N APPROVAL BY 'THE DISTRICT DRILLING SUPERINTENDENT. ' - __ . ~ OJAWN 0 _(KO. · ./ AFt'l). H.B I. SCAt[ Non e (2) Ix)c. ~ Yes . ~.~---is the permit fee attached .......................................... ~ oz_ 2. Is w~ll to be located in a defined pool L~ No Lease &weii 6, f.' A-z¥ o Remarks 3. Is a registered survey plat attached ................................ 4. Is well located proper distance frcm property line .................. 5. Is well located proper distance frcm other wells .................... (4) Casg.~ (5)BOPE ~ Additional Requirements: 6. Is sufficient undedicated acreage available in this pool ............ 7. Is well to be deviated .............................................. ~d~ 8. Is operator the only affected party ................................. 9 Can pemit be approved.before ten--daywait .. . 10 Does operator have a bond Jrt force ......... , 11. Is a conservation order needed ...................................... ~_~ 12. Is administrative approval needed ................................... /~,-' 13. Is conductor string provided ....................................... ~~ 14. Is enough cement used to circulate on conductor and surface ......... ~ /3J~,F-~15. Will c~nent tie in surface and intermediate or production strings .. '~ 16. Will cement cover all known productive horizons .................... 17. Will surface casing protect freshwater zones ...................... ~.~ 18. Will all casing give adequate safety in collapse, tension and burst..~~ /2-~-~19. Does BOPE have sufficient pressure rating - Test to ~O~ psig .~~ Approval Reccmmanded: ,,,Geology: rev: 03/05/80 Well Histocy 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 APPENDIXi .. No special'effort has been made to chronologically organize this category of information, .o * ALASKA COMPUTING CENTER * RECEIVED ~ ............................ : SEP 2 4 1998 * ............................ * ........ SCHL~BERGER ........ Alaska Oil & Gas Cons. Commission .............................. Anchorage COMPANY NAME : BP EXPLORATION WELL NAME : Gl09 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292058200 REFERENCE NO : 98460 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION WELL NAME : G-09 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA APINUMBER : 500292058200 REFERENCE NO : 98460 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/09/16 ORIGIN : FLIC REEL NAM~ : 98460 CONTINUATION # : PREVIOUS RRRL : COMMENT : BP EXPLORATION, PRUDHOE BAY, G-09, API #50-029-20582-00 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE : 98/09/16 ORIGIN : FLIC TAPE NAME : 98460 CONTINUATION # : 1 PREVIOUS TAPE : CO~VlENT : BP EXPLORATION, PRUDHOE BAY, G-09, API #50-029-20582-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: G-09 API NUMBER: 500292058200 OPERATOR: BP Exploration LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 16-SEP-98 JOB NUMBER: 98460 LOGGING ENGINEER: H. KIRKBY OPERATOR WITNESS: M. KISSINGER SURFACE LOCATION SECTION: 12 TOWNSHIP: lin RANGE: 13E FNL: 2664 FSL: FEL: 2367 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 64.14 DERRICK FLOOR: 63.00 GROUND LEVEL: 35.34 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) .............................................. 1ST STRING 8. 500 9. 625 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 26-MAY-81 LOGGING COMPANY: DRESSER BASELINE DEPTH .............. 88888.0 10149.0 10139.5 10135.5 10121.5 10118.5 10109.0 10098.5 10087.5 10055.0 10049.5 10031.5 10019.0 10011.5 10010.5 10008.0 10007.5 9984.5 9982.5 9899.0 9898.5 9842.5 9841.0 9828.5 9828.0 9819.0 9818.0 9812.0 9797.5 9791.5 9776.5 9775.5 9769.0 9768.0 9738.0 9737.5 9727.0 9726.0 9697.5 9696.5 9693.5 9693.0 9690.0 9689.5 9653.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTD 88887.0 88887.0 10148.0 10138.5 10138.5 10134.5 10134.5 10120.5 10120.5 10117.5 10117.5 10108.0 10108.0 10098.5 10098.5 10087.5 10087.5 10055.5 10055.5 10049.5 10049.5 10030.0 10030.0 10018.0 10018.0 10009.0 10009.0 10006.0 10006.0 9983.5 9983.5 9897.0 9897.0 9840.0 9840.0 9826.0 9826.0 9816.0 9816.0 9810.5 9810.5 9796.5 9796.5 9790.5 9790.5 9775.5 9775.5 9767.0 9767.0 9737.0 9737.0 9726.5 9726.5 9697.5 9697.5 9693.0 9693.0 9690.0 9690.0 9654.5 9654.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 9645.0 9645.0 9639.5 9639.5 9638.5 9640.0 9609.0 9609.5 9609.5 9599.5 9600.5 9600.5 9595.0 9595.0 9595.0 9588.0 9589.0 9589.0 9583.5 9583.5 9583.5 9566.5 9566.0 9566.0 9554.0 9554.0 9553.0 9554.0 9542.5 9543.0 9543.0 9533.5 9533.0 9533.0 100.0 99.5 99.5 $ CONTAINED HEREIN IS THE CNTD DATA ACQUIRED ON BP EXPLORATION WELL G-09 ON 2-JUN-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTD PASS #1 GRCH TO THE BASELINE GAM~A RAY PROVIDED BY THE CLIENT (GR.BCS) ; AND CNTD PASS #1 NPHI TO GR.BCS. ALL OTHER CNTD CURVES WERE CARRIED WITH THE NPHI SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10157.0 951 O. 0 CNTD 1 O184.0 951 O. 0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD ~: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTD PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1210807 O0 000 O0 0 I 1 1 4 68 0000000000 NPHI CNTD PU-S 1210807 O0 000 O0 0 I 1 1 4 68 0000000000 NRATCNTD 1210807 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTD 1210807 O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNTD CPS 1210807 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTD CPS 1210807 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTD CPS 1210807 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTD CPS 1210807 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTD GAPI 1210807 O0 000 O0 0 1 1 t 4 68 0000000000 TENS CNTD LB 1210807 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTD V 1210807 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: ** DATA ** DEPT. 10183.000 NPHI.CNTD 25.399 NRAT. CNTD 4.627 CRAT. CNTD NCNT. CNTD 3484.987 FCNT. CNTD 753.130 CFTC. CNTD 744.972 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1640.000 CCL.CNTD 0.000 DEPT. 9509.500 NPHI.CNTD 34.593 NRAT. CNTD 6.274 CRAT. CNTD NCNT. CNTD 2312.468 FCNT. CNTD 368.553 CFTC. CNTD 364.561 CNTC. CNTD GRCH. CNTD 76.651 TENS. CNTD 1470.000 CCL.CNTD 0.000 4. 569 3543. 572 5. 687 2264. 989 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10157.0 9510.0 CNTD 10184.0 9510.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFIBER : 1 BASELINE DEPTH 88888.0 10177.5 10148.5 10144.0 10140.0 10137.5 10137.0 10127.5 10119.0 10115.0 10110.5 10104.0 10100.0 10096.0 10092.5 10088.5 10081.0 10080.0 10070.5 10069.5 10064.0 10050.0 10044.5 10042.0 10034.5 10024.5 10021.0 10014.5 10009.0 10007.5 10001.0 9996.0 9991.0 9987.0 9985.5 9984.5 9981.5 9950.0 992 O. 5 9900.0 9898.5 9884.5 9879.0 9874.5 9859.5 9843.0 9842.5 9829.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD 88886.5 88886.0 10175.5 10147.5 10143.5 10138.5 10136.5 10135.0 10125.5 10117.5 10113.5 10108.5 10102.5 10099.0 10095.5 10091.5 10087.5 10087.5 10079.5 10080.0 10068.5 10069.0 10064.0 10049.5 10043.5 10040.0 10032.5 10023.5 10019.0 10011.5 10006.0 10006.0 9999.5 9995.0 9989.5 9987.0 9983.5 9983.0 9981.0 9949.0 9919.0 9897.0 9897.0 9881.5 9876.5 9872.0 9857.5 9839.5 9840.0 9825.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-i998 13:58 PAGE: 9827.0 9824.5 9819.5 9816.0 9818.0 9816.0 9812.5 9810.5 9798.5 9796.5 9797.5 9796.5 9788.0 9787.5 9781.0 9779.0 9777.0 9775.0 9775.5 9774.0 9771.5 9769.5 9769.0 9766.5 9768.0 9767.0 9761.5 9760.5 9757.0 9754.0 9737.5 9736.5 9728.0 9726.5 9727.5 9726.0 9719.5 9719.5 9715.0 9714.5 9702.5 9704.5 9697.5 9696.0 9691.0 9690.0 9689.5 9690.0 9684.0 9684.0 9676.0 9676.5 9670.5 9670.0 9665.5 9666.5 9659.0 9659.5 9651.5 9653.0 9646.0 9645.5 9644.5 9643.5 9637.0 9635.5 9638.0 9627.5 9627.5 9626.0 9626.0 9622.5 9624.0 9615.0 9615.0 9610.0 9609.5 9609.0 9610.0 9600.5 9600.5 9596.0 9594.5 9595.0 9594.0 9592.5 9592.5 9584.5 9583.5 9584.0 9583.0 9573.5 9573.0 9572.5 9569.5 9567.5 9569.0 9567.0 9567.0 9566.0 9557.0 9556.5 9554.5 9554.0 9552.0 9553.5 9537.0 9537.0 9535.0 9533.5 9533.5 9532.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 9525.5 9519.0 9517.5 9517.0 100.0 $ 9515.0 98.0 9525.0 9518.0 9515.5 98.0 REM3LRKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTD PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTD PASS #2 GRCH TO CNTD PASS #1 GRCH; AND CNTD PASS #2 NPHI TO CNTD PASS #1 NPHI. ALL OTHER CNTD CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1210807 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 1210807 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTD 1210807 O0 000 O0 0 2 1 1 4 68 0000000000 CRATCNTD 1210807 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTD CPS 1210807 O0 000 O0 0 2 1 1 4 68 0000000000 FCNTCNTD CPS 1210807 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 1210807 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUFIB NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) CNTCCNTD CPS 1210807 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 1210807 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 1210807 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 1210807 O0 000 O0 0 2 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 10182.000 NPHI.CNTD 25.563 NRAT. CNTD 4.631 CRAT. CNTD NCNT. CNTD 3395.396 FCNT. CNTD 733.198 CFTC. CNTD 725.256 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 1673.000 CCL.CNTD 0.000 DEPT. 9508.000 NPHI.CNTD 37.691 NRAT. CNTD 6.578 CRAT. CNTD NCNT. CNTD 2288.083 FCNT. CNTD 347.826 CFTC. CNTD 344.059 CNTC. CNTD GRCH. CNTD 76.514 TENS. CNTD 1484.000 CCL.CNTD 0.000 4. 591 3515. 736 6. 039 2229. 339 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 10 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10157.0 9510.0 CNTD 10184 . 0 9510.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 10177.0 10155.5 10148.5 10142.0 10140.5 10137.5 10136.5 10132.5 10129.5 10128.5 10127.0 10120.0 10115.0 10110 5 10102 5 10099 5 10095 5 10092 0 10088 0 10080 5 10069.5 10063.5 10050.0 10047.5 10036.5 10028.5 10021.0 10012.0 IOO08.0 9992.5 9986.0 9985.0 9983.0 9950.0 9920.0 9899.5 9898.5 9880.5 9871.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD .............. 88886.0 88886.5 10175.5 10155.0 10147.5 10139.0 10138.5 10134.5 10127.5 10125.5 10117.5 10098.0 10087.5 10049.5 10027.5 10009.0 10005.5 9983.5 9897.0 10136.5 10129.5 10127.0 10113.0 10109.0 10102.5 10095.0 10091.5 10080.0 10068.5 10064.5 10046.5 10035.0 10019.0 10006.0 9992.5 9987.0 9983.0 9949.0 9919.0 9897.0 9878.5 9869.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center I6-SEP-1998 13:58 PAGE: 11 9859.0 9858.0 9842.5 9839.5 9841.5 9840.0 9836.5 9834.0 9828.5 9825.5 9827.5 9825.0 9819.0 9815.5 9818.0 9816.0 9812.0 9810.0 9798.0 9796.5 9797.5 9796.5 9792.0 9790.5 9789.5 9776.5 9775.0 9774.5 9775.5 9769.0 9767.0 9768.0 9767.0 9761.5 9760.5 9746.0 9745.0 9738.0 9737.0 9737.0 9736.5 9727.0 9726.5 9726.0 9726.0 9702.0 9704.0 9698.0 9697.0 9697.5 9697.5 9690.0 9690.0 9689.5 9689.5 9675.5 9674.5 9671.0 9670.0 9665.5 9666.5 9654.5 9654.0 9646.5 9648.5 9645.5 9645.5 9643.0 9643.0 9639.0 9640.0 9636.0 9636.0 9627.5 9628.0 9627.0 9628.0 9614.5 9615.0 9609.5 9609.5 9608.5 9609.5 9599.5 9600.0 9595.5 9595.0 9593.5 9593.0 9588.5 9589.0 9583.5 9583.0 9574.0 9573.5 9568.5 9568.0 9567.0 9560.0 9559.5 9556.0 9556.5 9554.0 9553.5 9552.0 9552.5 9543.5 9543.0 9537.0 9536.5 9533.5 9533.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 12 9531.5 9525.0 9522.0 9519.0 9513.5 100.0 $ 9522.0 9513.5 100.0 9532.5 9525.5 9518.0 99.0 REM_ARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTH CORRECTED DATA FOR CNTD PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CNTD PASS #3 GRCH TO CNTD PASS #1GRCH; AND CNTD PASS #3 NPHI TO CNTD PASS #1 NPHI. ALL OTHER CNTD CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 1210807 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTD PU-S 1210807 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTD 1210807 O0 000 O0 0 3 1 ! 4 68 0000000000 CRAT CNTD 1210807 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTD CPS 1210807 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTD CPS 1210807 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 13 NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP RL~ CODE (HEX) CFTC CNTD CPS 1210807 O0 000 O0 0 3 1 1 4 68 0000000000 CNTCCNTD CPS 1210807 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH ClFID GAPI 1210807 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTD LB 1210807 O0 000 00 0 3 1 1 4 68 0000000000 CCL CNTD V 1210807 O0 000 00 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10182.500 NPHI.CNTD 26.089 NRAT. CNTD 4.903 CRAT. CNTD NCNT. CNTD 3379.845 FCNT. CNTD 689.379 CFTC. CNTD 681.912 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1747.000 CCL.CNTD 0.000 DEPT. 9509.000 NPHI.CNTD 40.093 NRAT. CNTD 6.857 CRAT. CNTD NCNT. CNTD 2306.307 FCNT. CNTD 336.336 CFTC. CNTD 332.693 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 1677.000 CCL.CNTD 0.000 4.658 3523.254 6.303 2285.945 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREmENT 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 14 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3, THE ARIT~HETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... O0 000 O0 0 4 1 1 4 68 0000000000 DEPT FT 1210807 NPHI CNAV PU-S 1210807 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1210807 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1210807 O0 000 O0 0 4 1 I 4 68 0000000000 NCNT CNAV CPS 1210807 O0 000 O0 0 4 1 1 4 68 0000000000 FCNTCNAV CPS 1210807 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1210807 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1210807 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 1210807 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 1210807 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 15 ** DATA ** DEPT. 10183.000 NPHI.CNAV -999.250 NRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV GRCH. CNTD -999.250 TENS.CNTD 1640.000 DEPT. 9509.500 NPHI.CNAV 36.818 NRAT. CNAV NCNT. CNAV 2235.288 FCNT. CNAV 351.222 CFTC. CNAV GRCH. CNTD 76.651 TENS.CNTD 1470.000 -999.250 -999.250 6.381 347.418 CRAT. CNAV CNTC . CNA V CRAT. CNAV CNTC. CNA V -999.250 -999.250 5.938 2246.344 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... CNTD 1 O198.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TDDRILLER (FT): STOP DEPTH 9504.5 2-JUN-98 8C1-205 1559 2-JUN-98 10155.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 16 TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 10187.0 9510.0 10187.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTD COMP. NEUTRON $ CGRS-A CNT-D BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEI~PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 25000 TOOL STANDOFF (IN): REMARKS: TIED-IN TO BHC SONIC LOG DATED 5-26-81 436 BBLS SEAWATER AND 55 BBLS METHANOL PUMPED IN TO KILL WELL. TD TAGGED AT 10187 FEET. WELHEAD PRESSURE 0 PSI. GOC LOCATED AT 9995 FEET. THIS FILE CONTAINS THE RAW CNTD DATA FOR PASS #1. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 17 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1210807 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1210807 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1210807 O0 000 O0 0 5 1 1 4 68 0000000000 TNRAPS1 1210807 O0 000 O0 0 5 1 1 4 68 0000000000 RCIVT PS1 CPS 1210807 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1210807 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1210807 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1210807 O0 000 O0 0 5 1 1 4 68 0000000000 GR PSI GAPI 1210807 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1210807 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1210807 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10198.000 NPHI.PS1 19.496 RTNR.PS1 4.000 TNRA.PS1 RCNT. PS1 3878.788 RCFT. PS1 969.697 CNTC. PS1 3921.865 CFTC. PSI GR.PS1 54.242 TENS.PSI 993.000 CCL.PS1 0.000 3. 785 959.194 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 18 DEPT. 9504.000 NPHI.PSi RCNT. PS1 2150.713 RCFT. PS1 GR.PS1 71.087 TENS.PSI 39.570 RTNR.PS1 320.320 CNTC. PS1 1513.000 CCL.PS1 6.714 2192.526 -999.250 TNRA. PS1 CFTC. PS1 6.246 316. 851 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUF~IARY VENDOR TOOL CODE START DEPTH ........................... CNTD 1 O198.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 9502.0 2-JUN-98 8C1-205 1559 2-JUN-98 10155.0 10187.0 9510.0 10187.0 1800.0 NO LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 19 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTD COMP. NEUTRON $ CGRS-A CNT-D BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 8.500 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE T~PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 25000 TOOL STANDOFF (IN): R~CARKS: TIED-IN TO BHC SONIC LOG DATED 5-26-81 436 BBLS SEAWATER AND 55 BBLS METHANOL PUMPED IN TO KILL WELL. TD TAGGED AT 10187 FEET. WELHEAD PRESSURE 0 PSI. GOC LOCATED AT 9995 FEET. THIS FILE CONTAINS THE RAW CNTD DATA FOR PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 2O ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1210807 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1210807 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1210807 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1210807 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 1210807 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1210807 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1210807 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1210807 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1210807 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1210807 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1210807 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 10198.000 NPHI.PS2 52896.617 RTNR.PS2 -999.250 TNRA.PS2 RCNT. PS2 3764.706 RCFT. PS2 0.000 CNTC. PS2 3806.517 CFTC. PS2 GR.PS2 78.971 TENS.PS2 946.000 CCL.PS2 0.000 DEPT. 9501.500 NPHI.PS2 45.852 RTNR.PS2 7.123 TNRA.PS2 RCNT. PS2 2088.038 RCFT. PS2 293.130 CNTC. PS2 2030.314 CFTC. PS2 GR.PS2 46.748 TENS.PS2 1515.000 CCL.PS2 -999.250 -945.586 0.000 6.949 289.955 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 21 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 10194.0 9505.5 CNTD LOG HEADER DATA DATE LOGGED: 2-JUN-98 SOFTWARE VERSION: 8C1-205 TIME LOGGER ON BOTTOM: 1559 2-JUN-98 TD DRILLER (FT) : 10155.0 TD LOGGER (FT) : 10187.0 TOP LOG INTERVAL (FT): 9510.0 BOTTOM LOG INTERVAL (FT) : 10187.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ........... LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 22 GR GAMMA RAY CNTD COMP. NEUTRON $ CGRS-A CNT-D BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRInn~.~S CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 25000 TOOL STANDOFF (IN): REMARKS: TIED-IN TO BHC SONIC LOG DATED 5-26-81 436 BBLS SEAWATER AND 55 BBLS METHANOL PUMPED IN TO KILL WELL. TD TAGGED AT 10187 FEET. WELHEAD PRESSURE 0 PSI. GOC LOCATED AT 9995 FEET. THIS FILE CONTAINS THE RAW CNTD DATA FOR PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 23 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 1210807 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1210807 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1210807 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1210807 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 1210807 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1210807 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1210807 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1210807 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1210807 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1210807 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1210807 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 10194.000 NPHI.PS3 19.496 RTNR.PS3 4.000 TNRA.PS3 RCNT. PS3 3764.706 RCFT. PS3 941.177 CNTC. PS3 3806.517 CFTC. PS3 GR.PS3 78.971 TENS.PS3 1069.000 CCL.PS3 0.000 DEPT. 9505.000 NPHI.PS3 39.663 RTNR.PS3 6.290 TNRA.PS3 RCNT. PS3 2082.082 RCFT. PS3 331.034 CNTC. PS3 2174.320 CFTC. PS3 GR.PS3 73.173 TENS.PS3 1654.000 CCL.PS3 -999.250 3.785 930.982 6.256 327.449 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1998 13:58 PAGE: 24 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/09/16 ORIGIN : FLIC TAPE NAME : 98460 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, PRUDHOE BAY, G-09, API #50-029-20582-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/09/16 ORIGIN : FLIC REEL NAME : 98460 CONTINUATION # : PREVIOUS REEL : COGENT : BP EXPLORATION, PRUDHOE BAY, G-09, API #50-029-20582-00 ~mmmmmmmmm~mmmmmmmmm~ ~ .... SChLUmBERGER .... · ~mmmmmmmmmmmmmmmmmmmm~ LIS TAPE VERIFICATION LISTING ~mmmmmmmmmmmmmmmmmm~m~ ~ .... SCHLUMBERGER .... · LIS TAPE VERIFICATION LISTING LYP 009.H03 YERIFICA?ION LISTING PAGE ** REEL HEADER ** SER~tCE NAME :SERVIC DATE :G1/07/17 DP!GIN : REEL N~ME :REEL iD CONTINUATION ~ :01 PREVIOUS REEL : CO~NENT& :REFL COMMENTS ** TAPE HEADER ** SERVlCf: NA~E :SERVIC DATE :B~/07/17 ORIGIN :!070 TAPE NAME :6~667 CONTIN~iATION # :01 PREVIOUS TAPE ~ ** FILE HEADER FILE; NAME :SERVIC.O01 SERVICE MANE : VERSION ~ : DATE : ~AXI~U~ LENGTH : 1024 FIL~ TYPE : PREVIOUS FILE ** INF{}RMATION RECORDS CONTENTS C~ : UNOIN OIL CO. OF CALIFORNIA WN : TBS A-24 RD FN : TRADING BAY RANG: TO~N: SECT: 4 COUP: K~;NAI STAT: ALASKA CTRY: USA MNE~ CONTENTS PRES: NgDIT4F ** RECORD TYPE 047 ** RECORD TYPE 047 UNIT TYPE CATE SIZE CODE 000 000 O28 O65 000 000 0~2 065 000 000 012 065 000 000 003 065 000 000 002 065 000 000 001 065 000 000 006 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE mmm~ mmmm mmmm mmmm mmmm 000 000 0O7 065 LV'P 009.H03 VERIFICATION 5ISTING PAGE 2 RECORD TYPE 047 *~ jOB ~ 10707,61667 DIS R(,];~,~ ~i, 50GGED 24-MAY-~! BOTTOM LOG INTERVAL TOP LOG INTERVAL CASING-LOGGER BiT SIZE TYPE HOLE FLUID DENSITY VISCDSITY P~ R~ ~ ~EAS. TE~P. RMF s i<EA6. TEMP. R~C ~ ~EAS. R~F 9 -- 5434 FT. -- 1695 FT. -- 1695 FT. = 8.5 I~, - XC -- 76.0 -- 42.0 S = 9.0 = 9.6 C3 = 0.538 OH~.~I ~ 6~.0 DF - 0 267 - . OH.-~M e 74.0 DR -- 0.624 OB,~,~.H C~ 7~ 0 DF = 0.315 Oht4 ~ 10~ DF = 0.435 MATRIX SANDSTONE LVP 009.P. 03 VERIFICATION LISTING PAGE 3 ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE 9 4 0 i DATUM SPECIFICATION BLOCKS MNE~ SERVICE SERVICE UNI~! AP1 ID ORDER # DEPT FT GR MIl. GAPI SP ~IL bLS ElL OHM~ Lb[) ~IL GR SHF GAPi DT SMF US/F CALI ISN IN GR IS~ GAPI DRHO ISN G/C3 NPHI ISN PU RHOB ISN G/C3 FCNb NC~L lS~ NRA~~ DATA ** DEPT 5458.500 GR LLD -999.250 GR GR -999.250 DRHO FCNL -999.250 NCNb DEPT 5400.000 GR bLD 7.009 GR GR 93.813 DRHO FCNL 629.000 NCNb DEPT 5300.000 GR LLD 5.877 GR GR 97.312 DRHO FCNL b68.000 NCNU DEPT 5200.000 GR LLD 4.600 GR GR 98.438 DRMO FCML 592.000 NCN~ DEPT 5100.000 GR LLD 4.539 GR GR 48.969 DRHU AP1 LOG TYPE 0 0 0 31 0 0 0 0 0 0 31 0 52 0 28 0 31 0 0 68 0 35 0 34 0 34 0 42 -999 -73 -999 -999 91 84 0 2192 .25O .875 .250 .250 ,312 .813 .117 .000 REPR AP1 CLASS 0 32 0 0 0 32 32 3 32 0 2 93 92 ! API NIOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 90.625 93.250 0.065 2188.000 9 8 199 5,063 7.312 0.066 2.000 8.406 ~.469 0.032 SP DT NPHi NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPHI CODE 66 73 65 66 FIbE NO. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ENTRY 1 60 .lin 0 SI ZE PROCESS SAMPLE REPR bEVEL CODE 4 0 ! 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 I 68 4 o I 68 4 0 1 68 4 0 ~' 68 '999.250 102 563 '999.250 -35.695 93.750 39.014 3.318 -31.457 90.188 35.059 3.184 -24.668 92.188 34.494 3.139 -36.389 100.188 25.244 CALl RHOB CALl RHOB CALl RHOB CALI RHOB bLS CALX RHOB -999 250 -999:250 -999.250 6.675 9 305 2.'461 5.168 ! 0 359 4.747 10,234 2.471 4.059 8.453 2.322 LYP 009.~03 V~RIFICATION LISTING PAGE 4 FCNL 1038,000 6iCNb DEPT 5000.000 GR LbO 20.983 GR GR 81,125 DRHO FCNb 247,750 NCNb DEPT 4900,000 GR bLS 7.446 GR GR 54.094 DRHO FCNL 1245.000 NCNL DEPT 4800.000 GR LLD 6,068 GR GR 95.125 DRHO FCML 616,500 NCNb DEPT 4700.000 GR bLD 7.215 GR GR 85,125 DRHO FCNh 585,500 NCNb DEPT 4600,000 GR LLD 11,687 GR GR 52,500 DRHO FCNL 763,000 NCNb DEPT 4500,000 GR LDD 10.450 GR GR 82,438 DRHO FCNL 63~,500 NCNb DEPT 4400,000 GR LLD 35,719 GR GR 48.469 DRHO FCNL 797,500 NCNb DEPT 4300.000 GR LLD 7.673 GR GR 65,625 DRHO FCN~ 455.000 NCNb DEPT 4200.000 GR LLD 5.254 GR GR 85,563 DRHO FC~b 495.250 NCNb DEPT 4100,000 GR LLD 20.602 GR GR 56,938 DRHO FCML 244.~75 NCNb DEPT %000.~00 GR LLD 7.4t3 GR GR 97,250 DRHO 261.2 75 73 -0 1470 5~ 54 0 2674 95 0 1985 81 78 0 1925 48 43 0 2428 7~ 72 0 202e 47 46 -0 2532 63 62 0 1778 87 83 0 1775 54 0 1240 91 88 0 ,000 .375 ,813 .021 .000 .406 .094 .014 .000 .688 .188 .083 .000 .750 .813 .018 .000 .750 .469 .043 .000 .625 .000 ,063 .000 .750 .500 ,000 ,000 .344 .688 .074 .000 .312 .438 .05i .000 .906 .563 .009 .000 .312 .188 .079 SP DT NRAY SP DT NPHI NRAT SP DT NPHI NRAT SP NPHI NRAT DT NPHI NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPMI 2.418 -29,930 121.563 73.730 5.301 -29.416 130.000 19,873 2.057 -29.385 97~750 37,549 3,357 -3~.4t0 95.000 32,959 3,125 -26,662 107.375 32.764 3.004 -39.895 107,188 34.912 3.244 -28.661 113.000 36.084 3.166 -26.113 105.563 40.088 3,533 -19.423 I00.563 4i.406 3.613 -10.71i 132,375 63.184 4.832 -17.434 107.188 47.070 LbS CALI bbs CALl RHOB CALI RHOB bbs CALl RHOB bLS CALl RHOB bbs CALI RHOB bLS CALi RHOB bLS CALl RHOB bLS CAbI RHOB LbS CALI RHOB bLS CALI RHOB 26,224 9'977 1.589 6.272 8,422 2.301 5.171 11.023 2.377 6.025 10,992 2.344 8.758 9.445 2.332 8.860 12,250 2.354 21.332 9 445 2:221 6.518 12 297 2:273 4,~17 12. 08 2.332 20.592 12 867 6,098 13.813 2.230 LVP 009.H03 VERIFICATION 440,750 NCNb DEPT 3900.000 GR LLD 10.712 GK GR 90.250 DRHO FCi~L 319.000 NCNb DEPT 3800.000 GR LLD ~9.479 GR GR 44.875 DRHO FCNL 1006,000 NCNb DEPT 3700.000 GR LLD 8.939 GR GR 73,188 DRHO FCNL 640,500 t]CNL DEPT 3600.000 GR LLD 5.105 GR GR 81.938 DRHO FC~L 655,000 NCNb DEPT 3500.000 GR LLD 19,638 GR GR 51.844 DRHO FCNL 965.000 NCNb DEPT 3400,000 GR LLD 5.972 GR GR 90.813 DRHO FCDL 536.500 NC~L DEPT 3300.000 GR LLD 7.078 GR GR 86.375 DRHO FCNu 627.000 ~ICNL DEPT 3200.000 GR LLD 5.693 GR GR 6%.563 DHHO FCNL 540.000 hCNL DEPT 3100,000 GR LLD 4,611 GR GR 62,000 DRMO FCNL 592.000 NCNb DEPT 3000,000 GR bbD 4.559 GR GR 89.938 DRMO FCML 497.500 NCNb DEPY 2900,000 GR LLD 43.329 GR G~ 15,797 DRHO LISTING 177 8 7 157 4 4 294 6 218 9 7 2O8 5 4 270 7 7 192 7 223 6 5 205 5 5 222 9 8 188 ! ! 1.000 8.750 7,563 0.059 0.000 5,750 2,000 0.029 4.000 9.250 5.625 0.028 4.000 0.938 6.625 0,060 4.000 3.375 9.406 0.040 2.000 9.875 0.563 0.052 9.000 5.375 5.500 O.075 4.000 1.281 8.438 0.046 2.000 8.969 2.406 0.073 2.000 1.625 7.563 0.033 1.000 9,625 5.125 0.03~ NRhT SP DT NPHI NRAT SP DT NPHI ~RAT DT NPHI NRAT SP DT NPHI NRAT SP DT MPHI NRAT SP DT MPHi NRAT SP DT NPHI NRAT SP DT MPHI NRAT SP DT NPHI NRAT SP NPHI NRAT SP DT NPHI 3.961 -12.963 129,750 55.420 4.402 -15.432 110.i8~ 30,908 2.~42 -16.200 116.563 39,453 3.412 '14,68~ 1~9 75O 3.260 -23.675 ~,563 28.6~3 2,725 -8.397 103,188 35.596 3.385 -i4,205 137'500 37.695 3.389 -12,44~ 98.750 42,9~0 3,703 38,232 3.527 -16,178 113,000 41,113 3,61! -6,987 141,750 66.748 LbS CALI RHOB LbS CALI RHOB bLS CALI RHOB bLS CAL~ RHOB bLS CALX RHOB LbS CALI RHOB bLS CALI RHOB CAbI RHOB CALl RHOB ChbI RHOB CALI RHOB PAGE I,598 .016 2.121 17.365 8.992 2.303 7 120 2,297 3.863 ll.320 2.213 13,825 9,43O 2,332 4.69! ~6.203 2.400 4 929 i1:930 2.305 4 699 ~2i7§0 2 338 3 ?3 2.332 3.687 131086 2,342 46,910 ~2.430 1.423 LVP 009.H03 VERIFICATION LISTING PAGE 6 FC:~L DEPT LLO GR FC~b DEPT GR FC~iL DEFT FCNL DEPT GR FC{'~ L DEPT LLD GR FCNL DEPT L L 0 F C i,i L DEPT LLD GR FC~L DEPT LLD GR DEPT LbO GR FCSb DEPT FCi~ DEPT GR · ~.T 219 750 1240.000 2800.000 GR 9,196 GR 46.031 DRHO 723,500 NCNb 48 45 0 2154 .03l ,406 .059 .000 270U.000 GR 8.748 GR 55.563 DRHO 697.500 NCNb 53 57 0 2226 .$13 .188 .040 .000 2600,000 GR 13,528 GR 54.750 ORgO 788.500 NCNb 54 47 0 2646 .375 .156 .018 .000 2500.000 GR 13.447 GR 31.797 DRHO 260.250 25 25 0 1310 .031 .500 .019 .000 2400.000 GR 3.498 GR 52.250 DRHO b~9,bO0 NCNb 53 48 0 214~ .125 .813 .037 .000 2300.000 GR 11.346 GR 36.250 DRHO 256.000 NCNb 38 28 0 1216 .500 .531 .016 .000 2200.000 GR 3.303 GR 72.063 DRHO 540.000 ~CNL 66 64 0 2192 .500 .125 .028 .000 2100,00o GR 3.500 GR 63.625 DRHO 490.750 NCNb 63 6O 0 1755 .594 .656 .053 ,000 2000.000 GR 10.669 GR 36.969 DRHO 225,750 NCNU 36 25 -0 1233 .43B .516 .014 .000 1900.000 GR 3,197 GR 59,813 ORHO 629.500 NCNb 56 5O 0 2324 .188 .000 .024 .000 1800.OOU GR 3.097 Ga 50.b88 DRHO 50.750 44.938 -0.009 NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPHI MRAT DT NPHI NRAT SP DT NPHI MRAT SP DT ~RAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT 5.016 -12.417 103,375 29,932 2.990 -20.630 2!9.500 32.422 3.i21 '21,667 143.750 35,352 3'178 -8.413 78.375 60,205 4.594 -3.450 116.188 33.154 3.070 1.427 i40,125 ~64.160 4,875 -3,855 i28,500 44.385 3.750 -11.194 125.000 45.557 3,814 -8.226 147.125 76.172 5.520 -9,239 130.500 39.063 3.383 -9.706 I34.750 36.i82 CALI RHOB bbs CAbI RHOB bbs CAbI CALi RHOB bbs CALI RHOB CAbI RHOB LbS CALl RHOB CALI RHOB CALl RHOB CAbI bLS CAbi RHOB 57O 2.334 6.239 12.211 2.273 234 o°:o 4 2.279 13.259 10 531 3 435 91961 2.324 9.530 12'492 1,,533 3 097 t1~438 2.260 3 225 11i406 2 279 10 693 111688 1.410 2.998 10.078 2.244 2.750 9.312 2.217 0O9. HO3 FC~,~b bLD GR FCN~ VERIFICATION LISTING DEPT LL 0 FC~,ib 780.500 NCNb DEPT bbD Ga FCNb 1700.000 GR 1.200 GR 43.7t9 ORHO 501,750 NCNb DEPT LLD GR FCNL 1600.000 GR -999.250 GR 35.781 DRMO 286.500 NCNb DEPT LLD GR FCNb i500.000 GR -999.250 GR 31.594 DRHO 210.625 NCNb DEPI LbO GR FCNL 1400.000 GR -999.250 GR 31.15o DRHO 356.750 NCNb DEPT LLD FCNb 1300.000 GR -999.250 GR 38.000 ORHO 274.500 NCNb DEPT bbD GR FC~L 1200.000 GR -999.250 GR 32.563 ORHO 246.000 NCNb DEPT LLD FCNb 1100.000 GR '999.250 GR 32.938 DRHO 228.750 NCNb DEPT GR FCNG 1000,000 GR -999.250 GR 26.016 ORMO 252.625 NCNb DEPT LbO GR 900.000 GR -999.250 GR 26.B28 DRHO 252.875 NCNb 800.000 GR -999.250 GR 18.484 ORHO 212.375 NCNb 7 -9 2462.000 46,906 40.063 -0.031 2039.000 -999.250 -999.250 -0.593 1269.000 -999.250 -999.250 -0 520 1199:000 -999.250 -999.250 -0.564 1346.000 -999.250 -999.250 -0'546 1179.000 -999.250 -999.250 -0.557 1150.000 -999.250 -999.250 -0.561 1151.000 -999.250 -999.250 -0.576 1279.000 -999.250 -999.250 -0.803 1399.000 -999.250 -999.250 -0.554 1266.000 00.000 GR 99.250 G~ 22.625 ORHO -999.250 -999.250 -0.461 NRAT SP DT NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPMI NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPH I NRAT SP DT NRAT SP DT NPHI NRAT SP DT NPHI 3,160 -4.720 165.500 43.506 3.791 -999.250 -999.250 50.830 4.188 -999.250 -999.250 62.793 4.844 -999.250 -999.250 45.996 3.926 -999.250 -999.250 55.273 4.434 -999.250 -999,250 68.506 4.941 -999.250 -999.250 62.793 4.6~9 -999.250 -999.250 66.162 4.813 -999.250 -999.250 75.049 5.309 -999.250 -999.250 <77.637 5.453 -999 250 -999:250 72,656 bbs CALI RHOB bLS CAbI RHOB CAbI RHOB bbs CAbI RHOB CALI RHOB CAbI RHOB bbs CALl RH00 LbS CALl RH00 bbs CALI RHOB bbs CAbI RHOB CAbI RHOB PAGE I 222 2.258 -999.250 9.195 1.887 -999.250 9.203 1.910 -999.250 9.188 1.943 -999.250 9.211 1.759 -999.250 9.141 1.880 -999.250 9.203 1.892 -999.250 9.180 2,303 -999 250 g: so 2.475 -999,250 9.195 2.379 -999.250 9.141 2.484 009.H03 VERIFICATION FC~L 236.875 NCNb DEPT bO0,O00 LLD -999.250 GR GR 19.703 FCNb 237.500 NCNb DEPT 500.000 GR LLD -999,250 GR GR 17,563 DRHO FC~L 264.250 NCNL DEPT 400.000 GR bbP -999.250 GR GR 22.047 DRHO FCi~L 231.250 NCNb DEPT 300,000 OR LLD -999.250 GR GR 21.250 DRHO FCNL 245.250 NCNb DEPY 200,000 GR LLD -999.250 GR GR 17.234 DRHD FCNL 262.750 NCNb DEPT 101.500 GR LbO -999.250 GR GR 24.125 DRHO FCaL i002~.000 NCNb LISTING 1263.000 -999,250 -999,250 -0,504 1267.000 -999.250 -999.250 -0.47i 1201.000 -999,250 -999.250 -0 616 12521000 -999.250 o 6 1242.000 -999.250 -999.250 -0.555 1290,000 -999.250 -999.250 -0.75i 5216.000 NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPHI NRAT SP DT NPMI NRAT SP DT NRAT ** FILE TRAILER FILE NAME :SERVIC.O0! SERVICE NAME VERSIO~ # DATE : MAXIMU~ 5ENGTH : 1024 FILE TYPE NEXT FILE NAME : EOF ** TAPE T~AILER SERVICE NA~E :$£RVIC DATE :81/07/17 ORIGIN :1070 TAPE NAME :61667 CONTINUATION NEXT TAPE NAME : COM~ENT$ :TAPE COMMENTS 5.i72 -999.250 -999.250 70.947 5.082 -999.250 -999.250 63.818 4.686 -999.250 -999.250 71.191 5.094 -999.250 -999.250 69.238 4.992 -999.250 -999.250 63.184 4.656 -999,250 -999,250 -0,244 0,51.1 bLS CALI RHOB bLS CALI RHOB LbS CALI RHO8 bLS CAbI RHOB LbS CALI RHOB bbs CAbI RHOB PAGE -999.250 9,280 2.316 -999.250 9.148 2,404 -999.250 9,195 2,312 -999,250 9,281 2,311 -999 250 2.438 -999,250 9 289 2:230 LVP 009.H03 VERIFICATION 5~STING ** REEL TRAILER *~ SERVICE NAME :SERVIC DATE :81/07/17 ORIGIN : REEL NAME :REEL ID CONTINHATION ~ :01 NEXT RE[IJ NAME : CO~ENT$ :REEL COMMENTS EOF ********** EOF PAGE