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181-154
1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Re-Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: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): 5,700'N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 4,760psi 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: Contact Email: Contact Phone: 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 dtaylor@hilcorp.com 907-947-8051 Noel Nocas, Operations Manager 907-564-5278 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: LS 3-1/2" PRESENT WELL CONDITION SUMMARY Daniel Taylorr, Optimization Engineer AOGCC USE ONLY Tubing Grade: 9.2# / N-80 Tubing MD (ft): 5,180'Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028055 181-154 50-133-20348-00-00 Hilcorp Alaska, LLC Proposed Pools: 87'87' 9.2# / N-80 TVD Burst 4,587' 6,870psi 1,907' Size 2,029' MD See Attached Schematic 3,090psi2,029' November 29, 2024 SS 3-1/2" 87'20" 5,686' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Unit (KU) 34-32CO 510C Same 4,959'9-5/8" ~200psi 5,686' 5,373' Length Baker A-5 Dual Hy, Baker D, Baker D; N/A 4,574' MD/4,023' TVD, 4,726' MD/4,149' TVD, 5,166' MD/4,518' TVD; N/A, N/A 4,971'5,350'4,674' Kenai Kenai 5.1 & 6 Gas, Sterling 6 GS 13-3/8" See Attached Schematic m n P s 66 t _ N 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 3:04 pm, Nov 15, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.11.15 14:49:27 - 09'00' Noel Nocas (4361) 324-651 FEE A093808, FEE A028142 SFD SFD 11/20/2024 SFD BJM 11/26/24 10-404 GSTOR DSR-11/21/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.26 15:27:05 -09'00'11/26/24 RBDMS JSB 112924 Well Prognosis Well: KU 34-32 Date: 11-14-24 Well Name: KU 34-32L API Number: 50-133-20348-00-00 Current Status: Storage Prod/Inj Permit to Drill Number: 181-154 First Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Second Call Engineer: Daniel Taylor (907) 777-8319 (O) (907) 978-9135 (C) Maximum Expected BHP: ~ 300 psi @ 4587’ TVD (Pool 6 Max pressure in 4 years) Max. Predicted Surface Pressure: ~ 200 psi (Current Pool 6 SI pressure) Brief Well Summary KU 34-32 was drilled in January 1982 to produce the Sterling Pool 6 reservoir. In June 2021 well began producing pool 6 storage gas as annular and long string producer. Well currently produces about 4.1 mmscfd @ 180 psi bottom hole pressure and 60psi tubing pressure. The reservoir model indicates this well is underperforming and the purpose of this work is to reperforate the Pool 6 sands. Notes Regarding Wellbore Condition x 9-5/8” completion with dual 3.5” tbg strings Pool Top in KU 22-06X x Sterling Gas Pool 6 Top: 5,171’ MD; 4,430’ TVD Pre-sundry procedure 1. MIRU SL, PT to 1,000 psi 2. Bail fill to 5,300’ 3. RDMO SL E-Line Procedure 1. MIRU E-line, PT lubricator to 250 psi low and 1,000 psi high 2. PU GPT and RIH to ensure well is dry and complete correlation log 3. PU Guns and Reperforate Sterling Pool 6 sands: Proposed Perforated Intervals Pool Sand Top, MD ft Bottom, MD ft Top, TVD ft Bottom, TVD ft Total ft MD Sterling Gas Pool 6 Pool 6 ±5,207’ ±5,287’ ±4,460’ ±4,537’ ±50’ a. Proposed perfs also shown on the proposed schematic in red font. b. Send the correlation pass to the Reservoir Engineer (Daniel Taylor), and Geologist (Daniel Yancey) for confirmation. c. Verify PTs are open to SCADA before perforating. Record tubing pressures at 5, 10 and 15 minutes after each perforating run. d. These sands are in the Sterling Gas Pool 6 per CO 510C. 4. RDMO e-line. 5. Turn well over to production. Well Prognosis Well: KU 34-32 Date: 11-14-24 Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic XA Sliding Sleeve @ 4685 Lease: State/Prov. Country:USA Perforations (MD) (TVD) Angle/Perfs BHP: 379 BHT: 82 3/24/1986 Well Name & Number:KU 34-32 Kenai Gas Field County or Parish:Kenai Pennisula Bureau AK Completion Fluid: Dated Completed: C-1, 5207'-5270', B-3, 4630'-4650' Angle @ KOP and Depth C-1 Sd. 5207'-5270' MD, B-3 Sd. 4630'-4650' XA Sliding Sleeve @ 4544 XA Sliding Sleeve @ 4566 Baker Model A-5 Dual Hydraulic Packer at 4576' Baker Blast Joints 4617'-4667' Otis XN Nipple 4585' Baker Model D Packer with 10.5" SA set at 4726' Baker Model D Packer with 21.35" SA st at 5166' Baker Model D Packer with Millout Ext. At 5350' Approximate cement top 1420' in 9 5/8" Annulus 13 3/8", 61#, K-55 to 2029' 20" Drive Pipe to 88' Cemented Squeeze Holes From 4280' to 4282' tested to 500 psi March 1986. Mule shoe at 5180' 9 5/8", 46#, N-80 Casing at 5686' Otis X Nipple With Plug at 5373' Rotary table to Cameron Dual Tubing Hanger 19.45' 3.5 " tubing tail at 5384' All tubing 3.5" 9.2# N-80 XA Sliding Sleeve @ 4685 Lease: State/Prov. Country:USA Perforations (MD) (TVD) Angle/Perfs BHP: 379 BHT: 82 3/24/1986 Updated by DMA 11-15-24 Completion Fluid: Dated Completed: C-1, 5207'-5270', B-3, 4630'-4650' Angle @ KOP and Depth Well Name & Number:KU 34-32 Kenai Gas Field County or Parish:Kenai Pennisula Bureau AK C-1 Sd. 5207'-5270' MD C-1 ±5207'-5287' MD Proposed B-3 Sd. 4630'-4650' XA Sliding Sleeve @ 4544 XA Sliding Sleeve @ 4566 Baker Model A-5 Dual Hydraulic Packer at 4576' Baker Blast Joints 4617'-4667' Otis XN Nipple 4585' Baker Model D Packer with 10.5" SA set at 4726' Baker Model D Packer with 21.35" SA st at 5166' Baker Model D Packer with Millout Ext. At 5350' Approximate cement top 1420' in 9 5/8" Annulus 13 3/8", 61#, K-55 to 2029' 20" Drive Pipe to 88' Cemented Squeeze Holes From 4280' to 4282' tested to 500 psi March 1986. Mule shoe at 5180' 9 5/8", 46#, N-80 Casing at 5686' Otis X Nipple With Plug at 5373' Rotary table to Cameron Dual Tubing Hanger 19.45' 3.5 " tubing tail at 5384' All tubing 3.5" 9.2# N-80 PROPOSED Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: r~ Diskettes, No. D Maps: [] ~yscale items: [] Other, No/Type ~ Other items scannable by ~ large scanner ~'~ Poor Quality Originals: ,0V~~r~n-Scannable) [:3 Other: ~ Logs of various kinds NOTES: [] Other Project Proofing BY: ~OBIN VINCENT SHERYL MARIA WINDY Scanning Preparation x 30 = BEVERLY ROBINt/~SHERYL MARIA WINDY BY: Production Scanning Stage 1 Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) TOTAL PAGES PAGE COUNT FROM SCANNED FILE: _ PAGE COUNT MATCHES NUMBER IN SCANNING ('REPARATION' ""~YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO III IIIIIIII IIIII III RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IS~ General Notes or Comments about this file: Quality Checked (done) 12/10/02 Rev3NOTScanned.wpd UNSCANNED, OVERSIZED MATERIAI../S A V AII~ABLE: l>?/ /S-C¡ FILE # I lJr'Ndh"c ( fJÚ/1r'Aj S-i<rt/~(' (ltAI' To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission 1333 W. 7th Ave., Ste. 100 I Anchorage, Alaska 99501 Voice (907) 279-1433 IFax (907) 276-7542 . . MEMO WELLS PRODUCING IN KENAI, STERLING POOL 6 AS NATIVE & STORAGE GAS WELLS Reference letter in file dated October 25, 2006 about wells producing from the Kenai, Sterling 6 Pool (pool code 448568) and the Kenai Pool 6 Gas Storage (pool code 448809). Storage Injection Order 7 A has a report, 2007 Annual Gas Storage Performance Evaluation dated March 2, 2007 which has a statement with an official start date of May 8, 2006 where storage started in the pool. There was no formal paperwork submitted about this change so this letter is for the official well status date change for the well status or date it was accomplished by AOGCC. The following is a list of wells that is reported with both pool codes 448568 and 448809: APD No. 201-097 201-231 159-013 165-007 178-055 168-071 181-092 181-154 182-015 182-085 184-109 185-181 200-148 Well No. 21-6RD 43-6RD 34-31 33-32L 44-30L DU5-L 14X-6AN 34-32L 14-32L 13-6L 23X-6SAN 33-7S 3 1- 7X 71' I 0 ?yi/ ~o" L þl-- ...\~'" sCANNED JUL 2 7 2007 <F ' . AlaSka. Team Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 October 25,2006 Alaska Oil and Gas Conservation Commission Attn: Steve McMains 333 W. 7th Street, Suite 100 Anchorage, AK 99501 6" to, .1 <.: . ti\fANNf;f) RE: Wells Completed in Pool Codes 568 and 448809 Dear Steve, ,- Per your request, this letter is being provided to the AOGCC to identify wells completed in the Kenai Sterling Pool 6 (Pool Code 568) and the Kenai Pool 6 Gas Storage (Pool Code 448809). As you are aware, the above pool codes refer to the same geologic reservoir, a partially depleted gas reservoir which is being used for gas storage operations. Subsequent to the initiation of storage operations in May 2006, all future production from this reservoir is allocated between the remaining native gas and the injected/stored volumes, per written agreements between Marathon Oil Company and both the ADNR and the BLM. Therefore, any production from the wells completed in Pool 6 will be reported monthly on Form 10-405 under both pool codes. The wells appearing on Form 10-405 will appear the same for both pool codes. Per your request, the following is a list of wells which will be reported on Form 10-405, for both Pool Code 568 and 448809: Well No. 21-6RD 43-6RD 34-31 33-32L 44-30L DU5-L 14X-6AN 34-32L 14-32L 13-6L 23X-6SAN 33-7S 3 1- 7X API No. 5011331009001 5011331009101 5011331009700 5011331009800 5011332013900 5011332031900 5011332034200 5011332034800 5011332035100 5011332035600 5011332037100 5011332038000 5011332049500 APD No. 201097 201231 159013 165007 178055 168071 181092 181154 182015 182085 184104 185181 200148 . ~. . . Please advise if you have any questions or need any additional information. I can be reached at 907.565.3041 or lcibe1e@marathonoi1.com. yndon Ibele, PE Production Coordinator Cc Randy Jindra, IBM, Tulsa Ken Walsh, MOC, Kenai Marathon Houston Central Files Brian Havelock, ADNR, Anchorage Greg Noble, BLM, Anchorage O:~EXCEL~34-32 LAOGCCSUNDRYANN.X~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend__ Operation Shutdown Alter Casing Repair Well Plugging__ Change Approved Program Pull Tubing__ Variance Re-enter Suspended Well Time Extension Stimulate Perforate Other X Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface '1972' FSL, 1000' FEL, Sec. 32, T5N, R11W, S.M. At top of Productive Interval 381'FSL, 2228' FEL, Sec. 32, T5N, R11W, $.M. At Effective Depth At TOtal Depth 59' FNL and 739 FEL, Sec. 6, T4N, R11W, S.M. 5. Type of Well: Development X Exploratory__ Stratigraphic __ Service Convert to Annular Flow 6. Datum Elevation (DF or KB) KB 95 feet 7. Unit or Property Name KENAI UNIT 8. Well Number KU 34-32L 9. Permit Number 81 - 154 10. APl Number 50-- 133-20348 11. Field/Pool Kenai Gas Field, Pool 6 12. Present Well Condition Summary Total Depth: measured true vertical 5700 feet Plugs (measured) 4977 feet Model 'D' packer with plug in X Nipple at 5373 feet Effective Depth: measured true vertical 5350 feet Junk (measured) 4589 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 87' 20" Driven 2029' 13 3/8" 1300 sacks 5686' 9 5/8" 1730 sacks B~3: 4630' - 4650' MD, C-1: 5207' - 5270' MD Measured Depth True Vertical Depth 87' 87' 2029' 1907' 5686' 4965 true vertical B-3: 4069' - 4086' TVD, C-1' 4553' - 4606' TVD Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) LS 3 1/2", 9.2#, N-80 tubing to 5180' MD SS 3 1/2", 9.2#, N-80 tubing to 4587' MD Baker Model A-5 Dual Hydraulic Packer @ 4574' Baker Model D Packer @ 4726' Baker Model D Packer @ 5166' RECEIVED JUN 8'8 2001 Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description Summary of Proposal Detailed Operations Program X BOP Sketch 14. Estimated Date for Commencing Operation 7/5/2001 16. If Proposal was Verbally Approved Name of Approver Date Approved 15. Status of Well Classification as: Oil Gas X Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Don Eynon Title Production Engineer Intern Date 6/26/2001 FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity BOP Test ~ Location Clearance Mechanical Integrity Test Subsequent Form Required 10--~ Approved by Order of the Commission Form 10-403 Rev. 06/15/88 ORIGINAL I^ppr°va'i Comm, s,on Sub/nit in '~riplicate Well KU 34-32L Kenai Gas Field Convert to Annular and Long String Flow Cost Tracking AFE-04906201 Objective: Utilize flow up the longstring tubing and tubing casing annulus to improve deliverability at a low cost. Procedure: 1) MIRU welder to fabricate 3" symmetric flow lines from each 2 1/16" annular gate valve to 3' 5K ball valve above the cellar grates if possible. We will install them after installing new gate valves in step 3. If possible complete steps 2 and 3 with one hot work permit. 2) MIRU Haskel pump on KU 34-32 tubing-casing annulus. Pressure test to 400 psi to ensure wellhead and casing integrity (squeeze holes at 4,280-4282 MD, 3780-82 TVD). Bleed off pressure. RD Haskel pump. 3) Open existing casing valve and remove blind flange on opposite side of tubing head. Check for VR plug in new outlet. Install new 2-1/16" 5M gate valve on the outlet, test against VR plug, and then remove VR plug, leaving valve open. Install VR plug on opposite side of tubing spool and remove old 2-1/16" 5M gate valve. Install new 2- 1/16" 5M valve, test against VR plug, and then remove VR plug. Install flow lines from each annular gate valve to above cellar grates. 4) SI LS and SS on KU 34-32. MIRU slickline unit on short string. Test BOPs and lubricator to shortstring shut-in pressure. Set PX plug in 2.625" ID XN nipple at 4585' MD. RD slickline unit. 5) Fill shortstring with 3% KCL using a lubricate and bleed method. 6) MIRU slickline unit on shortstring. Test BOPs and lubricator to 500 psig. MU tool string with XA sleeve shifting tool, spang jars, and oil jars. RIH and locate XA sliding sleeve (ID 2.750) at 4565' MD. Shift sleeve open while monitoring casing and tubing pressure. POOH and check shifting tool to ensure it is not sheared and sleeve is opened entirely. RDMO slickline unit. 7) RU nitrogen unit on annulus and pump nitrogen down casing taking returns up shortstring to catch tank. Continue until nitrogen is blowing around the end of tubing, shut down N2 pump. Trap 325 psi on well and shut in. 8) MIRU slickline unit on longstring. Test BOPs and lubricator to SITP. MU tool string with XA sleeve shifting tool, spang jars, and oil jars. RIH and locate XA sliding sleeve (ID 2.750) at 4543' MD. Shift sleeve open while monitoring casing and tubing pressure. POOH and check shifting tool to ensure it is not sheared and sleeve is opened entirely. RDMO slickline unit. As soon as possible, produce well at maximum flow rate up the longstring tubing to clean up well and remove any remaining packer fluid from wellbore. Please test well, recording flow rates and tubing pressures. 9) Shut in well. Install towline to produce symmetrically through both the annulus valves, 3" ball valves, and on into the SSV and finally into the flow line. Put well on test with both the tubing and annulus flowing simultaneously, record rate and pressures. Do not exceed maximum rate out annular flow line per attached graph. When finished testing put on production as per instructions of Production Foreman. Well KU $4-32L Kenai Gas Field Conversion to Annular Flow Problems Addressed Discussion: KU 34-32 will be converted to annular flow to increase deliverability of gas from Sterling C-1 perfs, Pool 6 (current SBHP 345 psig). Potential problems are addressed below: Potential Problems: Erosion Velocity: The highest velocity gas flow will occur at the 2 1/16" 5M flanged outlet on each side of the tubing hanger. Flow will be out both sides of the hanger to reduce velocity and minimize erosion. Erosion could potentially occur if flow out the annulus exceeds 7.8 MMCFD at 168 psig casinghead pressure. Marathon plans to produce the well below erosive limits. Also, Marathon will conduct periodic UTT inspection of the wellhead and flowlines for signs of unusual wear. Corrosion: Partial-pressure of CO2 is less than 1.0 psi. If the partial pressures of CO2 is less than 7 psi the gas is generally considered noncorrosive. Furthermore, there is no H2S produced in the Kenai Gas Field. Corrosion of the casing is highly unlikely. Surface Safety Controls: The annulus will be produced via a separate towline from the existing tubing completion. Surface safety controls will be similar to that of other Kenai Gas Field completions. Casing Integrity: Pressures imposed on the 9 5/8" casing during this procedure will not compromise the integrity of the casing. Worst-case forces will not exceed 34% of the rated casing burst or collapse. The squeeze perfs (4280' MD) above the dual packer will be pressure tested to 400 psig (surface). The procedure is written so that the productive longstring completion will not be jeopardized if the squeeze peris unintentionally break down. III IV B-3 Sd. C-I Sd.~~ 10 11 WELL KU 84-82 CASING & ABANDONMENT DETAIL I. Rotary Table at 0.0' II. Cameron Dual Tubing Hanger at 19.45' III. 20' Drive Pipe at 88' IV. 13-3/8', 61'~, K-55 Casing at 2,029' V: 9-5/8', 47~, N-80 Casing at 5,686' TUBING DETAIL LONG STRING: 3-1/2', 9.2~, N-80 TUBING 1. Otis "XA' Sliding Sleeve at 4,543.52' 2. Baker Model 'A-5' Dual Hydraulic Packer at 4,575.54 3. Baker Blast Joints From 4,617.42' to 4,666.75' 4. Otis 'XA' Sliding Sleeve at 4,685.13' 5. Baker Locator Sub at 4,723.25' 6. Baker Model 'D' Packer W/10.5' Seal Assembly at 4,723.95'. Packer Set at 4,726' 7. Baker Model 'D' Packer W/21.35' Seal Assembly at 5,159.02'. Packer Set at 5,166' 8. Baker Mule Shoe at 5,180.37' 9. Baker Model "D' Packer W/Millout Extension at 5,350' 10. Otis 'X' Nipple W/Plug at 5,373' 11. Tubing Tail at 5,384' SHORT STRING: 3-1/2", 9.2~, N-80 TUBING A. Otis 'XA' Sliding Sleeve at 4,565.54' B. Baker Model 'A-5' Dual Hydraulio Packer at 4,573.99' C. Otis 'XN' Nipple at 4,585.32' D. Bottom of tubing Collar at 4,586.60' DA TE 118/82 1/17/82 PERFORATION RECORD INTERVAL C ONDITIOM 4,630'-4,650' B-3 Sd. Production 5,207'-5,270' C-1 Sd. Production A-01055 , ~EV. I :.ATE WELL KU 34-32 WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA O.~WN gA W APP'O. scwtL£ NONE O~TE: ,3124~86 IV B-3 Sd. C-I Sd. WELL KU 34-32 CASING & ABANDONMENT DETA I. Rotary Table at 0.0° II. Cameron Dual Tubing Hanger at 19.45' III. 20' Drive Pipe at 88' IV. 13-318', 61'~,, K-55 Casing at 2,029' ~/.' 9-5/8', 47~, N-80 Casing at 5,686' TUBING DETAIL LONG STRING: 3-172~, 9.2~, N-80 TUBING 1. Otis "XA' Sliding Sleeve at 4,543.52' cb~ (t4 2. Baker.Model 'A-5' Dual Hydraulic Packer at 4,575.~ 3. Baker Blast Joints From 4,617.42' to 4,666.75' 4. Otis 'XA' Sliding Sleeve at 4,685.13' 5. Baker Locater Sub at 4,723.25' 6. Baker Model 'D' Packer W/10.5' Seal Assembly at 4,723.95'. Packer Set at 4,726' 7. Baker Model 'D' Packer W/21.35' Seal Assembly at 5,159.02'. Packer Set at 5,166' 8. Baker Mule Shoe at 5,180.37' 9. Baker Model 'D' Packer W/Millout Extension at 5,35 10. Otis 'X' Nipple W/Plug at 5,373' 11. Tubing Tail at 5,384' SHORT STRING: 3-1/2", 9.2~, N-80 TUBING A. Otis 'XA' Sliding Sleeve at 4,565.54' O~.~t B. Baker Model 'A-5' Dual Hydraulic Packer at 4,573.9 C. Otis 'XN' Nipple at 4,585.32' D. Bottom of tubing Collar at 4,586.60' DA TE 118182 1/17/82 PERFORATION RECORD INTER VA L C OND ITIOM 4,630'-4,650' B-3 Sd. Production 5,207'-5,270' C-1 Sd. Production A -01055 I~EV. I WELL KU 34-32 WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA O,AWU BA W tko. __ APP~O. SCAL£ NONE OAT£ ,3/24J86 KGF Annular Procedures Subject: KGF Annular Procedures Date: Thu, 19 Jul 2001 14:25:34 -0800 From: "Eynon, Donald E." <DEynon~MarathonOil.com> To: "Williamson, Jane" <jane_williamson~admin.state. ak.us> Hi Jane, This email is to address your concerns on the 21-7S and 34-32L annular procedures. The objective of the conversions is to provide higher deliverability than is currently available. The wells are typically produce at Iow rates or are inactive in the summer and are needed in the winter to provide higher rates to satisfy peak demand. Well Current Production Anticipated Rate MMSCF MMSCF MMSCF Incremental Deliverability 21-7S 3 7.4 to 12.2 4.4 to 9.2 34-32L 4.2 10 to 11 5.8 to 6.8 The range of incremental production is a function of bottlenecks in the gathering system. Production at each well will be limited by erosional velocity at the casinghead annular outlets. The annular conversions completed to date have had no problems with water or sand production and we anticipate no problems with these conversions. Annual UTT inspections will be conducted on the flowpaths to check for erosion. We are testing the casing to 400 psi to ensure casing integrity. Current reservoir pressure in Pool 3 (21-7S) is 290 psi which will have a surface shut in pressure of 270 psi considering a gas gradient to the perforations. Pool 6 (34-32L) reservoir pressure is 345 psi which will have a surface shut in pressure of 315 psi considering a gas gradient to the perforations. The attached excel file shows maximum production rates out the two annular flow paths to keep flow velocities below erosive conditions. <<ErosionRatevsPress.xls>> If you have any further questions feel free to call me at 564-6302 or email me back. Thanks Don Eynon Production Engineer Intern 907-564-6302 work 907-268-7868 pager 907-529-0523 cell ~ ErosionRatevsPress.xls Name: ErosionRatevsPress.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 Description: ErosionRatevsPress.xls 1 of 1 7/19/01 5:35 PM FW: KU 3~-32 Pressure Test and N2 Displacement/~,~ Subject: FW: KU 34-32 Pressure Test and N2 Displacement Date: Thu, 12 Jul 2001 11:09:52 -0800 From: "Eynon, Donald E." <DEynon~MarathonOil.com> To: <jack_hartz~admin. state.ak.us> ..... Odginal Message ..... From: Eynon, Donald E. Sent: Thursday, July 12, 2001 11:08 AM To: 'jack_hartz@admin.state.ak. us" Subject: KU 34-32 Pressure Test and N2 Displacement Dear Jack, Through Ralph Affinito and Tom Maunder I have been relayed your concerns regarding the pressure test and displacement of water with nitrogen on KU 34-32 in the Kenai Gas Field. The s~rfs at a measured depth of 4280'-4282', 3780-82 TVD will be pressure tested with the annulus full of packer~FfTuid-a~d 400 psig applied at surface. This will create a bottom hole pressure across the squeeze perfs of,~2071 psig. To displace water out the sliding sleeve at 4565 MD, 4019 TVD will require a BHP 1776 psig at the sleeve;- ~ n~s-gives a 295 psi cushion as we displace the water out of the annulus. The sleeve is manufactured to provide a circulation area equal to the internal area of the 3.5" tubing, therby reducing friction at the sleeve. Nitrogen rates intially will be slow as to not create a BHP at the squeeze perfs higher than when we pressure tested. Please see attached spread sheet for anticipated surface pressures. When I get back to Anchorage this weekend I will include data for a fluid level of every 100'. The maximum annulus surface pressure represents a 145 psi cushion below the test pressure. If you have questions feel free to call or page me and I can return your call. Thanks, Don Eynon Produ~ion Engineerlntern 907-564-6302 work 907-529-0523 cell 907-268-7868 pager 907-344-0604 home <<Circulating Pressures.xls>> ~_~ Circulating Pressures.xls Name: Circulating Pressures.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 Description: Circulating Pressures.xls 7/12/2001 3:51 PM KU 34-32 Circulating Pressures Downhole Minimum Maximum Pressure Annulus Annulus Nitrogen Short String Measured Total at N2 Surface Surface Volume Nitrogen Returns Depth Vertical Interface Pressure Pressure Pumped Volume (bbls) (E) Depth(E) (psig) (psig) (psig) (Msc0 (liquid gals) 25 500 499 221 217 367 2.2 23 49 1000 990 438 424 574 7.9 85 74 1500 1449 640 610 760 17.3 185 99 2000 1882 832 781 931 30.7 330 124 2500 2309 1021 845 995 47.8 513 148 3000 2732 1208 1102 1252 68.2 733 173 3500 3146 1391 1252 1402 91.6 984 198 4000 3551 1570 1393 1543 113.8 1222 226 4565 4016 1776 1552 1702 146.6 1575 11 10 KU 34-32L Maximum Allowable Flow Rate -Assumes flow through both 2" annular valves. -Based on the MOC flow model using Salama et al. -Based on a minimum flow area at VR thread ID of 1.469" ISAFE PRODUCTION RATES ARE BELOW CURVE 0 50 100 150 200 250 300 Pressure (psig) Rate for Dual Outlets / Example: At 100 psig Max Rate is 5.9 MMCFGPD Marathon OilCompany Mr. Tom Maunder AOGCC 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 9071564-6~9 June 26, 2001 RE: KU 34-,3~ Kenai Gas Field Dear Mr. Maunder: Attached is a Sundry application for KU 34-32L to convert the well to an annular and Iongstring producer. Sterling Pool 6 static reservoir pressure is now at 345 psig. In order to provide higher deliverability we propose to produce up the Iongstring and annulus simultaneously. A set of squeeze perfs above the dual packer will be tested to 400 psig before displacing the hole with nitrogen to ensure casing integrity. Producing the well up the 9 5/8" annulus will not impart extraordinary erosion, corrosion, or burst / collapse stresses to the casing. The highest potential for erosion will take place at the tubing head annular outlets which we plan to produce below erosional velocities. Surface safety devices will be similar to other wells in the KGF. We have tentatively scheduled operations to start July 5th, 2001. Please contact me at 564-6302 if you have any questions. Sincerely, Don Eynon Production Engineer Intern 564-63O2 RECEIVED JUN :~ $ ;~00~ Alaska 0il & Gas Cons, Commission Anchorage Date: 7/20/01 To: Julie Huesser From: Jane Williamson Subject: Approval for Annular gas flow in KGF Wells 21-7S and 34-32L Julie, You had requested that I look into the sundries for conversion of wells KU 34-32L and 21-7S to annular flow for gas. These wells have a very low SIBHP, but a high PI. At higher rates, the 4000' of tubing creates friction loss that bottlenecks the production. The attached from Don Eynon provides an explanation of the rate benefits projected. As noted, potential deliverability increases predicted with their hydraulics models are 4.5-9 MMSCFD for 21-7S, and 5.8-7 MMSCFD for 34-32L. They want to produce up both strings and the annulus, as they will have to choke back the annulus a bit to stay under "safe" guidelines they are using for erosion. This should provide the higher overall delivery. I quizzed them quite a bit, and they have done their modeling and homework. They will ensure the annular production is below the "safe" erosional velocity rates. The production to date (begun in 1998) has seen no instance of wear in their inspection program. They recently pulled and inspected KU 24-5 wellhead (workover), which had been producing up the annulus since August '98. No wear was seen, and they will be re-using the head. They will forward that information later. The gas is very dry, 99.6% methane. There is no problem from a commingling standpoint. In the case of KU 34-32L, B-3 production is left SI. Flow will be from C-1, into long sting, out the long string XA sliding Sleeve at 4543', back and up the annulus, and up short string (through xa sleeve at 4564'). The short string has a plug at 4585' to prevent production from B-3 zone. Well KU 21-7 has the long string production from B-sand shut-offwith plug. Proposed production is from Benches A-, A-10, A-11, through the short string, out the short string Sliding sleeve above packer, up the annulus and into the long string through the sliding sleeve above the packer. I recommend approval of both sundries. Jane Williamson Petroleum Engineer Union Oil and Gas [~ion: Western Region Union Oil Company or California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union June 5, 1984 Mr. C.V. Chatterton Aiaska Oil & Gas Conservation Commission 300i Porcupine Drive Anchorage, AIaska 99502 Dear Mr. Chatterton: SUNDRY NOTICE INTENTIONS Attached for your approval are Sundry Notice intentions for KU 21X-32, KU 34-32 and KU 21-5, Kenai Unit. Rlease return the approved Sundry's to the undersigned. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST LOC/tj Attachments RECEIVED ju N 0 6 1985 OLL & Gas Cons. commWsioll Anchorage .. STATE OF ALASKA ALASKa-. JIL AND GAS CONSERVATION C __,,~'IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. UNION OIL COHPANY OF CALIFORNIA 81-154 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50~33-20348 4. Location of Well 1990'N & llO0'W of SE Cot., Sec. 32, TSN, RllW, SH. 5. Elevation in feet (indicate KB, DF, etc.) 95' KB 6. Lease Designation and Serial No. A-028055 9. Unit or Lease Name Kenai Unit 10. Well Number KU 34-32 11. Field and Pool Kenai Gas Field 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 J~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon _. _[--I Stimulation [] Abandonment · Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing 1~ 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 i proposed work, for Abandonment see 20 AAC 25.105-170). 1.) Hove Rig to 43-32 Pad, well KU 34-32 and rig up. 2.) 3.) 4.) 5.) 6.) 7.) 8.) 9.) lO.) il.) 12.) 13.) 14.) 15. ) 16.) Kill well, install BPV's, remove tree, install & test BOPE. Pull and lay down existing dual completion assembly. Clean out perm pkr's ~ 4726' and 5166'. Run 9 5/8" casing scraper to 6348' ETD. Squeeze the B-4 sands 4807-4852' for abandonment. DST the B-3 sand 4630-4650'. If dry go to Step 10. Squeeze the B-3 sand (4630-4650') for abandonment. Clean out squeeze and test to a .80 psi equivalent. DST the B-2 sand 4532-4570' DIL. DST the B-1 sand 4472-4490' DIL. Reperforate sands to a final shot density of 8 HPF. Run dual 3 1/2" completion assembly. Install SPY's remove 8OPE, install and test dual tree Place well on production. Rig down and move rig. If not go to Step 8. JUN O 6 !B 5 14. I hereby certify..t~at thej[.oregg. Lng is ~r..u.e and correct The space below for Commission use to the best of my knowledge. Title ENVIRONMENTAL SPECIALIST Date 06-04-85 Conditions of Approval, if any: Approved by. IIIIttlAL Iltl[I BT LOIIIIIE C. SMITII Approved Co~' Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in DUplicate PRESENT PROPOSED 20' CASING AT 88' DUAL 3 112', 9.2~, N-80 TUBING- BAKER 'A-5' DUAL PACKER AT 4'575' B-3 S~ND 4630'-4650° 13 3/8',61~,K-55 CASING AT 2020' DUAL PACKER AT ±4400' - DUAL 3 1/2', 9.2~, N-80 TUBING BLAST JOINTS B- 1 SAND 4472'-4490' B'2 SAND 4532'-4570' DUAL PACKER AT +_4600' BAKER MODEL 'D' PACKER AT 4726' B-4 SAND 4807'-4852' C'1 SAND 5207'-5270° ·BAKER MODEL 'D' PACKER AT 5166' NIPPLE WITH PLUG BELUGA ZONE T 9 5 /8'.47~,N-80 CASING AT 5686' WELL KU 3/ -32 RECOMPLETIOtl (IF THE B-3 TESTS DRY) BLAST JOINTS B-3 SAND 4630'-4650' SINGLE PACKER AT 4750' · /~-4 SAND SQUEEZED 4807'-4852' SINGLE PACKER AT ~_5130' C-1 SAND 5207'-5270' BAKER MODEL 'D° PP, CKER AT 4_.5348 'X' NIPPLE WITH PLUG - BELUGA ZONE Fic~ur e 3 PRESENT PROPOSED 20' CASING AT 88' DUAL 3 1/2', 9o2'~', N-80 TUBING- BAKER 'A-5' DUAL PACKER AT 4575 13 3/8",61,~,K-55 CASING AT 2020' DUAL PACKER AT +4400' - DUAL 3 112", 9.2~, N-80 TUBING B'3 S~ND 4630'-4650' B'I SAND ' 4472'-4490' BAKER MODEL "O' PACKER ~T 4726' B'4 SAND 4807'-4852' C'1 SAND 5207°-5270. BAKER MODEL 'D' PACKER AT 5166' NIPPLE WITH PLUG BELUGA ZONE 9 5 /8',47.~,N-80 CASING AT 5686' WELL KU 3/ -32 RECOMPLETIOIkl (IF THE B-3 TESTS WET) B-2 SAND 4532'-4570° SINGLE PACKER AT +_.4600' B-3 & B-4 SANDS SQUEEZED SINGLE PACKER AT +5130' --= C-1 SAND 5207'-5270' BAKER MODEL "D° PACKER AT 4.534; °X' NIPPLE WITH PLUG BELUGA ZONE Figure 3b KU 34-32 0' 19' .. 20" 88 ' Otis 3 1/2" 'XA' Sleeve 4544' 13 3/8"~ 61# K-55 2020" · Otis 'XA' Sliding, Sleeve 4566 ' BKR 'A-5' dual p~r 4573' Otis 3 1/2" "XA" Sleeve 4685 .-. BKR mod. "D" pkr '4726 ' BKR mod. "D" pkr 5166' 'Mule Shoe 5181 ' BKR 'A-5 ' Du~. PKR 4573' Otis 'XN'~ Nipple 4585" B-3 pe~_~fs. , = 46'3b' =46~" ?, .. C-1 Sand ~.rfs ' ~2-9 7 '.,5270 BKR mod. 'D' pkr. 5348' 'X' Nipple w/ plug 5373' Tail 5384 .. _9'.:,5~"-47# N-80 5686 .. OAIE KU 34-32 Well Schematic Kenai Gas Field UNION OIL COMPANY C~i: ,,-"~ STATE OF ALASKA ALA'SKA~ . ~.AND GAS CONSERVATION Cg MISSION I-O~li ~_~j~ WELL COMPLETION OR RECOMPLETiON REPORT AND i. St~]tus of Well . Classification of Service Well OIL [] GAS [~ SUSPENDED [] /~,BANDONED [] SERVICE [] . 2. Name of Operator 7. Permit Number UNION OIL CO OF CALIFORNIA 81-154 3. Address 8. APl Number P. O. BOX 6247, ANCHORAGE, ALASKA 99502 s0-133-20348 4. Ldcation of well at surface ~ ~.~, 9. Unit or Lease Name SM. 1972'N & W 'SE Cor, Sec 32, T 5N, R llW Kenai Unit At Top Producing ~nterval 381' N & 2228' W of SE Cor, Sec 32,-'T5N, Rll~;7 10. Well Number SM. KU #34-32 ' At Total Depth 59'S & 739' W of NE Cor, Sec. 6, T41~, RllW, S.M. 11. Field and Pool Kenai Gas Field .5. Elevation in feet (indicate KB, DF, etc.) 'I 6. Lease Designation and Serial No. KB 95' MSLI A-028055 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore ] 16. No. of Completions 11--23--81 ]2-07-81 01-21-82I .... feet MSLI - ' 2 _17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 5700 & 4971 YES~ N© [] feet MD 22. Type Electric or Other Logs Run DIL-SP-BHC-Sonic-GR, FDC-~'/~!L-GR, CBL-V!DL-GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 945 Plain surface - "87' Driven 13 3/8" 615 K-55 Surface 2029' 17 1/2" 1300 sxs cl "G" 9-5/8"' 475 N-80 Surface 5686' 12 1/4" .... 1730 sxs cl "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBIN.,G RECORD interval, size andnumbe~) . . ' ' . SIZE ., DEPTH SET (MD) PACKER SET (MD) ~ 3 1/2" 4720' 4.720' ... MD 4630-4650 B-3 8 HPF 4069-4085 3 1/2" 5160' 5160' 5207-5270 C-1 8 HPF 4553-460i5 26: ACID, FRACTURE, CEMENT SQUEEZE. ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED · · " '~" ' "5~92-5553 2000 qal 7 1/2 % MSR 2:7. ', ' :''" : pRoDuCTioN"~E'~'T' Date First Production . Method of Operation (Flowing, gas lift, etc.) ' ' 'i/2'3,/E12 ' Fl°Wing' ''~ .... ?' . _ . Date of Test Hours Tested PRODUCTION FOR O IL-BBL GA~AJ~ WATER-BBL C HOKESlZE ,GAS-OILRATIO 1/27/82 24 TEST PERIOD ;~.....1[~5~ I ·" ' ' ' ": W~ATER-BBL L Flow T~g Casing Pr ure CALCULATED 1l~ ':iD I:-BB·I''' ' :"'-G'A~-'I~J]~I~ OI GRAVITY-APl (corr) 'Press: 9[~0' . e~ T 24/H0,UI~I RA':rI~': :" ":' '" ...... :"1~05.~J ' j[ 28. CORE DA'F'A' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water· Submit core chips. None '' · i?EcEI .,. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . ,:~ ;~" -j 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/sterling Fm. 4206 3736 B-4 Sand 4807-4852 Gas Sands Final rate. after 6 hrs. 0.30 ~CFPD @ 100 PSI w/950 BWPD T/Beluga Fm. 5441 4776 .Beluga Sands ~-',,'~ 5543-5553 No Entry Acidized w/2000 gal 5462-5478 MSR 1.00 5442-5454 After acidizing, rate 1.5 ~CFPD @ 600 PSI 5 Hr. buildup survey gave Pe ~ 1615 psi ., .. 31. LIST OF ATTACHMENTS - 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ' S igned~,,..~ ~ ~/~' Title' Date /- / "/. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item' 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in-other 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". ADDENDUM TO KU 34-32 WRI,T, CQMP~ION , · Perfed & Sqz. 4280-4282 4614-4616 4664-4666 4807-4852 4807-4827 4848-4852 4874-4876 4868-4870 5196-5198 5480-5482 5553-5555 Perfed: 5442-5454 5462-5478 5543-5553 350 sxs CL "G" 350 350 5O0 400 300 400 350 350 350 350 ADDENDUM TOKU 34-32W~I, CtIMPLETION Perfed & Sqz. 4280-4282 4614-4616 4664-4666 4807-4852 4807-4827 4848-4852 4874-4876 4868-4870 5196-5198 5480-5482 5553.5555 Perfed: 5442-5454 5462-5478 5543-5553 350 sxs CL "G" 350 350 500 400 300 400 350 350 350 350 Oil & Gas Cons. anc.borage UNION OiL. CO. CALIFORNIA WELL ,~'F_.CORD · . · , SH E,':'T ^ PAGE: NO. LOCATIOn. 1972' N & 1000' W of SE corner Sec 32 T5N, 1211W, S.M. Kenai U~it State VTELL NO KU #34-32SPUD DATE---11-21-81 COMP; DATE 1'18-82 CONTRACTOR B£inkerkoff ~ RIG NO. 58 TYPE UNIT.. DRII, L P1PE DESCRIPTION .... ELF, VAT~ONS: WATER DEFI'II 17.5' K 15 to grn. d._ . PE2MIT NO. 81-154 SERI.kL NO. A-028055 ILT. TO OCEAN FLOOR · "~^^ TMD -- - - 4844' R T 'fO MLL~V ~ 76 ' above MLLW 'I.D. .'.')/uu __ T.V.D, ___ ' ' DEVIATIO~ tBHL~ 2506" at 5 38° 7' W COMPANY E~'~I~'ER Mc-----~lli---ster-----~berna----~y __ .. ~ .. - size WEIGHT THRE_AD ... " 2o" 188.' " ' -1.3""3/8" 61# Butt K-55 ~2029' Cont'd,w/ 1300 sxs "G"-w/addi~ives 2 5/8" 47~ Butt N-80 5686' Cont'd w/ 1730 sxs "G" w/ 3 % KCL 3.._~2" 9.2~ Butt N-80' " 5181' Pkr at 5%66' 3..1/2" 9.2# Butt N-80 I 4587' Pkr'at 4~73f ..... ....... PERFORATING RECORD _~.'ATE IH~VAL E,T.D. ~ ~% S O ~ iPR_F~F.~T CONL)ITIQ_~f .2-.13,81 5553-5555 -5596 (F,C~) Isolation Sqz'd w/ 350 sxs "G" .2-14-81 5480-5482 5511' (Ret.) Isolation F~.~z'd w/ 350 sxs "G" · _ 2/14-81 5196-.5198 5392' (Ret.) Isolation Sqz'd w/ 350 sxs "G" .2'15-81 4868-4870 · 5116' (Ret.) Isolation Sqz'd w/. 350 sxs "G" -- , .2-15-81 4664-4666 4776" (Ret.) Isolation Sqz'd w/ 350 .~ "G"' .2-16-81 4614-4616 '4640 .(Ret..) Isolation Sqz'd w/ 350 .sxs ,,G" .2-16-8t 4280-4282 ~554' (Ret.) Isolation Sqz'd w/ 350 sxs '~G" __ 2-24-81 ~4~30-4650)''~' .5596' (F.C.) Production Open for Production S.S. (B-3, 4 HPP) .2-24.-81 ~ 5596' (F.C.)I Production ' Sqz'd w/300 sxs "G" '(B-4, 4 HPF) .2-26-81 4874-4876- 5596' .(F.C.)I Isolation Sqz'd w/200 sxs "G" .2-27-81 4848-4852 4864' (Ret.) Isolation .S~..z 'd w/300 sxs "G" ..2 .-. 31-81. -~ 4864' .(Ret') P~oduction Sqz;d w/100 sxs "G" (B-4 Snd) " .. 1-05-82 4874,4876 5582' Isolation Sqz'd ~/200 sxs "G" ,, 1-05-82 ' 48i8~ 4862' (Ret.)' Abandonment' Sqz'd w/500 sxs "G" '(B-4 Abdn) 1-08-82 ,~30-'4650~ 5582' Production Open for production S.S. (B-3,4. HPF) 1-213-82 15442-5454'/ 5596' (F.C-.) Production Behind ,'px" plug in ,,x, nipple (Beluga) --- 1-14-82 ~5462-54781 5596'. (F.C.) Produchion Behind "PX". plug in '"x' nipple (Beluga.) .1..-14~-82 i 5443_.-5553 i .55961. 0F.C. )1 Production _~[ ,/~d "PX". plug in "x.". nipple (Be]'.uga).~'i~'."-'.i~ 1-16-82 ~ 5462-54741 5596~' .(F.C.) Production -Behind "PX" p.lug in "x" nipple (Beluga) 1.-17-821L--B~52707 -537,3.' (x plg) Production Open for production L.S. (C-1 sand) ! I ~VELL PI~3ID__A~ S E M D~L Y TYPE:· ~;?;~ '_~?.~<[ - .. .. CASING HEAD:. 1'~ 3/8" SCW x 12"-3000 pSi. ' · CASING HANGER: 9 5/8" 7~- '/¢¢¢,J CASING SPOOL: TUBING HEAD:.,. CZW ~CB 10" 5000 pJi x 12" '30d0 psi TUBING HANGER: Dual Cameron. 3, 1/2" TO : F L£" MASTER VALVES: 3 1/2" . CHRISTMAS TREE TOP CONN.:_ LEASE Kenai Unit State UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. KU 934-32 SHEET O .. PAGE NO. FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1 150 1 14 1 147 Short String Tbg. Detail Description 3 1/2" Butt. tub collar. C~_is "X1N" Nipple. Baker "A-5" Eual 11 yd. Pkr. _o. 3~1/2'' Butt. N-80,9.29 tt~. pnp. Otis "X-A Sli~ ng Sleeve Jts. 3 1/2" N-80,9.2# Butt. th~. Mmas R.T. to 5~Dg./H~. Ze_ngth Top. Bottom 0.7' 4586.53 4586.60 1.21' 4585.32 4586.33 11.53' 4573.99 4585.32 5.10' 4568.89 4573.99 3.35' 4565.54 4568.89 4546.09' 19.~45 4565.54 19.45' -0- -0- Long String Tbg. Detail Bkr 3 1/2" Mule Shoe Bkr ~bd. "D" 9 5/8" Pkr w/21.35' Seal ~sbly. 3 1/2" N-80,9.2~/ft. Butt. tt~. Bkr Mod. "D" 9 5/8" Pkr set at 10.50 Seal ~tssbly. Bkr 3 1/2" Locator Sub. 3 1/2" N-80,9.2#/ft Butt. tt~. O~is 3 1/2" "XA" Sleev~ Pups 3 1/2" N-80,9.2#/ft Butt. Bkr Blast Jts 3 1/2" N-80,9.2#/ft Butt tbg.' Bkr "A-5" Dual Hyd. pkr 3 1/2" N-80,9.2#/ft Butt tbg Otis 3 1/2" "XA" Sleeve Ja. 3 1/2" N-80,9.2#/ft Butt. tt~ ~4~as. R.T. T/Hgr. .63' 5180.37 21.35' 5159.02 (PkrA. 30 set at 5166') 424.57' 4734.35 10.50' 4723.95 (PkrA. 30 set at 4726') .70' 4723.25 34.14' · 3.98 18.38 A9.33 29.14 12.74 27.97 4.05 4524.07 19.45 4689.11 4685.13 4666.75 4617.42 4588.28 4575.54 4547.57 4543.52 19.45 -0- 5181.00 5180.37 5159.02 4734.45 4723.95 4723.25 4689.11 4685.13 4666.75 4617.42 4575.54 4547.57 4543.52 -0- LEASE Kenai Unit UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. KU 34-32 SHEET D -, PAGE NO, FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS 49 13 3/8" Casing Detail Description B+W 13 3/8" Csg Shoe 13 3/8" K-55 619 csg B+W 13 3/8" Stab-in float collar 13 3/8" K-55 61# csg Top of 13 3/8" Csg Head to Top of Rotary Table. 1.8' 2029.00' 2027.20' 37.36 2027.20 1989.84 2.03 1989.84 1987.81 1969.15 1987.81 18.66 18.66 18.66 -0- 9 5/8" Casing Detail Description 9 5/8" Blcr float shoe 9 5/8" 479 N-80 csng. 9 5/8" Blcr float, collar 9 5/8" 47~ N-80 csng 1.82' 86.50 1.68 5577.34 Top 5684.18' 5597.68 5596.00 18.66 Bottom 5686.00' 5684.18 5597.68 5596.00 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE ~0. LEASE KENAI UNIT WELL NO. #34-32 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1 11/21/81 DAILY COST: ACC COST: AFE'AMT: 2 11/22/81 DAILY COST: ACC COST: AFE AMT: 3 11/23/81 $ 66,246 $ 66,246 $2,090,000 20" D. 87' 66 PCF 220 SEC $ 31,974 $ 98,220 $2,090,000 94'/94' 20" D. 87' 66 PCF 250 SEC DAILY COST: $ 38,662 ACC COST: $ 136,882 AFE AMT: $2,090,000 4 11/24/81 415'/321' 20" D. 87' 71PCF 210 SEC DAILY COST: $ 45,087 ACC COST: $ 181,969 AFE AMT: $2,090,000 5 11/25/81 721'/306' 20" D. 87' 70 PCF 158 SEC DAILY COST: ACC COST: AFE AMT: $ 30,896 $ 212,865 $2,090,000 6 11/26/81 1117'/396' 20" D. 87' 70 PCF 210 SEC DAILY COST: $ 27,238 ACC COST: $ 240,103 AFE AMT: $2,090,000 Brinkerhoff completed turnkey move & rig up of Rig #58 on KU #34-32. Commenced operations ~ 17:00 hrs ll/21/al. RU drive hammer. Drove 20" conouctor to refusal ~ 87' below RT (71' below ground level). Installed 20" SOW flange & 20" 2000 psi diverter assembly. Completed installing 6" diverter lines. RD on repairs for 6 hrs. Spud ~ 21:30 hrs. Drld 17 1/2" hole to 94'. Drld 17 1/2" vertical hole f/ 94' to 300' KOP. Survey - 1° drift ~ 300'. Trip for dyne-drill. Orient DD w/ single shot. DD 17 1/2" hole w/ bit #2 on BHA #2 f/ 300' to 415'. Dyna-drld 17 1/2" hole f/ 415' to 721'. POOH. (Rig down for repairs 10 hrs working on Tioga heater & drawworks clutch & brakes). Repaired drawworks. RIH w/ bit #3 on BHA #3. (Note: had to ream thru 20" drive shoe w/ NB stab). Direc- tionally drld 17 1/2" hole f/ 721' to 1117' w/ bldg assy. (Rig down for repairs 1 hr). UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE 'NO. LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7 11/27/81 2050'/933' 20" D. 87' 72 PCF 250 SEC DAILY COST: $ 29,223 ACC COST: $ 269,326 AFE ANT: $2,090,000 8 11/28/81 2050' TD 1988' ETD (FC) 20" D. 87' 13 3/8" C. 2029' 71PCF 220 SEC DAILY COST: $ 113,978 ACC COST: $ 383,304 AFE AMT: $2,090,000 9 11/29/81 2050' TD 1988' ETD (FC) 20" D. 87' 13 3/8" C. 2029' 70 PCF 64 SEC DAILY COST: $ 51,398 ACC COST: $ 434,702 AFE AMT: $2,090,000 10 11/30/81 DAILY COST: ACC COST: AFE AMT: 2050' TD 1988' ETD (FC) 20" D. 87' 13 3/8" C. 2029' 68 PCF 55 SEC $ 25,947 $ 460,649 $2,090,000 DD 17 1/2" hole f/ 1117' to 1461' w/ bldg assy. POOH. RIH w/ bit #4 on BHA #4. DD 17 1/2" hole f/ 1461' to 2050' w/ packed assy. (Rig down for repairs 3 hrs). Surveyed ~ 2050' bit depth. Circ clean w/ high vis pill. Pulled 5 stds. RIH. No fill. Circ clean. POOH. Ran 13 3/8" 61# K-55 butt csg. Landed w/ FS ~ 2029' & stab in FC ~ 1988'. RIH w/ 4 1/2" DP. Stabbed into FC $ 1988'. Circ clean. Cmtd 13 3/8" csg w/ 737 sxs cl "G" w/ 2 1/2% pre- hydrated gel & 2% CaCL2 followed by tail slurry of 563 sxs cl "G" w/ 2% CaCL2. Pumped 50 CF caustic water ahead & displaced w/ 1/2 the volume of DR. CIR ~ 07:30 hrs. POOH w/ DR. WOC. Cut off 13 3/8" csg & in- stalled 13 3/8" SOW X 12" 3000 psi csg head. Welded 20" to csg head gusset plate. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE 'NO. LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 11 12/1/81 DAILY COST: ACC COST: AFE AMT: 12 12/2/81 DAILY COST: ACC COST: AFE AMT:. 13 12/3/81 2050' TD 1988' ETD 20".D. 89' 13 3/8" C. 2029' 69 PCF 50 SEC $ 21,436 $ 482,135 $2,090,000 2132'/82' 20" D. 87' 13 3/8" C. 2029' 68 PCF 42 SEC $ 35,082 $ 517,217 $2,090,000 3700'/1568' 20" D. 87' 13 3/8" C. 2029' 70 PCF 52 SEC DAILY COST: $ 34,154 ACC COST: $ 551,371 AFE AMT: $2,090,000 14 12/4/81 DAILY COST: ACC COST: 4119'/419' 20" D. 87' 13 3/8" C. 2029' 70 PCF 52 SEC $ 111,338 $ 662,709 Installed & tested BOPE. RIH w/ slick BHA. Tagged cmt 8 1961' CO cmt to FC ~ 1988' & teste~ csg to 2500 psi. Drld FC ~ 1988' & CO cmt to 2008' & re- tested csg to 2500 psi - ok. Drld shoe ~ 2029' & new hole to 2060'. Pulled into csg & testeO csg shoe to leak off. Shoe held 87 1/2 PCF equiv. POOH. RIH w/ angle bldg assy i.e. blt #6 on BHA #6. DD 12 1/4', hole f/ 2060' to 2132'. DD 12 1/4" hole f/ 2132' to 3700'. POOH. RIH w/ bit #7 on BHA #7. Thawed out surf equip that froze during trip. DD 12 1/4" hole f/ 3700' to 4119'. AFE AMT: $2,090,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 15 12/5/81 4710'/591' 20" D. 87' 13 3/8" C. 2029' 69 PCF 48 SEC DAILY COST: $ 29,511 ACC COST: $ 692,220 AFE AMT: $2,090,000 16 12/6/81 5575'/865' 20" D. 87' 13 3/8" C. 2029' 70 PCF 50 SEC DAILY COST: $ 26,744 ACC COST: $ 718,964 AFE AMT: $2,090,000 17 12/7/81 5700'/125' 20" D. 87' 13 3/8" C. 2029' 71 PCF 50 SEC DAILY COST: $ 64,322 ACC COST: $ 783,286 AFE AMT: $2,090,000 18 12/8/81 DAILY COST: ACC COST: . · AFE AMT: 19 12/9/81 DAILY COST: ACC COST: 5700' TD 5700' ETD 20" D. 87' 13 3/8" C. 2029' 71 PCF 57 SEC $ 89,696 $ 872,982 $2,090,000 5700' TD 5700' ETD 20" D. 87' 13 3/8" C. 2029' 70 RCF 42 SEC $ 21,395 $ 894,377 OD '12 1/4" hole f/ 4119' to 4689'. POOH. RIH w/ bit #8 on BHA #7. DD 12 1/4" hole f/ 4689' to 4710'. DO 12 1/4" hole f/ 4710' to 5575'. POOH. RIH w/ bit #9 on BHA #7. Wash to btm. OD 12 1/4" hole f/ 5575' to 5700'. C&C hole for logs. Short trip to Shoe (haO 8' fi11). Circ clean. POOH. Ran Schlumberger DIL-SP-BHC- Sonic-GR & FDC-CNL-GR f/ i3 3/8" shoe to 5691' WL TD. RIH. C&C hole for 9 5/8" csg. POOH. RU csg tools. AFE AMT: $2,090,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE ~0. LEASE KENAI UNIT WELL NO. #~4-~2 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 20 12/10/81 5700' TO 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' 70 PCF 48 SEC DAILY COST: $ 308,949 ACC COST: $1,203,326 AFE AMT: $2,090,000 21 12/11/81 5700' TD 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' 70 PCF 48 SEC DAILY COST: $ 31,027 ACC COST: $1,234,353 AFE AMT: $2,090,000 22 12/12/81 5700' TD 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' 71PCF 42 SEC DAILY COST: $ 38,910 ACC COST: $1,273,263 AFE AMT: $2,090,000 23 12/13/81 DAILY COST: ACC COST: AFE AMT: 5700' TD 5502' ETD (RET) 13 3/8" C. 2029' 9 5/8" C. 5686' 70 PCF 40 SEC $ 57,669 $1,330,932 $2,090,000 Ran 9 5/8" 47# butt csg to 5686'. Landed csg w/ FS ~ 5686' & FC ~ 5596'. Cmtd 9 5/8" csg w/ 1730 sxs ,G" w/ 3% KCL, .6% D-19, .3% D-31 & .2% D-6. Bumped plug w/ 419 bbls of muO. CIP ~ 12:40 hrs. Removed BOPE, set slips, cut off 9 5/8" csg & install CIW DCB spool. Installed CIW DCB spool & BORE. Tested BORE to 3000 psi. RIH w/ 5" HWDP. LD 5" HWDP. RIH w/ 8 1/2" bit. Tagged FC ~ 5596'. Circ clean. Tested 9 5/8" csg to 3000 psi. POOH. RU Dresser Atlas. Ran CBL-VDL-GR f/ 5586' WLTD to top of cmt. Ran SDC gyro. Perfed 4 HPF f/ 5553' to 5555' for sqz #1 in Beluga. Set cmt ret on WL ~ 5502'. RIH w/ DR stinger. Broke down perfs w/ 2500 psi & pumped into same w/ 2400 psi 6 BRM. Formation held 800 psi w/ pumps off. Sqz'd perfs f/ 5553' to 5555' w/ 350 SXS "G" w/ 3% KCL, .6% D-19, .6% D-31 & .2% D-6. Final rate 4 BPM 6 2600 psi, formation halo 1400 psi w/ pumps off. Rev clean. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 24 12/14/81 DAILY COST: ACC COST: AFE AMT: 25 12/15/81 DAILY COST: ACC COST: AFE ANT: 5700'TD 5400' ETD (RET) 13 3/8" C. 2029' 9 5/8" C. 5686' 71PCF 39 SEC $ 46,297 $1,377,229 $2,090,000 5700' TD 4640' ETD (RET) 13 3/8" C. 2029' 9 5/8" C. 5686' 70 PCF 37 SEC $ 66,734 $1,443,963 $2,090,000 Perfed 4 HPF f/ 5480, to 5482' for sqz #2. RIH & set cmt ret on DR ~ 5400'. Could not break dwn below ret. Broke down above ret ~ 1400 psi. Strapped DR out of hole. De- termined that ret is set ~ 5491'. RIH & set ret & 5400' Broke down perfs f/ 5480' to 548~' w/ 1400 psi & established inj rate ~ 3 BRM w/ 1300 psi. Formation.held 650 psi w/ pumps off. Sqz'd perfs w/ 350 sxs "G" w/ 3% KCL, .6% D-19 & .6% D-31 & .2% D-6. Final rate 6 BRM ~ 1800 psi. Form held 1000 psi w/ pumps off. Rerfed 4 HRF f/ 5i96' to 5198'. Set ret on DP ~ 5116'. Broke down perfs f/ 5196' to 5198' w/ 1100 psi. Rumped into perfs w/ 3 1/2 BRM 8 1050 psi. Form held 500 psi w/ pumps off. Sqz'd perfs f/ 5196' to 5198' w/ 350 sxs "G" w/ 3% KCL, .7% D-19, .7% D-31 & .2% D-6. Final rate 4 1/2 BPM ~ 1750 psi, form held 1200 psi w/ pumps off. Perfed for sqz #4 f/ 4868' to 4870'. Set ret ~ 4776' on DP. Broke down perfs w/ 1000 psi. Pumped in ~ 4 1/2 BPM ~ 1750 psi. Held 80 psi w/ pumps off. Sqz'd perfs f/ 4868' to 4870' w/ 350 sxs "G" w/ 10% silica flour, 5% KCL, .75% D-31, .7% D-19, .2% A-2 & .2% D-6. Final rate 3 BRM ~ 1500 psi, held ll50 psi w/ pumps off. Rerfed for sqz #5 f/ 4664' to 4666'. Set ret on WL ~ 4640'. RIH w/ DR. Broke down perfs f/ 4664' to 4666' w/ ll50 psi, pumped into perfs w/ 4 BRM ~ llO0 psi, held 400 psi w/ pumps off. Sqz'd perfs w/ 350 sxs "G" w/ 10% silica flour, 5% KCL, .75% D-31, .7% D-ig, .2% A-2 & .2% D-6. Final rate 3 BRM ~ 1400 psi, held 900 psi w/ pumps off. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE 'NO. LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD . DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 26 12/16/81 DAILY COST: ACC COST: AFE AMT: 27 12/17/81 DAILY COST: ACC COST: AFE AMT: 28 12/18/81 · . DAILY COST: ACC COST: AFE AMT: 5700' TD 4214' ETD (RET) 13 3/8" C. 2029' 9 5/8" C. 5686' 69 PCF 36 SEC $ 80,909 $1,524,872 $2,090,000 5700' TD 4289' ETD (CMT) 13 3/8" C. 2029' 9 5/8" C. 5686' 69 PCF 36 SEC $ 71,602 $1,596,474 $2,090,000 5700' TD 4639' ETD (CMT) 13 3/8" C. 2029' 9 5/8" C. 5686' 68 PCF 36 SEC $ 23,198 $1,619,672 $2,090,000 POOH w/ DP. Perfed for sqz #6 f/ 4614' to 4616'. Set ret on DP ~ 4554'. Broke down perfs f/ 4614' to 4616' w/ 1300 psi & pumped in w/ 3 BRM ~ 900 psi, held 250 psi w/ pumps off. Sqz'd perfs f/ 4614' to 4616' w/ 350 sxs "G" w/ 10% silica flour, 5% KCL, .75% D-31, .7% D-19, .2% A-2 & .2% D-6. Final rate 3 BRM ~ 850 psi, held 850 psi w/ pumps off. Rev clean & POOH. Rerfed for sqz #7 f/ 4280' to 4282'. Set ret on DR ~ 4214'. Broke down perfs f/ 4280' to 4282' w/ 1250 psi, pumped in ~ 3 1/2 BRM ~ 950 psi, held 400 psi w/ pumps off. Sqz'd perfs f/ 4280' to 4282' w/ 350 sxs "G" w/ 10% silica flour, 5% KCL, .75% D-31, .7% D-19, .2% A-2 & .2% D-6. Final rate 3 BRM ~ llO0 psi, held 900 psi w/ pumps off. Rev clean. POOH. WOC. RIH w/ 8 1/2" bit. Drl out ret 8 4214'. Cmt below ret - soft. WOC. CO cmt f/ 42i4' to 4289'. Drld out frm cmt f/ 4289' to 4295'. RIH to 4557'. 'Drld out ret & cmt to 4590'. Trip for bit. Drld out cmt to 4639'. UNION OIL CONPANY OF CALIFORNIA WELL RECORD SHEET D · PAGE NO. LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 29 12/19/81 DAILY COST: ACC COST: AFE AMT: 30 12/20/81 5700' TD 5497' ETD (RET) 13 3/8" C. 2029' 9 5/8" C. 5686' 65 PCF 35 SEC $ 23,542 $1,643,214 $2,090,000 5700' TD 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' 65 PCF 35 SEC DAILY COST: $ 21,358 ACC COST: $1,664,572 AFE AMT: $2,090,000 31 12/21/81 DAILY COST: ACC COST: AFE AMT; 32 12/22/81 DAILY COST: ACC COST: 5700' TD 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' 66 PCF 33 SEC $ 46,620 $1,711,192 $2,090,000 5700' TD 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' BRINE $ 20,370 $1,731,562 Drld out hard cmt & retainers to 5497' w/ bit trip ~ 5449' (rets 4640', 4776', 5116' & 5400'). Drld out cmt & rets to FC ~ 5596' ETD. (Note.: Rets ~ 5497' & 5502'). Ran Dresser Atlas CBL-VDL-GR log. RIH w/ 8 1/2" bit .& 9 5/8" csg scrpr to 5596'. Circ clean. POOH. RIH w/ test tools. Displaced DR w/ w/ nitro to +4600'. Set RTTS 6 5133'. Opene--~ tool & dry tested sqz Perfs f/ 5553' to 5555', 5480' to 5482' & 5196' to 5198'. Rev clean- no entry. Picked up to 4530'. Dis- placed DR w/ nitro to +4000'.drySet RTTS ~ 4530'. Openee~ool & tested sqz perfs f/ 4868' to 4870', 4664' to 4666' & 4614' to 4616'. Rev clean - no entry. Rig down test manifold. POOH. LD test tools. RIH w/ 8 1/2" bit & 9 5/8" csg scrpr to 5596'. Dumped & cleaned pits. AFE AMT: $2,090,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 33 12/23/81 5700' TD 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 RCF 34 SEC DAILY COST: $ 40,437 ACC COST: $1,771,999 AFE AMT: $2,090,000 34 12/24/81 DAILY COST: ACC COST: AFE AMT: 35 12/25/81 DAILY COST: ACC COST: AFE AMT: 36 12/26/81 DALLY COST: ACC COST: AFE AMT: 5700' TD 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 PCF 29 SEC $ 43,438 $1,815,437 $2,090,000 5700' TD 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 PCF 34 SEC $ 58,836 $1,810,853 $2,090,000 5700' TD 4864' ETD (RET) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 PCF 30 SEC $ 41,358 $1,852,213 $2,090,000 X-over to KCL comp fluid. POOH. RIH w/ RTTS to 4503' w/ tail to 4539'. Displaced DP w/ N2 & set RTTS ~ 4503'. RU test manifold. Pressure tested test manifold (spent 8 hrs changing out valves until man- ifold would test). Inflowed perfed the B-3 w/ 4 HRF f/ 4630' to 4650' & the B-4 f/ 4807' to 4852' (well starteO making lots of water when B-4 was perfed). Flowed 8-3 & 8-4 thru separator for 12 hrs. Rate avg'd 3.5 MMCFPD w/ 1150 BWPD ~ 675 psi. Spot 30 bbl pill w/ 30 ppb CaC03 across perfs- well taking fluid fast. Reset pkr ~ 4605'. Built surf volume & spot- tee 140 bbls high vis pill w/ 30 ppb CaCO across perfs. Well took 130 bbls total into 8-3 & 8-4 perfs before loss circ stopped. RIH w/ RTTS to 4685'. Displaced DR w/ N2 & set RTTS ~ 4685'. RU test manifold. Attempted to bring well on but could not produce to surf. Displaced DR w/ N2 & at- tempted to produce - no luck. Dis- placed w/ N2 & tried again. B-4 perfs making too much water to pro- duce to surf. KilleO well & POOH. Rerfed 4 HRF f/ 4874' to 4876'. Set cmt ret on WL ~ 4864'. RIH w/ DR. UNION OIL CONPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 10 LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 37 12/27/81 DAILY COST: ACC COST: AFE ANT: 38 12/28/81 5700' TD 4756' ETD (RET) 13 3/8" C, 202~' 9 5/8" C. 5686' 64 PCF 30 SEC $ 34,402 $1,906,345 $2,090,000 5700' TD 4760' ETD (CMT) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 RCF 29 SEC DAILY COST: $ 25,042 ACC COST: $1,931,747 AFE AMT: $2,090,000 39 12/29/81 DAILY COST: ACC COST: 5700' TD 4817' ETD (CNT) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 RCF 30 SEC $ 25,835 $1,957,582 Broke down perfs f/ 4874' to 4876' w/ 2000 psi. Initial rate 3 BPM ~ 2100 psi, formation held li50 psi w/ pumps off. Sqz'd perfs f/ 4874' to 4876' w/ 200 sxs "G" w/ 3% KCL, .6% 0-19, .6% D-31, & .2% D-6. Final rate 4 BRM ~ i800 psi, form held 1000 psi w/ pumps off. POOH. RIH w/ 8 1/2" bit & CO to ret ~ 4864'. POOH. Rerfed 4 HRF f/ 4848' to 4852'. Set ret on WL ~ 4756'. RIH. Broke down B-4 perfs w/ 750 psi. Initial rate 3 8PM ~ 900 psi, form halo 500 psi w/ pumps off. Sqz'd B-4 perfs w/ 300 sxs "G" w/ 5% sd, 5% silica flour, .75% D-31, .7% D-19, .2% D-6, .2% A-2 & 5% KCL. Final rate 4 BRM ~ 2400 psi, form held 2033 psi~w/ pumps off. POOH. RIH w/ 8 1/2" bit. CO cmt f/ 4710' to ret $ 4756'. WOC 16 hrs total. CO ret ~ 4756' & soft cmt to 4760'. POOH. RIH w/ RTTS & aux valve. Set RTTS ~ 4535'. Installed & tested test manifold. Opened aux valve. Test lines to separator froze when fluid to surface. Thawed test lines. Tested 8-3 perfs f/ 4630' to 4650'. Rate averaged 6.0 MNCFPD & 5 BWPD ~ 700 psi during last 3 hrs of test. Killed well, POOH. RIH w/ 8 1/2" bit. CO cmt to 4817'. AFE ANT: $2,090,000 UNION OIL CONPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. ll LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD DETAiLs OF OPERATIONS, DESCRIPTIONS & RESULTS 40 12/30/81 DAILY COST: ACC COST: AFE ANT: 41 12/31/81 DAILY COST: ACC COST: AFE ANT: 42 1/1/82 DAILY COST: ACC COST: 5700' TD :5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 RCF 42 SEC $ 30,397 $1,987,979 $2,090,000 5700' TD 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 PCF 44 SEC $ 49,338 $2,027,317 $2,090,000 5700' TD 4820' ETD (FISH) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 PCF 45 SEC $ 34,817 $2,072,134 CO cmt f/ 4817' to 4864'. Drld out ret ~ 4864' No cmt under ret. RIH to 5326'. ~0 cmt f/ 5326' to 5400'. CO sO f/ 5400' to 5596'. Circ clean. POOH. RIH w/ 8 1/2" bit & csg scrpr. Tagged sd ~ 5424'. CO sd f/ 5424' to 5596'. Circ clean w/ high vis.sweep (rec +6 bbls total of gray-black form sd). .POOH. RIH w/ test tools. Displaced DP w/ nitrogen & set RTTS ~ 4727'. .Inflow perfed the B-4 f/ 4807' to 4827' w/ 200 psi nitrogen cushion. Opened well to flare ~ 10:03 hrs. Fluid & gas to surface ~ 10:12 hrs. Well making lots of sd. Attempted to POOH w/ perf gun. Gun stuck in test tools. Pulled out of rope socket. Put well in test separator, 6 hr avg rate .30 MMCFPD, 950 BWPD .& 250 bbls sd per day ~ 100 psi. Killed well. POOH. RIH w/ RD OS w/ 9.7' ext. Tag fish 6 4819'. Wash over to 4837'. POOH. No recovery. RIH w/ OS w/ 14' ext. Tag fish ~ 4820'. AFE AMT: $2,090,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 12 LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 43 1/2/82 DAIL¥COST: ACC COST: AFE AMT: 44 1/3/82 DALLY COST: ACC COST: AFE AMT: 45 1/4/82 DAILY COST: ACC COST: AFE AMT: 5700' TD 4750' ETD (RET) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 PCF 46 SEC $ 35,163 $2,107,297 $2,090,000 5700' TD 4750' ETD (RET) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 PCF 46 SEC $ 23,091 $2,130,388 $2,090,000 5700' TO 5582' ETD (JUNK) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 RCF 46 SEC $ 33,495 $2,163,883 $2,090,000 Worked over fish ~ 4820'. Wash to 4833'. Made connection ~ 4833'. Unable to get back over fish 6 4820'. POOH. No rec. RIH w/ 20' wash pipe, globe basket & 8 1/4" X 5 7/8" shoe. Worked over fish ~ 4820'. Cleaned out sand f/ 4820' to 5596' (776' of sand in 9 5/8" 47# = 56.8 bbls). POOH. No rec. RIH & set cmt ret on DR 6 4750'. Broke down 8-4 perfs w/ 1250 psi. Initial rate 6 BPM ~ 750 psi. Held 50 psi w/ pumps off. Sqz'O B-4 perfs f/ 4807' to 4827' w/ 100 sxs "G" w/ 3% KCL, .6% D-lB, .6% D-31 & .2% D-6 followed by 300 sxs "G" w/ 10% sands, .75% D-J1, .7% D-lB, .2% A-2, .2% D-6 & 5% KCL. Final rate 1 3/4 BRM ~ 1400 psi, held 1300 psi w/ pumps off. Pulled out & dumped 4 bbls cmt on top of ret. POOH. WOC. RIH w/ 8 1/2" bit. Tagged cmt 6 4710'. CO green cmt to ret ~ 4750'. Drld out ret ~ 4750'. CO cmt stringers f/ 4750' to 5515'. CO cmt & sd f/ 5515' to 5582' EID. Circ clean w/ high vis pill. Recovered lrg amts of formation sd over shakers. POOH. Tight spot in csg 4820'. RIH w/ 8 1/2" watermelon mi11. Dressed out csg f/ 4815' to 4852' (8-4 perfs 4807' to 4852' DIL). RIH to 5582' - no fill. POOH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D .. PAGE NO. 13 LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD DETAILS. OF OPERATIONS, DESCRIPTIONS & RESULTS 46 115182 5700' TD 4862' ETD (RET) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 PCF 42 SEC DAILY COST: $ 64,543 ACC COST: $2,228,426 AFE AMT: $2,090,000 47 11:6182 DAILY COST: ACC COST: 5700' TD 4770' ETD (RET) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 PCF 40 SEC $ 35,076 $2,263,502 AFE AMT: 48 1/7/82 DAILY COST: ACC COST: AFE AMT: $2,090,000 5700' TD 5582' ETD (OUNK) 13 3/8" C. 2029' 9 5/8" C. 5686' 64PCF 39 SEC $ 25,219 $2,288,721 $2,090,000 RU DA. Perf'd 4 HPF w/4" csg. guns f/4874' to 4876'. Set cmt ret on WL ~ 4862'. RIH w/ DP & HOWCO stinger. BD PERF'S f/4874' to 4876' w/ 1900 psi. Pumped into perfs w/3 1/4 BPM ~ 1900 psi. Held 1200 psi w/pumps off. Sqz'd perfs w/200 sxs "G" w/3% KCL, .6% D-19, .6% D-31 & .2% D-6. FR 3 1/2 BRM 6 2050 psi. Held 1250 psi w/ pumps off. POOH. RIH w/ 8 1/2" bit & CO to cmt ret ~ 4862'. POOH. RU DA. RerfeO 4 HRF 2/ 4" csg guns f/ 4848' to 4852'. RD DA. RIH & set cmt ret on DP ~ 4770'. Sqz'O 8-4 for abandonment w/ 500 sxs "G" w/ 10% sd, .75% D-31, .7% D-ig, .2% A-2 .2% D-6, & 5% KCL. Form held lO00 psi w/ RO initially, & held 1050 psi after sqz. Initial rate 3 1/2 BRM ~ llO0 psi, final rate 3 1/4 BRM 6 1250 psi. POOH. RIH w/ 8 1/2" bit & CO to ret ~ 4770'. WOC. Drld ret ~ 4770'. Drld cmt f/ 4772' to 4868'. Drld ret ~ 4868' & cmt f/ 4868' to 4928'. RIH & pushed junk f/ 5500' to 5582'. Circ & POOH. RIH w/ 8 1/2" string mill & milled tight spot in csg f/ 4823' to 4845'. Reamed thru several times & RIH to 5582'. Pumped sweep & POOH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 14 LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 49 1/8/82 DAILY COST: ACC COST: AFE AMT: 50 1/9/82 5700' TD 5582' ETD (OUNK) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 PCF 39 SEC $ 41,575 $2,330,236 $2,090,000 5700' TD 5582' ETD (OUNK) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 PCF 40 SEC DAILY COST: $ 37,829 ACC COST: $2,368,065 AFE AMT: $2,090,000 51 1/10/82 5700' TD 5582' ETD (OUNK) 13 3/8" C. 2029' 9 5/8" C. 5686' 64 PCF 40 SEC DALLY COST: $ 19,650 ACC COST: $2,387,715 AFE AMT: RU Dresser Atlas. Tested lub & perfed 8-3 sd f/ 4630' to 4650' DIL. POOH. RD Dresser Atlas. RIH w/ bit & csg scrpr to 5582' - no tight spots. Circ & POOH. RU Dresser Atlas & nIH w/ 8 1/2" GR - could not go below 4710'. POOH - found pce of rubber on GR. nIH w/ 8 3/8" GR - stopped ~ 4820' POOH & RD Dresser Atlas. nIH w/ ~ 1/2" string mill & reamed tight spots f/ 4781' to 4794' & 4828' to 4869'. nIH to 5582'. Circ& POOH. nIH w/ OB to 5582'. Circ & mixed hi-vis sweep. POOH. RU Dresser Atlas. Ran GR to 5530'. POOH. nIH w/ Baker Model "D" pkr w/ mill out ex- tension & set ~ 5350' DI1. nIH w/ DP & tested pkr to 500 psi. POOH. nIH w/ Baker Model "D" pkr on WL & set ~ 5160' DI1. nIH w/ DP & tested pkr to 500 psi. POOH. nIH w/ Baker Model "D" pkr on WL & set ~ 4720' DIL. nIH w/ DP & tested pkr to 500 psi. POOH & LD DP. Fin LD DP & DC's. RU & ran 3 1/2" N-80 tbg. $2,090,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 15 LEASE KENAI UNIT WELL NO. #~4-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 52 1/11/82 DALLY COST: ACC COST: AFE AMT: 53 1/12/82 DAILY COST: ACC COST: AFE AMT: 54 1/13/82 DAILY COST: ACC COST: AFE AMT: 5700' TD 5582' ETD (OUNK) 13 3/8" C, 2029' .9 5/8" C. 5686' 64 RCF 4O SEC $ 175,878 $2,563,593 $2,090,000 5700' TD 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' $ 35,473 $2,599,068 $2,090,000 5700' TD 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' $ 27,781 $2,626,849 $2,090,000 Ran dual 3 1/2" tbg strings. Stab'd into model "O" pkrs ~ 4720' & 9160' & tested seals - ok. Spaced out tbg. Could not turn tie-down pins in DCB spool. Changed out pins. Installed BRV & displaced LS w/ nitro. Landed tbg. Set plug in "XN" nipple in SS. Press up & set dual "A-5" pkr w/ nitro. Tested pkr to 500 psi - ok. POOH w/ WL - plug had sheared off setting tool. Fished for plug in "XN" nipple. Fish "XN" plug f/ "XN" nipple ~ +4587'. Installed BRV's. Remove tree. Installed & tested dual CIW 3 1/2" tree. Removed BRV's. RU Otis & open "XA" sleeve ~ 4566' in SS. Displaced 9 5/8" X Oual } 1/2" annulus w/ pkr fluid. Displaced SS to "XA" sleeve ~ 4566' w/ nitrogen. Closed "XA" sleeve ~ 4566'. In- stalled & tested test lines to 3000 psi w/ nitrogen. Flow 8-3 perfs thru SS. Rate +5.00 MMCFPD ~ 700 psi & +10 BWPD. S-hut in SS. Inflow perfe-6 Beluga f/ 5442 to 5454'. No apparent entry. Open- ed "XA" ~ 4685' in LS. Flowed B-3 perfs thru "XA" in LS ~ 4685'. Rec 19 bbls water f/ LS in 4 hrs. Shut in B-3. Closed "XA" ~ 4685'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D -. PAGE NO, 16 LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 55 1/14/82 DAILY COST: ACC COST: AFE AMT: 56 1115/82 DAILY COST: ACC COST: AFE AMT: 57 1/16/82 DAILY COST: ACC COST: AFE AMT: 58. 1/17/82 DAILY COST: ACC COST: 5700' ID 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' $ 32,957 $2,659,806 $2,090,000 5700' TD 5596' ETD (FC) 13 3/8" C. 2029' 9 5/8" C. 5686' $ 39,118 $2,698,924 $2,090,000 5700' TD 5373' ETD (X Plug) 13 3/8" C. 2029' 9 5/8" C. 5686' $ 29,362 $2,728,286 $2,090,000 5700' TO 5373' ETD (X Plug) 13 3/8" C. 2029' 9 5/8" C. 5686' $ 26,073 $2,754,359 Perfed Beluga w/ 4 HPF using 2 1/16" rigid jet guns f/ 5462' to 5478' No apparent entry. Opened "XA" in LS ~ 4686' & flared B-3 thru L$. No water above "XA" in LS. Closed "XA" - still no flow f/ Beluga. Perfed Beluga w/ 4 HPF f/ 5543' to 5553'. Had slight entry, dead in 5 min. Filled L$ w/ fluid. Broke down Beluga perfs w/ 900 psi. Injected 2 3/4 BPM ~ 700 psi. Held 500 psi w/ pumps off. Blew down LS w/ nitro thru "XA" ~ 4686'. Close "XA" ~ 4686'. Acid- ized Beluga perfs w/ 2000 gal 7 1/2% MSR lO0 w/ .75% A-200. Displ acid w/ nitro. Final press 2900 psi - bled to 2500 psi immediately when nitro hit perfs. Opened Beluga to flare. Initial rate 1.5 MMCFRD ~ 600 psi, .5 MMCFRD ~ 300 psi in i hr & dead in i 3/4 hrs. Rec 68 bbls H20 & sd ~ surface. RU DA. Displ LS w/ nitro. Perfed Beluga f/ 5462' to 5474' (Tagged sd ~ 5505' prior to perf). Flowed Be- luga to flare. Initial rate 2.2 MMCFRD ~' 600 psi - well dead in 1 hr. Ran 5 hr static press survey (fluid level ~ 3000' & sd ~ 5496'). Set Otis "RX" plug in "X" nipple ~ 5373'. Opened "XA" ~ 4686' & cleaned up LS w/ B-3 perfs. Closed "XA". Inflow perfed C-1 sd f/ 5207' to 5270' w/ 4 HPF using 2 1/16" rigid jet guns. Rate approx 8.98 MMCFRD ~ 1050 psi. AFE AMT: $2,090,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D · PAGE NO. 17 LEASE KENAI UNIT WELL NO. #34-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1/18/82 5700' TD ~ 5373' ETD (X Plug) 13 3/8" C. 2029' 9 5/8" C. 5686' DAILY COST: $ 51,542 ACC COST: $2,805,901 AFE AMT: $2,090,000 60 1/19/82 5700' TD 5373' ETD (X Plug) 13 3/8" C. 2029' 9 5/8" C. 5686' DAILY COST: $ 16,445 ACC COST: $2,825,346 AFE AMT: $2,090,000 61 1/20/82 DAILY COST: ACC COST: AFE AMT: 62 1/21/82 DAILY COST: ACC COST: 5700' TO 5373' ETD (X Plug) 13 3/8" C. 2029' 9 5/8" C. 5686' $ 18,893 $2,844,239 $2,090,000 5700' TD 5373' ETD (X Plug) 13 3/8" C. 2029' 9 5/8" C. 5686' $ 20,416 $2,864,644 Inflow perfed "C-i" sd 8 HPF total w/ 2 1/16" rigid jet guns f/ 5207' -to 5270'. Rate 10.8 MMCFRD ~ 900 psi - dry gas. Installed BRV's. Released rig to moving rate ~ 18:00 hrs. LD Oerrick& prep to move rig. Continued to rig down & prep to move rig to KU #11-17. Continued general rig down on KU #34-32. Released rig f/ KU #34-32 ~ 24:00 hrs 1/21/82. AFE'AMT: $2,090,000 AMF / SCIENTIFIC DRILLING 1111 E 80TH ANCHORAGE AK, GYROSCOPIC DIRECTIONAL SURVEY FOR ~UNIO~. OIL OF CALIFORNIA~ JOB NUMBER: 4961 WELL NAME: K, U, 34-32 LOCATION: SURVEY DATE: KENAI GAS FIELD 12/13/81 SURVEY ENGINEER: CHAPPELL VERTICAL SECTION: COMMENTS: METHOD OF CALCULATION: THE RADIUS OF CURVATURE CALCULATED USING PROPOSAL~ OF S 39-46 W REFERENCE BEARING · THIS SURVEY IS CORRECT TO THE BEST OF MY ~ COMPANY REPRES[~T~TIVE ~ JOB NUMBER: qEAS, VERT. VERT, }EPTH DEPTH SECT, ,, AMF./ SCIENTIFIC DRILLING 1111 E 80TH ANCHORAGE Al(, INRUN SURVEY BY THE RADIUS OF CURVATURE COURSE INC BEARING DEV, D M D M PAGE 1 DATE: 12/13/81 199,98 1 ,32 2',41 299.92 3.35 3,50 399,78 7,24 5,29 499.55 13,62 6,74 598,96 24,11 1 0 , 65 ?00,00 697,58 40,01 16,50 300,00 795.47 59,98 20,43 ?'0(),00 892.76 82,67 23,10 ~00.00 989,28 108,43 26,12 lO0,O0 1084.71 138,02 '"29,86 171.78 210.03 253.43 300,93 350.16 ]00.00 1178,75 ]00.00 1271.05 ;00,00 1361.06 500,00 1448.98 ~00.00 1535.95 COORDINATES LATITUDE DEPARTURE PER 1-23 N 83-20 W ,28 N 2,40 W 2-38 N 88-. 4 W ,54 N 5,89 W 3-26 S 72-27 W ,17 S 11,11 W 4-18 S 39-48 W 3.88 S 16,63 W 7-56 S' 22-26~W.i.' 12,97.1'.S'~::' 22,12 W .... . :.. .~ ,: > : 12-31 S 28-52',W 46,14 S~.:'~ :~:,38,32 W 14-12 S 29- 5 W 66,35 S 49,52 W 16- 5 S 31-26 W 88,91 S 62,68 W 18-40 S 32-36 W 114,23 S 78,51 W 33,99 38,44 43,54 47,64 49,36 21- 5 S 33-28 W 24- 8 S 34-52 W 27-30 S 35-17 W 29-24 S 35-37 W 29-45 S 35-45 W 142,73 S 97,04 W 174,53 S 118.62 W 210,17 S 143,65 W 248,97 S 171,27 W 289,06 S 200,06 W D-LEG 100 ,69 1 ,26 1 .29 2 4,04 3,19 1 ,56 I ,68 1 ,98 2,61 2,43 3,10 3.37 1 ,91 JOB NUMBER: 4961 ~EAS. VERT, VERT, ) I:-" I~ TH DEP TH SECT, ;'l.lO, O0 1622,70 2;99.75 JO0,O0 1709,24 449,67 ~00,00 '1795.62 499.83 100.00 1881 ,91 550,17 .00.00 196'7.87 601 ,12 ~00 , O0 2053.59 652.56 ~00 , 00 2139,12 704 , 26 ;'00 , 00 2224 , 30 756 , 64 ~00,00 2309,25 809,35 ~00 . 00 23~:1 , 29 861 , 88 '00, O0 2479,22 914,60 '.00. O0 2563.81 967,92 ~00.00 2648.05 1021.79 ;00.00 2732.08 1076,00 .00,00 2816.05 1130,24 AMI-'-"/ 1111 SCIENTIFIC DRILLING E. 80TH ANCHORAGE Al<, P A G E 2 DATE: 12/13/81 INRUN SURVEY · BY THE RADIUS OF CURVATURE COURSE IN(: BEARING DEV, ,D H D H COORDINATES LATITUDE I)EPARTURE PER 49.74 29-54 S 34-53 50,11 30-15 S 34-38 · ,"50,2;8 30-15 S 34-28 50 54 30-28 51,10 31- 0 S- 35-50 51,56 31- 3 S 51,80 31-21 S 52,39 31-50 S 52,78 31-51S 52,62 31-39 S W 329,64 S W 370,81 S W 4'12,,30 S W 453,88 S W 4~5,57 S . ,, 35-57:W' 537,34'.S 36-22 W 36-21W 36.-37 W 36-31W 228,82 W 257,39 W 285,95 W 314,68 W 344,23 W · ,374,45 W 57~?,17 S ~ 405,02 W , 621,43 S 436,13 W 663,87 S 467,52 W 706,13 S 4~78,86 W 52,78 ,32- 4 S 53,34 32.-24 S 53,89 32-49 S 54,22 32-51 S 54,26 32-53 S 37-52 W 748,17 S 530,77 W 38-16 W 790,17 S 563,66 W 38-16 W 832,48 S 5S~7,03 W 38--47 W 874,89 S 630,80 W 38:.-54 W 917,14 S 664,82 W D-LEG 100 ,46 ,37 ,08 ,28 ,74 ,08 ,37 ,48 ,14 .21 ,83 ,40 ,42 .28 .07 AMF / SCIENTIFIC I)RILLING 1111 E 80TH ANCHORAGE AK, P A (.3 E 3 JOB NUMBER: 4961 flEAS, VERT, VERT, }EPTH DEPTH SECT , INRUN SURVEY BY THE RADIUS OF CURVATURE COURSE INC BEARING DEV, D H D M !ZO0.O0 2899.55 1185,27 55,04 :33-54 S ~lO0.O0 2982.27 1241,45 56,18 34-28 S ;00,00 3064,34 1298,59 57,13 :35-13 S 500,00 3145,74 1356,69 58,09 :35-49 S ~00,00 3226,70 1415,:38 58,70 36- 4 S- 0 3307,44 1474,:38 0 3388.20 153:3,:35 0 3469,33 1591,79 0 3550.82 1649,76 0 3632,53 1707,41 DATE: 12/13/81 ? 00,0 ]00,0 )'00.0 :) 00,0 LO0, 0 _~ 00,0 .; 00.0 100. 0 ~00.0 ;00,0 0 3714.:37 1764,89 0 3796,:39 1822,08 0 3878.79 1878,74 0 3961.52 19:34.92 0 4044.47 1990,79 COORDINATES D-LEG LATITUDE DEPARTURE PER 100 59,00 :36-15 S 58,98 36- 2 S 58,45 35-:30 S 57,96 35-21 S 57,66 35- 4 S :39.- 7 W 959,91 S 699,46 W :39-11 W 100:3,48 S 7:34,94 W ,57 39-39 W 10'47,62 S 771,22 W ,80 :39-28 W 1092,42 S 808,22 W ,61 2;9-42 W ..11;5'7,65 S.~ 845,62 W .29 , 40-2i W 1182183 S 88:3,57 W .'43 40-27 W '1227,75 S 921,79 W ,22 40-58 W 1272,05 S 959,91 W ,61 40-54 W 1315,86 S 997,89 W ,15 39-20 W 1359,95 S 1035,04 W ,95 1 ,02 57,48:35- 6 S 57,20 34-41 S 56,66 34-21 S 56,17 34- 0 S 55,87:33-56 S 40- 3 W 1404,17 S 1071,75 W ,41 :39-'55 W 1447,99 S 1108,50 W .42 39--22 W 1491,63 S 1144,65 W .46 39-49 W 1534,92 S 1180,45 W ,43 40-50 W 1577,51S 1216,61 W .57 JOB NUMBEI~: '~ E A S , V E R T , )EP TH DEP TH ?00,00 41 27 ]00 , 00 4211 ;~00 , 00 4294 ] 00 , O0 437E1 [ 00 , 00 4462 ~ 00,00 4546 ~00 , 00 4631 ;'00 , 00 471 6 .~00 , 00 4800 .";50 , 00 41343 A M F:' / S C I I:'] N T I F I C D R I I... L I N G 1111 E 80TI"I ANCHORAGE Al<, P A [.; Ii: 4 4961 DATE: 12/13/81' I N R JJ N S IJ R V EY BY THE RAI) IUS 01"' CURVATURE V I-] R l', SECT, CC)UR SE I NC BEAR I NJ; DEV, D M I) M C (] 0 R D I N A T i"_ ,.~ D - L_ E [-; LA'I"ITUDE DEPARTURE PIER 100 ,55 2046,41 55,64 33'-41 S 41'-19 W ,00 2101,51 55,11 33-12 S 40"-27 W ,94 2155,86 54,35 32-39 S 39-56 W .97 2210,06 54,21 33- 0 S 39--30 W .138 2264.48 54,41 32-56 S-39- ? W 1619,46 S 1253,16 W ;37 1661,12 S 1289,23 W ,68 1702,64 S 1324,31 W ,62 1'744,33 S 1,3.58,94 W ,42 17El6,44 S 1393,42 W .22 .97 231El,60 54.12 32-36 S 39-35 W .41 2372,16 53,57 32'-11 S 38""59 W ,13 2425.28 53,13 32- 0 S 39-32 W ,98 2478,21 52.93 31-55 S 40'-54 W ,45 2504,62 26,39 31-48 S 40-56 W 1828.29 S 1427.73 W ,42 1869,75 S 1461,65 W ,53 1910,El8 S 1495,27 W ,34 1951.30 S 1529,44 W ,73 1971.27 S 1546,74 W ,24 THE H[]RIZONTAL DISPI_ACEMENT AT THE DEPTH OF 555[],(]0 FEET EQUALS 2505,66 FLEET AT S 38- 7 W, SUggested form to be inserted 'in each "Active" well folder to check for timely compliance with our regulations. Operator, Well Name and Number Reports and Materials to be received by: Date Required. Date Received Remarks Comp letiOn Report Yes Well History Yes 3 --~/?--' ~Z ~ ~/' e'' , -Pt ..... a K Mud L~ , .....~- PI Core ~scription , -- : .. ~~_~~ ..... ,~ d~.~ -- ..... Drill St~ Test RemUs ~~ '~'e , .... ~ ~ , , ,, ~ , .. , .... , ........... .......... ~ , ., . ~ . , ,, ~..% ,, . ,. ., - , , ....... ~3~, .~ ,. ~ Union Oil and Gas Division: Western Region Union Oil Company ¢ '~lifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 R. C. Warthen District Development Geologist Alaska District April 27, 1982 Mr. William Van Alen State Oil and. Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Bill' Enclosed is the data you requested as per your letter of 4-22-82. As you check the document of transmittal,.you will note several items are missing. They are as follows' ' TBU D-9 RD Library tape; th-is tape is currently being redone and ~reproduced by. SchlUmberger. TBU K-3 RD Well History; Union Oil as TBU Operator has no receipt of receiving this history from ARCo - suboperator. We are currently checking with ARCo on thi~ matter. Cannery Loop LibrarY tape; as a confidential well, the logs have never Unit #3 been composited by Schlumberger and therefore a library tape is not aVailable. When available, the tape will be ........................... ~ .... delivered to the 0il and Gas Commis'sion. KU 34-32--"~"% Test reports; these test reports have not been delivered -'! to Union Oil.-Co.- from Haliburton at this time. .¢~¢*'" R. C. Warthen RCW'nd Document Transmittal w Union Oil Company of California unlen Page '2 o~' o .. DATE 'SU'E~MIYTE'D ACCOUNTING MON~'~ 'l -- TO FROM ,~ . ,,,. Van 3,1en R C '&~rthen AT AT . ..... T~L~HON~ NO. TRANSMITTING THE ~OLLOWING: , , i ea:,, CerLiFied buFvey plaL " , ' No tes'L data awii~ble ..... . K6U 31 -/· DST ~est',l'.thru , - = PLEAoL Si..,,~ AhD KktU~,~ " nn~[- ' ' ' ' ,'~ , , : .', , ..... I i i i FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. · K U 34-32 Center of' Well Cellar Lat. 60°28'45.495" N Lono. 151°14'11.632" W X : 276,926.55 Y : 2,369,209.29 1/4 32 West-99g. 5 SCALE l" = 300' LEGEND AND NOTES'~ .. ~ Found GLo brass cap monument. All bearinqs refer to the east lineof Section.32, GLO datum N 0007' W. Top south corner of well cellar elevation is 76 32 feet above MLLW of Cook Inlet or 65.3 feet above MSL datum of O.O0-feet. Basis of Coordinates is USC&GS Tri Station AIJDRY in ASP Zone 4. AUDRY , Lat. 60°30' 50. 559 N . Lena. 151°16'37.445 W ~ X = 269,866.75 ~ ¥ = 2,382,045.45 KENAI UNIT 34- 3'2 PREPARED FOR UNION OIL COMPANY OF CALIF. OPERATOR SURFACE LOC^TION- 1972 Ft. Nort~h an~l 1000'Ft West. from the SE corner of Section 32, TSN, Rl lW, S.M., Alaska Surveyed by: McLane and Associates,' Inc. Date of Survey; Oct. lO-12, 1981 ' i Oil & Oas COns ' 'i,:e.Oor. ag~ C°tna~!saioa SE Corner. Sec. Bk. No. 81-31 i i ,-' SECU ITY BIT RECORD DRESSER INDUSTRIES, INC. OF ~ WELL NAME ,' WELL NO COUNT '' AREA CODE $~T .~ ]' E I' ' ' ~ *~. ;O SELF CONT PLAT ~/~'k\,.,_4,-:., L£,~"-~..' ,:,,,,_,_,:.,,.~.zL.._ .4 -~.o. ~"'~ -7 ~l o,o,-,-~o.,,,o~ -- ' JETS DEPTH ' FEET WT. PUMP PUMP ~DmOPERTI~ DULLCOND ~4 J J RUN SIZE TYPE SERIAL NO. 32 FEET HOURS PER 1000 RPM ~ REMARKS DATE~P~ I ~]~,~.~~ ~ ..~ ~ "$--..~ k , , ' · - -- ~ ' ' . PM-- 68 3-C SUBJECT T ~IONS ON REVERSE SIDE Mr, Robert C. Warthen Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 April 22, 1982 Re: Missin§ Information - Completed Wells Dear Bob: We wish to bring to your attention that the below-indicated material on the following Union 0il Company wells has not yet. been received by the Alaska Oil and Gas Conservation Commission: Wall Granite Pt. t33-14ED' Comp !e_t ion Date 3/6/81 His s ing_ !.fat eria ! -DIL/SP & CBL/VDL Elec. Logs. Tra.dinz Bay Unit ~D-9RD 3/2/82 -Digitized E. Log Tape Trading Bay Unit ~D-16RD Trading Bay Unit ~D-17RD 6/22/81 -Directional Survey -Elec. Logs -Directional Survey Trading Bay Unit #K-3RD 5/22/81 -Well History Trading Bay St. #A-gRD 5/6/8l -Directional Survey -Digitized E. Log Tape Trading Bay St. ~A-17RD Cannery Loop Unit ~3 7/3/81 9/13/81 1/18/82 -Digitized E. Log Tape -Digitized E. Log Tape -Digitized E. Log Tape -Certified Survey Plat -Directional Survey .~ -DST or Prod. Test Reports Trail Ridge Unit #1 12/13/so -Certified Survey Plat Please submit the above material at your earliest convenience since you are now in violation of Title 20, Chapter 25 of =he Alaska Admin- istrative Code. Very t~.uly ~jours, William Van Alen Petroleum Geologist WVA:v~i ! Document Transmittal . Union Oil Company of, California DATE SUI~MITTED AC'COUN'TING MONTH 04/02/82 T°Alaska O&G Commission FRoM ATTN' Harry Kugler Robert C. Warthen AT AT 3001 Porcupine Drive UNION OIL COMPANY Anchora§e~ AK 99504 Anchorage TELEPHONE NO. TRANSMITTING THE FOLLOWING: 276-7600 KU 34- 32 ,, , 1 ~ach Blueline & Sepia of the :ollowi)g' 5" DIL 2" DIL 5" CNL FDC 5" BHC Soni 2" BHC Sonic 5" FDC 1 Maginetic Tape .i, , , , d~PleaSe acknowledge receipt by signing and DZZg: R E C I:1 V AP~ t~ 19~2 ,.. ~ 0il & Gas Cons, Corem i i i FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. STATE OF ALASKA .--~ ALASKA ~_~,,L~AND GAS CONSERVATION CC :VllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of operator 7. ~e~'m~t~N~,. UNTON 0TL COMPANY OF CALIFORNTA O.L--.I.,,~+ 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 133-20348 9. Unit or Lease Name KENAT UNIT 4. Location of'Well at surface +1972'N & +iO00'W of SE corner, S--ec. 32, T5--N, RllW, SN. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. "~ °"' ~SL A-O?an55 For the Month of OANUARY , 19 10. Well No. KU #34-32 11. Field and Pool KENAI GAS FIELD 82 12. Depth at end of month, footage drilled, fishing'jobs, directional drilling problems, spud date, remarks Fish $ 5596' - could not recover. TD 5700' Released rig $ 18:00 hrs 1/18/82 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 None FEB 2 ,5 1982 0il & 6as Cons, .1 6. DST data, perforating data, shows of H2S, miscellaneous data Per¢'d & sqz'd: 4874-4876' 4848-4852' Perfed: 4630-4650' 5207-5270' 5442-5454' 5462-5478' 5543-5553' 17. I herebY-~ertify that the foregoing is true and correct to the best of my knowledge. N~,,~--R~ p q 'oh, regardl h s operations, and must be filed in duplicate with the Alaska ~J~nd Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ALASKA~'L AND GAS CONSERVATION CL'.,.;MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ) 1 Workover operation [] L~.[] 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 81-154 · Drilling well [] 2. Name of operator 3. Address P0 BOX 6247 ANCHORAGE AK 99502 4· Location of Well at surface +1972'N & +lO00'W of SE corner, Sec. 32, TSN, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KR 95' MSi A-OPRR55 8. APl Number 50- 133-20348 9. Unit or Lease Name KENAI UNIT 10. Well No. KU ¢t34-32 11. Field and Pool KEN~I G~S FIELD For the Month of DECEMBER 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Tagged fish ~ 4819' - left in hole, could not recover. 5700' TMD 12/7/81 13. Casing or liner run and quantities of cement, results of pressure tests Tested 13 3/8" csg to 2500 psi - ok. Ran 9 5/8" 47# butt csg to 5686' w/ 1730 sxs & tested to 3000 psi - ok. 14. Coring resume and brief description None 15. Logs run and depth where run DIL-SP-BHC-Sonic-GR 2029-5691' FDC-CNL-GR 2029-5691' CBL-VDL-GR 5586-5596' RECEIVED JAN 2 2 ]982 11 6. DST data, perforating data, shows of H2S, miscellaneous data Perf'd & sqz'd: 4280-4282' 4614-4616' 4664-4666' 4868-4870' 4874-4876' 4848-4852' 5196-5198' 5480-5482' 5553-5555' Perfed: Naska0ii& GasC0ns. C0mmissl0 4630-4650' Anchorage 4807-4827' 4807-4852' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNE _-., _ _ --,---- . TITLE DATE 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~,04 Submit in duplicate ' '~'-" STATE OF ALASKA '--x ~,../~ ALASKA ~JiL AND GAS CONSERVATION COMMISSION '~'~'.~-, MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION OIL CONPANY OF CALIFORNIA 81-154 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 133-20348 9. Unit or Lease Name KENAI UNIT 4. Location of Well at surface +lgO0'N & +llO0'W of SE corner, Sec. 32, TSN, RllW, SN. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KB 95' MSL A-028055 10. Well No. KU #34-32 11. Field and Pool KENAI GAS FIELD For the Month of NOVEIvlBER , 19. 8.[ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations ~17:00 hfs 1.[/21/8.[ & spud ~ 21:30 hrs .[.[/23/8.[, 17 1/2" hole to 2050' ll/30/el. 13. Casing or liner run and quantities of cement, results of pressure tests Drove 20" conductor to refusa.[ ~ 87'. Ran l~ 3/8" 61# K-55 butt csg to 20z9'~ & cmtd w/ 1~00 sxs. 14. Coring resume and brief description None 15. Logs run and depth where run None I ECEI VED .16. DST data, perforating data, shows of H2S, miscellaneous data None DEC2 1 1981 Alaska Oil & Gas Cons. Commission AnChorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED~'~~~{///~~~~' TITLE DIST DRLG SUPT 12']5'81 / .... , DATE 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. ..... · , A~,A ~uhmit in duolicate November 13, 1981 Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 -Anchorage, A!aska 99502 Res Kenai Unit KU No. 34-32 Uni'on Oil company of California Permit No. 81-154 Sur. Loc. l 1900"N, 1100~g of SE cr Sec 32, TSN, R11W, SM. Bottomhole Loc. t 300"N, 2300~W of SE cr Sec 32, TSN, RllW, S~. Dear Mr. Andersonl Enclosed is the approved application for permit to drill the above referenced- wel 1. Well samples and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5), If .available, a tape con~atning the ~igitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dtpmeter 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 Habitat Coordinator"s office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Po!1ution Control Act, as amended. Prior to Mr. Robert T. Anderson Kenau Unit KU .Nos 34-32 --2--' November 13, 1981 cc~mencing operations you may be contacted by a representative of the Depar~nt of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying th~s office within 4'8 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 e~uipment 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 witness present. Very truly yours, Hoy~e H. Hamilton C~~a OE BY ORDER OF TH~ CO~,I~SS~ON Alas~ Oil a ~s Conservation C~mission Enclosure cow Department of Fish & Game, Habitat Section w/o enol. Department of Environmental Conservation w/o/encl. Robert T. Anderson' District Land Manager Union Oil and Gas"-',ison: Western Region Union Oil Company California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union October 16, 1981 Mr. Hoyle Hamilton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 STATE OF ALASKA 1981 Permits to Drill Correction of Bonding Information Dear Mr. Hamilton}. · , . It has been brought to my attention that we have been carrying incorrect bonding information on all Union operated Permits to Drill submitted to the Alaska Oil & Gas Conservation Commission since January 1, 1981. For each of the below listed wells, Item No. 12 on the Permit to Drill (Form 10-401) should be changed from United Pacific Insurance Company (B-55372) in the amount of ~100,000.00 to National Fire Insurance Company of Hartford (B-5534278) in the amount of ~200,000.00. WELLS PERMITED DATED PERMITED API NUMBER DATED APPROVED TBS A-9 Rd. 3/17'/81 50-733-20062-01 3/24/81 CLU #3 4/20/81 50-133-20340 '4/28/81 TBS A-17 Rd. 5/12/81 50-733-20135-01 5/15/81 KDU #7 6/26/81 50-133-20341 7/27/81 KDU #8 6/26/81 50-133-20342 9/17/81 WD #1 7/14/81 Pending Pending KBU #31-7 10/8/81 Pending Pending ~:~U~.~_~?~,2 ~ 10/'8/81 Pending Pending Tungak Creek #1 10/14/81 Pending RECE~vEDPending 0CT ,i, lq® Alaska. 0il 8, Gas Corm. Coinn'dssion Anchorage 1981 Permits to Drill Correction of Bonding Information -2- October 16, 1981 We would appreciate your reflecting these corrections on your copies of the subject Permits and we will do the same on ours. We apologize for the oversite and any inconvenience this has caused. Ail future Permits submitted for your approval ~ill have the cUrrent bonding information on them. sk cc: Ann Lannin-LA Office Jim Callender Very Truly yours, Robert T. Anderson / RE£EIVED OCT 2 198! Oil & Gas 6ons. Gommission .. Union Oil and Gas.~N. ison: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager October 8, 1981 Mr. Hoyle Hamilton Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99504 KENAI SOLDOTNAAREA State of Alaska Kenai Gas Field Kenai Unit, KU #34-32, A-028055 (8-86-71-5390-600978) Dear Mr. Hamilton: Enclosed for your approval are three (3) copies of the Permit to Drill the above captioned well. Also enclosed is our check number 19163 in the amount of $100.00 to cover the required filing fees. Upon approval, we would appreciate a copy so that we may complete our files. Very truly yours, bde Enclosures (4) OCT o Oil & c as Cons. AnC.~ora~ t-~,, STATE OF ALASKA ~ ALASKA ,,~AND GAS CONSERVATION C(., ,MISSION PERMITTO DRILL 20 AAC 25.005 _v la. Type of work. DRILL )~ lb. Type of well E)~'PLORATORY [] SERVICE [] STRATIGRAPHIC [] 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_, AK~ 99502 4. Location of well at surface , 9. Unit or lease name +1900' N & +llO0' W of SE Cor. Sec 32, T5N, RllW, S.M. Kenai Unit ... ~t top of proposed---producing interval 10. Well number +650' N & +2100' W of SE Cor. Sec 32, T5N, RllW, S.M. KU #34-32 --~t total depth -- 11. Field and pool 300' N & 2300' W SE Cor. Sec 32, T5N, RllW, S.M. Kenai Gas Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 95' KB A-028055 12. Bond information (see 20 AAC 25.025) Uni ted Pacific Ins. ~ ~'--~, Type Statewide Surety and/or number Company, B-55372 Amount ~ 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or cor~pleted feet well 1 800 ,feet 5 1/2 m~les South· miles ~00! 1,6. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 55 VD & 6100 MD feet 2324.67 11/1/81 , 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures * 1 .~1'~ psis@ .... Surface KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE o/ (see 20 AAC 25.035 (c) (2) **~psig@ ._.5.Q0~ft. TD (TVD) 21 **Based on KU #21-5 *Max.pos.sur.press.us'ing" Proposed Casing, Liner and Cementing Program weight of gas col umn. SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 20" 94# Plain End 100' Surfacei Z100' ~ Driven 17 1/~ 13 3/E 61# K-55 Butt. 2000' Surface~ 2000' 1'1900 ll00 sxs 12 1/z 9 5/8 47# N-80 Butt. 5600' Sur'face~, 560'0' iI 5000 1250 ...... sxs I 22. Describe proposed program: PROCEDURE' 1. Move in and rig up Brinkerhoff Rig #31. 2. Drive 20" to refusal at +100'. ~'C~.~i~ 3. Drill 12 1/4" directionaT hole to_+2000' M.D. 4. Open 12 1/4" hole to 17 1/2" to +2000'. 5. Run and cement 13 3/8" casing to--+2000'. 00T09 198t 6. Drill 12 1/4" directional hole to-+_5600'. Alaskaoij&GasOoas. 7. Run 1 ogs. A~C.~otag~ Corarai$'~ioa 8. Run and cement 9 5/8" casing at +_5600'. 9. Test Sterling sands as directed. 10. Complete well as a dual 3 1/2" Sterling producer. 23. I hereby certify that the foregoing is tr~p and c, orrect to the best of ray_knowledge SIGNE C ~ The s~ [~om~use RolSert ~nders' on" f CONDITIONS OF APPROVAL Samples required Mud log required I Directional Survey required I APl number []YES ~NO []YES [~]NOI ]~YES []NOI 50- /.~- Z Approval date Permit number f/_/.~&/ i 11/13/81 I SEE COVER LETTER FOR OTHER REQUIREMENTS . .. BY ~ ,COMMISSIONER DATE . Nov~zber 13,~ 1981.. APPROVED by order of the Commission Form 10-401 Submit in triplicate · .o · o ~$ $,'~" 5000 · ..~ P/Pk' R43~. . .~ L; 'o · · · · , · ' p/?£ · RECEIVED OOT o 9 lge] Alaska 0ii;& Gas Cons. C0mmiss~or~ ' ~chorage )30TE ' APPROVAL BY T~E DISTRICT DRILLING SUPERh~TENDENT Zo" Zooo & i · 5" 4 ,, j ii . i ji _ iii i i i _1'1' i i t ii Ko '~ ~q-~z RECEIVEI) · OCT 0 9 ]9.8] Ill ,. ~ I ,, . , ----v. VII - UNION OIL COMPANY OF DATE OCT 0 9 19~! oi/& Gas UNJON OIL COMPANY OF CALIFORNIA DKAWI~I ~ CKD. ~ AI'P'D. SGALE DATE SHEETS J SHEET FORM ' C, ASING SIZE Bottom Top PIELD ~J. CASING AND TUBING DESIGN HO~ SIZE . Wt. ~ WT. I ~8 ~c~~_ HYD GR. i .'.5~L psi/ft_~. MUD %~ II DESCRIPTION '~EIOHT TENSION }[[N!MU~4 TDF COLLAPSE W/ BF -top of STRENGgH PRESS. ~ Grade Thread W/O B~? ~ section TENSION _ bottom .. lbs lbs 1000 lbs psi COLLAPSE PZSIST. tension __ p.~ ,,. # · .· DESIGN BY ~ ~ ~ . HYD. GR. II: : _psi/ft..., M.S.P. CDP BUP~T IETERi~d5 BDF PP~CE PRESSURE 1.~,.'~!:~. . ~R .. PT. psi ..... psi ..~si. , . COS! Formulae: Collapse resistance in tension = X (Collapse pressure ratify) Burst Pressure = BF (BouyanCy Pac'tor) = i.oo- (o.oi~3 x ~ua wt. z) · i , Calculations: i i il i Ji i ~ -- · i Total Cost _ _ I L CHECK LIST FOR NEW WELL PERMITS Company ITEM APPROVE DATE (3) Admin ~~ /~-l%-f/ ~ thru 11) 2. Is well to be lo~ated in a defined pool ......... 3. Is well located distance from property line ~1 ~.. 1. 4. Is well located proper distance from other wells .. 5. Is sufficient undedicated acreage available in this pool ......... 6. Is well to be deviated and is well bore plat included ............ 7. Is operator the only affected party .............................. 8. Can permit be approved before ten-day wait ..................... e 10. 11. YES NO REMARKS 12. 13. 14. 15. 16. 17. 18. 19. 20. · · · · · · eeeee Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... ,,, Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and. intermediate or production strings .. Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore 'abandonment procedure included on 10-403 ............. Is adequate well bore separation proposed ........................... (5) BOPEi~_~ ! (~,1~/8' ' (21 thru 24)' 21. 22. 23. 24. 25. Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached Does BOPE have sufficient pressure rating - Test to ~ ~ O~slg Does the choke manifold comply w/API RP-53 (Feb.78) .................. Add±t'i onal requ-irements Geology: Eng inj~r ing: , cs rev: 03/10/81 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No Special'effort has been made to chronologically organize this category of information. .o · : .... SCSLU~BERG£R .... · LIS TAPE 'VERIFICATION LISTING VP 00g. HO5 VERIFICATION 5ISTING PaGE 1 ERVICE NAMf : SERV'IC ATE :82/03/19 EEL NAME :REE5 ID ONTINUATION # :01 O~qnE~TS :R~EL COMMENTS ~ TAPE HEADER ** ERVICE NAME :SERVIC ATE :82/O3/19 RIGIN :1070 APE HAME :A62576 ONTiNUATIO~ # :01 REVIOUS TAPE: OM~ES~TS :TAPE COMMENTS * FILE HEADER ** 'Ibg ~AME :SERVIC,O01 ;ERVl'CM NAME : ~ERSIO~ # : ;ATE : ~AXlSti~ LENGTH : 102~ 'ILE TYPE : 'REVIOUS FI4E : '* INFORMATION RECORDS ~NE~i CONiENTS IIII I III IIII .~N : UNION 0I CO OF CALIFORNIA ~N : KENAI UNII' 34-'32 '"N : KENAI GAS ~ANG: 1 1N ~OWN: SECT: ~OU~: KE~AI 5TAT: ALASKA 2TRY: M N E '~,~ C 0 M T E N T S PRES: ** REC~~', Ro TYPE 047 UiilT TYPE CATE SIZE CODE 000 000 02~ 065 000 000 016 065 000 000 010 065 000 000 003 000 000 002 0~5 000 000 002 065 000 000 006 065 000 000 006 065 000 000 004 065 CATE SiZE CODE 000 000 010 065 VP 009.HO5 VERIFICATION LIS'lING PAGE 2 $~ R~CORO TYPE 047 ~$ , COiviiqEN935 *~ OB ~ 10707,A62576 OMPANY NA~E EGG IELO OU~Y ECTION = 'UNION OIL OF CALIFORNIA = KENAI UNIT 34-32 - K~NAI GAS = ~ENAI = 32 : 5N AN'GE = IL RUN ~I, LOGGED OB-DEC-81 OTTOM LOq INTERVAb = 5688 :FT. OP LOG INTgRVAG = 2021 FTf ' = 13.37 Ii~. ~ 2021 FT. ASING-LOGGER ~YP~ f!OLE Fb0ID iSC~SI?Y [~F ~ MEAS. TEMP. :~C ~ ~EAS. TEMP. : 12.25 i~. : DUDUI$ gfb :9.5 L~B/G 50.8 S :9.5 = 8.4 C3 = ~4.50 0~'t1~¢, @ 57!0 DF = 0.30 OHg~ g 57 0 DF = 6.100 Oh~~ $ 57 0 DF VP 009,H05 VERIFICATION LISTING TRfX LIMESTONE , ~ ~ L & SHE DATA IS STRAIGHT:LINE FRO~ 2958 TO 2480 * DATA i FORMAT RECORD NTRY BLOCKS TYPE SIZE REPR CODE 4 ~ 66 9 4 65 0 ! 66 ATU~ SPECIFICATION BL~C~$ &ER¥ICE SERVICE ID ORDER EPT FLU D l L 5M OIL bD ,P OIL ;R OIL }T ~P SaC ;R ~C IPHI ~HO~ )RHU FDN ~ALI ;R FDN ~RA i' FDN ~CNL FDN ~CNL API API API AP1 FILE bOG TYPE' ChA$'S' MOD :NO, ~ 0 0 0 0 0 OHMM 7 0 0 0 0 OMMM 7 0 0 0 0 OHMM 7 12 46 0 0 MV 7 1 0 0 0 GAPI 7 31 32 0 0 US/F 60 52 32 0 0 ~V 60 1 0 0 0 GAPI 60 31 32 0 0 PU 42 68 2 0 0 G/C3 42 35 I 0 0 G/C3 42 44 0 0 0 iN 42 28 3 0 0 GAPI 42 31 32 0 0 42 42 1 0 0 42 34 92 0 0 42 34 93 0 0 DA'IA ** )EPT ~P 2ALI ?CND 5716.000 -999,250 -999,250 ~2.250 680'000 BFLU NPHI G~ -999.250 IbM -999.250 DT 35,352 RHOB 63.781 NRAT 5P ~R CALl FCNL 5700.000 -38'188 56,844 10,117 ~80,000 SFLU GR NPHI 11.781 IbM 56,B44 35,254 RHOB 63,781 NRAT ENTRY 1 60 .lin 0 SIZE PROCESS SAMPLE 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 1 4 0 4 0 1 4 0 1 4 0 1 4 0 4 0 1 4 0 1 REPR CODE 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 -999,250 IbD -999,250 SP 2,361 DRBO 3.176 NCNb -99g,250 -999,250 0 163 2262 ooo 13.492 ILD 104,000 SP 2,355 DRHO 3,176 NCNb 10,016 -38,188 0,155 2262.000 VP 009.H05 VERIFICATION blSTiNG PAGE 4 EPT 5~00,000 SFbO P 40.063 GR R 49.375 NPMI ALI 12.242 GR CNL 815.000 'SPT 5500.000 SFL$ P -27.281 GR ,R 53,7t9 NPMI AL1 12,828 GR 'CNL 502,000 5400 -4 50 529 ,000 SFbO 3O5 GR 50O NPHI 563 GR .500 ~EPT 5~00,000 SFLU ;R 57,406 NPHI iALI 12,695 GR 'C~b 565,500 tEPT 5200.000 SFLU ;P -33.188 GR ;R 51.500 NPHi :AL1 12.297 GR 'CNL 707,000 )EP'~ 5100,000 Sf'l,O ;P -40.594 GR ]ALI ~2.320 GR 'CNL 61~.500 ;P ;R :AL1 5000,000 SFLU -2~.~06 GR 5~,000 N~I 12.594 G~ 534.000 ~P ."ALI rC~ L 4900.000 SFLU -14.555 GR 46.531 NPdi 12.883 GR 590.000 2ALl 4BO0,O00 SFLO -23.594 GR 50.531 NP?~i 12,445 G~ 463.000 25,594 49,375 31.104 48,063 6,6~9 53,7~9 4B.340 49.500 3.338 50,500 41.695 48,000 ~.~3I 42.5~9 55,469 6,535 51.500 34,229 4~.750 9.3~3 55.063 3{~,91g 51,469 4,293 58.000 46.240 43.938 5,625 46.531 39,160 44,250 5.578 50.531 4~.096 45.594 DT NRAT Ib~ DT RHOB NRAT DT RHOB NRAT ILM DT RHOB NRAT ILM DT RHOB NRAT DT RHOB NRAT DT NRAT IbM DT NR~T IbM DT RHO~ NRAT 2~,000 104.375 2,408 3.033 8,391 104.000 2.381 4.004 3.953 110.188 2,293 3.666 5.688 109,750 2.291 3.680 7,805 119,563 2.176 3,207 9,453 iOl,O00 2,29'7 3,355 5,820 110.375 2,219 3.683 5.711 114,375 2,221 3.498 ~,465 i15,750 2,182 3.9B2 IbD SP DRHO NCNB ILD 8P DRMO NCNb SP DRHO NCNB ILD SP DRHO NCNb SP DRHO NCNb SP DRHU NCNB ILD NCNb SP DRHO NCNb SP DRHO NCNb 2~,766 -4 .063 0,059 2~80,000 B 50O 0,065 2204,000 3.967 -4,3O5 2056.000 .793 -2 ,656 0,073 2150.000 7,766 '33.I88 0,042 2394,000 8,969 '40,594 0,072 2168.000 5 785 -24:406 0,017 2218,000 5,758 '14'555 0.052 2044.000 ,699 '2 .594 0,051 1904.000 ) ) ~P 009.H05 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128,500 2,186 3.932 24.422 155.750 2.066 3,152 6.824 129,000 2,172 4.098 7.355 122.375 1,749 4.~4i 6,086 123,375 2,127 4,063 9.344 i21.750 2.102 3.885 4.836 109.563 2,205 3.838 ILD DRHO NCNL DRHO NCNb ILD BP DRHO NCNb ILD SP DRHO NCNb ILD SP DRHO NCNb I LD SP DRHO NCNb SP DRMO NCNL ILD SP DRHO NCNb SP DR~O NCNb PAGE 6,266 -10,188 0.063 1990,000 5.105 -9.898 0,112 1909.000 375 0.056 1587.000 26,234 '57.625 0,009 2148.000 '3 875 0.078 1686,000 8,211 -12,656 -0.005 1950,000 6,160 -14.352 0.079 1688.000 9.422 -33.375 0.028 2015,000 4.918 -13.328 0.058 2OO0.00O ]P 009.H05 VERIFICATION ~ISTING PAGE 6 00.000 8FbO 3'2~ 188 GR 57,281 14,078 GR 387.250 EPY 3!00,000 SFLU p 32,375 R 51,844 NFHI ALI 13,0!00 GR CNL 408.750 EPT 3~00,000 SFLU P 28,656 GR R 55,438 NPHI ALI 13,594 GR CNL 407.250 £PT 3500,000 SFLO p -40.344 GR R 44,813 NPHI Abi 12,594 GR CNL 459.750 EPY 3400.000 SFLU P -52.375 GR R 40.594 NPHI AL1 12,461 GR C{~L 588.000 EP~ 3300.000 SFLU ~p -22,844 GR ;R 51.531 NPH£ :AL1 13,453 GR 'CNL 431.750 ~EPP 3200,000 SFbO ;p -43.094 GR ;R 29,250 NPH£ ~ALI 12,641 GH 'C~L 343,750 )EP'£ 3100,000 ~P -32.344 ;R 44.000 NP~I ~ALI 1~.813 GR ~C~b 392.000 )EPi' 300u. O00 ~p -]4,125 ;R 41,250 NPHI ~ALI 13.406 GR ~C:~L 363.250 6.141 57,281 49,3~.6 47,375 9.945 5i.844 49.658 46.938 6.676 55.438 48.682 50.031 13.242 44,8t3 43.994 41.719 16.359 40.594 43 115 5.]24 51.531 51.563 48.6~8 17,656 29,250 50,635 3~.2~1 9.742 44,000 45,850 47.625 9.883 41.250 56.494 46,781 IbM DT RHOB NRAT IbM PT RHOB NRAT IbM DT NRAT DT RHOB NRAT DT RMOB NRAT DT RHOB ~RAT D~ RHOB NRAT NR~T RHOB NRAT 5,i37 132,375 2.06i 4,094 11.813 120.563 2.064 8.555 122,750 2.133 4.043 15,484 119.000 2.137 3,758 17.391. 13~.375 2.121 3.705 125.375 2.113 4,199 25.172 132.750 2.006 4.i29 8,672 131.000 2,111 4.023 !0.641 131.i25 1,968 4.973 IbD SP DRHO NCNb SP NCNb ILD DRHO NCNb IbP SP DRHO NCNb SP DRHO NCNb SP DRHO NCNb IbP SP DRHG NCNb SP DRHO NCNb ILD SP DRMO NCNb 5 637 -24,188 0,040 1648.000 12.398 -32.375 0,057 1735.000 8.992 -28,656 0,042 1652.000 15,352 -40,344 0,007 1892.000 16.563 -52.375 0.009 2124.000 6.891 -22.844 0,017 1844.000 22.797 -43,094 0.104 1382,000 9.125 -32.344 0,117 1592.000 10,414 -34.125 O.02b 1516.000 ~P 009.H05 VENIFICATiON ~PT 2900,000 SFLU p -5'7.312 GR R 3!,922 NP~i Ab/ i2.82B GR CNL 617.O00 EPT 2800.000 SFbU p -52,906 GR ~ 45,531 NPHI ABi 12,680 G~ C~L q72.250 EPT 2700 000 SFLd p -63~344 GR R 39.813 NPHI ALI 12.672 GR C~L 512.500 EPY 2600.000 SFhU p -65.063 G~ R 42.90~ NPHI ABI 12,461 GR CNL 599.000 EPT 2500.000 SFDU .p -72,5o0 GR ;R 40.594 NPHI IALI 12.578 GR ~C~b 560.000 )EPT 2400,000 SFL~ ;p -74,125 GR ;R 47.469 NPMI IALi 12,445 GR ~CNL 517.000 )EPT 2300,000 SFLU ~p -27,766 GR ;R 39,875 NPMi ~ABi 12,438 GR rCNL 538,500 )£PT 2200.000 ~p -21.76b GR 2Ahi 12.578 ~C!qb 900.000 Sp -26.281 GR SR 47.406 NFel ~AL! 12.336 GR ?C?4b 473.750 ~ISrlNG 14.438 31.922 40,088 33,75o 9.078 45.53i 45,312 45.53i 10.602 39,8!3 45.166 38.719 12.5o0 42.906 42.920 39,918 11.141 40.594 4i.553 36.906 11.727 47,469 41,895 39,125 12,047 39,875 42.236 37.625 64,750 25,391 35.375 1~.922 47.4()6 44.873 32,219 RHOS DT NRAT ILg DT ~MOB Nf~T DT RHOB NRAT DT RHOB DT NRAf !L~ ~HOB NRAT O~ NRAT DT RHOB NRAT 16,125 150.000 2.113 3.549 !0,188 135,125 2,I48 3,B34 10,953 134.000 2.113 3,824 139,000 2.121 3,695 10,039 140.750 2,137 3.621 9.914 137.375 2,178 3.639 11,008 139.375 2,158 3.654 22.~09 81,375 2.430 2,664 15.078 148,750 2.146 3.799 I5D SP DRHO NCNB SP DRMO NCNL IBP SP DRHO NCNb SP DRHO NCNU SP DRHO NCNB SP DRHO NCNB IBP SP DRMU NCNB ILO DRHO NCNB SP DRHO NCNB 15,563 -57'312 0'036 2164,000 9,805 -52,906 2031,000 10,648 -63;344 0,019 2204,000 -65:063 0,029 2041.000 9,711 -72,500 0.031 2035'000 9.492 -74.t25 0.019 2060.000 10,648 -27.766 0.034 2042,000 19.172 -21,766 0.048 2150.000 15,336 -28.281 0.029 1927.000 ~P 009.H05 VERIFICA~IOM LISTING EPT 2~00,000 SFLU ~ 95,813 Gl{ R 29,094 NPNI ~Li i2.77B GR ,~,~b 336.250 3.146 ibm 29.094 DT 58,740 RHOB 26.969 NRAT SPT 1978.500 SFLb ? -999,250 GR R -999,250 NPHI ALI 12,742 GR CML 293,750 -999,250 IL~ -999,250 DT 52.783 RHOB 26.500 NRAT * FILE TRAILER ILE NAME :SERV!C.O01 ERVICE NAME ATE : AXlNUS LENGTh : 1024 ILE TYPE : EXT FiLE NAME : * T~PE TRAILER *~ ERVICE NA~E :SERVIC ATE :82/03/19 ~I~IN :1070 APE LAME :~6257~ ONTi~.,~]ATION ~ :01 EXT TAPE NAME; : OM~'/~E~TS :TAPE COmMeNTS * REEh TRAILER ** iERVlCi~ I~AM£ :SERVIC ~AT~ :~2/0~/19 ~RiGIi..3 : IEEb Ma~E :REEL ID :ONTiaLIATION $ {EXT R~EL NAME : IOMiqE~TS :REEL COMMENTS EOF 200O.O00 ILD 25.188 SP 1.969 DRHO 4,582 NCN5 -999,250 =999'250 SP 1.868 DRHO 4.246 NCNL PAGE 2000 000 -95!813 -0 478 ~449,000 -999,250 -999.250 -0,518 1334.000
