Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
168-018
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,370 feet 10,250 & 6,067 feet true vertical 9,875 feet N/A feet Effective Depth measured 6,067 feet See schematic feet true vertical 4,743 feet See schematic feet Perforation depth Measured depth See schematic feet True Vertical depth See schematic feet 3-1/2" N-80 351 (MD) 351 (TVD) Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80 10,142 (MD) 7,721 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Hemlock Oil, Middle Kenai Gas 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 4,750psi 3,090psi 6,870psi 2,476 2,274 Burst Collapse 1,540psi Production Liner 10,434 3,059 Casing Structural 7,930 7" 10,434 13,368 9,883 315 2,476 315Conductor Surface Intermediate 24" 8,160psi 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 168-018 50-733-20092-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018772 / ADL0017594 McArthur River / Hemlock Oil, Middle Kenai Gas Trading Bay Unit K-05 Plugs Junk measured Length measured TVD true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD N/A 5 Size 315 0 10990 0 80 13-3/8" Other: Tubing Punch / Production Test / N2 160 323-502 Sr Pet Eng: 7,020psi Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager N/A measured Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 1:31 pm, Feb 15, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.02.14 14:53:40 - 09'00' Dan Marlowe (1267) RBDMS JSB 022427 DSR-2/15/24 _____________________________________________________________________________________ Updated By: JLL 02/14/24 SCHEMATIC McArthur River Field Well: K-05 Last Completed: 06/10/1996 PTD: 168-018 API: 50-733-20092-00 PBTD =10,250’ TD =13,368’ 24” KB: 35’ 7” Corrosion Holes @ 10,185’ Zone F-7 4 5 6 7 2 Tubing Punch 5,971’ 9-5/8” TOC 10,250’ 1 3 Volumetric ToC with 10% washout at ~8,400’ MD Bad Casing below 9,244’ TOL @ 10,309’ 13-3/8” X X CASING DETAIL Size Wt Grade Conn ID Top Btm 24” Surf 315’ 13-3/8” 61 J-55 BTC 12.516 Surf 2,476’ 9-5/8” 47 N-80 / P-110 BTC 8.688 Surf 10,434’ 7” 29 N-80 BTC 6.184 10,309’ 13,368’ TUBING DETAIL 3-1/2” 9.2 N-80 BTC 2.984 Surf 351’ 2-7/8” 6.5 L-80 8rnd EUE 2.438 351’ 10,142’ Junk Tubing 3-1/2” 9.2 N-80 BTC 2.984 10,676’ 12,472’ Note: Cork-Screwed Tubing below 2,500’ (gets worse with depth) JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 35’ 35’ 2.984 Hanger 1 307’ 307’ 2.813 HES “FLX” TRSV 5,971’ 4,671’ 3’ tubing punch (9/28/23) 2 6,067' 4,743' D&D Packoff Plug -(Sundry required to remove plug - See Sundry # 323-502) 3 9,139’ 7,024’ 2.313 HES “XD” Durasleeve SSD 4 9,186’ 7,057’ 3.875 HES 9-5/8” 43.5# - 53# “VTL” Packer 5 10,059’ 7,655’ 4.00 HES 36# - 59.4# “BWD” Permanent Packer 6 10,110’ 7,689’ 2.313 HES “X” Landing Nipple 7 10,142’ 7,710’ 2.984 Re-Entry Guide 10,640’ 8,075’ EZSV 10,797’ 8,195’ Camco KBUG GLM 11,150’ 8,444’ Camco KBUG GLM 12,413’ 9,252’ Baker FB-1 Packer 12,458’ 9,283’ 2.75” Camco “D” Nipple 12,472’ 9,292’ WLEG 13,200’ 9,767’ EZ Drill Retainer FISH 02/12/1995 12,800’-12,824’ – 1-1/2” Slickline Tools PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status HK-1 12,520' 12,564' 9,325' 9,355' 44' 06/08/1996 Isolated HK-2 12,588' 12,720' 9,371' 9,460' 132' 06/08/1996 Isolated HK-3 12,720' 12,806' 9,460' 9,516' 86' 06/08/1996 Isolated HK-4 12,806' 12,878' 9,516' 9,562' 72' 06/08/1996 Isolated HK-4 12,902' 12,979' 9,578' 9,626' 77' 06/08/1996 Isolated HK-5 12,992' 13,192' 9,635' 9,762' 200' 06/08/1996 Squeezed HK-6 13,212' 13,300' 9,775' 9,831' 88' 08/22/1970 Squeezed OPEN HOLE / CEMENT DETAIL 13-3/8"18” Hole: Pumped 1175sxs Class G with 10% gel lead followed by 450sxs neat tail cement.Notes indicate cement circulated back to surface (522sxs back) 9-5/8"12-1/4" Hole: Pumped 700sxs class G. No losses noted. Did not bump plug. 8.8bbls cement found inside 9- 5/8” (including shoe).Volumetric ToC with 10% washout at ~8,400’ MD. Well Name:MRF K-05 API #:50733200920000 Field:McArthur River Field Start Date:9/16/2024 Permit #:168018 Sundry #:323-502 End Date:1/25/2024 9/16/2023 9/27/2023 9/28/2023 11/1/2023 11/2/2023 Well Operations Summary PJSM and PTW SITP 0psi IA 50psi ZͬhDĂƌůŽǁĞƉƵŵƉ͕ƟĞŝŶƚŽƉƵŵƉŝŶƐƵď͕WdůŝŶĞƐƚŽϮϱϬƉƐŝͬϭ͕ϱϬϬƉƐŝ͘Z/,ǁŝƚŚϮƐƚŽƉ͕ƐĞƚĂƚϱϵϳϰΖ Fill tubing with FIW, 8BBLS pumped to Įll and pressure up to 500psi. ƵŝůĚϭͲϭϭͬϭϲΗKƚƵďŝŶŐƉƵŶĐŚϴĞĂdžϬ͘ϮϱΗƐŚŽƚƐŽǀĞƌϯŌ͘Z/,ĂŶĚƉƵŶĐŚƚƵďŝŶŐĨƌŽŵϱϵϳϭΖƚŽϱ͕ϵϳϰΖ Initial T/IA 500/40psi - Fire puncher. Tubing dropped and IA came up, kick on Marlowe pump and pressure up tubing to 500psi, IA climbed to 300psi. Good punch. POOH, all shots fired (10BBL total FIW pumped). RIH and retrieve AD2 stop. Secure well, RD SL. MIT-IA PASSED to 3300psi Took 1bbl to Įll up and 3 bbls to pressure up. IAP losses were 5psi followed by 5 psi (<1% overall) /ŶŝƟĂů;dͬ/ͬKͿ͗ϬͬϯϯϱϬͬϬ 15mins: 0 / 3345 / 0 30mins: 0 / 3340 / 0 W:^DĂŶĚWdt͘^/DKW^ǁŝƚŚƉƌŽĚƵĐƟŽŶ SITP 0psi. R/U Pollard SL Pressure up SSSV from 400psi to 4000psi. SSSV took ~3 cups of hydraulic oil to pump up to 4000 psi. Bled air and pumped up again quicker. Pressure appears to bleed very slowly from SSSV line. Stab on lubricator and pressure test 250psi/3000psi - Test Good. RIH/w 2.25" x 4' DD Bailer (Drift for AD-2 Stop and GS) to first trouble ƐƉŽƚĂƚϮϰϯϱΖ͕ƐĞĞůŝŐŚƚĞƌǁĞŝŐŚƚƚŽϮϱϰϬΖ͕ĐŽŶƟŶƵĞƚŽϮϳϬϬΖƐĞƚĚŽǁŶĂďůĞƚŽǁͬƚƚŚƌƵďƵƚŶŽƚƉĂƐƐĨƌĞĞ͘WKK, RIH/w knuckle joint /w 2.25" x 4' DD bailer to 2700', slow fall to 5992', w/t down lightly not passing. POOH Fluid level observed at 650ft. RIH w/ 2.83" Gauge ring to SSSV's 2.813" X nipple, Set down at 287' SLM ( 307' RKB 20' correction). POOH. C/O TS to 1.5" RS 5' KJ 5' KJ OJ KJ SSSJ KJ RIH/w 1.62" Gauge Ring to 6500' POOH 100' with consistent 650 LBS, at 7000' see 800 lbs consistent 7500' see 950 to 1150 LBS Inconsistent weights 8000' see 1000 LBS to 1450 LBS inconsistent weight 8200' see 1200 to 1700 LBS very inconsistent weights POOH. Secure well and SDFN Rigging up to pump N2 Daily Operations: PT lines to 4000psi (pass). Start N2 lift down IA taking returns up tubing at 11:30. Page 1 of 2 Well Name:MRF K-05 API #:50733200920000 Field:McArthur River Field Start Date:9/16/2024 Permit #:168018 Sundry #:323-502 End Date:1/25/2024 11/3/2023 11/4/2023 11/5/2023 1/23/2024 1/24/2024 1/25/2024 Well Operations Summary Daily Operations: Rig up Slickline and P/T- PASS. RIH/w 2 7/8" AD-2 stop to 6070' SLM, pull up and set at 6051' SLM (6070' RKB) POOH. RIH/w 2 7/8" D&D Packoff Plug to 6049' SLM ( 6068' RKB) w/t set POOH. Pressure up Lub with IA to 350 prior to open- RIH/w 2 1/2" GS w/ AA Stop to 6048' SLM (6067' RKB) w/t Set POOH Rig up slickline. PT to 2000psi, good. SSSV appears to be closed and unable to get higher than 1650 PSI. K 5 N2 lift for 24hrs. N2 lift for 24hrs. Nitrogen lift to production. SD at 10:00. Recovered a total of 627bbls water and pumped 17,000gal nitrogen. ZŝŐĚŽǁŶͲZĞĚƌĞƐƐt>sΖƐͲĞƉĂƌƚWůĂƞŽƌŵ Page 2 of 2 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: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): 13,370 N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 4,750psi Liner 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng N/A 9/15/2023 13,3683,059 3-1/2" & 2-7/8" 9,883 HES VTL & BWD Packers & FLX TRSV 9,186 (MD) 7,057 (TVD) / 10,059 (MD) 7,655 (TVD) & 307 (MD) / 307 (TVD) 10,434 Perforation Depth MD (ft): See Schematic 10,434 7" See Schematic 7,9309-5/8" 24" 13-3/8" 315 2,476 MD 3,090psi 315 2,274 315 2,476 Length Size Proposed Pools: N-80 & L-80 TVD Burst 351 & 10142 6,870psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018772 168-018 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20092-00-00 Hilcorp Alaska, LLC Other: Tubing Punch, Production Test, N2 AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Trading Bay Unit K-05 McArthur River Hemlock Oil, Middle Kenai Gas Same 9,875 9,884 7,543 2,920psi 10,250 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 4:03 pm, Sep 01, 2023 323-502 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.09.01 12:36:34 - 08'00' Dan Marlowe (1267) A Passing MITIA to 3000 psi is required before punching holes in the tubing. MDG 9/7/2023 , ADL 00175941 BJM 9/11/23 DSR-9/1/23 10-404 After the flow test, plug must be set below holes in tubing to secure the well until a RWO is performed. Place a note in the wellfile stating that a sundry is required to remove the plug. &': 09/11/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.11 17:15:33 -05'00' RBDMS JSB 091223 Gas Production Test Well: K-05 Well Name:King-05 API Number:50-733-20092-00-00 Current Status:Long term Shut-in Gas producer Permit to Drill Number:168-018 First Call Engineer:Ryan Rupert (907) 301-1736 (c)Leg #2 (SE corner) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:3736 psi @ 8,301’ TVD using 0.45psi/ft (aligns with SITP) Max. Potential Surface Pressure: 2920 psi Max recorded SITP (3/4/96) Brief Well Summary K-05 is a long term shut in gas producer. It was an oil producer since drilled in 1968 until in 1996, the well shot up to high GOR, and sustained SITP = 2900psi. The well was subsequently killed, and the oil pools were abandoned per sundry #96-122. The gas production / pressure was thought to be coming from a hole in the 9- 5/8” casing at the F-7 Grayling Gas sand at 10,185’ MD (8,301’ TVD). The oil pool was abandoned, and a gas completion was set to try and produce through this casing leak. Right after the RWO the plan was to perforate the F-7 sand, but WL couldn’t get down. The well was brought online as-is and was plagued with freezing / hydrate issues. There was a half day flow test completed in 2000 where the well produced at 4MMCFD at 1250psi FTP and made 160bwpd before freezing off again. In 2004 a downhole choke was set at ~5500’ MD to take the pressure drop downhole where it was warmer, and help mitigate freezing issues. The choke worked, and the well produced for ~2.5months before dying. It averaged 2.5MMCFD and 3 bwpd over the first two months, and then the water shot up to 25bwpd at the end . The well is also known to have corkscrewed tubing, making large drifts below ~5000’ challenging. SL found sand above the downhole choke, and the well sat SI until 2016. SL drifted the well and was able to break through sand bridges and recover the downhole choke. They found a FL at ~2000’ MD, and despite swabbing on the well for 6 days and recovering 165bbls water, the well wouldn’t sustain gas production (nor could they depress the FL) This procedure aims to unload the water to evaluate if the gas resource is still producible. If we can get the well unloaded and free-flowing Hilcorp would like to production test the zone for no longer than 30 days. A RWO would then be evaluated to install a SSSV, allow for better liquid unloading, and install hydrate mitigation. The corkscrewed tubing would be fixed as well. The goal of this project is to production test F-7 Grayling Gas Sands for RWO screening If we can get the well unloaded and free-flowing Hilcorp would like to production test the zone for no longer than 30 days. e gas production / pressure was thought to be coming from a hole in the 9- 5/8” casing at the F-7 Grayling Gas sand at 10,185’ MD (8,301’ TVD). a gas completion was set to try and produce through this casing leak. Gas Production Test Well: K-05 Pertinent information: - F-7 Grayling gas Sand: 10,185’ MD (8301’ TVD) - Max inclination is the 49 degree sail angle form 2400’ MD - PBTD -Production test o Hilcorp requests to test the existing gas sand for no more than 30 total days of total on time o Once free-flow is established, production to be routed into existing facilities and sold or consumed as fuel gas. o Production will be measured for production accounting / regulatory tracking - SSSV: Hilcorp requests a waiver to 20 AAC 25.265(d) to produce this well without an SSSV for no more than 30 days of total ontime Well History: - 2016: Successfully break through fill bridge, and recover downhole choke o Swab well for 6 days and produce 165bbls water cumulative o Found FL at ~2000’ and didn’t move it down much beyond that - 2005: tagged what appears to be fill above choke - 2004: Downhole choke set at 5500’. o Well produces for 2.5months o Produced at ~2MMCFD and 3bwpd for first 2 months o Water jumped to 25bwpd at the end, and then well dies. o Corkscrewed tubing noted - 2000: Flow test for 12hrs measuring 4MMCFD at 1250psi FTP and 160bwpd - 1996: Attempt to perf the F-7 Grayling gas sand, but can’t get down due to fill - 1996: RWO to abandon the oil Pool and install a gas production completion - 1996: Oil production goes to high GOR. SITP = 2920psi production to be routed into existing facilities and sold or consumed as fuel gas. Gas Production Test Well: K-05 Flow test procedure: 1. MIT-IA to 3000psi 2. MIRU SL 3. PT lubricator to 250psi low / 3000psi high 4. D&T to PBTD check for fill 5. Drift to mimic 3-1/2” tubing puncher 6. RIH and punch tubing (memory) as deep as practical (±5,000’) a. Confirm FL’s before punching b. May need to pump on tubing while punching to avoid overbalance form IA to tubing 7. RDMO SL 8. RU nitrogen to 9-5/8” x 3-1/2” IA and PT lines to 3500psi 9. Circulate wellbore fluid to surface a. Pump down IA and taking returns up tubing b. Approximately 390bbls to recover from IA (assuming punch at 5000’) 10. Produce well to blow down tanks or production depending on rates. 11. Lift well for no more than 3 days and obtain test data 12. RDMO Nitrogen Attachments: 1. Current Wellbore Schematic 2. Proposed schematic 3. Standard well procedure – N2 operations Set plug below tubing punch holes, above the casing leak, to secure well until RWO is performed. Place a note in the wellfile stating that a sundry is required to remove the plug. -bjm _____________________________________________________________________________________ Updated By: JLL 08/25/23 SCHEMATIC McArthur River Field Well: K-05 Last Completed: 06/10/1996 PTD: 168-018 API: 50-733-20092-00 PBTD =10,250’ TD =13,368’ 24” KB: 35’ 7” Corrosion Holes @ 10,185’ Zone F-7 3 4 5 6 9-5/8” TOC 10,250’ 1 2 Volumetric ToC with 10% washout at ~8,400’ MD Bad Casing below 9,244’ TOL @ 10,309’ 13-3/8” X X CASING DETAIL Size Wt Grade Conn ID Top Btm 24” Surf 315’ 13-3/8” 61 J-55 BTC 12.516 Surf 2,476’ 9-5/8” 47 N-80 / P-110 BTC 8.688 Surf 10,434’ 7” 29 N-80 BTC 6.184 10,309’ 13,368’ TUBING DETAIL 3-1/2” 9.2 N-80 BTC 2.984 Surf 351’ 2-7/8” 6.5 L-80 8rnd EUE 2.438 351’ 10,142’ Junk Tubing 3-1/2” 9.2 N-80 BTC 2.984 10,676’ 12,472’ Note: Suspect Cork-Screwed Tubing below 8,500’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 35’ 35’ 2.984 Hanger 1 307’ 307’ 2.813 HES “FLX” TRSV 2 9,139’ 7,024’ 2.313 HES “XD” Durasleeve SSD 3 9,186’ 7,057’ 3.875 HES 9-5/8” 43.5# - 53# “VTL” Packer 4 10,059’ 7,655’ 4.00 HES 36# - 59.4# “BWD” Permanent Packer 5 10,110’ 7,689’ 2.313 HES “X” Landing Nipple 6 10,142’ 7,710’ 2.984 Re-Entry Guide 10,640’ 8,075’ EZSV 10,797’ 8,195’ Camco KBUG GLM 11,150’ 8,444’ Camco KBUG GLM 12,413’ 9,252’ Baker FB-1 Packer 12,458’ 9,283’ 2.75” Camco “D” Nipple 12,472’ 9,292’ WLEG 13,200’ 9,767’ EZ Drill Retainer FISH 02/12/1995 12,800’-12,824’ – 1-1/2” Slickline Tools PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status HK-1 12,520' 12,564' 9,325' 9,355' 44' 06/08/1996 Isolated HK-2 12,588' 12,720' 9,371' 9,460' 132' 06/08/1996 Isolated HK-3 12,720' 12,806' 9,460' 9,516' 86' 06/08/1996 Isolated HK-4 12,806' 12,878' 9,516' 9,562' 72' 06/08/1996 Isolated HK-4 12,902' 12,979' 9,578' 9,626' 77' 06/08/1996 Isolated HK-5 12,992' 13,192' 9,635' 9,762' 200' 06/08/1996 Squeezed HK-6 13,212' 13,300' 9,775' 9,831' 88' 08/22/1970 Squeezed OPEN HOLE / CEMENT DETAIL 13-3/8"18” Hole: Pumped 1175sxs Class G with 10% gel lead followed by 450sxs neat tail cement.Notes indicate cement circulated back to surface (522sxs back) 9-5/8"12-1/4" Hole: Pumped 700sxs class G. No losses noted. Did not bump plug. 8.8bbls cement found inside 9- 5/8” (including shoe).Volumetric ToC with 10% washout at ~8,400’ MD. Corrosion Holes @@ 10,185’, Zone F-7 _____________________________________________________________________________________ Updated By: JLL 08/31/23 PROPOSED McArthur River Field Well: K-05 Last Completed: 06/10/1996 PTD: 168-018 API: 50-733-20092-00 PBTD =10,250’ TD = 13,368’ 24” KB: 35’ 7” Corrosion Holes @ 10,185’ Zone F-7 3 4 5 6 Tubing Punch ±5,000’ 9-5/8” TOC 10,250’ 1 2 Volumetric ToC with 10% washout at ~8,400’ MD Bad Casing below 9,244’ TOL @ 10,309’ 13-3/8” X X CASING DETAIL Size Wt Grade Conn ID Top Btm 24” Surf 315’ 13-3/8” 61 J-55 BTC 12.516 Surf 2,476’ 9-5/8” 47 N-80 / P-110 BTC 8.688 Surf 10,434’ 7” 29 N-80 BTC 6.184 10,309’ 13,368’ TUBING DETAIL 3-1/2” 9.2 N-80 BTC 2.984 Surf 351’ 2-7/8” 6.5 L-80 8rnd EUE 2.438 351’ 10,142’ Junk Tubing 3-1/2” 9.2 N-80 BTC 2.984 10,676’ 12,472’ Note: Suspect Cork-Screwed Tubing below 8,500’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 35’ 35’ 2.984 Hanger 1 307’ 307’ 2.813 HES “FLX” TRSV 2 9,139’ 7,024’ 2.313 HES “XD” Durasleeve SSD 3 9,186’ 7,057’ 3.875 HES 9-5/8” 43.5# - 53# “VTL” Packer 4 10,059’ 7,655’ 4.00 HES 36# - 59.4# “BWD” Permanent Packer 5 10,110’ 7,689’ 2.313 HES “X” Landing Nipple 6 10,142’ 7,710’ 2.984 Re-Entry Guide 10,640’ 8,075’ EZSV 10,797’ 8,195’ Camco KBUG GLM 11,150’ 8,444’ Camco KBUG GLM 12,413’ 9,252’ Baker FB-1 Packer 12,458’ 9,283’ 2.75” Camco “D” Nipple 12,472’ 9,292’ WLEG 13,200’ 9,767’ EZ Drill Retainer FISH 02/12/1995 12,800’-12,824’ – 1-1/2” Slickline Tools PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status HK-1 12,520' 12,564' 9,325' 9,355' 44' 06/08/1996 Isolated HK-2 12,588' 12,720' 9,371' 9,460' 132' 06/08/1996 Isolated HK-3 12,720' 12,806' 9,460' 9,516' 86' 06/08/1996 Isolated HK-4 12,806' 12,878' 9,516' 9,562' 72' 06/08/1996 Isolated HK-4 12,902' 12,979' 9,578' 9,626' 77' 06/08/1996 Isolated HK-5 12,992' 13,192' 9,635' 9,762' 200' 06/08/1996 Squeezed HK-6 13,212' 13,300' 9,775' 9,831' 88' 08/22/1970 Squeezed OPEN HOLE / CEMENT DETAIL 13-3/8"18” Hole: Pumped 1175sxs Class G with 10% gel lead followed by 450sxs neat tail cement.Notes indicate cement circulated back to surface (522sxs back) 9-5/8"12-1/4" Hole: Pumped 700sxs class G. No losses noted. Did not bump plug. 8.8bbls cement found inside 9- 5/8” (including shoe).Volumetric ToC with 10% washout at ~8,400’ MD. Tubingg Punch ±5,000’ Corrosion Holes @@ 10,185’, Zone F-7 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. Mr. Maunder: Unocal Corporation P O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7805 UNOCAL ' Alaska November 5, 2002 State of Alaska Alaska Od and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Attn: Tom Maunder Re: 10-407 for June 1996 Workover King Salmon Platform Well No. K-5 Trading Bay Unit McArthur River Field Per our phone conversation, attached please find a 10-407 and supporting documents for the June 1996 workover and recompletion of the King Salmon Platform Well No. K-5 ~n Trading Bay Unit. Apparently, this paperwork was inadvertently left undone. In March 1996, Well K-5 (a Hemlock oil producing completion) experienced a sudden failure of the casing (due to corrosion) above the production packer and across from the Grayhng Gas Sands F-7 Sand at 10185' MD. With shut-in tubing and casing pressures reaching 3000 psi, the well was worked over in June 1996. Significant corrosion of the tubing also prevented a successful recovery of the entire tubing stnng and after the Hemlock was abandoned, the well was completed to produce the gas from the F-7 Sand. Due to apparent corkscrewed tubing just above the packer and eventual fill above all of the F-7 Sand, perforating has not been possible. After surface facilities were modified in 1997 to handle the high pressure gas, attempts to make Well K-5 suitable for sustmned flow were unsuccessful. Therefore, the well has been essentially idle since the June 1996 workover. The limited flow tests on Well K-5 (which produces gas, water, and sand) have been through the corroded holes in the casing. If you have any questions regarding this, please contact me at 263-7675. Enclosures K-5 10407 Cover Letter to AOGCC 1102 Sincerely, Hal Martin Reservoir Engineer RECEIVED NOV 0 7 2002 M,a l & gens. Oommlgsloa Anohomge JJd STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Serwce Well OIL: GAS X SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 68-18; 96-122 (Sundry Approval) 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 50- 733-20092-00 4. Location of well at surface Leg 2, Slot 16 King Salmon Platform 9. Unit or Lease Name 615' FSL, 119' FEL, Sec. 17, T9N, R13W, SM Trading Bay Unit At Top Producing Interval (10185' MD) 10 Well Number 2004' FSL, 531' FEL, Sec. 21, T9N, R13W, SM K-5 At Total Depth 13,370' MD/9874' TVD 11. Field and Pool 11' FSL, 4788' FEL, Sec. 22, T9N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. McArthur River Field 100' KBI ADL-17594 Grayling Gas Sands ' 2. Date Spudded3/24/68 13' Date T'D' Reached I 14' Date C°mp" Susp' °r Aband' I ' 5' Water Depth' if °fish°re ' 6' N°' °f C°mpleti°ns5/16/60 6/17/96 Completed 125' 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+'rVD) I 19. D~rectional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 13370' MD/9874' TVD 10250' MD/7784' TVDI Yes: No: XI 307' feet MD NA 22. Type Electric or Other Logs Run GR/USIT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 61# J-55 0 2476' 18" 1625 sx 0 9-5/8" 47# N-80, P-110 0 10434' 12-1/4" 700 sx 0 7" 29~ N-80 10309' 13368' 8-1/2" 800 sx 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" x 2-7/8" 9192' Stung in to leo. Assy None (Holes m casing) 2-7~8" Isolation Ass' 10143' 9186', 10059' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Producbon I Method of Operation (Flowing, gas Idt, etc.) 2/10/2000I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 2/11/00 18 TEST PERIOD => 0 2,625 83 24/64I N/A Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1375 t40 24-HOUR RATE => 0 3,600 114 N/A 28. CORE DATA Brief descnpbon of hthology, porosity, fractures, apparent dips and presence of od, gas or water. Submit core chips. None NO!/ 8 2002 RBOMs BFL AFE #151736 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit ~n duphcate 29 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and grav~y, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. GGS F-7 Sand 10,185' 7,738' 31. LIST OF ATTACHMENTS Wellbore schematic, Daily Summary of Rig Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S~gned _ Title. Reservoir En.qineer Date 11/5/02 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 rejection, water injection, steam injection, air injection, salt water d~sposal, 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 space 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 ~em 24 show the pmducfln intervals for only the interval reported in ~em 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 (D.F, 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. UNOCAL ) King Salmon Well K-5 Workover Recompletion to GGS Daily Summary 5/20/96 5/21/96 5/22/96 5/30/96 5/31/96 6/1/96 6/2/96 6/3/96 6/4/96 6/5/96 6/6/96 6/7/96 6/8/96 6/9/96 RU DS pump to well tree and pit. Had 3000 ps~ on both casing and tubing. Began pump/bleed operation -- Lubricated 9.0 ppg KCL/NaCI brine down annulus and bled off gas from tubing. Continued pump/bleed operation. Tubing and casing pressure reduced to 100 psi. No change observed on annulus pressures of nearby wells K-7, K-17, K-30RD, or K- 21 RD during pump/bleed operation. Accepted rig. Continued riggig up. Continued rigging up. Continued rigging up. Lubricated 9.0 ppg KCL/NaCI brine down annulus and bled off gas from tubing. Tubing and casing dead. Continued rigging up. Reverse circulated 430 Bbls 9.0 ppg bnne. Well dead. Installed BPV. ND tree. NU and tested BOPs. PU on tubing and parted pipe. POOH laying down 4- 1/2" tubing Continued POOH with 4-1/2" tubing TOF at 10222'. microroentgens/hr. PU 8-1/8" OS on 3-1/2" DP. NORM at 50-70 Continued RIH with fishing assembly, PU 3-1/2" DP. CBU. Washed down and latched fish at 10222' PU and pulled loose w~th 60K overpull POOH POOH with fish Recovered 439' of fish TI H w/ 5-3/4" OS with extensions and engaged fish at 10666'. PU and pulled loose with 60K overpull. POOH w/16' of fish. TIH w/8-1/2" bit on clean out assy. Continued RIH with b~t and tagged top of 7" liner at 10311' POOH. TIH w~th 6" bit on clean out assy. Tagged TOF at 10676' DPM. C~rculated clean w~th 8.8 ppg brine. POOH. RU Schlumberger. Ran GR/USIT log from 10600' to surface. Ran 7" EZSV on DP and set at 10515' DPM. Pumped 8 Bbls cement below retainer and equalized 16 Bbls cement above retainer. POOH. TIH w/ 8-1/2" bit and 9-5~8" scraper Drilled hard cement from 10187' to 10250' Unable to test 9-5/8" casing. Ran RTTS and determined top hole in casing at +/- 9244' DPM. O:\OOE\OOEFlelds\TbuXKlng\WellsXaK-05\State_Fonns\407xaK-5 10-407 DmlySummaryl 102 for 0696 Workover.doc 11/5/2002 UNOCAL ( King Salmon Well K-5 Workover Recompletion to GGS Daily Summary 6/10/96 6/11/96 6/12/96 6/13/96 6/14/96 6/15/96 6/16/96 6/17/96 POOH. RIH w~th Halhburton "BWD" packer with tail pipe assembly on DP. Set packer at 10059' with tubing taft at 10142' Circulated 9.0 ppg FIW + 3% KCL packer fluid POOH. TIH with Halhburton "VTL" packer and ~solat~on assembly and stung seals in to "BWD" packer at 10059'. Dropped ball and set "VTL" packer at 9186' POOH laying down 3-1/2" DP. Tested BOPs. PU and ran 2-7~8" completion string with gas lift and crossover to 3-1/2" tubing at 350'. Stung in to J-latch receptacle and spaced out with 20K down weight. Installed tree. RU slickline. RIH with 2" JDC pulling tool. Gaining 100 lb p~ck up weight per 1000' near EOT. Unable to work past 9983' POOH. RU braided line RIH with 2" JDC tool and worked to 10041' WLM POOH RIH with 2" drive down bailer and worked to 10129' WLM (RKB). POOH w~th "soupey, scaley, dopey" material RIH w~th 31'x 1-1/2" tool string with 2-1/4" blind box to 10127' WLM (RKB) RIH with various tool stnngs. Max depth reached of 10089' WLM (RKB) Bailed several times recovering similar material as above as well as dry clay and some rubber pieces. RIH with "GS" pulling tool and recovered "PX" plug from "X" n~pple at 10110'. RIH w~th 2.29" GR and tagged at 10222' WLM (RKB). RD. O:\OOE\OOEF~elds\TbuXK~ng\WellsLK-05\State_Forms\407~c~-5 10-407 DaflySummaryl 102 for 0696 Workover doc 11/5/2002 : King Salmon K-5 507332009200 Well Head (0 0-35.0, 0D'13 3/8, Cement (35 Tul~ng (51 ~-299.8, OD:3 1/2, Pup Jt (299.7-306 5, OD.3 1/2, Top Sub (306.5-306.9, OD:4 33/64 ID~2 Sssv Valve (306.9-314.5, OD-3 ID;2 13/18) Btm Sub (314.5-314.8, OD:4 15/64 ID:2 13/16) Surface Casing (35.0-2476 O, OD: 3/8, Wt:61.00) Tubing (351 2-g132.5, OD:2 7/8, Pup Jt (9132.5-9138.7, OD:2 7/8, 7/16} Steeve (9138.7-9143,0, Pup Jt (9143 0-9148.1, OD:2 7/8, 7/16) Cement Tubing (g148.1-9180.4, 002 7/8, 7/16) Pup Jt (9t80.4-9185.5, OD:2 7/8, 7/16) Crossover (9185.5-9186.2, OD:4 ID:2 7/16) Locator Joint (9186.?-9187.7, 17/64, ID-3 1t16) Retry. Packer (9186.2-9192 2, 19/64, tD:3 7/8) Pup Jt (9193.7-91982, OD:2 7/8, 7/18) Tubing (9198.2-10051.7, ID:2 7/16) Pup Jt (10051 7-10057.8, I D'.2 7/16) Locator Joint (10057.8-10059 17/84, ID:2 7/16) Extension Packer OD;8 1/8, ID:4 ) Pup Jt (10072.8-10077.9, ID:2 7/16) Tubing (10077.9-10109.6, I D:2 7/16) Landing Nipple (t0109.6-10110.6 OD:4 1/4, ID:2 5/16) Casing (9245.0-10433.0, Wt:47.00) Cement Plug (10250 0-10309.0, Bad tag (10060.0,10309.0, wt-47.oo) Shoe (10433 0-10434,0, Cement Plug (10~309.0-105 I5,0, -- SL- 4/27/98 31 -Jun-Ce STATE OF ALASKA ( ,-AND GAS CONSERVATIO I COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well X Plugging' T~me extension Sbmulate: Change approved program Pull tubing X Vanance Perforate Other' 2 Name of Operator 5 Type of well 6 Datum elevabon (DF or KB) UNOCAL Corporahon Development X 100' KB feet 3 Address Exploratory 7 Unit or Property name P O Box 19-0247 Strahgraph~c Trading Bay Un~ Anchorage, AK 99519-0247 Sennce 4 Locahon of well at surface 8 Well number 615' N & 119'W from SE Corner, Sec 17, T9N, R13W, SM K-5 At top of productive ~nterval 9 Permit number 612' N & 5033' W from SE corner, Sec 22, T9N, R13W, SM 68-18 At effectwe depth 10 APl number 286' N & 4894" W from SE Comer, Sec 22, T9N, R13W, SM 50- ~ 7-.,~'" ~:~~~ ~'L~ At total depth 11 F~eld/Pool 11'N & 4788' W from SE Corner, Sec 22, T9N, R13W, SM Hemlock 12 Present well condition summary Total depth truemeasuredvertlcal 13,370 feet 9,864 feet Plugs(measured)ORIGINAL Effechve depth measured 12,990 feet Junk (measured) true vertical 9,623 feet Casing Length S~ze Cemented Measured depth True vertical depth Structural Conductor Surface 2,476 13-3/8" 1175 sx G ~ 12 8 2,476 2,273 Intermediate + 450 sx G {~ 15 8 Producbon 10,434 9-5/8" 700 sx G 10,434 7,898 Liner 3,059 7'' 800 sx G 13,368 9 863 Perforation depth measured 12,520'-564', 12,588'-878', 12,902'-979' true vertical 9,313'-9,342', 9,358'-9,550', 9,566'-9,617. Tubing (s~ze, grade, and measured depth) U U fl 0 4-1/2',, 12 6~, N-80, BTC A-B modified {~ 10,277' MD, 3-1/2", 9 2~, N-80, BTC A-B modified @ 12,47Z Packers and SSSV (type and measured depth) Baker FB-1 packer {~ 12,413', Camco TRDP-1A SSSV @ 281' MD Alaska Oil & Gas Cons bOfllflllSSlOrt 13 Attachements Descrtphon summary of proposal Detaded operahons program X BOP ske~(~l~'"~. 14 Estimated date for commencing operahon 15 Status of well class~ficabon as May 30, 1996 16 If proposal well verbally approved: Od X Gas Suspended Name of approver Date approved Se~ce 17 I hereby cerhfy that the foregoing ~s true and correct to the best of my knowledge. Signed' Z~~ (J- {~lQ..-x T,tle DrdlingManager Date: May24,1996 FOR COMMISSION USE ONLY Cond~3ons of approval Notify Comm,sslon so representahve may w,tness IAppr°val N°'~)~ Plug Integnty z..'" BOP Test ~ Location clearance -" Mechamcal Integnty Test Subsequent form required 10- J'~.O ~'~ &pproved Copy Returned Original Signeci By __ David W. Johnston ' l" Approved by order of the Commissioner Commissioner Date ~)////?~:) Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ~ PRODUCTIOH.TOOLSoOF.RK i! Si' ! , · m ...2-/ 50-733-20092-00 King Platform Leg 2, Conductor 16 35.0- 2476.0' 1,$.,$75"00 61.OOJ/ll K-55 SURF CSC 2416.0 - 2416.0' ~ "" Proposed K-5 Trading Bay Unit Mc~hur River Field PRO. DE ~PLEllON RKB [lev. 100 FT. MSL _,~ Head ting Depth 35 Ft. Mkl'-Perf Deviation 50 I)egs. 350- 11810.0' 3.50" OD 9.20f/ft L-80 ~ ~,0- 36.[~ H~NC[R 36.0- 37.~ CRDSSOVER 4 1/2" x 3 1/2" ~5.0-10464.0' 9.625"00 47.00l/fi N-80/P-IIO PRO0 CSC 10100.0 - 10309.~ ZOO" O0 ~ Scab Lin~ 1241,3.0 - 12416,0' PACKER Boiml' FB-1 Pla' - 12824.0' BAR FISH 12/94, Weights (I0'), Slxmg-~s, ~: ~ooch 12824.0-12~.0' FI.L 6/6/94 [~t W/2.20" CR 1~- 13113.~ ~ ~ ~ i ~, 121' 1511&0 - 1~1~.~ ~ ~S 8-6, ~ ~, ~ lb~.O - 1~1.~ ~R EZ ~ 1~212.0 - I~.~ ~ ~S B-6, ~ ~, ~ ,.... _ ,";:. -,:li.,-~? :~., --- , .... ~- ~- - ' - "' ...,h, .,F ' 11750.0 - 11753.1Y PNCK[R Pr~ Pkr. 11/800- 11181.~ Z81" [} ~ ~ ~" 1252g0 1258&0 12720~ 1280~0 12902~ 12~,~.0 - ~2~.0' m B..t, 6/8 m', ~' -~.0' m B-~, 6/tO ~, 86' - t~.O' m ~-4, 8/t2 i~, 7? - 1~79.0' ~ B-4, 6 I~, T/' FILL-UP ANNULAR BOP 13 F8 3000 I I PIPE RAMS 13%'5000 psi BLIND RAMS 13%"5000 psx { FLOW KILL ,exi/m-x ~ SPOOL LINE ~ L/'-4tl/'--~3~,~ooo p~.~ CHOKE 4" 5000 psi['[ I] 4" 5000 psi LINE~ I PIPE RAMS { 13%"5000 psi I { RISER 130'8" 5000 pm RECEIVED JUN 0 a 1996 Alaska 0tl & 6ms Cons ~omm~6ston Anchorage COOK INLET' PLATFORMS= gqPq~ ~TA CK. 172 bbls. 1.6 bbl/in. SHALE SHAKER£ DEGASSER 248 bbls. 31 bbls/ff. CHEM. 2.6 bbl/in. MIXER 248 bbls. 31 bbls/ft. 2. 6 bbl/in. DESANDER-- 74 bbls. 9 bbl$/ft. .~ bbVi~. DESILTER 140 bbls. 16 bbls/ft. ~.~ bbi/~. DESANDER SUPPLY UUD HOPPER RETURN MUD HOPPER SUPPLY DESILTER SUPPLY TRANSFER LINE CENT SUCTION I~UDC, UNS POP OFT LINE LEOEMQ FROM MUD PUMP NO FROM MUD PUMP NO 2 TQ MUD PUMPS7 ! 11o' 10" GATE VALVE I ~ 4' BALL VAL~ I ~ I I 4~ I 4~ lui lul ill (' ':LUG VALVE FROM CEMENT PUMP Z" ID. 10,000 PSI WORKING PRESSURE STAINLESS STEEL ARMORED HOSE 10,000 PLUG VALVE t. Z 1/2 1.0 X 5,000 PSI ROTARY HOSE PLUG VALVE BLOW DOWN 2" PLUG VALVE r~ .i BI..ANK 3" TRIP TANK ?ILL UNE ~"SENSOR MANIFOLD $ I/2 ID. X 5,000 PS1 VIBRATOR HOSE FROM MUD PUMP RECEIVED JUN 0 ~ 1996 Alaska 0tl & Gas Cons. Commission Anchorage 4" x 5,00 MUO VALV[. F~OOF ~3 5/8' x 5,ooo ~ BLOWOUT PRE~ STACK VENT OUTS/DE WlNDWALLS VENT UP DERRICK PANIC LINE --~ 4" 5,000 PSI BALL VALVE 3' RELIEF VALVE SET AT 40 PSi ~0" VENT LINE -- 10,000 PSi HYD. CHOKE BUFFER TANK G~4G£ AOJ. CHOK£ MUD CAS ,//~ 2' 5'IPHON UNE MUD RETURN UNE JUN 0 fi ~o~ 'Naska Oil & Gas Cons uommm~ul, Anchorage ,50-733-20092-00 King Plalform Leg 2, Conductor 16 13.$75" OD SUI~ CSG ~ 2476.0' 9.625" O0 PROO CSC ~ SHOE 0 2476.0'"' K-5 Trading ~ Unit kArthur River Field · PRESENT RKB Elev. 100 Fl'. MSL ., Head ting .Depth 35 Ft. Mid-Per[ l)ev~ation 50 Degs. 35.0 - 10277.0' 4,.50" O0 TBC 10277.0- 12472.0' 3.500" O0 TBC RECEIVED JUN 0 6 1996 Alaska 011 & Gas Cons commission Anchorage ~ F~H 0 62~1.0' SlE 0 100,.0' z~ 7.00"00 UNB 0 13368.0' flSt. I FtL 0 12824J)' 12992.0 - 13115.0' ~E ~ 13113.1) - 13192.0' SOLIEEZE I:~ RB~ g 1,1200.1/ 15212.0 - I~.0' .~lJ~E PILE'S FLOATg'tO[ ~ 13367.0' J C~R 01o2n.17 /13/% h~b~ Hole lj 10180' J- P~a([R e 12413.0' ~ ~ 0 12458J~ · OE iS Fi! u~,omL .~ii,~.Fvk~,.,E F.q4 h0. ~u~ 263 7884 APPLICATION FOR SUNDRY APPROVALS P, 01./09 1 T,,vpe of Request: UNOCAl. Corporation 3. Address P O Box 19-0247 A~:ran. c~on: ,X Suspend: ~bcn shutdown, _ Alter casing, Repair well Plugging, Change approved p-'-'~ra,'fl' Pu, tubing varrance' ._Anch.°.ra ,ge, AK 9~_5190247 Type of wed. Development _X__. Exploratory' ---.- Str'afigraph~c: ~ Sqrwce' Location of well at surface 615' N & 11g'W from ,SE Comer, Sec, 17, TgN, R13W, SM At top of productive interval 6i2' N & 5033' W from SE comer, Sm 22, TgN. RI3W, At effe~ve del~h 286' N & 4894" W from SE Corner, Sec 22, TgN. ~3W, ~I'N & 4788' W from SE Comer, Sec, 22. TgN, R13W, SM Re-enter suspended well. ' ' ' Time extension: Stimulate: Perforate: Othe~ 7 Umt or Property name Trading Bay Unit 100' KB feet S. we, n~n~ber ' ' , ,, 9. Permit number 68.-18 "iO~API numl~er ....... 50- -733-20092.,0 - 1'1, Fieid/Po~l He~ocl( 1Z Present w~ll conc~ffion summary Total depth: measured 13 370 feet true verttcal 9,864 fe~t Effective depth: measured 12,¢J0 feet true vertical 9,6Z3 feet P?ugs (measured) Junk (measured) 0RI61NAL Casing, , Length Structural Conductor Surface 2,476 tntermedmte Production 10,434 I. ina' 3,O59 Perforabon depl~: measured ~ Cemented Measured depIh 13-3/8' 1175 s~ G {~ 12 8 2,476 + 450 sx G {~ 158 9.5/8" 700 ~ G 10,434 7" 800 sx G 13,368 12,520'-564', 12,.~'-878'; 12,g0Z-979' True vettlcat depth 2,273 7,898 9.883 true vertical 9,313'-g,34Z, 9,358'-g,550', 9,566'~,617' 13 14 Tubing (siZe, grade, and measured depth) 4..11Z', 12.6~, N-80, BTC A-I~ modified ~. 10,277' MD, 3-1/2", g.2~, N-80, BTC A-B modified ~ 12,472' Packers and SSSV (type and measured depth) , Baker F ,B.1 _pa_cker..~ 12,413', Camco TRDP-1A SSSV {~ 281' MD Attachemellts Descnptlon summary of proposal: Detailed opemtJons pr~mm: X , BOP sketch: F.=t~mat~ date [or commencing operatmn June 8, 1996 16 If praposal welt verbally approved: ?Jame of aDprcver D~te ?..~pmved 15. Status of well classification as' Od X Gas' -- ~ Service: Suspended' I ? I hereoy cellify that the foregoing is true and correct to the best of my knowledge. Si,ned .,, ~;.~_. ,,~~ ,T,m~: DnllingManager FOR coMMISSION USE ONLY ' PI~ int~~ BO~ Te~ ~ L~ ~n~ M~h~a Integrl~ T~ Su~u~ m~ r~u~ I~ _~ 0 ~__ . "~. o'~e ' ' ............ .... Date:. June,7, 1996 .... AlaSka 01[ & Gas Cons'. Commt~sion . Anchorage ui,i,o,,.;~,.....~i,C;~L.,r~,C-E FR× ~I0, 907 263 7884 P, O2/O9 ., i RECEIVED Naska Oil & Gas Cons. Commission Anchorage UNOCflL flI, IOHORflGE FAX NO, 907 263 7884 03/09 TBU K,O$ Workover Procedure Revision 4 Introduction: The objective of this workover is to completely kill the well so that the tubing can be pulled and an assessment macte of the potential casing damage. Well control operations are complicated by lost slickline in the hole. Although "killed" once, the well pressures have continued to build and a second kill was necessary in order to reduce the wellhead pressures and prepare the well for rig workover. Well History: On the evening of March 13, platform operation personnel felt a "iolt". It was later discovered that K-05 was experiencing heading flow. When the well was shut in, the tubing and annulus pressures built up to 2900 psi. The suspected cause of the pressure is communication to a deep Grayling gas sand due to either a hole or part of the 9-5/8" casing. The well was killed via the lubrication method using a combination of 9.2 ppg CaCO3 LCM pills and FIW w/, 3% KCI. When the initial pumping operations were completed, the casing pressure was 480 psi and the tubing pressure was 90 psi. Since the pumping operations were completed, wireline fishing operations have been conducted in an attempt to recover some of the 12,000' of slickline previously lost in the hole. These fishing operations have cleaned the wellbore out to about 6,200' MD. This is below the 3rd GLM in the string,, The gas lift valves in mandrels 1 and 2 have been successfully removed and dummies installed. Throughout the wireline fishing operations, the tubing and annulus pressures have increased. The pressures increased to nearly the initial values of mid March and the well was again killed. Move Rig from K-26 to K-05 1. Move rig from K-26 to K-05. Kill Well: Conduct additional kill activities prior to or during rig move if possible 2. Fill pits with workover fluid. Based on the recent successful lubncation using, 9.0 ppg bdne, that fluid should be used. 3. Rig up Doweli to th,e tubing annulus and to the tree above the swab valve. Pressure test lines to 4500 psi. Insure' sufficient block valves are in the lines to avoid' using the tree valves if possible, A check valve should be included as practical. 4. Equahze pressure.across 9.-5t8" x 4-1/2" annulus and open valve. RECEIVED JUN 0 7 199(; Alaska Oil & Gas Cons. Commission Anchorage KGO5PRO4.doc 6/7/96 2 24 PM UNOCAL ~NOHORF~GE FP,× NO, 907 263 7884 5. Shoot fluid level in annulus and tubing if possible. Calculate available volume in annulus. 6. Lubricate 9.0 ppg mud into the annulus, observing for any sharp pressure ~ncrease indicating fluid at Surface. ' 7. Bleed off annulus gas observing for fluid. SI annulus and bleed off tubing Repeat as necessary to kill well; 8. After lubricating into annulus, attempt to reverse drculate well via #3 GLM, shut down circulation and observe well. Note. If it is not, possible to cimulate, be prepared to punch c~rculating holes with Schlumberger puncher (4 spf, 2'). Plan to punch tubing immediately below #3 GLM at 5799' MD. 9. Install FMC BPV in tubing hanger. 10. ND tree, NU BOP equipped with vadable bore rams. Note: VBR's are recommended since the tubing ~s a combination strfng of 4-1/2" and 3- 1/2" and the DP is 3-1/2" as well. A set of 3-1/2, - 6" Hyddl VBRs is available on the Baker Platform for installation in the single. A set of 3-1/2' - 5" Shaffer is available in the warehouse for installation in the double. Send tree to FMC in Anchorage for refurbishment. 11. Test BOP per Unocal specifications. If so noted on well permit, notify AOGCC 24 hours in advance of BOP test so they may witness if desired. 12. Check well for pressure and retrieve BPV. Note: If necessary it is possible to pump through BPV. BPV cannot be retrieved through landing joint. 13. Screw landing joint into tubing hanger. Hanger landing thread is 4-1/2" Buttress. Have circulating lines and valves dgged up to landing joint. Test lines to 4000 ps~. 14. Back out lockdown screws, Pick up on landing joint and attempt tc pull seals from packer. Note; Allowable pull on 4-1/2' tubing based on derating to 80% is 230,000#. Buoyed weight of string, based on 9.0 ppg fluid is 128,0008. Pulling to 230,000~ does not dsk parting the tubing at the 4-1/2" x 3-1/2" XO. Based on buoyed weight of 4-1/2', pull at XO should be about .120,000#. These {]gums neglect hole drag, No actual completion report has been located. Note: On the evening of June 3, the workover had proceeded, to step 14. When the attempt was made to pull the tubing, it parted at 175,000g pull. 10,189' of fi~h 2 RECEIVED JUN 0 7 ]996 Alaska Oil & Gas Cons. Commission Anchorage KG05PRO4 doc 6/7/96 2:24 PM JUN-07-@6 FRI 02:16 PI'I UI/OCRL RNCHORRGE FAX IlO, 907 263 7884 . ( ( ?, 05/09 was recovered. 2 fishing trips have been made since then with recoveries of 439' and 16'. Present, TOF is estimated at 10,677' and is about 366' below the top of the 7" liner. The tubing below about 10000' has been badly corroded, Some of the lost wimline has been recovered with the tubing, It is estimated that about 1,000' of wire has been recovered, leaving some 3,000' still in the well. 15. PU 8-1/2' bit and 9-5/8' casing scraper. Use caution due to potential casing damage. Although the casing problem is be!ie,;ect to be at cr near the liner top, the exact location is'unknown. RIH cautiously to avoid running into a section of collapsed casing. RIH and tag liner top at 10,309' 16. PU 6" bit and 7' casing scraper. Use caut~cn due to potenbal casing damage. Aithough the casing problem is believed to be at or near the liner top, the exact location is unknown. RIH cautiously to avoid running into a section of collapsed casing. RIH and clean out 7" liner to about 10,650'. Do not attempt to tag fish. 17. Circulate and condition workover fluid. Assure well is stable. POOH 18. RU Schlumberger and run USIT casing inspection log. Note: Schlumberger has indicated that if the workover fluid is clean, it is possible to inspect both the 7" liner and 9-5/8" casing on one tnp. Tim Smith has indicated that there will be only one depth charge even if two trip are needed. Logging speed is 15.00'/hr, , Assuming the USIT Iog indicates 9-5/8= casing damage is limited to 10,000' and deeper; it is proposed to abandon the 7" liner and complete the well as a gas well in the zone at 10,180.'- 10,220'. Two alternatives are possible for abandoning the 7" liner, 1. If competent pipe is identified in the 7" liner, set a 7" retainer above the fish at about 10,640' and attempt to squeeze cement below the retainer and spot sufficient cement above to fill the liner into the 9-5/8" casing. 2. It' competent pipe is not identified, spot a balanced plug from above the top of fish up into the 9-5/8" casing. A cleanout trip would then be made to clean the well out to about 10.250'. 19. PU 7' F2.SV, running tool, 14 joints £-7/8" tubing stinger and RIH. Plan to set EZSV at about 10,640'. 20. Sting into retainer and establish injection rate. Use analysis from USIT to guide establishing pressure limits. When originally ddtled, Re liner was tested to 1000 psi on a 10.7 ppg mud column resulting in a 13.1 EMW at the liner top at 7,797' TVD. On this basis, 1,660 psi on a 9.0 ppg column is 13.1 EMW at the liner top. 21. Assuming it proves possible to inject below the retainer, mix and pump 115 sx Class G (24 bbls) at 15.8 ppg. JUN 0 7 1996 Alaska Oil & (]as Cons. Comml~mn Anchorage KG05PRO4.doc 6/7t96 2;24 PM .JUN-07-96 FRI 02:15 P~I UNO~l ~NOHOE~GE FAX NO, 907 263 7884 ( P, 06/09 22. Spot cement to stinger, sting in and pump 6 bbls of cement below retainer. 23. Unsting and spot remaining cement on top of retainer. 18 bbls of cement shou!d completely fill 7" liner and 9-5/8" camng to about 10,230'. 24. Pull out of plug and POOH. No pumping is necessary if the pipe is on vacuum 25. MU 8-1/2" bit and 9-5/8' cssmg scraper. RIH and tag cement plug. Assure wellbore dean to 10,250'. POOH. 26. PU 9-5/8" RTTS and bypass TIH to about 10,000' Set RTTS and test 9-5/8" casing to 3000 psi. PU 9-5/8" R']-FS and bypass. 27. POOH. NOTE; if it is not possible to set an EZSV in the 7" liner, substitue the following steps, 19 PU 14 joints 2-718' tubing stinger on 3-1/2' DP and RIH. Position stinger at about 10,660'. 20. Mix and pump 85 sx Class G (17.7 bbi), Spot balanced plug from 10,660' to' 10,240'. 21. Pull out of cement and POOH, Avoid pumping unless necessary., 22. MU 8-t/2' bit and 9-5/8" casing scraper, RIH and tag cement plug. weilbore clean to 10,250'. POOH. Assure 23. PU 9-5/8" RTTS and bypass. TIH to about 10,000'. Set RTTS and test 9-5/8" casing to 3000 psi. 24. POOH LDDP. Run new completion: 27. Puli wear bushing 28. MU 9-5/8" permanent packer, seat bore, 1 joint 2-7/8' tubing, 2-7/8* X topple (2.313" ID), I joint 2-7/8" tubing and WL entry guide/Shear out sub on Schlumberger, EL. , , 29. RIH and set at about 10,000'. 30. RU tubing crew, MU seal unit, 1 joint 2-7/8" tubing, sliding sleeve and 2-7/8" tubing stdng, See attached completion detail. · , Note: Do not pick up SCSSV until annulus has been pressure tested and space out requirements have been determined, JUN 0 7 1996 Al~ka 0ii & Gas Cons. Commission Anchorage KGO5PRO4.doc 6/7196 2:24 PM JUN-O?-96 FRt 02:i5 UI,tO¢6L rlNOHOR~GE FAX 1,lO, SOT 263 78.~4 ( P, 0~/09 31. Stab into packer wrth seal unit and land locator. Determine space out requirements. Plan to land tubing with Iocator about 1' above packer 32. Drop bali in tubing. Allow ball to fall Pressure up on tubing to 3000 psi Hold pressure for 15 minutes. 33. Bleed off tubing pressure, close annular and pressure test annulus to 3000 psi. Hold pressure for 10 minutes, Release pressures and open annular, 34. POOH wIth about 10 joints of tub;rig and MU SC$SSV. Test control line to 5000 psi. Maintain control line pressure while running ~n hole. 35. Space out, Install tubing hanger and Xover(s) from 2-7/8" to 4-1/2", Cut control line and MU to hanger. Test Control line to 5000 psi, 36, MU landing joint and land tubing hanger. Run in lock down screws, Make sure tubing is open when engaging seals to avoid blowing ball out of shear sub. 37, RU Dowell to tubing and annulus. Pressure test lines to 4000 ps~, 38, Open 9-5/8" annulus valve and pressure up on tubing to 3000 psi and test 10 rain, 39, Pressure up on annulus to 3000 psi to test packer and seals for 30 minutes. · pressure and note volume returned. 40, Release all pressure on annulus. Pressure up on tubIng to 3000 psi. Release 41. Pressure up on tubing to 3000 psi and close SCSSV. Bleed off pressure a'bove $C$SV, Note marked decrease in return volume venfymg SCSSV is closed and holding. 42, Pressure up to 3000 psi above SCSSV to equalize. Open SCSSV. Pressure up orr annulus to 2000 psi, Pressure up to 3500 psi on tubing to shear out ball. 43. Retdeve landing joint. Install BPV. 44, Remove BOP. 45. Install tree. 46; Puli BPV and install tree test plug. 47, Test tree to 5000 psi. 48. Turn well over to production. KG05PRO4.d0c 6/7/96 2:24 PM OUN-OV-~6 FR~ 02: 1~ PH UNOORL ~NOHOR~GE F~X NO, 907 263 7'884 P, 08/09 June 7, 1996 To Tom Matmder From: Hal Martin Re AOGCC Questions Conce,m/ng K-5 1 Are we losing reserves by not recompleting back into the Hemlock? Any completion abandoned results in a loss of some incremental recovery of oil, simply due to the proximity of the well bore to the oil immediately in the area. In the case of K-5, the incremental loss is negligtbte. Prior to the easxng failure, the K-5 was producing at 190 BOPD, 4300 BWPD, 95 8% WC Based on the negative impact the killing and workover operation will have On the completion, it is expected that the most likely production output from a restored K-5 completion would be approximately one-half the former oil;rate, or 95 BOPD ,Over a field life of 8 years, that equates to a cumulative production of approximately 180,000 BO. As a result, the K-5 is economically unattractive to recomplete in its current location and given its current well bore condition. Offset wells G225 and K-17 are slightly upstructur~, similarly completed in the Hemlock, and within 1800' of K-5 and should continue to effectively drain the more permeable Hemlock Benches, which could reduce the 180,000 BO allocated to the K-5. Additionally, another well, K-9, is being planned for a redrill in an upstructure position to K-5 and will better define the current status of ali Hemlock Benches in the area. The K-9 redrill will not only improve overall Hemlock recovery in the area, but also help in the evaluation of a potential future redrill of the K-5, should the gas completion fail. 2 Is crossflow of the current Hemlock completion a concern'? Isolation of the Hemlock Benches from one mother is ideally preferred to eliminate,crossflow. ,PracticalIy speaking, there are two reasons that crossflow in K-5 is not a critical need. First, the location of the well in a down structure position minimizes the impact on recovery of crossflow, since s~gnificant recovery has already occurred and the potential crossflow of water from the more permeable and high pressure benches to the lower permeable and pressure benches may continue to benefit own'all sweep. Second, the essentially continuous perforating in K-5 in Hemlock Benches I through 4 makes effective isolation difficult, if not !mpossible, behind pipe. RECEIVED JUN 0 7 199t; Alaska Oil & Gas Cons. Commission Anchorage JUi,i-07-96 FRI 02' i6 ?11 UitOCRL RI',IOHORRO. E Fa;'<; NO, 907 2637884 P, 09/09 UNOC t.e' ( Unocal ( UNOCALe' 7-Day Project Summary Report ,, Well NA__w~_: HcA~T/%n= River--King Sal-K-~ Objective: K~ll Well, PUll Compl~ton & assess AFr.. #: 122718 AF~ Total: Tangible Toml Propo-~l TD: f~ GL Elev.: 0.0 fi ~ F_.]tw.: fi: 7-Day Operations Look Back Com~iet=~ POH with fishing assew~_l¥ #1, and laye~ down fish . ~_q~_o~er_ed of fiwh, ~ub_i__n~ had D~ed 27' below a coupling in a ve~ba~y ~'ozn~- ~ish inolu~ one 4 1/2" G~ wz~ p~s, o~e j~ant of 4 1/27 ~&~q, 4 150 ~rsho~ w~ 9e of e~s~ons, 4.25" baske~ ~apple ~h 3.635" circ. s~, b~er ~, ~ars, (6) 4 3/4" ~ill ~llla~. ~H to ~L $ !0,~09'~ 5~o 10. 666~ ~ e~=a~_~__~=~., a=~'=s-'~ ~1~ k6bs~ wL~ ~og ~~ ~a~, b~ u~,~s, (6) 6 ~/2" ~ co~2~, e 2400 W~ou~-P~pe za~s/Housek~p&n~ fai~, so~ boards ~d =i~n~ pi~ , Con~&nue ~R wi~h ~&shinq ass~ly ~1 pi~ing ~ 3 1/2" 13.39 S-135' ~use of consi~r~le b,,kk~ing a= flow ~pple. Con~inu~ ~H px~inq ~ill pi~e, ~ook we&gh~ ~ 10,059t. Worked do~ hole ~o 10,132', ~ing 7-10K and fluw~g ba~ ~' ~ill string. Wash~ ~ from 10,132 ~ -10,216' a~ bo~ ~. Work~ ~r fish:~o Z0,222~, no p~ p~ss~ increase~ up ~ pullea loose wi~ 60K o~ui1, 8K in=ease in pick ~ C&~la=~ an~ ~~red fled l~ls, no g~n o= loss. Stopp~ p~ ~se~ ~ell, s~a~ic. POH w2~ fish ~ 2400 hrs.. Walk,out :~ ~s/Housek~&nu ~oo~. CO~I~ P~H L/~ 4-1/2" ~G ¢~~TI~, TOT~ ~C.= 10188.48~ (S~) · 8 G~ ~IN 30' OF DE~, & ~C +- 1~40~ S~ LI~ (R~~ ~~T} , T.O.F ~ 10221.83~ ~./ C~ ~ ~G ~R NO~ (NO~ FO~ O~ S0 ~RO~~S ~ ~ ON O~ SIDE OF ~, S~ ~. ~ S~E OF ~ - 70 ~~~~S ~ ~, SL~ ~ ~ ~ O~ S0 ~O~~ ~~) / 2S0-S000 PSI (~) / ~DN'~ E~IP / M/~ ~S~NG ~LS - S-1/8" 9-1/9" O/S W/ 6-7/0" ~P~ + 30/S ~ + ~ S~ + B/S + ~ · XO+' ~-A-BO~: L/~ ~6, ~L P~ ~S ~ & ~ P~~ D~ ~ ~ ~ ~ ~ & D~ ~ ~ PIT RECEIVED · _ JUN 0 7 1996 AI~ Oil & Ga~ Cons. Anchorage JUN-07-96 FRI 17: 10 UNOO~L ~SSET G~S GRP ( Ffi× NO, 9072637874 ( P, 01/02 June 7, 1996 To: Tom Maunder From: Hal Martin Post-it' Fax Note 7671 I*o IPhone # ' Re' AOGCC Questions Concerning K-5 I, . Are we losing reserves by not recompleting back into the Hemlock? Any completion abandoned results in a loss of some incremental recovery of oil, simply due to the proximity of the well bore to the oil immediately in the area In the case of K-5, the incremental loss is negligible. Prior to the casing failure, the K-5 was producing at 190 BOPD, 4300 BWPD, 95.8% WC. Based on the negative impact the killing and workover operation will have on the completion, it is expected that the most likely production output from a restored K-5 completion would be approximately one-half the former oil rate, or 95 BOPD Over a field life of 8 years, that equates to a cumulative production of approximately 180,000 BO. As a result, the K-5 is economically unattractive to recomplete in its current location and given its current well bore condition. Offset wells (]-25 and K-17 are slightly upstructure, similarly completed in the Hemlock, and within 1800' of K-5 and should continue to effectively drain the more permeable Hemlock Benches, which could reduce the 180,000 BO allocated to the K-5. Additionally, another well, K-9, is being planned for a redrill in an upstructure position to K-5 and will better define the current status of all Hemlock Benches in the area. The K-9 redrill will not only improve overall Hemlock recovery in the area, but also help in the evaluation of a potential future redrill of the K-5, should the gas completion fail. Is crossflow of the current Hemlock completion a concern? Isolation of the Hemlock Benches from one another is ideally preferred to eliminate crossflow, Practically speaking, there are two reasons that crossflow in K-5 is not a critical need. First, the location of the well in a down structure position minimizes the impact on recovery of crossflow, since significant recovery has already occurred and the potential crossflow of water from the more permeable and high pressure benches to the lower permeable and pressure benches may continue to benefit overall sweep Second, the essentially continuous perforating in K-5 in Hemlock Benches 1 through 4 makes effective isolation difficult, if not impossible, behind pipe. JUN-07-96 FRI 17:10 UN00aL aSSET GaS GRP FaX NO, 9072637874 · UNOCALO' ( Unocal ?-Day Project Summary Report P, 02/02 UNOCALe Propo~d TD: fl GL F_~v.: O.O fl RKB Elev.: ft 7-Day Operations Look Back Completed POH with fishing assembly #1, an_~ layed do~A fi?h .. ~,C~.~ed,_ 439:! of fish,__ ~:ub.~nq h~d paz~ 27' below a ~oupZing in a ~ ~ 150 o~z~ho~ w$~ 9' o~ extensions, 4.25 basket grapple wzcn ~. ~J~ size..~, b~ez 8~, jars, (6) 4 3/4" ~tll,c?l~la~s. ~Ia to .~-~-!~~=4. W~sh~d ~ ~om 10,309' to 10,659' ~nd ctgau~a~ea o~e~n, wo~a .0veg ~is~nq too!s,. ~ up ele~n out ass~l~ ~1, 8 1/2".~t, ~o~_~, 9 ~s~ng soza~r, b~z s~,~a=s, (6) 6 1/2" ~11 Go&&ars ~ ~00 ARS.. p$ak~ up. Con~inu. ~N wi~h fishing ass~ly ~1 pi~ing up 3 1/2" 13.39 S-135 ~ill u~O 9,235e. Cir~a~ed bottom up, ~ook re~urns ~h~ choke ~d 9~s buster se o~ consi~r~le b~1ing it ~o~ nt~le, Continued RIH piek~ng and ~low~n~ back ~h~ ~iZ1 string, ~ashed do~ ~om 10,132 t -10 ~216' tagged ~tsh. C~leted ~iz~attn~ clean, moderate b~bling ~d seals at bottom up. Worked o~z ~ish to ~0.222', no p~ p~ssu~e ink.eye. Pieked up ~d ~11ed loose ~th 60E ore.u11, 8K increase in pic~ up ~e1~n~. Cir~1l~ed and monitored ~lu~d le~ls, no gain o~ loss, Stopped p~ and oboe~d well, s~atLc. POH ~th fish 9 2400 h~s.. Walk~ou~: Mud tanks/Sousekeepinq ~ood. CONT~ POOH L/DN 4-1/2" TBS CCMPLEATION, TOTAL REC.- 10188.48' (ELM) 328 JTS & ~ GLM WITHIN 30' OF DEPTH, & I~EC +- 1340' SLZ~K LINE (RUFFNE~K T.O.F ~ 10221.83! RKB / CHK ALL TBG FOR NORMS (NONE FOUND OVER 50 I~CCRORO~I~S ~ l~t ON OUT SIDE OF THG, SCALE FRM. IN SIDE OF TBG ~ 70 MICROROEHT~EN$ PER HR, SLICK LINE NONE FOUND OVER 50 MZCROROENT~ENS PER HR) ./ R/DN GBR & CLEAN FLOOR / R/UP TEST EQUIP. & TEST KELLY COCKS & .BLIND RAMS 2S0-.S000 .PSI (OK) / R/DN TEST E~UIP / M/UP FISHIN~ TOOL. S ~ 9-1/8" GUIDE W! 8-1/8" O/S N/ 6-?/8" ~PPLE · 30/S EXT + TOP S~B + B/S + JARS + XO + PDMP/OUT SUB + 6 DC'S + XO + INTENSAFZRER + XO B 237.54 / P/~P 3-1/2" DP WALK-A-BOUT: L/DN TBG, ALL PIN ENDS CAPED & THREAD PROTECTORS DONT FIT BOX END W~LL D~¢K ON & 6 JTS W/ HOLES WILL RAP IN VIS~UEEN NIGHT C~EW HELD VALVE DRILL & DAY CREW HELD PIT DRILL RECEIVED ............................... JUN_ 0 7 !996 ............. Alaska 011 & Gas Cons. Commission Anchorage TBU K-05 Workover Procedure Revision 3 JUN 0 ~ ~.~9~; Naska 0ti & Gas C(~ns [;omm~sston Anchorage Introduction: The objecbve of th~s workover ~s completely kill the well so that the tubing can be pulled and an assessment made of the potenbal casing damage. Well control operations are complicated by lost slickline ~n the hole. Although "killed" once, the well pressures have continued to build and a second k~ll was necessary ~n order to reduce the wellhead pressures and prepare the well for dg workover. Well History: On the evening of March 13, platform operation personnel felt a "jolt". It was later discovered that K-05 was experiencing heading flow. When the well was shut in, the tubing and annulus pressures built up to 2900 ps~. The suspected cause of the pressure is communication to a deep Grayling gas sand due to e~ther a hole or part of the 9-5/8" casing. The well was killed via the lubrication method using a comb~nabon of 9.2 ppg CaCO3 LCM pills and FIW w/3% KCI. When the ~n~tial pumping operations were completed, the casing pressure was 480 psi and the tubing pressure was 90 ps~. Since the pumping operations were completed, wireline fishing operations have been conducted in an attempt to recover some of the 12,000' of slickline previously lost in the hole. These fishing operations have cleaned the wellbore out to about 6,200' MD. This is below the 3rd GLM in the stnng. The gas lift valves in mandrels 1 and 2 have been successfully removed and dummies installed. Throughout the w~reline fishing operations, the tubing and annulus pressures have increased. The pressures increased to nearly the ~nitial values of m~d March and the well was again killed. Move Rig from K-26 to K-05 1. Move rig from K-26 to K-05. Kill Well: Conduct additional kill activities prior to or during dg move if possible 2. Fill pits with workover fluid. Based on the recent successful lubrication using 9.0 ppg bdne, that fluid should be used. 3. Rig up Dowell to the tubing annulus and to the tree above the swab valve. Pressure test lines to 4500 psi. Insure sufficient block valves are in the lines to avoid using the tree valves if possible. A check valve should be ~ncluded as practical. 4. Equalize pressure across 9-5/8" x 4-1/2" annulus and open valve. 10-403 I KG05PRO3.doc 5/24/96 6:55 AM 5. Shoot fluid level ~n annulus and tubing ~f possible. Calculate avadable volume ~n annulus. 6. Lubricate 9 0 ppg mud into the annulus, observing for any sharp pressure ~ncrease ~ndicat~ng fluid at surface. 7 Bleed off annulus gas observing for fluid. SI annulus and bleed off tubing. Repeat as necessary to k~ll well. 8. After lubricating into annulus, attempt to reverse circulate well via #3 GLM, shut down circulation and observe well. Note: If it is not possible to c~rculate, be prepared to punch circulating holes with Schlumberger puncher (4 spf, 2'). Plan to punch tubing ,mmediately below #3 GLM at 5799' MD. 9. Install FMC BPV in tub,ng hanger. 10. ND tree, NU BOP equipped w~th vanable bore rams. Note: VBR's are recommended since the tubing ~s a combination stdng of 4-1/2" and 3- 1/2" and the DP is 3-1/2" as well. A set of 3-1/2" - 6" Hydril VBRs is avadable on the Baker Platform for ~nstallation ~n the s~ngle. A set of 3-1/2" - 5" Shaffer is avadable in the warehouse for installation in the double. Send tree to FMC in Anchorage for refurbishment. 11. Test BOP per Unocal specifications. If so noted on well permit, nobfy AOGCC 24 hours ~n advance of BOP test so they may w~tness ~f des,red. 12. Check well for pressure and retrieve BPV. Note: If necessary ~t is possible to pump through BPV BPV cannot be retrieved through landing joint. 13. Screw landing joint ~nto tubing hanger. Hanger landing thread is 4-1/2" Buttress. Have c~rculating lines and valves ngged up to landing joint. Test lines to 4000 ps~. 14. Back out Iockdown screws. Pick up on landing joint and attempt to pull seals from packer. Note: Allowable pull on 4-1/2" tubing based on derating to 80% is 230,000#. Buoyed weight of stdng, based on 9.0 ppg fluid is 128,00(7#. Pulling to 230,000# does not risk parting the tubing at the 4-1/2" x 3-1/2" XO. Based on buoyed weight of 4-1/2", pull at XO should be about 120,000#. These figures neglect hole drag. No actual completion report has been located. If tubing will not pull, plan to cut tubing between #3 GLM (5799' MD) and hard wire ball last reported at (6237' MD) with APES chemical cutter, circulate well at cut depth, recover cut tubing, and fish tubing with packoff overshot and jars. 10-403 2 KG05PRO3.doc 5~24~96 6:55 AM RE 'FIVFD 15. Pull hanger out of bowl and attempt to circulate the well. 16. Circulate bottoms up and venfy well is stable. 17. Pull tubing stdng out of hole. Number joints and strap tubing. No tubing tally has been located in the town well files. NORM handling procedures should be practiced. Given the age of the completion, all recovered matenal should be sent to shore as junk. Note: Some 6000' of slickline (. 105") is stdl ~n the well. Last top of wire was reported at about 6200'. There is a poss~bd~ty that the w~re and tool string wdl be pulled with the tubing. Use caution due to the bnttle nature of the wire if an attempt is made to spool the w~re out. It is recommended to have bolt cutters available to cut wire if it is recovered when tubing is pulled. It may also be advisable to have wire bar clamps available. Based on the w~reline reports, the tool stnng was in the tubing when the line broke. A d~agram of the tool stnng is attached. 18. PU test plug and complete BOP test. Retrieve test plug and install wear bushing. 19. If the w~re was successfully recovered, PU 6" b~t and 7" and 9-5/8" casing scrapers. Space scrapers out to allow b~t to tag 7" packer at 12413'. Use caution due to potential casing damage. Although the casing problem is believed to be at or near the liner top, the exact location is unknown. RIH cautiously to avoid running into a section of collapsed casing. If the w~re was not successfully recovered, PU w~re stop w~th spear and TIH looking for w~re. Use caution due to unknown location of casing damage. Clean out to the top of liner. After runmng wire stop, make 8-1/2" bit and 9-5~8" scraper run to top of liner. 20. C~rculate and condition workover fluid. Assure well is stable. POOH. 21. If the w~re was not successfully recovered, PU wire stop with spear and TIH looking for w~re ~n 7" liner. Again, make bit and scraper run after w~re stop run. 22. RU Schlumberger and run USIT casing inspection log. Note: Schlumberger has indicated that if the workover fluid is clean, it is possible to inspect both the 7" liner and 9-5~8" casing on one trip. Tim Smith has indicated that there will be only one depth charge even if two trip are needed. Logging speed is 1500'/hr. 23. PU 7" retrievable bridge plug, running tool, 1500' of 3-1/2" DP and 9-5/8" RTTS. 24. RIH testing 9-5/8" casing. Testing depth will be determined based on the interpretation of the USIT information. 10-403 3 KG05PRO3. doc 5/24/96 6:55 AM RECEIVED JUN 0 G 1996 _Ala~k[U:)il & Gms Cons. Commmsion Accord)ng to the AOGCC regulations, a test pressure of 2000 ps~ will De sutt~cier~ch'~hl~ test pressure is 25 ps#ft x TVD of shoe. The 9-5/8" shoe is at approximately 8000' TVD. 25. Set 7" retnevable bndge plug at about 11800'. PU and set 9-5/8" packer at about 10280'. Attempt to test 7" liner and liner lap to 2000 psi. 26. Assuming the problem ~s determined to be ~n the 9-5/8" casing, repair the casing damage if possible. Note: At this time the enwsioned repair method w)ll be to straddle the damaged casing with a 7" scab hner. Once the damage is determined, a specific procedure for repair will be prepared. Run new completion: 27. MU Baker SAB permanent packer with lower seal bore and mill out extension and tailpipe equipped w~th X nipple and wireline entry gu~de/ball shear out sub on 3-1/2" tubing. 28. RIH and set at about 11750'. With packer set, pressure up on 9-5/8" and 7" annuh to 2500 psi to test packer and annuli. 29. Shear out of packer and POOH. It is possible that rig will lay down drill pipe. 30. Pull wear bushing. 31. RU tubing crew. MU Baker seal un~t, and 3-1/2" tubing string with GLMs. See attached completion detail. Note: Do not pick up SCSSV unbl annulus has been pressure tested and space out requirements have been determmed. 32. Stab into packer with seal unit and land Iocator. Determine space out requirements. Plan to land tubing w~th Iocator about 1 - 2' above packer. 33. Drop ball in tubing. Allow ball to fall. Pressure up on tubing to 3000 psi. Hold pressure for 15 minutes. 34. Close annular. Holding tubing pressure, pressure up on annulus to 2000 psi. Hold pressure for 10 minutes. Release pressures and open annular. 33. POOH with about 10 joints of tubing and MU SCSSSV. Test control line to 5000 psi. Maintain control line pressure while running in hole. 34. Space out. Install tubing hanger. Cut control line and MU to hanger. Test control line to 5000 psi. 10-403 4 KG05PRO3.doc 5/24/96 6:55 AM Note. Tubing hanger ~s for 4-1/2" tubing so an XO and I joint of 4-1/2" tubing should be run at the hanger. 35. MU landing jo,nt and land tubing hanger. Run ~n lock down screws. Make sure tubing ~s open when engaging seals to avoid blowing ball out of shear sub. 36. RU Dowell to tubing and annulus. Pressure test lines to 4000 ps~. 37. Open 9-5~8" annulus valve and pressure up on tubing to 3000 ps~ and test 10 m~n. 38. Pressure up on annulus to 2500 psi to test packer, and seals for 30 m~nutes. 39. Release all pressure on annulus. Pressure up on tubing to 3000 ps~. Release pressure and note volume returned. 40. Pressure up on tubing to 3000 ps~ and close SCSSV. Bleed off pressure above SCSSV. Note marked decrease in return volume venfying SCSSV is closed and holding. 41. Pressure up to 3000 ps~ above SCSSV to equalize. Open SCSSV. Pressure up on annulus to 2000 ps~. Pressure up to 3500 psi on tubing to shear out ball. 42. Retdeve landing joint. Install BPV. 43. Remove BOP. 44. install tree. 45. Pull BPV and ~nstall tree test plug. 46. Test tree to 5000 ps~. 47. RU slickl~ne and run 2.80 gauge to EOT. RD slickhne 48. Turn well over to production. Gas I,ft on production and test well. 10-403 5 KG05PRO3.doc 5/24/96 6:55 AM STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown' Stimulate. Plugging Perforate Pull tubing' Alter casing. Repair well. Other X 2. Name of Operator 5 Type of Well. 6 Datum elevabon (DF or KB) UNOCAL Corporation Development: X 10(7 KB feet 3. Address Exploratory 7 Unit or Property name P.O. Box 19-0247 Stratigraph~c' Anchorage, AK 99519 Service. Trading Bay Un~ 4. Location of well at surface 8 Well number 615' N & 119W from SE Comer, Sec. 17, T9N, R13W, SM K-5 At top of productive interval A ! 9 Permit number/approval number 61ZN&5033'Wfr°mSEC°mer'Sec'22'T9N'R'3W'SMORIGINAL At effective depth ~ 0 APl number 286' N & 4894' W from SE Comer, Sec. 22, T9N, R13W, SM 50- 733-20092-00 At total depth 11 F~eld/Pool 11' N & 4788' W from SE Comer, Sec. 22, T9N, R13W, SM Hemlock 12. Present well condition summery Total depth: measured 13,370 feet Plugs (measured) true vertical 9,864 feet Effective depth, measured 12,990 feet Junk (measured) 12,827 feet. true vertical 9,623 feet Casing Length Stze Cemented Measured depth True vertical depth Structural Conductor Surface 2,476' 13-3/8" yes 2,476' 2,273' Intermediate Production 10,434 9-5/8" yes 10,434' 7,898' Liner 3,059 7" yes 13,368' , 9,863' Perforation depth: measured 12,520'-564'; 12,588'-878', 12,902-979' true vertical 9,313'-9,342', 9,358'-9,550', 9,566'-9,617' Tubing (size, grade, and measured depth) 4-1/Z', 12.6~, N-80, BTC A-B mod. {~ 10,277' MD, 3-1/Z', 9.2/t, N-80, BTC A-B mod. {~ 12,472'RECEIVED Packers and SSSV (type and measured depth) Baker'FB-l' packer ~ 12,413' MD, Camco TRDP-1A SSSV {~ 281' MD 13. Stimulation or cement squeeze summary ~A~ Intervals treated (measured) Alaska 0il & Gas Cons. C~mmission Ar.~.horage Treatment description including volumes used and final pressure 14 Representative Daily Average Production or Inlecbon Data O~I-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation 301 200 3707 1150 (gas hft) 110 Subsequent to operation 0 0 0 480 90 15. Attachments: 16 Status of well classification as. Copies of Logs and Surveys run Daily Report of Well Operations: X O~1: X Gas Suspended. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Slgned:!~,,, ~ ~ Title' Drilling Manager Date. Form 10-404 Rev 06/15/88 I SUBMIT IN DUPLICATE KING SALMON WELL K-5 OPERATIONS SUMMARY MARCH 13 - MARCH 18, 1996 On the March 13, 1996 at 2300 hours the operating personnel on King Salmon Platform felt a ~olt'~ Soon afterward increased flare activity was noted and there was an upset in the gas lift system. Investigation revealed that well K-5 was heading strongly. The well was shut in and the tubing and tubing annulus pressures climbed to and stabilized at 2900 psi. Prior to this event, K-5 was certified as not capable of unassisted flow and was produced via gas lift. Normal flowing tubing pressure was about 110 psi and normal annulus pressure due to gas lift was about 1300 psi. This summary details the pumping operations performed between March 14 and March 18, 1996. Blair Wondzell of the Commission was contacted at about 0930, 3/15/96 by Hal Martin and Tom Maunder and appraised of the then current well condition and the intended pumping operation. Further contact was made the mornings of 3/18/96 and 3/19/96 with updates. 3/14/96 Ddlling personnel arrived on platform @ 1225. follows: 4-1/2" tubing: 2920 psi 9-5/8" casing: 2860 psi 13-3/8" casing: 435 psi 24" casing: 245 psi K-5 wellhead pressures as RECEI¥ MAR 2 8 1995 Alaska 0il & Sas C~ns Commission Ordered pumping equipment and necessary salt for brine. Bled casing to 300 psi. Bled small volume of gas. No hydrocarbon odor. Shut in with pressure remaining stable at 300 psi. Equipment and material arrived late evening. 3/15/96 Mixed 3% KCI/FIW fluid. Rig up Dowell to 9-5/8"casing and 4-1/2"tubing. Hold safety meeting and pressure test lines to 4500 psi. Begin lubricating 8.6 ppg fluid into 9-5/8"casing according to schedule. Annulus pressure did not decline per schedule. Crossflow to tubing via gas lift valves believed to be problem. Continue pumping and attempt to bleed off tubing pressure. Casing and tubing pressures continued to build to initial levels. Secure equipment and shut down for night. 3/16/96 Mix 52 bbls 9.2 ppg Calcium Carbonate pill. Pump pill down 4-1/2"tubing, followed by 120 bbls 8.6 ppg KCI/FIW fluid. Switch to annulus, lubricated 54 bbls of same pill into well. Follow with 8.6 ppg KCI/FIW fluid in 50 bbls stages. Casing pressure declining per schedule. Pressures at 2400 hours Casing: 2540 psi Tubing: 2675 psi. King Salmon K-5 Page I of 2 3/17/96 3/18/96 Continue lubricating fluid into well in 50 bbl stages. Final pressures at 2245 hours: Casing: 475 psi Tubing: 1975 psi. Shut down and monitor pressures. Pressures at 0700 hours: Casing: 500 psi Tubing: 1725 psi. Resume pumping operations. Pumped into 9-5/8" casing maintaining 600 psi on annulus and taking returns to production. Had water returns with 99 bbls pumped. Shut well in with 650 psi on casing and 350 psi on tubing. Pressures slowly declining. Secure operation and rig down Dowell. 3/19/96 Well pressures at 0700 hours: Casing: 480 psi Tubing: 90 psi. The intended plans for the well are to resume fishing for the slickline presently lost in the hole, replace the gas lift wells with dummies and prepare the well for workover The tubing and annulus pressures will be monitored daily. King Salmon K-5 Page 2 of 2 Unocal Corporation ( P O Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOCAL ) G. Russell Schmidt Drdhng Manager Thursday, March 21, 1996 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell: KING SALMON WELL K-5 Attached, please find form 10-404 detailing the recent pumping operations on the subject well. If you have any questions, please contact the undersigned at 263-7676 or Dan Williamson at 263-7677. G. Russell Schmidt Drilling Manager GRS/leg RECEIVED M/~R 2 8 199~ Alaska 0il & Gas Cons. Commission Anchorage (' STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION ¢ ~ ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Class,hcatlon of Service Well OIL r-~ GAS ,r--) SUSPENDED [] ABANDONED ~ SERVICE [] 2 Name of Operator ' 7 Permit Number UNOCAL (ARCO Alaska, Inc. is sub-operator) 68-18 3 Address 8 APl Number P. 0. Box 190247, Anchorage, AK 99519 50- 133-20092 4 Locat,on of well at surface King Salmon Platform Leg #2, Cond. #16 9 Un,tor LeaseName 615' FSL, 119' FEL, Sec.17, TgN, R13W, SM Trading Bay Unit ... At Top Producing Interval 10 Well Number N/A K-5 At Total Depth 11 F,eld and Pool 44' FSL, 261' FWL, 5ec.22, TgN, R13W, SM McArthur River 5 Elevation ~n feet (indicate KB, DF, etc ) I 6 Lease Des,gnatlon and Serial No Hemlock RKB 100' HLW I ADL 18772 12 Date Spudded 13 Date T D Reached 14 Date Comp, Susp or Aband ! 15 Water Depth, if offshore 116 No of Completions 03/24/68 05/15/68 05/22/68* I -- feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+l'VD)19 DirectlonalSurveyI20 Depth where SSSV set 121 Thlckness of Permafrost 13370'MD~ 9817'TVD 12990'MD~ 9635'TVD YES [] NO [] I 274 feet MD I N/A 22 Type Electric or Other Logs Run DIL. BHCS. FDC/GR/Cal, HDT Dipmeter, CBL, FDC/CNL/GR, Gyro 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 24" .... Surf ~15' -- Driven !3-~/m' 6!.0# )-~ Surf ?~,TA, 1R,, !6')5 sx C!ess C 7" ?q A~ N-RI3 liT~i3q' I~'~RR' R-l/?' ROIl3 ~x ('-IR.~.~ ~, . 24 Perforations open to Production {MD+TVD of Top and Bottom and 2,5 TUBING RECORD interval, s.ze and number) SIZE DEPTH SET [MD) PACKER SET {MD) Perforated w/1 2 spf 4-1/2"/3-1/2" 12473 ' 1241~ ' 12520'-12564'MD 9324'-9354'TVD 12588'-12878'MD 9370'-9562'TVD 2{; ACID, FRACTURE, CEMENT SaUEEZE, ETC 12902'-12979'MD 9577'-cj627'TVD DEPTH INTERVAL {MD) AMOUNT& KINDOF MATERIAL USED 12992'-13150'MD 9636'-9673'TVD Perfs f/12520'-131!~2' 50 sx cmt Perforated w/4 spf . 13212'-13300'MD 9714 '-9771'TVD 27 N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc ) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD e Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl {corr) Press. 24-HOUR RATE I~ 28 CORE DATA ........ Brief description of hthology, porosity, fractures, apparent dips and presence of oil, gas or waterNone Submit core chips.~t~' }''~,-~ ~C~"~ ..~,, !~ ,~,,~j ~,.~ D ,;ss!;,~ .Oil, & GBs Gores. ,,", '" ~Note; Workover performed~ squeezed perforations & reperforated 8/29/70. Workover performed & ....... perforations added 2/18/81. Workover performed 10/4/84. Form 10-407 WCS/16: DAN I Submit in duphcate Rev 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME .......................................... Include interval te~ted, pre~$ure data, all fluids recovered and gravity. .... MEAS, DEPTH TRUE VERT. DEPTH GOR, and .me of each phase. N/A N/A 31 LIST OF ATTACHMENTs Well History 32 I hereby certify that the forl~go~.g ,s true ~tld correct to the best of my knowledge iNSTRUCTIONS General' This form is designed for submitting a complete and correct well .c0~pi~fior~ report an~d'l'og'on ail 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 ts 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 sh;3uld show the details of any multiple stage cement'~' lng and the location of the cementittg tool, I~ Pl~=ll~l led II. relict Itl ,'11#1~ ~ IIi~.1~1~/!1~. Wednlldly .~ef a well is spudded or wooer o~mtionl ~ ~ ~r ~ e~41~ ~ ~~ ~ ~ ~ gland Inclu~ dat~ only. ~as~ ~'~' I North Slope Borough ~ld or Unit Tradin~ Bay Unit ~L #18772 Au~. o~ W.O. ,o ~E 496219 Recoapletion ( Well History- Initial Report - Dally lState Alaska all no K-5 W/0 Parker #58 O~retor ARCO Alaska, Inc. ARCO W I Prior status ,f a W 0 ,pudded o. W O be°u. [O,. IHour Workover 9/22/84 0600 Hrs. Date and depth aa of 800 am. 9/20/84 th~u 9/21/84 9~22~84 thru 9/24/84 Complete record for eech day reported 7" lnr @ 10,309'-13,368' Mobilize rig. 7" lnr @ 10,309'-13,368' 12,990' PBTB, Prep to retrv locking mandrel ~.8 Brine Accept rig @ 0600 hfs, 9/22/84. SI well, bleed off ann gas lift press to 0 psi. Fill ann w/70 bbls 8.8 ppg brine, followed w/±620 bbls 8.5 ppg FIW. NU WL BOPE/lub, tst to 3500 psi. Open well, RIH w/2" perf gun assy, unable to get past 258' WLM, POOH, LD perf gun assy. RIH w/I-ii/16" sinker bars w/CCL, att to rn thru 2-7/8" stinger & locking mandrel w/o success, POOH, RD DA. RIH w/2" impression block & GS tls to 232' WLM, POOH; indicates damaged/collapsed 2-7/8" OD stinger or locking mandrel. Rn 1.725" impression block w/same indications. RIH w/4-1/2" GS pulling tl assy to 232', POOH, rec'd 2-7/8" stinger. Modify 2-7/8" OD stinger w/locking mandrel, RIH, tag up @ 232' WLM, rn 2-7/8" stinger thru QLP flapper vlv, set locking mandrel, POOH. RIH w/2.175" OD sinker bar tl assy, tag up @ 255' btm of stinger, att several times to rn thru end of 2-7/8" stinker w/o success, POOH. RIB w/2.375" taper swage tl assy, tag up @ 255', unable to rn thru end of stinger, POOB. Dress taper swage, RIB w/2.375" OD taper swage tl assy, tag up @ 255', att to swage gage btm of stinger w/o success, POOH. RIB w/2.350" OD reg swage ti assy, tag up @ 255', att to swage gage btm of 2-7/8" stinger, POOH. RIH w/2.375" OD blunt swage tl assy, tag up @ 255', att to rn thru btm of stinger w/o success. RIH w/2.150" OD sinker bar tl bssy to 232' top of locking mandrel, rn thru 2-7/8" stinger btm @ 255' WLM, POOH. RIH w/2" perf guns, tag up @ 258', att to rn thru tbm of 2-7/8" stinger w/o success, POOB, LD perf guns. RIH w/I-I/16" sinker bar tl assy, rn thru locking mandrel & 2-7/8" stinger to 267', att to rn all tls thru stinger w/o success. Prep to RIH w/GS pulling tl &retrv locking mandrel & 2-7/8" stinger. For form preparation and distribution, see Procedures Manual, Section 10, Orllhng Peges 86 8nd 87 IDate I Title 10/12/84 Drilling Superintendent *A,RC~O Oil and Gas Company,,," Daily Well History--Interim Instructions Th~s form ~s used dunng drHhng or workover operations if testing, coring, or perforating, show formahon name ~n descmbsng work performed Number all drdl stem tests sequenttally Attach descmphon of all cores Work performed by Producing Section wdl be reported on "Interim" sheets untd hnal complehon Report ofhc~al or representahve test on "Final" form 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week ~n which od string ~s set Submit weekly for workovers and following setting of oH string unhl completson District F~eld Alaska ICounty or Pamsh IState North Slope Borough Alaska Lease or Umt IWell no ADL #18772 I K-5 W/O Trading Bay Unit Date and depth as of 800 am 9/25/84 9/26/84 9/27/84 9/28/84 9/29/84 thru 10101184 10/02/84 10/03/84 Complete record for each day whde drdhng or workover ~n progress I ,,a. ~ GLM's: The above is correct Signature ,,~._ q~~ -- For form preparation and distribution see Procedures Manual Secbon 10, Drdhng, Pages 86 and 87 7" lnr @ 10,309'-13,368' 12,990' PBTD, Tst BOPE 8.8 Brine Rn 2-7/8" OD stinger thru flapper vlv, set dn locking mandrel, POOH. Kill well by bullhead'g 116 bbls, 8.8 ppg br dn tbg; observe well f/flow. ND tree, NU BOPE. 7" lnr @ 10,309'-13,368' 12,990' PBTD, POOH w/compl string 8.8 Brine NU BOPE & tst to 250/3000 psi. welI, observe well f/flow; OK. Pull BPV. Unseat tbg hgr, circ Pull 4½" x 3½" compl string. Chg rams to 5" 7" lnr @ 10,309'-13,368' 12,990' PBTD, RIH w/DP 8.8 ppg Brine RIH w/pkr mill assy on 5" x 3½" DP. TOL @ 10,309' 12,990' PBTD, CO rn 8.8 ppg Brine Cont RIH, PU DP, circ @ TOL, tag pkr @ 12,433' DPM, mill, POOH, rec'd jnk. RIH w/mill'g assy, latch onto pkr, POOH, rec'd pkr. TIH w/fsh'g tls, tag fsh @ 12,821' & wsh over to 12,990' PBTD, POOH w/perf gun. PU 9-5/8" scrprs/JB, TIH, CO to TOL, CBU, POOH. RIH w/7" scrps, pmp hi-vis pill, short trip to TOL. TOL @ 10,309' ~ 12,990' PBTD, Rn'g comp l tbg i ~( l~'~~ 8.8 ppg Brine . ~ .. ~ Pmp hi vis pill, POOH. RU DA, rn GR/CCL/JB to 12,650'. RIH w/FB-1 pkr & tail assy, set pkr @ 12,400', POOH. Chg rams Fo , " 4½" & tst; OK. RU & RIH with 3½"/4½" compl string. TOL @ 10,309' , 12,990' PBTD, Rn'g std'g vlv '~ ~T~G~10¥g~B 8.8 ppg Brine Fin rn'g total 329 jts, 4½", 12.6# N-80 AB-Mod tbg & 68 jts, 3½", 9.2#, N-80 AB-Mod tbg w/SSSV @ 281', FB-1 pkr @ 12,413', "D" Nipple @ 12,458', tbg tail @ 12,472'. ND BOPE, NU & tst tree to 3000 psi. RIH to set std'g vlv. 1999', 4102', 5799', 7008', 8022', 8811', 9447', 9928', 10,228', 10,276', 10,528', 10,796', 11,149' 10/12/84 Drilling Superintendent 7" lnr @ 10,309'-13,368' 12,990' PBTD, PU mill assy 8.8 ppg Brine Fin pulling 4½" x 3½" compl string & LD. ,RCO Oil and Gas Company Daily Well History-Final Report Instinct,ohs Prepare and submit the "Final Repo~t" on the hrst Wednesday after allowable has been assigned or well ~s Plugged, Abandoned or Sold "Final Repo~t" should be submitted also when operations are suspended for an indehmte or appreciable length of hrne On workovers when an official test ~S not requIred upon completion, report completion and representative test data ~n blocks prowded The "F~nal Repe~t" form may be used for reporting the enhre operahon if space ,s avadable D~stmct ICounty or Pansh I Alaska F~eld ~Lease or Umt I Trading Bay Unit Auth or W O no ~T~tle I AFE 496219 North Slope Borough ADL #18772 [ Accounbng State cost center code Alaska Well no K-5 W/O Recompletion Operator ARCO Alaska, Inc. Spudded or W O begun Workover ARCo WI Date 9/22/84 I otal number of wells (achve or machve) on thts DSt center pmor to plugging and bandonment of thru well I our I Prior status ~f a W O I 0600 Hrs. Date and depth as of 8 00 a m Old TD 10/04/84 10/05/84 Complete record for each day reported TOL@ 10,309' 12,990' PBTD, Flow tst 8.8 ppg Brine - RIH~ set std'g vlv in "D" nipple @ 12,458' & tst, POOH. Tst SSSV vlv, pull std'g vlv. Gas lifting & flow/rate tst well. 7" lnr @ 10,368' 12,990' PBTD, RR 8.8 ppg Brine RR @ 0800 hfs, 10/4/84. Released ng 0800 Hrs. Classifications (od, gas, etc ) Oil Producing method Flowing Potential test data INew TD I PB Depth Date IKind of r,g 10/04/84 I Type completion (s~ngle, dual, etc ) Single I Official reservoir name(s) I MacArthur River - Hemlock 12,990' Rotary Signature ' J Date T~tle ~- 10/12/84 Drillins Superintendent For form preparation and d~strlbutlon, see Procedures Manual, Section 10, Drllhng, Pages 86 and 87 Well no Date Reservoir Producing Interval iOil or gasTest hme Produchon Od on test Gas per day Pump s~ze, SPM X length Choke s~ze T P C P Water % GOR Grawty Allowable Effective date corrected Unocal North Ame~'~ Od & Gas Oiws;an ~ IJnoc31 C~rcor~t~<3n P O ~ox ;90247 Anc~ora~_ e. AlasKa 99519-02.t7 Te~e0none tg0~ 276-T600 Ala.~a Re<j~on April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, Gar~. S. [_Bush Regional Drilling Manager GSB/lew APR /<lNG SALMON PLATFORM FROM SE CORNER SEC. 17, TgN, R13W CONDUCTOR "Y" COOR. "X" COOR. WELL #' LEG //1: 1 2,511,762 213,819 K-21 & RD 2 2,511,761 213,815 K-30 3 2,511,764 213,811 K-18 4 2,511,768 213,810 K-17 5 2,511,772 213,812 K-23 (23-19) 6 2,511,773 213,817 K-19 7 2,511,770 213,821 K-22 & RD 8 2,511,766 213,822 K-20 LEG #2: 2,511,690 213,768 9 2,511,686 213,772 K-15 & RD l0 2,511,684 213,768 K-9 ll 2,511,687 213,763 K-4 & RD 12 2,51 l, 691 21 3,762 K-11 13 2,511,695 213,765 K-13 & RD 14 2,511,696 213,769 K-2 & RD 15 2,511,694 213,776 K-7 & RD 16 2,511,689 213,774 K-5 LEG //3: 17 2,511,723 213,712 18 2,511,721 213,708 19 2,511,724 213,703 20 2,511,728 213,702 21 2,511,732 213,705 22 2,511,733 213,709 23 2,511,731 213,713 24 2,511,726 213,714 Leg #4' 25 2,511,799 213,760 26 2,511,798 213,756 27 2,511,801 213,752 28 2,511,805 213,751 29 2,511,809 213,753 30 2,511,810 213,758 31 2,511,807 213,762 32 2,511,803 213,763 K-8 K-1 & RD K-lO & RD K-16 K-12 & RD K-6 & 24 K-3 & RD FNL 688 687 690 694 698 699 696 692 611 610 613 617 621 622 619 615 725 724 727 731 735 736 729 FWL 74 78 82 83 81 76 72 71 121 126 130 131 128 124 120 ll9 133 135 141 142 140 135 130 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend CI Operation Shutdown [] Re-enter suspended well I-1 Alter casing [] Time extension [] Change appr~:wed program n Plugging I-i Stimulate F-I Pull tubmng [] Amend order [] Perforate ~ Other 2. Name of Operator UNOCAL Corporation (ARCO Alaska, Inc. is sub-operator) "'3. Address Post Office Box 190247 Anchora~le, AK 99519 4. Location of well at surface Leg 2, cond. 16, King Salmon Platform 5. Datum elevation (DF or KB) 100' KB 6. Unit or Property name Tradin9 Bay Unit 7. Well number feet 615'N & 119'W fr. SE corner, Sec. 17, T9N, R13W, SM At top of productive interval 612'N & 5033'W fr. SE corner, Sec. 22, TgN, R13W, SM At effecbve depth 286'N & 4894'W fr. SE corner, Sec. 22, TgN, R13W, SM At total depth 11'N & 4788'W fr. SE corner, Sec. 22, TgN, R13W, SM K-5 8. Permit number 68-18 9. APl number 50-- 733-20092-00 10. POOl Hemlock 11. Present well cond~hon summary Total depth: measured true vertical 13,370 feet Plugs (measured) 9,864 feet Effective depth: measured true vertical Casing ~~X Intermediate Production L~ner Perforation depth: Measured: 12,990 feet Junk (measured) 12,827 9,623 feet Length Size Cemented Measured depth True Vertical_depth 2,476' 13-3/8" yes 2,476' 2,273' 10,434' 9-5/8" yes 10,434' 7,898' 3,059' 7" yes 13,368' 9,863' 12,520-564'; 12,588-878'; True Vertical: 12,902-979'. 9,313-9,342'; 9,358-9,550'; 9,566-9,617'. Tubing (size, grade and measured depth) 4-1/2", 12.6#, N-80, BTC A-B mod. @ 10,277' MD; 3-1/2", 9.2#, N-80, BTC ABM @ 12,472' Packers and SSSV (type and measured depth) Baker 'FB-I' packer @ 12,413' MD, Camco TRPD-1A SSSV ~ 281' MD 12.Attachments Descriphon summary of proposal [] Detailed operahons program [] BOP sketch 13. Estimated date for commencing operation November, 1988 14. If proposal was verbally approved ~'i ~, ' [' .~,., Name of approver ~ ~. ~; ? ~':~ F~' .... ~r- ,;:]:'~ ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledg~~''I'~'''~ ,~;'~ ORIGINAL SIGNED BY LONNIE C. SMITH Approved by Form 10-403 Rev 12.1-85 ~ Roy]~). Eo~er~s Signed d~=~.'.~~..~/~ ~ Title Environmenta I En,qineer ~ .... ~_. ,_.. ~... / Commission Use Only Condi'i~o~f~[Irp~ Notify commission so representative may witness Date ~-~,~ ]~',~o~ ..... ~ Plug integrity [] BOP Test I-] Location clearance Approved Copy Returned Date 10/5/88 Commissioner JApproval No. 0c::::'-]77~ by order of the commission Date Submit in tri WELL TBU K-5 CEMENT SQUEEZE KING SALMON PLATFORM Procedure 1. Circulate-out fill to 12990' MD. 2. RIH with coiled tubing and fluid pack the wellbore with filtered seawater. 3. Pump 30 bbls of cement followed by 2 bbls of water and one coiled tubing volume of contaminant. Hold 1500 psig differential squeeze pressure for 60 minutes. 4. Jet or reverse out contaminated cement. RDMO CTU. 5. Re-perforate the following intervals with well flowing: Run No. Bench Interval (MD-CBL) Interval (MD-DIL) Length SPF 1 2 12588-12720 12588-12720 132' 4 2 3 12720-12806 12720-12806 86' 4 3 4 12806-12878 12806-12878 72' 4 4 4 12902-12979 12902-12979 77' 4 NOTE: Lubricator will be pressure tested to 2500 psig prior to each gun run. 6. RDMO E-line unit and lubricator. 7. Test well. , ( o E-L~ne BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead DML 7/22/88 'SEP..1. 3 ' 8,63:1. 3: .-,..,. ''~''~ 'STRTE( ~' RLRS~<A f',OT H,3hlE RI<. f BOWEN UNITIZED BLOWOUT PREVENTER STACK The Bowen unitized blow~u~ preventer sta~k for H~S service is eT-~Ipped wi~h ~n Otis quiok union box on top and a 2 1/2-inch Series 1500 flange on bottom. It consis%s of the following items: a. A 2 i/2-inch O.D. Bowen ~win hydraulic actuated blowout preven%er, rated at 5,000 psi workLug pressure. It is fitted with an upper blind ram assembly and a lower shear ram assembly (No. 60875) to cut 1-inch O.D. tubing. b. A 2 !/2-inch O.D, Bowen twin hydraulic actuated biowcut preventer, fa%ed a~ 5,000 psi working pressure. It is £i~ed with an upper s!iptype r~: assembly for 1-inch C,D. tubing and a lower heavy duty pipe ram asses. bly to close on *--inch O.D. tubing. P. Traininl[ The s%ack is complete with a 2-inch 1500 flange side outie~ between ~he and third ram furnished wi~h a ~-_~,.,, Series 1500 X 2-inch L.P. coup. anion flu. ge. BO~,'EN PkRT NU~,,~:P. 71483 - NC~i~ SIZE DET~ PART ~ ....... 1 Bled 2 Cutter Ra~ 3 Slip 4 Pipe 5 2-inch 1500 Series Fl~nge 6 Otis .~ck U2ion 2 3 4 December, Lq?6 BLOWOUT PREVENTER ASSEMBLY Traininl~- C) BLIND CUTTER IIAM_/ SLIP RAIl HNCli O.D. FIFE RAM ALAS .1~' OILANDGAS CONSERVATION aMMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1 Drilling well [] Workover operat~onX~ 2 Name of operator (ARCO Alaska, Inc. as sub-operator) 7 Perm~tNo Union 0il Company of California 68-18 3 Address 8 APl Number 909 W. 9th Avenue, Anchorage, AK 99501 50- 133-20092 4 Location of Well atsurface King Salmon Platform Leg #2 Conductor #16 5 Elevation ~n feet (.ndlcate KB, DF, etc ) I 6 Lease Designation and Serial No RKB 100' MLWI ADL 18772 9 Umt or Lease Name Trading Bay Unit 10 Well No K-5 W/O 11 F~eld and Pool McArthur River Hemlock For the Month of 0ctober ,19 84 12 Depth at end of month, footage drdled, hsh~ng jobs, directional drilling problems, spud date, remarks Accepted rig @ 0600 hrs, 9/22/84. Kill well. Pull 4-1/2" x 3-1/2" completion string. Mill pkr. Retrieve pkr. Recover fish (perf guns). Clean out well to 12,990'PBTD. Complete well w/FB-1 pkr @ 12,413' 4-1/2" , x 3-1/2" tbg (with GLMs) and SSSV ~ 281'. Flow test well. Released rig @ 0800 hrs, 10/4/84. 13 Casing or I~ner run and quantities of cement, results of pressure tests N/A 14 Coring resume and brief description N/A 15 Logs run and depth where run N/A RECEIVED 16 DST data, perforating data, shows of H2S, miscellaneous data N/A Alaska Oil & Gas Cons commission Anchors~oe 17 I hereby certify that the foregoing ~s true and correct to the best of my knowledge SIGNED ~ ~ TITLE ENVIRONMENTAL TECHNICIAN DATE 11/28/84 NOTE--Report on th~s form ~s required for each calendar month, regardless of the status of operations, and must be hied in duphcate w~th the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwme d~rected Form 10-404 H I LL/MR37 Submit in duplicate Rev 7-1-80 STATE OF ALASKA ALAS ^ OIL AND GAS CONSERVATION L, OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] COMPLETED WE LLxI~ OTHER [] 2 Name of Operator Union 0il Company of California 3 Address 909 W. 9th Avenue, Anchorage, AK 4 Location of Well King Salmon Platform Leg #2, Conductor #16 5 Elevatmon in feet (rand,cate KB, DF, etc) RKB 100' MLW 99501 7 Permit No 68-18 8 APl Number 50-- 133-20092 9 Umt or Lease Name Troding Bay Uni 10 Well Number K-5 11 F,eld and Pool McArthur Ri ver Hemlock [] [] [] I 6 Lease Designation and Sermal No ADL 18772 12 Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO. (~mlt in Trlphcate) Perforate Alter Casing [] Perforations Stimulate ,[],, Abandon [] Stimulation Repair Well ~ Change Plans [] Repairs Made Pull Tubmg [] Other [] Pulhng Tubing (Note Report muluple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) SUBSEQUENT REPORT OF. (Submit m Dupl,cate) [] Altering Casmng [] Abandonment [] Other 13 Descr,be Proposed or Completed Operations (Clearly state all pert)nent details and give pertmnent dates, ~ncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska, Inc., as sub-operator, proposes to repair K-5 as follows: 1. Rig up over Leg #2, conductor #16. 2. Perforate tubing and kill well. 3. Pull completion assy. Mill pkr. 4. Clean out well to PBTD. 5. Complete well with 4-1/2" x 3-1/2" completion assy. 6. Reperforate select Hemlock intervals @ 4 spf under drawdown conditions. A 5000 psi 13-5/8" SRRA BOP stack will be used during the workover. The BOPE will be tested weekly and operationally~ested each trip. A 3000 psi WP wireline lubricator will be used and tested on all wireline work. A new sub-surface safety valve will be installed and tested upon conclusion of the J~E C E iV E D Estimated Start: September 19, 1984 14 ' he&by~ertlfy that the~g~ true a[~ correct to the best of my knowledge S,gned .-c.fl.e Di st. Drl g. Supt. The~iEe below for Commission use Co~t~ons of Approval, ~f any SEP 1 7 191)4 Alaska 0il & Gas Cons. Commission Anchorage Date 9/14/84 tlIIIIIliAL llll[I Approved CoD, _..~eturned ~_? ,, ,2o ; ~ q, Approved by It tINKlE g. SIIITII By Order of COMMISSIONER the Commission Date ~)-' F~ Form 10~t03 Rev 7-1-80 GRU1/SN45 Submit "Intentions" ~n Trmpllcate and "Subsequent Reports" in Duplicate September 13, 1982 Union 0il COml~nY of California PoOo Box 6247 Anchoragej Alaska 99502 Res l~Io-Flov Tests o_n(~-5~and !(-13 on the 1(£n9 Salmon Plat;for~ We have reviewed the test data frc~ the no-flow test on Tradin9 Bay Unit Well 1-5 (14-22), Wing Sal~on platform and Trading Bay Unit ~-13 (33-15) Redrill, King Salmon pl&tform which was witnessed by Petroleum Inspector Edgar W. Sipple, Jr. Well 1~-5 has demonstrated by test that it is not capable of unassisted flow an.d t~refore removal of the subsurface safety val~ fr~ this well is approved. Well I(-13 had a s~all unassisted flow and consequently is no__[ approved as no-£1owo ccl ARCO STATE OF ALASKA ALASKa- IL AND GAS CONSERVATION (::ir VIMISSION SUNDRY'u, OTiCES AND REPORT ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Union Oil Company of California * 3 Address 909 West 9th Avenue, Anchoraqe, Alaska 4. Location of Well King Salmon Platform Leg #2, Conductor #16 615'N and l19'W from SE Corner Sec 17, T9N, R13W, SM MAR - 1981 Alaska Oil & Gas Cons Comr~ Anch0rag~ 5. Elevat,on in feet (indicate KB, DF, etc.) RKB 100' MLW Lease Designation and Serial No. ADT,-18772 7. Perm,t No. 68,18 8 APl Number so- 133-20092 9. Unit or Lease Name Trading Bay Unit 10. Well Number K-5 (14-22) !i~io~,eld and Pool McArthur River - Hemlock 12. Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF: (Submit in Trlphcate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing r-I Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [~ Other I-'l Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion ) 13. Descr,be Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) On 2/6/81, finished rigging up over Leg #2, Conductor #16. Filled 9-5/8" x 4-1/2" annulus w/filtered inlet water. Rigged up lubricator and tested to 2000 psi. Ran perf gun. Shot 4 SPF in 4-1/2" tubing @ 10,011-10,012'. Pumped 700 bbls of Drill-S workover fluid. Filled tubing. NU and tested BOPE - ok. Circulated well thru production system for 50 bbl and pulled packer loose w/25,000#. Laid down 320 joints 4-1/2" tubing. Recovered complete string w/fish inside tubing. RIH w/DP and bit. Tagged fill @ 12,779'. Reversed well 1 circulation and spotted 20 bbl Drill-S pill across open perfs. Washed fill 12,779~.12,915'. POH. RIH w/wash pipe. Tagged fill @ 12,910'. Washed fill and swallowed fish. Continued washing to 13,005'. POH. Tight spot from + 12,000' to top of 7" liner (10,309'). RIH w/overshot. Tagged fish @ 12,9~0'. POH and recovered all of fish. RIH w/bit, casing scraper and boot basket. Washed fill from 12,990'- 12,994'. Circulated bottoms up and spotted 30 bbl Drill-S pill on bottom. ~ ~.~ ,~(Soo attached) * ARCO Alaska, Inc. is sub-operator. 14 I he,rely '~rtify that the f.~,Wl'~ true and correct to the best of my knowledge 7the spa, c~below for Commission use {,__C,.ond~'~tlons of Approval, if any Date 3/1/81 By Order of Approved by COMMISSIONER the Comm,ss~on Date Form 10-403 Rev 7-1-80 Submit "Intentions" m Triplicate and "Subsequent Reports" in Duplicate Sundry Notices and Reports on Wells 13. Describe Proposed or Completed Operations (continued) Ran FDC/CNL/GR from PBD 12,974' to 6500'. Ran Gyro-Survey. Set Baker F-1 pkr @ 12,415'. Tested pkr - ok. LD 10 jts of DP and changed well to filtered inlet water. LD rest of DP. Changed to 4-1/2" rams. Ran 72 jts 3-1/2" 9.2# N-80 BTC tubing. Installed crossover and ran 335 jts 4-1/2" 12.6~ N-80 BTC tubing. Tested tubing to 2000 psi - ok. Set BPV and NU BOPE. Tested tree to 5000 psi - ok. RU Dresser, tested lubricator - ok. Perf gun #1 stuck @ 12,.870', and. pulled out of rope socket. RIH w/gun #2. Perf'd 4 SPF @ 12,825-845~ 12,803~824% Released rig to Production Department @ 2400 hrs., 2/18/81. 11 hr. Flow Test: 2844 gross B/D 569 BOPD 80% water cut R£C IVED - 1981 Alaska Oil & Gas Cons. Con;mission Anchorage Form ! 0-403 REV. 1-10-73 Submit "1 ntentlons" in Triplicate & "Subse~luent Reports" in Duplicate STATE ~ ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) O,L ~ GAs ['-] WELL ~l~.,J WELL OTHER NAME OF OPERATOR Union Oil Company of California * ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL At surface King Salmon Platform Leg #2, Conductor ~16 615' N & 119' W f/SE Corner Sec 17, T9N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, et~) RKB 100' MLW 14. Check Appropriate Box To Indicate Nature of Notice, Re APl NUMERICAL CODE ~ ,I/- 50-133-20092 6. LEASE DESIGNATION AND SERIAL NO. ~,. ADL-18772 JF 7. IF INDIAN, ALLOTTEE OR TRIBE NAME ~ 8. UNIT, FARM OR LEASE NAME Trad~n~ Bay Unit ,~- 9. WELL NO. K-5 (14-22) '~ 10. FIELD AND POOL, OR WILDCAT McArthur River- Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 17-T9N-R13W, SM 12. PERMIT NO. 68-18 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompietion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including est,mated date of starting any proposed work. We propose to repair well K-5 as follows: 1. Rig up over Leg #2, Conductor #16, remove wellhead .equi~nt, and install and test BOPE. 2. Pull completion assembly, retrieving fish stuck in tubing. 3. Clean out wellbore to tubing fish @ 12,906' MD and retrieve fish. 4. Clean outwellbore to 12,900' MD. 5. Log. 6. Rerun completion assembly w/ fourteen gas lift valves and mandrels. 7. Remove BOPE, reinstall wellhead equipment and bring well onstream. 8. Perforate 300' of the Hemlock Zone w/ 4 SPF under drawdown conditions. RECEIVED DEC- ~ B80 * ARCO Oil~d ~s ~y is sub-operator. 16. ' here~y ~~::t:he~/~./t rue and correct~/' -- S lG N~~~/ /~, ~~~~~T LE Dist. Dr 1 E. (T~e for State off u~) / CONDITIONS OF~PPROVAL, IF ANY~ BY ORDER 0F THE C0r;,U~SS~0N ~ub:equent VFmk E~portcd ,,~n Fora-, ~o. _._~_~.~ Datcd~/5~C~[ ~e Instru~Jons On Revere Side Alaska 011 & Gas Cons. Commission Anchorage DATE 12/1/8o DATE.. Approved Copy Returned CODE 50-133-20092 R~lease Date _ 6,22-70 State of Alaska Department of Natural Resources DIVISION OF MINES A~D ~NERALS Petroleum Branch Sec .... (17) _22_ -;~-- ~: INDIVIDUAL WELL RECORD Operator Union 0il Co. of Calif. Location Lease No. ADL 18772 or Owner Trading Bay Unit Well No. K75_,.(14',22) ~ Area McArthu~ River .... Spud Date 3-24-68 Drilling ceased 5-15-68 Suspended. Abandoned T. 9N _-~;~ . -.z. .,, -- ., , , R. 13W S Meridian ¥ Permit No. _68-18 _ Issued 2-26-68 (Surface }_ 615' FSL .&. 11_9'. FEL_, Sec. 17 Loc. (Bottom) 660' FSL & 660' FWL, Sec. 22 Elevation Completed (F-;7/~,, 5-2~-&~ _ _ IP= 7~&_8 _ B/D, Gray 3!.3° __API .... 13,37o' 100 K~ Cut 0.8 % !8oo . _ Casing: Size Depth Sx Cmt 13 3/8" ' 615 2676~ 1225 · 9 5/8" - 47~ 10,4,34' 700 7" 10,309 ' ' 13,368' 800 on packer 3%" & 4%" __ 12,482'_~ .~ GEOLOGIC FORMATIONS Surface Ix)west Teste_d._ Bean 96 /64 CP ....... 9- psi, TP _ _2~_0 ~ Perf: Pl~ug,?: · ~1,,2~520'-64' ~12~588'-878'; ,, , ,, ~, _.. . · ~ 12,902'-79'; 12,992'-13,192'; 13,212''300' psi PRODUCTIVE HORIZONS Name Depth Hemlock 12,5 20 ' - 13,300 ' Contents Hemlock 0il · Year Jan Feb Mar Apr WELL STATUS May June July Aug 'Sept Oct Nov Dec Remarks: Contractor: . WODECO (t Umon Oil and Gas D/ )n: Western Region Umon O~1 Company br Cal~forma 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 union March 6, 1974 Mr. Homer Burrell State of Alaska Department of Natural Resources Oil ~ Gas Division 5001 Porcupine Drive Anchorage, Alaska 99S04 RE: TBUS K-S (14-22) Dear Mr. Burrell: Submitted herewith are our Sundry Notices covering the reperforating of the K-5 {14-22) well on the King Salmon Platform. Very truly yours, District Drilling Supt. sk Enclosures (2) cc: Arco Marathon Standard Skelly Phillips Amoco MAR ? ~74 DIY~N OF OIL AND GAS ANOIORAC, It Form P--3 ( RJgV 9-30-.6 9 Submit "Intentions" in Triplicate & 'Subsequent Reports" m Duphcate STATE O'F AL~KA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposal~ to dllll or to deepen Use APPLICATION FOR PEHMIr~-'' for such prof~osals ) I OIL ~ GAS ~ WrLL WELL OTHER 2 NAME OF OPERATOR * Union 0il Company of California 3 ADDRESS OF OPERATOR 909 W. 9th Avenue, Anchorage~ Alaska 4 LOCATION OF WELL At sut face 99: Ol 615'N & llp'W fr SE cr Sec 17, T9N, R13W, SM AP1 NUMFA~CAL CODE 50-133-20092 LEASE DESIGNATION AND SERIA~L NO ADA 18772 IF INDIA/~, ~J~LOTTEE OR TRIBE NAdVLE 8 UNIT, FA/~M OR LEASE NAME Trading Bay Unit 9 WELL NO K-5 (14-22) 10 F!~--TX) A,ND POOL, OR WILDCAT McArthur River - Hemlock 11 SEC , T , R , M , (BOTTOM HOLE OBJECTIVE) Sec 22, TpN, RiBW, SM 13 ELEVATIONS (Show whether DF, RT, GR, etc 12 PERM. IT INTO 100'KB 68-18 14 Check Appropriate Box To [ncii,cate Nature of NOtice, Re ~ort, or Other D~ta NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTLRE TREAT MULTIPLE COMPI RTE SHOOT OR ACIDIZE ABANDONS REPAIR ',,ELL CHANGE PLAN, SUBSEQUENT R~PORT OF: FRACTURE TREATMENT __1 ALTERING CASING ~ SHOOTING OR ACIDIZING ~ ABANDONMENTs (Other) RePerforatinE (NOTE Report results of multiple completion on Well Completion or Recompletion Report and Log form ) I5 D~, SCRIBE PROPOSED OR COMPLETED OPERATIONS (Clea,ly state all perttneut details, and gh, e pertinent dates, including estimated date of starting an} proposed work. 2-21-74 - RU D-A. Changed out swab valve. Ran 2-1/2" gage ring w/collar locator. Tagged top of fill ~ 12876'. 2-22-74 - Shot 2 shots/ft w/well prod ~ 500 BPD at following intervals: 12874-12854' 12854-12834', 12834-12818'.- 2-23-74 - Perf'd 12791-12771', 12769-12749', 12747-12727', 12712-12692'. 2-24-74 - Perf'd 12690-12670', 12670-12650', 12648-12628'. 2-25-74 - Perf'd 12628-12608', 12608-12588', 12564-12544', 12540-12520'. RD D-A & started prod at 11 PM 2-25-74. * Atlantic Richfield Company, Sub-Operator MAR 7 1974 DIVISION OF IND 16 I hereby cer~i~y thet the39refainf tm true and correct ~ ~ ~ ~e ~AA~A TITLE District Prig. Supt. DATE 415/74 l, (Thtm space for State Grace use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Union Oil and Gas Df on. Western Region Union Oil Company of Califorma 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 un,en June ll, 1973 Mr. Homer Burrell State of Alaska Oil 6 Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 RE: TBUS K-5 Dear Mr. Burrell: Enclosed please find two (2) copies of the Gyroscopic Directional Multishot Survey for the above captioned well. Very truly yours, District Drilling Supt. JRC/sk Enclosures (2) JUN DIVISION ,-r: (.iL AND OAS ANCHORAGE Aflantic~ichfieldCompany North Ame~l/Ir 1 Producing Division North Alasl. J~stnct Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 18, 1973 State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Attn: Mr. Homer Burrell RE: King Platform K-5 (14-22) Well Permit 68-18 Gentlemen: Attached is State of Alaska form P-3, Subsequent Notice of shutting off bottom water on the above mentioned well. Very truly yours, ~~Drlg' Engineer Attachment Form P--3 R_EV 9-30-6 9 Submit "Intentions" in Tril~h~ate & 'Subsequent Reports" m Duplicate STATE O,F ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to dllll or to deepen Use APPLICATION FOR PERiVilr--" for such proposals ) 0IL ~ SAS _~ WELL WELL OTHER 2 NAME OF OPERATOR *Union 0il Company of California 3 ADDRESS OF OPERATOR 909 W. 9th Avenue, Anchorage, Alaska 99501 4 LOCATIONOF WELL At su~ face 615'N & llg'W fr SW cr Sec 17, T9N, R13W, SM 5 AP1 NLrNI_F.R.ICAL CODE 50-133-20092 6 LEASE DESIGNATION AND SERIAL NO ADL 18772 T IF INDIAN. ALLO'i-rI~E OR TRIBE NA-M_E 8 UNIT, FAth~ OR LEASE NAME Trading Bay Unit 9 V~ELL NO K-5 (14-22) 10 Fl~.T,r) A~rD POOL, OR WILDCAT McArthur River - Hemlock 11 SEC , r , R, M , (BOTTOM HOLE OBJECTIVE) Sec 22, T9N, R13W, SM 13 ELEVATIONS (Show whether DF, RT, GR, etc 12 PERMIT 1~O 100'KB 68-18 14 Check Appropriate Box To I,ndJcate Nature of N~.tice, Re :)orr, or Other Dai*a NOTICE OF INTENTION TO: TEST WATER SHUT-OFF Pt LL OR ALTER CASIWO FRACTLRE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE -- ABANDON* REPAIR %% ELL CHANOE PLANS ,~ ~Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF J I __j REPAIRINO WELL FRACTURE TREATMENT ~h~t ALTERING CAlalNG SHOOTING OR ACIDIZINO ABANDO,%MENT* (other) Wat er Off (NOTE' Report results of multiple completion on Well Completion or Reeompletlon Report and Log form.) 15 b~ SCRIBE PROPOSED OR COMPLETED OPERATIO%S (Clearly state all pertinent details, and gt~e pertinent dates, including estimated date of starting an~ proposed work. Finished jacking rig over K-5 at 10:30 AM 5-2-73. Shot 5 3/8" holes ~ 12455' (10' above packer) with WL. Killed well w/790 bbls 9.2# Invermul. Displaced well fluid, recovering 639 bbls oil and 46 bbls water. Installed BOP. ND tree. Tested rams and choke manifold w/3000 psi, Hydril to 2000 psi. Pulled packer and tubing. Cleaned out hole to 13136'. Dropped reversing ball, circ fill from 13136-13151'. Recovered radioactive source, shear sub seat, setting ball and 2 pieces of packer rubber. Spotted 65 sx Class G cmt w/l% CFR-2 through DP at 13150'. CIP 4:50 AM 5-7-73. WIH w/bit and csg scraper, cleaned out to 12990' (PBD). Tested csg for 6 hfs w/400 psi, pressure bled to 350 psi. Ran gyro survey to 12985'. Landed 3-1/2" and 4-1/2" completion assembly at 12496', hydraulic packer ~ 12428'. Installed tree & tested w/5000 psi OK. Displaced w/100 bbls 7.6# viscous Invermul followed by 900 bbls diesel. Put well on gas lift ~ 2:00 PM 5-11-73. Released rig 7:00 PM 5-13-73. * Atlantic Richfield Company, sub-operator 1~ I hereb7 c~s~, ~ correct SIGNED~'/ ~,L-~_ -r,~'f ~_~- _ _ ,___ ~ TITLE Dist. Drlg. Supt. O V $ O ctiOi AO DATE 5/50/75 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF AN~: TITLE DATE See Instructions On Reverse Side I Ill ~.E~., 9-20-69 & Su~q~cnt ~s' ~ Duph~te STATE OF A~KA ~..~ OIL AND GAS CONSERVATION COMMI~EE 50-~33-2009~ ~ E~ B ENG SUNDRY NOTICES AND REPORTS ON WEL~ J (~ not use th,s form for p, upo-al~ ,o dl,ll or to de, pen ~L 18772 - NiXlE OF oPERATOR 8 UNIT, FA~%I OR ~SE NAME 3 *Union 0il Compa~ of California Trading Bay Unit ,~ss o~ o~,~roa ' ' ~ ~L ~o J" O~ 909 W. 9Ch Avenue, Anchorage, Alaska tOC.XnoN O~ xV~ ~0 ~mLo ~D POO~, O~ x~i~cAr ~ONFER. at ~,~, ~ u s~c, ~. a. ~. (~o~o~ ~o= ..... O~E~IVE) 615'N & llS'W fr SW er Sec ~, TSN, ~3W, SM Sec. ' ,, 13 ELEVA FIONS ~Sno~ ~hether DF, RT, iO0'KB Check Appropriate Box To Indicate Nature of Notice, Re BOTICE OF INTENTION TO TEST WATER SHUT-Orr PtLL OR ALTER' CAllI'~O FRACTLRE TREAT _ _~JMULTIPLE COMPI RTE SHOOT X~~ -- ABANDON' REPAIR I~ELL [ CHANO~ PLANS .~ j, ,ot~r~ Shu~ off bo~%om wa%er ,At,,, 68-18 ~ort, or Other Data SUBSEQUENT REPORT OF : WATER 8ItUT-OFF -- REPAIRING WELL FRACTURE TREATMENT ALTERING CASING (Other)~ (NOTE' Report results of multiple completion on Well C,,mpletion or Reeompletion Report and Log form ) 9~ ~¢RIBE FROPOSED oB COMPLETED OPERATION8 (Clea:ly state all pertinent details, and gl~o pertinent dates, including estimated date of starting an} proposed work. Pull GLV w/wireline on 4-20-73. Move rig from K-1 over Leg 2 K-5 and kill well w/9.2# Invermul. Install BPV, ND tree and NU BOPE. Test BOPE to 3000 psi. Pull ball valve and production ass,embly. Spot 75 sx of Class G cmt w/1.0% CFR-2 mixed at 15.8 ppg at 13,200' w/ope~j~d drill pipe. Run Gyro survey to PBD, , Run redesigned completion assembly. Land tubing and set BPV. ND BOPE. Install and test tree to 5000 psi. Turn well over to Production Department for reperforating and testing. * Atlantic Richfield Company, Sub-Operator ANCHOR^Gf 16 I hereby c~y that the,~reg$ilng ia_~ue and correct 8IGNEI~~ / - ~_.___ , _ . District Drlg,,, Supt. DATE April 9, 1973 TITLE (This lpace for $~Xu~. TITLE See Instructions On Reverse Side DATE Approved CoF~j ' - : INSTRUCTIONS: This form ~s used dur~n6 drilling or workover operations. If testing, coring, or perforating, show formation name ~n descrlb~n~ ,ork performed. Number all dr~ll stem tests sequentially. Attach description of all cores. Work per- formed by Producing Section will be reported on "INTEBIM" sheets until final completion. Report official or representative test on "FINAL" form, (1) Submit "INTEBIM" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week xn which oil string ts set, Submit weekly for workovers and follow~ng setting ~f o~1 string until completion. DALLY WELL HISTORY - INTERIM District South Alaska County or Parish Cook Inlet State Alaska Field Lease or UnitKing Salmon Platform K-5 Well No.. Date & Depth at 8:00 A.M. 4-7-70 3-24-71 Complete Record for each Day While Drilling or Workover in Progress PRODUCTION POH w/BV. Ran new BV. Tstg BV. PRODUCTION 3-23~71 - RU North Star WL. SI well. RIH to !2,400' w/BHP bmb. Flowed well f~m 9:30 AM to 3:30 PM. Made stops 50' abv ea GL vlv. Tool strtd fltg @ 7108'. SI well. POHw/bmb. RD N~'th SLa~. Piaced well ~n prod @ 7:00. PM 3-23-71. Well is lifting ~ vlv ~9 @ 99t0', Pmod BHP 1723# @ -9350'. Tst 3800 g~oss fluid,, 1.8% wTP, injected GOR 760, GOR 299, The Above is Correct: S 1 GN^'i IlllL DATE $. Ak. I)i:,I. l'r()~l. ,'4,qmrvi%t~r II'111 (hl'Mlllli All llAIl~ ~,lll IIl",lOll~ l(Jlt~'-, (tP,,'-I(I]IlVII¥ A'~ IlitY Alit I'lllPAlflll I(ql IA(Il ~111.) Form P--3 Submit "Intentions" in Triplicate STATE OF ALASKA % APl ~c~ CODg ' J OIL AND GAS CONSERVATION ,COMMI~EE ~0-133-20092 J SUNDRY NOTICES AND REPORTS ON WEL~ (Do not use this form for proposals ~ dx lll or to deepen or plug back to a dlfflerent re~ Use "~PblCATION POR PE~IT--" for such proposals ) ~L 18772 ,, , , , , OIL ~ GA8 NAME OF OP~TOR 8 UNIT, F~ OR ~SE ~Union 0il Comply of California Tradin~ Bay Unit ADDRESS dF 6P~ATOR ' 9. ~L NO ~07 Northern Lf~h%~ BKv4., ~nehor~e, Alaska 99~03 ... K-~ (~-22) LOCATION O~ W~L 10 P~ ~ POOL, OR FILE At surface Me~%hu~ Rive~ - o~ivm) 615' N & 119' W fr SW er See. 17, TpN, Ri3W, SM Sec. 22~ TgN~ R13W~ SM ELEVATIONS (Sh~w whether DF. RT. GR. ere 12 P~ ~O 100' KB ]68r18 Check Appropriate Box To I, ndi~ate Nlature of N~ot~¢e, Reper~, or ,Other Data NOTICE OF INTENTION TO: TEST WATER 8HUT-0FF I I PULL OR ALTER CASING FRACTLRE TREAT I } MULTIPLE COMPI,ETE SHOOT OR ACIDI~,E ~__[ ABANDON* REPAIR WELL CHANGE PLANe eUBeEQUENT R~PORT OF: WATER 8HUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OB. ACIDIZING ABANDONMENT* (Other) Re-pe~eora%,a p~-esanfi zone (No~: Report }esults of multiple completion on Well (Other) Completion or Reeompletion Report and Log form.) DESCRIBE PROPOSED OR COMPLETED OPERATION8 (Clea~ly state all pertinent details, and give pertinent dates, including estimated date of starting proposed work. 8-22-70 Killed tubing with 66# Invermul. Pulled tubing. Ran and set 7" retainer ~ 13,200', ran stinger on tubing. Set into retainer @ 13,200' formation broken down ~ 4400 psi. OT mixed and pumped 50 sx Class "G" cmt with 1% CFR-2 and 0.3% HR-7, preceded by 50 cf diesel followed by 25 cf diesel. Pumped 882 cf mud and closed tool. Disp 44 sx cmt into perf @ 3200 psi. Had very slow return around outside of casing. Pulled out of retainer and reversed out 20 sx cmt. ~ 8-26-70 Reperforated 2 1/2" hpf with 4" casing gun 13,150~12992', 12979-12902', 12878-12718' 12718-12588' and 12564-12520' 8-28-70 Ran and hung 3-1/2" and 4-1/2" tubing ~ 12492', packer ~ 12455'. 4-1/2" x 3-1/2" X-over ~ 10255' gas lift mandrels ~ 10857' 10600' 10255' 9909' 9534', 9004', 8317', 7695', 7157', 6562', 5668', 3658'. Ball Valve @ 253' Disp Invermul with diesel oil, tested packer with 1400 psi-OK. Released Rig ~ 12:00 noon 8-29-~0. R E [*~ E !- ~/ ~ `~'' )any, Sub-Operator *Atlantic Rich~ld ~Co~ 16 I hereby ~tnd correct SIGNED APPROVED BY CONDITION8 OF ~ APPROVAL, IF TITLE Dist. DrlE. Supt. DATE 9/17/70 TITLE DATE See Instructions On Reverse Side Approved Copy Returned . Forrrr P~3 R.gV 9-30-67 STATE OF ALASKA Subrmt "Intentions" in Tnphcate & 'Subsequent Reports" Ln Duphcate OIL AND GAS CONSERVATION COMMITTEE . SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a dffflerent reservoir Use "APPLICATION FOR P~IT~" for such proposals ) OIL WELL WELL OTHER 2 NAME OF OPERATOR *Union Oil Co. of California ADDRESS OF OPERATOR 507 Northern Lights Blvd., Anchorage, Alaska 99503 4 LOCATION OF WELL At surface 615'N & l19'W fr SW cr Sec. 17, T9N, R13W, SM ELEVATIONS (Show whether DF, RT, GR, 100 ' KB Check Appropriate Box To I~ndir~te Nlature of NOtice, Re 68=18 x~t, or Other Data NOTICE OF INTENTION TO: FRACTLRE TREAT I I MULTIPLE COMP! RTE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS gURSEQUENT RI~PORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) ;_ (No~E: Rel~ort[results_~f multiple eompletion on Well (Other) Re-perforate, ,, , present zone Completion or Reeo~pletlon, r ,~,,R~port and ~Og form ) '~ DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent~da[es, including estimaf~d date of starting ~ro~o~ed work. We propose to pull the present production assembly, set ~a cement ~retai~r ~ 13,200' and squeeze 40sx of retarded class "G" cement into the lower most perforations of the present completed zone (13,212'-300') to shut off botto~ water influx. We will re-perforate the following with 2 shots per foot: 12,520-564 12,588-878 12,902-974 12,992-13,150 We will then re-run a gas lift completion assembly & place the well back on production. This well was originally perforated w/4~ shots-pcr f5ot as follows: 12,520-564 12,588-878 12,902-979 12,992-13,192 13,212-13,300 * Atlantic Richfield Co. 16SIGNEDI hereby ~certtfy th{ ~ for ot true, and correct APPROVED BY ~~(~ CONDITIONS OF APPROVAL, sub-operator TITLE TITLE Dist. Drl. Supt. JUL 2 2 u~¥1$lON OF OIL ,~r, ~c~o~o~'-" 7/21/70 DATE See Instruct'ions On Reverse Side Form P~3 REV 9-30-47 STATE OF ALASKA Subratt "Intentions" in Triplicate & "Subsequent Reports" m Duplicate OIL AND GAS CONSERVATIO,N COMMITTEE SUN'DRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals m drill or to deepen or plug back to a dl£fierent reservo~x Use "APPLICATION FOR PEH/VIIT--" for such proposals ) OIL ,~ oas [] WELL WELL OT~Ea NAME OF OPEH~TOR *Union Oil Company of California , ,, ADDRESS OF OPERATOR 507 W. Northern Lights Blvd. ,Anchorage,Ak 9950 4 LOCATION OF W~L At surface 615'N and l19'W from SE corner, T9N, R13W, SM Section 17, ELEVATIONS (Show whether DF, RT, GR, etc 100' K.,. S. Check Appropriate Box To Indicate Nature of NIotice, ~i /%PI NUIHISRICAL CODE 50-133-20092 , L~as~ DESaGNA~ON ANn S~.RL~L NO ADL 18772 ? IF INDIAN, ALLOTTEE Olt TRIBE NAME a UNIT, F~ OR LF~S~. Trading Bay Unit 9 WELL NO K-5 (~14- 22) 10 FIELD AJ~D POOL, OR WILDCAT McArthur River - Hemlock II SEC, T, R, M, (BOTTOM HOLE OBJECTIVE) Sec. 22, T9N, R13W, 12 P~M/T NO 68-18 SM ~, or Other Date NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I ] FRACTL RE TREAT SHOOT OR ACIDIZE REPAIR WELL ~O~her~ Plug Back PULL OR ALTER CASINO MULTIPLE COMPLETE ABANDONs CHANOE PLANS for Btm Wtr (Other) .... l (NOT~: Report results of multiple completion on Well Completion or Recompletlon Report and Log form ) 15 DESCRIBE PROP08ED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an~ proposed work. Proposed: 1. Kill well with Inlet water. 2. Set retainer ~ 13,202'. Squeeze with cement perforations 13,212-13,30~ 3. Recomplete well through perforations 12,520-13,192'. RECEIVED 0V 19 DIVISION O~ OIL ~ND OM * Atlantic Richfield Company sub-operator. 16 I hereby eer'j~[~hat-tl/e~o~eoln~ is true and corre~ ' (B.E. Talle ,", APPRON~D BX J] ~ ~ ~ ~'" M~~ ~ITL~ CONDITION80~t~PP~O~A~, I~ l~: ' Dist. Drlg. Supt. 11/13/68 See Instructions On Reverse Side UXIOX OIL CO, OF C.\L!FO2i',:tA ' ALASKA DIS"'~ '' FROX!' _Usii.oTi_D_i.!_.C_o. of_. Califo~rA~a_ Trp. r~:~i~titicd b.e_,'c,.,itt~, are the foilo:~ing- DATE' June 26z 1968 t',IiLL NAHE: T__ra__d__i_n~L~aff State ".V' #14 Trading gay Unit D-4 (run #1) Trading Bay Unit Run No._fj...r~_.L_ SeI, i a B I tie Sca 1 e Induction E!,~-,ctrical Log .J_.aa. _L_aa. _2/__ Dual Induction Lataro!og BtlC Sonic/Caliper I. og ) 1 t,,I,C Sonic,/(;a,,:r,,:~ Ray BtlC Soni,~/ Ca!Jpez/Ga~ma Ray Log Formation Sonic Log~,~*:~ l)cnsit>'-Carma Log Forn,a~ion Dcnsi~7 Log Ncut rcr, I,og Fornatioa Xcu~ro¢ !.oD (F'n) ~,esolution ' )' Pr CL .I Safety iht CD>I Or l'Fl~,tOtt~ CI)~ ar Pci)'.,~g Plot CDM Pola!' Plots Proximi ty.-',!xcro I c~/Ca I iper Gamma Ray Collar Log Cement Band Log Mud Iog Co~'e Descriptions, Convontlonxl, No. Core Dcscr'iplio:~s, Sidc,;al Core An-~lTsis Core Chips Sa,:.i, !~ Cut DJ'ii] 3tcm Test Diruzt i onal Su::vey.~ RECEIVED JUN 27 1968 DIVISION OF MINES & MINEP, A~ ANCHORAGE Date- Fem'n No P--~ ,STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DEPLICATE AIONTNLY REPORT O'F DRILLING AND WORKOVER OPERATIONS 2 N;~Vl]~ OF O~E~ATOR * Union 0il Company of California 3- ADDRESS 6F O~I~ATOR ' " 99503 507 W. Northern Lights Blvd. ,Anchorage,Alaska '4 LOCATiON O~ WELL 615'N and l19'W from SE corner, Section 17, T9N, R13W, SM ~ ApI NU~IEPaCAL CODE 50-133-20092 LEASE DESiGnATION A.~D SEqqlAL NO ADL 18772 ~, iF INDI ~N, ALOTTEJ~ OR TRIBE NAME ' 8' I/KIT,FA/~%I OR L~.ASE N.~ME Trading Bay Unit 9 WELL NO ,K-5 (14-2,2,) 10 ~LIfJ.~D A_ND POOL OR %VILDCAT McArghur River - Hemlock 11 SEC , T , lq. , M IBO%~FOM HOI.~ OBJECTIVE) Sec. 22, T9N, R13W, SM 12 PERMIT NO 68-18 '13' 'REPORT TOTAL DEi~TH AT END OF 'MONT'H, CI-LANG~ IN HOLE SIZE, CASING A/XTD CEMENTING JOBS INCLUDING DEPTH SET A_ND VOLLrNFES USED, PERFORATIONS, TESTS ~ RESULTS, FIStIING JOBS, JIINK IN HOLE A_ND SIDE-TI~ACKED HOLE ~ND ANY OTI{ER SIGNIFICANT O~.N'GES IN HOLE CONDITIONS Trading Bay unit K-5, ,(14-2,2) - ,May 1968 Directionally drilled 8½" hole 10,508-13,370'. Ran DIL, FDC-Gamma Ray and BHC Sonic from 13,370'. Ran CDM from 13,337'. Cemented 73 jts 7" 29% N-80 special clearance coupling buttress casing as liner (3059') ~ 13,368' w/top ~ 10,309' w/800 sacks Class G cement treated w/l% D-31. Displaced w/1675 cu. ft. mud. CIP ~ 2:00 PM 5-17-68. Cleaned out cement to 10,309'. Tested lap to 2200 psi for 15 min., OK. With 6~ bit and 7" casing scraper, cleaned out to 13,323'. Ran CBL. Tested liner w/1000 psi for 15 min., OK. Displaced mud w/salt wtr. Ran 3%" and 4%" tbg to 12,482'. Changed from salt wtr to diesel. Set packer ~ 12,443'. Perforated 4 holes/ft 13,300-13,212' 13 192-12 992' 12 979-12 902' , , , , i i , 12,878-12,588' and 12,560-12,520'. Tbg pressure 540 psi. On production Rig rele&~d ~ ,4,~00 ,~~ 5-22-68. RECEIVED ,JUN 10 1968 * Atlantic Richfield Company sub-operator. DIVISION OF MINES & MINERAL8 ANCHORAGE I',t-;) l/il/H/ Dist. Drilling Superintendent June 4, 1968 SIGNED . ~ ~/ [/ ~/ ~ TITLE .... DA'A E , NOTE--Report on th~s foJ~ m reqmred for each calendar month, regardless of the status of operat,ons, and must be hlecl m duplicate wKh the D~wslon of M~nes &/Minerals by the 15th of the succeeding month, unless otherwise directed / Form P~7 ' · STATE OF ALAS~(A reverse s~de) 5. Alii NTJ1M]SB.ICA/~ CODE OmL AND GAS CONSER~AT, ONv~~%t~%%N~s & WELL cOMPLETION oR RECOMPLETION REPORT AND LOG* WE~L ~ELL 9~ OtAer ~. TYP~ 0~ COMPLE~ON: NEW ~ WORK ~ PLUG ~ ruFF ~ Other WELL * Un&on 0~ Company .of California ,.w~o 507 W. Northern ~ights Blvd. ,Anchorage,~. 99503 ~, LOCATION 0F WELL (Re~ort location clearly and tn accord~ce with a~y Etate ,t ~.~a,. 615 '~ & 119'~ f=om SE come= Sec. 17 At top prod. interval reported below 605'E & 229'E fr~ ~ corner, 6'S a 467'E from ~ corner,Sec. 27, T9N,R13W,SM 68-18 3-24-~8 ~ 5-15-68 } 5-22-68 ~ 100' K.B. ] 62' _ . ~ ~ ~O~ ~Y~ { BOTARYTOOLS ~ ~ CABLE TOOLS 13,370 (9856) / / , -- I 0-I3,370 ~. pAoD~cma ~NT~V~(S), OF ~s ~P~~, ~m, N~E ~ AND ~); 12,520--12,564, 12,588--12,878, 12,902--12,979, 12,992--13,192, 13, 212--13, 300 H~lock Zone ,i Yes 50-133- 2,90,,92 APL 18772 'IF IN'I)IA.N. AJ.J.~OTTEE OR TRIBE NA/~E McArthur River-Hemlock sec.. T. R ,'~, (BO~rO~ ~OLE OBJECTIVE) Sec. 22, T9N, R13W, SM 84 ~ ELECTRIC A_ND OTHER LOGS RUN DIL ~ Dens.ityr. Gam!m_a Ray, Sonic and Dipmeter ii iii ~. CASING RECORD (Retort all strings set m well) C*$ING SIZE 1 WEIGHT. LB/FT ~' "GP~DI~ i DEPTH 'S~ '~), l HOL~ 1~-3/8" I i 61 I J ~ '1 ~i~'~I ~" ! I. _. ! I 9-5/8" [ 47~ {N&P [ 10,434 ] 12%" , , I I, i , 1 26 LINER REC O'i~D ,, ,368 800 -- · I i] ii I i i i PERFORATIONS OPEN TO PRODUC~OI¢ (Interval,s~ze and number) 12,520-12,564, 12,588-12,878, 12,902-12,979, 12,992-13,192, 13,212-13,300 4 holes/ft. 1175 sx w/10% Gel & 450 sx Neat . 700 sx i II I I I I ~0 PRODUCTION DATE FIRST PRODUCTION I Pl%ODUCTION NIE'£I{O'D (Flowing, gas hft, pump~--s]ze and type of p~P) 5- 23-68 [ Flowing ,,~m o~ xmsx. [~o~s T~ '[~OXE SiZE IPROD'N FOR OI~BEL ~CF 5-23-68} 24 { 1%" ~ 7448 { 1800 FLOW.~ ~BING [C~S~G ~S~ [C~~ OI~BBL. ~A~ 2zo I -{ v44s , , 1 zsoo , 31 mSPOS{~WN Or O~S (Sold, u~e4/o~/,el, ~6nte~, etc.)' ' ~ Vented ~2. LIST OF ATTACHMENTS TUBING REC OP,,D AiVIOLrNT PULLED None None D.EI~I*H SET (MD) ! PACKER SET (MI)) 482 443 29 ACID, SHOT, F~qJ%C~ItLrl{E, CE~ENT SQUEEZE, ETC DEi:elHI~,._,_'None~: mT~v~ .... (MD) i A~%IOUH']~ A/ND KIND O,F 1VL~I'Ei~IAL IJ~ED IWELL STAT~JS (Produmng or =~'~") Producing WATER---BBL I GAS-OIL FJ~TIO 149 I 242 WATER---BBL OIL 6~RAVITY-A/~I (COIl/{ ~ 149 31.3° ']TEST WITNESSED BY ' ' t R. Smith SIGNED . . ~ ,, ~ .... DATE · - ........ B.~. ~a~'le~ . . . *(Seetnstructions and Spaces I:or Additional Data on Reverse Side) II * Atlantic Richfie[Ld Company sub-operator. INSTRUCTIONS General Th~s form ~s design.ed for submitting a complete and correct well completion report and log on all types of lands ahd leases in Alaska Item: 16: Indicate which elevat,on ~s used as reference (where not otherwise shown) for depth measure- ments g~ven ~n cther spaces on th~s form and ~n any attachments Items 2ff, .nd 22::Jf th~s well ,s compl, ete. d for separatc production from mo? t. han one ~nterval zone (multiple comple.t~on), so state ~n ~tem 20. and ~n ,tern 22 show the prcJuc~ng interval, or ~ntervals, ~op(.s), bottom(s) and name (s) 0f any) for only_the ~nterv~! reported ~n ~tem 30 Submit a separate report (page) on th~s form, adequately ~dent~F, ed. for each adci~t~onal ~nte~val to be sepbrately produced, show- ~ng_the _~ckJ~t~onal data pertinent to such ~nterval Item26: "Sacks ~ement" Attached SUl~plemental records for th~s well should sho~ the details of any mul- tiple stage cementing and the location of the cementing tool Item 28: Submit a separate completion report on this form for each interval to be separately produced '($ee"instruct~on for '~tems 20 and 22 above) '.~.~[.~RY 0['~ IpO~.MATibN ',P~T$ iN( LUI)IN(, ,NTE~v~T~TP2D PR~U'u~ DAT~ ~-~COV'~q OF 01L ~AS - ( WATER AND MUD , Hemlock 12,520 9315 ~R.~ DATA. AWA¢I{ BRIE¢ ¢~CRI¢I~ONS OF LITHOLOOY pORosITY FRACWR~ APP~NT DIPS' ., [. , AND DETEC"I'EI) SHOWS OF OIL, G~ OR WA~t ........ County or Parish Lease or Unit ~Sistric% , _~1 · Field. },'_cAr,thur River Hemlock Auth. or W.O. No._ 19-7205 State Alaska /&~ #14-22 ~ T~U K-5 Well No.__~ Drill development well .from King Plmtfo~na Title Operator_ Atlantic Richfield (Unien of Cg!if. Unit Operntor) ..... TARCO'S W.I._ l~.OSO0% --- Spudddd or' -Prior Status W.O. Begun ~udd~d Date~~-~8 Hour .~if a W. O. Date & Depth as of 8:00 A.M. 3-25-68 '775 3-26-68 !,932 3-27-68 2,533 3-28-68 2,533 3-29-68 2,533 4-1-68 4,454 4-2-S8 5,265 4-3-68 6,120 4-4-68 6,701 4-5-68 7,182 Complete Record for each Day Reported (400) Drilling. ...... ' Mud 76#, Vis. 42". Moved rig #57 over Conductor #16. Spudded @ 4:30 ~M 3-24-68. Drilled 12 1/4" hole 375-455'. Ran hole opener and opened 12 1/4" hole to 15" 375-455', Ran Turbodrill and directionally drilled 12 1/4" hole 455-775' -' . (1157) Drilling. Mud 65#, Vis. 44". Directionally drilled 12 1/4" hole 775-{932'. Survey: 1872' 32° S60E, VD 1791.29, S203.51, E402.99. .... _ . (601) Drilling Mud 74#, Vis. 46", t~ 10. Sec. Dtrectionally drilled 12 1/4" hole 1932-2533'o Survey: 2533' 45° SS~E, VD 2290.24, S4C~'-~0, E731,72. ~(0) Running 13-3/8" csg.. Mud 75#, Vis. 43", VL lOcc. Opened_ 12 1/4" hole to 18" 455-2531'. RU t6-r~n csg. - '(0) Installing BODE. (13-3/8" @ 2~76) '- ...... - -- - -- Ran 59 its. (2436') of 13-3/8" 61# J-55 Buttress csg w/CCT Unihead, Baker float shoe and collar. Cmt 13-3/8" @ 2476' w/float collar O 2437'. Cmt w/1175 sx of Class G cmt w/lO~ gel and 450 sx. Neat cmt. Circ 522 sx of cmt. CIP @ 5:00 P~I 3-28-68. Floats held OX. (1921) Drilling. (13-3/8" @ 2476) Mud 73#, Vis. 45", YfL 8.0Ceo Tested pipe rams, CSO and Hydrill w/3000 psi for 30 min., OK. Tested csg w/lO00 psi for 30 min., OK. Directionaliy drilled 12 1/4" hole 2533-4454'. --- - '-- ~ Survey: 4454' 48° S5SE, VD 3543.54. Sl172.13, E1965.93. .($11) Drilling (13-3/8" @ 2476) Mud 74#, Vis. 39", YfL 6.8cc. Directionally drilled 12 1/4" hole 4454-5255'. Survey: 5105' 44° S58E, VD 399~.91, S1421.87z E23Sq.44. (855) Drilling (13-3/8" @ 2476) Mud 75#, Vis 40" , YfL 6.4cc. Directionally drilled 12 1/4" hole 5265-G120' Survey: 6015' 41-3/4° S57E, VD 4671.22, S1756.74, E2872.50. (ssi) (13-3/S" @ 2476) GIH w/bit. Mud 77~, Vis. 44" . , WL 6.0cc. Directionally drilled 12 1/4" hole 6120-670i' Survey: 6701' 3~ 1/2° $52E, VD 5203.93, S2009.81, E3221o64. (481) Drilling (13-3/8" @ 2476) Mud 76#, Vis. 47", WL 5.7cc. Directionally drilled 12 1/4" hole 6701-7182'. Survey: 7156' 43 Distribution: . Orig.: Drilling Section- Dallas cc:- District Office Engineering Division - (720) Co-Owner(s} As Appropriate Regional Office, Well Record File PAGE NO. S IG~ ATURE DATE District Drilling Supervisor TITLE: .(NUMBER ALL DAILY WELL IIISTOB~ FORMS CONSFCU'flVELY AS THEY ABE PREPARED FOR EACtl WELL.) 3B-450- 1 District Alaska Field McArthur River Hemlock 'LY WELL HISTORY - IHTERll~t County or Parish Lease or Unit TBU K-5 State Alaska #14-22 Well No.__ Date & Depth at 8:00 A.M. 8,082 4-9-68 8,293 4-10-68 8,298 4-11-68 8,298 4-15-68 8,425 Complete Record for each Day While Drilling or Workover in Progress ~900) Tripping. (13 3/8" @ 2476) Mud 79#, Vis 40", WL 6.0cc; Directionally drilled 12 1/4" hole 7182-7593' Ran Sperry-Sun Gyro Survey in, 13-3/8" csg. Directionally drilled 12 1/4" hole 7593-7845'. Power failure while using Halliburton unit on Rig 58. Bearing (blower) on skid #1 out. Took Rig 57 power to run Halliburton unit (mud pump and rotary table from skid ~2. Dlrectionally drilled 12 1/4" hole 7845- 8082 '. Survey: 7990' 41 1/2° S4OE, VD 6156.93, S2619.59, E3822o14. (211) On btm w/turbodrill. (1~3/8" @ 2476) Mud 77#, Vis. 40", WL 5.6cc. Directionally drilled 12 1/4" hole 9082-8293'. Survey: 8273' 44 1/2° S39E, VD 6372.12, S2770.19~ E3944.09. . (5) Fishing. (13-3/8" @ 2476) Mud 78#, Vis. 42", WL 5.5cc. Ran Turbo #5 and directionally drill3d 8293-8298'. Stuck pipe @ 3280' while pulling out of hole w/turbo #5. Ran into rite spot w/190,000# net @ 1:30 1~,.{ 4-9-68. Worked pipe, circ, waited on Halliburton. Mixed 80 bbls diesel w/4 drums "free pipe". Spotted 70 bbls. In place @ 6:15 Picked up Bowen surface Jars, Jarred down on fish @ 9:00 I~,{. Moved pill lbbl/hr. In place @ 7:30 AM 4-10-68. (0) Jarring on fish. (13-3/8" @ 2476) Mud 76#, Vis. 47" . , WL 5.4cc Jarred down on fish. Worked pipe w/80 bbls diesel oil "free Pipe" pill. Pulled 175,000# net on fish, helfl strain 1 hr. Did not move fish. Circ out diesel oil, conditioned mud. No cavings across sha!:er. Could not get turbo to run. LD jars. RU Schl and ran Pla-log free point, stopped @ 2932'. Circ I hr. Reran free point to 2932', stopped. LD free point tools. Ran spudder bar to bent sub @ 3221'. Reran free point to 2932'. Stopped. Pipe stuck @ 2775'. Backed off DP @ 2408'. LD 12 its. bent DP. RIH w/9 7-3/4 PCs, 3 Jts heavy-wate bumper sub and Jars. Screwed into fish @ 2406' (btm fish @ 3248'). Jarred dov.~ 7 1/2 hrs. Jarred up 2 1/2 hrs. (127) POH. (13 3/8" @ 2476) Mud 79#, Vis. 57", WL 5.8cc. Ran free point. Backed off @ 2740', recovered 11 its heavy-ware DP. Ran 5 Jts. 9 5/8" wash pipe w/DC spear, bumper sub and Jars. Washed over fish 2740-2934'. Backed off @ 2920', recovered 6 Jts. Heavy-wate DP. Reran wash pipe assembly. Washed over fish 2920-3110'° Ran Dialog and backed off @ 3100'. POH and recovered 6 Jts (150.67') of Heavy-ware DP. 'RIH w/9-5/8" wash pipe. Washed over fish 3100-3239'. Fish came free. Tried to work fish out of hole. Ran fish down hole to 3285', OK. Pulled back up to 3239', hole tight, working fish. While working pipe lost fish out of DP spear. POH. LD 9-5/8" wash pipe. RIH w/11-3/8" washover shoe and sub. Reamed hole 2920-2924' and 3224-3230'. Found top of fish @ 8122'. Screwed into fish, POH w/fish. Dlrectionally drilled 12 1/4" hole 8998-8425'. Distribution: Orig.: grilling Section - Dallas cc:- District Office Engineering Division - (?20) PAGE NO. SIGNATURE DATE Co-Owner(s) - As Appropriate Regional Office, Well Record File District Dr_J.l_ling_S_uperv~o~r . TITLE (NUMBER ALL DALLY WELL HISTO[1Y FO}~tS CONSECUTIVELY AS THEY ARE PREPA[1ED FOR EACH WELL.) 3B-459-2 District Alaska Field McArthur River Hemlock 12''LY WELL HISTORY - INTERII~ County or Parish Lease or Unit TBU K-5 State Alaska ~14-22 Well No.~ Date & Depth at 8:00 A.M. 4-16-68 8,506 4-17-68 8,669* 4-18-68 9,002 4-19-68 9,144 4-22-68 9,261 4-23-68 9,553 4-24-68 9,764 4-25-68 10,040 4-26-68 10,278 Complete Record for each Day While Drilling or Workover in Progress (81) Drilling. (13-3/8" @ 2476) Mud 79#, Vis. 51", WL 5.4cc; Tested BOPE.- Oriented turbodrill NSOE. Directionally drilled 12 1/4" hole 8425-8506'. Survey: 8476' 45° S43E, VD 6508.08, S2873.85, E4033.54. (163) Drilling, (13-3/8" @ 2476) Mud 76#, Vis. 46" , WL 5.6cc. Dlrectionaliy drilled t2 1/4" hole 8506-8669' Survey: 8611' 45 1/4° S43E, VD-6603.12, S2943~97, E4102.42.- (333) Drilling. (13a3/8"~@ 247'6) Mud 78#, Vis. 48", WL 6.1cc. Directionally drilled 12 1/4" hole 8669-9002'. Survey: 8816' 44° S44E, VD 6756.65, S3051.81, E4202.41. (142) Tripping. (13-3/8" @ 2476) Mud 77#, Vis. 46", WL 6.7cc. Directionally drilled 12 1/4" hole 9002-9144'. Survey: 9010' 4~1/4° S42E, VD 6898.61, S3152.41, E4292.99. (117) Drilling. (13-3/8" @ 2476) Mud 77#, Vis. 46", WL 6.0cc. Directionally d~illed 12 1/4" hole 9144-9193'. Stuck bit @ 9888', while GIH. Mixed 55 bbls of diesel and 2 drums of free pipe. Spotted 32 bbl around DC. Left 25 bbls in DP. Moving 1 bbl over 30 min. Oil in place @ 10:15 E,! 4-19-68. Ran in w/free point and back-of£ shot. Tried to back off @ 8893'. Pipe backed off at approximately 8200' while putting torque in pipe. Screwed back into fish. Backed off DP @ 889~'. Total 195' fish in hole. POH and picked up jars and 2 stands of DC and bumper sub and WE and screwed into fish. Jars did not work. Bumped fish dove. Fish came free. POH, LD fishing tools. WIH w/drilling assembly and rea~ed 9035-9193'. Directionslly drilled 12 1/4" hole 9193-9261'. Survey: 9193' 45 1/2© S40E, VD 7024.88, S3252.40, E4376.79. (292) Drilling. (13-3/8" @ 2476) Mud 80#, Vis. 46", WL 5.8cc. Directionally drilled 12 1/4" hole 9261-9553'. Survey: 9418' 46© S40E, VD 7181.19, S3376o37, E4480,82. (211) Drilling. (13-3/8" @ 2476) Mud 83#, Vis. 53", WL 5.8cc. Directionally drilled 12 1/4" hole 9553-9764'. Survey: 9623' 47© S40E, VD 7321.00, S3491.23, E4577.20. (276) Tripping. (13-3/8" @ 2476) Mud 79#, Vis. 47", WL 4.8cc. Directionally drilled 12 1/4" hole 9764-10,040'. Tested ROPE w/2500 psi for 30 min., OK. Survey: 9821' 47 1/4° S42E, VD 7455.40, S3599.27, E4674.48. (238) Drilling. (13-3/8" @ 2476) Mud 80#, Vis. 41", WI. 5.8cc. Directionally drilled 12 1/4" hole 10,040-10,278'. Survey: 10,064' 48 3/4© S40E, VD 7615.00, S3748.98, E4792.55. Distribution: Orig.: Urilling Section - Dallas cc:- District Office Engineering Division - (720) Co-Owner(s) - As Appropriate Regional Office, Well Record File PAGE NO. The Above is Cot t: Original S!~c~l flhTC IL T. LOUDERLM~K SIGNATUPE DATE District Drilling Supervisor TITLE .(NUMBER ALL DAILY WELl, HISTORY FORMS CONSFCUTIVELY AS TIIEY ARE PREPABED FOR EACH ~ELL. ) PHnted U S A " 3B-459-2 District Alaska .Fi,id McArthur River Hemlock b,..,,LY WELL HISTORY - INTERIA~ County or Parish Lease or Unit .... L._TBU K-5 State Alaska #14-22 Well No..____. Date & Depth at 8:00 A.M. 4-29-68 10,498 4-30-68 10,498 5-1-68 10,508 _ _ _ 5-2-68 10,825 5-3-68 11,065 5-6-68 11,620 5-7-68 11,923 5-8-68 12,037 5-9-68 12,175 Complete Record for each Day While Drilling or Workover in Progress (220) Running 9 5/8" csg. (13-3/8" @ 2476; DIL 10,498) Mud 80#, Vis 52", WL 4.4cc. ' Directionally drilled 12 1/4" hole 10,278-10,498'. Made 15 stand wiper run. Measured in hole w/bit OK. Circ and conditioned hole to log. RU Schl. Ran DIL from 10,498'. Stuck DI~ Sonde @ 8550'. Worked Sonde loose in 20 min. RIH w/12 1/4" ,bit, no tight spots. Circ, made 25 stand wiper run, no fill· Circ and conditioned mud, POH. Ran Sonic · and Density, stuck Density Sonde @ 10,300' POH. Worked free in 30 min. Logged out of hole. Gamma Ray did not record. WIH w/12 1/A" bit, circ and conditioned mud for csg for 3 1/2 hrs. POH. RU to run csg. (0) Standing cmt. (9-5/8" @ 10,434; DIL 10,498) RU bit guide puller on 9-5/8" csg,.~ulled bit guide. Ran and cm~ 9-5/8" ~7# P-ll0 and N-gO csg. @ 10,434' w/700 sx Class G cmt w/l% D-31. Mixing time 15 min. Displaced cmt w/lO0 cu. ft. wtr and 4400 cu.ft, mud. CIP ~ 4:05 AM 4-30-68. Shoe Jt fitted w/Hallib~urton float shoe and differential collar (10,392'). Did not bump plugs. Float did not hold. Csg landed in OCT unihead. (10) Drilling. (9-5/8" @ 10,434; DIL 10,498) Mud 80#, Vis. 64", ¥~ 8.1cc. Tested blind rams to 3000 psi, DP rams to 2500 psi and Hydril to 2500 psi for 15 min., OK. RIH w/8 1/2" bit. Found top pf cmt $ 10,314', differential float collar @ 10,392' and shoe ~ 10,424'. Cleaned out cmt o10,314-10,434', DO shoe and directionally drilled 8 1/2" hole 10,498-10,508'. - (317) Drilling· (9-5/8" @ 10,434; DI~, 10,498) Mud 79#, Vis. 44", WL 6.0cc. Directionally drilled 8 1/2" hole 10,508-10,825'. Survey: 10,667' 40° S31E, VD 8070.13, S4073.53, E5006.27. (240) Drilling. (9-5/8" @ 10,434; DIL 10,398) Mud 80#, Vis 43" · , WL 5.2CC. Directionally drilled 8 1/2" hole 10,825-11,065'. (555) Tripping. (9-5/8" @ 10,434; DIL 10,498) Mud 80#, Vis. 44", ~L 5.0cc. Directionally drilled 8 1/2" hole 11,065-11,620'. Survey: 11,620' 52° S28E, VD 8712.67, S4695.62, E5331.64. (303) Drilling. (9-5/8" @ 10,434; DIL 10,498) Mud 79#, Vis 43", WL 4.2cc. Directionally drilled 8 1/2" hole 11,620-11,923'. Survey: 11,817' 50° S28E, VD 8339.20, 84828.86, E5402.49o (114) POH, looking for washout. (9-5/8" @ 10,434; DIL 10,498) Mud 80#, Vis. 44", WL 4·4cc. Directionally drilled 8 1/2" hole 11,923-12,037'. Survey: 12,024' 50 1/2~ S29E, VD 8977.30, S4970.88, E5479.22o , (138) Drilling. (9-5/8" @ 10,434;.DIL 10,498) Mud 77#, Vis. 41", WL 3.8cc. Directionally drilled 8 1/2" hole 12,037-12,175'. With bit 45 found washout 58 stands off btm. With bit 46 found washout 10 stands from top. Survey - no good. Distribution: Orig.: Drilling Section - Dallas cc:- District Office Engineering Division - (720) Co-Owner(s) - As Appropriate Regional Office, Well Record File SIGNATURE DATE DJ~irlct Drt! 1 ing_f~up~or TITLF PAGE NO.. 4 (NUMBER ALL DAILY ~ELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WEI. L. ) 38-459-2 District .. . A3a~ka Field_ McArthur River Hemlock &,,~LY WELL HISTORY - INTERllk.~, County or Parish Lease or Unit TBU K-5 State Alaska #14-22 Well No.. Date & Depth at 8:00 A.M. .... 5-lO:68 .... 12,382 5-13-68 ....... 13,000 · 5-14-68 '_ 13,208 . . - 5-15-68 13,304 5-16-68 TI) 13,370 -- .""...' '/. 7fr - ~-17-68 TI) 13,370 5-20-68 TI) 13,370 PBD 13,323 Complete Record for each Day While Drilling or Workover in Progress (207) Drilling. (9-5/8" @ i0,434; DIL 10,498) Mud 78#, Vis. 43", WL 4.0cc. Directionally drilled 8 1/2" hole 12,175-12 382' (618) Drilling. (9-5/8" @ i0,434; DIL 10,498) Mud 78#, Vis. 44" , WL 3.42c. Directionally drilled 8 1/2" hole 12,382-13,000' Survey: 12,892' 50-3/4° S21E, VD 9553.90, 85558.93, E5737.~4. (208) GIH w/bit. (9-5/8" @ 10,434; DIL 10,498) Mud 79#,. Vis. 50", ~WL 3.6cc. Directionally drilled 8 1/2" hole 13,000-!.3,208' (96) GIH w/bit. (9-5/8" @ 10,434; DIL 10,498) Mud 80#, Vis. 42", WL 4.9cc. D%rectionally drilled 8 1/2" hole 13,208-13,304' (66) Logging. l~ (9-5/8" @ 10,434; DIL 13,370) Mud 80#, Vis. 43", WL 4.2cc. Directionally drilled 8 1/2" hole 13,304-13,470'. RU t.o log. Ran DIL, FDC-Gamma Ray and EHC Sonic from 13,370". Log tool pulled tight @ 11,710' and 13,320'. - Gilt w/7" liner. (9~5/8" @ 10,434; DIL 13,370) Mud 80#, Vis. 43", VfL 4.3cc. Ran Dipmeter, stuck @ 13,337'. Worked loose 321-13 370' in 15 mtn w/lO,000# pull. Did not run Hicrolog. Rer~med 1S, , . No fill. Conditioned mud. POH. }.lade up 73 ~ts 7" 29# I{-80. Special clearance coupling Buttress csg as liner (3059') w/}{owco float shoe and Bro%;m Oil .Tool landing collar and Brovm Oil Tool hydraulic liner hanger w/7" tie-back - sleeve. - ...... (7" liner @ 13,368, top @ 10,309; DIL 13,370) Running 4 1/2" tbg. Mud 80#, Vis. 43", WL 4.3cc. Ran and cmt 73 its (3059') of 7"~9# N-80 special clearance buttress csg @ 13,268, top of hanger @ 10,309'. stop collar @ 13,323'. Cmt 7" liner @ 13,368', top @ 10,309' w/800 sx Class ................. G cmt treated w/l% D-31. Mixing time 22 min. Displaced w/1675 cu. ft. mud. .. ClP @ 2:00 ~,! 5-17-68. WOC 15 hrs. CO cmt in 9-5/8" csg to top of liner @ 10,309'. Tested lap to 2200 psi for 15 min., OK. POH. Picked up 3100' of 3 1/2" BP and RIH w/6" bit and 7" csg scraper. CO liner to 13,274'. Measured out of hole OK. Ran Schl CBL, log OK. RIH w/6" bit and 7" csg scraped. DO cmt 13,274-13,323'. Tested liner w/1000 psi for 15 min., OK. Displaced mud w/saltwtr. POH and LD 5" DP and 3 1/2" DP. Pulled bit guide and installed spacer. Ran 71 its of 3 1/2" tbg w/Brovm pkr and Otis Q-nipple. _ _ 5-21-68 TD 13,370 PBD 13,323 (7" liner @ 13,368, top @ 10,309; DIL 13,370) RU Schl. to perforate. Ran 330 its of 4 1/2" Buttress tbg w/10 Otis CX gas mandrels 0~tis 4 !/2" ball valvo ~d O~T tbg hanger. Tbg btm @ 12,482'. Installed Xmas tree, tested to 5000 psi, OK. Displaced hole w/diesel. Distribution: Orig.: Drilling Sect{on - Dallas cc:- Distr{ct Office Engineering Division - (720) Co-Owner(s) - As Appropriate Regional Office, Well Record File PAGE NO. 5 P,lnted U S A The Above is Correct: Original $i~ By B. T. LOUDER.MILK SIGNATURE DATE District Drill{nE S_uporvisor TITLE (NUMBER ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS TREY ARE PREPARED FOII EACH WELL.) 3B-459-2 DAILY WELL HISTORY - FINAL KLI"VKI o bistri~t Alaska ~ County or Parish Field. McArthur River I~iemlock Lease or Unit Auth. or W.O. NoL 19-7205 State Alaska f~14-22 ~ell No. TitleDrill Development Well _from King Platform. Operator- Atlantic Richfie..ld. Co. (Union ~f Cai. Unit..Op~ r. )TARCO'S W.I. Spudded or . Prior Status W.O. Begun SDTld~d Date 3-24-68 Hour 4:30AM if a W.O. 17. 0600% Date & Depth as of 8:'00 A.M. 5-22-68 TD 13,370 PBD 13,323 5-23-68 TD 13,370 PBD 13,323 Cqmplete ~ecord for Each Day Bepo~ted Perforating. (7" liner ~ 13,368, top ® 10,309; DIL 13,370) Pulled ball valve sleeve. Set Brown pkr ~ 12,443' w/4300 psi. Tested tbg to 3~00 psi. Tested csg to 1100 psi. RU Schl. Per- forated 4 holes/ft 13,300-13,212', 13,192-12,992', 12,979- 12,902' and 12,878-12~588". Tbg pressure 540 psi. (7" liner ~ 13,368, top ~ 10,309; DIL 13,370) Perforated 12,564-12,520'. Removed Schl. Turned rig to Prod. Dept. @ 1:00 PM 5-22-68. Kickea well off snd flowed to clean up Released rig © 4:00 PP! 5-22-68. tleld fire drill. Continued t6 clean ~p well. Average ra~e as of 7:00 ~t 5-23-68, 7448 BOPD, 9_% RS&W, 31.3~ API, GOR 242, 210 psi F~P, 1%" choke, continuing to clean up. :~:k'~k TD~ 13. ~70 ,, New TI] PB Depth 13,323 Released Rig_ 4:00 PM Classifications (Oil, Gas, etc.) Date 5-22-68 Kind of Rig Rotary Type Completion (Single, Dual, etc. ) Single P. roduc lng Me thod _ .. Flowi.n.g Official Reservoir Name(s) McArthur River H_~mlock Potential Test Data: WELL NO. DATE RESERVOIR PRODUCING INTERVAL [ OIL OR TEST TIME PRODUCTION .... GAS. OIL ON TEST GAS PER DAY K-5 McArthur Selected Inte: :vals 7448 1802 14-22 5-23-68 River Hemloc~13,212-12,588 Oil 24 BOPD MCF PUMP SIZE SPM X LENGTH CHOKE SIZE T. P. C. P. WATER % GOR GRAVITY ALLOWABLE EFFECTIVE DATE ' CORRECTED .... Flowing · 1½,, 210 2% 242 31.3' .... Distribution: Orig.: Drilling Section - Dallas cc:- Distr.ict Office Engineering Division - (720) Co-Owner(s) - As Appropriate Regional Office, Well Record File The Above is Correct: $1r GNATUIqE DATE _Di~tr~~~u~ r v i ~o r TITLE PAGE NO~ 6 _(NUMBER AL~ DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL. ) Pdnted U S A 3B-459-3 FOR ATLANTIC RICHFIELD COMPANY JUN ~ 2~ 1973 DIVtSION ~F CIl. AND GAS ANCHORAGE TYP~ OF SURVEY: G~yr°sc°pic Directional Mu!tisbot SURVEY DEPTH: FROM 2300 LEASE:,. Trading Bay Unit 14-22, FIELD: Trading Bay FT. TO , , ~2~,895 WELL NO. K-5 COUNTY/PARISH, Kenai DATE OF SURVEY May 8, 1973 OFFICE: Anchorage, Alaska ....... STATE Alaska JOB NO. SU3-16792 ........ ATLANTIC- RICHFIELD COMPANY TRADING BAY UNIT 14-22 K-5 TRADING BAY ALASKA .... PAGE 1 MAY 7, 1973 SURVEY DATE VERTICAL SECTION CCFPUTED ALONG CLCSURE SPERRY-SUN WELL SURVEYING COMPANY SU3-16792 RECORD OF SURVEY -' TRUE ~EARURED VERTICAL SUB-SEA DEPTH DEPTH DEPTH 39. 39.00 39.00 75. 74099 74099 '100. ' ..... 99.99 99.99 125. 124.99 124.99 -! 50. ..... 1~9, 99 ..... 149.99 [75. 174.99 174.99 . INCLINATION DEG MIN 0 25 0 5 0 20 0 35 0 40 2.00. 199.99 199.99 0 20 2.25. 224099 224.99 0 40 250. 249.99 249.99 0 40 275. 274.99 274.99 300. 299.98 299.98 325. 324.98 324.98 0 40 0 20 0 15 DIRECTION DOG-LEG .... SEVERITY VERTICAL DEG NIN RECTANGULAR COORDINATES DEG/IO0 SECTION N 89 0 W 0.00 4.31 S 85 0 W 1.33 - - 4.29 S 57 0 H 1.05 4.27 S 59 0 E 3oi5 4.5I S 79 0 E 0.92 4.74 0.79 S 0.78 S 0.78 S 0.86 S 0.99 S 1.05 S S 86 0 E 1.35 4.85 S 65 0 E 1.50 5.12 S 81 0 E 0.74 5.35 1.06 S 1.18 S 1.23 S 5.78 E 5.51 E 5.48 E 5.36 E 5.57 E 5.86 E 6.00 E 6.27 E 6.55 E S 85 0 E 0.18 5.56 1.25 S 6.84 E N 53 0 E 1.89 5.58 1.17 S 6.96 E N 16 0 E 0.80 5.52 1.06 S 6.99 E 350. 349.98 375. -'----374.98 400. 399.98 349.98 374.98 399.98 0 35 0 5O 0 45 N 39 0 E 1.46 5.48 _ N 40 0 E 1.00 5.4~ N 49 0 W 4.44 5.11 0.86 S 0.58 S 0.37 S 7.15 E 7.38 E 7.14 E 500. 600. 700. 800. 900. 1000. 499.76 599.17 698.71 798.07 897.09 994.33 499°76 599.17 698.71 798°07 897.09 994.33 3 45 6 15 5 30 6 30 8 0 13 30 S 6 0 E 4.32 10.36 S 64 0 E 5.31 20.50 S 90 0 E 2.73 27.00 N 85 0 E 1.12 33.91 N 87 0 E 1.52 42.80 S 82 0 E 5.84 60.86 6.87 S 11.65 S 11.65 S 10.66 S 9.93 S 13.18 S 7.82 E 17.61 E 27.19 E 38.~7 52.37 75.48 1100. 1200. 1300. 1091.25 1187.50 1282.60 1091.25 11.87.50 1282.60 14 15 15 45 18 0 S 60 0 E 5.29 84.35 25.49 S S 56 0 E 1.82 110.77 40.67 S S 56 0 E 2.24 149.84 57.95 S 96.80 E 119.,30 E ATLANTIC RICHFIELD COMPANY TRADING BAY UNIT 14-22 K-5 TRADING BAY ALASKA PAGE 2 MAT 7~ 1973 SURVEY DATE VERTICAL SECTION COFPUTED ALONG CLCSURE , SPERRY-SUN WELL SURVEYING COMPANY SU3-16792 RECORD OF SURVEY ........ TRUE MEARURED VERT I CAL SUB-S EA DEPTH DEPTH DEPTH 1400. 1376.27 1376.27 1500. 1468.15 1468.15 1600. '~ 1558.41 1558.41 INCLINATION DEG MIN 20 30 23 15 25 30 DIRECTION DOG-LEG ............ RECTANGULAR SEVERITY VERTICAL C6CRDINATES DEG ~,IN DEG/IO0 SECTION _ . S 57 0 E 2.52 174.77 77.02 S S 56 0 E 2077 213.18 99.09 S S 56 0 E 2.24 255.07 123.17 S 176.29 E 207.02 E 242,,7 1 E I-/GO. 18 O0 1900 16q6.50 1646.50 1732.66 1732.66 1817.00 '1817.00 28 15 30 30 32 30 S 55 0 E 2.78 301.31 150.32 S S 57 0 E 2°45 350.49 177.96 S S 57 0 E 2000 402.55 207.22 S 281.48 E 324.05 E 369o 11 E '2000. 1899.41 1899o41 2100. 1979o54 1979.54 2200. 2057.53 2057.53 2300. 2132.71 2132071 2400. 2205.25 2205,.25 2500,, 2276.41 2276041 34 3O 36 45 38 45 41 15 43 30 44 38 S 57 0 E 1.99 457.43 238.07 S S 58 0 E 2.32 515.13 269.78 S S 56 0 E 2.34 576.04 304.78 S S 56 0 E 2.49 640.20 341.65 S S 56 0 E 2.24 707.18 380.14 S S 56 31 E 1.18 '775.39 418.90 S 416.61 E 467.35 E 519.25 E 573.91 E 630.97 E 689.57 E 26000 2344.53 2344.53 2700. 2410.31 2410.31 2800. 2473.80 2473.80 47 4 48 52 50 35 S 55 88 E 2.43 846.50 459.35 S S 54 92 E 1.92 919.92 501.97 S S 55 37 E 1.71 995.22 545.60 S 750.60 E 812.70 E 876.45 E 2900. 30 O0 · 3100. 32 O0 o 3300. 2536.51 2599.10 2661.58 2727.36 2793.97 2860.21 2536.51 2599010 2661.58 2727.36 2793.97 2860.21 51 10 51 15 51 2O 48 52 48 14 48 31 S 54 94 E 0.58 1071.15 589.65 S S 54 78 E 0.22 1147.25 634.04 S S 54 55 E 0.31 1223.55 678.92 S S 54 87 E 2.50 1297.01 721.64 S S 53 92 E 0.93 1370.00 764.91 S S 54 21 E 0o31 1443.37 808.58 S 940.70 E 1004.82 E 1068.71 E 1130.75 1191.50 1252.37 3500. 3700. 2926~25 2992.19 3058.01 2926.25 2992.19 3058.01 48 4C 48 45 48 50 S 54 55 E 0.45 1516.75 851.73 S S 54 32 E 0.29 1590.33 895.35 S S 54 1 E O. B9 1664.13 939.59 S 1313.E2 1375.05 1635.97 ATLANTIC RICHFIELD COMPANY TRADING BAY UNIT 14-22 K-5 TRADING BAY ALASKA ME '- .... TRUE ARURED VERTICAL DEPTH DEPTH 3300. 3124.17 3900. 3190.54 4000. 3256.52 SUB-SEA DEPTH 3124.17 3190.54 3256.52 4100. 3322.24 3322.34 4200. 3388.01 3388.01 4300. 3454.25 3454.25 44.00. 3520.80 3520.80 4500. 3587.60 3587.60 4-6 00o 3655 °46 3655 4700. 3723.34 3723.34 4800. 3792.39 3792.39 4900. 3861.54 3861.54 5000. 3933.07 5100, ..... 4006.20 5200. 4079.69 3933.07 .... 4006.20 4079.69 5300. 4154.49 4154.49 5~'+ 00. 4229.74 4229.74 55 00. 4305.17 4305 . 17 5600. 4380.45 4380.45 5700. 4454.86 44-54.86 5800. 4530.04 4530.04 5900. 4604.77 4604..77 6009. 4679.64 4679.64 6100. 4754.42 4754.42 VERTICAL MAY 7, 1973 SECTION COMPUTED PAGE 3 SURVEY DATE ~L£NG CLCSURE SPERRY-SUN WELL _ SURVEYING COMPANY RECORD OF SURVEY SU3-16792 INCLINATION DEG M IN 48 35 4.8 25 48 43 DIRECTION DEG MIN S 53 83 E S 5369 E S 53 92 E DOG-LEG SE VER I TY DEG/IO0 0.37 0.24 0.41 VERTICAL SECTION 1737.57 1810.87 1884.41 RECTANGULAR COORDINATES 983.26 S 1027.07 S 1070.67 S 1496.93 E 1557.56 E 1618.76 E 48 50 48 57 48 31 S 53 68 S 53 41 S 53 47 E 0.32 0.35 0.43 1958.19 2032.21 2105.72 1114.78 S 1159.44 S 1203.70 S 1679.77 E 1740.53 E 1800.97 E 4.8 17 48 5 47 16 47 15 46 20 46 15 S 53 43 S 53 46 S 54 5 S 54 5 E S 53 64 E S 53 57E 0-23 0.20 0.84 0.01 0.91 0.11 2178.99 2252.01 2324.01 2395.99 2466.90 2537.74 1247.87 1291.86 1334.95 1378. 1420. 1462. 02 47 98 S S S S S S 1861.14 E 1921.16 E 1980.65 E 2040.12 E 2098.69 E 2157.10 E 44 20 43 0 42 42 S 53 80 S 53 24 S 52 53 E 1.93 1 0.46 2606.18 2673.-19 2739.93 1503. 1544. 1585. 73 39 31 2213.87 E 2268.62 E 2322.70 E 41 35 41 12 41 2 S 52 83 S 52 77 S 51 51 1.16 0.38 0.95 2 805.15 2869.89 29 34.70 1624. 1664. 1704. 90 28 83 2375.97 E 2428.77 E 2480.40 E 41 41 41 10 55 15 S 51 70 S 51 98 'S 51 99 0.24 O.B1 0.66 2999.62 3065.42 3130.36 1745. 1785. 1825. 21 75 76 2532.39 E 2585.48 E 2637.90 E 41 39 41 31 41 36 S 52 71 S 52 44 S 51 21 0.53 0.32 0.92 3195.70 32 60.97 3326. o0 1855 lq05 1947 58 72 l& 2691.10 E 2743.85 E 2795.73 £ ATLANTIC RICHFIELD COMPANY IRADING BAY UNIT 14-22 K-5 TRADING BAY ALASKA PAGE MA/' 7, 1973 SURVEY DATE VERTICAL SECTION C£PPUTED ALONG CLCSURE SPERRY-SUN WELL SURVEYING COMPJ~NY ~U3-16792 RECORD OF SURVEY ............... TRUE INCLINATION MEARURED VERTICAL SUB-SEA DEPTH DEPTF: DEPTH DEG MIN 6200. 4830.18 4830.18 40 45 6300. 4907.16 4907.16 39 40 6/~00 o .... 4984.24 4984.24 -39 34 DIRECTION DOG-LEG " - RECTANGUI. AR SEVERI'IY VERTICAL CECRDINATES DEG MIN DEG/IO0 SECTION S 50 45 E 0.93 3391.23 1988.48 S 2846.25 E S 50 3 E 1.17 3454.53 2029.47 S 2895.19 E S 49 85 E 0.25 3517.65 2070.06 S 2944.28 E 6500. 5063.84 5063084 37 15 6600. 5143.85 5143.85 36 52 6700. 5224.34 5224.34 36 24 S 47 85 E 2.62 3577.87 2110023 S 2989.55 E S 46 98 E -- 0.60 3637.64 ..... 2150.66 S 3033.88 E S 45 17 E 1.47 3696.92 2192.42 S 3076.05 E -6800. ~ 5304.69 5304.69 36 32 6900. 5381.40 5381.40 39 54 7000. 5456.11 5456.11 41 40 7100. 5529.44 5529.44 42 50 7200. 5602.75 5602.75 42 51 ?300. 5676.21 5676.21 42 44 S 44 93-E 0.20 3756038 2234.10 S ,3118.54 E S 43 52 E 3.52 3820,51 2280.35 S 3162.99 E S 42 62 E 1.84 3886.99 2328.94 S 3208.36 E S 41 80 E 1.25 3954.97 2379.20 S S 41 51 E 0.32 4022.97 2429.86 S S 42 60 E 0.78 4090.83 2479.49 S 3254.15 E 3299.52 E 3345.80 E 7400. 5750.77 5750.77 41 47 7500. _5825.30 5825.30 41 49 7600. 5899.81 5899.81 41 50 S 39 98 E 1.85 4157.42 2530.05 S S 39 5 E 1.03 4223.96 2581.81 S S 37 9 E 1.28 4290.35 2634.97 S 3389.19 E 3431.23 E 3471.51E 7700.~ 5974.30 5974.30 41 51 7800. 6049.16 6049.16 41 32 '7900. 6124.34 6124.34 41 15 8000. 6199.49 6199.49 41 17 8100. 6273.10 6273.10 42 36 8200. 6345.11 6345011 43 56 S 37 2 E 0.07 4356.75 2688.23 S S 37 9 E 0.32 4422.74 2741.08 S S 35 98 E 0.44 4488.31 2793.99 S S 33 69 E 1.63 4553.56 2848.59 S S 33 54 E 1.32 4620.46 2904.77 S S 33 67 E lo34 4689.07 2962.22 S 3511.69 E 3551.73 E 3591.07 E 3628.11 E 3665.86 E 3704.78 E 8300. 6416.76 6416.76 44 14 8400,, 6488.45 6488045 44 12 8500° 6560.18 6560.18 44 10 S 34 24 E 0035 4758.10 3019.77 S S 37 33 E 2.19 4827.54 3075.05 S S 39 50 E 1.59 4897.13 3128.55 S 3744.19 E 3766.6'~,, E 3~31.31 E ATLANTIC RICHF. IELC CC,~P~NY - - TRADING BAY UNIT 14-22 K-5 TRADING BAY ALASKA ' - - P~GE 5 MAY 7, 1973 SURVEY DATE VERTICAL SECTION CCNPUTED ~LONG CLt]SURE SPERRY-SUN WELL SURVEYING COMPANY S'U3-16792 RECORD OF SURVEY ........ TRUE ..... INCLINAT I~]N DIRECTION DOG-LEG ............... RECTANGULAR NEARURED VERTIC/~L SUB-SEA SEVERITY VERTICAL CCORDINATES DEPTH DEPTH DEPTH DEG MIN DEG MIN DEG/IO0 SECTION 8600. 6631.00 6631.00 44 55 S 36 65 E 2.06 4967.40 3184.88 S 8700. 6702.79 6702.79 44 7 S 36 54 E 0.81 5036.66 3240.55 S '8800."- 6775.63 6775.63 43 15 S 37 59 E 1.14 5104.95 3294.55 S 3873.88 E 3915.68 E 3957.85 E 8900. 6847.94 6847.94 43 41 S 37 60 E 9~00:--- 6919.96 - 6919.96 43 56 S 35 99 E 9100. 6990.67 6990.67 45 0 S 36 42 E 0.43 5173.79 3348.98 S 0.96 ....... 5242.78 ..... 3404.64 S 1.06 5313.11 3461.34 S 4000.37 E _ 4041.79 E 4084.05 E '9200-" : 706t.01 9300. 7130.95 9400. 7200- 57 9500. 7270.14 9600. 7338.97 9700. 7407.21 7061.01 45 18 S 35 35 E 7130.95 45 37 S 34 90 E 7200.57 45 53 S 34 57 E 7270.14 45 55 S 34 89 E 7338.97 46 30 S 34 38 E 7407.21 46 58 S 34 69 E 0.84 5383.65' - 3519.14 S 4125.41 E 0.32 5454.56 3577.33 S 4166.91 E 0.47 5525.70 3636.17 S 4208.03 E 0.38 .5596.97 3694.66 S 4249.73 E 0.84 5668.79 3754.35 S 4290.96 E 0.59 ~ '- 5741.26 3814.11 S 4333.04 E 9800. 7475.27 7475.27 _ __ 9900_,~:--~7542.89-- 7542.89 lO000. 7608.91 7608.91 47 7 S 32 92 E _ 47 27 S 35 77 E 48 41 S 33 56 E 1.19 5813.60 3875.19 S 4373.52 E 2.04 .... 5886.81 ---3934.58 S '-4417.11 E 2.13 5961.05 3996.89 S 4459.04 E 10100.' 7675.33 7675.33 10200. 7744.37 7744.37 10300. 7817.41 7817.41 10~00. 7891.23 7891.23 10500. 7966.26 7966.26 1060D. 8043.59 8043.59 48 23 S 34 89 E 46 20 S 33 5 E 43 5 S 32 3 E 42 25 S 29 34 E 41 23 S 28 10 E 39 21 S 28 79 E 1.19 6035.22 4057.77 S 2.70 6106.55 4118.38 S 3.33 6173.68 4176.27 S __ 4502.44 E 4541.92 E 4578.17 E 1.81 6239.38 4234.94 S 4611.45 E 1.39 6303.38 4293.22 S 4642.66 E 2,16 6365,07 ~348.51 S 4673.70 E 10700. 8119.54 8119.54 10800. 8193.66 8193.66 10900. 8266.55 8266.55 40 35 S 28 16 E 42 10 S 28 4 E 43 12 S 25 79 E 1.40 6428.08 4405.80 S 4704.51 E 1.58 6493.04 4465.04 S 4736.10 E 1.57 6558.72 4526.40 S 4766.44 E ATLANTIC RICHFIELD COMPANY TRADING BAY UNIT I4-22 K-5 TRADING BAY ALASKA PAGE 6 MAY 7, Ig73 SURVEY DATE VERTICAL SECTION CCPPUTED ~LGNG CLOSURE SPERRY-SUN WELL SURVEYING COMPANY ~U3-16792 RECORD OF SURVEY ...... TRUE MEARURED VERTICAL SUB-SEA DEPTH DEPTH DEPTH INCLINATION DEG M IN DIRECTION DOG-LEG ......... RECTANGULAR SEVERITY VERTICAL COORDINATES DEG MIN DEG/IO0 SECTION 11000. 8335.92 8335.92 46 5 S 26 77 E 2.96 11100. 8403.88 8403.88 47 11 S 26 76 E 1.10 11200. - -8471.01 8471.01 47 50 S 25 71 E 1.02 11300. 8536.'48 8536.48 49 '6 S 24 89 E 1.37 11400. 8599.80 8599.80 50 43 S 26 44 E 1.87 11500. 8661.55 8661.55 51 52 S 2S 94 E 2.49 6628.17 4590.42 S 6698.89 4655.62 S 6769.96 --4722.14 S 4799.46 E 4833.07 E 4865.78 E 6842.17 4790.37 S 6916.60 --- 4859.50-S 6993.21 4927.91 S 4898.30 E 4933.11 E 4971.93 E 11600. 8722.31 8722.31 52 35 S 27 76 E 11700. 8785.08 8785.08 51 7 S 28 18 E 11800. 8848.71 8848.71 50 29 S 28 81 E 11900. 8912.03 8912.03 50 43 S 28 29 E 12000. 8975.30 8975.30 50 45 S 26 43 E 12100. 9038.39 9038.39 50 53 S 26 98 E 1.25 7070.13 --- 4997.86 S 5009.54 E 1.46 7145.54 5066.40 S 5046.44 E 1.03 7220.61 5133.65 S 5084.26 E 0.70 7295.65 5201.68 S 1.36 7370.10 5270.85 S 0.72 -7445.03 5339.59 S 5121.17 E 5155.98 E 5191.97 E 12200. 9103.56 9103.56 49 20 S 26 51 E 1.66 12300. 9169.60 9169.60 48 40 S 27 69 E 1.18 12400.-- -9237.95 9237.95 46 53 S 26 57 E 1.99 7518.01 5407.26 S 7590.70 5473.47 S 7660.96 5538.54 S 5226.23 E _ 5261.65 E 5294.74 E 12500. 9~06.47 9306.47 46 45 S 20 93 E 3.93 7728.91 5606.28 S 12600. 9374.15 9374.15 47 24 S 18 87 E 1.66 7796.55 5675.69 S 12700. 9440.31 9440.31 48 35 S 21 46 E 2.08 7866.61 5745.34 S 12800. 9505.08 9505.08 49 38 S 19 82 E 1.49 7937.10 5816.76 S 12895. 9565.08 9565.08 50 50 S 19 86 E 1.26 8005.27 5885.78 S 5321.49 E 5346.00 E 5373.81E 5400.33 E 5426.04 E THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THE TANGENTIAL CR CHORD YETHOD **** HC--RIZCNT~L ~,tSPLACENENT = 8005.27 FEET AT SOLTH 42 [;EG. qO FIN. EASTiTRUE) I I I I t , GO0' I ' i Fom. n Ne P--4 P,~EV 9-30-6T STATE OF ALASKA O~L AND GAS CONSERVATION COMMITI'EE SUBMIT IN DEPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2 NA~ OF OP~I~ATOR * Union Oil Company of California ~A~R~SOFOPS~R 99503 507 W. Northern Lights Blvd.,Anchorage,Alaska 4 L~CATION OF WELL 615'N and l19'W from SE corner, Section 17, T9N, R13W, SM ~ A~i NU~IERICAJ~ CODE 50-133-20092 6 LEASE DESIGNATION AN-D SEIqlAL AIO ADL 18772 7 IF INDI~,.N, ALOI I~:E OR TRIBE NASIE 8 U'NIT,F.~I:LM OR LEASE NA-%IE TradingBay Unit 9 %VELL NO K-5 (14-22) 10 F/E~UD A-ND POOL OR WILDCAT McArthur River Hemlock 11 SEC , T , R, M ~BOTTOM HOI~E OB~EC'TIVE ~ Sec. 22, T9N, R13W, SM 19. PEHNiIT 1~O 68-18 'REPORT TOTAL DEPTH AT END OF MONTH, CH.A.NGES IN HOLE SI~E, CASING A.ND CEMENTING JOBS INCLUDING DEPTH SET A/%VD VOL~ USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS, JUNK IN HOLE A.ND SIDE-TRACKED HOLE ~ ANY 07~ SIGNIFICAi~T CI-I.A/q~ES IN HOI.~ CONDITIONS .~.ra.di.ng Bay Unit K-5 .(14,2.2) - Ap~..i.1 !.9.6.8 Directionally drilled 12~" hole 4454-7593'. Ran Sperry Sun gyro survey in 13-3/8" csg. Directionally drilled 12¼" hole 7593-8298'. Stuck pipe ~ 3280' while pulling turbodrill. Could not free fish loose. Backed off ~ 2406'. Ran jars and bumper sub, screwed into fish and backed off ~ 2740'. Ran wash pipe and washed over fish 2740-3239'. Fish came free. Screwed into and recovered fish. Directionally drilled 12¼" hole 8298-9193'. Stuck pipe ~ 9088' while going in hole. Ran in w/free point and backoff shot and backed off drill pipe ~ 8893'. Ran in and screwed into fish w/jars and bumper sub and knocked fish free. Directionally drilled 12¼" hole 9193-10,498'. Ran DIL,.Sonic and Density from 10,498'. Cemented 9-5/8" casing (47~ P-110 and N-80) ~ 10,434' w/700 sx Class G cement w/l% D-31. Displaced cement w/100 cu. ft. wtr and 4400 cu. ft. mud. CIP ~ 4:05 AM 4-30-68. DidrDt bump plugs, float did not hold. Landed casing in OCT Unihead. Tested blind rams to 3000 psi, drill pipe rams to 2500 psi and Hydril to 2500 psi for 15 min., OK. Cleaned out cement 10,314-10,434'. Drilled out shoe and directionally drilled 8½" hole 10,498-10,508'. * Atlantic Richfield Company sub-operator. DIVISION OF MINES 8, MINE~ AN~O~GE 14 ! hereb~ certl/y that t¥~f~.,regoj~t~e a~d correct " M71/ i lilllll Dist. Drilling Superintendent s~ ,,, ,;il; , ~, =T~ .... D~'~ ~/14/68 ,, , R_E'/ T~llev/ NOTE--Report on tb~s fo~ ~ ~eqmred {or each calendar month. ~ega~d~e~s of the status of oDe~auon% an~ must w~th the Dw~sto~ of M,nes & ~meca~s by the 15th of the succeedm9 ~.th, u~ess othe~se d~ected Perm No P--4 ~ 9-30-6'7 STATE O,F ALASKA OiL AND GAS CONSERVATION COMMITTEE IMONTrHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2 NA/WiE OF OFE~TOR * Union 0il Company of California SUBMIT IH DEPLICATE ADDR~S OF OPm~OR 99503 507 West Northern Lights Blvd. ,Anchorage, "13 Ak. AP1 NL~{ERIC~L CODE 50-133-20092 6 LEASE DESiGNAiION AND SERIAL NO ADL 18772 ,~'7 IF INDI &N, ALOTTEE OR TRIBE NAAIE 8 I/NIT,FA/~%{ OR LEASE Trading Bay Unit g WELL NO K-5 (14-22) lO Fi ~ql !~ AND POOL OR WILDCAT McArthur River Hemlock 4 LO~A~ON ~ WELL 615'N and l19'W from SE corner Section 17, T9N, R13W, SM 11 SEC, T, R, Ii (BOTTOM HOLE OBJECTrV~) Sec. 22, T9N, R13W, 12 PERlVlIT NO 68-18 , REPORT TOTAL DEPTH AT F~qD OF MONTH, CIiA3qGES IN HOLE SIZE, CASING A_N-D CE!VIENTING JOBS INCLUDING DEPTH ~ET A/~ VOLLrNIES USED, PEI%FORATIONS, TESTS A/ND I~ESULTS. FISHING JOBS, JLFNK I2q HOLE A_ND SIDE-/-FL%CKED HOLE AND ANY OTHER SIGNIFICANT CHA_~ES IN HOLIiI CONDITIONS SM Trading Bay Unit K-2 (14-22) - Marc.h, 1968_ Moved rig %57 over conductor %16. Spudded ~ 4:30 AM 3-24-68. Ran 12%" bit and 18" hole opener and drilied'"'""3~5-455,' D'~re-ctionally drilled 12¼" hole 455-2533'. Opened 12%" hole to 18" 455-2531'. Ran 59 its (2436') of 13-3/8" 61% J-55 Buttress casing w/OCT Unihead, Baker float shoe and collar. Cemented 13-3/8" casing ~ 2476' w/float collar ~ 2437'. Cemented w/1175 sx Class G cement w/10% gel and 450 sx Neat cement. Circ 522 sx of cement. CIP ~ 5:00 PM 3-28-68. Floats held OK. Tested pipe rams, CSO and Hydril w/3000 psi for 30 min., OK. Tested casing w/1000 psi for 30 min., OK. Drilled out shoe and directionally drilled 12¼" hole 2533-4454'. * Atlantic Richfield Company sub-operator. RECEIV[D DIVISION OF MtN~S & MINEP, AL~ ANCHORAGE 1~ I hereby certify that .the foregoing Is t~e ~ .... Suner~ntendent ,. ~'lu. ~eaa~an n.',~ 4/5/68 NOTE--Report on th~s form IS reqmred for each calendar month, regardless of the status of operat,ons, and must ~ filed iR duphcate w~th the D~ws~on of Mines & Minerals by the 15th of the succeeding month, unless othe~se d~rected ;rnten OL~ Ceupmly o£ IhrJ,oomt pZetse f:Lud the q,p~ app~cac~ fox' peref. C co FORM SA- I B 125 5M 8/67 MEMORANDUM State of Alaska TO: r' FROM: DATE : SUBJECT: FORM SA- I B 125 5M 8/67 jt MEMORANDUM TO: F FROM: State of Alaska DATE : SUBJECT: . ' Form P--I reverse side) REV 9-30-6"/ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE i APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 1R. TYP]~ OF WORK DRILL [~ 2 NA1VIE OF OPERATOR * Union 0il Company o£ California DEEPEN i---I SUBMIT IN TR4 ~nkTE (Other Instructions PLUG BACK [--] ZONle ZONE API 50-133-20092 5. LEASE DESIGNATION AND SEEIAL NO. ADL 18772 IF INDIAN, ALLO~E OR TI~BE NAME 8 UNIT, FAB// OR LEASE NAME Trading Bay Unit 9 WELL NO K-S (14-22) 3 ADDP~ (~F OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 lO 4 LOCATION OF WELL Atsuriace 61SIN and llg'W from S£ corner Section 17, TgN, R13W, SM Atproposedprod zone 560'N and 550'£ from SW corner Section 22, TgN, R13W, SM 13 DISTANCE IN MILES AND D~ECTION F2OM NEAREST TOWN OR POST OFFICE* 24 miles NW of Kenai FIELD AND POOL, OR WILI)CAT McArthur River Hemlock 11 SEC , T, R, M, (BOTTOM HOLE OBJECTIVE) Sec. 22, TgN, R13W, S.M. 1.2. 14 BOND INFORMATION Statewide TYPE Surety and/or No 15 DISTANCE FROM PROPOSED* LO'CATION TO NEAREST PROPERTY OR LEASE LINE, FT (Also to nearest drlg, unit, if any) Federal Insurance Co. '8011-38-40 16 NO. OF ACR~ IN LEASE 660' ]3840 19 PROPOSED D~TH [ 13,700~T~D, 10,300~TV£ 18 DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT 3700 ' $100,000.00 Amount 1~ NO ACHES ASSIGNED TO THiS WELL 160 20 ROTARY OR CABLE TOOLS Rotary 21 ELEVATIONS (Show whether DF, RT, CR, etc ) 22 APPROX DA;rE WORK WILL STz%-RT* 100' K.B. ~arch 1, 1968 23 PIiOPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRA])E [ SETTING DEPTH QUANTIT! OF CEMENT 18,, 13-3/8,, ' 61# ........ ~J_S5 2500' ~6.00 sx. ~t'//('~t( " 12~" 9-5/8" 47# P-110~ 10~000, -700 sx. N-80 8~" 7" ~9~9 N-80 13,700' 650 sx. ~o~ ~ BOPE 5000 psi double and single Shaffer gate and GK Hydril. Logging program at 10,000' and TD. Supplementary notices will be submitted as required. * Atlantic Richfield Company sub-operator. ** Bottom Hole Location: 170'N and 1210'E from SW corner, Section 22, TgN, R13W, S.M. IN ABOVE SPACE DESCRI]~E PROPOSED PROGRA2Vi If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal ~s to drill or deepen direct_onally, give pertinent data on s~bsurface locatwns and rneasur~ and true vertical depths G~ve blo%vout prey~nt~er prograph 24 I hereby certify that~h~ Foregoing is True ant~ Correct S!GNET)~~'/~~~~~/fOr State o£ use) -- ' DATEFebruary 21, 1968 (This space zce C~DITIONS OF APPROVAL, IF ANY: [ S~IVIPLES AND CORE CHIPS RF_~LrI~ / [] YES ~' NO DIRECTIONAL SURVEY REQUIRED YES [] NO A?~ 50-133-20092 District Land Manage~ OTHER REQUIREMENTS ARCO MID. RIVER ST 2 TO 10295 18 WFU No3 TO 9768 19 9 17 20 t t 14-21 T9N-R 13W 52-~6 JO ./ 15 ARCO Mc ARTHUR ST No I TD ~0255 22 ?MO I~?00~ TVD I0, 500' ATLANTICRICHFIELD COMPANY ALASKA DISTRICT WELL LOCATION MAP K- 5 ('/4-22.) 2OOO
