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Home My WebLink About180-082STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY UNIT D-12RD JBR 03/20/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:3 3-1/2" TJ used. Fail on floor H2S and Methane sensors batteries replaced and passed. Fail on CMV 1 Serviced passed. Accumulator bottles 20 @ 1025 psi precharge. Test Results TEST DATA Rig Rep:Tim Matthews/Roland Operator:Hilcorp Alaska, LLC Operator Rep:Darcy Dunbar/Pat Stewart Rig Owner/Rig No.:Hilcorp 404 PTD#:1800820 DATE:2/8/2025 Type Operation:WRKOV Annular: 250/2500Type Test:WKLY Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopKPS250209200919 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5 MASP: 1933 Sundry No: 325-002 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 11 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 2-7/8:x5-1/2" P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16"P HCR Valves 2 2-1/16"P Kill Line Valves 2 2-1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P2950 Pressure After Closure P1900 200 PSI Attained P22 Full Pressure Attained P107 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2000 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator FP PMeth Gas Detector FP PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P14 #1 Rams P7 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 99 9999 9 9 9 9 FP FP FP Fail on floor H2S and Methane sensors Fail on CMV 1 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?N/A 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): 12,050 See schematic Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 3,090psi 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: Casey Morse Contact Email:CaseyMorse@hilcorp.com Contact Phone:(907) 777-8322 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 Other: Replace ESP 1/18/2025 12,031'2,894' See schematic 8,445' See schematic See schematic 9,374' Perforation Depth MD (ft): 10,729 - 11,715 9,374' 7" 8,958 - 9,871 7,746'9-5/8" 13-3/8"2,537' MD 3,090psi2,403'2,537' Length Size Proposed Pools: See schematic TVD Burst See schematic 5,750psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018729 180-082 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20142-01-00 Hilcorp Alaska, LLC Trading Bay Unit D-12RD 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 McArthur River Hemlock Oil & Middle Kenai G Oil Same 10,189 11,384 9,562 1,933psi 11,904 No Form 10-403 Revised 06/2023 Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 4:14 pm, Jan 03, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.01.03 16:00:07 - 09'00' Noel Nocas (4361) 325-002 10-404 DSR-1/8/25SFD 1/6/2025 Approved application valid for 12 months from date of approval. BOP test to 2500 psi X BJM 1/9/25&': &':IRU-/& Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.01.10 08:20:35 -09'00'01/10/25 RBDMS JSB 011025 ESP Swap RWO Well: Dolly Varden D-12RD Well Name:D-12RD API Number:50-733-20142-01-00 Current Status:Failed ESP Oil Producer Leg:B-1 (SE) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:180-082 First Call Engineer:Casey Morse (907) 777-8322 (o) (603) 205-3780 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:2,033 psi @ 7,000’ TVD 36 day shut in 7/11/24 Max. Potential Surface Pressure: 1933 psi Using 0.1 psi/ft This is a no-flow well 12/09/2024 Last Casing Test: 07/12/2016 at 10,435’ to 1,500 psig Brief Well Summary Dolly Varden D-12RD is a G-zone / Hemlock oil producer. The D-12RD well is currently completed with an ESP that was installed August 2020 and had electrical failure in November 2024. The well is currently shut in. This workover will pull and swap the failed ESP. The goal of this project is to pull the failed ESP and replace with a new ESP completion Pertinent wellbore information: - Max inclination: ~40-degree sail angle from 2600 – 9,200’ MD - Last casing test: 07/12/2016 at 10,435’ to 1,500 psig for 30 minutes on chart - Pertinent History o 12/09/2024: Verified no-flow test o 11/23/24: ESP died after a 4.25yr run (gross fluid ~4300BPD) o 7/29/2024: Acid stimulation to return productivity Attempted to return to production after 1-month shut-down for platform repair project, and well had poor inflow Acid stimulation restored prior rates o Aug 2020 RWO ESP Install Unable to pull tubing out of PBR. Cut @ 10,420’ Ran new ESP with 3-1/2” GL completion and landed ESP above liner top (9,137’) o July 2016 RWO GL Install: Pull ESP Run bit and scraper into 7” liner to tag fish top @ 10,562’ Run 4-1/2” GL completion: swallow previous fish with tubing tail and set new packer @ 10,435’ Acquire casing pressure test immediately after packer set o June 2012 RWO ESP Install ESP Swap RWO Well: Dolly Varden D-12RD Cut tubing and left packer in hole Landed ESP ~10,300’ inside 7” liner above packer o July - Sept 1999 RWO / Add perfs Set straddle packer across H3 and H2 perfs 11,308-11,393’ 4-1/2” GL completion w/ packer @ 10,566’ Add G-zone perfs RWO Procedure: 1. MIRU HAK 404 2. Circulate well: a. Work over fluid will be filtered inlet water (8.4ppg) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Tubing volume = 72bbls d. IA to ESP = 527bbls e. Casing to top perf below ESP = 121bbl 3. Set BPV/TWC, ND tree, NU Hilcorp BOP stack (see attached) a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 4. Pull BPV/TWC 5. BOLDS and unseat hanger 6. POOH with 3-1/2” ESP/GL completion 7. Contingent cleanout: Discuss with OE. If necessary, clean out well to PBTD 8. MU 9-5/8” test packer 9. Set packer at ±9,000’ MD / 7,460’ TVD 10. MIT of 9-5/8” casing to 1900psi (0.25 x 7,460’ TVD = 1,865psi) 11. Contingent acid stimulation / scale squeeze: discuss with OE if necessary a. RU pump and treating lines b. Pressure test all to 250psi low and 2500psi high c. Pump Mutual solvent/Xylene pre flush if required d. Pump acid pill (5-15% concentration HCL, or Oilsafe AR-Synthetic acid) to stimulate perforations e. Displace pill and spot across perfs with FIW keeping treating pressure <2500psi during displacement f. Let acid soak (duration per OE) g. Pump scale squeeze treatment if required and displace with FIW, keeping treating pressure <2500psi during displacement h. RD pumping equipment 12. Pickup ESP/GL completion a. Bottom ESP to be set above 7” liner at ±9,100’ MD b. Dual packer with vent valve set ±400’ MD 13. Set BPV/TWC, ND BOP 14. NU tree and test, pull BPV/TWC 15. RDMO RWO crew and equipment Acid to be pumped through workstring and test packer. -bjm ESP Swap RWO Well: Dolly Varden D-12RD With performing an acid stimulation and cleanout, another No Flow Test will be required or SSSV and vent valve testing will be required. Conduct NFT post-rig after ~10 days of stable production or SSSV and vent valve testing within 5 days of returning well to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current/Proposed Wellhead Diagram (no changes) 4. BOP Drawing 5. 404 Fluid flow diagram 6. RWO Sundry Change Form Revised by: CDM 12/17/24 SCHEMATIC Dolly Varden Platform Well: D-12RD PTD: 180-082 API: 50-733-20142-01 Completion Date: 08/16/20 CASING DETAIL Size WT Grade Conn ID Top (MD) Bottom (MD) 13-3/8” 61 J-55 Buttress 12.515 Surf. 2,537’ 9-5/8” 40 N-80 Buttress 8.835 Surf. 6,192’ 43.5 N-80 Buttress 8.755 6,192’ 8,289’ 47 N-80 Buttress 8.681 8,289’ 9,374’ (KOP) 7” 29 N-80 Buttress 6.184 9,137’ 12,031’ TUBING DETAIL 3-1/2” 9.2 L-80 Hyd 563 2.992 Surf 8,288’ 3-1/2” 9.2 L-80 Hyd 563 2.992 10,420’ 10,540’ 4-1/2” 12.6 L-80 IBT-M 3.958 10,540’ 10,566’ 4-1/2” 12.6 L-80 Buttress 3.958 10,566’ 10,646’ 3-1/2” 9.2 IBT-M 2.992 11,308’ 11,401’ JEWELRY DETAIL NO Depth (MD) Depth (TVD) ID OD Item 41’ 41’ Tubing Hanger, CIW-DCB-ESP, 3" Type H BPV profile A 314’ 314’ 2.812 5.916 SSSV, SLB, TRMAXX-10E, X-Type, 10K, P# 102847949, S# C19S- 0738 B 396’ 396 2.940 8.500 9 5/8" Tripoint Dual ESP Hyd Set Packer C 2,315’ 2,226’ 2.992 5.000 GLM #1 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches D 4,203’ 3,679’ 2.992 5.000 GLM #2 – GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches E 5,461’ 4,682’ 2.992 5.000 GLM #3 – GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches F 6,204’ 5,252’ 2.992 5.000 GLM #4 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches G 6,767’ 5,694’ 2.992 5.000 GLM #5 – GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches H 7,237’ 6,069’ 2.992 5.000 GLM #6 – GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches I 7,767’ 6,495’ 2.992 5.000 GLM #7 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches J 8,200’ 6,834’ 2.992 5.000 GLM #8 – GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches K 8,248’ 6,872’ 2.812 4.470 X-Nipple L 8,288’ 6,903’ N/A 5.130 Bolt on Discharge 8,290’ 6,905’ N/A 5.380 Triple Pump section, Summit 213 stage SJ6500AR 8,361’ 6,961’ N/A 5.130 Intake 8,362’ 6,962’ N/A 5.130 Tandem Seals –BPBSBPB 8,385’ 6,980’ N/A 5.620 Tandem Motors –KMS 500HP/3305V/83A 8,415’ 7,004’ N/A 4.500 Gauge (Zenith) / Centralizer / Anode N 10,435’ 8,688’ 3.000 5.880 7” 26-32# Perm. Isolation Packer 4-1/2” LTC O 10,449’ 8,700’ 2.813 4.450 X-Nipple w/coupling P 10,528’ 8,773’ 4.770 5.990 Non-sealing Overshot 5a 10,546' 8,790’ 3.880 5.250 Baker Locator and seal assembly 5b 10,546' 8,790’ 3.880 5.500 Baker 80-47 PBR (L = 18.4’) 6a 10,565’ 8,807’ 4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566’ 8,808’ 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 7 10,612’ 8,850’ 3.813 5.200 Baker X-nipple 8 10,646' 8,885’ 4.000 5.200 Wireline entry guide (DEFORMED) 9 11,308’ 9,492’ 4.000 5.875 Baker FB-1 permanent packer with mill out extension 10 11,318’ 9,501’ 2.992 3.500 3-1/2" 9.2 lb/ft tubing w/ Mod BTC (11,318’-11,391’) 11 11,392' 9,570’ 3.000 4.000 Baker Locator and G-22 locator seal assembly 12 11,393’ 9,571’ 5.000 4.000 Baker FB-1 permanent packer with seal-bore extension 13 11,401’ 9,578’ 4.000 5.000 Bottom of ½ cut mule shoe in Baker seal bore ext. A, B, C D E P O L N 9 6 10 11 12 K 13 B A TOL @ 9,136’ 5 7 C-J TD = 12,050’; PBTD = 11,904’ MAX HOLE ANGLE = 40q @ 9,300’ RKB = 34’ Rig Floor to TBG Hanger 8 Junk PKR @ 11,894’ DV Collar @ 5,778 X X Junk PKR @ 11,540’ BEWARE! EOT Deformed X Top of tubing @10,420’ X PERFORATION DETAIL Zone Top MD BTM MD Top TVD BTM TVD Date Comments G-2 10,729 10,752 8,958’ 8,979’ 10/01/1999 2-7/8” HC @ 4-8 SPF G-3 10,803 10,832 9,026’ 9,053’ 10/01/1999 2-7/8” HC @ 4 SPF G-4 10,856 10,866 9,075’ 9,084’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF G-3 10,803 10,823 9,026’ 9,045’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF HB-0 11,150 11,160 9,346’ 9,355’ Open HB-0 11,190 11,200 9,383’ 9,392’ Open HB-1 11,225 11,240 9,415’ 9,429’ Open HB-2 11,258 11,268 9,446’ 9,455’ Open HB-2 11,268' 11,308' 9,445' 9,492' 02/05/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-2 11,319' 11,335' 9,502' 9,517' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-3 11,350 11,380 9,531’ 9,559’ Open HB-3 11,351' 11,378' 9,532' 9,556' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-4 11,412 11,432 9,588’ 9,607’ Open HB-4 11,440 11,470 9,614’ 9,642’ Open HB-4 11,485 11,520 9,656’ 9,688’ Open HB-4 11,530 11,580 9,698’ 9,744’ Partially covered w/ Junk Packer at 11540’ HB-5 11,596 11,630 9,759’ 9,791’ Covered w/ Junk and Fill/Debris HB-5 11,690 11,715 9,847’ 9,871’ Covered w/ Junk and Fill/Debris Fish/Fill Information: A.10/9/93: 2-1/8” strip gun 25ft long tag @ 11,581’ DIL. B.10/93: Tag fill @ 11,607’ DIL. C.11/28/89: 16 ft long strip gun w/ bull nose D.RIH w/ 2-1/2” JDC and cannot pass 11,384’. E.2/4/17 – Potential Live Shot Left in Hole – approx. 11,400’ Revised by: CDM 12/17/24 SCHEMATIC Dolly Varden Platform Well: D-12RD PTD: 180-082 API: 50-733-20142-01 Completion Date: 08/16/20 CASING DETAIL Size WT Grade Conn ID Top (MD) Bottom (MD) 13-3/8” 61 J-55 Buttress 12.515 Surf. 2,537’ 9-5/8” 40 N-80 Buttress 8.835 Surf. 6,192’ 43.5 N-80 Buttress 8.755 6,192’ 8,289’ 47 N-80 Buttress 8.681 8,289’ 9,374’ (KOP) 7” 29 N-80 Buttress 6.184 9,137’ 12,031’ TUBING DETAIL 3-1/2” 9.2 L-80 Hyd 563 2.992 Surf ±9,000’ 3-1/2” 9.2 L-80 Hyd 563 2.992 10,420’ 10,540’ 4-1/2” 12.6 L-80 IBT-M 3.958 10,540’ 10,566’ 4-1/2” 12.6 L-80 Buttress 3.958 10,566’ 10,646’ 3-1/2” 9.2 IBT-M 2.992 11,308’ 11,401’ JEWELRY DETAIL NO Depth (MD) Depth (TVD) ID OD Item 41’ 41’ Tubing Hanger, CIW-DCB-ESP, 3" Type H BPV profile A ±350’ ±350’ SSSV B ±400’ ±400’ 9 5/8" Tripoint Dual ESP Hyd Set Packer C ±400’ ±400’ Profile Nipple DGLM #1 EGLM #2 FGLM #3 GGLM #4 HGLM #5 IGLM #6 JGLM #7 KGLM #8 L ±8,900’ 6,872’ X-Nipple M Bolt on Discharge Pump section Intake Tandem Seals Motors ±9,100’ ±7,535’ Gauge (Zenith) / Centralizer / Anode N 10,435’ 8,688’ 3.000 5.880 7” 26-32# Perm. Isolation Packer 4-1/2” LTC O 10,449’ 8,700’ 2.813 4.450 X-Nipple w/coupling P 10,528’ 8,773’ 4.770 5.990 Non-sealing Overshot 5a 10,546' 8,790’ 3.880 5.250 Baker Locator and seal assembly 5b 10,546' 8,790’ 3.880 5.500 Baker 80-47 PBR (L = 18.4’) 6a 10,565’ 8,807’ 4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566’ 8,808’ 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 7 10,612’ 8,850’ 3.813 5.200 Baker X-nipple 8 10,646' 8,885’ 4.000 5.200 Wireline entry guide (DEFORMED) 9 11,308’ 9,492’ 4.000 5.875 Baker FB-1 permanent packer with mill out extension 10 11,318’ 9,501’ 2.992 3.500 3-1/2" 9.2 lb/ft tubing w/ Mod BTC (11,318’-11,391’) 11 11,392' 9,570’ 3.000 4.000 Baker Locator and G-22 locator seal assembly 12 11,393’ 9,571’ 5.000 4.000 Baker FB-1 permanent packer with seal-bore extension 13 11,401’ 9,578’ 4.000 5.000 Bottom of ½ cut mule shoe in Baker seal bore ext. A, B, C D E P O M N 9 6 10 11 12 L 13 B A TOL @ 9,136’ 5 7 D-K TD = 12,050’; PBTD = 11,904’ MAX HOLE ANGLE = 40q @ 9,300’ RKB = 34’ Rig Floor to TBG Hanger 8 Junk PKR @ 11,894’ DV Collar @ 5,778 X X Junk PKR @ 11,540’ BEWARE! EOT Deformed X Top oftubing @10,420’ X PERFORATION DETAIL Zone Top MD BTM MD Top TVD BTM TVD Date Comments G-2 10,729 10,752 8,958’ 8,979’ 10/01/1999 2-7/8” HC @ 4-8 SPF G-3 10,803 10,832 9,026’ 9,053’ 10/01/1999 2-7/8” HC @ 4 SPF G-4 10,856 10,866 9,075’ 9,084’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF G-3 10,803 10,823 9,026’ 9,045’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF HB-0 11,150 11,160 9,346’ 9,355’ Open HB-0 11,190 11,200 9,383’ 9,392’ Open HB-1 11,225 11,240 9,415’ 9,429’ Open HB-2 11,258 11,268 9,446’ 9,455’ Open HB-2 11,268' 11,308' 9,445' 9,492' 02/05/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-2 11,319' 11,335' 9,502' 9,517' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-3 11,350 11,380 9,531’ 9,559’ Open HB-3 11,351' 11,378' 9,532' 9,556' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-4 11,412 11,432 9,588’ 9,607’ Open HB-4 11,440 11,470 9,614’ 9,642’ Open HB-4 11,485 11,520 9,656’ 9,688’ Open HB-4 11,530 11,580 9,698’ 9,744’ Partially covered w/ Junk Packer at 11540’ HB-5 11,596 11,630 9,759’ 9,791’ Covered w/ Junk and Fill/Debris HB-5 11,690 11,715 9,847’ 9,871’ Covered w/ Junk and Fill/Debris Fish/Fill Information: A.10/9/93: 2-1/8” strip gun 25ft long tag @ 11,581’ DIL. B.10/93: Tag fill @ 11,607’ DIL. C.11/28/89: 16 ft long strip gun w/ bull nose D.RIH w/ 2-1/2” JDC and cannot pass 11,384’. E.2/4/17 – Potential Live Shot Left in Hole – approx. 11,400’ Dolly Varden Platform D-12RD Current 03/28/2017 Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 2 1/16 5M EFO, CA slips installed in head Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X bottom, installed in 08/1999 N style lockpins Valve, CIW-F, 2 1/16 5M FE, HWO, AA trim Dolly Varden D-12RD 13 3/8 X 9 5/8 X 3 1/2 Valve, WKM-M, 2 1/16 5M FE, HWO, DD Qty 2 Adapter, CIW-Toadstool, 11 5M Stdd X 3 1/8 5M FE, prepped for 5 ¼ ESP neck, 2- ½ npt, 2- ¼ npt continuous control line ports Tubing hanger, CIW-DCB-ESP, 11 X 3 ½ eue lift and susp, w/ 3'’ type H BPV profile, 5 ¼ EN, 4- 1/4 continuous control line ports, prepped for BIW penetrator Valve, swab, WKM-M, 3 1/8 5M FE, HWO, T-24 Valve, lower master, WKM-M, 3 1/8 5M FE, HWO, T-24 Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 BHTA, Bowen, 3 1/8 5M FE X 3'’ Bowen top Valve, Wing, WKM-M, 3 1/8 5M FE, w/ 15'’ OMNI operator, DD trim Dolly Varden Platform BOP Stack Shaffer SL 13 5/8 5M 2 7/8-5.5 variables Blinds 2.00' Riser 13 5/8 5M FE X 13 5/8 5M FE Spacer spool 13 5/8 5M FE X 11 5M 4.54' 2.83' Choke and Kill valves 2 1/16 5M Mud Cross 3 1/8 5M EFO 4.30'Hydril GK 13 5/8-5000 DSA 3 X 2DSA 3 X 220.40' 1.33' HILCORP ALASKA, LLC Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Trading Bay Unit D-12RD (PTD 180-082)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 1 McLellan, Bryan J (OGC) From:Casey Morse <Casey.Morse@hilcorp.com> Sent:Thursday, January 9, 2025 6:08 AM To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] TBU D-12RD (PTD 180-082) RWO/Acid squeeze sundry Good morning Bryan. We plan to pump that through the tubing / test packer. We will likely use a work string for that portion of the job. Thanks, Casey From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, January 8, 2025 5:20 PM To: Casey Morse <Casey.Morse@hilcorp.com> Subject: [EXTERNAL] TBU D-12RD (PTD 180-082) RWO/Acid squeeze sundry Casey, When pumping the acid and scale squeeze on step 11 of the sundry application, are you planning to pump through a drill string below a squeeze packer? Or will you pump the acid fullbore through the 9-5/8” casing? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. 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DO NOT open links or attachments from UNKNOWN senders. 2024-1204_No-Flow_TBU_D-12RD_ae Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:12/5/2024 P. I. Supervisor FROM:Adam Earl SUBJECT:No Flow Test Petroleum Inspector TBU D-12RD Hilcorp Alaska LLC PTD 1800820 December 4, 2024: I traveled to Dolly Varden Platform to witness a no flow test on D-12RD. Jake Strecker was the Hilcorp representative on the job. The well had been open to bleed for 48hrs before the test. The following table shows test details: Time Pressures 1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 14:25 0.28 / 0.28 / 140 SI 14:40 0.28 / 0.28 / 140 14:55 0.27 / 0.27 / 140 15:10 0.61 / 0.60 / 140 15:25 0.93 / 0.93 / 140 1800+ none Open to flow meter 15:30 1150 none 15:32 900 none 15:40 0.25 / 0.14 / 140 600 none SI 15:55 0.29 / 0.30 / 140 16:10 0.65 / 0.67 / 140 16:25 0.99 / 1.01 / 140 16:40 1.29 / 1.33 / 140 1800+ none Open to flow meter 16:45 1400 none 16:48 1075 none 16:52 800 none 16:55 0.25 / 0.16 / 140 650 none SI 17:10 0.29 / 0.31 / 140 17:25 0.66 / 0.68 / 140 17:40 0.99 / 1.01 / 140 17:55 1.30 / 1.32 / 140 1800+ none Open to flow meter 18:00 1350 none 18:03 850 none 18:15 525 none End Test 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr I did not give approval to flow to production on this one before speaking with the office. Attachments: Certifications 9 9 99 9 99 9 99 9 7HVWGHHPHGD3$66EDVHGRQ FRQVLVWHQWJDVIORZUDWHGHFOLQLQJ EHORZDOORZDEOHOLPLWZLWKLQ PLQXWHV-5HJJ 7HVWGHHPHGD3$66EDVHGRQ FRQVLVWHQWJDVIORZUDWHGHFOLQLQJJ EHORZDOORZDEOHOLPLWZLWKLQ PLQXWHV-5HJJ 15:25 15:32 16:40 16:52 800 1800+ 1800+ 900 17:55 1800+ 18:03 850 James B. Regg Digitally signed by James B. Regg Date: 2024.12.06 10:15:57 -09'00' Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.govDecember 9, 2024 Mr. Dan Marlowe Operations Manager – CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit D-12RD PTD 1800820 Dear Mr. Marlowe: On December 4, 2024, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-12RD located on the Dolly Varden Platform in Cook Inlet. The AOGCC Inspector confirmed that the proper test equipment was rigged up prior to the test as outlined in AOGCC Industry Guidance Bulletin 21-001. The test procedure employed was a 1 hour shut in period to monitor pressure build up followed by a short flow period through the test equipment to an open top tank – repeated two additional times. There was no oil observed during the no-flow test. Each flow period demonstrated gas rates measured at the surface initially exceeding 1800 scf per hour, then declining to below the allowed 900 scf per hour limit within 10 minutes. Trading Bay Unit D-12RD may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion the test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit D-12RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter on the Dolly Varden Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2024.12.09 09:49:35 -09'00' 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 Other: Replaced ESP 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 12,050 feet 11,904 feet true vertical 10,189 feet See schematic feet Effective Depth measured 10,414 feet See schematic feet true vertical 8,668 feet See schematic feet Perforation depth Measured depth 10,729 - 11,715 feet True Vertical depth 8,958 - 9,871 feet Tubing (size, grade, measured and true vertical depth) See schematic 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 G Oil 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: 105 325-002 Sr Pet Eng: 7,020psi Sr Pet Geo: Sr Res Eng: WINJ WAG 43 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Casey Morse Casey.Morse@hilcorp.com 907 777-8322Operations Manager 115 BBL 15% HCl displaced w/ 290 BBL FIW - 1736psi; 25 BBL solvent pre-flush, 130 BBL scale inhibitor displaced w/ 350 BBL FIW - 550 psi measured 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) 141 Gas-Mcf MD 10,729 - 11,715 104 Size 3626 10620 181 1053645 13-3/8" 8,160psi 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 180-082 50-733-20142-01-00 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: ADL0018729 McArthur River / Hemlock Oil & Middle Kenai G Oil Trading Bay Unit D-12RD Plugs Junk measured Length measured TVD Production Liner 9,374 2,894 Casing Structural 7,746 7" 9,374 12,031 8,445 2,537 Conductor Surface Intermediate 3,090psi 3,090psi 5,750psi 2,537 2,403 Burst Collapse 1,540psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:41 am, Mar 27, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.03.26 15:30:18 - 08'00' Dan Marlowe (1267) BJM 5/2/25 DSR-4/2/25 RBDMS JSB 040325 Revised by: JLL 03/10/25 SCHEMATIC Dolly Varden Platform Well: D-12RD PTD: 180-082 API: 50-733-20142-01 Completion Date: 02/11/25 CASING DETAIL Size WT Grade Conn ID Top (MD) Bottom (MD) 13-3/8” 61 J-55 Buttress 12.515 Surf. 2,537’ 9-5/8” 40 N-80 Buttress 8.835 Surf. 6,192’ 43.5 N-80 Buttress 8.755 6,192’ 8,289’ 47 N-80 Buttress 8.681 8,289’ 9,374’ (KOP) 7” 29 N-80 Buttress 6.184 9,137’ 12,031’ TUBING DETAIL 3-1/2” 9.2 L-80 Hyd 563 2.992 Surf 8,981’ 3-1/2” 9.2 L-80 Hyd 563 2.992 10,420’ 10,540’ 4-1/2” 12.6 L-80 IBT-M 3.958 10,540’ 10,566’ 4-1/2” 12.6 L-80 Buttress 3.958 10,566’ 10,646’ 3-1/2” 9.2 IBT-M 2.992 11,308’ 11,401’ JEWELRY DETAIL NO Depth (MD) Depth (TVD)ID OD Item 41’ 41’ Tubing Hanger, CIW-DCB-ESP, 3" Type H BPV profile A 318’ 318’ 2.812 5.380 SSSV, Baker, P/N H824832810ST1, LID9921 B 406’ 406’ 2.940 8.500 Tripoint Dual ESP Hyd Set Packer (30k shear). Vent Valve Packer C 8,935’ 7,410’ 2.810 4.510 GXN-Nipple,2.81 profile/2.75''NoGo D 8,981’ 7,446’ - 5.130 Discharge Sub: Zenith 513X, 3-1/2'' EUE 8rd, LID 0029 8,983’ 7,447’ - 5.380 Pump: 538, SJ7000, 071 Stage (x3) 9,043’ 7,493’ - 5.380 Intake: Sub-Assy, A/R, 513, 416 SS, 9,044’ 7,494’ - 5.130 Upper/Lower Tandem Seals - 513 Series, BPBSBPB 9,067’ 7,512’ - 5.620 Motor: 562 Series, KMS2, 500HP/3305V/93A 9,100’ 7,537’ - 5.620 Anode: Triplate E 10,435’ 8,688’ 3.000 5.880 7” 26-32# Perm. Isolation Packer 4-1/2” LTC F 10,449’ 8,700’ 2.813 4.450 X-Nipple w/coupling G 10,528’ 8,773’ 4.770 5.990 Non-sealing Overshot 5a 10,546' 8,790’ 3.880 5.250 Baker Locator and seal assembly 5b 10,546' 8,790’ 3.880 5.500 Baker 80-47 PBR (L = 18.4’) 6a 10,565’ 8,807’ 4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566’ 8,808’ 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 7 10,612’ 8,850’ 3.813 5.200 Baker X-nipple 8 10,646' 8,885’ 4.000 5.200 Wireline entry guide (DEFORMED) 9 11,308’ 9,492’ 4.000 5.875 Baker FB-1 permanent packer with mill out extension 10 11,318’ 9,501’ 2.992 3.500 3-1/2" 9.2 lb/ft tubing w/ Mod BTC (11,318’-11,391’) 11 11,392' 9,570’ 3.000 4.000 Baker Locator and G-22 locator seal assembly 12 11,393’ 9,571’ 5.000 4.000 Baker FB-1 permanent packer with seal-bore extension 13 11,401’ 9,578’ 4.000 5.000 Bottom of ½ cut mule shoe in Baker seal bore ext. A, B, C D E G F D E 9 6 10 11 12 C 13 B A TOL @ 9,136’ 5 7 TD = 12,050’; PBTD = 11,904’ MAX HOLE ANGLE = 40q @ 9,300’ RKB = 34’ Rig Floor to TBG Hanger 8 Junk PKR @ 11,894’ DV Collar @ 5,778 X X Junk PKR @ 11,540’ BEWARE! EOT Deformed X Top oftubing @10,420’ X Cleanout to 10,414 2/5/25 PERFORATION DETAIL Zone Top MD BTM MD Top TVD BTM TVD Date Comments G-2 10,729 10,752 8,958’ 8,979’ 10/01/1999 2-7/8” HC @ 4-8 SPF G-3 10,803 10,832 9,026’ 9,053’ 10/01/1999 2-7/8” HC @ 4 SPF G-4 10,856 10,866 9,075’ 9,084’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF G-3 10,803 10,823 9,026’ 9,045’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF HB-0 11,150 11,160 9,346’ 9,355’ Open HB-0 11,190 11,200 9,383’ 9,392’ Open HB-1 11,225 11,240 9,415’ 9,429’ Open HB-2 11,258 11,268 9,446’ 9,455’ Open HB-2 11,268' 11,308' 9,445' 9,492' 02/05/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-2 11,319' 11,335' 9,502' 9,517' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-3 11,350 11,380 9,531’ 9,559’ Open HB-3 11,351' 11,378' 9,532' 9,556' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-4 11,412 11,432 9,588’ 9,607’ Open HB-4 11,440 11,470 9,614’ 9,642’ Open HB-4 11,485 11,520 9,656’ 9,688’ Open HB-4 11,530 11,580 9,698’ 9,744’ Partially covered w/ Junk Packer at 11540’ HB-5 11,596 11,630 9,759’ 9,791’ Covered w/ Junk and Fill/Debris HB-5 11,690 11,715 9,847’ 9,871’ Covered w/ Junk and Fill/Debris Fish/Fill Information: A.10/9/93: 2-1/8” strip gun 25ft long tag @ 11,581’ DIL. B.10/93: Tag fill @ 11,607’ DIL. C.11/28/89: 16 ft long strip gun w/ bull nose D.RIH w/ 2-1/2” JDC and cannot pass 11,384’. E.2/4/17 – Potential Live Shot Left in Hole – approx. 11,400’ GAS LIFT MANDRELS STA MD TVD ID OD Type Port Valve Psc Date 1 2,311’ 2,223’ 2.992 5.000 3-1/2'' Slimhole 1''Dummy 2/11/2025 2 4,215’ 3,688’ 2.992 4.520 3-1/2'' Slimhole 1''Dummy 2/11/2025 3 5,475’ 4,693’ 2.992 4.520 3-1/2'' Slimhole 1''Dummy 2/11/2025 4 6,216’ 5,261’ 2.992 4.520 3-1/2'' Slimhole 1''Dummy 2/11/2025 5 6,777’ 5,702’ 2.992 4.520 3-1/2'' Slimhole 1''Dummy 2/11/2025 6 7,245’ 6,075’ 2.992 4.530 3-1/2'' Slimhole 1''Dummy 2/11/2025 7 7,747’ 6,478’ 2.992 4.530 3-1/2'' Slimhole 1''Dummy 2/11/2025 8 8,188’ 6,824’ 2.992 4.520 3-1/2'' Slimhole 1''Dummy 2/11/2025 Page 1/3 Well Name: MRF D-12RD Report Printed: 3/25/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50733201420100 Field Name:McArthur River Field State/Province:ALASKA Permit to Drill (PTD) #:180082 Sundry #:325-002 Rig Name/No:404 Jobs Actual Start Date:1/7/2025 End Date: Report Number 1 Report Start Date 1/22/2025 Report End Date 1/23/2025 Last 24hr Summary Circ Tbg x IA w/ `1100 bbls FIW 2.5 bpm @ 70 psi. Used platform source water /pump and returns to production tank. Circulated until returns clean. Report Number 2 Report Start Date 1/23/2025 Report End Date 1/24/2025 Last 24hr Summary Continue periodic circulating Tbg x IA to displace migrating gas/crude from IA. Injectivity test: 1 bpm @ 200 PSI, 2 BPM @1000 PSI. Report Number 3 Report Start Date 1/24/2025 Report End Date 1/25/2025 Last 24hr Summary Skid rig to well center, Circulate well, clean returns, monitor good, Set BPV, N/D tree, N/U BOPE. Report Number 4 Report Start Date 1/25/2025 Report End Date 1/26/2025 Last 24hr Summary Spot Koomey. Connect BOP hoses and function test BOPE. Continue to spot and RU equipment. Raise and scope derrick. Adjust rig over center of well. Spot and connect pump lines. MU and install 2-7/8" test joint. Set up test equipment and fill lines. Shell test 300/2700 psi. BOP test in progress. Witness waived by S. Sullivan. Report Number 5 Report Start Date 1/26/2025 Report End Date 1/27/2025 Last 24hr Summary Complete BOP test to 250/2500 psi per Sundry. No failures. AOGCC witness waived by S. Sullivan (helicoptors grounded - weather). RD test joint and test equipment. Set up beaver slide. Slip and cut drill line. RU Summit ESP. MU landing Jt. w/ FOSV. Verify Tbg/Csg pressure @ zero and BOLDS. Attempt to pull release packer. Previous up Wt 86k. Hanger free @ 105k. Work up to 160k and packer released. Up Wt 120k. CBU 400 bbls. Final rate 3 bpm @ 400 psi. Crane operations stopped due to high winds. Secure well and Stby. Circulate hourly to fill hole. Static losses ~20 bbls/Hr. Report Number 6 Report Start Date 1/27/2025 Report End Date 1/28/2025 Last 24hr Summary Cont. weather Stby for high winds (42 - 52 MPH) Forward circulate and fill hole hourly. Resume operations @ 13:00 Hrs. Pull hanger to floor @ 110k. LD hanger. POH w/ 3-1/2" ESP completion from 8420' to 780'. Losses to formation ~13 bbls/Hr Report Number 7 Report Start Date 1/28/2025 Report End Date 1/29/2025 Last 24hr Summary Cont. POH w/ completion from 780'. LD ESP assy. Missing 11 of 12 Canon clamps from seal unit and motor. Mobe and RU slickline.. RIH Centralized Magnet. Tag @ 8428' WLM. Continue making centralized magnet runs, working down to 8434' WLM. Runs 1-4 resulted in retrieving 22 partial pieces 1-4" and 1 full length partial clamp. Runs 5-6 came back empty. Lay down Magnet, Pick up 5 Prong Wire Grab Assembly and RIH. Work through 8434' and continue down to 8578'. POH, LD Wire Grab, RIH #8 Magnet Assy, set dn 8580' WLM. POH and recover clamp and debris. Losses to formation ~13 BPH. Report Number 8 Report Start Date 1/29/2025 Report End Date 1/30/2025 Last 24hr Summary Cont. fishing for ESP Canon clamps w/ slickline w/ 4.51" OD magnet and 5.31" OD centralizer. Recovered 1 clamp (#3 of 11) and several pieces on runs 8 and 9 @ 8586'. No recovery on run #10, Re-ran same. Recovered one clamp on run #11 and 12 (4 of 11) and pieces. No recovery on run #13 or 14. MU RIH Wire Grab Run#15, recover clamp (5 of 11). No recovery on run #16 w/ Wire Grab. MU RIH Magnet Run #17. No recovery. Run #18 recover clamp (6 of 11). Run #19 and 20 no recovery. Run #21 in w/Wire Grab. Losses to formation ~12 BPH. Report Number 9 Report Start Date 1/30/2025 Report End Date 1/31/2025 Last 24hr Summary Cont. fishing for ESP Canon clamps w/ slickline w/ 4.51" OD magnet and 5.31" OD centralizer. Run #21 w/Wire Grab, no recovery. Run #22 w/Magnet, recover Clamp(7.5 of 11). Run #23 w/Magnet, no recovery. Run #24 w/Wire Grab, no recovery. Run #25 w/Magnet, recover clamp(8.5 of 11). Run #26 w/Magnet, recover clamp(9 of 11). Run #27 w/Magnet, no recovery. Run #28 w/Wire Grab, no recovery. Run #29 w/Magnet, no recovery. Run #30 w/W ire Spear, break free and work down from 8587' to 8727', recover hinge section. Run #31 w/Magnet, recover 2 hinge sections. Run #32 w/Magnet, recover clamp(10 of 11). Run #33 w/Magnet. Losses to formation ~12 BPH. Report Number 10 Report Start Date 1/31/2025 Report End Date 2/1/2025 Last 24hr Summary Cont fishing for ESP clamps. Continue to recover clamps (11 of 11) and remaining pieces of clamps at 8740' with a 4.51" magnet with Run #33. Run #34 w/Magnet, no recovery. Run #35 w/Wire Grab, partial hinge piece recovery. Run #36 w/Wire Grab, worked down F/8742' T/8770', no recovery. Run #37 w/Magnet, worked down F/8784' T/8814', recover several pieces and hinge section. Run #38 w/Magnet, recover partial hinge and pins. Run #39 w/Magnet, no recovery, C/O OJ - leaking. Run #40 w/Spear, no recovery. Run #41 w/Magnet, no recovery. Run #42 w/Wire Grab, no recovery. Run #43 w/Magnet, no recovery. Run #44 w/Wire Grab, worked down F/8812' T/9105'. Run #45 w/Magnet, no recovery. Current Run #46 w/2-prong Wire Grab. Sent weekly BOP Test notice @ 0630 hrs on 3/31. Losses to formation ~10 BPH Page 2/3 Well Name: MRF D-12RD Report Printed: 3/25/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Report Number 11 Report Start Date 2/1/2025 Report End Date 2/2/2025 Last 24hr Summary Cont. fishing ESP clamp pieces. Run #47 5.50" impression block. Tag @ 9104'. No impression (just the normal chatter on the edges). Run #48 a smaller 2.25" OD wire spear to stir things up. Didn't see much additional PU weight. Depth still 9104'. RBIH w/ the magnet for Run #49. No recovery. Two runs w/ 2.25" pump bailer. Recovered 1.2 gal scale (no metal). Metal marks on bottom of last bailer run. Run #53 2.70" 3 prong wire grab, tag @ 9105', several 200-300# overpulls. No recovery. Run in with 2.20 Wire Prong. Tag @ 9107', work up to 9102' with up to 700# overpull. No recovery. Run in with 4.51 Magnet, tag @ 9108', 1/2" of sludge on btm of Magnet. RIH w/Center Spear, tag @ 9108', no recovery. Make 2 runs with 3" x 8.75' Ball Bottom Bailer, tag @ 9108' initial, lost footage with subsequent runs, total of 4 cups of scale recovered. Make 2 runs with 3" x 8.75' Tyler Bottom Bailer, initial tag @ 9104', lost ground working bail, final tag before POH 9101', 1 gal scale recovered. RIH w/8.5" GR, tag @ 5619', PU and set down hard, POH. Report Number 12 Report Start Date 2/2/2025 Report End Date 2/3/2025 Last 24hr Summary Cont SL Operations, RIH w/8.25" GR. Tag @ 5808' SLM. Unable to work through. RIH w/3" Bailer to 5800' to Straighten out SL Drum due to loose wraps when working GR Run. RD SL. Perform Weekly BOP Test on 2-7/8" and 3-1/2" TJ, Choke Manifold, and Floor Valve to 250 PSI Low/2500 PSI High. Perform Accumulator Test. Test PVT and Gas Alarms. AOGCC Notification made on 1/31/2025 at 06:30 hrs. Make up Clean-Out BHA and RIH T/156'. Single in 2-7/8 PH6 7.9# P110 F/156' T/1306'. MU Scraper Assy. Work Scraper through obstruction at surface and RIH. Cont Singling in w/3-1/2" PH6 12.95# P110 T/1751' Report Number 13 Report Start Date 2/3/2025 Report End Date 2/4/2025 Last 24hr Summary Cont Singling in CO Assy #1 w/3-1/2" PH6 12.95# P110 F/1751' T/7141'. Tag at 7141'. Attempt to work down with and without rotary. Unable to work past. Discuss with town, 9-5/8" Scraper Assy at trouble area 5830' ORKB, decision to POH and LD Scraper Assy. TOH w/3-1/2" PH6 12.95# P110 , Laying down F/7141' T/1899' and racking back F/1899' T/1375'. L/D 9-5/8" Scraper Assy. TIH CO Assy #2 w/3-1/2" PH6 12.95# P110 F/1369' T/1896' out of the Derrick, singling in F/1896' T/6900' MD. AOGCC Notification for MIT sent on 2-3-2025 at 10:30 hrs. Report Number 14 Report Start Date 2/4/2025 Report End Date 2/5/2025 Last 24hr Summary Cont singling in CO Assy #2 w/3-1/2" PH6 12.95# P110 F/6900' T/9011'. RU Power Swivel and Washington Head. Fill hole and establish baseline parameters at 9011'. 36.6 BBL to fill hole, Initial loss rate of 17 BPH, subsided to no losses while reverse circulating down F/9043' T/9169'. TIH w/CO Assy #2, singling in w/3- 1/2" PH6 12.95# P110 F/9169' T/9980'. Reverse circulating every 30' to 120', seeing coarse to fine scale on BU strokes at shakers. Report Number 15 Report Start Date 2/5/2025 Report End Date 2/6/2025 Last 24hr Summary Continue to TIH w/CO Assy #2. Set down at 10370' while circulating. Reverse circulated, washing down to Top of Tubing Stub at 10414'(10424' ORKB). Heavy debris return f/10370' down to TOT. Attempt to establish injectivity rates after cleaning up the hole, unable to maintain rate without pressure buildup. Rig down Power Swivel and Washington Head. Trip out of the hole and L/D #2 CO Assy. On the trip out displacements indicated well is taking fluid again. Calc loss rate ~12 BPH. Report Number 16 Report Start Date 2/6/2025 Report End Date 2/7/2025 Last 24hr Summary Make up 5-3/4” OD Washpipe Extension to 6” OD Shoe. TIH with 2-7/8” to 1249’. MU 7” JS-3 Packer Assy. Single in with 3-1/2” 12.95 PH6 F/1270’ T/ 10370’. Reverse circulate with packer above 7” LT. TIH f/10370’ t/10411’(10420’ ORKB). Tag tubing stub on depth at 10411’. P/U to 10401’ and set test packer(Packer depth 9143'MD). Perform MIT on 9-5/8 casing, packer depth of 9143' MD, to 1900 PSI f/30 minutes. 1950 PSI initial, 1910 PSI 15 min, 1900 PSI 30 min. MIT AOGCC witness waived by Petroleum Inspector Austin McLeod. Perform Injectivity test, establish 1 BPM at 1600 PSI. JSA for pumping acid. P-test lines. Start pumping Acid job, discover leaks on pumping equipment, pump 10 BBL FIW to flush lines. Address surface equipment leaks. Report Number 17 Report Start Date 2/7/2025 Report End Date 2/8/2025 Last 24hr Summary Address surface leaks on mud pump, replacing suction cap seals. Pump 42 BBL 15% HCl, displacing with 80 BBL of FIW at 1 BPM - FCP 1800 PSI. Allow Acid to soak for 5 hours, Simops - Mobilize Marlowe Acid Pump from Steelhead Platform, rig up same. Establish injectivity rates with FIW, 1.25 BPM - ICP 1325 PSI, FCP 1175 PSI. Pump 53 BBL 15% HCl, 1 BPM - ICP 1150 PSI, FCP 1183 PSI. Displace Acid w/200 BBL FIW, 1 BPM - ICP 1165 PSI / FCP 1736 PSI. Unseat Test Packer at 9143', TOH f/10401’ t/5725'. Report Number 18 Report Start Date 2/8/2025 Report End Date 2/9/2025 Last 24hr Summary Continue to TOH and L/D 3-1/2" PH6 f/5890' t/1250'. L/D 7" JS-3 Test Packer. TOH and L/D 2-7/8" PH6 f/1250' t/Surface and L/D Washpipe Extension. RU and Test BOPE, 3-1/2 Test Jt, all tests to 250 PSI Low/2500 PSI High. Perform Accumulator Drawdown Test and test all Gas Alarms. Test witness by AOGCC Petroleum Inspector Kam St.John. RU Pollard SL. RIH w/4.50 Magnet, Tag at 10403' WLM. RIH w/2.0" x 4.5' Centralized Ball Bottom Bailer, observe bobble going through tubing top, correlate to TOT, RIH slick to 10610'. POH, R/D SL. Perform Injectivity Test at 1 BPM, 30 BBL pumped - FCP 1220 PSI - 18 minutes to bleed off. Rig up to run 3-1/2" ESP Completion. Loss Rate of ~15 BPH Report Number 19 Report Start Date 2/9/2025 Report End Date 2/10/2025 Last 24hr Summary Set up Rig Floor and Summit ESP equipment for running ESP Completion. Pick up Summit ESP Motor Assembly. Perform surface checks on MLE and ESP Motor. TIH w/3-1/2" ESP/GL Completion Assembly F/120' T/4950' on 3-1/2 9.2# L-80 H563 Tubing. Install Cannon Clamps every other joint. Testing ESP Cable every 1000'. Current loss rate of 13 BPH. Page 3/3 Well Name: MRF D-12RD Report Printed: 3/25/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Report Number 20 Report Start Date 2/10/2025 Report End Date 2/11/2025 Last 24hr Summary Continue TIH w/3-1/2" ESP/GL Completion Assembly. Splice ESP Cable at 5000'. Make up Tri-Point Dual ESP Hydraulic Set Packer(30K Shear), make up Summit ESP Packer Splice, Chemical Injection Line, and Vent Valve Control Line - Fully functioned at 4000 PSI. Make up SSSV Valve, Control line, tested good - fully function at 2400 PSI. Pick up hanger and begin Summit ESP Cable termination. Tested Summit ESP Cable every 1000'. Total of 168 Cannon Clamps and 21 Stainless Bands. Current Loss Rate of 10 BPH Report Number 21 Report Start Date 2/11/2025 Report End Date 2/12/2025 Last 24hr Summary Landed hanger, Made 2.79” drift run with slickline to 8,919’, dropped ball, set ESP packer, pressure tested tubing to 3800 psi and IA to 1900psi. Could not latch the ball and rod to pull it, bailing fill off the top of plug with 2.25” pump bailer Report Number 22 Report Start Date 2/12/2025 Report End Date 2/13/2025 Last 24hr Summary Slickline runs trying to remove fill off the top of the RHCP plug, no success. Postpone slickline work, begin RD 404 Report Number 23 Report Start Date 2/13/2025 Report End Date 2/14/2025 Last 24hr Summary ND BOPE, Pull riser, skid rig to remove derrick. NU production tree and test tbg hgr void to 5k. Pull BPV and install TWC. Shell test tree to 5000 psi for 15 min- good test. Conduct ESP surface checks, all checks good. Pull TWC and handover well to production. Remove derrick, draw works, A-leg, stage loads. Work boat: Load carrier, base beams, racking matt, draw works and aux eqpt. Transfer crews to steelhead, leave a few guys to clean and finish loading boats for the Steelhead. Report Number 24 Report Start Date 2/14/2025 Report End Date 2/15/2025 Last 24hr Summary RU SL Pressure test lubricator 250/1500psi, pull ball and rod, pull RHCP plug. Turn well over to production, start ESP. Report Number 25 Report Start Date 2/20/2025 Report End Date 2/21/2025 Last 24hr Summary Test SSSV, packer vent, and SSV with AOGCC inspector Austin McLeod Report Number 26 Report Start Date 2/23/2025 Report End Date 2/23/2025 Last 24hr Summary CCI Contract Labor for WE 2/23/2025 on SRU Dolly Cat Stream Report Number 27 Report Start Date 2/28/2025 Report End Date 3/1/2025 Last 24hr Summary PTW/PJSM. Spot and RU pump and tanks. Fill tanks with FIW and heat overnight. Report Number 28 Report Start Date 3/1/2025 Report End Date 3/2/2025 Last 24hr Summary PTW/PJSM. P-test lines to 250/2,500 psi. Pump 25 bbl solvent pre-flush, 130 bbl scale inhibitor, and 350 bbl FIW displacement. FCP 550psi, rig down equipment. 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 Other: ______________________ 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 12,050 feet 11,904 feet true vertical 10,189 feet See schematic feet Effective Depth measured 11,384 feet See schematic feet true vertical 9,562 feet See schematic feet Perforation depth Measured depth 10,729 - 11,715 feet True Vertical depth 8,958 - 9,871 feet Tubing (size, grade, measured and true vertical depth) See schematic 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 G Oil 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: 3,090psi 3,090psi 5,750psi 2,537 2,403 Burst Collapse 1,540psi measured TVD Production Liner 9,374 2,894 Casing Structural 7,746 7" 9,374 12,031 8,445 2,537 Conductor Surface Intermediate 13-3/8" 8,160psi 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 180-082 50-733-20142-01-00 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: ADL0018729 McArthur River / Hemlock Oil & Middle Kenai G Oil Trading Bay Unit D-12RD Plugs Junk measured Length measured 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) 164 Gas-Mcf MD 10,729 - 11,715 105 Size 3941 10415 156 1053332 104 324-412 Sr Pet Eng: 7,020psi Sr Pet Geo: Sr Res Eng: WINJ WAG 35 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 907 777-8503Asset Team Leader Pumped 52 bbls OilSafe AR followed with 80 bbls FIW pressure 225 max Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:11 am, Aug 23, 2024 Digitally signed by Trudi Hallett (1231) DN: cn=Trudi Hallett (1231) Date: 2024.08.23 10:58:38 - 08'00' Trudi Hallett (1231) Revised by: JLL 09/13/20 SCHEMATIC Dolly Varden Platform Well: D-12RD PTD: 180-082 API: 50-733-20142-01 Completion Date: 08/16/20 CASING DETAIL Size WT Grade Conn ID Top (MD) Bottom (MD) 13-3/8 61 J-55 Buttress 12.515 Surf. 2,537 9-5/8 40 N-80 Buttress 8.835 Surf. 6,192 43.5 N-80 Buttress 8.755 6,192 8,289 47 N-80 Buttress 8.681 8,289 9,374 (KOP) 7 29 N-80 Buttress 6.184 9,137 12,031 TUBING DETAIL 3-1/2 9.2 L-80 Hyd 563 2.992 Surf 8,288 3-1/2 9.2 L-80 Hyd 563 2.992 10,420 10,540 4-1/2 12.6 L-80 IBT-M 3.958 10,540 10,566 4-1/2 12.6 L-80 Buttress 3.958 10,566 10,646 3-1/2 9.2 IBT-M 2.992 11,308 11,401 JEWELRY DETAIL NO Depth (MD) Depth (TVD) ID OD Item 41 41 Tubing Hanger, CIW-DCB-ESP, 3" Type H BPV profile A 314 314 2.812 5.916 SSSV, SLB, TRMAXX-10E, X-Type, 10K, P# 102847949, S# C19S- 0738 B 396 396 2.940 8.500 9 5/8" Tripoint Dual ESP Hyd Set Packer C 2,315 2,226 2.992 5.000 GLM #1 GLMAT-1HP, RD-1 Dummys w/ T-1 latches D 4,203 3,679 2.992 5.000 GLM #2 GLMAT-1HP, RD-1 Dummys w/ T-1 latches E 5,461 4,682 2.992 5.000 GLM #3 GLMAT-1HP, RD-1 Dummys w/ T-1 latches F 6,204 5,252 2.992 5.000 GLM #4 GLMAT-1HP, RD-1 Dummys w/ T-1 latches G 6,767 5,694 2.992 5.000 GLM #5 GLMAT-1HP, RD-1 Dummys w/ T-1 latches H 7,237 6,069 2.992 5.000 GLM #6 GLMAT-1HP, RD-1 Dummys w/ T-1 latches I 7,767 6,495 2.992 5.000 GLM #7 GLMAT-1HP, RD-1 Dummys w/ T-1 latches J 8,200 6,834 2.992 5.000 GLM #8 GLMAT-1HP, RD-1 Dummys w/ T-1 latches K 8,248 6,872 2.812 4.470 X-Nipple L 8,288 6,903 N/A 5.130 Bolt on Discharge 8,290 6,905 N/A 5.380 Triple Pump section, Summit 213 stage SJ6500AR 8,361 6,961 N/A 5.130 Intake 8,362 6,962 N/A 5.130 Tandem Seals BPBSBPB 8,385 6,980 N/A 5.620 Tandem Motors KMS 500HP/3305V/83A 8,415 7,004 N/A 4.500 Gauge (Zenith) / Centralizer / Anode N 10,435 8,688 3.000 5.880 7 26-32# Perm. Isolation Packer 4-1/2 LTC O 10,449 8,700 2.813 4.450 X-Nipple w/coupling P 10,528 8,773 4.770 5.990 Non-sealing Overshot 5a 10,546' 8,790 3.880 5.250 Baker Locator and seal assembly 5b 10,546' 8,790 3.880 5.500 Baker 80-47 PBR (L = 18.4) 6a 10,565 8,807 4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566 8,808 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 7 10,612 8,850 3.813 5.200 Baker X-nipple 8 10,646' 8,885 4.000 5.200 Wireline entry guide (DEFORMED) 9 11,308 9,492 4.000 5.875 Baker FB-1 permanent packer with mill out extension 10 11,318 9,501 2.992 3.500 3-1/2" 9.2 lb/ft tubing w/ Mod BTC (11,318-11,391) 11 11,392' 9,570 3.000 4.000 Baker Locator and G-22 locator seal assembly 12 11,393 9,571 5.000 4.000 Baker FB-1 permanent packer with seal-bore extension 13 11,401 9,578 4.000 5.000 Bottom of ½ cut mule shoe in Baker seal bore ext. A, B, C D E P O L N 9 6 10 11 12 K 13 B A TOL @ 9,136 5 7 C-J TD = 12,050; PBTD = 11,904 MAX HOLE ANGLE = 40 @ 9,300 RKB = 34 Rig Floor to TBG Hanger 8 Junk PKR @ 11,894 DV Collar @ 5,778 X X Junk PKR @ 11,540 BEWARE! EOT Deformed X Top of tubing @10,420 X PERFORATION DETAIL Zone Top MD BTM MD Top TVD BTM TVD Date Comments G-2 10,729 10,752 8,958 8,979 10/01/1999 2-7/8 HC @ 4-8 SPF G-3 10,803 10,832 9,026 9,053 10/01/1999 2-7/8 HC @ 4 SPF G-4 10,856 10,866 9,075 9,084 11/28/2000 2-7/8 HC @ 60 o, 6 SPF G-3 10,803 10,823 9,026 9,045 11/28/2000 2-7/8 HC @ 60 o, 6 SPF HB-0 11,150 11,160 9,346 9,355 Open HB-0 11,190 11,200 9,383 9,392 Open HB-1 11,225 11,240 9,415 9,429 Open HB-2 11,258 11,268 9,446 9,455 Open HB-2 11,268' 11,308' 9,445' 9,492' 02/05/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-2 11,319' 11,335' 9,502' 9,517' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-3 11,350 11,380 9,531 9,559 Open HB-3 11,351' 11,378' 9,532' 9,556' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-4 11,412 11,432 9,588 9,607 Open HB-4 11,440 11,470 9,614 9,642 Open HB-4 11,485 11,520 9,656 9,688 Open HB-4 11,530 11,580 9,698 9,744 Partially covered w/ Junk Packer at 11540 HB-5 11,596 11,630 9,759 9,791 Covered w/ Junk and Fill/Debris HB-5 11,690 11,715 9,847 9,871 Covered w/ Junk and Fill/Debris Fish/Fill Information: A.10/9/93: 2-1/8 strip gun 25ft long tag @ 11,581 DIL. B.10/93: Tag fill @ 11,607 DIL. C.11/28/89: 16 ft long strip gun w/ bull nose D.RIH w/ 2-1/2 JDC and cannot pass 11,384. E.2/4/17 Potential Live Shot Left in Hole approx. 11,400 Well Name:MRF D-12RD API #:50733201420100 Field:McArthur River Field Start Date:7/29/2024 Permit #:180082 Sundry #:324-412 End Date:7/29/2024 7/29/2024 Well Operations Summary PTW, JSA with Operators. Ensure tubing and IA bleed down. Confirm vent valve open. Fire Marow triplex pump. Charge and prime up triplex with FIW. PT pump line to wing valve on tree 250/2500 psi. Open well and start pumping FIW to catch fluid. No pump presure noticed until 38 bbls away pressure climbed to 45 psi and rate dropped from 160 gpm to 120 gpm. Continue pumping until tubing volume of 75 bbls reached. Returns to surface at 72 bbls pumped. Shut down. Continue pumping FIW to fluid pack tubing and annulus. Looks like 1:1. 160 bbls pumped for fluid pack. Shut down and line up on acid totes. Pumped 8 totes for a total volume of 52 bbls of Oilsafe AR-Synthetic acid. Tubing on a vac. Line up to FIW to spot acid across ESP pump. Online at 1.5 bbls/min for 80 bbl pump stage. After 42 bbls pumped noticed pump pressure increase to 150 psi. Dropped rate to 1 bbl/min. Pressure gradually climbed and rate dropped. 80 bbls pumped pressure was 225 max at 36 gpm. Acid spotted in place. Close wing valve. Bleed down pump lines and secure acid totest to shipping skid. Shut down triplex pump and secure. Daily Operations: Page 1 of 1 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 Other: ___________________ 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A 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): 12,050 See schematic Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 3,090psi 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 McArthur River Hemlock Oil & Middle Kenai G Oil Same 10,189 11,384 9,562 2,226psi 11,904 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018729 180-082 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20142-01-00 Hilcorp Alaska, LLC Trading Bay Unit D-12RD Length Size Proposed Pools: See schematic TVD Burst See schematic 5,750psi MD 3,090psi2,403'2,537' 7,746'9-5/8" 13-3/8"2,537' 9,374' Perforation Depth MD (ft): 10,729 - 11,715 9,374' 7" 8,958 - 9,871 8/1/2024 12,031'2,894' See schematic 8,445' See schematic See schematic 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 4:23 pm, Jul 17, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.07.17 15:03:08 - 08'00' Dan Marlowe (1267) 324-412 A.Dewhurst 23JUL24 DSR-7/17/24BJM 7/24/24 10-404 CDW 07/18/2024 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.25 08:44:38 -08'00'07/25/24 RBDMS JSB 073024 Acid Well: Dolly Varden D-12RD Well Name:D-12RD API Number:50-733-20142-01-00 Current Status:ESP Oil Producer Leg:B-1 (SE) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:180-082 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:3,196 psi @ 9,700’ TVD 7/11/24 Static BHP Max. Potential Surface Pressure: 2226 psi Using 0.1 psi/ft Brief Well Summary Dolly Varden D-12RD is a G-zone / Hemlock oil producer. It has been a steady producer at ~3500bfpd since it’s current ESP was installed in August of 2020. After a recent production outage at Dolly, the well showed signs of poor inflow. It is possible that packed in scale is to blame. The goal of this project is to remediate downhole damage and return the well to full production Pertinent wellbore information: - Pertinent History o February-2017: 2.5” perf gun tags at 11,495’ MD o March-2017: GL completion pulled. ESP installed GL completion cut at 10,420’ MD. Pull same Run ESP completion o August-2020 ESP installed 8.25” SL gauge ring made it to 9168’ (top 7” liner) 4 subsequent runs to recover cable armor SL drift with 2.84” down tubing to 7848’ MD (top of ESP at the time) Acid Stimulation Procedure 1. RU pump and treating lines 2. Pressure test all to 250psi low and 2000psi high (pump limitation = 2000psi) 3. Pump Mutual solvent/Xylene pre flush if required 4. Pump acid pill (5-15% concentration HCL, or Oilsafe AR-Synthetic acid) to stimulate perforations 5. Displace pill and spot across perfs with FIW keeping treating pressure <2000psi during displacement 6. RD pumping equipment 7. Let acid soak (duration per OE) Attachments: 1. Current Wellbore Schematic (no changes) Revised by: JLL 09/13/20 SCHEMATIC Dolly Varden Platform Well: D-12RD PTD: 180-082 API: 50-733-20142-01 Completion Date: 08/16/20 CASING DETAIL Size WT Grade Conn ID Top (MD) Bottom (MD) 13-3/8” 61 J-55 Buttress 12.515 Surf. 2,537’ 9-5/8” 40 N-80 Buttress 8.835 Surf. 6,192’ 43.5 N-80 Buttress 8.755 6,192’ 8,289’ 47 N-80 Buttress 8.681 8,289’ 9,374’ (KOP) 7” 29 N-80 Buttress 6.184 9,137’ 12,031’ TUBING DETAIL 3-1/2” 9.2 L-80 Hyd 563 2.992 Surf 8,288’ 3-1/2” 9.2 L-80 Hyd 563 2.992 10,420’ 10,540’ 4-1/2” 12.6 L-80 IBT-M 3.958 10,540’ 10,566’ 4-1/2” 12.6 L-80 Buttress 3.958 10,566’ 10,646’ 3-1/2” 9.2 IBT-M 2.992 11,308’ 11,401’ JEWELRY DETAIL NO Depth (MD) Depth (TVD) ID OD Item 41’ 41’ Tubing Hanger, CIW-DCB-ESP, 3" Type H BPV profile A 314’ 314’ 2.812 5.916 SSSV, SLB, TRMAXX-10E, X-Type, 10K, P# 102847949, S# C19S- 0738 B 396’ 396 2.940 8.500 9 5/8" Tripoint Dual ESP Hyd Set Packer C 2,315’ 2,226’ 2.992 5.000 GLM #1 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches D 4,203’ 3,679’ 2.992 5.000 GLM #2 – GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches E 5,461’ 4,682’ 2.992 5.000 GLM #3 – GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches F 6,204’ 5,252’ 2.992 5.000 GLM #4 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches G 6,767’ 5,694’ 2.992 5.000 GLM #5 – GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches H 7,237’ 6,069’ 2.992 5.000 GLM #6 – GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches I 7,767’ 6,495’ 2.992 5.000 GLM #7 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches J 8,200’ 6,834’ 2.992 5.000 GLM #8 – GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches K 8,248’ 6,872’ 2.812 4.470 X-Nipple L 8,288’ 6,903’ N/A 5.130 Bolt on Discharge 8,290’ 6,905’ N/A 5.380 Triple Pump section, Summit 213 stage SJ6500AR 8,361’ 6,961’ N/A 5.130 Intake 8,362’ 6,962’ N/A 5.130 Tandem Seals –BPBSBPB 8,385’ 6,980’ N/A 5.620 Tandem Motors –KMS 500HP/3305V/83A 8,415’ 7,004’ N/A 4.500 Gauge (Zenith) / Centralizer / Anode N 10,435’ 8,688’ 3.000 5.880 7” 26-32# Perm. Isolation Packer 4-1/2” LTC O 10,449’ 8,700’ 2.813 4.450 X-Nipple w/coupling P 10,528’ 8,773’ 4.770 5.990 Non-sealing Overshot 5a 10,546' 8,790’ 3.880 5.250 Baker Locator and seal assembly 5b 10,546' 8,790’ 3.880 5.500 Baker 80-47 PBR (L = 18.4’) 6a 10,565’ 8,807’ 4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566’ 8,808’ 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 7 10,612’ 8,850’ 3.813 5.200 Baker X-nipple 8 10,646' 8,885’ 4.000 5.200 Wireline entry guide (DEFORMED) 9 11,308’ 9,492’ 4.000 5.875 Baker FB-1 permanent packer with mill out extension 10 11,318’ 9,501’ 2.992 3.500 3-1/2" 9.2 lb/ft tubing w/ Mod BTC (11,318’-11,391’) 11 11,392' 9,570’ 3.000 4.000 Baker Locator and G-22 locator seal assembly 12 11,393’ 9,571’ 5.000 4.000 Baker FB-1 permanent packer with seal-bore extension 13 11,401’ 9,578’ 4.000 5.000 Bottom of ½ cut mule shoe in Baker seal bore ext. A, B, C D E P O L N 9 6 10 11 12 K 13 B A TOL @ 9,136’ 5 7 C-J TD = 12,050’; PBTD = 11,904’ MAX HOLE ANGLE = 40q @ 9,300’ RKB = 34’ Rig Floor to TBG Hanger 8 Junk PKR @ 11,894’ DV Collar @ 5,778 X X Junk PKR @ 11,540’ BEWARE! EOT Deformed X Top of tubing @10,420’ X PERFORATION DETAIL Zone Top MD BTM MD Top TVD BTM TVD Date Comments G-2 10,729 10,752 8,958’ 8,979’ 10/01/1999 2-7/8” HC @ 4-8 SPF G-3 10,803 10,832 9,026’ 9,053’ 10/01/1999 2-7/8” HC @ 4 SPF G-4 10,856 10,866 9,075’ 9,084’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF G-3 10,803 10,823 9,026’ 9,045’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF HB-0 11,150 11,160 9,346’ 9,355’ Open HB-0 11,190 11,200 9,383’ 9,392’ Open HB-1 11,225 11,240 9,415’ 9,429’ Open HB-2 11,258 11,268 9,446’ 9,455’ Open HB-2 11,268' 11,308' 9,445' 9,492' 02/05/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-2 11,319' 11,335' 9,502' 9,517' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-3 11,350 11,380 9,531’ 9,559’ Open HB-3 11,351' 11,378' 9,532' 9,556' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-4 11,412 11,432 9,588’ 9,607’ Open HB-4 11,440 11,470 9,614’ 9,642’ Open HB-4 11,485 11,520 9,656’ 9,688’ Open HB-4 11,530 11,580 9,698’ 9,744’ Partially covered w/ Junk Packer at 11540’ HB-5 11,596 11,630 9,759’ 9,791’ Covered w/ Junk and Fill/Debris HB-5 11,690 11,715 9,847’ 9,871’ Covered w/ Junk and Fill/Debris Fish/Fill Information: A.10/9/93: 2-1/8” strip gun 25ft long tag @ 11,581’ DIL. B.10/93: Tag fill @ 11,607’ DIL. C.11/28/89: 16 ft long strip gun w/ bull nose D.RIH w/ 2-1/2” JDC and cannot pass 11,384’. E.2/4/17 – Potential Live Shot Left in Hole – approx. 11,400’ 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 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 12,050 feet 11,904 feet true vertical 10,188 feet 11,540; 11,581; 11,894 feet Effective Depth measured 11,384 feet See schematic feet true vertical 9,562 feet See schematic feet Perforation depth Measured depth 10,729 - 11,715 feet True Vertical depth 8,958 - 9,871 feet Tubing (size, grade, measured and true vertical depth)See schematic (multiple size/grade) 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: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,160psi Daniel E. Marlowe Operations Manager Burst Collapse Karson Kozub kkozub@hilcorp.com Tubing Pressure 1,540psi3,090psi 907 777-8376 5,750psi 2,403 7,746 8,445 2,537 Conductor Surface 7,020psi 3,090psi 13-3/8" 9,374 Size 140 Production Casing Structural Liner 2,894 Length Intermediate N/A Junk 5. Permit to Drill Number: 13 McArthur River Field / Hemlock Oil & Middle Kenai G Oil PoolsN/A measured 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 271 Gas-Mcf 1,268 N/A Oil-Bbl 111 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-073 140 Authorized Signature with date: Authorized Name: 5,362 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 180-082 50-733-20142-01-00 Plugs ADL0018729 Trading Bay Unit D-12RD Other: ESP/GL Completion measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 73 Representative Daily Average Production or Injection Data 2842,182 Casing Pressure 7" 9,374 MD 2,537 12,031 TVD measured true vertical Packer 9-5/8" Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:05 am, Sep 15, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.09.15 09:38:25 -08'00' Dan Marlowe (1267) DSR-9/15/2020 Oil ESP/GL Completion gls 10/23/20 RBDMS HEW 9/15/2020 Revised by: JLL 09/13/20 SCHEMATIC Dolly Varden Platform Well: D-12RD PTD: 180-082 API: 50-733-20142-01 Completion Date: 08/16/20 CASING DETAIL Size WT Grade Conn ID Top (MD) Bottom (MD) 13-3/8” 61 J-55 Buttress 12.515 Surf. 2,537’ 9-5/8”40 N-80 Buttress 8.835 Surf. 6,192’ 43.5 N-80 Buttress 8.755 6,192’ 8,289’ 47 N-80 Buttress 8.681 8,289’ 9,374’ (KOP) 7” 29 N-80 Buttress 6.184 9,137’ 12,031’ TUBING DETAIL 3-1/2” 9.2 L-80 Hyd 563 2.992 Surf 8,288’ 3-1/2” 9.2 L-80 Hyd 563 2.992 10,420’ 10,540’ 4-1/2” 12.6 L-80 IBT-M 3.958 10,540’ 10,566’ 4-1/2” 12.6 L-80 Buttress 3.958 10,566’ 10,646’ 3-1/2” 9.2 IBT-M 2.992 11,308’ 11,401’ JEWELRY DETAIL NO Depth (MD) Depth (TVD) ID OD Item 41’ 41’ Tubing Hanger, CIW-DCB-ESP, 3" Type H BPV profile A 314’ 314’ 2.812 5.916 SSSV, SLB, TRMAXX-10E, X-Type, 10K, P# 102847949, S# C19S- 0738 B 396’ 396 2.940 8.500 9 5/8" Tripoint Dual ESP Hyd Set Packer C 2,315’ 2,226’ 2.992 5.000 GLM #1 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches D 4,203’ 3,679’ 2.992 5.000 GLM #2 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches E 5,461’ 4,682’ 2.992 5.000 GLM #3 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches F 6,204’ 5,252’ 2.992 5.000 GLM #4 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches G 6,767’ 5,694’ 2.992 5.000 GLM #5 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches H 7,237’ 6,069’ 2.992 5.000 GLM #6 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches I 7,767’ 6,495’ 2.992 5.000 GLM #7 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches J 8,200’ 6,834’ 2.992 5.000 GLM #8 –GLMAT-1HP, RD-1 Dummy’s w/ T-1 latches K 8,248’ 6,872’ 2.812 4.470 X-Nipple L 8,288’ 6,903’ N/A 5.130 Bolt on Discharge 8,290’ 6,905’ N/A 5.380 Triple Pump section, Summit 213 stage SJ6500AR 8,361’ 6,961’ N/A 5.130 Intake 8,362’ 6,962’ N/A 5.130 Tandem Seals –BPBSBPB 8,385’ 6,980’ N/A 5.620 Tandem Motors –KMS 500HP/3305V/83A 8,415’ 7,004’ N/A 4.500 Gauge (Zenith) / Centralizer / Anode N 10,435’ 8,688’ 3.000 5.880 7” 26-32# Perm. Isolation Packer 4-1/2” LTC O 10,449’ 8,700’ 2.813 4.450 X-Nipple w/coupling P 10,528’ 8,773’ 4.770 5.990 Non-sealing Overshot 5a 10,546' 8,790’ 3.880 5.250 Baker Locator and seal assembly 5b 10,546' 8,790’ 3.880 5.500 Baker 80-47 PBR (L = 18.4’) 6a 10,565’ 8,807’ 4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566’ 8,808’ 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 7 10,612’ 8,850’ 3.813 5.200 Baker X-nipple 8 10,646' 8,885’ 4.000 5.200 Wireline entry guide (DEFORMED) 9 11,308’ 9,492’ 4.000 5.875 Baker FB-1 permanent packer with mill out extension 10 11,318’ 9,501’ 2.992 3.500 3-1/2" 9.2 lb/ft tubing w/ Mod BTC (11,318’-11,391’) 11 11,392' 9,570’ 3.000 4.000 Baker Locator and G-22 locator seal assembly 12 11,393’ 9,571’ 5.000 4.000 Baker FB-1 permanent packer with seal-bore extension 13 11,401’ 9,578’ 4.000 5.000 Bottom of ½ cut mule shoe in Baker seal bore ext. A, B, C D E P O L N 9 6 10 11 12 K 13 B A TOL @ 9,136’ 5 7 C-J TD = 12,050’; PBTD = 11,904’ MAX HOLE ANGLE = 40q @ 9,300’ RKB = 34’ Rig Floor to TBG Hanger 8 Junk PKR @ 11,894’ DV Collar @ 5,778 X X Junk PKR @ 11,540’ BEWARE! EOT Deformed X Top of tubing @10,420’ X PERFORATION DETAIL Zone Top MD BTM MD Top TVD BTM TVD Date Comments G-2 10,729 10,752 8,958’ 8,979’ 10/01/1999 2-7/8” HC @ 4-8 SPF G-3 10,803 10,832 9,026’ 9,053’ 10/01/1999 2-7/8” HC @ 4 SPF G-4 10,856 10,866 9,075’ 9,084’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF G-3 10,803 10,823 9,026’ 9,045’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF HB-0 11,150 11,160 9,346’ 9,355’ Open HB-0 11,190 11,200 9,383’ 9,392’ Open HB-1 11,225 11,240 9,415’ 9,429’ Open HB-2 11,258 11,268 9,446’ 9,455’ Open HB-2 11,268' 11,308' 9,445' 9,492' 02/05/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-2 11,319' 11,335' 9,502' 9,517' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-3 11,350 11,380 9,531’ 9,559’ Open HB-3 11,351' 11,378' 9,532' 9,556' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-4 11,412 11,432 9,588’ 9,607’ Open HB-4 11,440 11,470 9,614’ 9,642’ Open HB-4 11,485 11,520 9,656’ 9,688’ Open HB-4 11,530 11,580 9,698’ 9,744’ Partially covered w/ Junk Packer at 11540’ HB-5 11,596 11,630 9,759’ 9,791’ Covered w/ Junk and Fill/Debris HB-5 11,690 11,715 9,847’ 9,871’ Covered w/ Junk and Fill/Debris Fish/Fill Information: A.10/9/93: 2-1/8” strip gun 25ft long tag @ 11,581’ DIL. B.10/93: Tag fill @ 11,607’ DIL. C.11/28/89: 16 ft long strip gun w/ bull nose D.RIH w/ 2-1/2” JDC and cannot pass 11,384’. E.2/4/17 – Potential Live Shot Left in Hole – approx. 11,400’ Rig Start Date End Date HAK 404 8/10/20 8/17/20 M/U landing joint, BOLDS, Pull hanger free @ 60k, pull packer f ree @ 120k cont pull dragging 80-100k. Line up on FIW to circulate taking returns to production @ 3 bpm, catch fl uid @ 48 bbls pumped, cont. pumping @ 2.6 BPM, 260 psi, returns @ 323 bbls total pumped, circulate clean w/ 365 bbls total pumped. Pull hanger to floor, strip penetrator & control lines, r/u & pump open SSSV lock open. Bre akoff hanger & l/d landing joint. POOH laying down SSSV and packer 8364'-8006' MD, PU 85K. POOH f/ 8006'-7407' MD, with tubing standing back (lay down short joints/unable to stand back & jewelry) PU 82K. POOH f/ 7407'-5968' MD, with tubing standing back (lay down short joints/unable to stand back & jewelry) PU 69K. Slip and cut 100' of drill line. SIMOPS change out ESP spool. POOH f/ 5968'-5687' MD, with tubing standing back (lay down short joints/unable to stand back & jewelry) PU 65K. POOH f/ 5687'-2850' MD, with tubing standing back (lay down short joints/unable to stand back & jewelry) PU 37K. 08/12/20 - Wednesday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20142-01 180-082 Well Name D-12RD 08/11/20 - Tuesday Prepped & stood mast, strung up drill line, tugger & manrider, prepped & raised mast, installed floor. Cont. dress out floor, r/u PVT system, move gs alarms for visual r/u on D-12, function test BOPE good. M/U 3 1/2" test joint shell test 250/2500 good. Rig up & stage Summit ESP equipment, rig maintenance, derrick inspection, rig up handling equipment for 3-1/2", housekeeping. Test BOPE with 3-1/2" TJ to 250 / 2500 psi for 5 minutes each, charted. Test #1 fail / pass with K-3 valve functioned; test #2 fail / pass CV #3 greased & functioned (during retest test hose failed, C/O); test #3 on super choke bleed off operator error first attempt. AOGCC Rep Jim Regg waived witness on 8-11-20 at 13:56 hrs. Rig down test equipment, blow down lines & pull blanking sub. Rig up & circulate 75 bbls FIW taking returns to well clean tank. Pull BPV. 08/10/20 - Monday Break down, beam package from D-43rd & assemble on D-12rd. Spot rig carrier, A -leg, Draworks on beam package, install walkways on carrier. Adjust carrier & A-leg stands, cle an & clear drill deck. Pin Mast to carrier. R/U wire line equipment on D-12RD, pressure test lubricator to 2500 psi. RIH with EQ prong to 329' WLM. Observe pressure on tubing increase from 130 psi to 180 psi. POOH. RIH with GS tool to 329' WLM. Retrieve K-Valve. POOH & rig down wire line equipment. Rig up circulating lines to well & pump. Circulate FIW down the tubing taking returns from IA to the well clean tank. Stage up to 3 bpm, pump 94 bbls catch pressure at 200 psi. & increased to 1000 psi. Observed crude w/ 321 bbls pumped at 3 bpm, 1000 psi. At 448 bb ls pumped, no returns were observed w/ same rate & pressure. Regained returns w/ 501 bbls pumped, same rate & psi. Observed water back with 581 bbls pumped same rate & psi. Total of 602 bbl pumped. Monitor well, tubing & IA on a vac. Set BPV, nipple down tree, prep wellhead, check lift threads & install Blanking sub. Nippl e up riser, mud cross, double gate, & annular. Begin torque flanges. SIMOPS continue rigging up. POOH laying down SSSV and packer 8364'-8006' MD, PU M/U 3 1/2" test joint shell test 250/2500 good. M/U landing joint, BOLDS, Pull hanger free @ 60k, pull packer f ree @ 120k c . Test BOPE with 3-1/2" TJ to 250 / 2500 psi for 5 minutes each , RIH with GS tool to 329' WLM. Retrieve K-Valve. Rig Start Date End Date HAK 404 8/10/20 8/17/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20142-01 180-082 Well Name D-12RD 08/15/20 - Saturday Perform ESP splice per Summit at 6529'. RIH with 3-1/2" 9.2# L80 Hyd 563 ESP completion with stands out of derrick from 6529'-7991' MD, SO 42K, MEG test at 7991'. Rig up Pollard slick line. Run 2.84" drift to 7848' without issue. POOH and rig down slick line. Pick up packer assembly. Make cable splice through packer. Dress control lines, etc. Meg test good. Function test vent valve at 3000 psi/good. Pick up 2 joints and SSSV, function test good. Pick up 9 joints, a pup joint, XO pup, hanger, & landing joint to 8372' MD, SO 56K. Make ESP splice, chemical injection, & vent line to hanger. Land hanger in wellhead with SO 58K. Hanger not fully seated, pick up enough to take weight & orient hanger. Slack off & land in the wellhead, confirmed. RILDS, and energize seals. Test ESP, good. Drop 1.5" ball & rod. Fill tubing with FIW & rig up to pressure up tubing. Pressure up tubing to 3600 psi to set packer, chart for 30 minutes. Rig up on IA & fill backside. Test IA to 1600 p si for 30 minutes, charted. Rig down test equipment. Test ESP, good. Rig up wireline. RIH to 349' WLM, with 2.2" re trieval tool & set down, POOH. RIH w/ a 2" drift & set down at 349' WLM, POOH. RIH with LIB to 349' WLM, POOH. 08/13/20 - Thursday Service rig and equipment. POOH standing back 3 1/2" tubing and 7 GLM's. Recovered 174 total clamps. PJSM. POOH laying down ESP as per Summit. Clear rig floor and organize equipment. Reload Summit motor lead and flat pack spools. Spot Pollard slick line unit and rig up same. Run #1: 8.25 gauge ring/junk basket to 9168' WLM, tag liner top. POOH basket full large chunks of rubber. Fill hole w / 10 bbls of FIW every hour. Run # 2: 4.5" magnet to 9168' WLM, POOH fully loaded with pieces of metal armor from ES P cable. Run # 3: 4.5" magnet to 9168' WLM, POOH 12-15 pieces of metal armor. Run # 4: 4.5" magnet to 9168' WLM, POOH 5 pieces of metal armor. Run # 5: 4.5" magnet to 9168' WLM. POOH w/ metal shaving only. Rig down wirel ine. Make up 9 5/8" scraper assembly, TIH to 426' MD, work scraper from 307' - 426' MD, TOH laying down asse mbly, clear & clean rig floor. Rig up Summit equipment to pick up ESP assembly. Begin picking up ESP assembly; Motor, Gauge, & Anode. 08/14/20 - Friday Pick up ESP: motor and pump assembly as per Summit. Motor, gas seperator, 3 pumps and ported pressure sub. Finish making up last ESP pump. Make up X-nipple and GLM #8. Me gged good. RIH with 3-1/2" 9.2# L80 Hyd 563 ESP completion with stands out of derrick from 221'-1654' MD, SO 24K, MEG test at 654', 1184', & 1654'. RIH with 3-1/2" 9.2# L80 Hyd 563 ESP completion with stands out of derrick from 1654'-4825' MD, SO 39K, MEG test at 2218', 2961', & 4219'. RIH with 3-1/2" 9.2# L80 Hyd 563 ESP completion with sta nds out of derrick from 4825'-6529' MD, SO 42K, MEG test at 5128', 6063', & 6226'. Perform ESP splice per Summi t Rep. Drop 1.5" ball & rod. F Function test vent valve at 3000 psi/good. POOH laying down ESP as per Summit. Make up 9 5/8" scraper assembly, TIH to 426' MD, work scraper from 307' - 426' MD, TOH Test IA to 1600 psi for 30 minutes, charted. Set packer Test IA Rig Start Date End Date HAK 404 8/10/20 8/17/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20142-01 180-082 Well Name D-12RD Tie up lines on mast. Stow koomey lines. R/D HPU. Remove drive line. Remove bolts on drawworks. N/U tree. Meg test good. Test void at 5000 psi. Test tree at 5000 psi. Pull two-way check valve. Turn well over to production. 08/16/20 - Sunday R/U Pollard wire line. RIH to pull prong but set down at 349'. Make 2 LIB block runs with minimal marks. RIH with braided line brush 2 times and able to move fish up hole 35'. RIH with slick line stretcher and pull fish to surface. Retrieve same (shipping rubber 2.9" OD). RIH to pull prong but hit obstruction at 385'. POOH and run with scratcher and attempt to engage fish to no avail. Service rig while waiting on additional tools. RIH with 2.62 magnet without success. RIH with wireline grabber and able to work fish up to +-100'. Continue working fish up hole with various tools and make recovery of 3/4 of the second plug. RIH with 2" RB tool run #1 to 8242' (no recovery except for rubber from plug). Run #2: 2" RB to 8242' and recovered prong. Run #3: 2.62 magnet with no recovery. Run #4: Retrieve plug. Run #5: Run 2.2" magnet with bolt recovery. Rig down wireline. Lay down landing joint. Set BPV. Prep mast & scope down. Unstring lines & secure blocks. Lay derrick over & prep for removal. Prep doghouse & slide back from carrier. Remove rig fl oor & stage for cleaning. De-energize accumulator & disconnect lines from BOPE. Disconnect kill & choke lines. Be gin nipple down of BOPE. Install bolsters on derrick. Continue nipple down of BOPE, cleaning equipment as di smantled. Test accumulator bottles. Rig down alarm system. Prep wellhead for tree installation. Test ESP, all checks good. O-rings for ESP penetration to adapter swelled and not usable, sourcing more from Summit shop. SIMOPS continue rigging down to move. Continue rigging down for move. Secure lines in derrick for transport. Continue disconnecting accumulator lines and stowing. Wrap up circulating lines. Rig down hydraulic unit. 08/17/20 - Monday drawworks. N/U tree. RIH to pull prong but set down at 349'. . Prep wellhead for tree installation. Test ESP, all checks good. Run #2: 2" RB to 8242' and recovered prong. Run # 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Install SSC-SSSV 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 12,050 feet 11,904 feet true vertical 10,188 feet 11,540; 11,581; 11,894 feet Effective Depth measured 11,384 feet See schematic feet true vertical 9,562 feet See schematic feet Perforation depth Measured depth 10,729 - 11,715 feet True Vertical depth 8,985 - 9,871 feet Tubing (size, grade, measured and true vertical depth)See schematic (multiple size/grade) 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: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD measured true vertical Packer 9-5/8" 7" 9,374 MD 2,537 12,031 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 50 Representative Daily Average Production or Injection Data 2392,795 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 180-082 50-733-20142-01-00 Plugs ADL0018729 Trading Bay Unit D-12RD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-203 294 Authorized Signature with date: Authorized Name: 2,177 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 72 Gas-Mcf 1,280 N/A Oil-Bbl 103 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 116 McArthur River Field / Hemlock Oil & Middle Kenai G Oil PoolsN/A measured 9,374 Size 1,258 Production Casing Structural Liner 2,894 Length 2,537 Conductor Surface 7,020psi 3,090psi 13-3/8" 907 777-8387 5,750psi 2,403 7,746 8,445 Collapse Mark McKinley mmckinley@hilcorp.com Tubing Pressure 1,540psi3,090psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,160psi Daniel E. Marlowe Operations Manager Burst Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:23 pm, Jun 16, 2020 Daniel Marlowe I am approving this document 2020.06.16 14:30:45 -08'00' Daniel Marlowe SFD 6/17/2020RBDMS HEW 6/16/2020 Install SSC-SSSV gls 6/17/20 DSR-6/16/2020 k- valve Revised by: JLL 06/15/20 SCHEMATIC Dolly Varden Platform Well: D-12RD PTD: 180-082 API: 50-733-20142-01 Completion Date: 03/25/17 CASING DETAIL Size WT Grade Conn ID Top (MD) Bottom (MD) 13-3/8” 61 J-55 Buttress 12.515 Surf. 2,537’ 9-5/8”40 N-80 Buttress 8.835 Surf. 6,192’ 43.5 N-80 Buttress 8.755 6,192’ 8,289’ 47 N-80 Buttress 8.681 8,289’ 9,374’ (KOP) 7” 29 N-80 Buttress 6.184 9,137’ 12,031’ TUBING DETAIL 3-1/2” 9.2 L-80 Hyd 563 2.992 Surf 8,252’ 3-1/2” 9.2 L-80 Hyd 563 2.992 10,420’ 10,540’ 4-1/2” 12.6 L-80 IMBT 3.958 10,540’ 10,566’ 4-1/2” 12.6 L-80 Buttress 3.958 10,566’ 10,646’ 3-1/2” 9.2 Mod BTC 2.992 11,308’ 11,401’ JEWELRY DETAIL NO Depth (MD) Depth (TVD) ID OD Item 34’ 34’ CIW-DCB-ESP, 11”X 3 ½” EUE Lift and Susp w/3” Type H BPV profile A 329’ (WLM) 329’ (WLM) SSC-SSSV (K-Valve) 327’ 327’ 2.812 5.310 SSSV –Baker TE-5 B 390’ 390’ 3.000 8.500 Packer –D&L Oil Tools Hydroset II w/ Vent Valve C 2,313’ 2,225’ 2.992 5.750 SFO-2 GLM #1 D 4,206’ 3,681’ 2.992 5.750 SFO-2 GLM #2 E 5,462’ 4,683’ 2.992 5.750 SFO-2 GLM #3 F 6,198’ 5,247’ 2.992 5.750 SFO-2 GLM #4 G 6,770’ 5,696’ 2.992 5.750 SFO-2 GLM #5 H 7,221’ 6,056’ 2.992 5.750 SFO-2 GLM #6 I 7,771’ 6,498’ 2.992 5.750 SFO-2 GLM #7 J 8,168’ 6,809’ 2.992 5.750 SFO-2 GLM #8 K 8,211’ 6,842’ 2.812 4.470 X-Nipple L 8,252’ 6,875’ N/A 5.130 Bolt on Discharge 8,252’ 6,875’ N/A 5.380 Triple Pump section, Summit 198 stage SJ10000AR 8,323’ 6,931’ N/A 5.130 Intake 8,324’ 6,932’ N/A 5.130 Tandem Seals –BPBSL 8,342’ 6,946’ N/A 5.620 Tandem Motors –KMS 1000HP/3600V/165.5A 8,407’ 6,998’ N/A 5.620 Gauge (Zenith) / Centralizer / Anode N 10,435’ 8,688’ 3.000 5.880 7” 26-32# Perm. Isolation Packer 4-1/2” LTC O 10,449’ 8,700’ 2.813 4.450 X-Nipple w/coupling P 10,528’ 8,773’ 4.770 5.990 Non-sealing Overshot 5a 10,546' 8,790’ 3.880 5.250 Baker Locator and seal assembly 5b 10,546' 8,790’ 3.880 5.500 Baker 80-47 PBR (L = 18.4’) 6a 10,565’ 8,807’ 4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566’ 8,808’ 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 7 10,612’ 8,850’ 3.813 5.200 Baker X-nipple 8 10,646' 8,885’ 4.000 5.200 Wireline entry guide (DEFORMED) 9 11,308’ 9,492’ 4.000 5.875 Baker FB-1 permanent packer with mill out extension 10 11,318’ 9,501’ 2.992 3.500 3-1/2" 9.2 lb/ft tubing w/ Mod BTC (11,318’-11,391’) 11 11,392' 9,570’ 3.000 4.000 Baker Locator and G-22 locator seal assembly 12 11,393’ 9,571’ 5.000 4.000 Baker FB-1 permanent packer with seal-bore extension 13 11,401’ 9,578’ 4.000 5.000 Bottom of ½ cut mule shoe in Baker seal bore ext. A, B, C D E P O L N 9 6 10 11 12 K 13 B A TOL @ 9,136’ 5 7 C-J TD = 12,050’; PBTD = 11,904’ MAX HOLE ANGLE = 40q @ 9,300’ RKB = 34’ Rig Floor to TBG Hanger 8 Junk PKR @ 11,894’ DV Collar @ 5,778 X X Junk PKR @ 11,540’ BEWARE! EOT Deformed X Top of tubing @10,420’ X PERFORATION DETAIL Zone Top MD BTM MD Top TVD BTM TVD Date Comments G-2 10,729 10,752 8,958’ 8,979’ 10/01/1999 2-7/8” HC @ 4-8 SPF G-3 10,803 10,832 9,026’ 9,053’ 10/01/1999 2-7/8” HC @ 4 SPF G-4 10,856 10,866 9,075’ 9,084’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF G-3 10,803 10,823 9,026’ 9,045’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF HB-0 11,150 11,160 9,346’ 9,355’ Open HB-0 11,190 11,200 9,383’ 9,392’ Open HB-1 11,225 11,240 9,415’ 9,429’ Open HB-2 11,258 11,268 9,446’ 9,455’ Open HB-2 11,268' 11,308' 9,445' 9,492' 02/05/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-2 11,319' 11,335' 9,502' 9,517' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-3 11,350 11,380 9,531’ 9,559’ Open HB-3 11,351' 11,378' 9,532' 9,556' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-4 11,412 11,432 9,588’ 9,607’ Open HB-4 11,440 11,470 9,614’ 9,642’ Open HB-4 11,485 11,520 9,656’ 9,688’ Open HB-4 11,530 11,580 9,698’ 9,744’ Partially covered w/ Junk Packer at 11540’ HB-5 11,596 11,630 9,759’ 9,791’ Covered w/ Junk and Fill/Debris HB-5 11,690 11,715 9,847’ 9,871’ Covered w/ Junk and Fill/Debris Fish/Fill Information: A.10/9/93: 2-1/8” strip gun 25ft long tag @ 11,581’ DIL. B.10/93: Tag fill @ 11,607’ DIL. C.11/28/89: 16 ft long strip gun w/ bull nose D.RIH w/ 2-1/2” JDC and cannot pass 11,384’. E.2/4/17 – Potential Live Shot Left in Hole – approx. 11,400’ 329’ (WLM)329’ (WLM)SSC-SSSV (K-Valve) K valve installed Rig Start Date End Date Slickline 5/21/20 5/23/20 05/23/2020 - Saturday PJSM, PERMIT. RU RIH W/ 2.8" CENTRALIZER TO 329', POOH. RIH W/ SAME AND 8' STEM TO 324' (ZERO @ CENTRALIZER). T/IA PRESSURE = 150/200. HAVE OPS ADD GAS PRESSURE ABOVE FLAPPER. AT 1300 PSI, FLAPPER REMAINED CLOSED. HAD OPS BLEED PRESSURE FROM IA, AT 120 PSI ON IA, FLAPPER OPENED, DROPPED TO 329'. PRESSURE LUBRICATOR TO 1300 PSI. RIH W/ K-VALVE AND SET AT 329'. OPS BEGIN SET TEST, STAND BY RIH W/ EQUALIZING PRONG TO 329'. W/T. POOH NO SUBTANTIAL CHANGE IN PRESSURE. RIH W/ SAME TO 329'. W/T WHILE PRESSURING UP TBG. STOP PRESSURIZING TBG. MONITOR PRESSURE CHANGE. MINIMAL CHANGE NOTICED. RIH W/ EQAULIZING PRONG (WITHOUT CENTRALIZER) TO 329'. W/T. MINIMAL ORESSURE CHANGE. RIH W 3 1/2" GS TO 329', HAVE OPS INCREASE TP TO 1180 PSI TO OPEN K-VALVE (IAP=690 PSI). CONTINUE PUMPING TO INSURE VALVE IS OPEN TO TP BELOW VALVE. TP REACHES 1300 PSI, LATCH AND PULL K-VALVE. POOH. VALVE SENT TO PWL FOR RECALIBRATION. LAY DOWN AND SECURE WELL FOR THE NIGHT, no activity PJSM, PERMIT. REBUILD XX-LOCK FOR K-VALVE. RU, PT TO 2500 PSI. RIH W/ 2.8 CENTRALIZER AND 8' STEM TO 329' (ZERO @ CENTRALIZER). T/IA PRESSURE = 1300/1300. STAND BY FOR HELICOPTER, ON WEATHER HOLD. K-VALVE ARRIVES. PRESSURES ARE 110-LOW AND 200-HIGH. RIH W/ K-VALVE TO 98, W/T. COULD NOT PASS. POOH. RIH W/ 2.85 GR TO 98', W/T FROM 93'-105'. TAG X NIPPLE @ 329', POOH. RIH W/ 3" BRAIDED LINE BRUSH, W/T THROUGH TROUBLE AREAS, NO ISSUES. POOH. RIH W/ K-VALVE TO 90', COULD NOT PASS. POOH. RIH W/ 2.85 GR, W/ 5 GAL MEOH, W/T THROUGH 93', 159', 210', 226', TAG NIPPLE, POOH. RIH W/ K-VALVE TO 329', W/T. SET VALVE. POOH. STAND BY FOR TEST OF VALVE. VALVE TEST GOOD, RD. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20142-01 180-082 Well Name D-12RD 05/21/2020- Thursday ARRIVE AT PWL SHOP, GATHER TOOLS ARRIVE AT OSK. DEPART OSK. ARRIVE AT DOLLY VARDEN PLATFORM. PJSM AND PERMIT. STAGE EQUIPMENT. RU PT LUBRICATOR TO 2500 PSI, PASS. RIH W/ 2.85 GAUGE RING TO 327' KB, TAG SSSV X NIPPLE. POOH, RIH W/ 3" BRAIDED LINE BRUSH TO 327', BRUSH N-NIPPLE. POOH, RIH W/ K-VALVE TO 326' KB, UNABLE TO SET. POOH, RIH W/ SAME, POOH W/ VALVE AND BOTH X-LINE PINS SHEARED. RIH W/ BL BRUSH, W/T ACROSS X-NIPPLE (1 HR). POOH, RIH W/ K-VALVE, W/T. NO SET, POOH. CALL WL SUPERVISOR. RIH W/ 2.5 CENTRALIZER TO 331' KB, TAG FLAPPER. POOH. RIH W/ 2.5 CENTRALIZER AND 3' STEM TO 328' KB, TAGFLAPPER. POOH. RIH W/ 2.81 CENTRALIZER TO 329' TAG. POOH, TALK TO WL SUPERVISOR AND OPS. STAND BY FOR OPS TO PRESSURE UP ON TBG AND MONITOR IA FOR PRESSURE INCREASE. STAND BY FOR CRANE TO UNLOAD BOAT. LAY DOWN LUBRICATOR AND SECURE WELL FOR THE NIGHT, no activity. 05/22/2020 - Friday 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:3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6. API Number: 7. If perforating:8. W ell Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12,050'11,540; 11,581; 11,894 Casing Collapse Structural Conductor Surface 1,540 psi Intermediate Production 3,090 psi Liner 7,020 psi 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:mmckinley@hilcorp.com Contact Phone: (907) 777-8387 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7,746'9-5/8" 12,031' 8,445' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 5/30/2020 3-1/2", 3-1/2", 4-1/2", 3-1/2" Daniel E. Marlowe See schematic 10,729 - 11,715 9,374' See schematic Tubing Grade:Tubing MD (ft): 8,985 - 9,871 Perforation Depth TVD (ft): 8,160 psi Tubing Size: 2,894' 2,537' 9,374' Perforation Depth MD (ft): 7" 2,403'2,537'13-3/8" 9.2#/ L-80, 9.2#/L-80, 12.6#/L-80, 9.2# TVD Burst 8,252', 10,540', 10,646', 11,401' 5,750 psi MD 3,090 psi 50-733-20142-01-00Anchorage, AK 99503 Hilcorp Alaska, LLC N/A Trading Bay Unit D-12RD 11,904'10,188' 11,384' 9,562' 2,255 psi COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018729 Authorized Signature: Operations Manager Mark McKinley Other: Install SSC-SSSV PRESENT WELL CONDITION SUMMARY Length Size 180-082 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Daniel Marlowe I am approving this document 2020.05.15 10:36:22 -08'00' Daniel Marlowe By Samantha Carlisle at 10:51 am, May 15, 2020 320-203 X DLB 05/15/2020 DSR-5/15/2020 * Witnessed performance test of the K-valve and SVS system within 2 weeks of install. gls 5/18/20 10-404 Comm ion Required? Yes 5/18/2020 dts 5/18/2020 JLC 5/18/2020 RBDMS HEW 5/22/2020 Well Work Prognosis Well Name:D-12RD API Number:50-733-20142-01 Current Status:Oil producer (Gas-Lift/ESP) Leg:Leg #: B-1 (SE) Estimated Start Date:May 30, 2020 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett 777-8332 Permit to Drill Number:180-082 First Call Engineer:Mark McKinley (907) 777-8387(O) (907) 953-2685 (M) Second Call Engineer:Dan Marlowe (907) 283-1329 (O) (907) 398-9904 (M) Current Bottom Hole Pressure:3,000 psi @ 8,527’ TVD (ESP) 0.352 lbs/ft (6.78 ppg) based on SBHP 05/25/16 Maximum Expected BHP:3,151 psi @ 8,958’ TVD (Top perf) 0.352 lbs/ft (6.78 ppg) based on SBHP 05/25/16 Maximum Potential Surface Pressure:2,255 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) Brief Well Summary: The D-12rd well is currently completed with an ESP that failed July 2018 and is currently at minimal production rate on gas-lift. The SCSSSV line is not holding pressure and we cannot open the SCSSSV. This project will install a subsurface controlled subsurface safety valve (SSC-SSSV) in accordance with Guidance Bulletin 10-004. Last Casing Test: 07/12/2016 tested at 10,435’ to 1,500 psig for 30 minutes on chart SSC-SSSV Suitability Evaluation: Well historic parameters Gross Gas 1.4 mmcfd Gross Fluid 2610 BPD FTP 240psig Temp 100F This safety valve will be setup with a trip pressure of ~150 psig. We will hold backpressure on the well with the production choke to maintain a normal FTP of ~240 psig (Header pressure is 100psi). To test the valve we will open the production choke, lowering the FTP and trip the SC-SSSV. To reset the valve the well will be pressured up to above the trip pressure then gradually reopened to the normal operating range. Procedure: 1. MIRU Slick-line, PT lubricator to 2,500 psi Hi 250 Low. 2. RIH and lock open the failed TR-SSSV. 3. RIH and set the subsurface controlled subsurface safety valve. 4. Turn well over to production. 5. Conduct a SVS test within 14 days after stabilized flow. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Halliburton K-valve cut sheet (K-valve) Set K- valve The D-12rd well is currently completed with an ESP that failed July 2018 and is currently at minimal productio n rate on gas-lift. T Revised by: JLL 07/31/18 SCHEMATIC Dolly Varden Platform Well: D-12RD PTD: 180-082 API: 50-733-20142-01 Completion Date: 03/25/17 CASING DETAIL Size WT Grade Conn ID Top (MD)Bottom (MD) 13-3/8”61 J-55 Buttress 12.515 Surf.2,537’ 9-5/8”40 N-80 Buttress 8.835 Surf.6,192’ 43.5 N-80 Buttress 8.755 6,192’8,289’ 47 N-80 Buttress 8.681 8,289’9,374’ (KOP) 7”29 N-80 Buttress 6.184 9,137’12,031’ TUBING DETAIL 3-1/2”9.2 L-80 Hyd 563 2.992 Surf 8,252’ 3-1/2”9.2 L-80 Hyd 563 2.992 10,420’10,540’ 4-1/2”12.6 L-80 IMBT 3.958 10,540’10,566’ 4-1/2”12.6 L-80 Buttress 3.958 10,566’10,646’ 3-1/2”9.2 Mod BTC 2.992 11,308’11,401’ JEWELRY DETAIL NO Depth (MD)Depth (TVD)ID OD Item 34’ 34’ CIW-DCB-ESP, 11”X 3 ½” EUE Lift and Susp w/3” Type H BPV profile A 327’327’2.812 5.310 SSSV – Baker TE-5 B 390’390’3.000 8.500 Packer – D&L Oil Tools Hydroset II w/ Vent Valve C 2,313’2,225’2.992 5.750 SFO-2 GLM #1 D 4,206’3,681’2.992 5.750 SFO-2 GLM #2 E 5,462’4,683’2.992 5.750 SFO-2 GLM #3 F 6,198’5,247’2.992 5.750 SFO-2 GLM #4 G 6,770’5,696’2.992 5.750 SFO-2 GLM #5 H 7,221’6,056’2.992 5.750 SFO-2 GLM #6 I 7,771’6,498’2.992 5.750 SFO-2 GLM #7 J 8,168’6,809’2.992 5.750 SFO-2 GLM #8 K 8,211’6,842’2.812 4.470 X-Nipple L 8,252’6,875’N/A 5.130 Bolt on Discharge 8,252’6,875’N/A 5.380 Triple Pump section, Summit 198 stage SJ10000AR 8,323’6,931’N/A 5.130 Intake 8,324’6,932’N/A 5.130 Tandem Seals – BPBSL 8,342’6,946’N/A 5.620 Tandem Motors – KMS 1000HP/3600V/165.5A 8,407’6,998’N/A 5.620 Gauge (Zenith) / Centralizer / Anode N 10,435’8,688’3.000 5.880 7” 26-32# Perm. Isolation Packer 4-1/2” LTC O 10,449’8,700’2.813 4.450 X-Nipple w/coupling P 10,528’8,773’4.770 5.990 Non-sealing Overshot 5a 10,546'8,790’3.880 5.250 Baker Locator and seal assembly 5b 10,546'8,790’3.880 5.500 Baker 80-47 PBR (L = 18.4’) 6a 10,565’8,807’4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566’8,808’3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 7 10,612’8,850’3.813 5.200 Baker X-nipple 8 10,646'8,885’4.000 5.200 Wireline entry guide (DEFORMED) 9 11,308’9,492’4.000 5.875 Baker FB-1 permanent packer with mill out extension 10 11,318’9,501’2.992 3.500 3-1/2" 9.2 lb/ft tubing w/ Mod BTC (11,318’-11,391’) 11 11,392'9,570’3.000 4.000 Baker Locator and G-22 locator seal assembly 12 11,393’9,571’5.000 4.000 Baker FB-1 permanent packer with seal-bore extension 13 11,401’9,578’4.000 5.000 Bottom of ½ cut mule shoe in Baker seal bore ext. A, B, C D E P O L N 9 6 10 11 12 K 13 B A TOL @ 9,136’ 5 7 C-J TD = 12,050’; PBTD = 11,904’ MAX HOLE ANGLE = 40qq @ 9,300’ RKB = 34’ Rig Floor to TBG Hanger 8 Junk PKR @ 11,894’ DV Collar @ 5,778 X X Junk PKR @ 11,540’ BEWARE! EOT Deformed X Top of tubing @10,420’ X PERFORATION DETAIL Zone Top MD BTM MD Top TVD BTM TVD Date Comments G-2 10,729 10,752 8,958’8,979’10/01/1999 2-7/8” HC @ 4-8 SPF G-3 10,803 10,832 9,026’9,053’10/01/1999 2-7/8” HC @ 4 SPF G-4 10,856 10,866 9,075’9,084’11/28/2000 2-7/8” HC @ 60o, 6 SPF G-3 10,803 10,823 9,026’9,045’11/28/2000 2-7/8” HC @ 60o, 6 SPF HB-0 11,150 11,160 9,346’9,355’Open HB-0 11,190 11,200 9,383’9,392’Open HB-1 11,225 11,240 9,415’9,429’Open HB-2 11,258 11,268 9,446’9,455’Open HB-2 11,268'11,308'9,445'9,492'02/05/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-2 11,319'11,335'9,502'9,517'02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-3 11,350 11,380 9,531’9,559’Open HB-3 11,351'11,378'9,532'9,556'02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-4 11,412 11,432 9,588’9,607’Open HB-4 11,440 11,470 9,614’9,642’Open HB-4 11,485 11,520 9,656’9,688’Open HB-4 11,530 11,580 9,698’9,744’Partially covered w/ Junk Packer at 11540’ HB-5 11,596 11,630 9,759’9,791’Covered w/ Junk and Fill/Debris HB-5 11,690 11,715 9,847’9,871’Covered w/ Junk and Fill/Debris Fish/Fill Information: A.10/9/93: 2-1/8” strip gun 25ft long tag @ 11,581’ DIL. B.10/93: Tag fill @ 11,607’ DIL. C.11/28/89: 16 ft long strip gun w/ bull nose D.RIH w/ 2-1/2” JDC and cannot pass 11,384’. E.2/4/17 – Potential Live Shot Left in Hole – approx. 11,400’ Revised by: JLL 05/15/20 PROPOSED Dolly Varden Platform Well: D-12RD PTD: 180-082 API: 50-733-20142-01 Completion Date: 03/25/17 CASING DETAIL Size WT Grade Conn ID Top (MD) Bottom (MD) 13-3/8” 61 J-55 Buttress 12.515 Surf. 2,537’ 9-5/8”40 N-80 Buttress 8.835 Surf. 6,192’ 43.5 N-80 Buttress 8.755 6,192’ 8,289’ 47 N-80 Buttress 8.681 8,289’ 9,374’ (KOP) 7” 29 N-80 Buttress 6.184 9,137’ 12,031’ TUBING DETAIL 3-1/2” 9.2 L-80 Hyd 563 2.992 Surf 8,252’ 3-1/2” 9.2 L-80 Hyd 563 2.992 10,420’ 10,540’ 4-1/2” 12.6 L-80 IMBT 3.958 10,540’ 10,566’ 4-1/2” 12.6 L-80 Buttress 3.958 10,566’ 10,646’ 3-1/2” 9.2 Mod BTC 2.992 11,308’ 11,401’ JEWELRY DETAIL NO Depth (MD) Depth (TVD) ID OD Item 34’ 34’ CIW-DCB-ESP, 11”X 3 ½” EUE Lift and Susp w/3” Type H BPV profile ±322’ ±322’ SSC-SSSV A 327’ 327’ 2.812 5.310 SSSV –Baker TE-5 B 390’ 390’ 3.000 8.500 Packer –D&L Oil Tools Hydroset II w/ Vent Valve C 2,313’ 2,225’ 2.992 5.750 SFO-2 GLM #1 D 4,206’ 3,681’ 2.992 5.750 SFO-2 GLM #2 E 5,462’ 4,683’ 2.992 5.750 SFO-2 GLM #3 F 6,198’ 5,247’ 2.992 5.750 SFO-2 GLM #4 G 6,770’ 5,696’ 2.992 5.750 SFO-2 GLM #5 H 7,221’ 6,056’ 2.992 5.750 SFO-2 GLM #6 I 7,771’ 6,498’ 2.992 5.750 SFO-2 GLM #7 J 8,168’ 6,809’ 2.992 5.750 SFO-2 GLM #8 K 8,211’ 6,842’ 2.812 4.470 X-Nipple L 8,252’ 6,875’ N/A 5.130 Bolt on Discharge 8,252’ 6,875’ N/A 5.380 Triple Pump section, Summit 198 stage SJ10000AR 8,323’ 6,931’ N/A 5.130 Intake 8,324’ 6,932’ N/A 5.130 Tandem Seals –BPBSL 8,342’ 6,946’ N/A 5.620 Tandem Motors –KMS 1000HP/3600V/165.5A 8,407’ 6,998’ N/A 5.620 Gauge (Zenith) / Centralizer / Anode N 10,435’ 8,688’ 3.000 5.880 7” 26-32# Perm. Isolation Packer 4-1/2” LTC O 10,449’ 8,700’ 2.813 4.450 X-Nipple w/coupling P 10,528’ 8,773’ 4.770 5.990 Non-sealing Overshot 5a 10,546' 8,790’ 3.880 5.250 Baker Locator and seal assembly 5b 10,546' 8,790’ 3.880 5.500 Baker 80-47 PBR (L = 18.4’) 6a 10,565’ 8,807’ 4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566’ 8,808’ 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 7 10,612’ 8,850’ 3.813 5.200 Baker X-nipple 8 10,646' 8,885’ 4.000 5.200 Wireline entry guide (DEFORMED) 9 11,308’ 9,492’ 4.000 5.875 Baker FB-1 permanent packer with mill out extension 10 11,318’ 9,501’ 2.992 3.500 3-1/2" 9.2 lb/ft tubing w/ Mod BTC (11,318’-11,391’) 11 11,392' 9,570’ 3.000 4.000 Baker Locator and G-22 locator seal assembly 12 11,393’ 9,571’ 5.000 4.000 Baker FB-1 permanent packer with seal-bore extension 13 11,401’ 9,578’ 4.000 5.000 Bottom of ½ cut mule shoe in Baker seal bore ext. A, B, C D E P O L N 9 6 10 11 12 K 13 B A TOL @ 9,136’ 5 7 C-J TD = 12,050’; PBTD = 11,904’MAX HOLE ANGLE = 40q @ 9,300’ RKB = 34’ Rig Floor to TBG Hanger 8 Junk PKR @ 11,894’ DV Collar @ 5,778 X X Junk PKR @ 11,540’ BEWARE! EOT Deformed X Top of tubing @10,420’ X PERFORATION DETAIL Zone Top MD BTM MD Top TVD BTM TVD Date Comments G-2 10,729 10,752 8,958’ 8,979’ 10/01/1999 2-7/8” HC @ 4-8 SPF G-3 10,803 10,832 9,026’ 9,053’ 10/01/1999 2-7/8” HC @ 4 SPF G-4 10,856 10,866 9,075’ 9,084’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF G-3 10,803 10,823 9,026’ 9,045’ 11/28/2000 2-7/8” HC @ 60 o, 6 SPF HB-0 11,150 11,160 9,346’ 9,355’ Open HB-0 11,190 11,200 9,383’ 9,392’ Open HB-1 11,225 11,240 9,415’ 9,429’ Open HB-2 11,258 11,268 9,446’ 9,455’ Open HB-2 11,268' 11,308' 9,445' 9,492' 02/05/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-2 11,319' 11,335' 9,502' 9,517' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-3 11,350 11,380 9,531’ 9,559’ Open HB-3 11,351' 11,378' 9,532' 9,556' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB-4 11,412 11,432 9,588’ 9,607’ Open HB-4 11,440 11,470 9,614’ 9,642’ Open HB-4 11,485 11,520 9,656’ 9,688’ Open HB-4 11,530 11,580 9,698’ 9,744’ Partially covered w/ Junk Packer at 11540’ HB-5 11,596 11,630 9,759’ 9,791’ Covered w/ Junk and Fill/Debris HB-5 11,690 11,715 9,847’ 9,871’ Covered w/ Junk and Fill/Debris Fish/Fill Information: A.10/9/93: 2-1/8” strip gun 25ft long tag @ 11,581’ DIL. B.10/93: Tag fill @ 11,607’ DIL. C.11/28/89: 16 ft long strip gun w/ bull nose D.RIH w/ 2-1/2” JDC and cannot pass 11,384’. E.2/4/17 – Potential Live Shot Left in Hole – approx. 11,400’ K-valve install Completion Solutions 10-30 Storm Choke® K Safety Valves Storm Choke® K safety valves are ambient-type, wireline- retrievable valves with the largest flow area of all direct- controlled safety valves on the market. They are ideally suited for high-volume, low-pressure wells. These valves are normally closed and pre-charged with a set dome pressure. When the well flowing pressure drops below the predetermined dome-pressure charge because of a rupture in flowline or surface equipment, the dome pressure and main valve spring close the valve, shutting in the well below the earth’s surface. This valve contains a detent mechanism to provide a positive snap-action closure at the predetermined disaster rate of the valve. Its bore is not restricted by a flow bean. The valve is designed to resist pressure surges. A metal-to-metal poppet valve and seat comprise the valve’s primary closure mechanism. The K valve is ideal for protecting wells with declining bottomhole pressure. This valve closes in situations where a pressure decline would not activate a valve with a flow bean. To reopen the valve, the operator must fully equalize pressure either by applying pressure in the tubing from the surface or by an equalizing prong. The valve will reopen when the tubing pressure acting on the internal piston area overcomes the dome charge. Applications »Wells with declining bottomhole pressure »High-volume, low-pressure wells »Wells with no provisions for surface-controlled valves Features »Poppet closure »Large ports with capacity for high-volume wells »Designed to resist pressure surges Benefits »Installed and retrieved under pressure using wireline methods »Adaptable to any Halliburton lock mandrel »Can be located in any Halliburton landing nipple »Can also be located on large bore intervention packers Storm Choke® K Safety ValveHAL39265 Completion Solutions | Subsurface Safety Equipment 10-31 Ambient Safety Valves (Poppet-Type Closure) Nominal Size Compatible Lock Mandrel OD ID Top Thread (Box) in.mm in.mm in.mm 1 1/2 38.10 1.500 X 1.463 37.16 0.78 19.81 1 1/8-16 UN 2 50.80 1.875 S 1.750 44.45 0.650 16.51 1 3/16-14 UNS 1.875 X 1.750 44.45 0.970 24.64 1 3/8 -14 UN 2 1/2 63.50 2.313 S 2.170 55.12 1.250 31.75 1 3/16-12 UN 2.313 X 2.160 54.86 1.380 32.51 1 3/4-12 UN 3 1/2 88.90 2.750 X 2.500 63.50 1.620 41.15 2 1/4-12 SLB 4 101.60 3.313 X 3.120 79.25 2.120 53.85 2 3/4-12 SLB 4 1/2 114.30 3.813 X 3.500 88.90 2.250 to 2.41 57.15 to 61.21 3 1/16-12 SLB 5 127.00 4.125 X 3.880 98.55 2.41 61.21 3 1/4-12.5 SLB 5 1/2 139.70 4.562 X 4.440 112.78 2.880 73.15 4-12 SLB 7 177.8 5.750 X 5.400 137.16 3.50 88.90 4 15/16-8 SLB Ordering Information Specify: nipple bore and lock profile, service (standard, %H2S, %CO2, amines), pressure and temperature requirements, flowing pressure at closing rate, necessity of API monogramming or other certification requirements. Part Number Prefixes: 22KX, KS: poppet-closure THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Dan E. Marlowe Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.o[osko.gov Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G and Hemlock Oil Pool, TBU D-12RD Permit to Drill Number: 180-082 Sundry Number: 320-073 Dear Mr. Marlowe: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, jh `�[� J y rice Chair DATED this `J day of February, 2020. 1ABDMSt-'/ FEB 14 2020 ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ACG io s utdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP/GL Completion ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: - 'J Hilcorp Alaska, LLC Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ 180-082 - 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: r Anchorage, AK 99503 50-733-20142-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No El Trading Bay Unit D-12RD 9. Property Designation (Lease Number): 10. Field/Pool(s): • ADL0018729 McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,050 10,188 11,384 9,562 2,255 psi 11,904 11,540; 11,581; 11,894 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,537' 13-3/8" 2,537' 2,403' 3,090 psi 1,540 psi Intermediate Production 9,374' 9-5/8" 9,374' 7,746' 5,750 psi 3,090 psi Liner 2,894' 7" 12,031' 8,445' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,729-11,715 8,958-9,871 3-1/2" 9.2#/L-80 8,252 3-1/2" 9.2# / L-80 10,540 4-1/2" 12.6# / L-80 10,646 3-1/2" 9.2# 11,401 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ff): See Schematic See Schematic 12. Attachments: Proposal Summary ❑✓ Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Straligraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/28/2020 OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Dan Marlowe Contact Name: Mark McKinley Authorized Title: Operatin Manager g 51 Contact Email: marrickinley2hilcorp.com Contact Phone: (907)777-8387 y Authorized Sig ur ol Date: COMMISSI N USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 320 -073 HA Plug Integrity ❑ BOP Test Q Mechanical Integrity Test ❑ Location Clearance ❑ Other: IV ZSR 1,05a 186P t-- tBDMS NF4 FEB 14 2020 Post Initial Injection MIT iYes ❑ No ❑ Spacing Exception Required? Yes No Subsequent Form Required: 11 0 - 14o z-1 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-40iii 412017 Approved application is valid for 12 months from the date of a proval. Anachmen s in Duplicate �1l�Zo � t//21 ZaW H llil..p Alaska, LLC Well Work Prognosis Well Name: D-12RD API Number: 50-733-20142-01 Current Status: Oil producer (Gas-Lift/ESP) Leg: Leg #: B-1 (SE) Estimated Start Date: February 28, 2020 Rig: HAK-404 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 180-082 First Call Engineer: Mark McKinley (907) 777-8387(0) (907) 953-2685 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 3,000 psi @ 8,527' TVD (ESP) 0.352 lbs/ft (6.78 ppg) based on SBHP 05/25/16 Maximum Expected BHP: 3,151 psi @ 8,958' TVD (Top pert) 0.352 lbs/ft (6.78 ppg) based on SBHP 05/25/16 Maximum Potential Surface Pressure: 2,255 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) Brief Well Summary: The D-12rd well is currently completed with an ESP that failed July 2018 and is currently at minimal production rate on gas -lift. This work over will pull and replace the completion to increase drawdown. • Last Casing Test: 07/12/2016 tested at 10,435' to 1,500 psig for 30 minutes on chart Procedure: r 1. MIRU Rig #404. ,/ 2. Circulate hydrocarbon off of well. Work over fluid will be FIW. o o u�„F ori ci a I. ` 3. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with completion. --- c it -c_ 6. PU and RIH with new combo gas -lift / ESP assembly. a. A high set packer, packer vent valve, and SSSV will be ran if well indicates ability to flow to surface. b. If applicable - Set packer and test IA to 1,500 psig charting for 30 minutes. Gj" 7. Set BPV, ND BOP, NU wellhead and test. 8. Turn well over to production. 9. Conduct SVS testing per AOGCC regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current/ Proposed (Same) 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form K L TOL @ 9,136' 9 0 DV Collar @ 5,778 @10,420' U@W E unk PKR 11,540- A, B,C�, Junk PKR @11,894' TO = 12,050'; PBTD =11,904' MAX HOLE ANGLE = 40° @ 9,300' SCHEMATIC CASING DETAIL Dolly Vanden Platform Well: D-12RD PTD: 180-082 API: 50-733-20142-01 Completion Date: 03/25/17 Size WT Grade Conn ID Top (MO) Bottom (MD) 13-3/8" 61 J-55 Buttress 12.515 Surf. 2,537' 4-1/2" 40 N-80 Buttress 8.835 Surf. 6,192' 9-5/8" 43.5 N-80 Buttress 8.755 6,192' 8,289' 3-1/2" 47 N-80 Buttress 8.681 8,289' 9,374'(KOP) 7" 29 N-80 Buttress 6.184 9,137' 12,031' 3-1/2" 9.2 L-80 HL563 2.992 Surf 8,252' 3-1/2" 9.2 L-80 Hyd 563 2.992 10,420' 10,540' 4-1/2" 1 12.6 L-80 IMBT 3.958 10,540' 10,566' 4-1/2" 12.6 L-80 Buttress 3.958 10,566' 10,646' 3-1/2" 9.2 D Mod BTC 1 2.992 11,308' 11,401' IFWFF By m rAu NO Depth (MD) Depth (TVD) ID OD Item Top MD 34, 34' BTM TVD Date CIW-DCB-ESP,11-X 314" EUE Lift and Susp w/3" Type H BPV profile A 327' 327' 2.812 5.310 SSSV - Baker TE -5 B 390' 390' 3.000 8.500 Packer -D&L Oil Tools Hydroset 11 w/ Vent Valve C 2,313' 2,225' 2.992 5.750 SFO -2 GLM#1 D 4,206' 3,681' 2.992 5.750 SFO -2 GLM #2 E 5,462' 4,683' 2.992 5.750 SFO -2 GLM #3 F 6,198' 5,247' 2.992 5.750 SFO -2 GLM #4 G 6,770' 5,696' 2.992 5.750 SFO -2 GLM #5 H 7,221' 6,056' 2.992 5.750 SFO -2 GLM #6 I 7,771' 6,498' 2.992 5.750 SFO -2 GLIM #7 J 8,168' 6,809' 2.992 5.750 SFO -2 GLM #8 K 8,211' 6,842' 2.812 4.470 X -Nipple 9,502' 8,252' 6,875' N/A 5.130 Bolt on Discharge 11,380 8,252' 6,875' N/A 5.380 Triple Pump section, Summit 198 stage SJ10000AR 11,351' 8,323' 6,931' N/A 5.130 Intake L 8,324' 6,932' N/A 5.130 Tandem Seals -BPBSL Open 8,342' 6,946' N/A 5.620 Tandem Motors - KMS 1000HP/3600V/165.5A 8,407' 6,998' N/A 5.620 Gauge (Zenith)/Centralizer/ Anode N 10,435' 8,688' 3.000 5.880 7" 26-32# Perm. Isolation Packer 4-1/2" LTC O 10,449' 8,700' 2.813 4.450 X -Nipple w/coupling P 10,528' 8,773' 4.770 5.990 Non -sealing Overshot 5a 10,546' 8,790' 3.880 5.250 Baker Locator and seal assembly 5b 10,546' 8,790' 3.880 5.500 Baker 80-47 PER (L=18.4') 6a 10,565' 8,807' 4.000 5.500 Baker KBH-22 anchor seal assembly fib 10,566' 8,808' 3.875 5.875 Baker SABL-3 permanent packer ./mill out extension 7 10,612' 8,850' 3.813 5.200 Baker X -nipple 8 10,646' 8,885' 4.000 5.200 Wireli ne entry gui de (DEFORM ED) 9 11,308' 9,492' 4.000 5.875 Baker FB -1 permanent packer with mill out extension 30 11,318' 9,501' 2.992 3.500 3-1/2" 9.216/ft tubing w/ Mod BTC (11,318'-11,391') 11 11,392' 9,570' 3.000 4.000 Ba ker Locator and G-22 locator seal assembly 12 11,393' 9,571' 5.000 4.000 Baker FB -1 permanent packer with seal -bore extension 13 11,401' 9,578' 4.000 5.000 Bottom of %cut mule shoe in Baker seal bore ext. Fish/Fill Information: A. 10/9/93:2-1/8" strip gun 25ft long tag @ 11,581' DIL. B. 10/93: Tag fill @ 11607' DIL. C. 11/28/89: 16 ft long strip gun w/ bull nose D. RIH w/2-1/2" 1DC and cannot pass 11,384'. E. 2/4/17- Potential Live Shot Left in Hole - approx. 11,400' Revised by: JLL 07/31/18 PERFORATION DETAIL Zone Top MD BTM MD Top TVD BTM TVD Date Comments G-2 10,729 10,752 8,958' 8,979' 10/01/1999 2-7/8" HC @ 4-8 SPF G-3 10,803 10,832 9,026' 9,053' 10/01/1999 2-7/8" HC @ 4 SPF G4 10,856 10,866 9,075' 9,084' 11/28/2000 2-7/8" HC @ 60°,6 SPF G-3 10,803 10,823 9,026' 9,045' 11/28/2000 2-7/8" HC @ 60°, 6 SPF HB -0 11,150 11,160 9,346' 9,355' Open HB -0 11,190 11,200 9,383' 9,392' Open HB -1 11,225 11,240 9,415' 9,429' Open HB -2 11,258 11,268 9,446' 9,455' Open HB -2 11,268' 11,308' 9,445' 9,492' 02/05/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB -2 11,319' 11,335' 9,502' 9,517' 1 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase HB -3 11,350 11,380 9,531' 9,559' Open HB -3 11,351' 11,378' 9,532' 9,556' 02/04/2017 2.50" OD GeoDynamics Razor, 6 Err, 60 Deg Phase HB -4 11,412 11,432 9,588' 9,607' Open HB4 11,440 11,470 9,614' 9,642' Open H84 11,485 11,520 9,656' 9,688' Open Wit 11,530 11,580 9,698' 9,744' Partially covered w/Junk Packer at 11540' HB -5 11,596 11,630 9,759' 9,791' Covered w/ Junk and Fill/Debris HB -5 11,690 11,715 9,847' 9,871' Covered w/ Junk and Fill/Debris Fish/Fill Information: A. 10/9/93:2-1/8" strip gun 25ft long tag @ 11,581' DIL. B. 10/93: Tag fill @ 11607' DIL. C. 11/28/89: 16 ft long strip gun w/ bull nose D. RIH w/2-1/2" 1DC and cannot pass 11,384'. E. 2/4/17- Potential Live Shot Left in Hole - approx. 11,400' Revised by: JLL 07/31/18 Varde Dolly D-12R Platform WellPROPOSED PTD: 180-082 PTD: 180-082 ufh�orP Alaekn, 61.0 API: 50-733-20142-01 Completion Date: FUTURE RKB = 34' Rig Floor to TBG Hanger TD =12,050'; PBTD =11,904' MAX HOLE ANGLE = 40° @ 9,300' CASING DETAIL Size WT Grade Conn ID Top(MD) Bottom (MD) 13-3/8" 61 1-55 Buttress 12.515 Surf. 2,537' 4-1/2" 40 N-80 Buttress 8.835 Surf, 6,192' 9-5/8" 43.5 N-80 Buttress 8.755 6,192' 8,289' 3-1/2" 47 N-80 Buttress 8.681 8,289' 9,374'(KOP) 7" 29 N-80 Buttress 6.184 9,137' 12,031' TUBING DETAIL 3-1/2" 9.2 L-80 Hyd 563 2.992 Surf 38,250' 3-1/2" 9.2 L-80 Hyd 563 2.992 10,420' 10,540' 4-1/2" 12.6 L-80 IMBT 3.958 10,540' 10,566' 4-1/2" 12.6 L-80 Buttress 3.958 10,566' 10,646' 3-1/2" 9.2 D Mod BTC 2.992 11,308' 11,401' JEWELRY DETAII NO Depth (MO) Depth (TVD) ID OD Item Top MD 34' 34' BTM TVD Date CI W -DCB -ESP, 11"X 374" EUE Lift and Susp w/3" Type H BPV profile A ±325' ±325' 2.812 5.310 SSSV B ±390' ±390' 3.000 8.500 Packer w/ Vent Valve C ±2,315' x2,226' 2.992 5.750 SIP04 GLM #1 D ±4,205' ±3,681' 2.992 5.750 5FO-2 GLM #2 E ±5,460 ±4,682' 2.992 5.750 SFO -2 GLM #3 F ±6,200' ±5,249' 2.992 5.750 SFO -2 GLM #4 G ±6,770' ±5,696' 2.992 5.750 SFO -2 GLM#5 H ±7,220' ±6,055' 2.992 5.750 SFO -2 GLM #6 1 ±7,770' ±6,497' 2.992 5.750 SFO -2 GLM 97 1 ±8,170' ±6,810' 2.992 5.750 SFO -2 GLIM #8 K ±8,210' ±6,842' 2.812 4.470 X -Nipple 9,502' ±8,250' ±6,873' N/A 5.130 Bolton Discharge 11,380 9,531' 9,559' N/A Open Triple Pump section, Summit 198 stage SJ10000AR 11,351' 11,378' 9,532' N/A 02/04/2017 Intake L 11,412 11,432 N/A 9,607' Tandem Seals -SPBSL Open HB -4 11,440 N/A 9,614' Tandem Motors - KMS 1000HP/360OV/165.5A ±8,410' ±7,000' N/A 11,520 Gauge (Zenith)/ Centralizer/ Anode N 10,435' 8,688' 3.000 5.880 7" 26-32# Perm. Isolation Packer 42/2" LTC O 10,449' 8,700' 2.813 4.450 X -Nipple w/coupling P 10,528' 8,773' 4.770 5.990 Non -sealing Overshot 5a 10,546' 8,790' 3.880 5.250 Baker Locator and seal assembly 51P 10,546' 8,790' 3.880 5.500 Baker 8047 PER (L=18.4') 6a 10,565' 8,807' 4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566' 8,808' 3.875 5.875 Baker SABL-3 permanent packer /mill out extension 7 10,612' 8,850' 3.813 5.200 Baker X -nipple 8 10,646' 8,885' 4.000 5.200 Wireline entry guide (DEFORMED) 9 11,308' 9,492' 4.000 5.875 Baker FB -1 permanent packer with mill out extension 10 11,318' 9,501' 2.992 3.500 3-1/2"9.2lb/ft tubing w/ Mod BTC (11,318'-11,391!) 11 11,392' 9,570' 3.000 4.000 Baker Locator and G-22 locator seal assembly 12 11,393' 9,571' 1 5.000 1 4.000 Baker FB -1 permanent packer with seal -bore extension 13 11,401' 1 9,578' 1 4.000 1 5.000 Bottom of M cut mule shoe in Baker seal bore ext. Fish/Fill Information: A. 10/9/93: 2-1/8" strip gun 25ft long tag @ 11581' DIL B. 10/93: Tag 811 @ 11 607' OIL C. 11/28/89: 16 ft long strip gun w/ bull nose D. III w/2-1/2" 1DC and cannot pass 11,384'. E. 2/4/17 - Potential live Shat Left in Hole- approx. 11,400' Revised by: JUL 07/31/18 PERFORATION DETAIL Zone Top MD BTM MD Top TVD BTM TVD Date Comments G-2 10,729 10,752 8,958' 8,979' 10/01/1999 2-7/8" HC IT 4-8 SPF G-3 10,803 10,832 9,026' 9,053' 10/01/1999 2-7/8" HC @ 4 SPF G-4 10,856 10,866 9,075' 9,084' 11/28/2000 2-7/8" HC @ 60-, 6 SPF G-3 10,803 10,823 9,026' 9,045' 11/28/2000 2-7/8" HC @ 60°, 6 SPF HB -0 11,150 11,160 9,346' 9,355' Open HB -0 11,190 11,200 9,383' 9,392' Open 1413-1 11,225 11,240 9,415' 9,429' Open HB -2 11,258 11,268 9,446' 9,455' Open HB -2 11,268' 11,308' 9,445' 9,492' 02/05/2017 2.50" OD GeoDynamia Razor, 6 SPF, 60 Deg Phase HB -2 11,319' 11,335' 9,502' 9,517' 02/04/2017 2.50" OD GeoDynamia Razor, 65PF, 60 Deg Phase HB -3 11,350 11,380 9,531' 9,559' Open HB -3 11,351' 11,378' 9,532' 9,556' 02/04/2017 2.50" OD GeoDynamics Razor, 6 SPF, 60 Deg Phase H84 11,412 11,432 9,588' 9,607' Open HB -4 11,440 11,470 9,614' 9,642' Open HB -4 11,485 11,520 9,656' 9,688' Open HB -4 11,530 11,580 9,698' 9,744' Partially covered w/ Junk Packer at 11540' HB -5 11,596 11,630 9,759' 9,791' Covered w/ Junk and Fill/Debris HB -5 11,690 11,715 9,847' 9,871' Covered w/ Junk and Fill/Debris Fish/Fill Information: A. 10/9/93: 2-1/8" strip gun 25ft long tag @ 11581' DIL B. 10/93: Tag 811 @ 11 607' OIL C. 11/28/89: 16 ft long strip gun w/ bull nose D. III w/2-1/2" 1DC and cannot pass 11,384'. E. 2/4/17 - Potential live Shat Left in Hole- approx. 11,400' Revised by: JUL 07/31/18 0 ttilrv,q Ala.ku,1.11: Dolly Varden D-12RD 133/8 X 95/8 X 31/2 Valve, swab, WKM-M, 3 1/8 SM FE, HWO, T-24 Valve, wing, WKM-M, 21/165M FE, HWO, T-24 Valve, lower master, WKM-M, 3 1/8 5M FE, HWO, T-24 Tubing head, CIW-DCB, 135/83M X 115M, w/ 2- 2 1/16 SM SSO, X bottom, installed in 08/1999 N style lockpins Casing head, CIW-W F, 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 2 1/16 5M EFO, CA slips installed in head BHTA, Bowen, 3 1/8 SM FE X 3" Bowen top Dolly Varden Platform D-12RD Current 03/28/2017 Tubing hanger, CIW-DCB-ESP, 11 X 3 % eue lift and susp, w/ 3" type H BPV profile, 5 Y. EN, 4- 1/4 continuous control line ports, prepped for BIW penetrator Valve, Wing, WKM-M, 3 1/8 SM FE, w/ 15" OMNI operator, DD \� trim Adapter, CIW-Toadstool, 11 5M Stdd X 3 1/8 5M FE, prepped for 5 %ESP neck, 2-'h npt, 2-%npt continuous control line ports Valve, WKM-M, 21/165M FE, HWO, DO Qty 2 Valve, CIW-F, 21/165M FE, HWO, AA trim H Hil.,q ANA, LM Dolly Varden Platform 2020 BOP Stack 01/24/2020 Il valves iM C o r D --i Z T w C Z O AJ mG)�� ! �pDn m r N n Z 0 0 Mn>M A D�SeG) CPDD yZ�G)4t -iG) O a D C U) K — __m 3 ❑ -i �cF7 C ryr m0 W mCT Z Ll G) o z z z 0 v v m N >0 D � s� o pA <z a a m / ^m o p O p 2 ik 0. m 09 ma L� �J a z z mn 0� N W J t0 N O 33 < ^ - 3 3 3 3 3 3 3 3 3 3 o' e 3 3 c 0 n 0 n n 0 n 0 n 0 n 0 0 n 0 0 n 0 n 0 0 �, c C ? O o 0 o n o n o� s z D Z co 2 g z -n z y U W 0 0 C Oao00 N zz-u 00T �G) DC::> a Z > > cc F7O �c zcm D m14 Z z O c Z D z 0 v mm >� n0 F N p Om r p p Dx p rn <p m 09 ik ak 0. oz A W Om mz mx v ;io z z M, ak ik m <n W V �D M N 04 O � o 3 a xx-vccovp-3avaaEr z `<33i33nodd�>w- F701TO ME 33333 ... o 0 o n o n o� s Rig 404 BOP Test Procedure Hik.rp Alaka, LLC Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift -threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift -threads d) For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) H Hikrurp Alaska, LLC Rig 404 BOP Test Procedure Attachment #1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump -in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump -in sub below safety valve and IBOP in testjoint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1" valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross, open 1' valve of standpipe, close valves 3, 4 & 9 on choke manifold, open valves 1 & 2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross, close valves 5 & 6 /open valves 3 & 4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke / open valves 5 & 6 on choke manifold. Pressure up to —1200 psi and bleed off 200— 300 Its recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. f) Close HCR (outside valve on choke side of mud cross), open manual & super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. n Aik,.p AI.Ak , LLC Rig 404 BOP Test Procedure Attachment #1 g) Close inside valve / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug/ 2 -way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7 & 8 / open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure'. It should be+/ -3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre - charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto', not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. In v d w CD iz N N CD CD1 w d 3 O v d 0 7 N 3 d d to CD O w m a v 0 d CD Q CD CL O o CD c 3 DCD Om � a Ci d C) � n � d ^; a V CD O d v m v C' gCD m O' �O sW N d s 3 y (D O m m (D d �v ca CD0 a< 6 Q (D y O C N � a 3 -o g m m m O O 0 3 3 CD O 3 d m a m o m W c c n S d 3 f0 N O D a v CLCD 6 N C C CL Z o' n m CL c 'm 0 m v S N .:1 v 1 v co 0 co Z. y m d d v m a c n d m N � Z j C ZC o CL CD v D CL D N CD CL v'O D m ° O NOLs n Ca0 � ID —a CD Q CD CL O o CD c 3 DCD Om � a Ci d C) � n � d ^; a V CD O d v m v C' gCD m O' �O sW N d s 3 y (D O m m (D d �v ca CD0 a< 6 Q (D y O C N � a 3 -o g m m m O O 0 3 3 CD O 3 d m a m o m W c c n S d 3 f0 N O D a v CLCD 6 N C C CL Z o' n m CL c 'm 0 m v S N .:1 v 1 v co 0 co Z. Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Friday, May 31, 2019 1:46 PM To: 'Juanita Lovett' Cc: Dan Marlowe; samantha.carlisle@alaska.gov Subject: RE: Withdraw Sundry # 318-328 (PTD 180-082) - D-12RD Juanita, The AOGCC will cancel sundry 318-328 as requested for well D-12. Guy Schwartz Sr. Petroleum Engineer RBDMSL JUN 0 b 2019 AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwartz@alaska.aoov). From: Juanita Lovett <jlovett@hilcorp.com> Sent: Friday, May 31, 2019 10:37 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com> Subject: Withdraw Sundry # 318-328 (PTD 180-082) - D-12RD Guy, Please withdraw the above mentioned sundry. The scope of work was to pull and replace the completion to increase drawdown. Thank you, Juanita L Lovett Sr. Operations/Regulatory Tech it Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 1 Anchorage I AK 199503 (907) 777-8332 1 ilovett@h lcorp.com The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA RECEIVED ALOA OIL AND GAS CONSERVATION COM ION APR 2 4 2017 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0Utdown 0 Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other:Install GL/ESP Completion 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 0 180-082 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20142-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 Trading Bay Unit D-12RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 12,050 feet Plugs measured 11,904 feet true vertical 10,188 feet Junk measured 11,540; 11,581; feet 11.894 Effective Depth measured 11,384 feet Packer measured See Schematic feet true vertical 9,562 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,537' 13-3/8" 2,537' 2,403' 3,090 psi 1,540 psi Intermediate Production 9,374' 9-5/8" 9,374' 7,746' 5,750 psi 3,090 psi Liner 2,894' 7" 12,031' 8,445' 8,160 psi 7,020 psi Perforation depth Measured depth 10,729-11,715 feet True Vertical depth 8,958-9,871 feet 3-1/2" 9.2#/L-80 8,252&10,528(MD) 6,875&8,773(TVD) Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 10,566&10,646(MD) 8,808&8,882(TVD) Packers and SSSV(type,measured and true vertical depth) See Schematic 12.Stimulation or cement squeeze summary: Intervals treated(measured): ' N/A �y n;� z Treatment descriptions including volumes used and final pressure: SE bJ I ` - N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 89 41 540 1066 133 Subsequent to operation: 335 51 6295 128 140 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-635 — Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dm arlowe hilcorp.com -- Authorized Signature: Lw.W11 . Date: 404/17 Contact Phone: (907)283-1329 Form 10-404 Revised 4/2017 74 LS•!c-/? RBDMS tji/MAY - 3 20 17 Submit Original Only • Dolly Varden Platform , fir ii• SCHEMATIC well: D-12RD PTD: 180-082 Hilcora Alaska,LLC API: 50-733-20142-01 Completion Date: 03/25/17 CASING DETAIL Size WT Grade Conn ID Top(MD) Bottom(MD) 13-3/8" 61 J-55 Buttress 12.515 Surf. 2,537' 40 N-80 Buttress 8.835 Surf. 6,192' 9-5/8" 43.5 N-80 Buttress 8.755 6,192' 8,289' RKB=34' Rig Floor to TBG Hanger 47 N-80 Buttress 8.681 8,289' 9,374'(KOP) 7" 29 N-80 Buttress 6.184 9,137' 12,031' ww,it gni TUBING DETAIL k a 3-1/2" 9.2 L-80 Hyd 563 2.992 Surf 8,252' .,. B 3-1/2" 9.2 L-80 Hyd 563 2.992 10,420' 10,528' 4-1/2" 12.6 L-80 IMBT 3.958 ±10,540' 10,566' ` 4-1/2" 12.6 L-80 Buttress 3.958 10,566' 10,646' ® JEWELRY DETAIL MEI NO Depth(MD) Depth(TVD) ID OD Item 1 34' 34' CIW-DCB-ESP,11"X 334"EUE Lift and Susp w/3"Type H BPV profile ''N' C-.1 liMil A 327' 327' 2.812 5.310 SSSV-Baker TE-5 MIR B 390' 390' 3.000 8.500 Packer-D&L Oil Tools Hydroset II w/Vent Valve Ili • C 2,313' 2,225' 2.992 5.750 SFO-2 GLM#1 :, :,. 1 D 4,206' 3,681' 2.992 5.750 SFO-2 GLM#2 ' M � E 5,462' 4,683' 2.992 5.750 SFO-2 GLM#3 "y _' F 6,198' 5,247' 2.992 5.750 SFO-2 GLM#4 rn G 6,770' 5,696' 2.992 5.750 SFO-2 GLM#5 K iWA H 7,221' 6,056' 2.992 5.750 SFO-2 GLM#6 DV Collar I 7,771' 6,498' 2.992 5.750 SFO-2 GLM#7 5 778 J 8,168' 6,809' 2.992 5.750 SFO-2 GLM#8 fER K 8,211' 6,842' 2.812 4.470 X-Nipple 8,252' 6,875' N/A 5.130 Bolt on Discharge 8,252' 6,875' N/A 5.380 Triple Pump section,Summit 198 stage SJ10000AR L = L 8,323' 6,931' N/A 5.130 Intake TOL @ 9,136' 8,324' 6,932' N/A 5.130 Tandem Seals-BPBSL 8,342' 6,946' N/A 5.620 Tandem Motors-KMS 1000HP/3600V/165.5A N 8,407' 6,998' N/A 5.620 Gauge(Zenith)/Centralizer/Anode Top oftubing N 10,435' 8,688' 3.000 5.880 7"26-32#Perm.Isolation Packer 4-1/2"LTC @10,420' 0 10,449' 8,700' 2.813 4.450 X-Nipple w/coupling P 10,528' 8,773' 4.770 5.990 Non-sealing Overshot • 5a 10,546' 8,790' 3.880 5.250 Baker Locator and seal assembly 5b 10,546' 8,790' 3.880 5.500 Baker 80-47 PBR(L=18.4') ,( • 6a 10,565' 8,807' 4.000 5.500 Baker KBH-22 anchor seal assembly 5 6b 10,566' 8,808' 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 7 10,612' 8,850' 3.813 5.200 BakerX-nipple J s 8 10,646' 8,885' 4.000 5.200 Wireline entry guide(DEFORMED) '3 9 11,308' 9,492' 4.000 5.875 Baker FB-1 permanent packer with mill out extension I 7 10 11,318' 9,501' 2.992 3.500 3-1/2"9.2 lb/ft tubing w/Mod BTC(11,318'-11,391') 11 11,392' 9,570' 3.000 4.000 Baker Locator and G-22 locator seal assembly - 8e& 12 11,393' 9,571' 5.000 4.000 Baker FB-1 permanent packer with seal-bore extension BEWARE! 0'� PERFORATION DETAIL EOT t Zone Top MD BTM MD Top TVD BTM TVD Date Comments Deformed 4'`, G-2 10,729 10,752 8,958' 8,979' 10/01/1999 2-7/8"HC @ 4-8 SPF r ` G-3 10,803 10,832 9,026' 9,053' 10/01/1999 2-7/8"HC @ 4 SPF 1/411 6-4 10,856 10,866 9,075' 9,084' 11/28/2000 2-7/8"HC @ 60°,6 SPF G-3 10,803 10,823 9,026' 9,045' 11/28/2000 2-7/8"HC @ 60°,6 SPF '' HB-0 11,150 11,160 9,346' 9,355' Open . 9 HB-0 11,190 11,200 9,383' 9,392' Open `i HB-1 11,225 11,240 9,415' 9,429' Open a HB-2 11,258 11,268 9,446' 9,455' Open 11- HB-2 11,268' 11,308' 9,445' 9,492' 02/05/2017 2.50"OD GeoDynamics Razor,6 SPF,60 Deg Phase 474\7 HB-2 11,319' 11,335' 9,502' 9,517' 02/04/2017 2.50"OD GeoDynamics Razor,6 SPF,60 Deg Phase HB-3 11,350 11,380 9,531' 9,559' Open I.- 12- HB-3 11,351' 11,378' 9,532' 9,556' 02/04/2017 2.50"OD GeoDynamics Razor,6 SPF,60 Deg Phase .01 E l�'f � Junk PKR HB-4 11,412 11,432 9,588' 9,607' Open "t, @ 11,540' HB-4 11,440 11,470 9,614' 9,642' Open 114 HB-4 11,485 11,520 9,656' 9,688' Open i4* HB-4 11,530 11,580 9,698' 9,744' Partially covered w/Junk Packer at 11540' HB-5 11,596 11,630 9,759' 9,791' Covered w/Junk and Fill/Debris A B' 1:7 111 '.� HB-5 11,690 11,715 9,847' 9,871' Covered w/Junk and Fill/Debris r 4Junk PKR ,' Fish/Fill Information: @ 11,894' ;r, . A. 10/9/93:2-1/8"strip gun 25ft long tag @ 11,581'DIL. B. 10/93:Tag fill @ 11,607'DIL. TD=12,050'; PBTD=11,904' C. 11/28/89:16 ft long strip gun w/bull nose MAX HOLE ANGLE=40°@ 9,300' D. RIH w/2-1/2"JDC and cannot pass 11,384'. Revised by: JLL 04/10/17 E. 2/4/17-Potential Live Shot Left in Hole-approx.11,400' S • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-12RD Moncla 404 50-733-20142-01 180-082 3/15/17 3/25/17 Daily Operations: 03/15/17-Wednesday M/V Titan arrives. Unable to offload due to high winds. Boat returns to dock for additional loads. Wait on boat return. M/V Titan returns and waiting for tide to turn to allow pull up to platform and offload. 3 helicopters deliver rig crews to platform. Platform orientation, safety meeting and JSA/permits completed. Off load M/V Titan. Offload rig substructure beams, BOPE and Annular.Spot rig substructure beams on drill deck over well. Stop boat off load to slide east crane stairs/landing support column and remove stairs to VRU deck so that substructure beams can be put in place on drill deck. Boat pulls away from platform due to ice. Continue placing substructure beams in place. 03/16/17-Thursday Continue w/ R/U of W/O package. Landed carrier on strongback beams, positioned and secured- installed drawworks, A- frame and derrick-organized deck while waiting on next load of equipment. We have greased the crown blocks-torqued bolts on drawworks- mounted driller's console. Received misc tools, hyd tb tongs and HS connex from Monopod- raised derrick (at half mast) and strung up block. Continue w/ R/U of W/O package. Boat returns. Off load koomey, choke house and walkways. East crane whip line anti-2 block caught in sheave, unable to continue boat off load. Worked boat with west crane picking remaining loads possible while platform mechanics troubleshoots east crane. Assembled 4 walkways to carrier. Returned to east crane using heavy block line only. Cleared space on drill deck to allow for remaining heavy picks off boat. Whip line wraps & entangles around heavy block lines.Stop crane work& remove whip line from heavy block line. Release boat to return to dock. Set stair case on walkway with west crane. Clear and clean up deck area using west crane. Waiting for new whip line cable and sheave to repair east crane. 03/17/17- Friday Began prepping for slickline work. R/U 2" hose from 9 5/8" annulus to production well-clean tank. R/U Pollard S/L w/full lubricator- M/U Run#1 (3.5" Daniels kick-over tool, 1 3/4" spang and oil jars, knuckle jt, 10' of 13/4" stem, rope socket)- pulled inside lubricator- held PJSM w/prod crew, crane op &WSM. Tested lubricator to 2500 PSI- released pressure and opened well. TIH and recovered dummy valve at 10,383'- POOH- R/D S/L. R/U rig pump to circulate well. Offload M/V Titan.Turn east crane over to platform operators for repair of whip line. Test WH packoff void to 5000 psi- PASS.Tubing hanger holds pressure. Run 3" fluid supply hose to platform FIW supply and 2", 1502 return line to tank. Run 2", 1502 line from rig pump to WH. Mounted gas buster on rig tank. Changed 6" suction valve on rig pump. M/U panic line to choke house and gas buster. Filled rig tank with FIW. East crane whip line repaired, crane returned to service.Tarped pump and ran heater trunks to thaw out pump. Heater keeps kicking breaker- re-wire heater plug. Began pumping FIW (LW) @ 2 BPM 300 PSI sending returns to production's well-clean tank. Took—90 bbls to get returns. • ! Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-12RD Moncla 404 50-733-20142-01 180-082 3/15/17 3/25/17 Daily Operations: tt Viµ .444.. . :,; 03/18/17-Saturday Finished flushing well w/ FIW at 2 BPM 300 PSI sending returns to production's well-clean tank. Continued spotting/hooking up W/O equipment. Shutdown pump- both sides on vacuum. NOS rep installed BPV. N/D tree w/ assistance from production. Abandon platform drill held at 1230 hrs. NOS rep worked spool cleaning hanger threads and ring groove- M/U blank test sub into hanger threads. Sent M/V to Monopod to retrieve riser lifting eye- received lifting eye and M/U 13 5/8" 5M riser w/ 11" adapter onto tb head. Worked M/V Titon w/3rd load of W/O equipment. Boat empty, release boat. Continue to N/U BOPE. M/U 13-5/8" 5M mud cross (4-1/16 side ports), 13-5/8" 5M dual ram BOP and 13- 5/8" 5M annular preventer to the 13-5/8" Riser.Torque all BOPE flanged connection bolts to spec starting at 13-5/8" riser base and working up the stack. M/U co-flex lines from koomey to BOPE stack. Set drillers shack in place. Raised and scoped out derrick. Secured guy lines. Continue positioning/setting up W/O package. 03/19/17-Sunday Continue R/U W/O package. Finished securing all guy lines from derrick. Found damaged spot in drill line that occurred while scoping out derrick-slipped and cut 120' of drill line to remove this damage. Quadco &Total Safety reps onboard to setup their systems. Ran and connected koomey hoses to BOPE. Modified heater legs to fit beside carrier on off driller side. 1400 hrs worked M/V Titon receiving co-flex hoses, light plant, (1) cutting box. Installed drill floor. Work M/V Titon receiving hooches. Welder fabbed stairs to carrier walkway and fit same in place. Set hooches over carrier. M/U choke and kill lines. Spotted heater and fuel tank beside carrier. R/U hyd tongs on rig floor. M/U 3-1/2" test joint w/ NOS x-over on btm- pumpin, safety valve, IBOP on top. R/U test pump. Ran heat to test pump, choke house, koomey unit. M/U carriage support cables. Wrapped BOPs and run in heat. 03/20/17- Monday Continue setting up test pump while BOP stack is being heated- thawed out hoses, worked thru test pump issues. Welder is working on walkway across double beams for access to BOP stack. Start BOP pre-test. Fluid load BOP stack w/test pump and pressure up stack= 250 psi. Pressure bleeding off.Tighten flange bolts at 13-5/8" riser X adaptor spool connection. Re- start BOP pre-test. BOP pre-test pressure continues to bleed down. Pull 3-1/2" test joint/test sub assy and unseat BPV. Break bolted connections at 13-5/8" riser X 11" tubing adaptor flange and tubing adaptor X tubing head flange and replace ring gaskets at each flanged interface. M/U tubing adapter to tubing head and riser to tubing head flanges and torque flange connection bolts to spec. Re-set BPV and 3-1/2' test joint/test sub assy.Total Safety relocates H2S/LEL alarm unit mounted on carrier. Move heater unit closer to rig pump to increase open deck space. Fluid load BOP stack. Continue with BOP pre-test. 2500 psi shell test- PASS. Swaco sensor pumped up. Unibolt connection for K-1 valve to co-flex circulation line will not mate up. Call out boat to deliver Moncla flanged co-flex hose. Wrap visquine around bottom of entire carrier for wind wall. Offload flanged co-flex hose from M/V Resolution, M/U flanged co-flex hose to K3 valve. Start pretesting BOPE 250/2500 psi.Test#1 (Annular) - PASS.Test#2 (Pipe Rams) - PASS. Continue pretesting BOPE.Test#3 (K1 vlv) - PASS. Test#4 (Man &Sup choke) - PASS. Test#5 (HCR) - Pass. Continue working thru pretest. • r Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-12RD Moncla 404 50-733-20142-01 180-082 3/15/17 3/25/17 Daily Operations: 03/21/17-Tuesday Continued with BOPE pretest and housekeeping/organizing deck and W/O package. Welder is finishing walkway over double beam and racking mat beam w/stairs to stack. Setup stair way to rig tank. Mr. Lou Grimaldi/AOGCC on board at 1300 hrs. 1330 hrs began BOPE test. Tested all BOPE to 250 PSI low 2500 PSI high as per Hilcorp &AOGCC requirements. Performed successful koomey draw-down test- tested all H2S/LEL sensors w/assistance from Total Safety rep. R/D test equipment. Circulate FIW down tubing,taking returns to production well-clean tank @ 2 BPM 300 psi to load hole. Returns to surface with 136 bbl. away. Pump 200 bbl.total. Move heater&fuel tank from front of pump. Spot ELU in front of pump. Clear west deck for area to lay down pipe. B/O every other hold-down pin. Keep pump circulating to rig tank for freeze protection. M/U landing joint. B/O all hold-down pins. P/U 100K string weight, unseat from hanger @ 95K. 3-1/2" collar at slips. P/U to 120K, collar still at slips. Lower back down and set on hanger. Re-configure landing joint to put pup joint on bottom. P/U 100K string weight and set string in slips. M/V Resolution arrives. Work boat offloading V-door and packer. Backload 6 stair sets and empty 4' X 8' basket. R/U ELU with chemical cut tool string. 16.5' CCL to cutter. RIH to cut tubing 5' above packer at 10,435' +/-. 7950' working wire in hole EL operator seeing weight slack-off. PUH and then RIH able to keep working wire in hole with repeated PUHs. 8150' driller spots bird nested wire @ EL head. Stop RIH. ELU operator inspects wire and finds 1 broken strand of armor shield. PUH until nested wire is at sheave. Remove 2 wire nests to allow wire to pass sheave. Check well for pressure. Well static. PUH to find lower end of broken armor shield strand. Secure strand to allow wire to pass through head without nesting. POOH. EL tools at surface. L/D tool string. Unspool and cut off damaged wireline. 03/22/17-Wednesday Spooled off ELine to remove damaged wire from drum. Reheaded line and M/U 2 5/8" chemical cutter.TIH and correlated on depth to downhole hardware-fired cutter at 10,420' (5' above x-over at 10,425'). POOH. Pulled cut into at 130k-string moving uphole at 104k. R/D ELine. Pulled hanger to surface and NOS rep worked same. Took 83 bbls to catch fluid level. B/O L/D hanger. Prepped rig floor to POOH laying down singles- laid down 5 jts (oil in ID of tb). Lined up to circulate tb volume LW at 3 BPM to flush oil from tb ID. 32 bbls to break circulation. Pumped 85 bbls total then shutdown pump. Began POOH laying down 3 1/2" 9.2# Hydril 563 production tubing, pumping 5 bbls every 20 jts. Laid down a total of 56 jts. POOH racking back production tubing, laying down GLM & pups. Pumped 5 bbls FIW every 10 stands. Pump 82 bbls FIW to catch fluid level. Continue POOH racking back production tubing, laying down GLM & pups. 66 stands racked back. Laid down 1 joint. Crane working boat. Return to racking back stands. Stand back 5 stands (71 total back). Crane done working boat. Laid down 22 joints (total joints laid down 56+ 1 +22 = 79) . Pumped 10 bbls. FIW. Return to racking back production tubing, laying down GLM & pups. Pumped 10 bbls FIW every 20 stands. RU Summit wire spooler. Laid down 2 more joints. OOH. 126 stands in derrick+81 joints laid down + 1 cut joint= 10,420'. M/U Scraper BHA: 3-1/2 Hydril 563 Box X 3-1/2 IF PIN (4-3/4" OD X 0.88' L), 3-1/2 IF Box X 4-1/2" IF Pin(5-1/2" OD x 2.50' L), 4-1/2 IF Box X 4-1/2 Box(5.50" OD X 3.50 L), Scraper(6" X 3.50'L) = 10.38'TL. Tripoint strapped all GLM lengths. RIH with scraper BHA. P/U 1 joint+8 stands (510' +/-). Pump FIW at 3 BPM to load and circulate hole. 87 bbls to catch fluid top. Pump 150 bbls total. POOH and B/D scraper assy. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-12RD Moncla 404 50-733-20142-01 180-082 3/15/17 3/25/17 Daily Operations: 03/23/17-Thursday Laid out scraper-cleared and cleaned rig floor- prepped floor to run ESP assy- held PJSM w/Summit, rig and crane crew, WSM & K Kozub. Lower 1st motor w/gauge and centralizer in hole- P/U and serviced motor- M/U 2nd motor and serviced it. Connected flat pack lines and M/U lower& upper tandem seal sections. 1400 hrs spliced in power cable and checked insulation. M/U intake, triple pump sections and bolt on discharge. Plan is to pump 20 bbls FIW every hour, on the hour. R/U KOT McCoy tongs and power pack. Set tongs for 3000#s MUT. C/O tong dies to 4-1/2". M/U X-nipple. C/O tong dies to 3-1/2" f/ running tubing. RIH with ESP picking up 3 1/2" 9.2# L-80 563 Hydril production tubing, power cable,flat pack, GLMs and pups per Tripoint tubular tally. Clamped power cable and flat pack at top of each stand of 3-1/2" tubing plus above and below each GLM. Test insulation of power cable every 1000'. 60 stand in hole at report time = 3,855'. 03/24/17- Friday Continued running in hole with Summit ESP/SPM production assembly on 3 1/2" 9.2# L-80 Hydril 563 tubing from 3,855' to 5,927' checking insulation every 1000', pumping 20 bbls FIW every hr. Summit made power cable splice at—6,000'. Checked insulation-good. Continued in hole w/ ESP/SPM assy from 5,927' to 8,006'. M/U Tripoint pkr assy. Plumbed all control lines and power cable thru pkr- Pollard connected vent valve control line and function test same. M/V Titon arrives. Work boat back loading.Swap out Summit power cable spool. Summit splices power cable and flat pack.Test same. RIH with Tripoint 9-5/8" Dual ESP hyd. set packer. M/U SSSV and Pollard M/U control line and function test same. RIH with joints 258- 266. M/U tubing hanger. Plumbed all control lines and power cable thru tubing hanger. M/U landing joint. Presently landing hanger. 03/25/17-Saturday Landed hanger placing EOP at 8,407'. Ran in hold-down pins and packed off void. Pumped FIW down tb ahead of prong- dropped prong and continued filling tb. Pressured up to 3800#s 3 times due to bled off, most probably leaking past prong. Held pressure on chart for 30 mins (worked thru surface leaks also).Tied pump into casing and filled annulus. Pressured_up. to 1500#s and held on chart f/30 mins-solid test- released pressure. R/U Pollard S/L w/full lubricator. Run#1 TIH w/2" JDC pulling tool w/2 1/4" bell guide, 1 1/2" spang& oil jars, knuckle, 10' of 1 1/2" wt bars & RS to 8,211'- latched prong- POOH. M/U Run#2 B/O 2"JDC- M/U 3" GS pulling tool w/same tool string-TIH to 8,211' and latched plug- POOH. B/D tool string- R/D Pollard S/L. NOS rep pulled landing jt and set BPV. Cleared and moved rig floor. Nipple down BOPE. Move stair set to carrier, koomey and the walkway across the beams prepping for rig skid. Nipple up WH tree. Plumb control lines and power cable thru tree adapter. Summit tested ESP power cable-good test. NOS test tubing hanger neck seals (500 psi/5 mins.) and pack-off void (500 psi/5 mins, 5000 psi/15 mins) -good test. NOS cycled vent valve and SSSV-good test. RU pancake jacks and power pack. Attempted to move racking mat beam w/crane- unable to make pick with derrick scoped out. Scope down derrick and moved RMB. NOS set 2-way check. Shell tested tree to 5000 psi. Received Moncla specific cylinders and clamps to skid carrier on their beams. Turned well over to production at 0500 hrs. RECEIVED STATE OF ALASKA AKA OIL AND GAS CONSERVATION COM SION ,REB 2 8 2017 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 0 180-082 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20142-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 Trading Bay Unit D-12RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 12,050 feet Plugs measured 11,904 feet true vertical 10 188 feet Junk measured 11,400,11,540, feet 11,581,11,894 Effective Depth measured 11,400 feet Packer measured See Schematic feet true vertical 9,577 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,537' 13-3/8" 2,537' 2,403' 3,090 psi 1,540 psi Intermediate Production 9,374' 9-5/8" 9,374' 7,746' 5,750 psi 3,090 psi Liner 2,894' 7" 12,031' 8,445' 8,160 psi 7,020 psi Perforation depth Measured depth 10,729-11,715 feet True Vertical depth 8,958-9,871 feet 3-1/2" 9.2#/L-80 __10r628'(MDr' 8,773'(ND) Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 10,566'(MD) 8,808'(ND) 4-1/2" 12.6#/L-80 10,646'(MD) 8,882'(TVD) Packers and SSSV(type,measured and true vertical depth) See Schematic SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): > " N/A scoots) M:i. _ Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 99 34 608 1080 125 Subsequent to operation: 65 33 1243 1328 128 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ ❑ WAG 0 GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-028 Contact Dan Marlowe(907)283-1329 Email dmarlowenhilcora.com Printed Name Stan W.Golis ,,Q Title Operations Manager Signature s��`� Phone (907)777-8356 Date Z f te/Z•i i Form 10-404 Revised 5/2015 X40,- /.f RBDMS L r d - 2 p/ Submit Original Only • • SCHEMATIC Dolly Varden Platform Well # D-12RD Hhlcorp Alaska,LLC Completion Date: 07/13/16 CASING DETAIL Size WT Grade Conn ID Top(MD) Btm(MD) 13-3/8" 61 J-55 Buttress 12.515 Surf. 2,537' RKB=34' Rig Floor to TBG Hanger 9-5/8" 40 N-80 Buttress 8.835 Surf. 6,192' 9-S/8" 43.5 N-80 Buttress 8.755 6,192' 8,289' « 9-5/8" 47 N-80 Buttress 8.681 8,289' 9,374' (KOP) .moi. 7" 29 N-80 Buttress 6.184 9,137' 12,031' TT. Mb I4 TUBING DETAIL 1 1 3-1/2" 9.2 L-80 Hyd 563 2.992 Surf 10,528' I' 4-1/2" 12.6 L-80 IMBT 3.958 ±10,540' 10,566' - r) 4-1/2" 12.6 L-80 Buttress 3.958 10,566' 10,646' 4,4 lit i tikv- JEWELRY DETAIL s" A"+ . i ;rM1\'. NO (MD) Depth(TVD) ID OD Item ,, ,w4' '1 41' 41' CIW-DCB_FBB 11 X 3-1/2"EUE 8RD LIFT&SUSP W/3"Type H i' i .1 4, BV ( r A 2,308' 2,221' 2.992 4.800 GLM#1 . �r B 4,200' 3,676' 2.992 4.800 GLM#2-PSPO-1M MBt inC 5,463' 4,684' 2.992 4.800 GLM#3-PSPO-1M e AIR�b4 A-L I D 6,207' 5,254' 2.992 4.800 GLM#4-PSPO-1M E 6,743' 5,675' 2.992 4.800 GLM#5-PSPO-1M lir F 7,215' 6,051' 2.992 4.800 GLM#6-PSPO-1M 'DV Collar G 7,773' 6,499' 2.992 4.800 GLM#7-PSPO-1M iir @ 5,778 H 8,267' 6,887' 2.992 4.800 GLM#8-PSPO-1M I 8,814' 7,315' 2.992 4.800 GLM#9-PSPO-1M IP r J 9,405' 7,770' 2.992 4.800 GLM#10-PSPO-1M ir I K 9,928' 8,228' 2.992 4.800 GLM#11-PSPO-1M L 10,383' 8,640' 2.992 4.800 GLM#12-PSPO-1M TOL @ 9,136' 1111 I / M 10,435' 8,688' 3.000 5.880 7"26-32#Perm.Isolation Packer 4-1/2"LTC N 10,449' 8,700' 2.813 4.450 X-Nipple w/coupling M 0 10,528' 8,773' 4.770 5.990 Non-sealing Overshot Sa 10,546' 8,790' 3.880 5.250 Baker Locator and seal assembly N 5b 10,546' 8,790' 3.880 5.500 Baker 80-47 PBR(L=18.4') la • 6a 10,565' 8,807' 4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566' 8,808' 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension iA 7 10,612' 8,850' 3.813 5.200 Baker X-nipple 5 8 10,646' 8,885' 4.000 5.200 Wireline entry guide(DEFORMED) ,',a 9 11,308' 9,492' 4.000 5.875 Baker FB-1 permanent packer with mill out extension 6 10 11,318' 9,501' 2.992 3.500 3-1/2"9.2 Ib/ft tubing w/Mod BTC(11,318'-11,391') 11 11,392' 9,570' 3.000 4.000 Baker Locator and G-22 locator seal assembly 7 12 11,393' 9,571' 5.000 4.000" Baker FB-1 permanent packer with seal-bore extension ,'i JI P." 8 PERFORATION DETAIL BEWARE! Date Zone Top MD BTM MD Top ND BTM ND Comments EOT Deformed , II 10/1/1999 G-2 10,729 10,752 8,958' 8,979' 2-7/8"HC @ 4-8 SPF 10/1/1999 G-3 10,803 10,832 9,026' 9,053' 2-7/8"HC @ 4 SPF 11/28/2000 G-4 10,856 10,866 9,075' 9,084' 2-7/8"HC @ 600,6 SPF .� 11/28/2000 G-3 10,803 10,823 9,026' 9,045' 2-7/8"HC @ 60°,6 SPF HB-0 11,150 11,160 9,346' 9,355' Open J HB-0 11,190 11,200 9,383' 9,392' Open HB-1 11,225 11,240 9,415' 9,429' Open D , 9 HB-2 11,258 11,268 9,446' 9,455' Open Ag 10 11� 2/5/2017 HB-2 11,268' 11,308' 9,445' 9,492' D50 "ODGeoDynamicsoRazor,6 SPF,60 eo g " 2.50"OD GeoDynamics Razor,6 SPF,60 2/4/2017 HB-2 11,319' 11,335' 9,502' 9,517' Deg Phase "a" HB-3 11,350 11,380 9,531' 9,559' Isolated .Mi 1 2/4/2017 HB-3 11,351' 11,378' 9,532' 9,556' 2.50"OD GeoDynamics Razor,6 SPF,60 E Junk PKR Deg Phase @ 11 540 HB-4 11,412 11,432 9,588' 9,607' Open ABC*.9 ' HB-4 11,440 11,470 9,614' 9,642' Open ''.2 HB-4 11,485 11,520 9,656' 9,688' Open ' +'li{ ,14,.» HB-4 11,530 11,580 9,698' 9,744' Partially covered w/Junk Packer at 11540' HB-5 11,596 11,630 9,759' 9,791' Covered w/Junk and Fill/Debris \ is Junk PKR HB-5 11,690 11,715 9,847' 9,871' Covered w/Junk and Fill/Debris . ' @ 11,894' TD=12,050';PBTD=11,904' Fish/Fill Information: MAX HOLE ANGLE=40°@ 9,300' A. 10/9/93:2-1/8"strip gun 25ft long tag @ 11,581'DIL. B. 10/93:Tag fill @ 11,607'DIL. C. 11/28/89:16 ft long strip gun w/bull nose D. RIH w/2-1/2"JDC and cannot pass 11,384'. E. 2/4/17-Potential Live Shot Left in Hole-approx.11,400' Revised By JLL 02/16/17 • ! in. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-12RD E-Line 50-733-20142-01 180-082 2/2/17 2/5/17 Daily Operations: 02/02/17-Thursday Arrive OSK heliport. Fly to Dolly Varden. Platform orientation. Wait on boat to arrive with E-line unit kit. East crane requires repair before use. Boat arrives. Offload boat with west crane. Continue repair work on east crane. Fly lighter skids of ELU kit to east deck using west crane. MU WHA and lubricator. East crane repaired and operating.Transfer ELU ops cab from west deck to east deck and spot on well. Safety/JSA meeting with Platform operators. RU ELU. PT lubricator and WH stack. Lubricator 0-ring leaks. Lay down lubricator. Break for dinner. Replace failed 0-ring. PU lubricator and MU to WH stack. Restart PT= 250/2500- PASS. LD lubricator.SDFN.Job in Progress. 02/03/17 - Friday Safety meeting and permit. RU ELU. MU GR/CCL Tool suite+Gun# 1 (27.2' GeoDynamics Razor, 2.50" OD, 6spf, 60 deg. phase). CCL to Top Shot= 2.90'. Top Shot to Bottom Shot= 27.2' Open swab, RIH with well flowing (700 BPD), RIW=- 250#. Tool floating and unable to get in hole. PUH into lubricator. Production Operators shut in lift gas and allow well to flow to production line. Initial T/IA/OA= 110/1080/10. RIH slowly, RIW= 250#. Continue TIH. Resume normal trip rates @ 300'. GR goes off scale (500-800 RGR) at 3-1/2"X 4-1/2" tubing transition indicating heavy scale build up on tubular walls. Good CCL indicators. 10,575' WT CHK= 1800#. . Continue RIH and exit tubing tail @ 10,646'. PUH past tubing tail with no weight anomalies. Continue RIH with high RGR in 7" production casing. GR back on scale (75 - 125 RGR) From 11,380'to tag depth. Tag @ 11,420' (UNCORRECTED). Conference call with Ops. & Res. Engineers, decision made to POOH and PU Pulse Neutron suite POOH w/ LIVE Gun# 1. Return to surface. Close Swab. Lay down Gun# 1 and MU RST tool suite (GR/CCL/Pulse Neutron). Rig back to WHA. Open Swab, RIH to tag depth 11,504' (CORRECTED). Pull up for Correlation Pass logging at 20 FPM. Stop logging @ 10,900'. Correction shift log 6' in hole. POOH. Close Swab. Send Corrected Correlation log to GEO for correlation verification. GEO verifies correlated log correction depths. Lay down log suite. RD ELU. Secure well and deck. Return well to production. Shut down for night.Job in Progress. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-12RD E-Line 50-733-20142-01 180-082 2/2/17 2/5/17 Daily Operations: 02/04/17-Saturday Safety meeting and permit. Production Operator shut in lift gas leaving well open to flow line. RU ELU. MU GR/CCL+ 27.2' Perf Gun# 1(2.50" OD GeoDynamics Razor, 6 spf, 60 deg phase).Test GR/CCL at surface. CCL to Top Shot= 2.90'. Initial T/IA/OA= 110/1000/10 Open Swab, RIH. to 11,495' (UNCORRECTED) slack off depth. PUH logging to correlate and correct depth, +4.5' depth shift. RIH to 11.495' (CORRECTED), PUH logging to 11,250' to verify. Return to 11,495', PUH logging to place perf shots on depth. CCL Stop Depth = 11,348.1'. (11,348.1' +2.90' = 11,351'Top Shot) Fire Gun perforating 11,351' - 11378.2'. Good Indication of shots fired at surface. Pre-shot T/IA/OA= 110/990/10 POOH with Gun#1. Post-shot T/IA/OA= 110/990/10. Return to surface, SI swab, L/D Gun# 1. Shots fired. PU Gun#2 (16', 2.50" GeoDynamics Razor, 6 spf, 60 deg. phase). CCL to Top Shot= 6.80' Open Swab, RIH to 11,491' tag depth (UNCORRECTED). Log up to correlate and correct depth, +16.5 depth shift. RIH to 11,485' (CORRECTED). Log up to 11,215'verify depth correction. RIH to 11,496'. PUH logging to place perf shots on depth. CCL stop depth = 11,312.2'. (11312.2' +6.80' = 11,319'top shot). Fire gun perforating 11,319' - 11,335'. Good Indication of shots fired at surface. Pre-shot T/IA/OA= 110/980/10 POOH with Gun#2. Post-shot T/IA OA= 110/980/10. Return to surface. SI swab and L/D Gun#2 Shots fired. PU Gun#3 (19', 2.50" PowerSpiral EnerJet, 5 spf, 60 deg. phase).CCL to top shot= 7.30' Open swab, RIH to 11,458' (UNCORRECTED). PUH logging to correlate and correct depth. -8.0' depth shift. RIH to 11,450' (CORRECTED). Log up to 11,100'to verify depth correction. RIH to 11,450'. PUH logging to place perf shots on depth. CCL stop depth = 11281.7'. (11,281.7+7.30' = 11,289'top shot) Fire perforating gun, NO INDICATION AT SURFACE THAT GUN FIRED. Gun shorted out and no weight loss on line tension. POOH with LIVE Gun. 200#overpulls after entering tubing tail at 10, 646'. Continue PUH. Intermittent overpulls (100#-400#) continue. 9913' CCL depth unable to pull past at 1700#(500#overpull). RIH to 9925'. PUH @ 50 FPM, NO PASS. Repeat @ 100 FPM, NO PASS. Attempt to RIH, Unable to TIH. 9913' CCL depth = 9920'Top Shot.Top of GLM# 11 = 9920'. Continue to work wire, Unable to PUH or TIH. Call Town to discuss with Ops Eng Line up well to lift gas and flow well. Work Wire- No Change Line up water flood to well. Pump water flood to well at 2.10 BPM. Work wire, able to move wire in hole. RIH to 10,100' and stop. PUH, continuing to inject water flood to well. Pull past 9913' CCL depth and continue to PUH slowly. Stop water flood with CCL depth = 8750'. Continue POOH Return to surface. SI well. Final T/IA/OA= 760/1160/10. L/D lubricator and Gun#3.Top 2' of Gun#3 fired perfing 11,289' - 11,291'.Verify 9 of 10 shots in top 2 " of gun fired. No visual verification if missing#10 shot fire. POTENTIAL LIVE SHOT LEFT IN HOLE.All shots and hardware remaining on lower 17' of gun returned to surface. Secure well and deck. SDFN. Return well to production. Job in Progress. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-12RD E-Line 50-733-20142-01 180-082 2/2/17 2/5/17 Daily Operations: 02/05/17 -Sunday Vendor callout for 2 GeoDynamics Razor perf guns (20 X 2.50" OD, 6 spf, 60 deg. phase)to be delivered to OSK dock for marine delivery. Wait on boat to deliver guns to platform Boat arrives. Offload boat. Safety meeting and permit. Shut in lift gas and allow well to flow to production. RU ELU.Test CCL/GR and firing head. PU Gun#4 (20' GeoDynamics Razor, 2.50" OD, 6 spf, 60 deg phase). CCL to Top Shot= 2.90' Open swab. Initial T/IA/OA= 150/1120/15. Unable to RIH,tool suite will not fall. Wait on well flow to fall off RIH with Gun#4 slowly. Trip to 300' and increase trip rate. Slack off weight at 11,465' (UNCORRECTED). PUH to correlate and correct depth, +25' depth shift. RIH to 11,485' (CORRECTED). Log up to verify depth correlation correction. RIH TO 11,482'. PUH loging to place shots on depth at CCL stop depth = 11285.1'. (11285.1' +2.90' = 11,288'TS) Pre-shot T/IA/OA= 125/1080/15. Fire Gun#4 perforating 11,288' - 11,308'. Good Indication at surface Gun#4 fired. Post-shot T/IA/OA= 125/1080/15. PUH logging to 11,110. Stop log. POOH. Return to surface. Shut swab. L/D Gun#4, shots fired. Test GR/CCL and firing head. PU Gun#5. (20' GeoDynamics Razor, 2.50" OD, 6 spf, 60 deg phase). CCL to Top Shot= 2.90'. Rig back to WH RIH with Gun#5 to 10,476' (UNCORRECTED). Log up to correlate and correct depth, +26' depth shift. RIH to 10,479' (CORRECTED). Log up to 11,185'to verify depth correction. RIH to 11,479'. Log up to place shots on depth = 11265.1' CCL stop depth. (11265.1 +2.90' = 11268'Top Shot) Pre-shot T/IA/OA= 140/180/15. Fire Gun#5 perforating 11,268' - 11,288'. Good indication at surface that gun fired. PUH logging to 11,170'. Stop log. POOH. Return to surface. Final T/IA/OA= 140/1080/15. SI swab. L/D Gun#5, shots fired. Secure well and deck. SDFN. Return well to production. Complete ELU RD and prep ELU package for return boat to beach following day.Job Complete and Ended. • • oF h*•P THE STATE A Alaska Oil and Gas o Conservation Commission fALAsKAL Sri � 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF ° p. Main: 907.279.1433 74-16.1s.S� Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis �� j $�� 1t, Operations Manager SCS Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU D-12RD Permit to Drill Number: 180-082 Sundry Number: 317-028 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /69-t41/z Cathy P Foerster Chair DATED this 6.7 day of January, 2017. RBDIIa - 32017 • IS RECEIVED STATE OF ALASKA ZO17 JAN 2 3 ALASKA OIL AND GAS CONSERVATION COMMISSION pis 3 Z 7 APPLICATION FOR SUNDRY APPROVALS A�G�G 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdow❑ Suspend ❑ Perforate Q • Other Stimulate ❑ Pull Tubing ❑ Change Approved Prograr❑ Plug for Redrill El Perforate New Pod El Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC 1 Exploratory El Development E , 180-082, 3.Address: 3800 Centerpoint Drive,Suite 1400 Stradgraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20142-01-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pod? CO 228A • Will planned perforations require a spacing exception? Yes ❑ No 0 f Trading Bay Unit D-12RD • 9.Property Designation(Lease Number): 10.Field/Pod(s): ADL0018729 a McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pods + 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,050 - 10,188 , 11,384 . , 9,562 2,255 psi 11,904 11,540;11,581;11,894 Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,537' 13-3/8" 2,537' 2,403' 3,090 psi 1,540 psi Intermediate Production 9,374' 9-5/8" 9,374' 7,746' 5,750 psi 3,090 psi Liner 2,894' 7" 12.031' 8,445' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,729-11,715 " 8,958-9,871 3-1/2" 9.21 L-80 10,528' 4-1/2" 12.6/L-80 10.56? 4-1/2" 12.6/L-80 10,64? Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Packers(x5)See Schematic See Schematic/ 12.Attachments: Proposal Summary El Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 2 ) Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/10/2017 OIL D - WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown o Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature G L. L) f l..y Phone (907)777-8356 Date (/ 2.3 / 2.0 1"7 COMMISSION USE ONLY Conditions of approval: Notify Co ission so that a representative may witness Sundry Number: ( O25( Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test ❑ Location aearance ❑ r. 5� t I I I Other: t Post Initial Injection MIT Req'd? Yes ❑ No ❑ 2 7 Spacing Exception Required? Yes ❑ Nod ‘--•Subsequent Form Required: /0yQLt RBDP FEBr - ��I APPROVED BY Approved by' COMMISSIONER THE COMMISSION Date: /—iS— `7 1 /.Zf /7Submit Fdrm and Form 10-40311/23/Il vised15 IrGoleNipAt n is valid for 12 mo s from the date of approval. Attachments in Duplicate • • Well Work Prognosis Well: D-12rd Hileorp Alaska,LLC Date: 01/19/2017 Well Name: D-12RD API Number: 50-733-20142-01 Current Status: Oil producer(gas-lift) Leg: Leg#: B-1 (SE) Estimated Start Date: February 10,2017 Rig: E-Line Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 180-082 First Call Engineer: Dan Marlowe (907)283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907)777-8356 (0) Current Bottom Hole Pressure: 3,000 psi @ 8,527'TVD(ESP) 0.352 lbs/ft(6.78 ppg)based on SBHP 05/25/16 Maximum Expected BHP: 3,151 psi @ 8,958'TVD(Top perf) 0.352 lbs/ft(6.78 ppg)based on SBHP 05/25/16 Maximum Potential Surface Pressure:2,255 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) **Note this is a No-Flow Well(07/27/2006),Current SITP is 170 psig,Will not flow based on an expected oil and water gradient of 0.427 psi/ft Brief Well Summary: The D-12rd well is currently completed with a Gas lift string installed July 2016.This project will perforate the Hemlock Bench 2 &3, prior to a scheduled rig workover. Last Casing Test: 07/12/2016 10,435' 1,500 psig for 30 minutes on chart E-line Procedure: 1. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. 2. RU e-line guns and perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic • • Dolly Varden Platform SCHEMATIC Well # D-12RD Hilcorp Alaska,LLC Completion Date: 07/13/16 CASING DETAIL Size WT Grade Conn ID Top(MD) Btm(MD) RKB=34' Rig Floor to TBG Hanger 13-3/8" 61 J-ss Buttress 12.515 Surf. 2,537 9-5/8" 40 N-80 Buttress 8.835 Surf. 6,192' 9-5/8" 43.5 N-80 Buttress 8.755 6,192' 8,289' . 9 `s; 9-5/8" 47 N-80 Buttress 8.681 8.289' 9KOP • i ( ) 7" 29 N-80 Buttress 6.184 9,137' 12,031' 4-'3 " TUBING DETAIL 'f. ft il "44, 3-1/z" 9.2 L-80 Hyd 563 2.992 Surf 10,528' i+'° 4-1/2" 12.6 L-80 IMBT 3.958 ±10,540' 10,566' 4-1/2" 12.6 L-80 Buttress 3.958 10,566' 10,646' al VA * JEWELRY DETAIL w NO Depth Depth ID OD Item a Y N I, (MD) (ND) ; ; , 1 41' 41' CIW-DCB_FBB 11 X 3-1/2"EUE 8RD LIFT&SUSP W/3" ? ,.... Type H BPV A L "^ A 2,308' 2,221' 2.992 4.800 GLM#1-PSPO-1M B 4,200' 3,676' 2.992 4.800 GLM#2-PSPO-1M DV Collar C 5,463' 4,684' 2.992 4.800 GLM#3-PSPO-1M ? '@ 5 778 D 6,207' 5,254' 2.992 4.800 GLM#4-PSPO-1M E 6,743' 5,675' 2.992 4.800 GLM#5-PSPO-1M F 7,215' 6,051' 2.992 4.800 GLM#6-PSPO-1M ti G 7,773' 6,499' 2.992 4.800 GLM#7-PSPO-1M H 8,267' 6,887' 2.992 4.800 GLM#8-PSPO-1M TOL @ 9,136' i I 8,814' 7,315' 2.992 4.800 GLM#9-PSPO-1M J 9,405' 7,770' 2.992 4.800 GLM#10-PSPO-1M M K 9,928' 8,228' 2.992 4.800 GLM#11-PSPO-1M N L 10,383' 8,640' 2.992 4.800 GLM#12-PSPO-1M M 10,435' 8,688' 3.000 5.880 7"26-32#Perm.Isolation Packer 4-1/2"LTC N 10,449' 8,700' 2.813 4.450 X-Nipple w/coupling 0 10,528' 8,773' 4.770 5.990 Non-sealing Overshot *' l5 5a 10,546' 8,790' 3.880 5.250 Baker Locator and seal assembly ' i Sb 10,546' 8,790' 3.880 5.500 Baker 80-47 PBR(L=18.4') 6 6a 10,565' 8,807' 4.000 5.500 Baker KBH-22 anchor seal assembly 7 6b 10,566' 8,808' 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 7 10,612' 8,850' 3.813 5.200 Baker X-nipple :48 , 8 10,646' 8,885' 4.000 5.200 Wireline entry guide(DEFORMED) BEWARE! 9 11,308' 9,492' 4.000 5.875 Baker FB-1 permanent packer with mill out extension EOT Deformed y I 10 11,318' 9,501' 2.992 3.500 3-1/2"9.2 Ib/ft tubing w/Mod BTC(11,318'-11,391') A, 11 11,392' 9,570' 3.000 4.000 Baker Locator and G-22 locator seal assembly . PERFORATION DETAIL ..,,i • Date Zone Top BTM Top BTM MD MD TVD TVD Comments • 10/01/99 G-2 10,729 10,752 8,958' 8,979' 2-7/8"HC @ 4-8 SPF D 1„,,,,,,,,* 9 10/01/99 G-3 10,803 10,832 9,026' 9,053' 2-7/8"HC @ 4 SPF 11/28/00 GA 10,856 10,866 9,075' 9,084' 2-7/8"HC @ 600,6 SPF 10 11 11/28/00 G-3 10,803 10,823 9,026' 9,045' 2-7/8"HC @ 600,6 SPF HB-0 11,150 11,160 9,346' 9,355' Open 'II HB-0 11,190 11,200 9,383' 9,392' Open .10 ,M' 12 HB-1 11,225 11,240 9,415' 9,429' Open HB-2 11,258 11,268 9,446' 9,455' Open "' ll Junk PKR HB-3 11,350 11,380 9,531' 9,559' Isolated • @ 11,540' HB-4 11,412 11,432 9,588' 9,607' Open A,B,C HB-4 11,440 11,470 9,614' 9,642' Open • D HB-4 11,485 11,520 9,656' 9,688' Open D HB-4 11,530 11,580 9,698' 9,744' Partially covered wl Junk Packer at 11540' +� r. Junk PKR HB-5 11,596 11,630 9,759' 9,791' Covered wl Junk and Fill/Debris L @ 11,894' HB-5 11,690 11,715 9,847' 9,871' Covered w/Junk and Fill/Debris «O 11,904' Fish/Fill Information: TD=12,050'; PBTD= A. 10/9/93:2-1/8"strip gun 25ft long tag @ 11,581'DIL. MAX HOLE ANGLE=40°@ 9,300' B. 10/93:Tag fill @ 11,607'DIL. C. 11/28/89:16 ft long strip gun w/bull nose D. RIH w/2-1/2"JDC and cannot pass 11,384'. Revised By JLL 08/09/16 • • Dolly Varden Platform PROPOSED Well # D-12RD lliIcon)Alaska,LLC Completion Date: 07/13/16 CASING DETAIL Size WT Grade Conn ID Top(MD) Btm(MD) RKB=34'Rig Floor to TBG Hanger 13-3/8" 61 J-55 Buttress 12.515 Surf. 2,537' 9-5/8" 40 N-80 Buttress 8.835 Surf. 6,192' 9-5/8" 43.5 N-80 Buttress 8.755 6,192' 8,289' 9-5/8" 47 N-80 Buttress 8.681 8,289' 9'374 (KOP) P ': 7" 29 N-80 Buttress 6.184 9,137' 12,031' :I TUBING DETAIL 3-1/2" 9.2 L-80 Hyd 563 2.992 Surf 10,528' 4-1/2" 12.6 L-80 IMBT 3.958 ±10,540' 10,566' {�- �� 4-1/2" 12.6 L-80 Buttress 3.958 10,566' 10,646' '4 Cr � �, pJEWELRY DETAIL .01Siti al 6•4 44 `.00 i rAto NO (MD) Depth ID OD Item w,q MD TVD 444451, I' .' 41' 41' CIW-DCB_FBB 11 X 3-1/2"EUE 8RD LIFT&SUSP W/3" - 40Z Type H BPV on A 2,308' 2,221' 2.992 4.800 GLM#1-PSPO-1M A-L aB 4,200' 3,676' 2.992 4.800 GLM#2-PSPO-1M p iv ' DV Collar C 5,463' 4,684' 2.992 4.800 GLM#3-PSPO-1M @ 5 778 D 6,207' 5,254' 2.992 4.800 GLM#4-PSPO-1M E 6,743' 5,675' 2.992 4.800 GLM#5-PSPO-1M F 7,215' 6,051' 2.992 4.800 GLM#6-PSPO-1M ir G 7,773' 6,499' 2.992 4.800 GLM#7-PSPO-1M H 8,267' 6,887' 2.992 4.800 GLM#8-PSPO-1M TOL @ 9,136' / I 8,814' 7,315' 2.992 4.800 GLM#9-PSPO-1M 1 9,405' 7,770' 2.992 4.800 GLM#10-PSPO-1M M K 9,928' 8,228' 2.992 4.800 GLM#11-PSPO-1M L 10,383' 8,640' 2.992 4.800 GLM#12-PSPO-1M N M 10,435' 8,688' 3.000 5.880 7"26-32#Perm.Isolation Packer 4-1/2"LTC N 10,449' 8,700' 2.813 4.450 X-Nipple w/coupling 44 0 10,528' 8,773' 4.770 5.990 Non-sealing Overshot 5 5a 10,546' 8,790' 3.880 5.250 Baker Locator and seal assembly A - sb 10,546' 8,790' 3.880 5.500 Baker 80-47 PBR(L=18.4') 6 6a 10,565' 8,807' 4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566' 8,808' 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 7 7 10,612' 8,850' 3.813 5.200 Baker X-nipple 8 , 8 10,646' 8,885' 4.000 5.200 Wireline entry guide(DEFORMED) 9 11,308' 9,492' 4.000 5.875 Baker FB-1 permanent packer with mill out extension BEWARE! ;hill . 10 11,318' 9,501' 2.992 3.500 3-1/2"9.2 lb/ft tubing w/Mod BTC(11,318'-11,391') EOT Deformed,F 11 11,392' 9,570' 3.000 4.000 Baker Locator and G-22 locator seal assembly I.., ' 12 11,393' 9,571' 5.000 4.000" Baker FB-1 permanent packer with seal-bore extension PERFORATION DETAIL 7 s Date Zone Top MD BTM MD Top TVD BTM TVD Comments 10/1/1999 G-2 10,729 10,752 8,958' 8,979' 2-7/8"NC @ 4-8 SPF D i► )' 9 10/1/1999 G-3 10,803 10,832 9,026' 9,053' 2-7/8"HC @ 4 SPF 10 _ 11/28/2000 G-4 10,856 10,866 9,075' 9,084' 2-7/8"HC @ 60,,6 SPF 11= 11/28/2000 G-3 10,803 10,823 9,026' 9,045' 2-7/8"HC @ 60°,6 SPF HB-0 11,150 11,160 9,346' 9,355' Open I. HB-0 11,190 11,200 9,383' 9,392' Open I 'i 1 HB-1 11,225 11,240 9,415' 9,429' Open I Junk PKR HB-2 11,258 11,268 9,446' 9,455' Open ,£ J IL @ 11,540' Future HB-2 ±11,268' ±11,308' ±9,445' ±9,492' A,B,Ci` +i Future HB-2 ±11,319' ±11,335' ±9,502' ±9,517' ' % p= HB-3 11,350 11,380 9,531' 9,559' Isolated + Future HB-3 ±11,351' ±11,377' ±9,532' ±9,556' `�' e'p Junk PKR HBA 11,412 11,432 9,588' 9,607' Open r @ 11,894' HB-4 11,440 11,470 9,614' 9,642' Open ,„%g,5112...1 HB-4 11,485 11,520 9,656' 9,688' Open > 11,904' HB 4 11,530 11,580 9,698' 9,744' Partially covered w/Junk Packer at TD=12,050 ; PBTD= 11540' MAX HOLE ANGLE=40°@ 9,300' HB-5 11,596 11,630 9,759' 9,791' Covered w/Junk and Fill/Debris HB-5 11,690 11,715 9,847' 9,871' Covered wl Junk and Fill/Debris Fish/Fill Information: A. 10/9/93:2-1/8"strip gun 25ft long tag @ 11,581'DIL. B. 10/93:Tag fill @ 11,607'DIL. Revised By JLL 01/19/17 C. 11/28/89:16 ft long strip gun w/bull nose D. RIH w/2-1/2"JDC and cannot pass 11,384'. y OF Tye • re-" I/7-• • THE STATE Alaska Oil and Gas �w ��'9� 0,f LAS 11 COSe2 Vail®1T CommissionCommission A 5 } _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ra Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager Hilcorp Alaska, LLC SC014E 3 � 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU D-12RD Permit to Drill Number: 180-082 Sundry Number: 316-635 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy y Foerster Chair DATED this d y of December, 2016. RBDMS L -BEC 2 8 2016 • • �# I D STATE OF ALASKA DP' 2 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION Z, 'z ` j APPLICATION FOR SUNDRY APPROVALS , LICC 20 MC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well 0 Operations shutdow❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Prograr❑ Plug for RedriN ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other:Combo GL&ESP Completion 0 2.Operator Name: 4.Current Well pass: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0. 180-082 t 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20142-01-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pod? WA Will planned perforations require a spacing exception? Yes ❑ No 0 Trading Bay Unit D-12RD 9.Property Designation(Lease Number): 10.Field/Pod(s): ADL0018729 McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pods 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): ' 12,050 • 10,188 • 11,384 , 9,562 2,255 psi 11,904 11,540;11,581;11,894 Casing Length Size MD IVO Burst Collapse Structural Conductor Surface 2,537' 13-3/8" 2,537' 2,403' 3,090 psi 1,540 psi Intermediate Production 9,374' 9-5/8" 9,374' 7,746' 5,750 psi 3,090 psi Liner 2,894' 7" 12,031' 8,445' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,729-11,715 ' 8,958-9,871 3-1/2" 9.2/L-80 10,528' 4-1/2" 12.6/L-80 10,565 4-1/2" 12.6/L-80 10,645 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Packers(x5)See Schematic See Schematic 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 2/1/2017 Commencing Operations: OIL 0. WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG El Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.corrt Printed Name Stan W.Geis Title Operations Manager Signature iPhone (907)777-8356 Date 1' /1.1 /2"b I L COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number kms. - x.. 5 Plug Integrity ❑ BOP Test / Mechanical Integrity Test ❑ Location aearance ❑ Other: At 2 50 0 /t,S'� a.) 0 ' / s/— iAsT---- 1 Z4 2 -1 I}le 0 / / r/ 4 Post Initial Injection MIT Req'd? Yes ❑ No ❑ :( Spacing Exception Required? Yes ❑ No Subsequent Form Required: /6 / RBDMS vL CEC 2 8 2016 V �D APPROVED BY Approved bye/e�/ COMMISSIONER THE COMMISSION Date: /2 —2...9..-1 , 71/4# �� /,� ® RplirGdiliNaA Submit Forth and Form 10-403�tevised 11/2015 valid for 12 months from the date of approval. , Attachments in Duplicate /d- a7--a ! • Well Work Prognosis Well: D-12rd Hilcorp Alaska,r►c Date: 12/19/16 Well Name: D-12RD API Number: 50-733-20142-01 Current Status: Oil producer(gas-lift) Leg: Leg#: B-1 (SE) Estimated Start Date: February 01,2017 Rig: Moncla 404 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 180-082 First Call Engineer: Dan Marlowe (907)283-1329 (0) (907)398-9904 (M) Second Call Engineer: Stan Golis (907)777-8356(0) Current Bottom Hole Pressure: 3,000 psi @ 8,527'TVD(ESP) 0.352 lbs/ft(6.78 ppg)based on SBHP 05/25/16 Maximum Expected BHP: 3,151 psi @ 8,958'TVD(Top perf) 0.352 lbs/ft(6.78 ppg)based on SBHP 05/25/16 Maximum Potential Surface Pressure:2,255 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) **Note this is a No-Flow Well(07/27/2006),Current SITP is 170 psig,Will not flow based on an expected oil and water gradient of 0.427 psi/ft Brief Well Summary: The D-12rd well is currently completed with a Gas lift string installed July 2016.This work over will replace the Gas-Lift completion with a combination gas-lift ESP to increase drawdown. b44.4.7. ? Last Casing Test: 07/12/2016 10,435' 1,500 psig for 30 minutes on chart Procedure: 1. MIRU Moncla Rig#404. 2. Pull lowest GLV and circulate hydrocarbon off of well.Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. RU E-line and cut tubing at±10,425'. 6. Unseat hanger and POOH with gas-1M completion. 7. PU and RIH with new combo gas-lift/ESP assembly. 8. ND BOP, NU wellhead and test. 9. Turn well over to production. 10. Conduct SVS testing per AOGCC regulations. 1 > 1d e i& l()c " l�/mak, f�s. ( ", "te-V, Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. Wellhead Schematic Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form 0 • Dolly Varden Platform . 11SCHEMATIC Well # D-12RD Hilcor)Alaska,LLC Completion Date: 07/13/16 CASING DETAIL Size WT Grade Conn ID Top(MD) Btm(MD) RKB=34' Rig Floor to TBG Hanger 13-3/8" 61 J-ss Buttress 12.515 Surf. 2,537' 9-5/8" 40 _ N-80 Buttress 8.835 Surf. 6,192' 9-5/8" 43.5 N-80 Buttress 8.755 6,192' 8,289' f ' 9-5/8" 47 N-80 Buttress 8.681 8,289' 9'374 7" 29 N-80 Buttress 6.184 9,137' 12,031' TUBING DETAIL 1.h) 3-1/2" 9.2 L-80 Hyd 563 2.992 Surf 10,528' ' 4-1/2" 12.6 L-80 IMBT _ 3.958 ±10,540' 10,566' 56 ' 4-1/2" 12.6 L-80 Buttress 3.958 10,566' 10,646' JEWELRY DETAIL 111 '�,, NO Depth TVD) ID OD Item k MD " i 41' 41' CIW-DCB_FBB 11 X 3-1/2"EUE 8RD LIFT&SUSP W/3" t 14s Type H BPV �a A 2,308' 2,221' 2.992 4.800 GLM#1-PSPO-1M MN A L i B 4,200' 3,676' 2.992 4.800 GLM#2-PSPO-1M • DV Collar C 5,463' 4,684' 2.992 4.800 GLM#3-PSPO-1M Llig l 1 @ 5,778 D 6,207' 5,254' 2.992 4.800 GLM#4-PSPO-1M •: E 6,743' 5,675' 2.992 4.800 GLM#5-PSPO-1M la i F 7,215' 6,051' 2.992 4.800 GLM#6-PSPO-1M in G 7,773' 6,499' 2.992 4.800 GLM#7-PSPO-1M H 8,267' 6,887' 2.992 4.800 GLM#8-PSPO-1M TOL @ 9,136' I / I 8,814' 7,315' 2.992 4.800 GLM#9-PSPO-1M r J 9,405' 7,770' 2.992 4.800 GLM#10-PSPO-1M M '` K 9,928' 8,228' 2.992 4.800 GLM#11-PSPO-1M N L 10,383' 8,640' 2.992 4.800 GLM#12-PSPO-1M • M 10,435' 8,688' 3.000 5.880 7"26-32#Perm.Isolation Packer 4-1/2"LTC N 10,449' 8,700' 2.813 4.450 X-Nipple w/coupling 0 10,528' 8,773' 4.770 5.990 Non-sealing Overshot 5 5a 10,546' 8,790' 3.880 5.250 Baker Locator and seal assembly b 5b 10,546' 8,790' 3.880 5.500 Baker 80-47 PBR(L=18.4') ^ "" 6 6a 10,565' 8,807' 4.000 5.500 Baker KBH-22 anchor seal assembly 7 6b 10,566' 8,808' 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension , 7 10,612' 8,850' 3.813 5.200 Baker X-nipple .Nimi 8 8 10,646' 8,885' 4.000 5.200 Wireline entry guide(DEFORMED) BEWARE! 9 11,308' 9,492' 4.000 5.875 Baker FB-1 permanent packer with mill out extension t" • 10 11,318' 9,501' 2.992 3.500 3-1/2"9.2 lb/ft tubing w/Mod BTC(11,318'-11,391') EOT Deformed;;r' 11 11,392' 9,570' 3.000 4.000 Baker Locator and G-22 locator seal assembly PERFORATION DETAIL II Date Zone Top BTM Top BTM Comments t MD MD TVD TVD 10/01/99 0-2 10,729 10,752 8,958' 8,979' 2-7/8"HC @ 4-8 SPF D i. ,- 9 10/01/99 0-3 10,803 10,832 9,026' 9,053' 2-7/8"HC @ 4 SPF 11/28/00 G-4 10,856 10,866 9,075' _ 9,084' 2-7/8"HC @ 600,6 SPF I 11 i 11/28/00 G-3 10,803 10,823 9,026' 9,045' 2-7/8"HC @ 600,6 SPF HB-0 11,150 11,160 9,346' 9,355' Open 4 HB-0 11,190 11,200 9,383' 9,392' Open sr' HB-1 11,225 11,240 9,415' 9,429' Open 12 HB-2 11,258 11,268 9,446' 9,455' Open ;. L Junk PKR HB-3 11,350 11,380 9,531' 9,559' Isolated A,B,C M. 11,540' HB-4 11,412 11,432 9,588' 9,607' Open HB-4 11,440 11,470 9,614' 9,642' Open "* , V HB-4 11,485 11,520 9,656' 9,688' Open D HB-4 11,530 11,580 9,698' 9,744' Partially covered w/Junk Packer at 11540' ` Junk PKR HB-5 11,596 11,630 9,759' 9,791' Covered w/Junk and Fill/Debris w r @ 11,894' HB-5 11,690 11,715 9,847' 9,871' Covered w/Junk and Fill/Debris Fish/Fill Information: TD=12 050 PBTD=11,904 MAX HOLE�ANGLE=40°@ 9,300' A. 10/9/93:2-1/8"strip gun 25ft long tag @ 11,581'DIL. B. 10/93:Tag fill @ 11,607'DIL. I C. 11/28/89:16 ft long strip gun w/bull nose D. RIH w/2-1/2"JDC and cannot pass 11,384'. Revised By 1LL 08/09/16 0 0 Dolly Varden Platform PROPOSED Well: D-12RD PTD: 180-082 Hilcorp Alaska,LLC API: 50-733-20142-01 Completion Date: FUTURE CASING DETAIL Size WT Grade Conn ID Top(MD) Btm(MD) 13-3/8" 61 J-55 Buttress 12.515 Surf. 2,537' 9-5/8" 40 N-80 Buttress 8.835 Surf. 6,192' RKB=34' Rig Floor to TBG Hanger 9-5/8" 43.5 N-80 Buttress 8.755 6,192' 8,289' 9,374' 9-5/8" 47 N-80 Buttress 8.681 8,289' (KOP) i t i 7" 29 N-80 Buttress 6.184 9,137' 12,031' ii TUBING DETAIL , II 3-1/2" 9.2 L-80 Hyd 563 2.992 Surf ±8,950' ?' MB'' ti 3-1/2" 9.2 L-80 Hyd 563 2.992 ±10,425' 10,528' MI ,loti 47 4-1/2" 12.6 L-80 IMBT 3.958 ±10,540' 10,566' I4-1/2" 12.6 L-80 Buttress 3.958 10,566' 10,646' i IN 0 JEWELRY DETAIL .*/*. A-I 1 , 4NO Depth Depth ID OD Item `` (MD) (TVD) f 41' 41' CIW-DCB_FBB 11 X 3-1/2"EUE 8RD LIFT&SUSP W/3" ....-5 ' I J Type H BPV ' A ±2,310' ±2,222' GLM#1 i III 8 ±4,200' ±3,676' GLM#2 • C ±5,465' ±4,686' GLM#3 ' 'DV Collar D ±6,210' ±5,257' GLM#4 @ 5,778 E ±6,745' ±5,677' GLM#5 F ±7,215' ±6,051' GLM#6 G ±7,775' ±6,501' GLM#7 J H ±8,270' ±6,889' GLM#8 TOL @ 9,136' / I ±8,815' ±7,316' GLM#9 J ±9,100' ±7,537' Bottom of ESP Cut tubing±10,425' K 10,435' 8,688' 3.000 5.880 7"26-32#Perm.Isolation Packer 4-1/2"LTC K L 10,449' 8,700 2.813 4.450 X-Nipple w/coupling L r,. _l M 10,528' 8,773' 4.770 5.990 Non-sealing Overshot IF 5a 10,546' 8,790' 3.880 5.250 Baker Locator and seal assembly 5b 10,546' 8,790' 3.880 5.500 Baker 80-47 PBR(L=18.4') I. 6a 10,565' 8,807' 4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566' 8,808' 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 6 7 10,612' 8,850 3.813 5.200 Baker X-nipple 1 , 8 10,646' 8,885' 4.000 5.200 Wireline entry guide(DEFORMED) 7 9 11,308' 9,492' 4.000 5.875 Baker FB-1 permanent packer with mill out extension 1 10 11,318' 9,501' 2.992 3.500 3-1/2"9.2 lb/ft tubing w/Mod BTC(11,318'-11,391') :1 13. 11 11,392' 9,570' 3.000 4.000 Baker Locator and G-22 locator seal assembly BEWARE! . 12 11,393' 9,571' 5.000 4.000" Baker FB-1 permanent packer with seal-bore extension EOT V Deformed PERFORATION DETAIL i.. Date Zone Top BTM Top BTM MD MD TVD TVD Comments . 10/01/99 G-2 10,729 10,752 8,958' 8,979' 2-7/8"HC @ 4-8 SPF 10/01/99 G-3 10,803 10,832 9,026' 9,053' 2-7/8"HC @ 4 SPF §`' 9 11/28/00 G-4 10,856 10,866 9,075' 9,084' 2-7/8"HC @ 60.,6 SPF ` 11/28/00 G-3 10,803 10,823 9,026' 9,045' 2-7/8"HC @ 60°,6 SPF r 11� HB-0 11,150 11,160 9,346' 9,355' Open HB-011,190 11,200 9,383' 9,392' Open HB-1 11,225 11,240 9,415' 9,429' Open ' # 12 HB-2 11,258 11,268 9,446' 9,455' Open 'y ' JUnk PKR HB-3 11,350 11,380 9,531' 9,559' Isolated r L J11,540' HB-4 11,412 11,432 9,588' 9,607' Open @ ill HB-4 11,440 11,470 9,614' 9,642' Open HB-4 11,485 11,520 9,656' 9,688' Open ,.~ D HB-4 11,530 11,580 9,698' 9,744' Partially covered w/Junk Packer at 11540' HB-5 11,596 11,630 9,759' 9,791' Covered w/Junk and Fill/Debris j + !�' Junk PKR HB-5 11,690 11,715 9,847' 9,871' Covered w/Junk and Fill/Debris i: v @ 11,894' Fish/Fill Information: TD=12,050'; PBTD= MAX HOLE ANGLE=40°@ 9,300' A. 10/9/93:2-1/8"strip gun 25ft long tag @ 11,581'DIL. Revised by: JLL 12/14/16 B. 10/93:Tag fill @ 11,607'DIL. C. 11/28/89:16 ft long strip gun w/bull nose ll • 0 Dolly Varden Platform D-12RD Current 07/24/2016 Ililenrp:Vnrku.LIA. Dolly Varden Tubing hanger,CIW-DCB- D-12RD FBB,11 X 3''A EUE 8rd lift X 13 3/8 X 9 5/8 X 3 1/2 susp,w/3"type H BPV,3/8 non continuous control line, 6.25"extended neck prep BHTA,Bowen,3 1/8 5M FE X 3"Bowen top ... .. Valve,swab,CIW-FL, 3 1/8 5M FE,HWO,DD •®® trim _„ / Valve,Wing,WKM-M, ®," 3 1/8 5M FE,w/15" ® OMNI operator,DD trim =7 G _ I' I: Valve,master,CIW-FL, 3 1/8 5M FE,HWO,DD = ,„F;® trim 1111111 I Valve,master,CIW-FL, ®�FP 31/85M FE,HWO,DD ,-..,,/, , trim Atimi�,O . 11 ... E -' CCU Tubing head,CIW-DCB, -( _r 13 5/8 3M X 115M,w/2- - a • 2 1/16 5M SSO,X bottom, _.;;p II 0 ii;,, installed in 08/1999 III — lel Valve,WKM-M,2 1/16 5M FE, N style lockpins HWO,DD 0 Qty 2 ..i.1 Illi4.11 1.1, 1100-1.., it III _. 1111 Casing head,CIW-WF, 13 5/8 3M X 13 3/8 casing a,► Valve,CIW-F,2 1/16 5M FE, thread bottom,w/2- III '+ III HWO,AA trim 2 1/16 5M EFO,CA slipsEigl_ - installed in head • l 1 iii • • Dolly Varden Platform D-12RD Proposed 12/19/2016 Hilmrp:Alaska.I.T t Dolly Varden Tubing hanger,CIW-DCB-ESP, D-12RD 11 X 3%1 eue lift and susp,w/ 13 3/8 X 9 5/8 X 3 1/2 3"type H BPV profile,5''A EN, 2-3/8 continuous control line ports,prepped for BIW penetrator BHTA,Bowen,3 1/8 5M FE X 3"Bowen top n, .u. Millit ..r^ •. Valve,swab,WKM-M, ` 3 1/8 5M FE,HWO, :, ,� T-24 Valve,Wing,WKM-M, 'imii4161 3 1/8 5M FE,w/15" ‘•� 1I OMNI operator,DD 111 trim Valve,wing,WKM-M, X4,7.,® " .1 2 1/16 5M FE,HWO, ®�° ®�� , 0 T-24 Yi WI 181 40 Valve,lower master,WKM-M, r,;`( O®,-, 3 1/8 5M FE,HWO,T-24 ®®®;, •1-lit Adapter, CIW-Toadstool, 11 5M Stdd X 3 1/8 5M FE, prepped for 5 1/4 ESP neck, 2-1/npt continuous - i Tubing head,CIW-DCB, - control line ports 13 5/8 3M X 11 SM,w/2- , w_ 2 1/16 5M SSO,X bottom, _•al • • Ir:.= installed in 08/1999 IiI III N style lockpins , Valve,WKM-M,2 1/16 5M FE, k a1 HWO,DD �I®j` O � i1. Qty 2 : I 1 `',...' ill ll lItet:011 IiI IL., at i„, Casing head,CIW-WF, 1 13 5/8 3M X 13 3/8 casing all ��. �- Valve,CIW-F,2 1/16 5M FE, thread bottom,w/2- 1I1 I III HWO,AA trim 2 1/16 5M EFO,CA slips _ _ installed in head PIE', �\ E E • • . fitDolly Varden Platform Moncla BOP 12/19/2016 Hiknrp Alamko.ILIA, lit Iii iii tit111 ii 4.54' Hydril GK 13 5/8-5000 iii litI/illi tit imii IP ill IIl`l!! III .a _l H C lA l ciw-U �'� H Variahle rams 0 a �' 2 7/8-5 -4fl I i 4.67' UI Hi I 13 5/8-5000 I 1 ) H Blind Rams t�f3l I G, 1 Cb 7 )11 fit rain - Choke and Kill valves .. 2 1/16 SM r o ,1i'Iti,llk III III i _ r !rt. 2 26 r : I_ Mud Cross n1 r t i 'i l x 4 1/16 5M EFO X I �I �i r i Ill III Rlser 13 5/8 5M FE X 13 5/8 5M FE 1 I:II l al tii Iii r u. m—"."7.11- - I. Ill I!l iv ie( iill Spacer spool 135/85M FEX115M Iii ill 111'111 itl '= Q O O V O u ', O O V O 0 u O V O u u O u V 0 • 0 2 0 N m V N ti - ry en a to tO n CO CO 5 a, 2 2 2 2 2 2 2 2 2 a a o a d E V u V V V V V u V 0 ri N en < to O) .-1 04 m a N Lb iN CO CO .-1 Y -0 V V "0 "0 "0 U -0 V V 0 0 0 0 L0 0 0 0 0 0 0 0 0 0 N U y C 'C G C 'C 'C 'C C C W t j C C C C C N C 10 . N C N t0 co co 0 d a l O. O. 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OD . q .- to . (O U Z Z r- �f, J Q a a 0 MIn . Nt . Z 0 11 qk 2> J 0 J_ ZCI O K _ aa..0 LL aQ T E2 U m Mm...... 11 0--te 1. 41 . ? kil i w ni O Q m m I— UJ HII_ • p z H co Q -J D 0 Z H W Q EL D U Z Z_ ❑ � a A oWU › ii 2OwCt ° % J J J D J C4 C4 002ZI \ 2 � :1-- 1 J O O f7v tnv QN LL Z � c7 m Z 0 1— Z p J Q, . _ I ._ LL D U Ct U • S • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,ILC Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program —Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT)is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump,(monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) s �r • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska, Attachment#1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close ft valve on standpipe manifold,close valves 1, 2, 10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint,close outside valve on kill side of mud cross,open ft valve of standpipe,close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross, close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to^'1200 psi and bleed off 200—300#5 recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross),open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. • S Moncla Rig 404 BOP Test Procedure [Wog)Alaska,1.1.1. Attachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed(e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP,FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form(10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. 0 0 � ca � .— � � 2 2 & O 2 e c \ E 0o § / / kki E0 < a E — 0 S3 ) = § 1 0. c » a < �. / / Y � 7 ƒ 0 E \.{ � _ § .cn -0a) a) 2 \ � I- z k k W in co >- g's as c o z CL o 0 / 4. % o 1911 13 � ƒ 2 @ u 2 k 0 o c W. 6 kk & o ® k § ag — .c\ co 0 -oO 22 cn 4. J ƒ / 2 @ 2 E § o Q 2 2o a o / / C) S \ v g a) .� 7 in K m kF 2 2 / 0 c w Q 2 2 o. § � 2 o O < A § O 12 M o ct 0. / 0o E o Q $ X o » e § — ■ g e J 0q § � 0 *ii \ ƒ c. q t o0 T k 2 o v 2 E 03 U 2 2 < < o < I STATE OF ALASKA ALA"OIL AND GAS CONSERVATION COMMI ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon El Plug Perforations El Fracture Stimulate El Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool El Repair Well ❑ Re-enter Susp Well 0 Other: Run G/L CompletiofE 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 180-082 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20142-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 Trading Bay Unit D-12RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 12,050 feet Plugs measured 11,904 RCCEIVED true vertical10 188 feet Junk measured 11,540;11,581; 11,894 AUG 0 9 2016 Effective Depth measured 11,384 feet Packer measured See Schematic feet true vertical 9,562 feet true vertical See Schematic fee /`1C'"+ C Casing Length Size MD ND Burst 1 Collapse Structural Conductor Surface 2,537' 13-3/8" 2,537' 2,403' 3,090 psi 1,540 psi Intermediate Production 9,374' 9-5/8" 9,374' 7,746' 5,750 psi 3,090 psi Liner 2,894' 7" 12,031' 8,445' 8,160 psi 7,020 psi Perforation depth Measured depth 10,729-11,715 feet True Vertical depth 8,958-9,871 feet 3-1/2" 9.2/L-80 10,540'(MD) 8,784'(ND) Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6/L-80 10,546'(MD) 8,790'(ND) 4-1/2" 12.6/L-80 10,646'(MD) 8,882'(ND) Packers and SSSV(type,measured and true vertical depth) Packers(x5)See Schematic 12.Stimulation or cement squeeze summary: Intervals treated(measured): 0 r N/A I L a x Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 305 40 1306 140 140 Subsequent to operation: 64 74 1075 960 150 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ DevelopmentE Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG ❑ GINJ 0 SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-286 Contact Trudi Hallett(907)777-8323 Email # thallettCa.hilcoro.com Printed Name Stan W.Golis Title Operations Manager Signature c,._J • 4/ (L.^ Phone (907)777-8356 Date a 14 ii {, )Z FA,•/4RBDMS 1,1- AUG 1 1 2016 Form 10-404 Revised 5/2015 �y /' Submit Original Only //v 11 • • Dolly Varden Platform In SCHEMATIC Well # D-12RD 11r"Icorp Alaska,LLC Completion Date: 07/13/16 CASING DETAIL Size WT Grade Conn ID Top(MD) Btm(MD) RKB=34' Rig Floor to TBG Hanger 13-3/8" 61 1-55 Buttress 12.515 Surf. 2,537' 9-5/8" 40 N-80 Buttress 8.835 Surf. 6,192' 1 "5," 9-5/8" 43.5 N-80 Buttress 8.755 6,192' 8,289' 9-5/8" 47 N-80 Buttress 8.755 6,192' (KOP) 7" 29 N-80 Buttress 6.184 9,137' 12,031' TUBING DETAIL 3-1/2" 9.2 L-80 Hyd 563 2.992 Surf 10,540' I 0 4-1/2" 12.6 L-80 IMBT 3.958 ±10,525' 10,546' 4-1/2" 12.6 L-80 Buttress 3.958 10,577' 10,646' li JEWELRY DETAIL ou NO Depth Depth ID OD Item I (MD) (ND) 0 41' 41' CIW-DCB_FBB 11 X 3-1/2"EUE 8RD LIFT&SUSP W/3" Icy TypeHBPV A-L ,W ' A 2,308' 2,221' 2.992 4.800 GLM#1-PSPO-1M 11illB 4,200' 3,676' 2.992 4.800 GLM#2-PSPO-1M i 'DV Collar C 5,463' 4,684' 2.992 4.800 GLM#3-PSPO-1M gall 5,778 D 6,207' 5,254' 2.992 4.800 GLM#4-PSPO-1M E 6,743' 5,675' 2.992 4.800 GLM#5-PSPO-1M F 7,215' 6,051' 2.992 4.800 GLM#6-PSPO-1M 0 G 7,773' 6,499' 2.992 4.800 GLM#7-PSPO-1M I H 8,267' 6,887' 2.992 4.800 GLM#8-PSPO-1M TOL @ 9,136' \ V / I 8,814' 7,315' 2.992 4.800 GLM#9-PSPO-1M J 9,405' 7,770' 2.992 4.800 GLM#10-PSPO-1M Ma WI K 9,928' 8,228' 2.992 4.800 GLM#11-PSPO-1M N L 10,383' 8,640' 2.992 4.800 GLM#12-PSPO-1M M 10,435' 8,688' 3.000 5.880 7"26-32#Perm.Isolation Packer 4-1/2"LTC N 10,449' 8,700' 2.813 4.450 X-Nipple w/coupling " . 0 10,528' 8,773' 4.770 5.990 Non-sealing Overshot 5 5a 10,546' 8,790' 3.880 5.250 Baker Locator and seal assembly Sb 10,546' 8,790' 3.880 5.500 Baker 80-47 PBR(L=18.4') „ , )1 6 6a 10,565' 8,807 4.000 5.500 Baker KBH-22 anchor seal assembly 6b 10,566' 8,808' 3.875 5.875 Baker SABL-3 permanent packer w/mill out extension 7 10,612' 8,850' 3.813 5.200 Baker X-nipple 8 8 10,646' 8,885' 4.000 5.200 Wireline entry guide(DEFORMED) %, 9 11,308' 9,492' 4.000 5.875 Baker FB-1 permanent packer with mill out extension BEWARE! 11 318' 9 501' 2.992 3.500 3-1 2"9.2 lb ft tubingw/Mod BTC 11 318'-11 391' I1 10 / / ( ) EOT Deformed` 11 11,392' 9,570' 3.000 4.000 Baker Locator and G-22 locator seal assembly II PERFORATION DETAIL . IIIDate Zone Top BTM Top BTM Comments MD MD TVD TVD I 10/01/99 G-2 10,729 10,752 8,958' 8,979' 2-7/8"HC @ 4-8 SPF ♦ 9 10/01/99 G-3 10,803 10,832 9,026' 9,053' 2-7/8"HC @ 4 SPF D '04,,; 11/28/00 G-4 10,856 10,866 9,075' 9,084' 2-7/8"HC @ 60°,6 SPF ir 1011 m 11/28/00 G-3 10,803 10,823 9,026' 9,045' 2-7/8"HC @ 600,6 SPF HB-0 11,150 11,160 9,346' 9,355' Open HB-0 11,190 11,200 9,383' 9,392' Open IME 12 HB-1 11,225 11,240 9,415' 9,429' Open 116-2 11,258 11,268 9,446' 9,455' Open V. ME Junk PKR HB-3 11,350 11,380 9,531' 9,559' Isolated • J @ 11,540' HB-4 11,412 11,432 9,588' 9,607' Open A,B,C 4,4 fatHB-4 11,440 11,470 9,614' 9,642' Open "� V HB-4 11,485 11,520 9,656' 9,688' Open . Junk PKR HB-4 11,530 11,580 9,698' 9,744' Partially covered vi/Junk Packer at 11540' ip4r HB-5 11,596 11,630 9,759' 9,791' Covered w/Junk and Fill/Debris @ 11,894' HB-5 11,690 11,715 9,847' 9,871' Covered w/Junk and Fill/Debris i s*11r' .:r TD=12,050'; PBTD=11,904' Fish/Fill Information: MAX HOLE ANGLE=40°@9,300' A. 10/9/93:2-1/8"strip gun 25ft long tag @ 11,581'DIL. B. 10/93:Tag fill @ 11,607'DIL. C. 11/28/89:16 ft long strip gun w/bull nose D. RIH w/2-1/2"JDC and cannot pass 11,384'. Revised By.ILL 08/09/16 i S Hilcorp Alaska, LLC HilcorpAlaska,LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-12RD Moncla 404 50-733-20142-01-00 180-082 7/7/2016 7/13/2016 7/6/16-Wednesday No Operations to Report. 7/7/16-Thursday Day rig crew,catering personnel, welder and WSM transferred from Grayling to Dolly-stoodby onboard while East crane was being repaired. Tied waterflood back into tb and continued flushing sending returns to TB thru well clean system.Offloaded M/V Titon building rig package as we go. Set strong back beams in place and mounted spacer bars-set carrier in place and mounted draw works,A-frame,walkways and derrick. Off loaded tool connex and set in place.Sent M/V Titon to dock for riser and then to Grayling to P/U 2nd load of W/O equipment. Spooled drill line back on draw works- laid out all derrick cables and lines. Worked 2nd load of W/O equip off M/V Titon spotting drill shack,mud pump,active tank,accumulator,choke house, racking mat and parts connex.Secured rig carrier to platform skid rails-connected accum lines and ran to BOPE area-setup accum remote on carrier walkway-checked returns from waterflood flushing well and shutdown same-monitored well(on vacuum)and knocked off tree cap.NOS rep set BPV then rig crew N/D tree. Checked 4 1/2"IBT lift threads in hanger-prepped control lines. Presently waiting on last load of W/O equipment from Grayling. 7/8/16-Friday Worked M/V Titon with 3rd and final load of W/O equip from Grayling platform. N/U 13 5/8"x 11"5k adapter spool,20'riser,mud cross w/manual& hyd gate valves,double gate ram body Idd w/2 7/8"x 5"variable rams and hydril. Mr.Regg w/AOGCC waived witness on tomorrow's BOPE test by email at 1:14 PM.Raised and scoped out derrick-securing all guy lines. Continue to nipple up BOP,install floor and floor supports,lnstall accumulator hoses, check rotation on accumulator pump had electrician change same, and function test BOP,continue with floor installation installing handrails on same, hook up super choke panel and function test same,fill choke and BOP with test fluid(FIW),fabricate and install hatch cover for riser,and run hoses,lnstall weight indicator,install stairs to rig floor carrier and dog house,spot power pack,rig up McCoy tongs,and dress out floor with tools. Fill pits with FIW, and make up 3.5"test joint. 7/9/16-Saturday f Screw into hanger with 3 1/2"test jt and fill stack w/FIW-closed hydril and shell tested to 2500#s.Tested all BOPE as per Sundry to 250#s low 2500#s high in accordance to AOGCC and Hilcorp requirements-tested with 3 1/2"&2 7/8"tubing-performed successful accumulator draw down test. AOGCC witness waived by Mr.Jim Regg @ 1:14 PM 7/8/16 by email.B/0 2-way check and M/U 3 1/2"PH-6 landing jt-screwed into hanger and lined up to circulate to TBF thru well clean system.Attempted to circulate at 3.5 BPM but pressured up to 2400 PSI at 1 BPM-called for E-Line crew at 13:00 hrs- minimal returns diminishing to zero returns-stopped pumping at 14:45 hrs and prepared to R/U E-Line-Pollard crew and equipment onboard at 15:30 hrs.R/U Pollard E-Line with full lubricator on top of landing joint with full open safety valve,test lubricator to 1000 PSI for 5 minutes all good.RIH with 1.5625 tubing punch loaded with 8 shots(4 SPF)Fired tubing punch from 10153 WLM to 10155 WLM,5"above cross over sub at 10160'WLM in first full joint. Pull out of hole(Misrun)guns not fired,inspect tool string found short. Make up new tool string,run in hole with 1.5625 tubing punch loaded with 8 shots(4 SPF)fired tubing punch from 10153 WLM to 10155 WLM. had good indication of guns firing,POOH,Rig up and circulate down tubing at 3 BPM rate taking returns to the well clean tank caught pressure at 44 bbl away and had fluid back to surface at 112 bbl away,circulating pressure 500 PSI @ 3.5 BPM rate pumped a surface to surface volume with returns coming back clean,shut down pumps with a total of 710 BBL pumped.While circulating perform rig acceptance inspection to include DROPS inspection in derrick. Load out Pollard E-Line unit and tool box on boat to be stored on the Steelhead platform. Spot Summit cable spooler and flat pack spooler,Back out LDS,Pull hanger to rig floor 110K UW,disconnect capillaries from hanger,disconnect connector from penetrator and remove penetrator from hanger,lay down same. Rig up Summit sheaves,and pull cable through connecting to spooler. Rig up power washer,armor on cable is oily.POOH with ESP completion racking back 3.5"Hydrill 563 tubing. • • Hilcorp Alaska, LLC HileorpAlaska,LLC Weekly operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-12RD Moncla 404 50-733-20142-01-00 180-082 7/7/2016 7/13/2016 7/10/16-Sunday POOH from 9270'to 1634'w/ESP completion racking back 3 1/2"9.2#L-80 Hydril 563 tb-pumping 10 bbls every 10 stands.Recovered 145 stands 290 joints total 3.5 563 Hydrill tubing,Clean floor change out handling equipment from 3.5"to 2.875",change dies in tongs.POOH from 1634'to 175'with 2.875 IBT/SCC tubing laying down same recovered 45 Joints 2.875 tubing,Break down and lay down pump and motor,found pump shaft above pump #lbroke.cause of ESP failure. Recovered 191 Cannon clamps,1 spice clamp,1 MLE round cable clamp,5 protectorlizers,all clamps recovered. Both motors checked out good. Rigged down Summit equipment.Clean and clear rig floor clean drill deck around rig,clean cellar and BOP area,wipe handrails, and prep to make scraper run,Make up BHA consisting of 6"Varel bit,7"casing scraper,bit sub,XO 3.5 Regular P x 3.5 563 B,run in hole with 563 pipe from derrick,while SLM in hole,to 8700'. 7/11/16-Monday Continued trip in hole with 6"bit&7"casing scraper,run_a total of 145 stands of 3 1/2"9.2#563 Hydril tb from derrick to a total depth of 8007.00,Make up x-over to 3 1/2"12.95#P-110 PH-6 work string and run singles in hole. Went thru 7"liner top at 9,137'with no issues,continued to trip in hole and tag at 10562.Reverse circulate hole clean,pumping at a 3BPM rate,took 206 BBL to get returns,pumped a total of 435 BBL returns clean shut down pump. Trip out of hole with cleanout assembly laying down 3.5"12.95#P110 work string,continue to trip out of hole racking back 145 stands of 3.5"9.2#Hydril 536 tubing. Break out and laydown cleanout BHA,Note:had slack in cone bearings.Clean floor,change out tongs,conduct PJSM prior to picking up completion.Pick up 5.5"cut lip guide with overshot,2 joints of 3.5 EUE tubing,x-nipple,pups with packer,crossing back over to 563 Hydril,continue to run completion per program drifting tubing in derrick TO 7200'. 7/12/16-Tuesday Continue to run in hole from derrick with 3 1/2"563 Hydril completion per program drifting tubing in derrick TO 9023',continue to run in hole picking up singles to tag @ 10562'up wt 85k,do wt 56k,Attempt to work over tubing stump with overshot,unsuccessful,Rig up Pollard wire line and run in hole with a 2.7 gauge ring to 10551 WLM,tag, unable to pass,Pull out of hole,pick up a 2.7 lead impression block,run in hole and tag same spot,pull out of hole had markings across impression block of obstruction,Run in hole with a 2.81 PX plug body to 10447'WLM,set plug body pull out of hole,and rig down wire line.Pull&lay down 2 joints of 563 tubing for space out. make up CIW DCB EBB tubing hanger with 3.5"EUE connections. Run in hole and land hanger,with tubing tail at 10539',drop ball and bar assembly for PX plug,run in lock down pins,energize tubing hanger seal, and rig up circulating head to set packer.Using rig pump fill tubing and pressure up to 3800 PSI to set packer per Tripoint tech. Had issues getting solid pressure test,found a leaking low torque valve and replaced same. Pressured up to 3800 PSI and charted for 30 minutes all good. Bled pressure off of tubing.Rigged up a high pressure hose to annulus valve with a jumper to the tubing and pressured up tubing X casing annulus too the packer,along with the inside of the tubing to the PK plug,all to 1500 P.S.Lc,hart for 30 minutes good test. Bleed pressure off and pumped through hoses to flush any oil out.Rig up wire line and run in hole with a 2"GDC pulling tool engage PX prong and pulled same well went on a strong vacuum after pulling. Laid down prong and picked up 2"GS pulling tool run in hole and engaged PX plug body and pulled same,rigged down Pollard wire line.Pull landing joint and break down same,clean floor and,set 3"CIW Type"H"BPV through BOP stack with a dry rod.Clean and clear rig floor,prep to disassemble and lay down floor. 7/13/16—Wednesday Cont.rig down rig floor&lay down derrick.Nipple down BOPE,nipple up tree.Test void t/250 &5000,15 min good.Pull TWC.Turn well over to production. • yoFTit 60"\��y/,.�� THE STATE Alaska Oil and Gas ii -�� o f Conservation Commission ALASIc:A � 333 West Seventh Avenue " `' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *� ` Main: 907.279.1433 0.0. ALASY'� - Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager Hilcorp Alaska, LLC SCANNED SEP. 2 8 2016' 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU D-12RD Permit to Drill Number: 180-082 Sundry Number: 316-286 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, i�5� Cathy . Foerster Chair DATED this /day of June, 2016. RBDMS t/t- J',;, 0 2 2016 • • RECEIVED STATE OF ALASKA MAY �5/2Q� ALASKA OIL AND GAS CONSERVATION COMMISSION t `E/ I APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 • Change Approved Program Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:Run G/L Completion 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. I-4t2.1.•' :•,,' Hilcorp Alaska, LLC Exploratory ❑ Development [. 180-082 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20142-01-00 • 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No LI Trading Bay Unit D-12RD • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools x 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 12,050 • 10,188 • ' 11,384 • 9,562 2,255 psi 11,904 11,581 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,537' 13-3/8" 2,537' 2,403' 3,090 psi 1,540 psi Intermediate Production 9,374' 9-5/8" 9,374' 7,746' 5,750 psi 3,090 psi Liner 2,894' 7" 12,031' 8,445' 8,160 psi 7,020 psi Perforation Depth MD(ft): 'Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,729-11,715 • 8,958-9,871 3-1/2" 9.2/L-80 8,741' 2-7/8" 6.4/L-80 10,186' 4-1/2" 12.6/L-80 10,646' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Packers(x5)See Schematic See Schematic / 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/13/2016 OIL 0 - WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarloweahilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature 3T"^� Lam.) Phone (907)777-8356 Date s 2�'-2.0 leo COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: .it 2 56 0 "5 -- 60 P '7— >X Cg's i>� ,-/-e s r l .......D r. P 5 Post Initial Injection MIT Req'd? Yes ❑ No ❑ �/ I RBDMS t-L Juiii 0 2 2016 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: / " T APPROVED BY Approved by: !p, _ COMMISSIONER THE COMMISSION Date: , /-4 Cod`�"I c - Jr' �� "�,�/- 4 Submit Form and 11/2015 owed a 'li Fat' for 12 months from the ate of approval. V r Attachments in Duplicate 0°40712-6 66 Form 10 403 Revised PR PP p • • Well Prognosis Well: D-12RD HBcorp Alaska,LL Date:05/24/2016 Well Name: D-12RD API Number: 50-733-20142-01 Current Status: Oil producer(ESP) Leg: Leg#: B-1 (SE) Estimated Start Date: 6/13/2016 Rig: Moncla 404 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 180-082 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Trudi Hallett (907)777-8323 (0) (907) 301-6657 (M) Current Bottom Hole Pressure: 3,000 psi @ 8,527'TVD(ESP) 0.352 lbs/ft(6.78 ppg)based on SBHP 05/25/16 Maximum Expected BHP: 3,151 psi @ 8,958'TVD(Top pert) 0.352 lbs/ft(6.78 ppg)based on SBHP 05/25/16 Maximum Potential Surface Pressure:2,255 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) **Note this is a No-Flow Well(07/27/2006),Current SITP is 170 psig,Will not flow based on an expected oil and water gradient of 0.427 psi/ft Brief Well Summary The D-12rd well is currently completed with an ESP which failed 05/19/16.This work over will replace the failed ESP with a Gas-Lift completion. Brief Procedure: 1. MIRU Moncla Rig#404. 2. Kill well and circulate Hydrocarbon off of well through ESP.Work over fluid to be FIW. 3. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE.Test all BOP equipment per AOGCC guidelines to 250psi low and 2,500psi high. 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with completion. - • - .. . A _' r. .. minutes. POOH. 8. RIH with bit and scraper to top of tubing at+/- 10,525' 9. Run Gas-Lift completion with live valves, packer, and non-sealing overshot stabbing over tubing at +/- 10,525'. Space out and land completion. 10. Set Packer/ Pressure test completion: a. Pressure up and set packer b. Test tubing against plug in X nipple to 2500#and chart for 30 minutes. V C"4� c. Test IA to 1,500 psi and chart for 30 minutes(This will pressure up tubing also). 11. Set BPV. NU tree,test same. 12. Turn well over to production. C1-.t i 13. Conduct SVS tests per AOGCC regulations. Attachments: 1. Well Schematic/Current 2. Well Schematic/Proposed 3. Wellhead Diagram/Current 4. Wellhead Diagram/Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form 11110 Well Prognosis Well: D-12RD llilcorp Alaska,LL Date:05/24/2016 Well Name: D-12RD API Number: 50-733-20142-01 Current Status: Oil producer(ESP) Leg: Leg#: B-1 (SE) Estimated Start Date: 6/13/2016 Rig: Moncla 404 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 180-082 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Current Bottom Hole Pressure: 3,000 psi @ 8,527'TVD(ESP) 0.352 lbs/ft(6.78 ppg)based on BHP 05/25/16 - Maximum Expected BHP: 3,151 psi @ 8,958'TVD(Top perf) 0.352 lbs/ft(6.78 ppg)base• •n SBHP 05/25/16 Maximum Potential Surface Pressure:2,255 psi Using 0.1 psi/ft gradient ! AAC 25.280(b)(4) "'Note this is a No-Flow Well(07/27/2006),Current SITP is 170 psig,Will not flow based on an expected pil and .er gradient of 0.427 psi/ft Brief Well Summary tt// The D-12rd well is currently completed with an ESP which failed 05/19/16.T► s work over will replace the failed ESP with a Gas-Lift completion. 7 a.. Brief Procedure: 1. MIRU Moncla Rig#404. 2. Kill well and circulate Hydrocarbon off of well throug SP.Work over fluid to be FIW. 3. Notify AOGCC 48 hours before pending BOPE test. -t BPV, ND tree, NU BOPE.Test all BOP equipment per AOGCC guidelines to 250psi low a'd 2,500psi high. 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with completion. P� 6. PU RIH with fishing assembly to remove to• ng stub and seals @ +/-10,525'. Circulate clean. POOH 7. RIH with seal assembly stabbing into sea •ore at 10,546', test casing to 1,500 psi and chart for 30 minutes. POOH. 8. Run Gas-Lift completion. --p• ( s I A - 56.a /0 9. Set BPV. NU tree,test same. FF 10. Turn well over to production. 11. Conduct SVS tests per AOGCC r-:ulations. Attachments: 1. Well Schematic/Current 2. Well Schematic/ Proposed 3. Wellhead Diagram/Curren' 4. Wellhead Diagram/Prop. ed 5. BOP Drawing fUR_PRC _ 6. Fluid Flow Diagrams DED 7. RWO Sundry Revisio hange Form • Dolly Varden Platform s n 0 PROPOSED Well # D-12RD Hileorp Alaska.1.1.0 Completion Date: Future CASING DETAIL Size WT Grade Conn ID Top(MD) Btm(MD) RKB=41' Rig Floor to TBG Hanger 13-3/8" 61 J-55 Buttress 12.515 Surf. 2,537' 9-5/8" 40 N-80 Buttress 8.835 Surf. 6,192' 9-5/8" 43.5 N-80 Buttress 8.755 6,192' 8,289' ', 9,374' ,.`. , 9-5/8" 47 N-80 Buttress 8.755 6,192' (KOP) 7" 29 N-80 Buttress 6.184 9,137' 12,031' aTUBING DETAIL ,- ' 3-1/2" 9.2 L-80 Hyd 563/SCC 2.992 Surf _ ±10,54b' ' li4-1/2" 12.6 L-80 IMBT 3.958 10,525' 10,546' r 4-1/2" 12.6 L-80 Buttress 3.958 10,577' 10,646' :4 t y JEWELRY DETAIL aDepth Depth i, NO (MD) (TVD) OD ID Item y 41' 41' 11"CIW-ESP-DBC Tubing Hangar 4-1/2"IBT 6 A ±2,344' ±2,250' GLM#1 (lib' ' A L . I.* B ±4,230' ±3,700' GLM#2 i C ±5,483' ±4,700' GLM#3 f ,DV Collar D ±6,266' ±5,300' GLM#4 @ 5,778 E ±6,775' ±5,700' GLM#5 F ±7,276' ±6,100' GLM#6 I G ±7,774' ±6,500' GLM#7 fi , t i. H ±8,284' ±6,900' GLM#8 i TOL @9,136' I I ±8,858' ±7,350' GLM#9 / 1 ±9,441' ±7,800' GLM#10 K ±9,953' ±8,250' GLM#11 M _ - L ±10,449' ±8,700' - GLM#12 N M ±10,465' ±8,715' Packer • N ±10,495' ±8,743' X-Nipple 0 ±10,525' ±8,770' Non-sealing Overshot 5a 10,546' 8,790' 5.250 3.880" Baker Locator and seal assembly Sb 10,546' 8,790' 5.500 3.880" Baker 80-47 PBR(L=18.4') 6a 10,565' 8,807' 5.500 4.000" Baker KBH-22 anchor seal assembly Ai ;, 6 ;A 6b 10,566' 8,808' 5.875 3.875" Baker SABL-3 permanent packer w/mill out extension 7 7 10,612' 8,850' 5.200 3.813" Baker X-nipple 8 10,646' 8,885' 5.200 4.000" Wireline entry guide(DEFORMED) 8 9 11,308' 9,492' 5.875 4.000" Baker FB-1 permanent packer with mill out extension BEWARE! 10 11,318' 9,501' 3.500 2.992" 3-1/2"9.2 lb/ft tubing w/Mod BTC(11,318'-11,391') EOT Deformed" III 11 11,392' 9,570' 4.000 3.000" Baker Locator and G-22 locator seal assembly 12 11,393' 9,571' 5.000 4.000" Baker FB-1 permanent packer with seal-bore extension ■ PERFORATION DETAIL ll Date Zone Top BTM s Top BTM Comments MD MD TVD TVD ■ 10/01/99 G-2 10,729 10,752 8,958' 8,979' 2-7/8"HC @ 4-8 SPF D 9 10/01/99 G-3 10,803 10,832 9,026' 9,053' 2-7/8"HC @ 4 SPF 11/28/00 G-0 10,856 10,866 9,075' 9,084' 2-7/8"HC @ 60°,6 SPF 10. f f 11/28/00 G-3 10,803 10,823 9,026' 9,045' 2-7/8"HC @ 60°,6 SPF __ •) HB-0 11,150 11,160 9,346' 9,355' Open HB-0 11,190 11,200 9,383' 9,392' Open 12 HB-1 11,225 11,240 9,415' 9,429' Open HB-2 11,258 11,268 9,446' 9,455' Open 4 �1 Junk PKR HB-3 11,350 11,380 9,531' 9,559' Isolated A,B,C J @ 11,540' HB-4 11,412 11,432 9,588' 9,607' Open V HB-4 11,440 11,470 9,614' 9,642' Open • 1HB- 4 11,485 11,520 9,656' 9,688' Open Junk PKR _. . HB-4 11,530 11,580 9,698' 9,744' Partially covered w/Junk Packer at 11540' HB-5 11,596 11,630 9,759' 9,791' Covered w/Junk and Fill/Debris • "I, . @ 11,894' HB-5 11,690 11,715 9,847' 9,871' Covered w/Junk and Fill/Debris TD= 12,050'; PBTD=11,904' Fish/Fill Information: MAX HOLE ANGLE=40°@9,300' A. 10/9/93:2-1/8"strip gun 25ft long tag @ 11,581'DIL. B. 10/93:Tag fill @ 11,607'DIL. C. 11/28/89:16 ft long strip gun w/bull nose D. RIH w/2-1/2"JDC and cannot pass 11,384'. Revised By JLL 05/31/16 . 11 • SCHEMATIC Dolly Varden Platform Well # D-12RD Hilcorp Alaska,LLC Completion Date: 05/30/2012 CASING DETAIL Size WT Grade Conn ID Top(MD) Btm(MD) RKB=41' Rig Floor to TBG Hanger 13-3/8" 61 J-55 Buttress 12.515 Surf. 2,537' 9-5/8" 40 N-80 Buttress 8.835 Surf. 6,192' �: . 11 • 0 PROPOSED Dolly Varden Platform Well # D-12RD Hilc°rp Alaska,LLC Completion Date: Future CASING DETAIL Size WT Grade Conn ID Top(MD) Btm(MD) RKB=41' Rig Floor to TBG Hanger 13-3/8" 61 J-55 Buttress 12.515 Surf. 2,537' 9-5/8" 40 N-80 Buttress 8.835 Surf. 6,192' '.:`, 9-5/8" 43.5 N-80 Buttress 8.755 6,192' 8,289' A 9-5/8" 47 N-80 Buttress 8.755 6,192' (KOP) 7" 29 N-80 Buttress 6.184 9,137' 12,031' 1, *;; TUBING DETAIL -e'...:4 3-1/29.2 L-80 Hyd 563/SCC 2.992 Surf ±10,546' 43-_11//22:: -1/212.6 L-80 Buttress 3.958 10,577 10,646' EWELRY DETAIL NO Depth Depth OD ID Item •�, ., (MD) (ND) ,. ' 41' 41' 11"CIW-ESP-DBC Tu."g Hangar 4-1/2"IBT A ±350' ±350' SSSV B-M B ±2,344' ±2,250' GLM#1 1 DV Collar C ±4,230' ±3,700' GLM#2 @ 5,778 D ±5,483' ±4,7%I' GLM E ±6,266' +',300' G , #4 „� F ±6,775' ±5,700' LM#5 G ,-,17,276' ±6,100' GLM#6 H ±7)74' ±6,500' GLM#7 I ±$,2 ±6,900' GLM#8 i e J ±: :58' ±7,350' GLM#9 q TOL @ 9,136' j `--A-K9,441' ±7,800' GLM#10 L ±9,95 ' ±8,250' GLM#11 M ±10,449' ±8,700' GLM#12 10,546' 8,790' 5.250 3.880" Baker Locator and seal assembly 5 Sb 10,546' 8,790' 5.500 3.880" Baker 80-47 PBR(L=18.4') .'..r 6a 10,565' 8,8e 5.500 4.000" Baker KBH-22 anchor seal assembly ,f 6 6b 10,566' •,:08' 5.875 3,875" Baker SABL-3 permanent packer w/mill out extension 7 10,612' '8,850' 5.200 3,813" Baker X-nipple A 7 8 10,646' 8,885' 5.200 4,000" Wireline entry guide(DEFORMED) 9 11,308' 9,492' 5.875 4.000" Baker FB-1 permanent packer with mill out extension ' ":14/ 8 1` 10 11,318' 9,501' 3.500 2,992" 3-1/2"9,2 lb/ft tubing w/Mod BTC(11,318'-11,391') BEWARE! # 11 11,392' 9,570' 4.000 3.000" Baker Locator and G-22 locator seal assembly EOT Deformed! III 12 11,393' 9,571' 5.000 4,000" Baker FB-1 permanent packer with seal-bore extension r" PERFORATION DETAIL 1t Date Zone MD MD TVD TVD Comments • ,,. .. .., . 10/01/99 G-2 10,729 10,752 8,958' 8,979' 2-7/8"HC @ 4-8 SPF •10/01/99 G-3 10,803 10,832 9,026' 9,053' 2-7/8"HC @ 4 SPF D IMS 9 11/28/00 G-4 10,856 10,866 9,075' 9,084' 2-7/8"HC @ 60,6 SPF 11/28/00 G-3 10,803 10,823 9,026' 9,045' 2-7/8"HC @ 600,6 SPF ' A 11 II HB-0 11,150 11,160 9,346' 9,355' Open HB-0 11,190 11,200 9,383' 9,392' Open g; HB-1 11,225 11,240 9,415' 9,429' Open 12 , HB-2 11,258 11,268 9,446' 9,455 Open IA ' ,i{tnk PKR HB-3 11,350 11,380 9,531' 9,559' Isolated @ 11,540' HB-4 11,412 11,432 9,588' 9,607' Open • l,C t HB-4 11,440 11,470 9,614' 9,642' Open i rt' '1'1 y HB-4 11,485 11,520 9,656' 9,688' Open b HB-4 11,530 11,580 9,698' _ 9,744' Partially covered wl Junk Packer at 11540' 60, D HB-5 11,596 11,630 9,759' _ 9,791' Covered w/Junk and Fill/Debris + "* Junk PKR ' >:� �'+ X%21 @ 11,894' HB-5 11,690 11,715 9,847' 9,871' Covered w/Junk and Fill/Debris 4, ` *Oro, Fish/Fill Information: TD=12,050'; PBTD=11,904' A. 10/9/93:2-1/8"strip gun 25ft long tag @ 11,581'DIL. MAX HOLE ANGLE=40°*9,300' B. 10/93:Tag fill @ 11,607'DIL. C. 11/28/89:16 ft long strip gun w/bull nose D. RIH w/2-1/2"JDC and cannot pass 11,384'. Revised By JLL 05/24/16 , ll • 0 Dolly Varden Platform D-12RD Current 05/24/2016 Hik'nrp%Isola,HA, Dolly Varden Tubing hanger,CIW-DCB-ESP, D-12RD 11 X 41/:IBT lift and susp,w/ 13 3/8 X 9 5/8 X 4 1/2 4"type H BPV profile,5'%<EN, 2-3/8 continuous control line ports,prepped for BIW penetrator BHTA,CIW,4 1/16 5M FE X Cameron internal blanking nut ill III II Valve,swab,WKM-M, 4 1/16 5M FE,HWO, T-24 �-c III MIN.III mom 1 Valve,wing,WKM-M, ��'= � Valve,WKM-M,3 1/8 5M FE,w/ 21/165M FE,HWO, �� l MA-16 operator T-24 • look Hi lit g Valve,lower master,WKM-M, _ 41/16 SM FE,HWO,T-24 ili III Ill MINIF III III Adapter,CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped for 5%ESP neck,2-'/z npt continuous I Tubing head,CIW-DCB, '�i control line ports 13 5/8 3M X 11 5M,w/2- , i ' 2 1/16 5M 550,X bottom, :al � Ir:.- installed in 08/1999 it I tik1!k N style lockpins ' Valve,WKM-M,2 1/16 5M FE, ra HWO,DD ! c '`" I - —"m ® Qty 2 In 1!k Casing head,CIW-WF, �•► 13 5/8 3M X 13 3/8 casing MI 1I� Valve,CIW-F,2 1/16 5M FE, thread bottom,w/2- 1.11 1 Iii _ HWO,AA trim 2 1/16 5M EFO,CA slips installed in head I 1.11111(11*111 II= • •• , llDolly Varden Platform D-12RD Proposed 05/24/2016 Hi'rump:tInM1.0.1.IA. Dolly Varden Tubing hanger,CIW-DCB- D-12RD FBB,11 X 3%EUE 8rd lift X 13 3/8 X 9 5/8 X 3 1/2 susp,w/3"type H BPV,3/8 non continuous control line, 6.25"extended neck prep BHTA,Bowen,3 1/8 5M FE X 3"Bowen top 111 tel MiMM Valve,swab,CIW-FL, ' 0. `i' 3 1/8 5M FE,HWO,DD Valve,Wing,WKM-M, _ trim sc3 1/8 5M FE,w/15" ity OMNI operator,DD NEW miaow,. trim N I . ) ami, Valve,master,CIW-FL, 31/85MFE,HWO,DDz. r. trim 6, Valve,master,CIW-FL, �` 3 1/8 5M FE,HWO,DD - '`;' trim .. Tubing head,CIW-DCB, i C � :- 13 5/8 3M X 11 5M,w/2- c _ 2 1/16 5M SSO,X bottom, ,. ii . , • is: installed in 08/1999tib — III Valve,WKM-M,2 1/16 5M FE, N style lockpins HWO,DD i # '2' i g #V r* Qty 2 c ii-.4111 41 ,,, 1., , ...ii :111 iii-i. 1!1 _!' , III 1111 . Casing head,CIW-WF, ii 1i► 13 5/8 3M X 13 3/8 casing ��► Valve,CIW-F,2 1/16 5M FE, thread bottom,w/2- III jt 1i1 HWO,AA trim 2 1/16 SM EFO,CA slips _ - installed in head MU 11.114101411111 I. .1101. J • Dolly Varden Platform BOP Stack(Moncla) Hi'curia Iarku.1.1A • O Ill If! Iiifrtl m l ittifill 3.74' Shaffer 135/85M I. Iii III ill III II IvII.I ISI I I __ ciw-U �� Variable 27/8-5 mil 4.67' _ 13 5/8-5000 _ i1 Imo_Blind Rams massmimmor 481..A SWWIII iii ifl II11I 1 Choke and Kill Valves 2 1/16 SM w/Unibolt connections for hoses lil,Ifl III li( 111 400/.. 2 00' IV e l.�: VEITTEPTCPUTV Riser,13 5/8 5M FE X 13 5/8 SM API#13 hub 13.70' C • 1 • O U '" ?O O V O U O O U O O V O U O V O D U O V U 0 d O • N m a to N N m a to tO n 00 01 2 71 C d d d O. O. J V U U V U U V U U O N N M V N O1 .'9 N no 7 to tO I, CO 01 v 'o o o v o v v a v v0 t v V V O 0000 U N 0 0 0 0 0 0 0 Ol a C C C C C O y E c c c c c c c c O O > y O. 2 2 O. o. C C j O1 111311" -8 -8 -8 -8k2 Ti O) Ol a _> E £ E E E = o 222222 _ = = , `w N J J J J J — = V t V U U U N � d O_ d O. d Y Y 2 U V U l./ V V V V V V V H uo ru t U U K 14 14 N CA Imo - 00 - IA - l0 . U Z Z 1_,....- �•. Ifi J CL LU Q a O 0 M , vt . ZO II 1 O o a0Q LL d W K> E H [J O =� stff,, I] 1] il Yv .: iii in / I, a m � v) w H a a 0 z co z 0 o ~ w Z aDz A D H Dj AsJU7J 111 a r. CL 0 [ Z_ o 001— a0i_ Z QQU) D C(DEw V c a Z N a � � qk -- w N N UU- Q0U 2 D r HZ act ZZ W qko qkg 03 z J a DJ N / .. a .- LL LUL . . • :42 `,10 ,..) 000 0 0 0 0 O U O U O U O D U O D U O 0 0 u , a , -. 'i N M a vt CO N 00 0, 5 ddada 0 U . 0U00000U00 , N Ca a La Ol N N M a M CO N 00 Ol N a a a a a p a a a a a a a a a a 22000 -C N C C C C Y 0000000000 O y C C C C C O1 C C C C C E L ] o .. 0- 0- 0- o- ± C > N 0 N 000000000000mJ wEEEEE ± U o .0 0 L L L O L 0 0 0 g T > d d CS0 YSU U U U U U U U U U U 0, In a • a O. O Y w LL O C to a r0 # U A 0 O N K OE e-- 1 11 In . (o . ZZ r-� I--...-1� IL I w Ili Q Etc) r') . * . zo �U �U LL, Et> U-, ce ma O wI , a¢ w_ ET cn ■ =U s} C' : CODtilai 401 Ellp m m 11 0 m F CO W H O. E. 0 z 1- w Q J D z O Z �- W Z a ° z o 1__Il I Da J� J Z ❑ � a A w LTQ o � OV •>_ a " ~Lt g ? < oo2Z = C 2 _ � � c � OQO " r7 u) aN 4k 4k 1 O D Z C7 I-a Z 5 J < +111 f >,i Ilr law u... J D 0 Et 5 • • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska. Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT)is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. if the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump,(monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) • Moncla Rig 404 BOP Test Procedure Mem")Alaska.IJ.f, Attachment#1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 15t valve on standpipe manifold,close valves 1, 2, 10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross,open 1st valve of standpipe,close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross,close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to^ 1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross),open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. • • Moncla Rig 404 BOP Test Procedure Hikorp Alaska.LLC Attachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and NCR. Close 2nd set of pipe rams if installed(e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP,FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. ii 9 • cDul0 a) � � I o & ci c 7 E c o § .q / 2k ° § / < a E ® E E -a \ k Q / �f 7a) 2a. .2 / E « \ / kA3 � �- > = f �� / \.§ 0. g 7 §• .0_ n -0 a) a) 2 % Nr � � k k $ %% co �>- E\ 2 t @ Co/ B k t / a) I- _a - O k ( Ci Csi > C) /la re e 0t k , 0 \ — 0 C ° -003 0 & / § Jc < _ k K E § 2 / •'K 2 _a / / Ua. a) »% co CC to § //a co Qp C La ■ _ 0 ■ tu J 7 � % 0 a. K % « 4) >o 0 0. � � E - . m0 Q ■ q 2 I- co x m � 0 OS / co a) $ 2 .000 0 ( 7 £ 2 / .. 7 0 � & as E 0 & / c O co 2 k k / fa a_ . U) • • Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Tuesday, May 31, 2016 12:08 PM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett Subject: RE: D-12RD (PTD 180-082) Attachments: D-12RD Proposed 2016-05-31.doc; D-12rd Well Work Prognosis for State 2016-05-31.docx Guy In 2012,the tubing was cut on the old gas lift completion at 10,525' ELM for the Cudd unit workover We have been discussing this as a team and have a revised plan given the project economics. I have attached a better schematic for you as well as updated the procedure to more accurately reflect the process Give me a shout and we can discuss the best way to facilitate this Thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe(c�hilcorp.com Hilcorp A Company Built on Energy From: Schwartz, Guy L(DOA) [mailto:guy.schwartzCa�alaska.gov] Sent: May 31, 2016 11:36 AM To: Dan Marlowe Subject: D-12RD (PTD 180-082) Dan, In your procedure you mention fishing a tubing stub and seals at 10525'. I don't see this on the schematic as well is now with the ESP completion?? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged 1 STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COMMISIPON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other 12 Convert to ESP /Replace tubing Performed: Alter Casing ❑ Pull Tubing 0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program El Operat. Shutdowrn❑ Stimulate - Other ❑ Re -enter Suspended Wells❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ 180-082 '" 3. Address: 3800 Centerpoint Drive, STE 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99503 50733201420100 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018729 / Dolly Varden Platform Trading Bay Unit D -12RD • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): McArthur River Field / Hemlock Oil and Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 12,050 feet Plugs measured 11,904 feet true vertical 10,188 feet Junk measured 11,581 feet Effective Depth measured 11,904 feet Packer measured 10,566, 11,308; 11,393 feet true vertical 10,050 feet true vertical 8,808; 9,492; 9,571 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 2,537' 13 -3/8" 2,537' 2,403" 3,090 psi 1,540 psi 1 Production 10,297 9 -5/8" 10,297' 8,561' 5,750 psi 3,090 psi Liner 2,894' 7" 9,137'- 12,031' 7,565- 8,445' 8,160 psi 7,020 psi 1 Liner Perforation depth Measured depth See Attachment #1 feet True Vertical depth See Attachment #1 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" L -80 12.6# 10,650' MD 8,885' (TVD) Baker SABL -2 packer 10,566' (MD) 8,808' (TVD) R� e r Packers and SSSV (type, measured and true vertical depth) Baker FB -1 packer 11,308' (MD) 9,492 (TVD) CEI a , Baker FB -1 packer 11,393' (MD) 9,571' (TVD) Y 12. Stimulation or cement squeeze summary: �`, J ff�� y �I:lv 2 Intervals treated (measured): ii M� J IJ L 2 4 L U t Z 9 2012 N/A AOGC Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 209 726 732 960 160 Subsequent to operation: 207 139 2000 110 120 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory El Development 0 ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: • Oil 0 Gas ❑ WDSPL GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 3 /Z. -14 Contact Ted E. Kramer Printed Name Ted E. Kramer Title Operations Engineer Signature < ' / ' G Phone 907- 777 -8420 Date 6/28/2012 ■ Vi'" !' '44,-) 6.2-7 z_ /' h Z RBDMS JUN 2 9 nil , / iffr Form 10-404 Revised 11/2011 Submit Original Only • • Hilcorp Alaska, LLC Attachment #1 Dolly Varden D -12RD Perforation Data June 26, 2012 Zone MD TVD G -2 10,729' - 10,752' 8,958' - 8,979' G -3 10,803' - 10,832' 9,028' - 9,053' G -4 10,856' - 10,866' 9,075' - 9,084' HB -0 11,150' - 11,160' 9,346' - 9,355' HB -0 11,190' - 11,200' 9,383' - 9,392' HB -1 11,255' - 11,240' 9,415' - 9,429' HB -2 11,258' - 11,268' 9,446' - 9,455' HB -4 11,412' - 11,432' 9,588' - 9,607' HB -4 11,440' - 11,470' 9,614' -9,642' HB -4 11,485' - 11,520' 9,656' -9,688' HB -4 11,530' - 11,580' 9,698' -9,744' • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -12RD 507332014201 180 -082 5/15/12 6/2/12 Daily Operaltlorxs: 05/19/2012 - Saturday Mix 700 h ose I KCL and from tree and cap same. R U circulating 00 bb s 3/o C a d transf to 400 bbl upright ht tanks. Remove flowline o t ee a d s p g p / to tree. Test high pressure lines to 2000 psi. Open well and displace with FIW to production at 4 bpm. Took 95 bbls to catch fluid (6240'). Continue at 4 bpm /250 psi until clean FIW returns at surface. Over displaced calculated volume by 230 bbls (mostly crude oil). Begin mixing spacer and sized salt pill. After two hours bring pump back on line until fluid level caught and returns to surface to calculate estimated loss rate @ 70 bbls per hour. Continue mixing sized salt pill. Pump spacers and sized salt pill @ 4 bpm /150 psi until lead at tbg punch holes (no returns to annulus). Shut in annulus. Had squeeze pressure almost immediately. Hesitation squeeze 5 bbls / 800 psi into perfs. 05/20/2012 - Sunday Displace annulus to 3% KCL taking returns to production @ 3 bpm /500 psi. After 1/2 hour 0 losses. Set BPV. Nipple down tree. Inspect and verify threads in tubing hanger to be 4 1/2" EUE. Nipple up spools and riser to drill deck. Nipple up stack: single gate, mud cross, double gate, annular and bell nipple. Torque bolts, install hydraulic fittings, run Koomey hoses, spot and wire in test pump, install choke hose. Make up floor valves and IBOP's for testing. R/U choke console, choke and kill hoses, etc. Fill accumulator with hydraulic oil. 05/21/2012 - Monday N/U BOPE. R/U nitrogen bottles to accumulator. Install flow sensor on flowline. M/U 3 1/2" test joint. Add hydraulic fluid to accumulator. Screw test joint into tubing hanger. Install floor valve and dart valve on top of test joint. Function test BOP's. Test remainder of manifold valves, choke and kill line valves @ 250L / 2500H. Perform accumulator test: 4 min 50 D � seconds for full charge. Pull 3 1/2" test joint. M/U 4 1/2" test joint. CUDD had to readjust the gin pole to be able to M/U joint. Fluid drained out of stack, past two -way check valve when 3 1/2" test joint was pulled. Mix 100 bbls 3% KCL. Test annular, top and bottom VBR's with 4 1/2" test joint. Pull and lay down 4 1/2" test joint. Begin filling hole with 3% KCL. Took 75 bbls to fill stack. Shut down filling and fluid level dropping rapidly. Pull BPV and set two -way check for testing blind rams.,Test BOP to 250 psi low and 2.500 psi high witnessed by Lou Grimaldi. 05/22/2012 - Tuesday Test blind rams 250L/2500H. Pull two -way check. Make up landing joint while mixing additional 3% KCL. Circulate down tubing and up annulus to production header. Back out lock down pins. R/U a -line. RIH with radial torch cutter. pull string weight up to 180K (20K over) and cut tubing at 10,525'. String weight dropped to 130K. Fluid losses jumped to 30 BPH. POOH with a -line and R/D same. Mix sized salt pill while rigging up power tongs. Pump and spot second 50 bbl sized salt pill to minimize losses to well bore. Monitor well on trip tank and establish 5 - 6 bbl /hr loss rate. Pull tubing hanger and lay down same. P/U wt = 118K S/O wt = 64K. POOH laying down 4 1/2" tubing. 1 BPH Toss rate. 05/23/2012 - Wednesday POOH laying down 4 1/2" tubing. • • 05/24/2012 - Thursday Continue POOH laying down 4 1/2" tubing and jewelry. Spot and R/U slick line. RIH with 3.83" bell guide & tagged up @ 6,312'. RIH with 1.5 bailer and collect sample @ 6,312'. R/D slick line. Change out stationary dies. Change slip dies to 3 1/2 ". Scope out gin pole. R/U lay down line. Strap top row of 3 1/2" tubing. P/U 3 1/2" 563 tubing and stand back. Drift each joint of tubing as it is picked up. 05/25/2012 - Friday Cont. P/U 3.5" 563 tbg, rabbiting and racking back, total of 153 stands racked back and 2 jts on deck; too short to rack back. Changed out tubing tongs for hawk jaws; P/U 4" HT -38 DP, torque to 18k, rabbiting and racking back, total of 25 stds racked back. Start M/U of BHA on deck. 05/26/2012 - Saturday RIH with bottom of BHA, run in 47 jts of 3.5" 563 tubing. Changed out Weatherford tongs for Hawk Jaws. P/U and M/U 9 5/8" scraper. Chg out Hawk jaws for tongs. RIH w/ 3.5" 563 tubing @ stand #101 to 6,053'. RIH w/ 3.5" 563 tubing, from stand #101 to #110 ran in slow due to slick line tag @ 6,300' + -. RIH w/ 3.5" 563 tubing @ stand #154 to 9,247'. P/U 85k, S/O 45k. RIH w/ 4 "HT -38 DP @ stand #172. 05/27/2012 - Sunday Finish RIH with CO asst', no obstructions. Tagged @ 15' in stand #176, 10,541'. Broke stand and install TIW. POOH with clean out assy and stand pipe back in derrick. Lost a tong die (down tbg at jt # 133 (7,996') will look for it in BHA. Left msg on AOGCC Jim Regg phone at 16:45 hrs of 48 hr notice of BOPE test on 5/28/12. POOH w/ clean out BHA, 3.5" 563 tubing, standing pipe back in jack, 2 stands left to pull. 05/28/2012 - Monday Break down clean out BHA, lay down WOT Hawkjaw tongs, PU WOT tubing tongs. Lay down BHA, both scrapers had black dehydrated substance on them. Did not recover tong die RU WL unit. Left 2nd msg on AOGCC machine of 5/28/12 BOPE test at 0800 hrs. Rcvd call f /AOGCC Jim Regg. Jim Regg waived BOPE test in it's entirety. RIH #1- 4.50" swage sticky. At 9,270' PU fell thrutag at 10,558'. RIH #2- 3.50" swage sticky, at 10,625' PU fell thru. Run btm tool string thru TT at 10,650' 05/29/2012 - Tuesday Continue RU of ESP running equip. Start MU /RIH with ESP assy. Install clamps and pump oil untill clean oil return returns. MU flat pack and power cable, test good. MU 2 7/8 "x3.5" XO, run 1 jt 2 7/8" tbg, install chem inj lines and test good. Secure well conduct cable cutting drill, service and fuel equip. RIH with 45 jts 2 7/8" tbg clamping cable and flat pack each jt. Test cable - good test. RIH with 3.5" tbg clamping every other jt. S/O wt 16k - 54 clamps in hole. 05/30/2012 - Wednesday Continue RIH with ESP assy placing clamps on 3 -1/2 " tbg every other jt and testing cable every ^'1,000'- Slow down thru DV collar at 5,778' cont RIH to 6,001' prep to make cable splice. Make and test cable splice and tested flat pack - good test (splice on bottom off jt # 76) at 6,090'. Continued RIH 3.5" tbg to 10,357'. P/U and M/U tubing hanger. Start to make -up cable and chem lines to hanger. 05/31/2012 - Thursday Continue M/U hanger, cable and chem. lines. PU pull slips, drain stack, test cable, install cap on chem lines and TIH land hgr. Engage LDS, fill void test to 5,000 psi. LD landing jt prep to ND BOPE. ND bell nipple off stack, scope down bottom section of gin pole, spot BOPE stands. RD hoses to up right tanks, break BOPE , install rigging. Rigging complete, remove Hydril, Rams and spool pieces, place on BOPE stands and secure. Prep hanger, test ESP cable, install 2 -1/6" casing valve, 06/01/2012 - Friday Test flow line and POOH. Turned well over to production. 1 i • Dolly VA IL Platform Well # 12RD Ililcorp Alaska, LLC Actual Workover Completion Date: 8/16/99 Casing Detail SIZE W T GRADE CONN ID MD MD RKB = 41' Rig Floor to TBG Hanger TOP BTM. 13- 61 J -55 Buttress 12.515 Surf. 2,537' 6 i :� 3/8„ t �r 9 -5/8" 40 N -80 Buttress 8.835 Surf. 6,192' 9 -5/8" 43.5 N -80 Buttress 8.755 6,192' 8,289' 9 -5/8" 47 N -80 Buttress 8.755 6,192' 10,297' 4,44 7" 29 N -80 Buttress 6.184 9,137' 12,031' '` Tubing Detail j 3 -1/2" 9.2 L -80 Buttress 2.992 49' 8,741' t�.4? k:'�`` 2 -7/8" 6.4 L -80 IBT 2.441 8,741' 10,186' f 6! i. Jewelry Detail ; ,,+ NO Depth Length ID Item l i * * 'ti' +, 41' 0.6' 11" CIW- ESP -DBC Tubing Hangar 4 -1/2" IBT 1 42' 7.2' X /Over 4.5" IBT to 3.5" IBT pin /pin to 3.5" HYD 563 ' ' DV Collar 2 8,741' 1.4' 2.441 X /Over 3.5" HYD 563 x 2 -7/8" ITB 5'778 3 10,171' 14.6' 2.441 X/O Sub 2 -7/8" IBT x 2 -7/8" 8RD EUE, 6.4 #/ L: -80 4 10,186' 160.0' SLB D2400N, 432HP ESP Pump Assembly 5a 10,546' 3.880" Baker Locator and seal assembly I 2 5b 10,546' 3.880" Baker 80 -47 PBR (L = 18.4') g 6a 10,565' 4.000" Baker KBH -22 anchor seal assembly TOL @ 9,136' ` I / 6b 10,566' 3.875" Baker SABL -2 permanent packer w /mill out extension . 7 10,612' 3.813" Baker X- nipple • 8 10,650' 4.000" Wireline entry guide (DEFORMED) 4 9 11,308' 4.000" Baker FB -1 permanent packer with mill out extension M, 10 11,318' 2.992" 3 -1/2" 9.2 lb/ft tubing w/ Mod BTC (11,318'- 11,391') 1 a' : >. ' 6 11 11,392' 3.000" Baker Locator and G -22 locator seal assembly X 7 12 11,393' 4.000" Baker FB -1 permanent packer with seal -bore extension Perforations , 8 Date Zone Top BTM Comments ." 10/1/1999 G - 2 10,729 10,752 2 - 7/8" HC @ 4 - 8 SPF 4';i BEWARE! '1 EOT Deformed 10/1/1999 G -3 10,803 10,832 2 -7/8" HC @ 4 SPF °'* • - 11/28/2000 G -4 10,856 10,866 2 -7/8" HC @ 60 ° , 6 SPF 'k • 11/28/2000 G-3 10,803 10,823 2-7/8" HC @ 60 ° , 6 SPF HB-0 11,150 11,160 Open D 9 HB -0 11,190 11,200 Open 10 1111 HB -1 11,225 11,240 Open HB -2 11,258 11,268 Open 14 ki :k 12 HB -3 11,350 11,380 Isolated rt Junk PKR HB 4 11,412 11,432 Open 11- @ 11,540' HB 4 11,440 11,470 Open A,B,C - x HB -4 11,485 11,520 Open � HB -4 11,530 11,580 Partially covered w/ Junk Packer at 11540' '+ r Junk PKR HB -5 11,596 11,630 Covered w/ Junk and Fill /Debris ",- i @ 11,894' HB -5 11,690 11,715 Covered w/ Junk and Fill /Debris `--`'" Fish /Fill Information: TD = 12,050'; PBTD = 11,904' A. 10/9/93: 2 -1/8" strip gun 25ft long tag @ 11,581' DIL. MAX HOLE ANGLE = 40 a @ 9,300 ' B. 10/93: Tag fill @ 11,607' DIL. C. 11/28/89: 16 ft long strip gun w/ bull nose D. 1/12/03: 21' Slickline tools with top at 11297' (RS, KJ, 10' Stem, KJ, OJ, SSJ, 2' Stem, 3.75" GR. All w/ 1.75" FN). Also dropped cutter bar w/ 1 -3/8" FN. REVISED: 6/28/2012 BY: TDF STATE OF ALASKA • 1PASKA OIL AND GAS CONSERVATION COMMISS . REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Othe0 Performed: Alter Casing ❑ Pull Tubing!: Stimulate - Frac ❑ Waiver ❑ Time Extensio❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑+ Re -enter Suspended We0 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development I] Exploratory ❑ 180 - 082 "` R EC 3. Address: 3800 Centerpoint Drive, STE 100 Stratigraphic ❑ Service El 6. API Number: Anchorage, AK 99503 50- 733 - 20142 -01 - 0 O 7. Property Designation (Lease Number): 8. Well Name and Number: MAY 2 5 2012 Trading Bay Unit / ADL 0018729 Dolly Varden D -12RD ! 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): McArthur Riv Field / Hemlock & Middle Kenai G Zones a v (/�/ G CC 11. Present Well Condition Summary: Total Depth measured 12,050 feet Plugs measured 11,904 feet true vertical 10,188 feet Junk measured 11,581 feet Effective Depth measured 11,630 feet Packer measured 10,566;11,308;11,393 feet true vertical 9,791 feet true vertical 8,808,9,492;9,571 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 2,537' 13 -3/8" 2537' 2403' 3,090 psi 1,540 psi Production 10,297' 9 -5/8" 10,297' 8,561' 6,870 psi 4,760 psi Liner 2,894' 7" 9,137'- 12,031' 7,565- 8,445' 8,160 psi 7,020 psi Liner Perforation depth Measured depth 10,729- 10,752; 10,803 - 10,832; 10,856 - 10,866; 11,150- 11,160; 11,190- 11,200; 11,225- 11,240; 11,258 - 11,268; 11,412- 11,432; 11,440 - 11,470; 11,485- 11,520; 11,530- 11,580 feet True Vertical depth 8,958 - 8,979; 9,026- 9,053; 9,075- 9,084; 9,346- 9,355; 9,383- 9,392; 9,415- 9,429; 9,446- 9,455, 9,588 - 9,607; 9,614 - 9,642; 9,656- 9,688; 9,698 -9,744 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" L -80 12.6# 10,650' (MD) 8,885 (TVD) Baker SABL - 2; Baker FB - 1; 10,566',11,308';11,393' MD MD Packers and SSSV (type, measured and true vertical depth) Baker FB - 8,808',9,492';9,571' TVD N/A N/A TVD 12. Stimulation or cement squeeze summary: {' !!!�J ) (� § Intervals treated (measured): 11,150' to 11,268' 9g Sy e�r fr J U L v G ! 3 4 Treatment descriptions including volumes used and final pressure: Acidize perfs w/ 1,300 gallons 10% HCL & 10% Xylene. Ending pump pressure was 242 psi. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 180 395 743 920 220 Subsequent to operation: 199 492 703 940 170 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development ID - Servic(j Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: . Oil E] Gas❑ ❑ WDSPL GSTOR ❑ 1MNJ ❑ WAG ❑ GINJ ❑ SUSI❑ ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Ted E. Kramer Printed Name Ted E. Kramer Title Operations Engineer Signature . ` v Phone 907 - 777 -8420 Date 5/24/2012 vL - j1/ z 10 r3DMS MAY 2 5 2012 r, . Form 10-404 Revised 11/2011 Submit Original Only • Dolly Var. Platform Well # 12RD Hilcorp Alaska, LLC Actual Workover Completion Date: 8/16/99 Casing and Tubing Detail RKB = 41' Rig Floor to TBG Hanger SIZE WT GRADE CONN ID MD TOP MD BTM. . 13 -3/8" 61 J -55 Buttress 12.515 Surf. 2,537' 11 - 9 -5/8" 40 N -80 Buttress 8.835 Surf. 6,192' 9 -5/8" 43.5 N -80 Buttress 8.755 6,192' 8,289' e 9 -5/8" 47 N 80 Buttress 8.755 6,192' 10,297' 7" 29 N -80 Buttress 6.184 9,137' 12,031' e` A 1 2 Tubing: n 4 -1/2" 12.6 L-80 Buttress 3.958 41 10,650' t Jewelry NO Depth ID Item e 1 41 3.958" CIW 4 -1/2" Type F Tubing Hanger: 4 -1/2" 8rd top /4 -1/2" BTC bottom 2 314' 3.813" Halliburton Safety Valve landing nipple e 3 2,464' 3.958" #1 4 -1/2" Otis GL GLM w/ 1.5" Valve, RA latch MIN 3 4,491' 3.958" #2 4 -1/2" Otis GL GLM w/ 1.5" Valve, RA latch t 6,012' 3.958" #3 4 -1/2" Otis GL GLM w/ 1.5" Valve, RA latch _ 7,164' 3.958" #4 4 -1/2" Otis GL GLM w/ 1.5" Valve, RA latch I 1 DV Collar 8,157' 3.958" #5 4 -1/2" Otis GL GLM w/ 1.5" Valve, RA latch _ • @ 5,778 8,995' 3.958" #6 4 -1/2" Otis GL GLM w/ 1.5" Valve, RA latch 9,612' 3.958" #7 4 -1/2" SMOR -1A McMurry -Macco GLM w/ 1" Valve, BK -2 10,103' 3.958" #8 4 -1/2" SMOR -1A McMurry -Macco GLM w/ 1" Valve, BK -2 _ 10,496' 3.958" #9 4 -1/2" SMOR -1A McMurry-Macco GLM w/ 1" Orifice, BK -2 4a 10,546' 3.880" Baker Locator and seal assembly 4b 10,546' 3.880" Baker 80 -47 PBR (L = 18.4') / 5a 10,565' 4.000" Baker KBH -22 anchor seal assembly 5b 10,566' 3.875" Baker SABL -2 permanent packer w /mill out extension TOL @ 6 10,612' 3.813" Baker X- nipple MIN 9,136' • 7 10,650' 4.000" Wireline entry guide (DEFORMED) e 8 11,308' 4.000" Baker FB -1 permanent packer with mill out extension 4 9 11,318' 2.992" 3 -1/2" 9.2 lb /ft tubing w/ Mod BTC (11,318'- 11,391') i 5 10 11,392' 3.000" Baker Locator and G -22 locator seal assembly 11 11,393' 4.000" Baker FB -1 permanent packer with seal -bore extension 6 t Fish /Fill Information: L � 7 111 A. 10/9/93: 2 strip gun 25ft long tag @ 11,581 DIL. ■ — BEWARE' B. 10/93: Tag fill @ 11,607' DIL. EOT Deformed C. 11/28/89: 16 ft long strip gun w/ bull nose II D. 1/12/03: 21' Slickline tools with top at 11297' (RS, KJ, 10' Stem, KJ, OJ, SSJ, 2' ■ Stem. 3.75" GR. All w/ 1.75" FN). Also dropped cutter bar w/ 1 - 3/8" FN. • D 0 8 Perforations Date Zone Top BTM Comments 9 101 10/1/99 G -2 10,729 10,752 2 -7/8" HC @ 4 -8 SPF 10/1/99 G -3 10,803 10,832 2 -7/8" HC @ 4 SPF 11/28/00 G -4 10,856 10,866 2 -7/8" HC @ 60 ° , 6 SPF 11 11/28/00 G -3 10,803 10,823 2 -7/8" HC @ 60 ° , 6 SPF Junk PKR HB -0 11,150 11,160 Open A,B,C X @ 11,540' HB -0 11,190 11,200 Open :. 4 r:r:f:r:f:f:f. y1111:. . HB -1 11,225 11,240 Open . .' :�f. f, HB 2 11,258 11,268 Open � f.J JunkPKR HB -3 11,350 11,380 Isolated " HB -4 11,412 11,432 Open L f1 .; rr�f, @ 1I,s94' HB -4 11,440 11,470 Open TD = 12,050'; PBTD = 11,904' HB 11,485 11,520 Open MAX HOLE ANGLE = 40 @ 9,300' HB -4 11,530 11,580 Partially covered w/ Junk Packer at 11540' HB -5 11,596 11,630 Covered w/ Junk and Fill /Debris HB -5 11.690 11.715 Covered w/ Junk and Fill /Debris REVISED: 5/24/2012 BY: TDF • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -12RD 507332014201 180 -082 4/23/12 4/23/12 Daily Operations: 04/23/2012 - Monday Test BOP 250 psi low /3,000 psi high. RIH to 11,414 and pump foam and gel while POOH. At 2,000' reverse direction & RIH to spot acid. Acid pumped away and jetting acid w /N2. POOH. RD. • • SEAN PARNELL, GOVERNOR ,..,1 0[F ALASEA ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ted E. Kramer Sr. Operations Engineer Hilcorp Alaska, LLC d$ 3800 Centerpoint Drive, Suite 100 • Anchorage, AK 99503 Re: McArthur River Field, Hemlock & Middle Kenai G Pool, Dolly Varden D -12RD Sundry Number: 312 -165 Dear Mr. Kramer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. • As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this I7 day of May, 2012. Encl. # -(v RECEIVED S TATE OF ALASKA APR 2 6 O1 A OIL AND GAS CONSERVATION COMMISSION l `® APPLICATION FOR SUNDRY APPROVALS ' s !� 20 AAC 25.280 ' 1. Type of Request: Abandon ❑ Plug for Redrih ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program El Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing O Time Extension ❑ Operations Shutdown' ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing El Other: Convert to ESP /Replace tubing a 2. Operator Name: 4. Current Well Class: 7� 5. Permit to Dry Number: Hilcorp Alaska, LLC Development a Exploratory' , , i i'''i80-082 , 3. Address: Stratigraphic ❑ Service ❑ `1 6. API Number. 3800 Centerpoint Drive, STE 100, Anchorage, AK 999503 50- 733 - 20142 -01 " 7. If perforating, closest approach in pool(s) opened bby this operation to nearest 8. Well Name and Number: property line where ownership or landownership ch.langes: Spacing Exception Required? Yes ❑ No ❑ Dolly Varden D -12RD - 9. Property Designation (Lease Number): g ,9p 21 10. Field /Pool(s): Trading Bay Unit ADL00187 '�'P /- ' l e 77- 7. McArthur River Field /Hemlock & Middle Kenai G Zones - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVp ( : Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): , 2Z <2 lu�l} D Z " AIL 11,630 9,791 11,904' 11581' Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 2,537' 13 -3/8" 2,537' 2,403' 3,090 psi 1,540 psi Production 10,397' 9 -5/8" 10,297' 8,561' 6,870 psi 4,760 psi Liner 2,894' 7" 9,137'- 12,031' 7,565' - 8,445' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,729- 10,752 8,958 -8,979 4 -1/2" L-80 12.6# 10,650' 10,803- 10,832 9,026 -9,053 10,856- 10,866 9,075 -9,084 11,150- 11,160 9,346 -9,355 11,190- 11,200 9,383 -9,392 11,225- 11,240 9,415 -9,429 11,258- 11,268 9,446 -9,455 11,412- 11,432 9,588 -9,607 11,440- 11,470 9,614 -9,642 11,485- 11,520 9,656 -9,688 11,530 - 11,580 9,698 -9,744 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker SABL -2 packer /Baker FB -1 packer /Baker FB -1 packer 10,566' (MD)/11,308' (MD)/11,393' (MD) & ? ?? (TVD) 12. Attachments: Description Summary of Proposal) a 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch a Exploratory El Development a ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/10/2012 Oil a - Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: y, /S ate: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A 2 GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Printed Name Ted E. Kramer Title Sr. Operations Engineer Signature �� ' , 7 Phone Date (907) 777 -8420 4/24/2012 COMMISSION USE ONLY 7 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3) 2. )(C6 Plug Integrity ❑ BOP Testt N Mechanical Integrity Test El Location Clearance ❑ Other: 6 v 7" tt J` ? cli D p L. ` Naf/fy ii; c v as ii.-7 CI / c4 7 Subsequent Form Required: APPROVED BY Approved by: / e a' MMISSIONER THE COMMISSION Date: S -17.... 2_ rui.,. 10- . \ A VLF 4/, /J Z 5 -l2- �1 _2.1.I 3 /I • • D -12RD Conversion to ESP McArthur River Field WO Procedure April 22, 2012 Hilcorp Alaska, LLC Version 1.0 WELL: D -12RD OBJECTIVE: To convert from gas lift to an ESP completion utilizing the CUDD Hydraulic Work Over Unit. Work Scope: Cut and pull the existing tubing, Run ESP on 3 -1/2" tubing completion. Current BHP: 3,100 psi @ 9,322' TVD 3100 -- 221 = /GS Max Downhole Pressure: 3,100 psi @ 9,322" TVD (Based on nearest offset well with a static pressure from the latest Mount Redoubt Volcanic eruption shut in. ) MASP: 0 psi (Based on actual reservoir conditions and water cut of 80% (.426 psi /ft) with added Safety Factor of 1000' TVD of oil cap) PROCEDURE: 1. MIRU CUDD Hydraulic Workover Unit. 2. Pump +/- 150 Bbls. of filtered Ilet water (FIW) and sized salt pill down the tubing. 3. Set a BPV in tubing. l-- IA s -�? �c� ? 4. ND tree and seal flange. e.00 tucf A.66 5. Nipple up BOP stack and test to 250 psi low/ 2500 psi high. l ,,,, / rSS • 6. M/U 4 -1/2" EUE (pin) landing string (have TIW valve attached). 7. MIRU E -line unit. 8. Test Lubricator 250psi low / 2500psi high. 9. MU and run in hole with GR working up to 2.0" to +/- 10,546'. POH. 10. MU and run in the hole with radial torch and cut 4 -1/2" tubing at +/- 10,525'. POH with Cutts .. L —� c.i (cf..) F Q v". 11. POH and UD 4 -1/2" tubing. 12. PU /MU and install ESP and RIH on with ESP on 3 -1/2" tubing, setting the bottom of the assembly at 10,450'( + / -). 13. MU tbg hanger and land same. 14. Install BPV. ND BOPE. NU tree. Remove BPV, install 2 way check. Shell test tree 250psi low/ 3,000psi high ? ?. Pull 2 way check. NU flow lines. Demobe Rig. 15. Turn well over to production. D.. 1 of • 1 0 • D -12RD Conversion to ESP McArthur River Field WO Procedure April 22, 2012 Hileorp Alaska, tic Version 1.0 Current Schematic: RKB = 41' Rig Floor to TBG Hanger Casing and Tubing Detail 1 SIZE WT GRADE CONN ID MD TOP MD BTM. e 13 -3/8" 61 J -55 Buttress 12.515 Surf. 2,537' 9 -5/8" 40 N -80 Buttress 8.835 Surf. 6,192' e 2 9 -5/8" 43.5 N -80 Buttress 8.755 6,192' 8,289' n 9 -5/8" 47 N -80 Buttress 8.755 6,192' 10,297' t 7" 29 N -80 Buttress 6.184 9,137' 12,031' Tubing: 4 -1/2" 12.6 L -80 Buttress 3.958 41 10,650' e Jewelry . 3 NO Depth ID 1.2.1 Item 1 41 3.958" CIW 4 -1/2" Type F Tubing Hanger: 4 -1/2" 8rd top /4 -1/2" BTC bottom 1 M 1 DV Collar 2 314' 3.813" Halliburton Safety Valve landing nipple @ 5,778 3 2,464' 3.958" #1 4 -1/2" Otis GL GLM w/ 1.5" Valve, RA latch - 4,491' 3.958" #2 4 -1/2" Otis GL GLM w/ 1.5" Valve, RA latch 6,012' 3.958" #3 4 -1/2" Otis GL GLM w/ 1.5" Valve, RA latch 7,164' 3.958" #4 4 -1/2" Otis GL GLM w/ 1.5" Valve, RA latch 8,157' 3.958" #5 4 -1/2" Otis GL GLM w/ 1.5" Valve, RA latch 8,995' 3.958" #6 4 -1/2" Otis GL GLM w/ 1.5" Valve, RA latch \ / 9,612' 3.958" #7 4 -1/2" SMOR -1A McMurry -Macco GLM w/ 1" Valve, BK -2 10,103' 3.958" #8 4 -1/2" SMOR -1A McMurry -Macco GLM w/ 1" Valve, BK -2 TOL @ 10,496' 3.958" #9 4 -1/2" SMOR -1A McMurry -Macco GLM w/ 1" Orifice, BK -2 NMI e/11 1' 4a 10,546' 3.880" Baker Locator and seal assembly 9,136' 4 r 4 ---- ,bi ✓l, 4b 10,546' 3.880" Baker 80 -47 PBR (L = 18.4') 4 5a 10,565' 4.000" Baker KBH -22 anchor seal assembly 5b 10,566' 3.875" Baker SABL -2 permanent packer w /mill out extension 5 6 10,612' 3.813" Baker X- nipple 7 10,650' 4.000" Wireline entry guide (DEFORMED) 6 8 11,308' 4.000" Baker FB -1 permanent packer with mill out extension t 9 11,318' 2.992" 3 -1/2" 9.2 lb/ft tubing w/ Mod BTC (11,318'- 11,391') Z. _ 7 10 11,392' 3.000" Baker Locator and G-22 locator seal assembly I 11 11,393' 4.000" Baker FB -1 permanent packer with seal -bore extension . BEWARE! 1 EOT Deformed Fish/Fill Information: ■ A. 10/9/93: 2 -1/8" strip gun 25ft long tag @ 11.581' DIL. • B. 10/93: Tag fill @ 11.607' DIL. 61 ■ C. 11/28/89: 16 ft long strip gun w/ bull nose 1 )1 8 D. 1/12/03: 21' Slickline tools with top at 11297' (RS, KJ, 10' Stem, KJ, OJ, SSJ, 2' Stem, 3.75" GR. All w/ 1.75" FN). Also dropped cutter bar w/ 1 -3/8" FN. 9 10I 11 Perforations MI Junk PKR Date Zone Top BTM Comments 10/1/99 G -2 10,729 10,752 2 -7/8" HC @ 4 -8 SPF 2 @ 11 540' 10/1/99 G -3 10,803 10,832 2 -7/8" HC @ 4 SPF 11 /28/00 G -4 10,856 10,866 2 -7/8" HC @ 60 °, 6 SPF 44:11 11/28/00 G -3 HB -0 10,803 11,150 10,823 11,160 2 -7/8" HC @ 60 °, 6 SPF Open f r Junk PKR HB -0 11,190 11,200 Open ilk7 11,894' HB -1 11,225 11,240 Open HB -2 11,258 11,268 Open TD = 11,904'; PBTD = 11,904' HB -3 11,350 11,380 Isolated MAX HOLE ANGLE = 41.25° @ 9,200' HB -4 11,412 11,432 Open HB -4 11,440 11,470 Open HB -4 11,485 11,520 Open HB -4 11,530 11,580 Partially covered w/ Junk Packer at 11540' HB -5 11,596 11,630 Covered w/ Junk and Fill/Debris HB -5 11,690 11,715 Covered w/ Junk and Fill/Debris Dor.P A ,.f K , - • • fli , #--,/ ,, . 1 )- 121(1) (; :a 14) 1' Sl' 111 A rill !fiver Field April Procedure Nit 22, 2012 si.i. -.., ki:,.t 111 L MCI I,0 Proposed Schematic RK11 41' Rig Floor to TFI : 11nnzer 1 12.1.1 Casing and Tubing Detail 5171" N 1" (.k %it! CY)' N« ID MD Tor 11O 11r11. 13 -3/W' 61 J -55 Buttress 12.515 Surf. 2,537' 9-5/8" 40 N -80 Buttress 8.835 Surf. 6,192' 9 5/8" 415 N -80 Buttress 8.755 6,192' $,289' 9 -s/S" 47 N-R1) Buttress 8.755 4,192' 10,297' 1 7" 29 N,1111 Buttress 6.184 9,137' 12,031' i i It him:. 1 +. 1 -1/2" 9.2 1: -40 411/41. 543 3.954 41 10.250 , t 2.2.1.2 Jewett %0 Depth 111 , i ON/ 1'0811 ile't' u .5.778 1 41 3.958" 1_:1W 3.1/2" Type F Tubing Hanger: 3 -112" 8rd top /3.1/2" RTC bottom 1I4' t.rl 3" Landmr, nipph. 3 10,450' of ESP 4a 10,546' 3.880" Baker Locator and seal assembly 4b 10.546' 3.880" Baker/10-47 PBR (L- 14.4') \ ` 50 10,565' 4.000" Raker 3(11)1 22 Anchor Seal Assembly Sh 10,566 3.8'75" Baker SAM, 2 permanent parker Wim nu( ettetisitat 14/1 a I a 10.612' 3.813" Baker N nibble '4 0 l 1 1 -1 7 10,660' 4.000" Wireline cab y guide. 8 11,308' 4.000" Baker I• -1 permanent parker with mill out extension '► 11,.318' 2.992." 3 112 "') 2 lb/ft tubing w/ Mud 111 f (11,318' - 11,39)`) io r 10 11.392' 3.1)10" Bake' Lo aloe and ( Inratnr .eat assembly t• 11 11,393' 4.000" Baker F$ -1 permanent packer with seal -burr ex tension 41 1 I Fish/F i 11Iutur Cation: I ( ..!• > 1 10/9/9+:2 I/8" strip gun 2511 long tag (a; 1 I,s11' 1)11 10/93: Tag 1111 I_I,607' f)IL. 111',* t 11 ' l 11/28/89: 16 11 long strip gun w/ bull nose It t i lt.t+",nr,1 11 1112 /03: 21' Slickhnc fools with lop at 11297' (RS, KJ, 10' Stem. KJ, 0.1, SSJ, 2' • Stem, 3.75" GR. All w/ 1.75" FN). Also dropped cutter bar w/ 13/8" FN. 1 7 11 2.2.2. Perforations 4 Cate lone lujr 1111I , „a,n+rrsl, ICU r e.+ Junk PKR 11134 11,150 11,1611 Open `` I1,�'10 811-0 11,190 11,2011 Open 2.2 L i CO ti 1181 11,225 11,240 Open . 118-2 11,258 11.268 Open ? '."' HR -3 11,3511 11,190 Isolated 1111-4 11,412 11.432 Opeo yyy Junk PKR 1111 4 11,4* 11,470 Open r, R) 11.894' 1111 -4 11,445 1)520 Open t. " -'• •' -''''' 1111-4 11,538 11,580 Pau tinny covered wlJnnk Packer at I1) 11,904'; PBTI) 11,901' 1113 - 11,596 11,630 Covered w/ Junk and I''ifhlhbtis MAX 1101,k ANGLE 31.15° oe, 9,2111l' 1111.5 11,690 11.715 (:,wrred / rook and Piu/Itebris 0..... C „Fs: I • • Hi lcorp Alaska Cudd Snubbing 13%"5MHWOStack Q 13 -5/8" o HYDRIL o `d 9~ HEIGHT+ 54 -1/8' INCHE WEIGHT+ 13,800 LEIS NATURAL RUBBE AVOID OIL BASE D 0 _1 '11 a r co W 1• ° S Pipe Mike Freeman ( 0 - - -- 713 -252 -1944 Houston, Tx. t 3 l i n d /Shear : ooster Bonnets Instd. I I1_ 1. _ 111, .. ..LP-1.... I ir 1.11. rt 1.2 LP - - 1 1 Ca V DRILLING ; 0 0 a SPOOL ___L illill 111111 _ i V ® J .__._. _ .. n 4 -1/16 5/4 4 -1/16' SM 5M VALV -x- _ . __ -x- 2 -1/16' 3M 2 -1/16' 3M AS,A r, •. D.SA P ie re+8239 Ill C 0 j j . . 3 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date D -12RD 507332014201 C 18000820, 5/15/12 Daily Operations: 05/23/2012 - Wednesday POOH laying down 4 1/2" tubing. 05/24/2012 - Thursday Continue POOH laying down 4 1/2" tubing and jewelry. Spot and R/U slick line. RIH with 3.83" bell guide & tagged up @ 6,312'. RIH with 1.5 bailer and collect sample @ 6,312'. R/D slick line. Change out stationary dies. Change slip dies to 3 1/2 ". Scope out gin pole. R/U lay down line. Strap top row of 3 1/2" tubing. P/U 3 1/2" 563 tubing and stand back. Drift each joint of tubing as it is picked up. 05/25/2012 - Friday Cont. P/U 3.5" 563 tbg, rabbiting and racking back, total of 153 stands racked back and 2 jts on deck; too short to rack back. Changed out tubing tongs for hawk jaws; P/U 4" HT -38 DP, torque to 18k, rabbiting and racking back, total of 25 stds racked back. Start M/U of BHA on deck. 05/26/2012 - Saturday RIH with bottom of BHA, run in 47 jts of 3.5" 563 tubing. Changed out Weatherford tongs for Hawk Jaws. P/U and M/U 9 5/8" scraper. Chg out Hawk jaws for tongs. RIH w/ 3.5" 563 tubing @ stand #101 to 6,053'. RII-t w/ 3.5" 563 tubing, from stand #101 to #110 ran in slow due to slick line tag @ 6,300' + -. RIH w/ 3.5" 563 tubing @ stand #154 to 9,247'. P/U 85k, 5/0 45k. RIH w/ 4 "HT -38 DP @ stand #172. JUL 8 2.01Z 05/27/2012 - Sunday Finish RIH with CO assy, no obstructions. Tagged @ 15' in stand #176, 10,541'. Broke stand and install TIW. POOH with clean out assy and stand pipe back in derrick. Lost a tong die (down tbg at jt # 133 (7,996') will look for it in BHA. Left msg on AOGCC Jim Regg phone at 16:45 hrs of 48 hr notice of BOPE test on 5/28/12. POOH w/ clean out BHA, 3.5" 563 tubing, standing pipe back in jack, 2 stands left to pull. • • 05/28/2012 - Monday Break down clean out BHA, lay down WOT Hawkjaw tongs, PU WOT tubing tongs. Lay down BHA, both scrapers had black dehydrated substance on them. Did not recover tong die. RU WL unit. Left 2nd msg on AOGCC machine of 5/28/12 BOPE test at 0800 hrs. Rcvd call f /AOGCC Jim Regg. Jim Regg waived BOPE test in it's entirety. RIH #1- 4.50" swage sticky. At 9,270' PU fell thrutag at 10,558'. RIH #2- 3.50" swage sticky, at 10,625' PU fell thru. Run btm tool string thru TT at 10,650' to 10,678'. RIH #3- 5.75" LIB tag 7" liner at 9,132'. RIH #4- 3.50" Super Magnet tag at 10,558' and recovered 2 shear pins & 2 metal shavings. Confer with Anch. Eng. Conclusion: well is clear of obstruction. Proceed with RIH with ESP completion. Begin to R/U ESP equipment. 05/29/2012 - Tues Continue RU of ESP running equip. Start MU /RIH with ESP assy. Install clamps and pump oil untill clean oil return returns. MU flat pack and power cable, test good. MU 2 7/8 "x3.5" X0, run 1 jt 2 7/8" tbg, install chem inj lines and test good. Secure well conduct cable cutting drill, service and fuel equip. RIH with 45 jts 2 7/8" tbg clamping cable and flat pack each jt. Test cable - good test. RIH with 3.5" tbg clamping every other jt. 5/O wt 16k - 54 clamps in hole. • • Ferguson, Victoria L (DOA) To: Ted Kramer Cc: Schwartz, Guy L (DOA) Subject: RE: Dolly Varden D -12RD 10 -403 Well SundryTom Fouts - (C) [tfouts @hilcorp.com] From: Ted Kramer [mailto:tkramerCThilcorp.com] Sent: Tuesday, May 15, 2012 9:34 AM {, (T To: Ferguson, Victoria L (DOA) \"� V Subject: RE: Dolly Varden D -12RD 10 -403 Well Sundry Victoria, The well is currently on gas lift and the tubing by casing annulus is pressure tested to 1340 psi (gas lift pressure) continuously. The next string out 13 -5/8" runs between 20 and 40 psi so there is casing integrity between the two strings. When the well is on ESP, the casing pressure on the 9 -5/8" casing string will be reduced from 1,340 psi. to less than 200 psi. (most likely in the 80 to 120 psi range). I hope this helps, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC Office Phone 907 - 777 -8420 Cell Phone 985 - 867 -0665 From: Ferguson, Victoria L (DOA) Jmailto :victoria.ferguson ©alaska.govl Sent: Tuesday, May 15, 2012 9:04 AM To: Ted Kramer Cc: Schwartz, Guy L (DOA) Subject: RE: Dolly Varden D -12RD 10 -403 Well Sundry When was the last time a pressure test was done on the casing. Thanx, Victoria From: Ted Kramer Jmailto:tkramer(ahilcoro.com] Sent: Monday, May 14, 2012 5:25 PM To: Ferguson, Victoria L (DOA) Subject: RE: Dolly Varden D -12RD 10 -403 Well Sundry Victoria, It will be a packerless completion ESP. There will be an SSV on the wellhead. 1 • schematic prepared. To be honest, I have to generate the schematic m I do not have a proposed workover sc p p myself and I g Y am afraid that it would not be very professional looking. If that is ok, with you, then I could draw something up on a tablet (and would be happy to do so) as Hilcorp does not have a drafting person /department. A post workover schematic is generated after the work is completed by the regulatory technicians. That schematic could be sent if that would suffice. If the commission is going to require a proposed schematic be submitted with each Sundry please let us know and we will make arrangements to make that happen. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC Office Phone 907 - 777 -8420 Cell Phone 985 - 867 -0665 From: Ferguson, Victoria L (DOA) J mailto :victoria.ferguson ©alaska.govl Sent: Monday, May 14, 2012 1:49 PM To: Ted Kramer Cc: Schwartz, Guy L (DOA) Subject: Dolly Varden D -12RD 10 -403 Well Sundry Ted, A couple of questions on this sundry: 1. Is this a packerless ESP completion? 2. Will there be a functional SSV? As always, a post - workover schematic would be nice - Thanx in advance, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson(a alaska.gov 2 i. - FRANK H. MURKOWSKI, GOVERNOR _.~'- ALASKA OIL AlWD GAS CONSERVATION COMMISSION August 3,2006 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Chris Myers Field Superintendent U nocal PO Box 196247 Anchorage, Alaska 99519 :3Cl\NNEC i\ \1 i" ;·"Î"-vt,.~ 07 RE: No-Flow Verification Trading Bay Unit D-12RD, PTD 180-082 Dear Mr. Myers: On July 27, 2006 an AOGCC Petroleum Inspector witnessed a "no flow test" at Unocal's Dolly Varden platform, Trading Bay Unit Well D-12RD. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. The well demonstrated no fluid flow while open to atmosphere, and a gas flow less than 180 standard cubic feet per hour. The subsurface safety valve may be removed from service in Well D-12RD based on this no-flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Dolly Varden platform. Sincerely, ---- ~ ,;) ~a'6¡j(J -5 ó 1'\ é~r; James B. Regg (L Petroleum Inspection Supervisor cc: Bob Fleckenstein . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 7' r(zi¡I¡" _._ <.;.. /? - '" ;>{".... ¡ "'''-!{tl DATE: July 27,2006 FROM: Jeff Jones Petroleum Inspector SCANNED SEP 0 8 2005 SUBJECT: No-Flow Test Chevron 1 Dolly Varden PL T Well D-12RD PTD-1800820 Trading Bay Unit July 27, 2006: I traveled to Chevron's TBU Dolly Varden Platform in Cook Inlet to witness a No-Flow Test on oil producing well D- 12RD. Chevron Operator Norm Fahnholz performed the test today in a safe and proficient manner. Prior to the test we inspected the well and verified to the extent possible an open flow path from the well bore and discussed the test procedure. Well D-12RD was lined up from the tree top swab valve through an Armor-Flow model # 3461-03TO flow meter (180 SCFH to 1800 SCFH span) and a 3/4" hose terminating in an open top container. Flow from the well was monitored for 3 hours with readings recorded every 30 minutes (see below). Unassisted flow from the well was below the measurable range of the flow meter and no liquid was produced during the test. Well D-12RD meets the AOGCC requirements for a No-Flow determination. Summary: I traveled to Chevron's TBU Dolly Varden Platform in Cook Inlet and witnessed a successful No-Flow test on oil producing well D-12RD. Attachments: none ÇÇ¡ Chris Meyers, Norm Fahnholz (Chevron) Gas <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH Start Test End Test Produced to open top container through Annor-Flow meter model #3461-03TO calibrated: 3/21/06 Total liquid produced: None JBJ02 Page I of 1 NO-FLOW Dolly Varden PLT D-12RD 7-27-06 JJ.xls Unocal Corporation (' P.O Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe Dan Williamson Dnlhng Manager 12/0710O Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Trading Bay Unit Well D-12rd APl No. 50-733-20141-01 10-404 Perforate G-Zone Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the perforation of the G3 & 4 benches in well D-12rd. The following intervals were perforated on 11/28/00: Bench Top Bottom Feet G3 10,803 10,823 20 G4 10,856 10,866 10 Total: 30 If you have any questions, please contact Ralph Holman at 263-7838. Dan Williamson Drilling Manager · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ' REPORT OF SUNDRY WELL OPERATIONS ,,, 1 Operat, ons performed Operabon shutdown Stimulate PluggIng Perforate: X Pull tubing. Alter casing Repair well' Other:. 2 Name of Operator 5 Type of Well 6 Datum elevabon (DF or KB) UNOCAL Development. X 106' KB above MSL feet 3 Address Exploratory. .... 7 Unit or Property name P O Box 196247 Anchorage, Alaska 99519-6247 Strabgraph~c' Trading Bay Umt Service 4 Locabon of well at surface 8. Well number 678' FSL, 1,217' FWL, Sec 6-8N-13W-SM D-12RD At top of producbve ~nterval 9 Permit number/approval number 915' FWL, 2,396' FNL, Sec 8-8N-13W-SM 80-082/399-018 At effecbve depth 10. APl number 1,117' FWL, 2,589' FNL, Sec 8-8N-13W-SM 50- 733-20142-01 At total depth 11 F~eld/Pool 1,150' FWL, 2,623' FNL, Sec. 8-8N-13W-SM Hemlock 12 Present well cond~bon summary Total depth' measured 12,050 feet Plugs (measured) 11,904'-12,050' Cement true verbcal 10,188 feet Effective depth measured 11,894 feet Junk (measured) 11,540' and 11,894' Packers true vertical 10,038 feet CasIng Length S~ze Cemented Measured depth True verhcal depth Structural Conductor Surface Intermediate Producbon 9,365' 9-5/8" 2,326 sx 9,365' 7,727' L~ner 2,894' 7" 850 sx 12,031' 10,168' Perforation depth measured See attached wellbore schemabc true vertical Tubing (s~ze, grade, and measured depth) 4-1/2", 12.6 Ib/ff L-80 Tubing to 10,650' Packers and SSSV (type and measured depth) Baker FB-1 Packers @ 11308' and @ 11393' Baker SABL-2 Packer @ 10556'. 13 Stimulation or cement squeeze summary Intervals treated (measured) NA Treatment descripbon ~nclud~ng volumes used and final pressure NA 14 Representative Da~ly Avera,qe ProductIon or Inlect~on Data O~I-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operabon 847 432 636 1177 140 Subsequent to operabon 882 687 676 1187 130 15 Attachments. 16 Status of well class,ficat~on as Cop~es of Logs and Surveys run Da~ly Report of Well Operabons X O~1: X Gas. Suspended Service 17 I hereby cerbfy that the foregoIng ~s true and correct to the best of my knowledge: S,gned Dan W~ll~amson Dnll~ng Manager Date. Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner '7 Blair Wondzell, P. I. Supervisor FROM' John Crisp,~ ~ ~. SUBJECT: Petroleum In~l~ector DATE: June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be changed out during next Platform shut down due to header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthur River Field. 24 wells, 57 components tested,-3 failures witnessed. 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc cc; NON-CONFIDENTIAL SVS Dolly Plt. 6-22-00jc UNOCAL ) RKB = 41' Rig Floor to TBG Hanger DV Collar @ 5,778 TOL @ 9,136' A,B,C Junk PKR @ 11,540' Junk PKR @ 11,894' TD = 11,904'; PBTD = 11,904' MAX HOLE ANGLE = 40° @ 9,300' D- 12RD Schem 11-7-00.doc Dolly VarOPlatform Well # 12RD Actual Workover Completion Date: Last Revision Date: 11/7/00 8/16/99 SIZE WT Casing and Tubing Detail GRADE CONN ID MD TOP MD BTM. 13-3/8" 9-5/8" 9-5/8" 9-5/8" 7" Tubing: 4-1/2" 61 40 43.5 47 29 12.6 J-55 Buttress 12.515 Surf. 2,537' N-80 Buttress 8.835 Surf. 6,192' N-80 Buttress 8.755 6,192' 8,289' N-80 Buttress 8.755 6,192' 10,297' N-80 Buttress 6.184 9,137' 12,031' L-80 Buttress 3.958 41 10,650' NO Depth Item Jewelry 4a 4b 5a 5b 6 7' 8 9 10 11 41 3.958" 314' 3.813" 2,464; 3.958" 4,491' 3.958" 6,012' 3.958" 7,164' 3.958" 8,157' 3.958" 8,995' 3.958" 9,612' 3.958" 10,103' 3.958" 10,496' 3.958" 10,546' 3.880" 10,546' 3.880" 10,565' 4.000" 10,566' 3.87~" 10,612' 3.813" 10,650' 4.000" 11,308' 4.000" 11,318' 2.992" 11,392' 3.000" 11,393' 4.000" CIW 4-1/2" Type F Tubing Hanger: 4-1/2" 8rd top/4-1/2" BTC bottom Halliburton Safety Valve landing nipple #1 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 #2 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 #3 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 #4 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 #5 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 95 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 S7 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 98 4-1/2" SFO-1 McMurry-Macco GLM w/1" Valve, BK-2 g9 4-1/2" SFO-1 McMurry-Macco GLM w/1" Orifice, BK-2 Baker Locator and seal assembly* Baker 80-47 PBR (L = 18.4') Baker KBH-22 anchor seal assembly Baker SABL-2 permanent packer w/mill out extension Baker X-nipple Wireline entry guide Baker FB-1 permanent packer with mill out extension 3-1/2" 9.2 lb/ft tubing w/Mod BTC (11,318'-11,391') Baker Locator and G-22 locator seal assembly Baker FB-1 permanent packer with seal-bore extension Fish/Fill Information: A. 2-1/8" strip gun 25ft long tag @ 11,581' DIL, 10/9/93 B. Tag fill @ 11,607' DIL, 10/93 C. 16 ft long strip gun w/bull nose, 11/28/89 Ds~_e Zone Top 10/1/99 G-2 10,729 10,752 10/1/99 G-3 10,803 10,832 11/28/00 G-4 10,856 10,866 11/28/00 G-3 10,803 10,823 HB-0 11,150 11,160 HB-0 11,190 11,200 HB-1 11,225 11,240 HB-2 11,258 11,268 HB-3 11,350 11~380 HB.4 11,412 11,432 HB-4 11,440 11,470 HB-4 11,485 11,520 HB-4 11,530 11,580 HB-5 11,596 11,630 HB-5 11,690 11,715 Perforations BTM Comments 2-7/8" HC @ 4-8 SPF 2-7/8" HC @ 4 SPF 2-7/8" HC @ 60°, 6 SPF 2.7/8" HC @ 60°, 6 SPF Open Open Open Open Isolated Open Open Open Partially covered w/Junk Packer at 11540' Covered w/Junk and Fill/Debris Covered w/Junk and Fill/Debris REVISED: 11/7/00 ORIGINAL DRAWN BY: MWD Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: McArthur Rv./Dolly Var& Separator psi: LPS 110 HPS 6/22/00 Well Data Pilots SV SSV '" Well Ty~e Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE D-01 1670800 110 80 85 P 4 OIL D-02ARD 1750380 110 80 65 P 5 OIL ,. D-03RD2 1830810 110 80 80 P P OIL D-04RD 1820410 110 80 80 P P OIL D-05RD 1800650 110 80 100 P P 43 OIL D-07RD2 1921550 110 80 80 P P P OIL D-08RD 1740030 110 80 75 P P P OIL D- 11 1680730 110 80 80 P P P OIL lii~R]~, '~ 1800820 110 80 75 P P 43 OIL D-17RD 1810230 110 80 80 P P 43 OIL D- 18 1690040 800 700 700 P P P GAS D-20 1690950 110 80 90 P P OIL D-25RD 1780870 110 80 100 P P OIL ~D-26RD 1981290 110 80 75 P P OIL D-27 1750240 110 80 60 P P OIL D-28 1760360 110 80 100 P P OIL D-30RD2 1880980 t~' D-31RD 1760740 110 80 70 P P 43 OIL D-32 1700370 110 80 75 P P P OIL D-40RD 1820830 110 80 80 P P OIL D-42 1830530 110 80 70 P P OIL D-43RD 1853110 110 80 70 P P P OIL D-46 1890610 110 80 60 P ? P OIL D-47 1910110 110 80 70 P P 9 OIL D-48 1921540 110 80 80 P P P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% [-190 Day Remarks: Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. o. ALASKA O(,-AND GAS CONSERVATION JMMISSlON REPORT OF SUNDRY WELL OPE TION$ 1. Operations performed: Operation shutdown: Stimulate: . Plugging: .. Perform[e: X Pull tubing: X '~er casing: , Repair well: X Other: 2. Name of Operator 5. Type of Well: 6. Datum c4c~vabon (DF or KB) UNOCAL Development: X 106' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 Stratigraphic: .. Trading Bay Unit Service: 4. Location of well at surface 8. Well number 678' FSL, 1,217' FWL, Sec. 6-8N-13W-SM D-12RD At top of productive interval 9. Permit number/approval number 915' FWL, 2,396' FNL, Sec. 8-8N-13W-SM 80-082 / 399-018 At effective depth 10. APl number 1,117' FWL, 2,589' FNL, Sec. 8-8N-13W-SM 50- 733-20142-01 At total depth 11. Reid/Pool 1,150' FWL, 2,623' FNL, Sec. 8-8N-13W-SM Gzone/Hemlock 12. Present well condition summary Total depth: measured 12,050 feet Plugs (measured) 11,904'-12,050' Cement true vertical 10,188 feet Effective depth: measured 11,894 feet Junk (measured) 11,540' and 11,894' Packers true vertical 10,038 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface Intermediate Production 9,365' 9-5/8" 2,326 sx 9,365' 7,727' Liner 2,894' 7" 850 sx 12,031' 10,168' Perforation depth: measured See attached wellbore schematic 0 ~ [ ~.~1 [~[AL true vertical Tubing (size, grade, and measured depth) 4-1/2", 12.6 Ib/ff L-80 Tubing to 10,650' RE EIVEI) Packers and SSSV (type and measured depth) Baker FB-1 Packers @ 11308' and @ 11393'. Baker SABL-2 Packer @ 10556'. 13. Stimulation or cement squeeze summary .^ 18 1999 Intervals treated (measured) Treatment description including volumes used and final pressure jll~ll~rl~ NA 14. Representative Dad¥ Avera,qe Production or Iniection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 6/20/99 34 12 156 682 110 Subsequent to operation 10/21/99 1488 452 650 1202 140 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certJfy that the foregoing is true and correct to the best of my knowledge: Signed: Dan Williamson (~/I/~){) ~./L/~f~/'~,- Title: Drilling Manager Date: //~- /~ --~'~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ( UNOCALe RKB = 41' Rig Floor to TBG Hanger DV Collar 5,778 TOL ~ 9,136' Proposed ~-'--G-Zone A,B,C ~ 11,540' " '~' ~ 11,894' TD = 11,904'; PB~ = 11,904' HOLE ~GLE = 40° ~ 9,300' SIZE 13-3/8" 9-5/8" 9-5~8" 9-518" 7" Tubing: 4-1/2" NO 4a 4b 5a 5b 6 7 8 9 10 11 Dolly Va(' n Platform Well # 12RD Actual Completion 8/16/99 61 40 43.5 47 29 12.6 Casing and Tubing Detail GRADE CONN ID MD TOP MD BTM. J-55 Buttress 12.515 Surt'. 2,537' N-80 Buttress 8.835 Surf. 6,192' N-80 Buttress 8.755 6,192' 8,289' N-80 Buttress 8.755 6,192' 10,297' N-80 Buttress 6.184 9,137' 12,031' L-80 Buttress 3.958 41 10,650' Depth ID Item Jewelry 41 3.958" 314' 3.813" 2,464' 3.958" 4,491' 3.958" 6,012' 3.958" 7,164' 3.958" 8,157' 3.958" 8,995' 3.958" 9,612' 3.958" 10,103' 3.958" 10,496' 3.958" 10,546' 3.880" 10,546' 3.880" 10,565' 4.000" 10,566' 3.875" 10,612' 3.813" 10,650' 4.000" 11,308' 4.000" 11,318' 2.992" 11,392' 3.000" 11,393' 4.000" CIW 4-1/2" Type F Tubing Hanger: 4-1/2" 8rd top~4-1~2" BTC bottom Halliburton Safety Valve landing nipple #1 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 02 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 03 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 04 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 05 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 05 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 07 4-1/2" SFO-1 McMurry-Macco GLM w/1.5" Valv, RA-2 08 4-1/2" SFO-1 McMurry-Macco GLM w/1" Valve, BK-2 09 4-1/2" SFO-1 McMurry-Macco GLM w/1" Orifice, BK-2 Baker Locator and seal assembly Baker 80-47 PBR (L = 18.4') Baker KBH-22 anchor seal assembly Baker SABL-2 permanent packer w/mill out extension Baker X-nipple Wireline entry guide Baker FB-1 permanent packer with mill out extension 3-1/2" 9.2 lb/ft tubing w/Mod BTC (11,318'-11,391') Baker Locator and G-22 locator seal assembly Baker FB-1 permanent packer with seal-bore extension Fish/Fill Information: A. 2-1/8" strip gun 25ft long tag ~ 11,581' DIL, 10/9/93 B. Tag fill @ 11,607' DIL, 10/93 C. 16 ft long strip gun w/bull nose, 11/28/89 Perforations Date Zone Top BTM Comments 10/01/99 G-2 10,722.5 10,746.2 09/30/99 G-3 10,800 10,829 HBO 11,150 11,160 HB-0 11,190 11,200 HB-1 11,225 11,240 HB-2 11,258 11,268 HB-3 11,350 11,380 HB-4 11,412 11,432 HB-4 11,440 11,470 HB-4 11,485 11,520 HB-4 11,530 11,580 HB-5 11,596 11,630 HB-5 11,690 11,715 2-7/8' HC 4 SPF 2-7/8' HC 4 SPF See well history for perforating dates RECEIVED 18 1999 DV-12RD 8-16-99.doc REVISED: 10/20/99 DRAWN BY: MWD Dolly Varden Platform D-12RD Workover Operations Summary 7119-7/26/99 ND tree and NU BOPE. Attempt to pull seal assembly out of packer. Second 3- 1/2' tubing joint parted. Lost control line downhole. RIH with rope spear and recover control line. RIH with overshot and pull on tubing. Tubing parted @ 757'. POOH with tubing and all of control line. Discovered weight indicator not working. Repair same. RIH with over shot and PU on tubing. Attempt to run jet cutter. Jet cutter will not enter tubing. 7/2.,,6-8/1/99 Make chemical cut at 8081'. POOH and lay down 6349' of 3-1/2" tubing. RIH with overshot and latch fish. Make chemical cut at 9007'. POOH and lay down 926' of tubing. RIH with overshot and latch fish. Attempt to jar tubing free from packer. RIH with chemical cutter and stuck at 10338'. Attempt to pull free from weak point without success. Fire chemical cutter and pull tubing free. Chemical cutter still stuck. Cut and strip out of hole with tubing fish and chemical cutter. RIH and latch fish. Run string shot and back off tubing at 10,633'. POOH and lay down 304' of tubing. RIH and attempt to latch tubing collar looking up with no success. (Collar OD is special clearance.) RIH with overshot assembly. ,8/2-8/8/99 Retrieve tubing with overshot grapples and blind back-offs from 10,634' to 10918' (5 trips). RIH with 4-1/8" grapple and latch GLM fish at 10,918'. Recovered bottom GLM and tubing down to packer seal assy. RIH with liner top dressing mill assy and polish top of liner at 9143'. RIH with packer milling assy. Mill packer from 11,013' to 11,017' (two mill runs needed). Packer released and pushed same to 11,187'. RIH with 4-3/4" overshot to latch packer. 8/9-8/15/99 Run overshot assembly. Latch fish and pull tighted tight. POOH with no recovery. Run string mill to clean up perfs and casing. Circulate well with 8.4 PPG. Well began to flow. Shut-in well. Weight up to 8.9 PPG with NACI. Well dead. POOH. Run fishing assy and recovered 1.85' of fish--Iocator with catcher sub fish inside. Run fishing assembly (box tap). Attempt to latch fish. Pull assembly above liner top. PU storm packer and set @ 55'. Change tubing spool. Pressure test new tubing spool to 2,200 psi. Test stack to 3,000 psi. Release storm packer and POOH. No recovery. Switch to AFE 134048: RECEIVED D-12RD ops Summary.doc lof2 ,'nV 18 1099 AII~ 11/15/99-1:31 PM Run bottom straddle packer @ set @ 11,393' DIL. RIH with top straddle packer on drillpipe and stab into packer. Set packer @ 11,308' DIL. POOH and LD BHA. Run 4-1/2' gas lift completion. Set packer @ 10566' DPM. .8/16..8/1,9/99 Test casing and packer to 2,200 psi for 30 min. ND BOPE. NU tree test to 5,000 psi. Lay down drillpipe. Turn well over to production and demobilize rig. 9,/29-10/1/99 RU Schlumberger wireline unit. RIH with 2-7/6" hollow carrier and perforate G-3 @ 10,800'-829' and G-2 @ 10,722.5' to 10746.5' Turn well over to production. RECEIVED ,nv 1 B 1990 D-12RD ops Summary.doc 2 of 2 11/15/99~-1:31 PM I STATE OF ALASKA C(u ALASKA O ,. AND GAS CONSERVATION MMISSION REPORT OF SUNDRY WELL OPERATIONS 10perabons performed Operation shutdown: Sbmulate: Plugging' Perforate Pull tubing Alter casing: Repair well X Other 2 Name of Operator 5 Type of Well' 6. Datum eleval~on (DF or KB) UNOCAL Development' X 106' KB above MSL feet 3. Address Exploratory 7. Umt or Property name '" P O. Box 196247 Anchorage, Alaska 99519-6247 StratJgraph~c: Trading Bay Umt Servme: 4. Locabon of well at surface 8 Well number 678' FSL, 1,217' FWL, Sec 6-8N-13W-SM D-12RD At top of produ~ve interval 9 Permit number/approval r{umber 915' FWL, 2,396' FNL, Sec. 8-8N-13W-SM 80-0082 / 399-018 At effective depth 10 APl number 1,117' FWL, 2,589' FNL, Sec 8-8N-13W-SM 50- 733-20142-01 At total depth 11 F~eld/Pool 1,150' FWL, 2,623' FNL, Sec. 8-8N-13W-SM Hemlock 12. Present well condition summary Total depth, measured 12,050 feet Plugs (measured) 11,904'-12,050' Cement true vertical 10,188 feet Effective depth: measured 11,894 feet Junk (measured) 11,894,11904' Packer true vertical 10,038 feet 11,007' Gas Ifit valve catcher sub Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface Intermediate Production 9,365' 9-5/8" 2,326 sx 9,365' 7,727' L~ner 2,894' 7" 850 sx 12,031' 10,168' Perforation depth, measured See attached wellbore schematic true vertical Tubing (s~ze, grade, and measured depth) 3-1/2", 9 2 lb/it N-80 Tubing to 11,070' Packers and SSSV (type and measured depth) 0~'~RECEIVED 3-1/2" Otis DC TRBV SCSSV @ 310'; Otis WD Packer @11,014' I ~'~ t~ /\ /' ~ I 13 NASt'mulati°n or cement squeeze summary ''~' ~ ~ ~'/"t L. I~%~' Y ], 2. 1999 Intervals treated (measured) NA Treatment description including volumes used and final pressure AJ~I~EB 0il & Gas Cons. C0m~nissi0rt NA Anchorage 14 Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation 11/20/1998 76 17 253 792 105 Subsequent to operation 12/24/1998 78 12 234 843 120 15 Attachments' 16 Status of well classification as: Copies of Logs and Surveys run. Daily Report of Well Operabons. X Oil' X Gas: Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Mitchell Damm for Dan Wdliamson T~tle Dnlhng Manager Date: 5/5/99 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE DOLLY VARDEN 12RD Operations Summary 11/27-30/99 FISH - CTCO - Spot 1-3/4" coil tbg equipment on east pipe rack. RIH & wtchks, slight scale noticed @ 7,800', milling scale @ 60 fpm @ 9,200' tag TOF @ 10,982', work pipe f/TOF t/10,500' & circ btm/up. (Fishing Junk ) RIH w/1%" JDS to 10,981', beat down, couldn't latch. RIH w/ 2.31" over shot to2,466', couldn't pass mandrel, POOH. (Over shot ran on JUC & shearable knuckle). RIH w/2.31" over shot on 5' stem & shearable knuckle, set down in mandrel @ 2,466', couldn't get by, POOH. A piece of grapple broke off (1" wide, 2-1/2" long X 3/8.) RIH 1 5/8" hyd bailer w/2.25" junk catcher on bottom to 10,982', POOH w/bailer empty. RIH w/2.25" lead impression block to 10,982', shows broken piece of grapple (Standing Up). Held safety meeting, got tools ready. RIH w/ over shot w/7/8" grapple to 10,982', POOH w/nothing. Modify over shot skirt. RIH w/ 2.31" over shot w/ 7/8 slips to 10,982', POOH, has marks on side. (Possibly laying over). RIH w/2.6" lead impression block to 10,982', POOH, shows 3 marks on side of lead Impression block. RIH w/CCL & log SSSV & all GLM while RIH. Set dn @ 10,982' rkb. POOH & logging & tie in to tbg tally @ GLM @ 10,619' (tbg tally) 10,954' (E-line) 25' correction. RIH & setdn @ 11,007' w/correction & relog. (T.O.F. is 2 ft below the top of the 5.08' pup that is above the Iocator.) UNOCALe RKB = 41' Rig Floor to TBG Hanger DV Collar @ 5,778 TOL @ 9,136' B,C,E Junk PKR ~ 11,894' TD = 11,904'; PBTD = 11,904' MAX HOLE ANGLE -- 40° ~ 9,300' DV-12RD 10-5-80.doc SIZE WT Dolly Va~ruen Platform Well # 12RD Completed: 10/05/80 Casing and Tubing Detail GRADE CONN ID MD TOP MD BTM. 13-3/8" 61 J-55 Buttress 9-5/8" 40 N-80 Buttress 9-5/8" 43.5 N-80 Buttress 9-5/8" 47 N-80 Buttress 7" 29 N-80 Buttress Tubing: 3-1/2" 9.2 N-80 Buttress Jewelry NO Depth ID Item 1 44.3 3.958" 2 310' 2.75 3 2,477' #1 3-1/2" 4,132' #2 3-1/2" 5,452' #3 3-1/2" 6,617' 04 3-1/2" 7,575' 05 3-1/2" 8,440' #6 3-1/2" 9,099' 07 3-1/2" 9,635' #8 3-1/2" 10,019' 09 3-1/2" 10,338' #10 3-1/2" 10,629' #11 3-1/2" 10,923 012 3-1/2" 4 10,970' 2.74" Otis 5 11,015' 2.992" Otis 6 11,038' 2.75" Otis 7 11,070' 2.992 Otis 12.515 Surf. 2,537' 8.835 Surf. 6,192' 8.755 6,192' 8,289' 8.755 6,192' 10,297' 6.184 9,137' 12,031' 2.992 41 11,070 C1W 4-1/2" Type F Tubing Hanger: 4-1/2" American seal- lock bottom with crossover to 3-1/2" Buttress Otis DC Tubing Retrievable SCSSSV Merla TPD Gas-Lift Mandrel Merla TPD Gas-Lift Mandrel Merla TPD Gas-Lift Mandrel Merla TPD Gas-Lift Mandrel Merla TPD Gas-Lift Mandrel Merla TPD Gas-Lift Mandrel Merla TPD Gas-Lift Mandrel Camco KBUG Gas-Lift Mandrel Camco KBUG Gas-Lift Mandrel Camco KBUG Gas-Lift Mandrel Camco KBUG Gas-Lift Mandrel Camco KBUG Gas-Lift Mandrel XA sliding sleeve locator and seal assembly (Length = 13.16') 'X' Nipple mule shoe (Cut) 8 11,014' 5.0"?? Otis WD Permanent packer Fish/Fill Information: A. P~ece of overshot grapple @ 11,007', 11/30/98 B. 2-1/8" strip gun 25ft long tag ~ 11,581' DIL, 10/9/93 C. Tag fill ~ 11,607' DIL, 10/93 D. Gas hft valve and catcher sub stuck in X-N~pple ~ 11,038', 8/1/95 E. 16 ft long strip gun w/bull nose, 11/28/89 Perforations Date Zone Top BTM Comments HB-0 11150 11160 See well history for perforat- HB-0 11190 11200 ing dates HB-1 11225 11240 HB-2 11258 11268 HB-3 11350 11380 HB-4 11412 11432 RECEI¥ D HB-4 11440 11470 HB-4 11485 11520 HB-4 11530 11580 I'~'X'~ ~[ 2 1~ HB-5 11596 11630 ItB-5 11690 11715 ikl~k0[[ &~_a?~C0B~I~0II~O~.~. ~ REVISED: 1/08/99 DRAWN BY' MWD ( STATE OF ALASKA ( ALASKAL~,~ AND GAS CONSERVATION C~vIMISSION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request Abandon Suspend Operabon shutdown Re-enter suspended well Alter casing Repair Well Plugging T~me extension- Stlmulat-~"' Change approved program X Pull tu~'~ng Vanance X Perforate Other 2 Name of Operator 5 Type of well 6 Datum elevation (DF or KB) UNOCAL Development X 106' KB above MSL feet 3 Address Exploratory 7 Umt or Property name P O Box 196247 Anchorage, Alaska 99519-6247 Strabgraphlc Trading Bay Unit Sen/~ce 4 Location of well at surface 8 Well number 678' FSL, 1,217' FWL, Sec 6-8N-13W-SM D-12RD At top of productive interval 9 Permit number 1,251' FWL, 2,526' FNL, Sec 8-8N-13W-SM ~33ej=O-.l~ ~) . (~)~ At effecbve depth 10 APl number 1,131' FWL, 2,418' FNL, Sec 8-8N-13W-SM 50- 733-20142-01 At total depth 11 F~eld/Pool 1,165' FWL, 2,620' FNL, Sec 8-8N-13W-SM Hemlock 12 Present well condition surr. hary Total depth measured 12,050 feet Plugs (measured) 11,904'-12,050' Cement true vertical 10,188 feet Effective depth measured 11,894 feet Junk (measured) 11,894,11904' Packer true verbcal 10,038 feet 11,007' Gas lilt valve catcher sub Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface Intermediate 9,365' 9-5/8" 2,326 sx 9,365' 7,727' Producbon 2,894' 7" 850 sx 12,031' 10,168' Liner Perforabon depth measured See attached wellbore schematic true vertical Tubing (size, grade, and measured depth) 0RJGJNAL 3-1/2", 9 2 Ib/ft N-80 Tubing to 11,070' Packers and SSSV (type and measured depth) 3-1/2" Otis DC TRBV SCSSV @ 310', Ohs WD Packer @ 11,014' 13 Attachements Descnpbon summary of proposal Detaded operabons program BOP sketch X 14 Estimated date for commencing operation 15 Status of well classification as May 1, 1999 16 If proposal well verbally approved Od X Gas. Suspended Name of approver Date approved Service 17 I hereby certify that the f~l\/~olng ~s t,rue a~id cio~Tect to the best of my knowledge S,gned Dan W, ll,amso ,r~/~/~ ~ ,!i~ ~~/~//~ , . . ,Title Drilling Manager Date 4/7/99 FOR COMMISSION USE ONLY Condlbons of approval Notify Commission so representative may witness IApproval No Plug ,ntegr,ty BOP Test /../" Location clearanceI ._~'~--~)~ { Mechanical Integnty Test Subsequent form required 10- /.~ O~ ,~,~ oo~'~ Approved by order of the C°mm'ss~ne~/~ ~ Comm,ss,oner Date S Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Unocal Alaska Resot~ Unocal Corporation 909 W 9th Avenue PO Box 196247 Anchorage, Alaska 99519-6247 UNOCAL Wednesday, April 07, 1999 AOGCC Attn: Mr. Jack Hartz 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Hartz: UNOCAL is currently planning to workover Dolly Varden D-12RD to access the G-zone. A new 403 sundry is being submitted requesting a variance to the original 403 Sundry that was sent in February--approval No. 399-018. Since the D-12RD has past its "No-Flow" test and the current Hemlock reservoir pressure is 3,900 psi ~ a 9,406' TVD, UNOCAL does not consider the well to be a high well control risk. Therefore, we are respectfully requesting the following variances be granted: Employ the use of secured 7,500 psi flexible lines fitted with 1502 WECO unions for service as a doxvnstream choke line. . Use the Dolly Varden low-pressure production separator system as opposed to the use of a "Poor Boy" degasser. Please see the attached BOP diagram and choke manifold diagram. If you have any questions, feel free to contact me ~ 263-7677. Sincerely, · Dan Wilhamson Drilling Manager AOGCC BOP letter. DOC RI(; FLOOR 6' RISER I' HYDRIL 13-5/8' GK ~ NeIULUR I:'REVENfB ! I CHOKElu~ SHAFf'ER DOUBLE ¢.,ATE BOP r~ (~RAMTOP PIPE ~ BUND I' DRILL DECK I~.1 5M CROSSOVER SPOOL i DOLLY VARDEN PLATFORM COOK INLET, t~C~N-r[~ ACTOR DOLLY VARDEN PLATFORM BLOW OUT PREVENTER UNOCAL D- DV-O 15 To Production Header: 1502 Weco Threaded Connection x 2" 7,500 psi flexible line UNOCAL Portable 5M psi Choke Manifold To Crown Vent Line: > 1502 Weco Threaded Connection x 2" 7,500 psi flexible line H~ Choke All valves are National 5M psi manual ball valves H~ Choke To Drain: Manual Choke From BOP Choke line: 2" 7,500 psi flexible line with Baker-locked 4-1/16" 5M psi flange bolted to inlet STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request Abandon Suspend Operabon shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing X Vanance Perfom_te. x Other 2 Name of Operator 5 Type of well 6 Datum elevabon (DF or KB) UNOCAL Development X 106' KB above MSL feet 3 Address Exploratory 7 Unit or Property name P O Box 196247 Anchorage, Alaska 99519-6247 Stratlgraphlc Trading Bay Unit Service 4 Location of well at surface 8 Well number 678' FSL, 1,217' FWL, Sec 6-8N-13W-SM D-12RD At top of productive interval 9 Permit number 1,251' FWL, 2,526' FNL, Sec 8-8N-13W-SM ~P(3 At effective depth 10 APl number 1,131' FWL, 2,418' FNL, Sec 8-8N-13W-SM 50- 733-20142-01 At total depth 11 Field/Pool 1,165' FWL, 2,620' FNL, Sec 8-8N-13W-SM Hemlock 12 Present well cond~bon summary Total depth measured 12,050 feet Plugs (measured) 11,904'-12,050' Cement true vertical 10,188 feet Effecbve depth measured 11,894 feet Junk (measured) 11,894,11904' Packer true vertical 10,038 feet 11,007' Gas lilt valve catcher sub Casing Length S~ze Cemented Measured depth True vertical depth Structural Conductor Surface Intermediate 9,365' 9-5/8" 2,326 sx 9,365' 7,727' Prod ucbon 2,894' 7" 850 sx 12,031' 10,168' Liner Perforabon depth measured See attached wellbore schemabc true verticalRECEIVE Tubing (s,ze, grade, and measured depth) 0 RIG IN A L FEB O~,- 1999 3-1/2", 9 2 Ib/ft N-80 Tubing to 11,070' Packers and SSSV (type and measured depth) 3-1/2" Otis DC TRBV SCSSV @ 310', Ot,s WD Packer @ 11,014' Alaska 0il & Gas Cons. C0m 13 Attachements Description summary of proposal X Detailed operabons program BOP sketch X 14 Esbmated date for commencing operation 15 Status of well classification as March 23, 1999 16 If proposal well verbally approved Od X Gas Suspended Name of approver Date approved Serv,ce 17 I hereby certify, tbatXhe.~ng ~s true and correct to the best of my knowledge Signed Mitchell Damm for Dan Wdhamson Title Drilling Manager Date 2/2/99 FOR COMMISSION USE ONLY Cond~bons of approval Nobly Commission so representabve may w~tness IApproval No Plug ,ntegr,ty.__ BOP Test ~ Locat,on clearance I Mechamcal Integnty Test Subsequent form reqmred 10- ORIGINAL SIGNED BY Robert N Chnstenson .~ C..~o~)~J Approved by order of the Comm,ss,oner ~OO~.O;~.~.~O~ _~ _~.~ Comm,ss,oner Date{;;~'"/l '"' ~' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Unocal Alaska Business Unit Dolly Varden Platform Well #D-12RD UNOCAL ) Kill Well and Cut Tubing RU APRS wireline trait. RU lubricator and pressure test. RIH with cutter and cut tubing above packer RD APRS unit. Kill well with FIW. Pull Completion 1 Set BPV in hanger. 2 ND Tree. 3 NU BOPE. 4 Pull BPV and set two-way check. Test BOPE 5 RIH with landing joint and engage tubing hanger. 6 Pull hanger loose and circualate well. 7 LD tubing hanger and POOH laying down tubing. 8 LD fish in tubing tail Mill 9 10 11 12 13 14 15 16 17 18 19 20 21 and Retrieve Packer Run wear bushing and complete BOP. MU packer mills. RIH with BHA PU drillpipe. Mill packer POOH with mills LD mills and PU packer retrieving tools RIH with retrieveing tools Latch packer POOH with retrieving tools. LD BHA. RIH with 9-5/8" and 7" casing scraper. POOH with casing scrapers; LD drillpipe. LD BHA. Run Scab Liner Across Hemlock Bench 3 22 RU Schlumberger wireline unit. 23 RIH with bottom scap packer and set below HB-3. 24 POOH and RD SWS. 25 MU 7" by 5" top scab packer, 5" scab liner and seal assembly. DV-12RD WO Cost Est 4.xls Page 1 of 2 2/2/99 Unocal Alaska Business Unit Dolly Varden Platform Well #D-12RD UNOCAL ) 26 R/H with scab liner. 27 Set top scap packer between HB-3 and HB-2 to isolate HB-3 28 POOH standing back ddllpipe. 29 LD packer nmning tools Run 30 31 32 33 34 35 36 37 38 39 40 41 42 43 Completion MU 7" by 4-1/2" production packer RIH with packer on drillpipe. Set production packer above G-zone. Pressure test packer and casing. POOH laying down drillpipe. Pull wear bushing. RU to run 4-1/2" gas lift completion. PU, rabbit and mn gas lift completion. Space out, install SCSSV, control line, and PU hanger. Circulate, Land hanger. Test Packer ND BOPE. Install original tree and test. Demoblize rig. ($35,000) Perforate G-zone and test G-zone. a Flowtest the Hemlock b RU wireline unit. c Perforate the G-zone. d RIH and set inflatable packer above Hemlock. e Flow test the G-zone for two weeks. f Run G-Zone production profile. g Retrieve inflatable packer. DV-12RD WO Cost Est 4.xls Page 2 of 2 2/2/99 UNOCAL ) RKB = 41' Rig Floor to TBG Hanger DV Collar @ 5,778 TOL @ 9,136' B,C,E Junk PKR @ 11,894' TD = 11,904'; PBTD = 11,904' MAX HOLE ANGLE = 40° ~ 9,300' DV-12RD 10-5-80.doc SIZE WT Dolly VarJ~. Platform Well # 12RD Completed: 10/05/80 Casing and Tubing Detail GRADE CONN ID MD TOP MD BTM. 13-3/8" 61 J-55 Buttress 9-5/8' 40 N-80 Buttress 9-5/8" 43.5 N-80 Buttress 9-5/8' 47 N-80 Buttress 7" 29 N-80 Buttress Tubing: 3-1/2' 9.2 N-80 Buttress NO Depth ID Item 1 44.3 3.958" 2 310' 2.75 3 2,477' 4,132' #2 3-1/2" 5,452' #3 3-1/2" 6,617' #4 3-1/2" 7,575' #5 3-1/2" 8,440' #6 3-1/2" 9,099' #7 3-1/2" 9,635' #8 3-1/2" 10,019' #9 3-1/2" 10,338' 010 3-1/2" 10,629' #11 3-1/2" 10,923 #12 3-1/2" 4 10,970' 2.74" Otis 5 11,015' 2.992" Otis 6 11,038' 2.75" Otis 7 11,070' 2.992 Otis 12.515 Surf. 2,537' 8.835 Surf. 6,192' 8.755 6,192' 8,289' 8.755 6,192' 10,297' 6.184 9,137' 12,031' 2.992 41 11,070 CIW 4-1/2" Type F Tubing Hanger: 4-1/2" American seal- lock bottom with crossover to 3-1/2" Buttress Otis DC Tubing Retrievable SCSSSV #1 3-1/2" Merla TPD Gas-Lift Mandrel Merla TPD Gas-Lift Mandrel Merla TPD Gas-Lift Mandrel Merla TPD Gas-Lift Mandrel Merla TPD Gas-Lift Mandrel Merla TPD Gas-Lift Mandrel Merla TPD Gas-Lift Mandrel Camco KBUG Gas-Lift Mandrel Camco KBUG Gas-Lift Mandrel Camco KBUG Gas-Lift Mandrel Camco KBUG Gas-Lift Mandrel Camco KBUG Gas-Lift Mandrel XA sliding sleeve locator and seal assembly (Length = 13.16') 'X' Nipple mule shoe (Cut) 8 11,014' 5.0"?? Otis WD Permanent packer Fish/Fill Information: A. P~ece of overshot grapple ~ 11,007', 11/30/98 B. 2-1/8" strip gun 25ft long tag @ 11,581' DIL, 10/9/93 C. Tag fill ~ 11,607' DIL, 10/93 D. Gas lift valve and catcher sub stuck m X-N~pple @ 11,038', 8/1/95 E. 16 ft long strip gun w/bull nose, 11/28/89 Perforations Date Zone Top BTM Comments HB-0 11150 11160 HB-0 11190 11200 HB-1 11225 11240 HB-2 11258 11268 HB-3 . 11350 11380 HB-4 11412 11432 HB-4 11440 11470 HB-4 11485 11520 FIB-4 11530 11580 HB-5 11596 11630 HB-5 11690 11715 See well history for perforat- ing dates REVISED' 1/08/99 DRAWN BY: MWD UNOCALe ( Dolly Varden Platform Well # 12RD Proposed RKB = 41' Rig Floor to TBG Hanger DV Collar 5,778 TOL ~ 9,136' 8 10 ~___Proposed G-Zone A,B,C 1~3~3~371 J~;~[ ~ 11,894' TD ~ 11~904~; PBTD = 11~904~ ~ ~OLE ~GLE ~ 40° ~ 9,300' DV- 12RD Proposed.doc SIZE WT Casing and Tubing Detail GRADE CONN ID MD TOP MI) BTM. 13-3/8" 9-5/8" 9-5/8" 9-5/8" 7" Tubing: 4-1/2" 61 40 43.5 47 29 12.6 J-55 Buttress 12.515 Surf. 2,537' N-80 Buttress 8.835 Surf. 6,192' N-80 Buttress 8.755 6,192' 8,289' N-80 Buttress 8.755 6,192' 10,297' N-80 Buttress 6.184 9,137' 12,031' L-80 Buttress 3.958 41 10,650' NO Depth ID Item Jewelry 44.3 310' 3.958" 3.833 3.833 CIW 4-1/2" Type F Tubing Hanger: 4-1/2" American seal- lock bottom with crossover to 3-1/2" Buttress Otis DC Tubing Retrievable SCSSSV gl 4-1/2" McMurry-Macco Gas-Lift Mandrel g2 4-1/2" McMurry-Macco Gas-Lift Mandrel g3 4-1/2" McMurry-Macco Gas-Lift Mandrel #4 4-1/2" McMurry-Macco Gas-Lift Mandrel g5 4-1/2" McMurry-Macco Gas-Lift Mandrel g6 4-1/2" McMurry-Macco Gas-Lift Mandrel g7 4-1/2" McMurry-Macco Gas-Lift Mandrel g8 4-1/2" McMurry-Macco Gas-Lift Mandrel g9 4-1/2" McMurry-Macco Gas-Lift Mandrel gl0 4-1/2" gll 4-1/2" 4 5 10,620' 6 7 10,650' 8 11,340' Baker packer 9 4.408" 5" 15 lb/ft L-80 Scab Liner 10 11,390' Baker packer McMurry-Macco Gas-Lift Mandrel SMOR-1A McMurry-Macco GLM w/1" Valve gl2 4-1/2" SMOR-1A McMurry-Macco GLM w/1" Orifice Baker sliding sleeves with gas-lift orifices Baker locator, seal assembly, and packer 'X' Nipple Wireline entry guide Fish/Fill Information: A. 2-1/8" strip gun 25ft long tag @ 11,581' DIL, 10/9/93 B. Tag fill @ 11,607' DIL, 10/93 C. 16 ft long strip gun w/bull nose, 11/28/89 Perforations Date Zone Top BTM Comments Proposed G-2 10,729 10,752 Proposed G-3 10,803 10,832 Proposed G-4 10,856 10,889 Proposed G-5 10,956 11,012 HB-0 11,150 11,160 HB-0 11,190 11,200 HB-1 11,225 11,240 HB-2 11,258 11,268 HB-3 11,350 11,380 HB-4 11,412 11,432 HB-4 11,440 11,470 HB-4 11,485 11,520 HB-4 11,530 11,580 HB-5 11,596 11,630 HB-5 11,690 11,715 See well history for perforating Ting dates REVISED: 1/22/99 DRAWN BY: MWD Unocal Corporatio~ Oil & Gas Operations" 909 West 9th Avenue P 0 Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOr. March 20, 1996 Alaska Mr. David Johnston, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Commissioner Johnston DUPLICATE Re: Dolly Varden Platform - Well D-12RD APl Number 50-733-2014;~-01 , The following intervals were perforated in Well D-12RD: H.B:0 .. . 11..., 150 .......... ' 1.!, 1~0'' 10 ....... ~/25/94 HB-0. 11,190........... 1..1,200 .... 10 '" 6/25/94 . 'i HE-1 .... 11..,230 ..... .1.1,240 10 ......... 6/24/94 . HE-3 ..... 11,41211,432 20 6/24/94 HB-4 .. 11,485 .... 11,515 ...... ,30 .. 6/2~4/~4 ,,, .. . TOTAL 80 ' ,,, ,,, , ........... Very truly yours, G. Russell Schmidt Drilling Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operatx)ns performed: 2 Name of Operat~ Pull tub~n~l UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3 Address P O BOX 196247 ANCHORAGE~ AK 99519 - 6247 4 Locatmn of well at surface 678' FSL, 1,217' FVVL, Sec 6, T8N, R13W, SM At top of productNe Interval 1,251' FWL, 2,526' FNL, Sec. 8, T8N, R13W, SM At effectNe depth 1,131' FVVL, 2,418' FNL, Sec 8, TSN, R13W, SM At total depth 1~165' FWLt 2t620' FNL, Sec. 8~ T8N, R13W, SM 12 Present well cond~Jon summary Total depth measured 12,050 true vertmal 10,188 Sbmulats Plug ~g.L~ --- After casln~l Repa,r well 5 Type of Well: Development ~ Strat3graph]c __ Ser~ce Perforate X Pull tub~n~l Other 6 Datum elevatmn (DF or KB) 106 KB above MSL feat 7 Unit or Property name Trading Bay Unit 8 Well number D-12RD 9. Perm~ number ..~ 10. APl number 50-733-20142-01 11. Field/Pool Hemlock feet Plugs (measured) feet 11,904' - 12,050' CMT Effective depth: measured 11,894 feet Junk (measured) true ver13cal 10,038 feet 11,894' - 11,904' Pkr. Caang Length S~ze Cemented Measured depth True verbcal depth Conductor Surface Intermediate 9,365' 9-518" 2,326 sx 9,365' 7,727' Produc~on 2,894' 7" 850 sx 12,031' 10,168' Liner Perforat3on depth measured See Attachment #1 DUPLICATE true ver'acal Tubing (size, grade, and measured depth) 3-112", 9 2#, N-80 Tbg to 11,070' Packers and SSSV (type and measured depth) 3-1/2" Ohs DC TRBV SCSSV @ 310'; Oas WD Pkr @ 11,014' 13 Sbmulaaon or cement squeeze summary Intervals treated (measured) 14 Treatment deecnpbon including volumes used and final pressure Representative Daily Average Produc'aon or Injec'aon Data Od-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Pnor to well operation 292 16 471 1160 140 --Subsequent to operation 489 350 776 11 50 135 15 Attachments Col~es of Logs and Surveys run Daily Report of Well Operaaons 16. Status of well class#icabon as* Oil X Gas Suspended Service 17. I hereby certify that the f(~[IO~..1.~ (/ IS trl~llll~ ,c~~beStlltl~t~__ of my knowledge. l Signed G. Russell Schmldt~,~~e Ddlling Manager Form 10-404 Rev 06115/88 l - SUBMIT IN DUPLICATE ATTACHMENT #1 WELL D-12RD BENCH MD TVD 0 11,190 11,200 9,379 9,388 1 11,225 11,240 9,415 9,429 2 11,250 11,268 9,434 9,451 3 11,350 11,360 9,526 9,536 3 11,412 11,432 9,588 9,607 4 11,440 11.470 9,610 9,637 4 11,485 11,495 9,656 9,661 4 11,496 11,520 9,662 9,688 4 11,530 11,580 9,693 9,744 5 11,596 11,630 9,759 9,790 5 11,690 11,715 9,843 9,867 Unocal Energy Resour~' '~' 'ivision Unocal Corporation ~, 909 West 9th Avenue, PO ~3ox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL September 21, 1995 Alaska Dear Mr. Douglas: Mr. Russ Douglas, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 SEP 2 7 ]995 Gas Cons. Commission Ntch0rage Re: Dolly Varden Platform Well D-12RD APl Number 50-733-20142-01 On July 27, 1995 the following intervals were perforated in Well D-12RD: BENCH TOP (MD) BOTTOM ('MD) FEET Stray 11,150 11,160 10 HBO 11,190 11,200 10 HB3 11,360 11,380 20 TOTAL 4O Very truly yours, Candace Williams Attachment STATE OF ALASKA ALASK~ ,L AND GAS CONSERVATION C~ /IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugg,ng __ Perforate X Pull tubing __ Alter casing__ Repair well __ Pull tubing __ Other__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 5. Type of Well: Development ~to~y Sift§graphic . Location of well at surface Leg B-l, Cond. #10 DollyVarden Platform 678' FSL, 1,217' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,251' FWL, 2,526' FNL, Sec. 8-8N-13W-SM At effective depth 1,131' FWL, 2.418' FNL, Sec. 8-8N-13W-SM At total depth 1,165' FWL, 2.620' FNL, Sec. 8-8N-13W-$M 12. Present well condition summary Total depth: measured true vertical 12,050' feet 10,188' fe et Plugs (measured) 6. Datum elevation (DF or KB) 106 KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-12RD g. Permit number/approval number 10. APl number ~ 50-733-20142-01 11. Field/Pool Hemlock 11,904' - 12,050' CMT Effective depth: measured true vertical Casing Structural Conductor Surface 11,894' feet 10,038' feet Length Size Junk (measured) Cemented 11,894' - 11,904' Pkr. Me asu~edf~l;~t/~, True ve rtk~al depth ' Intermediate 9,365' 9-5/8" Production 2,894' 7" Liner 2,326 sx 9,365' 7,727' 850 sx 12,031' 10,168' Perforation depth: measured See Attachment true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", 9.2#, N-80 Tbg. to 11,070' 3-1/2" Otis DC TRBV SCSSV @ 310'; Otis WD Pkr @ 11,014' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation SEP 2 7 1995 Ns~k~ 0[1 & Gas Cons. Commission Representative Daily Average Production or Injection Data Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 382 91 2675 1081 175 Subsequent to operation 152 106 2305 1249 150 15 Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17.1 herel~y certif)f)that th~ foregoj,ng i,i true and,correct to the best of myknowledge. Form 10 ~..404 Rev 06/15/88 SUBMIT IN DUPLICATE Attachment #1 Well D-12RD Perforations BENCH MD TVD Stray 11,150' 11,160' 9,341' 9,351' 0 11,190' 11,200' 9,379' 9,388' 1 11,225' 11,240' 9,415' 9,429' 2 11,250' 11,268' 9,434' 9,451' 3 11,350' 11,360' 9,526' 9,536' 3 11,360' 11,380' 9,536' 9,554' 3 11,412' 11,432' 9,588' 9,607' 4 11,440' 11,470' 9,610' 9,637' 4 11,485' 11,495' 9,656' 9,661' 4 11,496' 11,520' 9,662' 9,688' 4 11,530' 11,580' 9,693' 9,744' 5 11,596 11,630 .9,759 9,790 5 11,690 11,715 9,843 9,867 [. .I..i v S EP 2 7 1995 Ataska 0~1 & Gas Cons. Commission Anchorage S( STATE OF ALASKA ~ ALA F,,A OIL AND GAS CONSERVATION COM ~SION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request. Abandon Suspend Operation shutdown Re-enter suspended well Alter casin"~' Repair wel'"T' Plugging m -- Time extension St~mulat'"~ Change appro-~'ed programm m Pull Tubing ~ Variance__ P'-~rforate ~ Othe~ ,, 2 Name of Operator 5. Type of Well 6. Datum elevation (DF or KB) UNOCAL (Marathon Oil Company - Sub Operator) Development X 106' KB above MSL feet Exploratory - 3 Address Strahgraphic -- 7. Un~ or Property name P.O. Box 196247 Achorage, AK Service ~ Trading Bay Unit 4. Location of well at surface Leg B-l, Cond. #10 Dolly Varden Platform 8 Well number ,,,,, ,,,.,, ,,,,,,, ec. ,,. ,,,,,_, /,.. At top of productive mnterval 9 Permit number/approval number 1,251' FWL, 2,526' FNL, Sec. 8-8N-13W-SM At effecbve depth 10 APl number 1,131' FWL, 2.418' FNL, Sec. 8-8N-13W-SM 50- 733-20142-01 At total depth 11 F~eld/Pool 1,165' FWL, 2,620' FNL, Sec. 8-8N-13W-SM Hemlock 12 Present well condition summary Total Depth' measured 1 2,050' feet Plugs (measured) 11,904' - 12,050' CMT true vertical 1 O, 188' feet Effecbve depth' measured 1 1,894' feet Junk (measured) 11,894' - 11,904' Pkr true vertical 1 0,038' feet Casing Length S~ze Cemented Measured depth True vertical depth Structural Conductor Surface Intermediate 9,365' 9-5/8" 2,326 sx 9,365' 7,727' Producbon Liner 2,894' 7" 850 sx 12,031' 10,168' Perforation depth measured See Attachment #1 true vertical Tubing (size, grade, and measured depth)MAY '~ '1 1994 3-1/2", 9.2~, N-80 Tbg. to 11,070' At~sk~ 0ti & Gas Cons. Commission Packers and SSSV (type and measured depth) Anchorage 3-1/2" Otis DC TRBV SCSSV ~ 310'; Otis WD Pkr ~ 11,014' 13 Attachments Descnptton summary of proposal X.~ Detaded operations program Estimated date of commencing operabon 15 Status of well classification as April 28, 1994 If proposal was verbally approved Od ~ Gas Service Name of approver Date approved 17 I hereby certify that th,e~forego~ng ~s true and correct to the best of my knowledge S,gned,~~~ T,tle/~ VI.~ J~l.[l'~(.f' //~ jr, I Date,~/¢R¢ - ' ' ~ FOR COMM~SION USE ONLY Cond~bons of approval Not~fy Commission so representative may witness IApproval No Plug integrity_ BOP Test Location clearance.o.~.I Mechanical Integrity Test__ -'~ubsequent form required 10'"'~ Original Slgn~b ~) Approved Copy Returned David W. Johnston Approved by order of the Commlsion _ ~?""/~ ~ ~'~, Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 Well D-12RD Perforations Bench MD TVD 11,190' - 11,200' 9,379' - 9,388' 11,225' - 11,240' 9,415' - 9,429' 11,250' - 11,268' 9,434' - 9,451' 11,350' - 11,360' 11,412' - 11,432' 9,526' - 9,536' 9,588' - 9,607' 4 4 4 4 11,440' - 11,470' 11,485' - 11,495' 11,496' - 11,520' 11,530' - 11,580' 9,610' - 9,637' 9,656' - 9,661' 9,662' - 9,688' 9,693' - 9,744' 11,596' - 11,630' 11,690' - 11,715' 9,759' - 9,790' 9,843' - 9,867' [SUN DRYI.XLW]Perf Database RECEIVED MAY 1 1 1994 Alaska uil & Gas Cons. Commission Anchorage ( PROCEDURE WELL D-12RD OBJECTIVE: Increase oil production rate by perforating new interval in the HB-0 sand. Also reperforate selected interval in HB-0,1,3,4. 1. Test tree valves and ensure operational and holding. 2. Conduct pre-job meeting. Ensure adequate lighting for night operations. . RU E-line unit. Secure w/chains. Hook up platform PA system in unit. Ensure freeze protection. Install new packoff rubbers. Measure OD's and tool lengths. . Pressure test lubricator & BOPE to 2500 psi. Function test BOP's operation under pressure. . Shut-in production to RIH and POOH, but return to production after exiting the tubing tail to flow for approx 1/2 hour to achieve underbalance while perforating. NOTE: Prior to arming guns and until guns are 1,000' in the hole, complete perforating safety measures. Re-establish perforating safety measures while POOH above 1,000'. 6. Perforate the following intervals with 2-1/8" EJ III, 4SPF, 0 degree phasing, 0 offset. Run Sand Interval (DIL) Footaqe 1 HB-4 11,485-11,515 30' 2a HB-3 11,412-11,432 20' 2b HB-1 11,230-11,240 10' 3a HB-0 11,190-11,200 10' 3b HB-0 11,150-11,160 10' NOTE: for runs 2 and 3 which use select fire, correlate and fire the bottom gun, then recorrelate and fire the top gun. 7. RD E-line. 4/22/94 H \wp\Sundry\D-12RD RECEIVE1) MAY '~ '! 1994 Oil & G~s Cons. Commission Anchorage MARATHDN DIL CDMPANY D-t2 RD C~NPLETED 10-0~-00 C~ Type F 310' 3-1/2 Ot,s DC TRBV II) 2.75' 33" CDND, 409' 3 1/2' 9,2# N-80 TBG 13 3/8" CASING 8538' TOL 7' 9136' 9-5/8' Cs9 8 9365' B-O B-1 B-2 B-3 B-4 B-5 Depth Vglv¢ 2,477' AT II-CF 4,132' 5,452 6,617' 4 7,575' 5 8,441' 6 9,099' 7 Mcxcco CMII FSRC 9,635' 8 Camco KBUG PTA CFIR 10,019' 9 Daniels Pressure 10,338' 10 I 10,629' 11 10,923' 12 O-BK Orifice No Mandrel Latch Port 1 Merla TPD RA 2 3 10970' Dt;s XA sleeve ID= 2.74' 11,014' Otis WD Packer 11015' Dtis Locator & seal assembly 11038' Otis X-nipple ID= 8,75' 11070' Otis 1/8 MUle shoe (CUT) BK2 3/8" 5/16" I 22/64" Per¢orat;ons (])IL) B-O 11,190'-11,200' 10' B-1 11,225'-11,240' 15' B-2 11,258'-11,268' 10' B-3 11,350'-11,360' 10' 11,412'-11,432' 20' B-4 11,440'-11,470' 30' 11,485'-11,520' 35' 11,530'-11,580' 50' B-5 11,596'-11,630' 34' 11,690'-11,715' 15' RECEIVED MAY 1 1 1994 ~,,s~ u~ & Gas Cons. Commission Anchorage F~sh' 25.5' 2-1/8" Strip Gun @ 11,581' DIL 10/9/95 F~sh 16' Strip Gun w/ Bull Nose 11/28/89 TAG FILL 8 11,607' DIL 10/93 Rev,s,on Date, 4/19/94 .JUNKE]) PKR, I~ 11984' Revised By: AP/evo PBTD I~ 11904' Reason: Update 7' LINER TO 12031' Previous Revision: 9/23/95 MEMORAND State,. laska Alaska Oil and Gas Conservation Commission TO: David Jo hr).~, Chairmafl'~" ~ THRU: Blair Wondzell, 'x',.~'~' ~ ~ FILE NO: P. I. Supervisor ~' DA, TE: April 9, 1994 9VEJDHBD.DOC FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector No Flow Verification Wells #D-20,12,27,28,&25 Marathon Dolly Varden platform Middle Ground Shoal Field Friday, April 8, 1994: I traveled to Marathon's Dolly Varden platform in the Middle Ground Shoal field of Cook Inlet to verify the No Flow status of five wells. When I arrived the wells had already had their gas lift shut in and the tubing flowed down to the group separator, These were then flowed to the well clean system which has approximately .5 psi back pressure on it. The wells tubing was then routed to open top containers with water in them. All wells bled only gas and died off quickly with the exception of well #D-25 which kept flowing gas and would build up to 160 psi rather quickly, this may have been residual gas in the annulus coming through a leaky gas lift Valve. The platform needed this well back for production and we did not attempt any further tests on other wells. Recommendations: Wells # D-20, D-12, D-27, and, D-28 exhibited a inability to flow from the formation without the assistance of artificial lift and met the criteria for No Flow status. Well # D-25 would not die off and should be maintained as a flowing well. Summary: I verified the no flow status of 4 wells'on Marathon's Dolly Varden platform. cc: Don Lacour (Production Superintendent) DOLLY VARDEN PI-(,~TFORM Wireline Lubricator w/Associated BOPE - GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP 4 ~1/~1.6'-'. 5000 pal CHISTMAS TREE POSITIVE CHOKE RECEIV.ED MAY 11 1994. .~o~a u~l & Gas Cons. Commission Anchorage ---- 2' 5000 pal _.- 2' 3000 13 3/8' CASING STATE OF ALASKA ir. ALA ,,,~ OIL AND GAS CONSERVATION COM ...,SION REPORT OF SUNDRY WELL OPERATIONS Pull Tubing m Alter Casing __ Repair Wellm Other__ I 2 Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 6 Datum elevation (DF or KB) 106' KB above MSL 3 Address P.O. Box 196247 Anchorage, AK 99519 5 Type of Well Development X Exploratory Stratlgraphlc Service 4 Locabon of well at surface Leg B-l, Cond. #10 Dolly Varden Platform 678' FSL, 1,217' FWL, Sec. 6-8N-13W-SM At top of productrve interval 1,251' FWL, 2,526' FNL, Sec. 8-8N-13W-SM At effecbve depth 1,131' FWL, 2.418' FNL, Sec. 8-8N-13W-SM At total depth 1,165' FWL, 2,620' FNL, Sec. 8-8N-13W-SM 7 Un~: or Property name Trading Bay Unit 8 Well number D-12RD 9 Permit number/approval number 80'~2"X'2. ,= 10 APl number 50- 733-20142-01 11 Field/Pool Hemlock 12 Present well condrtion summary Total Depth measured true vertical Effecbve depth measured true vertical Casing Structural Conductor Surface Intermediate Production bner Perforation depth measured true vertical 12,050' feet Plugs (measured) 10,1 88' feet 1 1,894' feet 10,038' feet Length Junk (measured) S~ze Cemented 11,904' - 12,050' CMT 11,894' - 11,904' Pkr Measured depth 9,365' 9-5/8" 2,326 sx 9,365' True verbcal depth 2,894' 7,727' 7" 850 sx 12,031' 10,168' See Attachment #1 Tubing (s~ze, grade, and measured depth) 3-1/2", 9.2#, N-80 Tbg. to 11,070' Packers and SSSV (type and measured depth) 3-1/2" Otis DC TRBV SCSSV @ 310'; Otis WD Pkr @ 11,014' Stimulabon or cement squeeze summary Intervals treated (measured) Treatment descnpbon including volumes used and final pressure RECEIVEr DEC 1 7 Alaska 0il & Gas Cons Anchorage 14 Representabve Dady Average Producbon or Inlectlon Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operabon 349 - 366 546 Subsequent to operabon 402 // 110 722 16 Status of well class~ficabon as Od X Gas -- 7 I hereby,,r,,erbfy that the fope~g~ng ~s, true and correct. to the best of my knowledge S,gned ~~~ T,tle '~ ~, ~J,,t,,~ l~-X Form 10-404 Rev 06/15/88 15 Attachments Cop~es of Log and Surveys run Dady Report of Well Operabons X 1,100 1,150 Suspended Service 130 140 SUBMIT IN DUPLICAT~ Attachment #1 Well D-12RD Perforations Bench MD TVD 11,190' - 11,200' 9,379' - 9,388' 11,225' - 11,240' 9,415' - 9,429' 11,250' - 11,268' 9,434' - 9,451' 11,350' - 11,360' 11,412' - 11,432' 9,526' - 9,536' 9,588' - 9,607' 11,440' - 11,470' 11,485' - 11,495' 11,496' - 11,520' 11,530' - 11,580' 9,610'- 9,637' 9,656'- 9,661' 9,662'- 9,688' 9,693'- 9,744' 11,596' - 11,630' 11,690' - 11,715' 9,759' - 9,790' 9,843' - 9,867' RECEIVED DEC 1 7 199,~ ,~¢swa u,, a Gas Cons. Comm~ss~,, Anchorage [SUN DRYX.XLW] Perf Database DAILY WELL OPERATZONS D- 12RD 10/8-9/93 RU E-line. PT lub to 2500 psi. Good. RIH w/ 2-1/8" EJ, 4 SPF 0° phase strip gun. Flowed well to obtain underbalance and perforated the following: RUN BENCH DEPTH (DIL ) RESULT i HB-5 11,596' - 11,606' Fired 2 HB-4 11,550' - 11,580' Fired RD. Returned well to production. H: \wp\WE L LOPS\D 12RD RECEIVED DEC 1 7 199~ A~s~ U,~ & Gas Cons. Commission Anchorage L STATE OF ALASKA ~ ALA OIL AND GAS CONSERVATION COM I~$1ON APPLICATION FOR SUNDRY APPROVALS 1 Type of Request' Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well__ Plugging __ Time extension Stimulate Change approved program Pull Tubing Variance Perforate X Other 2 Name of Operator UNOCAL (Marathon Oil Company- Sub Operator) 3. Address P.O. Box 196247 Anchorage, AK 99519 5 Type of Well' Development Exploratory Strafigraphic Service 4. Location of well at surface 678' FSL, 1,217' FWL, Sec. 6-8N-13W-SM At top of productrve inten/al 1,251' FWL, 2,526' FNL, Sec. 8-8N-13W-SM At effecbve depth 1,131' FWL, 2.418' FNL, Sec. 8-8N-13W-SM At total depth 1,165' FWL, 2,620' FNL, Sec. 8-8N-13W-SM Leg B-l, Cond. #10 Dolly Varden Platform 12 Present well condition summary Total Depth. measured true verbcal 1 2,050' feet Plugs (measured) 1 0,1 88' feet 6 Datum elevation (DF or KB) 106' KB above MSL 7 Unit or Property name Trading Bay Unit 8 Well number D-12RD 9 Permit number/approval 92-054//'~'x-,-~ ;' 10. APl number 50- 733-20142-01 11 Field/Pool Hemlock 11,904' - 12,050' CMT feet Effective depth measured true vertical Casing Structural Conductor Surface IntermedIate Producbon bner Perforabon depth. measured true vertical 11,894' feet 10,038' feet Length Junk (measured) Size Cemented 11,894' - 11,904' Pkr Measured depth 9,365' 9-5/8" 2,326 sx 9,365' 2,894' 7" 850 sx See Attachment #1 12,031' True vertical depth 7,727' RECEIV£D Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 Tbg. to 11,070' Packers and SSSV (type and measured depth) 3-1/2" Otis DC TRBV SCSSV ~ 310'; Otis WD Pkr @ 11,014' 13 Attachments Description summary of proposal X Detaded operabons program 0 CT - 6 199 Alaska 0il & Gas Cons. Commissiog Anchorage 10,168' BOP sketch X Estimated date of commencing operation October 4, 1993 I, proposal was verbally appro, ve.d^ to the best of my knowledge FO~ co~mr,/o~ u~ o~t.¥ Cond~bons of approval. Nobly Commission so representative may w~ness Plug ~ntegrity__ BOP Test__ Location clearance__ Mechanical Integrity Test__ Subsequent form required 10- Approved by order of the Comm~s~on Form 10-403 Rev 06/15/88 Original Signed By 15 Statls of well class~ficabon as: Od X Gas Serwce Suspended JApproval N.~,~ --'""~'~' 3"'- .~,pproved Copy Returned Commissioner Date ,~ 0/' ~/~¢~ SUBMIT IN TRIPLICATE Bench Attachment #1 Well D-12RD Perforations MD 'I'VD 11,190' - 11,200' g,379' - g,388' 11,225' - 11,240' 9,415' - 9,429' 11,250' - 11,268' 9,434' - 9,451' 3 3 11,350' - 11,360' 11,412' - 11,432' 11,440' - 11,470' 11,485' - 11,495' 11,496' - 11,520' 11,530' - 11,580' 9,526' - 9,536' 9,588' - 9,607' 9,610'- 9,637' 9,656'- 9,661' 9,662'- 9,688' 9,693'- 9,744' 11,600' - 11,630' 11,690' - 11,715' 9,762' - 9,790' 9,843' - 9,867' [SUNDRYB.XLW]Perf Database RECEIVED OCT - 6 1993 Alaska Oil & Gas Cons. Commisston Anchorage D-12RD PROCEDURE OBJECTIVE: Reperforate HB-4,5 · 2. 3. 4. 5. · · . Obtain a 24-hour test with a minimum of four (4) WC's. Test tree valves and ensure operational and holding. Skid rig #76 over D-12RD. Conduct pre-job meeting. Ensure adequate lighting for night operations. RU E-line unit. Hook up platform PA system in unit. Install new packoff in lubricator prior to start of job if the age is unknown. Pressure test lubricator and BOPE to 2500 psi. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. NOTE: Prior to arming guns and until guns are 1,000' in the hole, notify logistic support and complete the ESC. Complete the ESC again when POOH w/guns at 1,000'. SI well. RIH w/ 2-1/8" strip guns, 4 SPF, 0° phase and perforate the following intervals underbalance (well flowing): RUN BENCH INTERVAL (DIL) FOOTAGE I HB-5 11,600' - 11,610' 10' 2 HB-4 11,550' - 11,580' 30' NOTE: Fill was tagged at 11,627' WLM on g/21/g3. Care should be taken while perforating HB-5 {11,600' - 11,610'} to avoid tagging into fill. POOH w/ well SI. RD E-Line unit. Return well to production and obtain a 24-hour well test w/ 4 WC's following cleanup. X: \wp\WLPRO\12RD RECEIVED OCT - 6 199~) Alaska 0ii & Gas Cons. Commission Anchorage MARATHON OI'L COMPANY TRADING BAY UNIT D-18 RD COMPLETED 10-08-80 CI~/ Type F th§ hgr-4 1/2" ASL 4 1/2" ASL 310' 3-1/2 Otis DC TRBV ID 2,75' 33" COND. 409' 3 1/2' 9,2# N-BO TOG 13 3/8" CASING 2538' TDL 7' @ 9136' 9-5/8' Cs9 @ 9365' OTIS WD PKR @ 11014' FISH-16' STRIP GUN W/BULL NOSE Ii/28/89 TAG FILL @ _~ 11627' ~LH 9/93 o B-O B-1 B-2 B-3 B-4 B-5 2477' GLN #1-Her~(l TPD w/AT II-CF valve 4132' GLM #2-Mer~ci TPD w/AT II-CF valve w/ RA {arch ID=2,875' 5458, GLM ~*3-Mer~ci TPD w/AT II-CF v(ilve w/ RA ~(itch ID=2,875 6617' GLM #4-Mer~(i TPD w/AT II-CF valve w/ RA ~(itch ID=2,875' 7575' GLN #5-Her~(l TPD w/AT II-CF valve w/ RA ~(ltch ID=2,875' 8441' GLH #6-Ner~(i TPD w/AT II-CF valve w/ RA latch ID=2,875' 9099' GLN #7-Ner~(1 TPD w/AT II-CF vc~ve w/ RA ~citch ID=2,875' 9635' GLN ~8-CAMCO KBUG 2,92' w/ PTA CFIR verve w/ OK2 Latch iooig' GLM ~9-CAHCO KBUG 2,92' Daniels Pressure w w/ OK2 Latch i0338' GLH ~IO-CANCO KBUG 2,92' Daniels Pressure v w/ OK2 Latch 10629' GLH ~ll-CAMCO KBUG 2,92' Daniels Pressure v( w/ OK2 Latch i0923' GLH ~i2-CAHCO KBUG 2,92' w/ AT O-BK Or,F,ce w/ OK2 Latch, Port = 82/64' 10970' 11015' 11038' 11070' B-O Ot,s XA s(eeve ID= 2,74' Ot;s (ocator & sec( assembty Otis X-nipp(e ID= 275' Otis 1/2 mu(e shoe (CUT) PerForations (DIL) 11190'-11200' B-1 B-2 B-3 B-4 B-5 11225'-11240' 11258'-11268' 11350'-11360' 11412'-11432' RECEIVED 0 CT - G 199 ii44o,_ii4~aska Oil & Gas Cons. Commission 11485'- 11520' Anch0ran~ ii530'-ii580' 11600'-11630' 11690'-11715' JUNKED PKR, @ 11984' PBTD @ 11904' 7' LINER TO 12031' Rev,s,on Date: 9/23/93 Rev,seal By: AP/eva Reason' Update Prev,ous Revision: 10/25/91 / ( .~OLLY VARDEN Pi~ ~TFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) LUBRICATOR 4-1/.1.6'-'. 5000 CHISTMAS TREE POSITIVE CHOKE RECEIVED 0 CT - 6 199~ ' -' Alaska 0ii & Gas Cons. Commission Anchorage .----2' 5000 psi ..-.- 2" 3000 psi 13 3/8' CASING REPORT OF SUNDRY WELL OPERATIONS 1 Operations pedormed Operation shutdown N Sbmulate __ Plugging __ Perforate X Pull tu~ng ~ Alter casing ~ RepaIr well g 2 Name of Operator ! 5 Type of Well v UNOCAL (Harathon 0il Company - Sub (~peratoP~'e~.°Pm.ant'' / t:xp~ora[ory g 3 Address / Strabgraph~c_ P.0. Box 190247 Anchorage, AK ..... 9951~J. .. . Serv,ce_. ..~_. 4 Locabon of well at surface Leg B-l, ¢ond. ~zu uo~ ,y varuen r~dc,un, 678' FSL, 1,217' FWL, Sec. 6-8N-13W-SM At ton of ornc~uct~ve ~nter~/al 1],2-5'1_ FW1.], 2,526' FNL, Sec. 8-SN-13W-SN Ate~c,~tv~f~P~WL, 2,418' FNL, Sec. 8-8N-13W-SM Attot~l,~ FWL, 2,620' FNL, Sec. 8-8N-13W-SM Other ~ 6. Datum elevabon (DF or KB) 106' KB above NSL feet 7 Unit or Property name Trading Bay Unit D8_ ~-~umber C~ .P{~r~t r~umber/approval number 10 APl ~0142-01 50-- 12 Present well condition summary Total depth measured true vertical 12,050' 11,904' 10,188 ' feet Plugs (measured) feet Effecbve depth measured 11,894 ' 11 894 ' feet Junk (measured) ' true vertical 10,038 ' feet - 12,050' CMT - 11,904' Pkr 13. Casing Length S~ze Cemented Measured depth Structural Conductor Surface Intermediate 9,365' 9-5/8" 2,326 SX 9,365' Production Liner 2,894' 7" 850 SX 12,031' Perforation depth measured True verbcal depth 7,727' 10,168' See Attachment #1 true vertical Tub~ln~ (.size, grade, and measured depth) /2", 9.2# N-80 Tbg. to 11,070' MD Pa§k-e/~2~dS~S~¥~tY~ar~Rr~S~s~P~)310', Otis WD Pkr @ 11,014' Stimulation or cement squeeze summary Intervals treated (measured) Treatment descnpt~on including volumes used and final pressure 14. Representabve Da~l¥ Average Production or Injection Data Od-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 582 ,~ 193 613 1180 130 Subsequent to operation 744 '~ 519 790 1190 15. Attachments 116 Status of well class#~cat~on as Copies of Logs and Surveys run ~ I Daily Report of Well Operations L Od X Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed v~5/c~ Form 10-404 Re Service 140 Date [t/~!~z._ ~ SUBMIT IN DUPLICATE ~ DA~LY NELL OPERATIONS D- 12RD 3/6-7/92 Safety meeting. Removed SCSSV from panel and connected to auxiliary pump. Pressure tested BOPE and l ub to 2500 psi. Established CBO. MU and armed 2-1/8", 4SPF 20.5 G DP strip guns. RIH. Flowed well to obtain underbalance. Perforated the following intervals: RD. RUN #1 HB-5 11,600' - 11,620' Fired #2 HB-4 11,550' - 11,580' Fired #3 HB-4 11,496' - 11,520' Fired #4 HB-4 11,485' - 11,495' Fired HB-1 11,225' - 11,240' Fired Returned well to production. H: \wp\WE L LOPS\D 12RD Unocal North America~' Oil & Gas Division ~, Unocal Corporation P O Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCALO Alaska Region DOCUMENT TRANSMITTAL December 1, 1992 TO' Larry Grant LOCATION: 3OOl PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM' Kirk Kiloh LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS TRADING BAY UNIT D-7, D-Il, D-12RD, D-25RD 1 blueline and 1 sepia Perforating Record PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT ~ TRANS TTAL. THANK YOU RECEIVED BY: ~.~ ~- DATED: IXE~. L I v ...^ ^ ,) lO, q9 Alaska Oil & aaa Cons. Commission Anchorage WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~IMlSSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE (907) 279-1433 TELECOPY (907) 276-7542 AUGUST 3, 1992 GARY BUSH UNION OIL COMPANY OF CALIFORNIA P O BOX 190247 ANCHORAGE, ALASKA 99519 DEAR MR. BUSH, OUR FILES INDICATE THAT UNION OIL COMPANY OF CALIFORNIA IS THE OPERATOR OF THE FOLLOWING WELLS MENTIONED IN THIS LETTER. WE ARE REVEIWING WELL FILES FOR MISSING 404 SUNDRY WELL OPERATION FORMS. SEVERAL 403 (SUNDRY APPROVALS) HAVE BEEN APPROVED FOR WORK ON THESE WELLS AND OUR FILES DO NOT REFLECT THAT THE WORK WAS ACCOMPLISHED. WOULD YOU PLEASE LOOK INTO THESE WELL SUNDRYS SO WE CAN CLOSE THEM OUT EITHER BY SUBMITTING THE APPROPRIATE 404 FORM WITH ATTACHMENTS FOR COMPLETED WORK OR A NOTE STATING THAT THE 403 APPROVAL NUMBER IS VOID. THE APPROVAL NUMBER IS ON THE SIGNED COPY OF THE 403 THAT AOGCC SENT BACK TO THE OPERATOR. WELLNAME PERMIT 403 APPROVAL # TRADING BAY UNIT D-5RD TRADING BAY UNIT D-12RD GRANITE PT ST 17568 8 TRADING BAY UNIT K-3RD 80-0065 91-163/7-514 80-0082 92-054 80-0084 91-87 80-0144 90-081 PLEASE LET ME KNOW IF THERE IS ANY PROBLEM WITH SUBMITTING THE PROPER FORM IN A TIMELY MANNER. IF THERE IS SOMEONE ON YOUR STAFF THAT I COULD CONTACT PLEASE GIVE ME THERE NAME AND PHONE NUMBER. THIS IS GOING TO BE AN ON GOING PROCESS JUST LIKE THE PLUG AND ABANDON WELLS. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN C: ROBERT CRANDALL SR PETR GEOLOGIST APPLICATION FOR SUNDRY APPROVALS 1 Type of Request Abandon __ Suspend __ Operahon shutdown __ Re-enter suspended well __ Alter cas~ ng__ Repair well ~ Plugging __ T~me extension __ Stimulate ~ Change approved program ~ Pull tubing __ Vanance ~ Pedorate .X.- Other __ 2 Name oJ Operator. . . ~ 5 Type of Well UNOCAL (Marathon O~l Company - Sub ~)perato~re~cqopmentX ! Exploratory __ 3 Addr. ~ Strat~graph~c i¢~. Box 190247 Anchorage, AK 9951 Serv,ceZ / 4 Locabon of well at surface Leg B-l, Cond. #10 Dolly Varden Platform 678' FSL, 10217' FWL, Sec. 6-8N-13W-SM At tOl~ of oroducbve interval ,251' FWL, 2,526' FNL, Sec. 8-8N-13W-SM Atefff?t~.v~fCPl~wL, 2,418' FNL, Sec. 8-8N-13W-SM Attot~l?~, FWL, 2,620' FNL, Sec. 8-8N-13W-SM %Datum elevabon (DF or KB) 6' KB above NSL feet 7 Unit or Property name Trading Bay Unit 8 Well number D-12RD 9 Permit number 80~.2. 10 API..~umber so333-20142-01 12 Present well cond~bon summary Total depth measured true vertical 12,050' 10,188' feet feet Effecbve depth measured 11,894 ' feet truevert~cal 10,038' feet Plugs (measured) Junk (measured) 11,904' 11,894' - 12,050' CMT - 11,904' Pkr Casing Length S~ze Structural Conductor Sudace Intermediate 9,365' 9-5/8" Production Liner 2,894' 7" Perforation depth measured true vertical See Tubing (s~ze. grade, and measured depth) 3 1/2", 9.2# N-80 Tbg. to 11,070' MD Packers and SSSV (type and measured depth) 3-1/2" Otis DC TRBV SCSSV @ 310', Otis 13 Attachments #1, 2 Descnphon summary of proposal 3,&4 Cemented Measured depth 2,326 sx 9,365' 850 sx 12,031' True vertical depth Attachment #1 7,727' 10,168' R[CEIVED Gas Cons. C0mmiss~o~ /~chomce WD Pkr 0 11,014' Detaded operabons program __ BOP sketch 14 Esbmated date for commencing operation 2/29/92 16 If proposal was verbally approved Mike Mender Name of approver 2 / 28/9 2_Date approved 15 Status of well class~hcabon as Od X__ Gas __ Suspended __ Service 17 I hereby cerbfy that the foregoing ~s true and correct to the best of my knowledge S,gned (~ c>~.~4~' ~ ~ T,tle ~,~.o, . %~'~k~ · ~ ~prov~ ~ ' ~ ~ FOR COMMI~ION USE ON~ Conditions Notify Commission so representabve may witness Plug ~ntegnty ~ BOP Test ~ L~at~on clearance ~ Mechanical Integnty Test ~ Subsequent form required 10- ~ ORIGINAL SIGNED BY LONNIE: C SMITH Approved by order of the Commission Comm,ss, oner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE / Bench 0 Bench 1 Bench 2 Bench 3 Bench 4 Bench 5 Attachment #1 TBU D-12RD Perforations (MD) 11,190' - 11,200' 11,225' - 11,240' 11,250' - 11,268' 11,350' - 11,360' 11,412' - 11,432' 11,440' - 11,470' 11,496' - 11,516' 11,530' - 11,580' 11,600' - 11,630' 11,690' - 11,715' (TVD) 9,379' - 9,388' 9,415' - 9,429' 9,434' - 9,451' 9,526' - 9,536' 9,588' - 9,607' 9,610' - 9,637' 9,662' - 9,680' 9,693' - 9,744' 9,762' - 9,790' 9,843' - 9,867' docs \ dvp \ D 12RD. doc R C irVI D AJ'as~ Oil & Gas Cons. Commissi_q Anchorage Attachment # 2 TBU Well D-12RD Perforation Procedure 1) 2) 3) 4) 5) 6) Obtain a 24-hour test with a minimum of four (4) WC's. Test tree valves and ensure operational and holding. Conduct safety meeting. Ensure adequate lighting for night operations. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. RU E-Line unit. Hook up platform PA system in unit. Install new packoff in lubricator prior to start of job if the age is unknown. Pressure test lubricator and BOPE to 2500 PSI. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE, NOTIFY LOGISTIC SUPPORT & ESTABLISH COMMUNICATION BLACK-OUT. RE-ESTABLISH THE COMMUNICATION BLACK-OUT WHEN GUNS ARE ~ 1000' WHEN POOH. SI WELL TO RIH & POOH. RIH with 2-1/8" strip guns, 4 SPF, 0° phase and perforate the following intervals underbal ance.' RUN BENCH INTERVAL DIL FOOTAGE COMMENTS i HB #1 2 HB #4 3 HB #4 HB #4 4 HB #4 5 HB #5 11,225 - 11,240' 11,550 - 11,580' 11,516 - 11,520' 11,496 - 11,516' 11,485 - 11,495' 11,600 - 11,630' 15 30 4 20 10 30 Reperf Reperf New interval Reperf New Interval Reperf 7) RD E-Line unit. Return well to production and obtain several 12-hour well tests obtaining 3 WC's per 12-hour test. \dvp\d12rd.doc 33" CE]ND @ 409' 13 3/8" CASING 2538' TnL 7' .r_a 9i36' 9-5/8' Csg 9365' OTIS WD PKR @ 11014' ALbachment ¢/3 ( MARATHFIN OIL CFIMPANY TRADING BAY UNIT C~qHPLETED 10-08-80 FISH-!6' STRIP GUN W/BULL NOSE 11/88/89 iB-O TAG FILL @ ~ 1165i' ELM 11/89 2477' D-12 RD Type F zbg hgr-4 1/2" ASL 4 1/2" ASL 310' 3-1/2 D.t,s DC TRBV ID 275' 3 1/2' 92~ N-80 TBG GLM ~l-Merto, TPD w/AT II-CF vo,tve 4132' GLM ~2-Mer"ta TPD w/AT II-CF vo,tve w/ RA to,.tch ID=2875' 5452' GLM ~¢3-Mer(o. TPD w/AT II-CF valve w/ RA Io`.tch ID=2875 66i7' GLM ~4-Mer(o, TPD w/AT II-CF valve w/ RA (a.tch ID=2875" 7575' GLM :~5-Mep(o` TPD w/AT II-CF valve w/ RA to,.tch ID=8,875' 8441' GLM ~6-Merto, TPD w/AT II-CF va, Lye w/ RA La.tch I]]=2875" 9099' GLM ~7-Mer(o, TPD w/AT II-CF va,Lye w/ RA ta.tch ID=2875" 9635' GLM ~8-CANCF1 KBUG 292" w/ PTA CFIR valve w/ BK2 La.rah 10019' GLH #9-CAr,4CO KBUG 892" Dan,ets Pr'essupe va,( w/ BK8 La.tch 10338' GLN ~:iO-CANCB KBUG P 92' Do,n,ets Pressure va`, w/ BK2 La.rah 10689' GLH ~ll-CAMCn KBUG 2 92' Dan,ets Ppessur'e w/ BK2 La.rah 10923' GLH ~12-CANCFI KBUG 292" w/ AT O-BK Flr"~F~ce w/ BK2 La.rah, Pop.t = 88/64' i0970' O.t,s XA sleeve ID= 2 11015' E]t,s Loco,.top g, seo,L assembly fq't,s X-n,ppte ID= 8 75" ,D.t,s 1/2 mute shoe (CUT) 11038' 11070' Pepforo~,ons (DIL) B-1 B-O 11190'-11200' B-1 11225'-11240' B-2 B-2 11258'-11268' B-3 11350'-11360' B-3 11418'-11432' B-4 B-4 11440'-i1470' 11496'-11516' 11530'-11580' B-5 B-5 11600'-11630' 11690'-11715' JUNKED PKR, ~ 11984' PBTD e 11904' 7' LINER Tn i803i' Rev,s,on Dote' 10/P5/9i Rev,seal By JDM/evo Prev,ous Rev,s,on: 8/15/90 Attachment #~ · DOLLY VARDE~" P~TFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP ,, GREASE HEAD (Hydraulically Activated) LUBRICATOR 4-11;1.$-'. 5000 p~l CHISTMAS TREE POSITIVE CHOKE ---- 2' 5000 p.l .._. 2" 3ooo psi 13 3/8' CASING Unocal North Ameri~ Oil & Gas Division Unocal Corporation P 0 Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Regton 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 CONDUCTOR DOLLY DISTANCE & DIRECTIONS FROM SE CORNER SEC. 6~ TSN~ R13W "Y" COORD. "X" COORD. WELL # FSL LEG ~A-1: LAT: 60o48, 28.272" LONG :151°37' 57.620" 2,490,836.22 208,461.20 757.5 1 2 3 4 5 6 7 8 9 lO 11 12 2,490,836.95 208,454.55 D-27 758.1 2,490,840.99 208,456.66 D-28 762.1 2,490,842.79 208,460.79 D-29 764.0 2,490,841.51 208,465.11' D-32 762.9 · 2,490,837.76 208,467.60 D-40 759.2 2,490,833.28 208,467.10 D-41 754.7 2,490,830.18 208,463.83 D-26 751.5 2,490,829.90 208,459.34 D-25 & RD 751'.1 2,490,832.58 208,455.72 753.7 2,490,835.56 208,458.66 D-24 & 34A 756.8 2,490,838.66 208,462.17 D-31 & RD 760.0 2,490,834.00 208,462.61 D-24A 755.3 LEG ~/A-2: 1 2 3 4 5 6 7 8 9 10 ll 12 LEG #B- l' LAT = 60048' 27.485" LONG =151037' 57.564" 2,490,835.42 208,381.20 754.7 2,490,836.16 208,374.66 D-1 755.3 2,490,840.19 208,376.67 ' D-17 759.4 2,490,842.00 208,380.80 D-11 761.3 2,490,840.72 208,385.11 D-7 & RD 760.1 2,490,836.97 208,387.60 D-9 756.4 2,490,832.49 208,387.10 D-19 751.9 2,490,829.39 208,383.84 D-23 748.8 2,490,829.11 208,379.34 D-21 748.4 2,490,831.78 208,375.72 ' D-5 & RD 750.9 2,490,834.77 208,378.66 D-15 & RD & 2 754.0 2,490,837.86 208,382.17 D-3 & RD 757.2 2,490,833.21 208,382.61 D-13 752.5 2,490,756.22 208,462. O0 677.5 1 2 3 4' 5 6 7 8 9 10 ll 12 LEG #B-2' 2,490,755.48 208,468.53 D-8 & RD 677.0 2,490,751.45 208,466.53 D-6 672.9 2,490,749.65 208,462.40 D-14 & RD 671.0 2,490,750.92 208,458.08 D-20 672.1 2,490,754.67 208,455.59 D-16 675.8 2,490,759.15 208,456.10 D-22 680.3 2,490,762.25 208,459.36 D-2 & A & RD 683.5 2,490,762.53 208,463.85 D-4 683.9 2,490,759.86 208,467.48 D-10 681.3 2,490,756.87 208,464.53 D-12 & RD 678.3 2,490,753.78 208,461.02 D-18 675.1 2,490,758.43 208,460.58 D-30 & RD 679.7 2,490,755.43 208,382.00 674.8 (Reserved for Compressors) FWL 1212.0 1205.5 1207.4 1211.5 1215.8 1218.4 1218.0 1214.8 1210.3 1206.7 1209.5 1213.0 1213.5 1132.1 1125.5 1127.4 ll31.5 1135.9 1138.5 1138.1 1134.9 1130.4 1126.7 1129.6 1133.0 1133.6 1214.8 1221.4 1219.5 1215.4 1211.1 1208.5 1 208.9 1212.1 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 ( STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION 0 ~ REPORT OF SUNDRY WELL OPERATIONS 10perabons pedormed Operabon shutdown __ Sbmulate __ Plugging __ Pedorate ~ Pull tul~ng __ Alter casing __ Repair well __ 2 Name of Operator ! 5 Type of Well D Iopment __X UNOCAL (Marathon Oil Company- Suh I)peratoryJ~P~orato~ 3 Address ! Strabgraphmc __-- Serwce P.O. Box ]90247 Anchorage~ AK 9951 -- 4 Locabon of well at surface Leg B-I, Cond. #10 Doily Varden Platform 678' FSL, 1,217' F14L, Sec. 6-8N-]314-SM At top of producbve interval 1,251' F14L, 2,526' FNL, Sec. 8-8N-]314-SM At 4IS' FNL, Se . S-SN-]3,-S, Att°t~j~,d~l~t~' F14L, 2,620' FNL, Sec. 8-SN-1314-SM Other __ 6 Datum elevabon (DF or KB) 106' KR ~hnve M_~m_ 7 Unit or Properby name Trading Bay Unit 8 Well number D- 12RD 9. Permit number/approval number 9-443 10 APl number 50--733-20142-01 1,1 Flqld/Ppol Heml OCK 12 Present well cond~bon summary Total depth measured true verbcal 12,050' feet Plugs (measured) ] 0, ] 88' feet 11,904' - 12,050' CRT Effecbve depth' measured true vertical 11,894 ' feet Junk (measured) 10,038' feet 11,894' - 11,904' Pkr Casing Length Structural Conductor Surface Intermediate 9,365' Production Lmer 2,894' Perforabon depth measured true vertmcal Size Cemented Measured depth True vertical depth 9-5/8" 2,326 SX 9,365' 7,727' 7" 850 sx 12,031' 10,168' See Attachment #1 Tubing (size. grade, and measured depth) 3 1/2", 9.2# N-80 Tbg. to 11,070' MD Pa~_k~r~rAd ~),~S~Vs(tY~,aol~r~s~e~S~p~) 310', Otis WD Pkr @ 11,014' 13. Stlmulabon or cement squeeze summary Intervals treated (measured) Treatment descnpbon ~ncludlng volumes used and final pressure 14. Pnor to well operation Subsequent to operabon Representabve Dady Average Production or Injecbon Data Od-Bbl Gas-Md Water-Bbl Casing Pressure 11/30/89 664 204 720 1140 12/14/89 307 118 510 1200 Tubing Pressure 130 100 15 Attachments 2 Copies of Logs and Surveys run __ Dally Report of Well Operations _.~ 16 Status of mil classlflcabon as. Oii ~ Gas_ Suspended Service 17. I hereby cert. b~/that the foregoing is true and correct to the best of my knowledge. //' , S,gned L//;,/.~.~-~'(L_./~'~'~"~'~1 TitleEnvironmental Analyst o6/15/88~ .or O-.0 .ev feet Date 1/12/90 SUBMIT IN DUPLICATE Bench 0 Bench 1 Bench 2 Bench 3 Bench 4 Bench 5 Attachment #1 TBU D-12RD Perforations (MD) 11,190' - 11,200' 11,225' - 11,240' 11,250' - 11,268' 11,350' - 11,360' 11,412' - 11,432' 11,440' - 11,470' 11,496' - 11,516' 11,530' - 11,580' 11,600' - 11,630' 11,690' - 11,715' (TVD) 9,379' - 9,388' 9,415' - 9,429' 9,434' - 9,451' 9,526' - 9,536' 9,588' - 9,607' 9,610' - 9,637' 9,662' - 9,680' 9,693' - 9,744' 9,762' - 9,790' 9,843' - 9,867' docs\dvp\D12RD, doc Attachment #2 Daily Summary of Operations TBU Well D-12RD 11/27/89 RU E-lin~. Pressure test 2500 psi, OK MU 30', 2-1/8" TRC strip guns, 4 SPF,u phasing, 20.7 gm charges. Si well. RIH. Flow well, correlate to DIL. Tag fill at 11,651' DIL. PU and perforate 11,600' - 11,630' (30' B-5 , new interval). Flow well for 10 min. POH. MU 30' guns as above. RIH out tubing tail. Flow well, correlate and perforate 11,550' - 11,580' (30' B-4). Flow well for 10 min. SI. POH. RD. 11/28/89 RU E-lins. MU 10' gun on top and 20' gun on bottom. 2-1/8" JRC strip gun, 4 SPF,0 phasing, 20.7 gm charges. RIH, correlate to DIL. Perforate 11,496' - 11,511' (20' B-4). PU, correlate and perforate 11,350' - 11,360' (10' B-3) (gun did not fire). Flow well for 10 min. POH. TOP gun fired, bottom gun failed. MU 20' gun as above, flow well, correlate, and perforate 11,412' - 11,432' (20' B-3). Flow well 10 min. SI. POH. All shots fired. MU 15' gun, top and 10' gun, bottom. RIH out tubing tail. Flow well. Correlate and perforate 11,350' - 11,360' (10' B-3). PU, correlate and perforate 11,225' - 11,240' (15' B-l). Flow well 10 min. SI. POH. All shots fired. RD. \docs\dvp~D12RD. doc ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 0 ~ APPLIC, ATION FOR SUNDRY APPROVALS IGIN A 1 Type of Request Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casmg __ Repair well __ PluggIng __ T~me extension __ Sbmulate __ Change approved program __ Pull tubing __ Vanance __ Perforate X Other __ 2 Name of Operator ! 5 Type of Well 6 Datum elevabon (DF or KB) UNOCAL (Marathon Oil Company - Sub (~perato~Cn[~.°Pm.ent x-~- 106' KB above MSL r 'exploratory __ 3 Address | Strabgraph~c __ 7 Unit or Property name P.O. Box 190247 Anchorage, AK 99519~ Serv,ce__ Trarl'inn Ray lin'it 4 Locatlon of well at sudace Leg B-l, Cond. #10 Dolly Varden Platform 678' FSL, 1,217' FWL, Sec. 6-8N-13W-SM At top of productive ~nterval 1,251' FWL, 2,526' FNL, Sec. 8-8N-13W-SM At effecbve depth 1,131' FWL, 2,418' FNL, Sec. 8-8N-13W-SM At total depth 1,165' FWL, 2,620' FNL, Sec. 8-8N-13W-SM 8 Well n~mbe~' D-12RD 9 Permit number 80-02 10 APl number 5o7-33-20142-01 11 Field/Pool Hemlock feet 12 Present well condition summary Total depth' measured true verbcal Effective depth measured true vertical Casing Length Structural Conductor Sudace Intermediate Producbon 9,365 ' Liner 2,894' Perforabon depth measured true vertical 12,050 ' feet Plugs (measured) 1 O, 188' feet 11,894 ' feet Junk (measured) 10,038 ' feet 11,904' - 12,050' CMT 11,894' - 11,904' Pkr Tubing (s~ze, grade, and measured depth) S~ze Cemented Measured depth True vertical depth 9-5/8" 2,326 sx 9,365' 7,727' 7" 850 sx 12,031' 10,168' See Attachment #1 3 1/2", 9.2# N-80 Tbg. to 11,070' MD Packers and SSSV (type and measured depth) 3-1/2" Otis DC TRBV SCSSV 0 310'. Otis 13. Attachments 2 & 3 Description summary of proposal ~ WD Pkr 0 '11:014' Deta)led operations program __ RECEIVED OCT 2 Alask~ Oil & Gas Cons,, Commission ,, Anchorage BOP sketch _Z._ 14. Esbmated date for commencing operabon October' 30, 1989 16 If proposal was verbally approved Name of approver Date approved 15. Status of well classlflcabon as: Od ~ Gas __ Suspended __ Service 17. I hereby certify that the forego)ng ~s true and correct to the best of my knowledge ~T~tle Envir'onmental Engineer' S,gned ~.~ ~. ~~~ J~'~' tJ FOR COMMISSION USE ONLY Conditions of approval. Not~fy Commission so representabve may witness Plug mtegnty __ BOP Test __ Locabon clearance __ Mechanical Integnty Test __ Subsequent form required 10- Original Signed By Approved by order of the Commission David W. Johnston Date 10/26/89 lAppr°va' N° Approved C.opy Returne(t Comm,ssloner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Bench 0 Bench 2 Bench 3 Bench 4 Bench 5 Attachment #1 TBU D-12RD Perforations (MD) 11,190' - 11,200' 11,250' - 11,268' 11,350' - 11,360' 11,412' - 11,432' 11,440' - 11,470' 11,496' - 11,516' 11,530' - 11,570' 11,605' - 11,622' 11,690' - 11,715' (TVD) 9,379' - 9,388' 9,434' - 9,451' 9,526' - 9,536' 9,584' - 9,602' 9,610' - 9,637' 9,662' - 9,680' 9,693' - 9,731' 9,764' - 9,780' 9,843' - 9,867' docs\dvp\D12RD, doc Attachment #2 Well D-12RD Procedure · RU E-line, PT to 2500 psig. With well flowing RIH with 2-1/8", 4 SPF, 0° phased expendable carrier guns. Be very careful not to get blown up hole. If necessary, choke back well until on bottom (if still having difficulties shut in well until on bottom). Perforate the following intervals: · BENCH INTERVAL (DIL) FOOTAGE B-1 B-3 B-4 11,225' - 11,240' 11,350' - 11,360' 11,412' - 11,432' 11,496' - 11,516' 11,550' - 11,580' 15' 10' 20' 20' 30' B-5 11,605' - 11,630' 25' POOH. R/D E-line. Place well on production, gradually increasing rate. Monitor well in test for 24 hours after reperf and obtain another test within 3 days. Note: Maximum anticipated SBHP is 3000 psi. docs\dvp\D12RD, doc Attachment #3 ( OLLY VARDEN PL('~TFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) BRICATOR 4,11~-1~'6-'- 5000 ps1 CHISTMAS TREE POSITIVE CHOKE ---- 2' 5000 pal __ 2' 3ooo pal ,- 13 3/8' CASING ( STATE OF ALASKA (' 0 ~'~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations pedormed Operation shutdown __ Sbmulate m Plugging m Pedorate .X- Pull tul~ng m Alter casing t Repair well t 2. Name of Operator ~ 5 Type of Well U~OCAL (Marathon Oil Company - Su~ Opera~Pm.entx t ~- Xl3ora~ory __ 3 Address / Strabgraph~c ~ P.O. Box 190247 Anchorage, AK 99~19 Serv,ce__ 4 Locat~on of well at surface Leg B-l, Cond. #10 Dolly Varden Platform 678' FSL, 1,217' FNL, Sec. 6-8N-13N-SM At top of producbve ~nterval 1,251' FNL, 2,526' FNL, Sec. 8-8N-13W-SN At effective depth 1,131' FNL, 2,418' FNL, Sec. 8-8N-13N-SM At total depth 1,165' FWL, 2,620' FNL, Sec. 8-8N-13W-SM 12. Present well condition summary Total depth measured true vertical 12,050' feet 10,188' feet Plugs (measured) Other 6. Datum elevabon (DF or KB) 106' KB above MSL feet 7 Un~tor Property name Trading R~y Ilni'l' 8 Well number D-12RD 9. Permit number/approval number 8-648 10 APl number 5o- 733-20142-01 11 Reid/Pool Hem] ock 11,904' - 12,050' CMT Effective depth measured 11,894 ' feet true vertical 10,038 ' feet Casing Length S~ze Structural Conductor Surface Intermediate Production 9,365 ' 9-5/8" L~ner 2.894' 7" Perforabon depth measured' Junk (measured) Cemented 11,894' Measured depth - 11,904' Pkr True vertical depth 2,326 sx 9,365' 7,727' 850 sx 12,031' 10,168' true vertical See Attachment #1 Tub, ng (size, grade, and measured depth) RECEIVE 3 1/2", 9.2# N-80 Tbg. to 11,070' MD Packers and SSSV (type and measured depth) 3-1/2" Otis DC TRBV SCSSV @ 310', Otis WD Pkr @ 11,014' /~o~? ~2~.~,~ 13. Stimulation or cement squeeze summary ~-~aska Oil & ~as Co~. Comrni~iort I ntervalstreated (measured) ' ~ ' ~Chorage Treatment descnption ~nclud~ng volumes used and final pressure 14. Representative Daily Average Produ~on or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2/17/89 Subsequent to operation 2/2 8/89 15 Attachments~ #2 Cop~es of Logs and Surveys run ~ Daily Report of Well Operations ~ 521 121 362 1090 110 808 192 454 1125 110 16 Status of well classification as Oil x_._ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-40/4 I~ev 06/15188 Date04/06/89 SUBMIT IN DUPLICATE Attachment #2 Daily Summary of Operations TBU Well D-12RD 2/19/89 RU wireline and PT lubricator to 2500 psi, OK. RIH w/ 2.70" gauge ring and tag fill @ 11,652' WLM. POOH and RD WL. 2121/89 RU E-line and PT to 2500 psi, OK. MU 17' of 2-1/8" Enerjet, 4 SPF, 0° phase perforating guns. RU MWP pressure/temperature gauge above perforating guns. RIH and made pass w/MWP gauges, tag TD @ 11,662' DIL. Correlate and perforate B-5 11,605' - 11,622' DIL. Observe FBH temp. POOH and RD. Flow well. em/54A/DVP Bench 0 Bench 2 Bench 3 Bench 4 Bench 5 Attachment #1 TBU D-12RD Perforations (MD) 11,190' - 11,200' 11,250' - 11,268' 11,350' - 11,360' 11,412' - 11,432' 11,440' - 11,470' 11,496' - 11,516' 11,530' - 11,570' 11,605' - 11,622' 11,690' - 11,715' (TVD) 9,379' - 9,388' 9,434' - 9,451' 9,526' - 9,536' 9,584' - 9,602' 9,610' - 9,637' 9,662' - 9,680' 9,693' - 9,731' 9,764' - 9,780' 9,843' - 9,867' NEF/em/54A/DVP S~ STATE OF ALASKA ~ ALA A OIL AND GAS CONSERVATION COM ,,SSlON APPLICATION FOR SUNDRY APPROVALS 1 Type of Request' Abandon Suspend Operation Shutdown - Re-enter suspended well -- Alter casing 5' Time extension Change approved program Plugging ; Shmulate .' Pull tubing Amend order r Perforate _~ Other 2 Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3 Address P.O. Box 190247 Anchorage, AK 99519 4 Locahon ofwellatsurfaC[eg B-l, Cond. #10 Dolly Varden Platfo~ 678' FSL, 1,217' FWL, Sec. 6-8N-13W-SM Attop of product~ve~nte~al 1,251' FWL, 2,526' FNL, Sec. 8-8N-13W-SM Ateffect~ve depth 1,131' FWL, 2,418' FNL, Sec. 8-8N-13W-SM Attotaldepth 1,165' FWL, 2,620' FNL, Sec. 8-8N-13W-SM 5. Datum elevahon (DF or KB) 106' KB above MSL 6 Unit or Property name Trading Bay Unit 7 Well number D-12RD 8 Permit number 80-02 9. APl number 50-- 733-20142-01 10. Pool Hemlock feet 11 Present well condition summary Total depth measured true verhcal 12,050 ' feet Plugs (measured) 10,188 ' feet 11,904' - 12,050' CMT Effective depth: measured 11,894 ' feet true verhcal 10,038' feet Junk (measured) 11,894' - 11,904' Pkr Casing Length S~ze Cemented Measured depth True Verhcal depth Structural Conductor Surface Intermediate Production 9,365' 9-5/8" 2,326 sx 9,365' 7,727' L,ner s2u,reSa94' 7" 850 sx 12,031' 10,168' Perforation depth: mea true vertical See Attachment #1 Tubing (s~ze, grade and measured depth) 3 1/2", 9.2# N-80 Tbg. to 11,070' MD Packers and SSSV (type and measured depth) 3-1/2" Otis DC TRBV SSSV @ 310', Otis WD Pkr @ 11~014' Anchorage 12 Attachments 2 & 3 Description summary of proposal ~ Detailed operahons program C; RECEIVED A'J3 2 ]S 88 0ii & Css Cons. Cornmiss:o~ BOP sketch 13. Estimated date for commencing operation September 1988 14 If proposal was verbally approved Name of approver Date approved 15 I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~::~f~ z.,,~,/~.iZ'~ Title Environmenta 1 Engineer Rdy~. Rdberts Commission Use Only CondItions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity [] BOP Test [] Location clearancel Approved Copy Returneo~..~ ORIGINAL SIGNED BY ~ '~ -~- Approved by Date 8/23/88 LONNIE C, SMITH Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit ~n triplicate Bench 0 Bench 2 Bench 3 Bench 4 Bench 5 Attachment #1 TBU D-12RD Perforations (~) 11,190' - 11,200' 11,250' - 11,268' 11,350' - 11,360' 11,412' - 11,432' 11,440' - 11,470' 11,496' - 11,516' 11,530' - 11,570' 11,690' - 11,715' (TVD) 9,379' - 9,388' 9,434' - 9,451' 9,526' - 9,536' 9,584' - 9,602' 9,610' - 9,637' 9,662' - 9,680' 9,693' - 9,731' 9,843' - 9,867' NEF / em/54A/DVP Attachment #2 D-12RD Procedure 1. RU wireline unit. PT to 2500 psi. 2. RIH with 2.70" gauge ring and tag bottom. 3. POH. RD wireline. 4. RU E-line. PT to 2500 psi. 5. Perforate the following intervals with 2-1/8" strip, or 2-5/8" hollow carrier guns, 4 SPF, underbalanced: Run Interval (DIL) Feet Zone 1 11,605' - 11,622' 17 Bench 5 Test well for 12 hours after stabilized. Continue perforating if oil production is less than 750 BOPD. 2 11,550' - 11,580' 30 3 11,496' - 11,516' 20 4 11,412' - 11,432' 20 5 11,350' - 11,360' 10 Bench 4 Bench 4 Bench 3 (B) Bench 3 (A) 6. POH and RD E-line. 7. Bring well on slowly over 24 hour period. Note: Maximum anticipated bottomhole pressure is 3000 psi. em/54A/DVP Attachment #3 I~.)LLY VARDEN PL/('. FORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) LUBRICATOR -- POSITIVE CHOKE 3 1/8' 5000 psi CHISTMAS TREE 2' 3000 psi 13 3/8' CASING S( STATE OF ALASKA ~ ALA ., OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1 Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ,~ Pull tubing [] Alter Casing [] Other [] Notice of Cancellation for Proposed Workover 2 Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3 Address P.O. Box 190247 Anchorage, AK 99519 4 Location of wellatsurfaceLeg B-l, Cond. ~10 Dolly Varden Platfo 678' FSL, 1,217' ~Tt,, Sec. 6-8N-13W-SM Attop of produchveinterval 1,251' ~WT`, 2,526' ~'3~, Sec. 8-8N-13W-SM Ateffective depth 1,131' FWL, 2,418' FNL, Sec. 8-8N-13W-SM Attotaldepth 1,165' FWL, 2,620' FNL, Sec. 8-8N-13W-SM 5 Datum elevabon (DF or KB) 106 ' KB above MST, 6 Unit or Property name Tr~R_~ R~y Tl.r,-ft- ...m7. Well number D-12RD 8 Approval number 7-831 9 APl number 50-- 733-20142-01 10. Pool Hemlock 11 Present well cond~hon summary Total depth: measured true vertical Effechve depth measured true vertical 12,050' feet Plugs (measured) 10,188' feet 11,894' feet Junk (measured) 10,038 ' feet Casing Length S~ze Structural Conductor Surface Intermediate Production 9,365 ' 9-5/8" Liner 2,894' 7" Perforation depth measured true verhcal 11,904' - 12,050' CMT 11,894' - 11,904' Pkr Cemented Measured depth Feet 2,326 sx 850 sx 9,365' 12,031' True Verhcal depth See Attachment #1 Tubing(s~ze, grade and measured depth) 3 1/2", 9.2# N-80 Tbg. to 11,070' MD Packers and SSSV(type and measured depth) 3-1/2" Otis DC TRBV SSSV @ 310', Otis WD Pkr @ 11,014' 12. Shmulation or cement squeeze summary Intervals treated (measured) Treatment descriphon ~nclud~ng volumes used and final pressure 13 Prior to well operahon Subsequent to operahon Representative Daily Average Produchon or Injechon Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Da~ly Report of Well Operahons [] Copies of Logs and Surveys Run [] 15 I hereby cerhfy that the foregoing is true and correct to the best of my knowledge ~ 7,727' 10,168' Form 10-404 Re~. 12-~-85 ' /"' -' (~ Tttle Environmental Engineer Date 2/17/88 Submit ~n Duplicate ~ Bench 0 Bench 2 Bench 3 Bench 4 Bench 5 Attachment #1 TBU D-12RD Perforations 11,190' - 11,200' 11,250' - 11,268' 11,350' - 11,360' 11,412' - 11,432' 11,440' - 11,470' 11,496' - 11,516' 11,530' - 11,570' 11,690' - 11,715' (TVD) 9,379' - 9,388' 9,434' - 9,451' 9,526' - 9,536' 9,584' - 9,602' 9,610' - 9,637' 9,662' - 9,680' 9,693' - 9,731' 9,843' - 9,867' NEF/em/54/Sundr3 "~ STATE OF ALASKA O~ A ,...,,~ OIL AND GAS CONSERVATION C ,,,,. SION OCT 2 0 1987 APPLICATION FOR SUNDRY APPROVALS. w, ocrwoor 1 Type of Request. Abandon [] Suspend [] Operahon Shutdown [] Re-enter suspended well [] Alter casing [] T~me extension r~ Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name ~f Operator UNOCAL 3 Address P.O. Box 190247 z~mchorage, AK 99519 4 Location of well at surfaceLeg B-l, Cond. #10 Dolly Varden Platfor 678' FSL, 1,217' FWL, Sec. 6-SN-13W-SM At top of productive ~nterval 1,251' FWL, 2,526' FNL, Sec. 8-8N-13W-SM At effective depth 1,131' FWL, 2,418' FNL, Sec. 8-8N-13W-SM At total depth 1,165' FWL, 2,620' FNL, Sec. 8-8N-13W-SM 5. Datum elevation (DF or KB) 106 ' KB above MSL 6. Umt or Property name Trading Bay Unit m 7 Well number D-12RD 8. Permit number 80-02 9. APl number 50-- 733-20142-01 10. Pool Hemlock 12,050' feet Plugs(measured) 11,904' - 12,050' CMT 10,188 ' feet feet 11. Present well cond~hon summary Total depth measured true verhcal Effechve depth measured 11,894' feet Junk (measured) 11,894' - 11,904' Pkr true verhcal 10,038' feet Casing Length S~ze Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate 9,365' 9-5/8" 2,326 sx 9,365' 7,727' Produchon L~ner 2,894' 7" 850 sx 12,031' 10,168' Perforation depth measured See Attachment #1 RECEIVED true vertical OCT 2 2 1537 Alaska Oil a Gas Cons. Commission Anchorage Tubing(size, grade and measured depth) 3 1/2", 9.2# N-80 Tbg. to 11,070' ND Packers and SSSV(type and measured depth) 3-1/2" Otis DC TRBV SSSV @ 310', Otis WD ?kr @ 11,014' 12Attachments#2 & 3 Description summary ofproposal [] Detailed operations program [] BOP sketch ~ Attachment #4 13. Estimated date forcommencing operahon October 1987 Date approved 14 If proposal was verbally approved Name of approver 15 I hereby,.,cerhfy that the f..orego~ng is true and correct to the best of my knowledge Signed ~,~t~~~.~~ ,d.~r.( Title ]~_v-i:ro~~ Specialist ~~Dod Commission Use Only Conditions of approval Notify commission %o representative may w~tness [] Plug integrity ,~ BOP Test [] Location clearance * Marathon Oil Company - Sub Operator Commissioner Date 10/22/R7 I Approval No..~ -- ~./ by order of the commission Date Approved by ~ ~;~;';'~"[ '~ Form 10-403 Rev 1~8~~j~i[ ~ '~"" Submit ~n triplicate-, Bench 0 Bench 2 Bench 3 Bench 4 Bench 5 Attachment #1 TBU D-12RD Perforations (M~) 11,190' - 11,200' 11,250' - 11,268' 11,350' - 11,360' 11,412' - 11,432' 11,440' - 11,470' 11,496' - 11,516' 11,530' - 11,570' 11,690' - 11,715' (TVD) 9,379' - 9,388' 9,434' - 9,451' 9,526' - 9,536' 9,584' - 9,602' 9,610' - 9,637' 9,662' - 9,680' 9,693' - 9,731' 9,843' - 9,867' NEF/em/54/Sundr3 Attachment #2 Well D-12RD Procedure 1. RU & skid rig over Cond. #10, Leg B-1 2. Kill well w/3% KC1 fluid. 3. Set BPV. ND X-mas tree. NU and test BOPE. 4. Pull w/3-1/2" completion string. 5. RIH w/PRT assembly and retrieve perm pkr @ 11,014'. POH. 6. RIH w/bit and 9-5/8" casing scraper to TOL @ 9,136'. 7. Circ hole clean. POH. 8. RIH w/ bit and 7" csg scraper. CO to junk pkr @ 11,894'. 9. Circ hole clean. POH. 10. RU WL & run csg inspection log. 11. Pressure test casing & liner lap. 12. RIH w/TCP guns & reperf Hemlock underbalanced. POH. 13. RIH w/ perm pkr on DP. Set @ ±11,050' DPM. Pressure test to 2000 psi. POH. 14. RIH w/3-1/2" completion string. 15. Land completion. Set BPV. ND BOPE. 16. NU X-Mas tree & test to 5000 psi. 17. Turn well over to production. Note: Anticipated maximum bottomhole pressure is 3,050 psi. Completion fluid will be FIW sufficiently weighted to keep the well overbalanced. PEM/em/527/0E24 conductor et 409' 13-3/8" casing at 2538' 7" liner Top at 9136~ 9-5/8" casing at 9365' 3-1/2", 9.2#, N-80, tbg DIL MEASUREHENT$ Otis ND pkr !1,014~ Perforations: D~L Bench 0 - 11,190~-11,200~ Bench ~- 11,258~-11,268' ~nch 3 - 11,350'-11o360~ 11~412~-11,432~ Bench 4 - 11,440~-11,470~ 11,496~-11,516' 11,~30~-11~570~ 8erich 5 - 11,690~-11~715~ · ~unked pkr at 11.894' T~V ~ELL D-~iRD Completion Schematic 10-08-80 CIW Type F tbg hgr - 4-1/2" ASL x 4-1/2" ASL 310 3-1/2" Oils 0C TRBV ID 2.75" 2,477 GLH #l-Merle TPD w/ CM2-RC valve w/ RA latch ID=2.875 4,132 GIN #2-Nerla TPDw/ CM2-RC valve w/ RA latch ID=2.875 5,452 GLH #3-Merle TPD w/ ~42-RD valve w/ RA latch ID=2.875 6,617 GU4 #4-Merle TPD w/ CM2-RD valve w/ RA latch IO=2.875 7,575 GLM #5-Merle TPD w/ CMi-RO valve w/ RA latch ID-2.875 8,441 GIN #6-Merle TPD w/ CN2-RD valve w/ iRA latch 10-2.875 9,099 GLN #7-Merle TPD w/ CM2-RD valve w/ RA latch ID-2.875 9,635 GIN #8-Camco KBUG w/ CNI-BK-PB valve w/ BK latch ID=2.875 10,019 GIN #9-Camco KBUG w/ Ct41-BK-PB valve w/ BK latch ID=2.875 10,538 GIN #lO-Camco KBUG w/ CMI-BK-PB valve w/ BK latch IB=2.875 10,629 GIN #11-Camco KBU$ w/ CHI-BK-PB valve w/ BK latch ID=2.87§ 10,923 GIN #12 22/64 orifice valve 10,970 Otis XA sleeve ID=2.7§" 11,015 Otls Iocator & seal assembly li,038 Oils X-nipple I D=2,75,, 11,070 ~ls 1/2 cut mule shoe o Fill {Ir~'1,851~ OIL on 06-24-82 06-24-82 TBU Well D-12RD Proposed Completion Schematic Tbs. Hanger SSSV 2.538' 13-3/8" C$$. 9,136' 7" Liner Top 9,365' 9-5/8" Cs8. 3-1/2" Tub/ns Completion String 11,050' Permanent Packer Perforations (DIL~ Bench 0 11,190' - 11,200' Bench 2 11,250' - 11,268' Bench 3 11,350' - 11,360' 11,412' - 11,432' Bench 4 Il,&40' - 11,470' 11,496' - 11,516' 11,530' - 11,$70' Bench S 11,690' - 11,715' 11,851' - Fill TaBged on 6/24/8[ 11,894' - Junked Packer 11,904' PBTD 12,031' 7" Liner '- MARATHON OIL GO.- -- DOLLY VARDEN PLATFORM -- ~",, 5,000'~- Kill Line. Attachment f/4 TBU Well D-12RD (Pipe R~ms) --Mo~ Pon C1~ (.o nnec-,ow _ Choke Linc- ~xS,000 DHIi Deck Floor / Riser ~_ BOP St~ck For D]-illin,~' From Uhder Sur{~ce C~sin$ To TI:).-- n ~¢!1 Room Floor,, CI~/ Swin:~-6oll' Clamp Connectors 2 Ff. Spool 12",,. 3,000~ C~sing I-i~c~d w/Flgn~t~d Outl~s ~ V~lvcs C, onduc-t'or STATE Of ALASKA C~ ALASKA OIL AND GAS CONSERVATION ,,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER 1 DRILLING WELL [] 2 Name of Operator Union Oil Company of California * COMPLETED WE LIZ:~ RECEIVED 3 Address P. 0. Box 6247, Anchorage AK 99502 JUL I 21982 4 Location of Well Sur face: Alaska Oil & Gas Cons. Leg B-l, Cond. ~)10, Dolly Varden Platform Anchorage Commission 678' FSL, 1217' MI'., Sec. 6-SN-13W-SM 5 Elevation in feet (~ndlcate KB, DF, etc ) 106.2' KB Above MSL 12 6 Lease Demgnat~on and Serial No ADL-O]872q 7 Permit No 80-02 8 APl Number 50-733-20142-01 9 UnIt or Lease Name Trading Bay Unit 10 Well Number D- 12RD 11 Fmld and Pool H~,Arrh,l~- R;ver Fiel_d Check Approprmte Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit in Tmpl~cate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Descmbe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~ncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) On June 23, 1982, Well D-1 under drawdown in the foll D-12RD Reper forat ion 2RD was perforated with a 2.6" Slimkome gun, 4HPF, 0° phasing, owing intervals: Bench 0 11,190' - 11,200' DIL Bench 2 11,258' - 11,268' DIL Bench 3 11,350' - 11,360' DIL 11,412' - 11,432' DIL On June 24, 1982, the well was reperforated with a 2.6" Slimkome gun, 4HPF, 180° phasing, under drawdown in the following intervals: Bench 4 11,440' - 11,470' DIL 11,496' - 11,516' DIL 11,530' - 11,550' DIL Production before reperforating: Production after reperforating: 738 BFPD, 51% WC, 362 BOPD, 376 BWPD, 6/17/82. 1776 BFPD, 40% WC, 1066 BOPD, 710 BWPD, 6/24/82. 14 I hereby c~t~fy that the foregoing ~s true and correct to the best of my knowledge S,gned ~ T~tle The space below for Commission use Conditions of Approval, ~f any Date By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n TriplIcate and "Subsequent Reports" ~n Duplmate STATE OF ALASKA ~ r ALASKA OIL'/~ND GAS CONSERVATION C ,,M~sSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL [~ OTHER [] 2 Name of Operator 7 Permit No UNION OIL COMPANY OF CALIFORNIA* 80-82 3 Address 8 APl Number P. O. Box 6247, Anchorage, AK 99502 5o-733-20142-01 4 Location of Well Surface- Leg B-l, Cond #10, Dolly Varden Platform 678' FSL, 1217' FWL, Sec 6-8N-13W-SM 5 Elevation ~n feet (~nd~cate KB, DF, etc ) 106.2' KB above MSL Lease Designation and Serial No ADL 018729 12 9 Umt or Lease Name Trading Bay Unit 10 Well Number D-12 RD 11 F,eld and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Triplicate) (Submit ~n Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [~ Abandon [] St~mulaBon [] Abandonment [] Repmr Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent details and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) It is OUroi guns at 0 Bench 0 1 BenCh 2 11,258 Bench 3 11,350 11,412 Bench 4 11,440 11,496 11,530 D-12 RD REPERFORATE HEMLOCK INTERVALS ntent to perforate and reperforate the well with 2 5/8" Sl imkone perforating phasing, 4 HPF, under drawdown conditions, as follows- 1,190 - 11,200 DIL -11 -11 -11 -11 -11 -11 ,268 DI ,360 DI ,432 DI ,470 DI ,516 DI ,550 -DI This work is scheduled for May, 1982. Subsequent Work Reported RECEIVED * Marathon Oil Company - Sub-Operator Alaska 0il & Gas Cons. Commission Anchorage 14 I hereby certify that~f~ f~lng Is true and correct to the best of my knowledge S~gned ~-. ~' __ Title District Engineer The space below for Commission use C. H. Case Conditions of Approval, ~f any Approved Copy Returned Date May 5, 1982 BY LilI~I~IE C. $~111t B¥Orderof Approved by. COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~r~ Triplicate and "Subsequent Reports" ~n Duplicate STATE OF ALASKA ALASK~ ,IL AND GAS CONSERVATION (~ vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL~ OTHER [] 2 Name of Operator 7 PermltNo Union Oil Company of California** 80-82 3 Address 8 APl Number P. O. Box 6247, Anchorage AK 99502 50-733-20142-01 4 Location of Well Surface: Leg B-I, Cond #10, Dolly Varden Platform 678' FSL, 1217' FWL, Sec 6-8N-13W-SM 5 Elevation in feet (indicate KB, DF, etc ) ]06.2' KB above MSL 6 Lease Designation and Semal No ADL 018729 9 Umt or Lease Name Trading Bay Unit 10 Well Number D-12RD 11 F~eld and Pool McArthur River Hemlock 12 Check Appropmate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Tmphcate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations ~1 Altering Camng [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Descmbe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) On 11/19/81 the well was reperforated under drawdown with 2.6" enerjet, 4 HPF, at the following intervals: Bench 4: 11,530' - 11,550' DIL 11,496' - 11,516' DIL 11,440' - 11,470' DIL Bench 5 interval was not reperforated at this time. Production before reperf: 553 BFPD, 70% WC, 166 BOPD, 387 BWPD Production after reperf: 1014 BFPD, 70% WC, 304 BOPD, 710 BWPD **Marathon Oil Company - Sub-Operator RECEIVED DECO 9 198! Al~ka Oil & Gas Cons. Commission Anchorage 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,§ned ~/~/~- //~~Z~~~- T,tle D~ST DRLG SUPT The spac/e below for C(~mm,s"~s,~n Date 12/9/81 Conditions of Approval, ~f any By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n TriplIcate and "Subsequent Reports" ~n Duplmate AL STATE OF ALASKA ~ ALASK IL AND GAS CONSERVATION C ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WE LLX~] OTHER [] 2 Name of Operator 7 PermIt No Union Oil Company of California** 80-82 3 Address 8 APl Number P. 0. Box 6247, Anchorage AK 99502 50-733-20142-01 4 Location of Well Surface: Leg B-I, Cond #10, Dolly Varden Platform 678' FSL, 1217' FWL, Sec 6-8N-13W-SM 5 Elevation ~n feet 0nd~cate KB, DF, etc ) 106.2' KB above MSL 6 Lease Demgnat~on and Semal No ADL 018729 9 Unit or Lease Name Trading Bay Unit 10 Well Number D-12RD 11 F~eld and Pool McArthur River Hemlock 12 (Submit ~n Triplicate) Perforate [] Alter Casing [] Perforations SBmulate [] Abandon [] St~mulat,on Repmr Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) Check Approprmte Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ,n Duplicate) [] Altering Casing [] Abandonment [] Other 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~ncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) We are requesting approval to reperforate the well w/ 2-1/8" enerjet gun w/ 0° phasing, under drawdown conditions at the following intervals: Bench 4: 11,530' - 11,550' DIL 11,496' - 11,516' DIL 11,440' - 11,470' DIL *Bench 5: 11,690' - 11,715' DIL Verbal approval received from Jim Trimble to W. J. Laverdure 11/6/81 Subsequent Work Ptc2c:tcd on Form No..4~ ~-- Dated tZ__./~_~/~1 *Dependiag on Bench 4 well test. **Marathon Oil Company - Sub-Operator RECEIVED NOV ? O 198~ 14 I hereby certify that the foregoing is true and correct to the best of my knowledge S,,ned £ .,e 7 ..... ! The space below for Commms~on use Alaska 0il & Gas Cons. Commission Anchorage Date 11~9/81 Cond~Bons of Approval, if any gY L~',hl[C. SiIAITlt Approved by COMMISSIONER , Approved "opy Returned 8¥ Order of the Commms~on Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duplicate STATE OF ALASKA A A K OIL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WE L I.X~ OTHER [] 2 Name of Operator 7 Permit No Union 0il Company of California* 80-82 3 Address 8 APl Number P, O, Box 6247, Anchoraqe AK 99502 s0-733-20142-01 9 Umt or Lease Name 4 Location of Well Surface: Leg B-I, Cond #10, Dolly Varden Platform 678' FSL, 1217' FWL, Sec 6-8N-13W-SH 5 Elevation ~n feet (~nd~cate KB, DF, etc ) _ 106.2' KB ahov~ M.ql 12 Lease Designation and Serial No ADL 0! R729 Tradin~ Bav Unit 10 Well Number D- 12RD 11 F~eld and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Tnphcate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations [] Altenng Casing [] Stimulate [] Abandon [] Sumulat~on [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~ Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each compleuon ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent details and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) We are requesting approval to treat the well with a 60:40 Solvent-Turflo mixture treatment. Estimated start up: 10/19/81 A description of proposed procedures is attached. Verbal approval received from Jim Trimble to Bill Laverdure on 10/16/81. *Marathon Oil Company - Sub-Operator OCT ? ahska Oil & 6as C~ns. 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge Signed ~ Title DIST DRLG SUPT The spa~e below for Cc~mmlsslon use Date 10/20/81 Conditions of Approval, If any ItRIgl~[ Approved by BY tl]~NgI[ I]. S~ITH COMMISSIONER By Order of the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" ~n Duplicate Procedure for Treating Well D-12RD with Turflo ® ® · · 0 ® · · Mix 5856 gal Dowel l P-20 solvent, 1464 gal Dowel I U66 mutual solvent, 73 gal Dowell W52 non-emulsifying agent. Mix 3960 gal water and 1320 gal Turflo acid in 500 bbl tank. Mix and filter Turflo/solvent through 5 micron filter. RU and pressure test lines to 4500 psi. RU to record annulus pressure. Fill the tubing with P-20 solvent, record volume. Pump 147 bbls Turflo/solvent (less tubing volume) at 2300 psi or 2 BPM max i mum · Pump 315 lb Benzoic Acid flake-diverter at 2 ppg concentrate (157.5 gal Turflo/solvent) at 2300 psi or 2 BPM maximum. Pump 151 bbls Turflo/solvent at 2300 psi or 2 BPM maximum. Displace with 112 bbl diesel at 2300 psi or 2 BPM maximum. I0. Shut in well for 4 hours, RD pumping equipment. II. Return well to production. !,tE£EiVED .~-,'~:k~ Oil & G3:) Cons, STATE OF ALASKA ALASKa' ~L AND GAS CONSERVATION C-~ .vIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WE L L:~ OTHER [] 2 Name of Operator Union Oil Company of California* 3 Address P. O. Box 6247, Anchorage AK 99502 4 Location of Well Surface: Leg B-2, Cond #10, Dolly Varden Platform 678' FSL, 1217' FWL, Sec 6-8N-13W-SM 5 Elevation ~n feet (~ndlcate KB, DF, etc ) MSL 6 Lease Designation and Semal No ADL 018729 7 Permit No 80--82 8 APl Number 50-- 733--20142-01 9 Umt or Lease Name Trading Bay Unit 10 Well Number D-12RD 11 F~eld and Pool McArthur River Field 12 Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ,n Tr~phcate) (Submit ~n Duplicate) Perforate [] Alter Casmg [] Perforations ~ Altermg Casing [] Stimulate [] Abandon [] Stimulation ~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubmg [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Descmbe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) On 8/20 - 8/22/81 the well was reperfd under drawdown, w/ 2-1/8" enerjet at 0° phasing, 4 HPF at the following intervals: Bench 5: 11,690' - 11,715' Bench 4: 11,530' - 11,560' 11,496' - 11,516' 11,440' - 11,470' The 1. 2. 3. 4. 5. 6. 7. 8. well was then stimulated as follows: RU Turflo equip, press tst to 4500 psi. Blend 3150 gal Turflo acid w/ 9450 gal 3% KCL. Filter Turflo thru 5 micron filter. Add J237 diverter & blend. Pumped 133 bbls Turflo, 2 BPM max. SD & RD Turflo equip. Press 1700 psi, no flow. Well open, produced thick emulsion & died before treatment fully unl~~V[ D (CONTINUED ON NEXT PAGE) *Marathon Oil Company - Sub-Operator. 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge OCT 2 }~l~ska Oil & Gas Cons, C0mmissi, The s~'ace below for Commmmon use Conditions of Approval, ~f any T~tle DIST DRLG SUPT Date 10/20/81 Approved by By Order of COMMISSIONER the Commms~on Date Form 10-403 Rev 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" ~n Duplicate Sundry Notice Well D-12RD Page 2 Prod before reperf & stimulation: 730 BFPD, 38% BS&W, 453 BOPD. Prod after reperf & stimulation: 73 BFPD, 59% BS&W, 30 BOPD. A~.chorag9 ALASKA('_,~L AND GAS CONSERVATION C( ~MI~SI~''''j /~Z,~,~,,,,,~ / , SUNDRY NOTICES AND REPORTS / 1 DRILLING WELL[] COMPLETED WELL~ OTHER [] 2 Name of Operator Union Oil Company of California* 3 Address ?.0. Bo× 6247, Anchorage, AK 99502 4 Location of Well Dolly Varden Platform, Leg B-i, Conductor #10 678' FSL, 1217' FWL, Sec 6, T8N, Ri3W, SM 5 Elevation ~n feet (indicate KB. DF. etc ) 106.2' KB above MSL 12 6 Lease Designation and Serial No ADL-018729 7 Permit No 80-82 8 APl Number 50- 733-20142-0l 9 Unit or Lease Name Trading Bay Unit 10 Well Number D-12RD 11 F~eld and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit in Triplicate} (Submit in Duplicate} Perforate ~ Alter Casing [] Perforations [] Altering Casing [] S.mulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note Reportmult~plecomplet~onson Form 10-407w~thasubm~tted Form 10-407 for eachcomplet~on) --1 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates. ~nclud~ng estimated date of starting any proposed work. for Abandonment see 20 AAC 25 105-170) We are requesting approval to reperforate selected intervals in Hemlock Zone Benches 4 & 5, through the tubing, and then treat the well with Turbo Chemical's "Turflo" treatment to stabilize the clays and fines. Estimated start up: 08-19-81 A description of proposed procedures is attached Verbal approval received from Russ Douglas to Tony Swan, 8-17-81. *Marathon Oil Company - Sub-Operator Alaska 0;1 & G~s Cons, Anch0ra~e 14 I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned T,tle DIST DRLG SUPT The spa~/e ~elow for Commission use / -- Cond~t,ons of Approval. if any Approved by __ By O~de~ of COMMISSIONER the Corniness,on Date. 8/1 g/S1 Form 10-403 Rev 7-1-80 S ~bm ! "Intentions" Itl Triplicate and 'Subsequent Reports" in Duplicate Attachment to Sundry Notice Well D-12RD REPERFORATING AND TREATING WELL D-12RD WITH TURFLO . · 5. 0 . . . RU A-frame. MU CCL, 24' of 2-5/8" Slim-kone gun loaded 4 SPF, 0° phasing, with magnetic decentralizer. Attach greasehead and BOPT to lubricator, RU & press test to 2500 psi. SI well & RIH. Locate to perforate 11,440' - 11,447' DIL. Obtain +400 psi drawdown & perforate. Flow well to clean up perfs. SI WELL & POH. Repeat steps 2 thru 4 as above, reperforating the following intervals: Bench 4 11440'-11470' 11496'-11516' 11530'-11560' Bench 5 11690'-11715' RD perforating equipment. Mix 13,425 gals (320 bbls) 3% KCI solution in 500 bbls tank. Add Turflo concentrate & mix. Add J237 diverter and mix. Press up tbg of D-12RD using lift gas. Shut off lift gas & bleed annls. Monitor TP for communication between tbg & csg. Repress annls w/ lift gas. RU Turflo lines to both the tbg & csg of D-12RD. Press test line to 4500 psi. RU to record annls press. !0. Fill tbg w/ Turflo. Note volume required. Pump all fluids thru 5 micron filters going in well. I!. Pump 17,900 gals Turflo (less volume required to fill tbg) at 2500 psi of 2 BPM max. 12. Displ w/ 149 bbls diesel at 2500 psi or 2 BPM max. 13. SI well for 4 hrs. RD Turflo equipment. 14. Return well to production. AUG ? 0 i98 Oil & Gas Cons. Commission ,~chorage o STATE OF ALASKA ([" ALASKA ~LAND GAS CONSERVATION C ,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2 Name of Operator Union Oil Company of California* 3 Address P.O. Box 6247, Anchorage, AK 99502 4 Location of Well Dolly Varden Platform, Leg B-I, Conductor #10 678' FSL, 1217' FWL, Sec 6, T8N, Ri3W, SM 7 Permit No 80-82 8 APl Number 50- 733-20142-01 9 umt or Lease Name Trading Bay Unit 10 Well Number D-12RD 11 F~eld and Pool 5 Elevation ~n feet (~nd~cate KB, DF, etc ) I 6 Lease Des~gnatmn and Semal No 106.2' KB above MSL I ADL-018729 McArthur River Field 12 Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Tr~phcate) (Submit m Duplicate) Perforate ~ Alter Casing [] Perforations [] Altemng Casing Stimulate ~ Abandon [] Stimulation [] Abandonment Repmr Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note Report mulBple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Descmbe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) We are requesting approval to reperforate selected intervals in Hemlock Zone Benches 4 & 5, through the tubing, and then treat the well with Turbo Chemical's "Turflo" treatment to stabilize the clays and fines. Estimated start up: 08-19-81 A description of proposed procedures is attached Verbal approval received from Russ Douglas to Tony Swan, 8-17-81. Subsequent Work Reported on Form No. --_----- Dated __/__/ : *Marathon Oil Company - Sub-Operator RECEIVED AUG 2 o 1981 Alaska 0ii & Gas Cons. C0mmissi0. Anchorage 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned . _ -__ ...- T,tle DIST DRLG SUPT The spa~7e/below for Commission use / " Date 8119181 Conditions of Approval, ~f any Approved by, BY LO[l~,~lE C. SMITH Ret~;m~d J olz/_ By Order of COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duphcate Attachment to Sundry Notice Well D-12RD REPERFORATING AND TREATING WELL D-12RD WITH TURFLO I · · · e · e ® · · RU A-frame. MU CCL, 24' of 2-5/8" Slim-kone gun loaded 4 SPF, 0° phasing, with magnetic decentralizer. Attach greasehead and BOPT to lubricator, RU & press test to 2500 psi. SI well & RIH. Locate to perforate 11,440' - 11,447' DIL. Obtain +400 psi drawdown & perforate. Flow well to clean up perfs. SI WELL & POH. Repeat steps 2 thru 4 as above, reperforating the following intervals: Bench 4 11440'-11470' 11496'-11516' 11530'-11560' Bench 5 11690'-11715' RD perforating equipment. Mix 13,425 gals (320 bbls) 3% KCI solution in 500 bbls tank. Add Turflo concentrate & mix. Add J237 diverter and mix. Press up tbg of D-12RD using lift gas. Shut off lift gas & bleed annls. Monitor TP for communication between tbg & csg. Repress annls w/ lift gas. RU Turflo lines ~ both the tbg &~'csg of D-12RD. Press test line to 4500 psi. RU to record annls press. I0. Fill tbg w/ Turflo. Note volume required· Pump all fluids thru 5 micron filters going in well. II. Pump 17,900 gals Turflo (less volume required to fill tbg) at 2500 psi of 2 BPM max. 12. Displ w/ 149 bbls diesel at 2500 psi or 2 BPM max. 13. SI well for 4 hrs. RD Turflo equipment. 14. Return well to production· s iAi'F, OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY I( )TiCES AND REPORT(' ON WELLS DRILLING WELL [] Name of Operator Union Oil Company of California* Address P. O. Box..6247, Anchorage AK 99502 4. Location of Well COMPLETED WELL Dolly Varden Platform, Leg B-i, Conductor #lO, 678'FSL, 1217'FWL, Sec. 6, T8N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) 106.2' MB Above MgL 12. 7 Permit No. 80-82 8. APl Number 50-733-20142-01 9. Unh or Lease Name Trading Bay Unit 10. Well Number D-12RD OTHER ~ , 11. Field and Pool I6. Lease Designation and Serial No. APL-018729 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data McArthur River Field NOTICE OF INTENTION TO: (._. SUBSEQUENT REPORT OF:j (Submit in Triplicate) ...... Perforate [] Alter Casing [] · Perforations Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well I-') Change Plans [] Repairs Made [] Other Pull Tubing r-~ Other ', D Pulling Tubing 1-] (Note. Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Desc,be Proposed or Completed Operations (Clearly state all pertinent details and g~ve pertinent dates, includ,ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On January 19, 20, & 21, 1981, perforat~ed and reperforated following Hemlock intervals under drawdown: Bench 4: Ferfd: Reperfd: 11,440'-11,470' 11,440'-11,470' 11,496'-11,516' 11,530'-11,560' 4 HPF DA 2.6" Slim Kone 0° Phasing 4 HPF DA 2.6" Slim Kone 90© & 270° Phasing 4 HPF DA 2.6" Slim Kone 0o ~hasing 4 HPF DA 2.6" Slim Kone 0© Phasing Bench 5: Perfd: 11,690'-11,715' 4 HPF · 11,690'-11,715' 4 HPF DA 2.6" S.1im Kone 0° Phasing DA 2.6" Slim Kone 90.© & 270o Phasing Production Test: Before Perfs: 1306 BFPD 20% WC 1045 BOPD After Perfd: 1822 BFPD 19% WC 1476 BOPD Verbal approval received from Russ Douglass on January 15, 1981, to Tony Swan. RECEIVED *Marathon Oil Company - Sub-Operator 14 I hereby?ert,f:~¢~~golng. ,strueand correct to the best of m¥ knowledge. S,c~ned/~/~'P'f,~. '~~f~~~ T,tle Dist. Drlg. Supt. Th~ace below for Commission use FEB I 1 Alaska 0il & Gas Cons. Commission Date 2/10/81 Cond~t,ons of Approval, ~f any By Order of Approved bv COMMISSIONER the Comm~ss,on Date .. Fo~,n 10-403 Re. 7-1-80 ~,,, Submd "Intentions" m TriplIcate and "Subsequent Reports" ~n Duphcate ~ill Van Alen Alaska O&G Cons. Comm. Union Oil Company:__! ~001 Porcupine Drive ~0 Box 6247 · Anchorage, AK 99504 Anchorage, AK 99~02, ~'T,,~ !1 TRANSMITTING THE FOLLOWING 1 / ~anoent~ I , 1 ._ Tangential J, Alaska Oil ECEIV Gas Cons, FORM 1-2M02 (REV 11-72) PRINTED IN U S A Form 10-403 REV°, 1-10-;3 Subml t "1 ntentions" in Triplicate , & "Subsequent Reports" In Duplicate [ STATE O~- ~LASKA 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-J' for such proposals.) O,L ~ GAs I'--1 WELLi---J WELL t--J OTHER 2. NAME OF OPERATOR Onion 0il Co. of California* ADDRESSOFOPERATOR 909 W. Ninth Ave., Anchorage, LOCATION OF WELL At ~ace 735' N & 140' W of SE Corner Sec 17, T9N, R13W, SM ELEVATIONS (Show whether DF, RT, GR, ets) K.B. 100' above MLLW Ak 99502' 5. APl NUMERICAL CODE 50-133-20156-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18777 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradin~ R~y ~n.it WELL NO." K-12Rd (44-18) 10. FIELD AND POOL, OR WILDCAT McArthur River - Hemlodk 11. SE~,T.,R.,M.,(BOTTOMHOLEOBJECTIVE) Sec 18, T9N, R13W, SM 12. PERMIT NO. Check Appropriam Box To Indicate Nature of Notice, Re ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER 5HUT-OFF FRACTURE TREAT SHOOT OR AClDIZE REPA! R WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF= WATER SHUT-OFF [~ REPAIRING WELL FRACTURE TREATMENT H ALTERING CASING · SHOOTING OR ACIDIZING ABANDONMENT* (Other) ~T-qcCaT-~t-~ ~ ~i-.~ Tt~ ~Tt~T'V~i (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED'OPERATIONS (Clearly state all pertinent details, and 9ive pertinent dates, including estimated Gate of starting any proposed work. .The following interval was reperforated on September -- 11072-11175 DIL 23 and ~4: *ARCO Oil & Gas Company, Suboperator 16. I hereby ce~l~y/~'~at the foregoing Is true and correct TITLE DATE 11-06-80 (This space for State office use) APPROVED BY.. , CONDITIONS OF APPROVAL, IF ANY: TITLE, ,, See Instructions On Reverse Side DATE ORIGINAL ALAS ,-;IL AND GAS CONSERVATION '/IISSION WELL COMPLETION OR RECOMPLETION REPORT AND'LOG-- _1 Status of Well Class~hcat,on of Serv,ce Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Perm,t Number Union Oil Company of California* 8082 3 Address 8 APl Number P. O. Box 6247, Anchorage AK 99502 50- 733-20]42-0] 4 Locat,on of well at surface Dolly Varden Platform, Leg B-l, Cond l0 9 Un,t or Lease Name 678'FSL, 1217'FWL, Sec 6-8N-13W-SM Trading Bay Unit At Top Producing Interval 10 Well Number 1251 'FWL, 2526 'FNL, Sec 8-8N-13W-SM D-12RD At Total Depth 11 F~eldandPool 1030'FWL, 2645'FNL, Sec 8-8N-13W-SM 5 Elevat,on ,n feet (,nd,cate KB, DF, etc ) 6 Lease Des,gnat,on and Ser,al No McArthur River Field 106.2'KB above MSL ADLOZ8729 12 Date Spudded 13 DateT D Reached 14 Date Comp,Susp orAband 115 Water Depth, ~f offshore 16 No of Completions 08-21-80 09-18-80 10-05-80I 112 feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Dlrect,onalSurvey I 20 Depth where SSSV set I 21 Thlckness of Permafrost 12,050'; 10,188' 11,905'; 10,040' YES~] NO[]I 310 feetMDI NA 22 Type Electric or Other Logs Run DIL, BHC, FDC/CNL, RFT, Gyro, CBL/CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 7" 29# N-80 9137' 12,031' 8-1/2" 850 sx, Cl G, 2 24 Perforations open to Production (MD+TVD of Top and BOttom and 25 TUBING RECORD interval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) Bench 4--Top: 9662'TVD ll,496'MD 3-1/2" ll/070' ll,O14' Btm: 9681'TVD ll ,516'MD Top: 9694'TVD ll,530'MD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC BTN: 9731 ' TVD ll. 570 'ND DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Used DA 2.6" Jet, 4 HPF, 180° phasing -- , , 27 PRODUCTION TEST Date F~rst Production I Method of Operation (Flowing, gas I~ft, etc ) 10-05-80I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER~BBL CHO.KF_.SJZE IGAS-OILRATIO url rl ce 10-09-80 24 TEST PERIOD ~ 2155 636 10 50 plate 295 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 160 1100 24-HOUR RATE I1~ 2155 6136 10 35° 28 CORE DATA Brief description of I~thology, porosity, fractures, apparent d~ps and presence of o~1, gas or water Submit core ch~ps 2 Form 10-407 Submit in duphcate Rev 7-1-80 CONTINUED ON REVERSE SIDE 29 30 GEOLOGIC MARKERS FORMATION TESTS ,, NAME Include ,nterval tested, pressure data, all fluIds recovered and gravity. MEAS DEPTH TRUEVERT DEPTH GOR. and t~rne of each phase G Zone lO, 346' 8600' Hemlock 11,224' 9410 ' W. Foreland 11,810' 9956' 31 LIST OF ATTACHMENTS Well History, Casing and Tubinq Details 32 I hereby c~.ult,fy that the foregoing rs true and correct to the best of my knolNledge INSTRUCTIONS General' Th~s 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 ~njection, water ~nject~on, steam ~nject~on, a~r injection, salt water d~sposal, water supply for ~njection, observation, injection for in-situ combustion. Item 5' Indicate which elevation ~s used as reference (where not otherwise shown) for depth measurements given ~, other spaces on th~s form and ~n any attachments. Item 16 and 24 If th~s well is completed for separate production from more than one ~nterval (multiple completion), so state in ~tem 16, and ~n item 24 show the producing intervals for only the interval reported ~n item 27 Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such ~nterval. Item 21 Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. ' '. ~, - ,ft, Rod Pump, Hydraulic Pump, Submersible, Water In- Eastman Whipstock A PET~ REPORT of ~UB-$URFACE DIRECTIONAL SURVEY JOB NUMBER A980GO021 Marathon Oil Company COMP AN Y Cook Inlet. Kenai Alaska ~; ~, ~ TYPE OF SURVEY DA~FE Gyro ~lti-Shot 9/25/~ /. SURVEY BY Andy Hic kman OFFICE Alaska MARATHON OIL DOLLY VARDIN PLTFM, WELL NO; D-12RD (GMS) COOK INLET, KENAI, ALASKA GMS, 0-11850MD, SURVEYOR; A HICEMAN, DATE RUN; 25-SEF'-80 12 DEG A/U NO; 790, 70 DEG A/U NO; 411, CAMERA NO; 1095 JOB NO~ A980G0021 RECORD OF SURVEY ANGLE AVERAGIN8 METHOD ~.AF(AIHON OIL CO. DOLLY VARDIN F'LIF~, WELL NO: D-12RD (GMS) COOk INLET, EENAI, ALAS~A COMF'UTATION TIME DATE 10:18:21 01-0CT-80 PAGE NO. I TRUE HEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D-t-N A T E S DISTANCE DIRECTION SEVERtT' FEEl' D M D FEET FEET FEET FEET FEET FEET D M DG/100F O. 0 0 0 O. 0.00 0.00 -t06o00 0~0~ ........ 0.00 0.00 0 0 0.00 100. 0 15 N 12 W 100. 100.00 -0.19 -6.00 0.21N 0.05 W 0.22 N 12 0 W 0.25 200. 0 15 N 35 E 100. 200.00 -0.44 94.00 0.64 N 0.04 E 0.64 N 3 43 E 0.20 300. 0 15 N 5 W 100. 300.00 -0.67 194,00 ...... ~(>~-'N ..... 0.15 E 1.07 N 8 17 E 0,17 400. 0 15 S 81 E 100. 400.00 -0.66 294.00 1.36 N 0.47 E 1.44 N 19 12 E P-~9 500. 0 30 S 52 E 600. 0 45 S 6 E 700. 2 45 S 69 E 800. 5 0 S 59 E 900. 6 30 S 46 E 1000. 6 30 S 47 E 1100. 6 45 S 46 E 1200. 8 15 S 51E 1300. 10 45 S 47 E 1400. 12 15 S 46 E 100. 499,99 -0.06 393.99 t~.iO-N ...... 1.07 E 100. 599.99 0.99 493.99 0.14 N 1.60 E 100. 699.94 4.03 593.94 2.28 S 3.46 E 100. 799i71 10.36 ...... 693~71 ..... 5~24~$ ....... 9.54 E 100~ ~899,2~ 20.25 793.21 ~ 11.34 S 17.48 E 10~?~ 1097.90 ~,~U.~. ~ ~P1.90 ~ 27.07jS J~o06 E loo. .so: 1.54 N 44 20 E 1.61 N 84 50 E 4.14 S 56 39 E -10.88 8 61 13 E- 20.84 S 57 2 E 32.04 S 53 20 E 43.51 S 51 31E 56.55 S 50 50 E 73.05 S 50 25 E 92.95 S 49 34 E 0.-31-- 0.54 2.50 2.34 1.98 0.11 0.28 1.63 2.58 1.51 1500. 14 15 S 43 E 1600. 16 45 S 46 E 1700. 19 0 S 52 E 1800. 22 30 S 56 E 1900. 24 45 S 56 E 100. 1491.00 100. 1587.37 100. 1682.54 100. 1776.05 100. 1867,67 115.31 1385.00 76.62 S 86.82 E 142.05 1481.37 95.68 S 105.55 E 172.58 1576.54 115.82 S 128.72 E 207.39 .... 16:70~05 -I~3-6~-'6~-~--- 15-7~38 E 246.49 1761.67 159.05 S 190.61E 115.80 S 48 34 E 142.47 S 47 49 E 173.16 S 48 1E 208.42 S 49- 2 E 248.25 S 50 9 E 2.11 2.62 2 0 ~.'~7 2.25 2000. 27 30 S 55 E 2100. 30 30 S 57 E 2200. 32 0 S 57 E 2300. 34 0 S 60 E 2400. 36 30 S 58 E 2500. 39 0 S 59 E 2600. 40 15 S 57 E 2700. 40 15 S 56 E 2800. 40 0 S 57 E 2900. 40 0 S 59 E 100. 1957.46 100. 2044.92 100. 2130.41 100. 2214.28 100, 2295.94 100, 2375.01 100. 2452.03 100. 2528.35 100. 2604.82 100. 2681.42 289.54 1851.46 336.84 1938.92 387.25 2024.41 439.81 2108.28 495.38 2189.94 t83f?VS 226.89 E 211.10 S 267.09 E 239.36 S 310.59 E 267.828 ---357.03 E 297.54 S 406.50 E 554.47 2269.0t ~32V~53 S .... 458.70 E 616.17 2346.03 365.35 S 512.79 E 679.09 2422.35 ~98.99 S 566.67 E 741.84 2498.82 434.56 S 620.41E 804.02 2575.42 468.62 S 674.92 E 292.12 S 50 58 E 340.44 S 51 41 E 392.13 S 52 23 E 446.32 S 53 8 E 503.76 S 53 48 E 564.80 S 54 18 E 628.46 S 54 41 E 693.04 S 54 51 E 757.46 S 54 59 E 821.66 S 55 14 E 2.78 3.15 1.50 2.58 ~ 75 2,57 1.79 0,65 0,69. 1,29 ~ARATHON OIL CO. [,~OLLY VARDIN F'LIF~4, WELL NO; D-12f(D (GMS) ~£OOK INLET, KENAI, ALASKA COMF'UTAT I TIME [;ATE 10; 18:21 OI-OCT-80 F'AGD NO~ 2 TRUE MEASURED DRIFI' DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG ~EF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C O 0 R D ! N A T E S BISTANCE DIRECTION SEVERIT', FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100Fi 3000. 40 0 S 60 E 3100, 40 0 S 58 E 3200. 40 0 S 61E 3300, 40 0 S 62 E 3400. 40 0 S 63 E 100, 2758,03 865.76 2652,03 100. 2834.63 927.65 2728,63 100, 2911.24 98~,39 2805,24 100. 2987.84 1050.46 2881,84 100, 3064°45 1111,18 2958,45 501,24 S 730,30 E 885.77 S 55 32 E 534,35 S 785,40 E 949,94 S 55 46 E 566.97 S 840.79 E 1014.09 S 56 0 E 597.65~'S 897,28 E 1078.09 S 56 20 E 627,33 S 954,29 E 1142,02 S 56 41 E 0,64 1.29 1.93 0.64 3500. 40 30 S 62 E 3600, 40 45 S 63 E 3700, 40 30 S 62 E 3800, 40 0 S 62 E 3900, 40 0 S 64 E 4000. 40 0 S 65 E 4100, 39 30 S 66 E 4200. 39 0 S 65 E 4300, 38 45 S 64 E 4400. 38 15 S 64 E 100, 3140,77 1172,21 3034,77 657~I6'"$~-I011.60 E 1206,32 S 56 59 E 100. 3216.67 1233.71 3110.67 687.23 S 1069.36 E 1271.14 S 57 16 E 100. 3292.57 1295.21 3186.57 717.29 S 1127.11 E 1336.00 S 57 32 E 100; .....3368;87- 1356,42 3262;87'~ ~ 749,62-S---1-I84i16 E 1400,42 S 57 44 E 100~445,4~;>3416,V5 333V,4? 776,81 S 1241,43 E 1464,44 S 57 58 E 10 3~,10~.. ~~I l~~i ~,45 E 1528,32 S 58 14 E lO 3~m,?e l~e~l:~ 3~2;98 ~ 831,~08s ~,&4 E 1591.77 S 58 32 E 10 7&,42~ 15~~'35~~~~ ~,21 E 1654.5~ S 58 48 E loo. z~12.51 1711.4~ 17~.51 ~ll~4~s 1527.~i ~ 177m.0~ s s~ il ~ 0,82 0,70 0.70 0.50 1.29 0.64 0.81 0.81 0.68 0.50 4500. 38 0 S 65 E 4600. 37 45 S 67 E 4700, 37 30 S 64 E 4800. 36 45 S 66 E 4900. 36 15 S 66 E 100. 3911.20 1769.05 3805.20 938.12 S 1583.53 E 1840.56 S 59 21 E 100, 3990,14 1825.70 3884,14 963,09 S 1639.62 E 1901,55 S 59 34 E 100. 4069.34 1882.24 3963.34 988.41S 1695.17 E 1962.29 S 59 45 E I00. 4147.07 1938.33 4043.07~ 101~~-S'-~1-747.87 E 2022.40 S 59 55 E 100. 4229.46 1993.22 4123.46 1038.11 S 1804.21 E 2081.55 S 60 5 E 0.67 1.25 0.50 5000. 35 15 S 72 E 5100, 35 30 S 64 E 5200, 35 0 S 64 E 5300. 36 15 S 63 E 5400, 37 45 S 62 E 100. 4310.61 2045.88 4204.61 1059.05 S~- 1858.76 E 2139.29 S 60 20 E 100. 4392.15 2098.49 4286.15 1080.74 S 1912.44 E 2196.68 S 60 32 E 100. 4473.82 2152.49 4567.82 1106.04 S 1964.31 E 2254.29 S 60 37 E 100. 4555,10 2207.17 4449,10 1132,03~S 2016,44 E 2312,47 $ 60 41 E 100, 4634,96 2264,01 4528,96 1159,81 S 2069,82 E 2372.62 S 60 44 E 3.64 4,64 0,50 1.38 1,62 5500. 40 0 S 60 E 5600. 40 15 S 61E 5700. 40 45 S 59 E 5800. 40 15 S 58 E 5900. 40 30 S 58 E 100, 4712.82 2323,82 4606,82 1190,24 S - 2124,71 E 2435,38 S 60 45 E 100. 4789,28 2585.39 4683.28 1221.98 S 2180.80 E 2499.83 S 60 44 E 100, 4865,32 2447,61 4759,~2 1254,45 S 2237,05 E 2564,76 S 60 43 100, 4941,36 2510,29 4835,36 1288,38 8-2292,42 E 2629.66 S 60 40 E 100, 5017,54 2572,96 4911,54 1322,71 S 2347,36 E 2694,37 S 60 36 E 2.58 0,69 1.S9 0.82 0.25 'MARATHON OIL CO. i~OLLl' VARDIN F'LTFM, WELL NO; D-12F<D (GHS> COOK INLET. h. ENAI, AL. ASEA COMPUTATION TIME DATE 10:18;21 01-0CT-80 PAGE NO. 3 TRUE MEASURED DRIFT [;RIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R--D I N A T E S DISTANCE DIRECTION SEVERtT'. FEET D M D FEET FEEl' FEET FEET FEET FEET D M DG/100FT 6000. 39 45 S 58 E 6100. 39 15 S 56 E 6200. 39 0 S 58 E 6300. 38 45 S 58 E 6400. 39 0 S 57 E 100. 5094.01 2635.30 4988.01 1356~8~S--- 2402.01 E 2758.75 S 60 32 E 100. 5171.17 2697.11 5065.17 1391.50 S 2455.36 E 2822.24 S 60 28 E 100. 5248.75 2758.43 5142.75 1425.87 S 2508.28 E 2885.23 S 60 23 E 100. 5326.60 2819.14 5220.60- 1459~i3-$---2561o50 E -2947.94 S 60 20 E 100. 5404.45 2880.00 5298.45 1492.85 S 2614.44 E 3010.63 S 60 16 E 0.75 1.3;7 1.29 0.25 0""'",8 6500. 37 45 S 57 E 6600. 38 0 S 54 E 6700. 37 45 S 55 E 6800. 37 0 S 55 E 6900. 37 15 S 53 E 7000. 37 0 S 54 E 7100. 37 0 S 53 E 7200. 37 0 S 52 E 7300. 37 0 S 50 E 7400. 37 15 S 51 E 100. 5482.85 2940,32 -5376.85- 1526,6&-"S---2&,S&.50 E 3072.61 S 60 12 E 100. 5561.78 3000.33 5455.78 1561.44 S 2717.10 E 3133.80 S 60 7 E 100. 5640.72 3060.57 5534.72 1597.09 S 2767.08 E 3194.91 S 60 0 E 100. 5720.18 3120~02-~56t4~"~8 .... t6~i~9t-S 2816~80 E 3255.38 S 59 55 E 10Q~,~799 9~ 79,33 5693 92 ;667 ~8 S 2865 6~ E ~315 42 S 59 48 E ~9~9.~1 3~2eB~ ~3.~1 J739.08~S ~.53 E 3435.25 S 5~ 35 E 3357;5~2 ~~~~~.27 E 3494.98 S 59 28 E 6039.38 100. &1~8.~7 ~476.~1 60~2,~7 1851~8~,5 ~10~.61 E ~14.18 S 5~ 10 E 1.25- 1.86 0.66 0.75 1.23 0.65 0.60 0.60 1.20 0.65 7500. 36 30 S 51E 100, 6278.97 3536.38 6172.97 1889.75 S -3150.25 E 3673.58 S 59 3 E 0.75 7600 ~ID INTERF'OLATED SURVEY STATION 7600. 36 0 S 52 E 7700. 35 30 S 53 E 7800. 38 0 S 54 E 7900. 39 30 S 51E 100. 6359.61 3594.91 6253.61 1926.56 S 3196.52 E 3732.21 S 58 55 E 100. 6440.77 3652.59 6334.77 1962.12 S 3242.88 E 3790.27 S 58 49 E 100. 6520.89 5711.49 6414.89 t997.71 S- 3290.97 E 3849.85 S 58 44 E 100. 6598.88 3773.28 6492.88 2035.82 S 3340.63 E 3912.08 S 58 38 E 0.77 0.77 2.57 2.40 8000. 38 45 S 51 E 8100. 38 0 S 49 E 8200. 38 0 S 50 E 8300. 37 30 S 49 E 8400. 37 30 S 49 E 100, 6676.46 3835.82 6570.46 2075,53-S -~3389.67 E 3974.63 S 58 31 E 100. 6754.85 3897.48 6648.85 2115.43 S 3437.23 E 4036.04 S 58 23 E 100. 6833.66 3958.69 6727.66 2155.42 S 3484.04 E 4096.87 S 58 15 E 100. 6912.73 4019.56 6806.73 2195~18-S---3530.59 E 4157.39 S 58 8 E 100. 6992.06 4080.13 6886.06 2235.11 S 3576.54 E 4217.51 S 58 0 E 0.75 1.45 0.62 0.79 0.00 8500, 39 15 S 52 E 8600. 39 0 S 57 E 8700. 38 45 S 55 E 100. 7070.46 4141.73 6964.46 2274.60 S ....3624.44 E 4279.06 S 57 53 E 100. 7148,03 4203.64 7042,03 2311,25 S 3675,81 E 4342.06 S 57 50 E 100. 7225.89 4264.87 7119.89 2346.34 S 3727.85 E 4404.79 S 57 49 E 2.56 3.16 1.28 '~AF(ATHON OiL CO. DOLLY VARDIN F'LTF~, WELL NO: D-12RD (G~S) COOK INLET, RENAl, Al_ASEA COMPUTATION TIME DATE 10~18~21 01-0CT-80 F'AGE NO. 4 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C O O R-~ I N A T E S DISTANCE DIRECTION SEVERIT', FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100F' 8800. 38 30 S 59 E 8900. 38 0 S 55 E 9000. 39 30 S 58 E 9100. 41 0 S 57 E 9200. 41 15 S 57 E 100. 7304.01 4325.53 7198.01 2380.34 $~ 3780.20 E 4467.20 S 57 48 E 100. 7382.54 4385.68 7276.54 2414.06 S 3832.12 E 4529.11 S 57 47 E 100, 7460,53 4446.63 7354,53 2448,61 S 3884,31 E 4591.68 S 57 46 E 100. 7536.85 4509.28 7430.85 -241B'8';3~37~8.81 £- 4656.~0- S 57 46 E 100. 7612.18 4573.18 7506.18 2519.14 S 3993.97 E 4722.06 S 57 46 E 2.51 2.53 2.40 1.63 O'""e 5 9300. 39 45 S 56 E 9400. 38 0 S 55 E 9500. 30 45 S 54 E 9600. 28 15 S 54 E 9700. 27 30 S 54 E 9800, 26 45 S 55 E 9900, 26 30 S 56 E 10000, 25 15 S 52 E 10100. 25 0 S 51 E 10200. 25 15 S 52 E 100, 7888,22 4636.42 7582,22 -2554-~79-5'----4048,12 E 4786,99 S 57 45 E 100. 7766.07 4697.77 7660.07 2590.54 $ 4099.85 E 4849.70 S 57 43 E 100. 7848.61 4753.17 7742.61 2623.~2 $ 4145.81E 4906.08 S 57 41E 100. 7935.65 4801.56' 7827i65 .... 2652%27-S--4nI85Y65£- 4955.22 S 57 38 £ 100~,,~,,,8024.0~,~847.5~ 7918.04 2679.75 S 4223.48 E 5001.88 S 57 36 E 100, "'8113.04 .~,4878-.~ ~0~0~:~~21~~.57 E 5047.41 S 57 ~5 E 100, ~8202.44 4956,0~ 8~6.44 ~7~[S ~.53 E 5092.19 S 57 34 E 100,. '82~2,41 4~78-~"~~~~~ ~,8Z E 51Z5,75 S 57 Z2 E ZOO, e~~'"-'5020,~ '~~"~~ ~,06 E 5177,~8 S 57 2~ E 100, 847S,4~ 5062,~ 8~67,4~ 28~0~Z2. S 4S~.2~ E 5220.21 S 57 26 E 1.63 1.86 7.27 2.50 0.75 0.88 0.51 2.15 0.49 0.49 10300. 24 45 S 52 E 10400. 23 45 S 52 E 10500. 22 45 S 49 E lO&O0. 23 0 S 41 E 10700, 22 45 S 42 E 10800. 23 30 S 41E 10900. 23 0 S 42 E 11000. 23 0 S 41 E 11100. 22 30 S 46 E 11200. 22 0 S 44 E 11300. 22 15 S 47 E 11400. 22 45 S 47 E li500o 22 0 S 45 E 11600. 21 0 S 46 E 11700. 19 45 S 4~ E 100. 8564.12 5104.77 8458.12 2836;14 S 4432.59 E 5262.28 S 57 23 E 100. 8655.30 5145o~7 8549.30 2861.45 S 4464.96 E 5305.17 S 57 21E 100o 8747.18 5184.54 8641.18 2886.54 S 4495.42 E 5~42.37 S 57 18 E 100. 8839.31 5223.39 875~.3I ..... 2~'~;5."02-'~--~522.?I~ ~ -5380.J5 -S-57 12 ~ 100. 8931.45 5262.24 8825.45 2943.14 S 4548.66 E 5417.7~ S 57 6 E 100. 9023.41 5301.50 8917.41 2972.'55-S--4574.69 E 5455.62 S 56 59 E 100. 9115.29 5340.95 9009.29 3002.12 S 4600.84 E 5493.68 S 56 53 E 100. 9207.34 5380.00 9101.34 30~1.38 S 4626.7J E 5531.36 S 56 46 E 100. 9299.56 5418.68 9193.56 3057~43~-S 4653.35 E 5569.01 S 56 41 E 100. 9392.12 5456.52 9286.12 3086.21S 4680.13 E 5606.09 S 56 36 E 100. 9484.75 5494.16 9378.75 3112~60 S - 4706.99-E 5643.06 S 56 31 E 100. 9577.14 5532.35 9471.14 3138.70 S 4734.98 E 5680.80 S 56 28 E 100. 9669.61 5570.38 956~.61 3165.15 S 4762.36 E 5718.24 S 56 23 E 100. 9762.65 5607.00 9656.65 3190.84~8~-4788~50 E ' 5754.23 S 56 19 E 100. 9856.40 5641.78 9750.40 3215.02 S 4813.55 E 5788.49 S 56 16 E 0.50 1.00 1 3 2 0.46 0.85 0.64 0,39 2.00 0,91 1.16 0.50 .l .07 1.07 1.25 MARATHON OIL CO. i.IOLLY' VARDIN F'LTFM, WELL NO: D-12RD (GMS) COOK INLET, KENAI, ALASKA COMPUTATION TIME DATE 10;18;21 01-0CT-80 PAGE NO. TRUE HEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R-D t-N A T E S DISTANCE DIRECTION SEVERIT'_ FEE1 D H D FEET FEET FEET FEET FEET FEET D M DG/100F'. 11800. 18 0 S 47 E 100. 9951.02 5674.08 9845.02 ~2~7~29-$- 48~7.01 E 5820.~7 S 56 12 E 11850. 17 ~0 S 47 E 50. 9998.64 5689.29 9892.64 ~247.69 S 4848.16 E 58~5.42 S 56 11 E FINAL CLOSURE -DIRECTION: S 56 DEGS 10 MINS 58 SECS E DISTANCE; 58~5.42 FEET 1.78 1.00 Eastman Whip st oc .k P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349.4617 TWX 910-881-5066/Cable: EASTCO September 26, 1980 Marathon 0il Company P.O. Box 2380 Anchorage, Alaska 99510 Well Number: Dolly Vardin Location: Cook Inlet, Kenai, Alaska Type of S~uryey: Gyro Multi-Shot Date: 9/25/80 Method of Computation: Radius of Curvature Surveyor: Andy Hickman - ' - ...... ----,-.- Job Number: A98OGO021 ATTN: Curtis Dowden ~" Dear Mr. Dowden, I am enclosing the original and one copy of the Gyroscopic Multi-Shot Survey run on the above mentioned well. We wisR°to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, . Gene Rutland District Surveyor Alaska District GR/cfw D~rect~onal Dr,llers/Sub-Sudace Surveyors/Instrument & Tool Rentals/Sales/Worldwide / /I Eastman~ Whipstock l A PETROLANE ~ REPORT of SUB-SURFACE DIRECTIONAL SURVEY Marathon Oil Company Dolly V,ardin,, WELL NAME Cook Inlet. Kenai Alaska LOCATION JOB NUMBER A980GO021 SURVEY BY Andy Hickman TYPE OF SURVEY Gyro Multi-Shotj ~;F FICE Alaska DATE 9/25/80 MARATHON OIL CO. ;~OLLY VARDIN F'LTFM, WELL NO: D-12RD (GMS) COOK INLET, RENAl, ALASKA GMS, 0-11850HD, SURVEYOR: A HICKMAN, [lATE RUN; 25-SEP-80 )2 [lEG A/U NO: 790, 70 DEG A/U NO; 411, CAMERA NO: 1095 dOB NO: A980GO021 9ERTICAL SECTION CALCULATEI~.IN PLgNE OF' ~I~Q~ALm ~ ~ RECORD OF SURVEY RADIUS OF CURVATURE METHOD ,ARATHON OIL CO. D~OLLY VARDIN F'LTFM, WELL NO: D-12RD (GMS) 500K INLET, KENAI, ALASKA COMPUTAIlON TIME DATE 12;03:21 26-S£F'-80 PAGE NO. 1 · TRUE IEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEF'IH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E $ DISTANCE DIRECTION SEVERIT FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100F O. 0 0 0 O· 0·00 100. 0 15 N 12 W 100. 100.00 200. 0 15 N 35 E 100. 200.00 300. 0 15 N 5 W 100· 300.00 400. 0 15 S 81 E 100. 400.00 500. 0 30 S 52 E 100. 600. 0 45 S 6 E 100, 700, 2 45 S 69 E 100. 800. 5 0 S 59 E 100, 900. 6 30 S 46 E 100. 1000. 6 30 S 47 E 1100. 6 45 S 46 E 1200. 8 15 S 51E 1300. 10 45 S 47 E 1400· 12 15 S 46 E 1500. 14 15 8 43 E 1600. 16 45 S 46 E 1700. 19 0 S 52 E 1800. 22 30 S 56 E 1900· 24 45 S 56 E 0.00 -106.00 --0.00- 0.00 -0.19 -6.00 0.21 N 0.05 W -0.43 94.00 0.63 N 0.04 E -~.65 194,00- -- 1,04-N ..... 0,15 E -0.65 294.00 1.30 N 0.43 E 100. 100, 100. 100. 100. 1393.64 499.99 -0.06 393.99 1.04-N- 1.02 E 599.99 0.97 493.99 0.11 N 1.54 E 699.94 3.86 593.94 2.19 S 3.30 E 799.70 10.17 693.70 5.15 S 9.37 E 899.20 20.04 793.20 11·23 S 17.30 E 92.~9 1~7,64 60,16. S 70.57 E 100. 1490.97 100. 1587.33 100· 1682.49 100. 1775.99 100· 1867·60 115.10 1384.97 76.51 141.81 1481.33 95.56 172.34 1576.49 115·69 207.14 1669.99 *-136.51-S 246.24 1761·60 158.92 86.63 E 105.36 E 128.51E 157.16 E 190.38 E 0.00 0 0 0.22 N 12 0 W 0.63 N 3 35 E 1.05 N 8 12 E 1.37 N 18 12 E 1.46 N 44 29 E 1.54 N 85 48 E 3.96 S 56 28 E 10.69 S 61 13 E 20.63 S 57 0 E 31.83 S 53 17 E 43.30 S 51 29 E 56.34 S 50 47 E 72.83 S 50 23 E 92.73 S 49 33 E 115.58 S 48 33 E 142.24 S 47 47 E 172.91 S 48 0 E 208.17 S 49 I E 247.99 S 5O 9 E 0.00 O.~ 0.20 0.17 0.39 0,31 0,54 2.50 2.34 1.98 0.11 0.28 1.63 2.58 1.51 2.11 2.90 J~'~7 2000. 27 30 S 55 E 2100. 30 30 S 57 E 2200. 32 0 S 57 E 2300. 34 0 S 60 E 2400. 36 30 S 58 E 100. 1957.38 100. 2044.83 100. 2130.32 100. 2214.18 100. 2295.84 289.28 1851,38 336,57 1938,83 386,98 2024,32 439,54 2108,18 495.10 2189.84 183.85 S 2~0.96 S 239.21S 267.67 S 297.39 S 226.67 E 266.85 E 310.36 E 356.79 E 406.26 E 291.86 S 50 57 E 340.17 S 51 40 E 391.85 S 52 23 E 446·03 S 53 7 E 503.47 S 53 48 E 2.78 3.15 1.50 2.58 2.75 2500. 39 0 S 59 E 2600. 40 15 S 57 E 2700. 40 15 S 56 E 2800. 40 0 S 57 E 2900. 40 0 S 59 E 100. 2374.90 100. 2451.93 lO0. 2528.25 100. 2604.71 100. 2681.32 554.19 2268.90 615.88 2345.93 678.79 ~47~~~. 25 741.54 2498·71 803.73 2575.$2 329.37 S 363.17 S 398.85 S 434.40 S 468.46 S 458.45 E 512.53 E 566.41E 620.15 E 674.66 E 564.50 S 54 18 E 628.16 S 54 41 E 692.74 S 54 51 E 757.16 S 54 59 E 821.35 S 55 14 E '~ 57 1.79 0.65 0.69 1.~9. ..RAlStON OiL CO. )'LLY VARI~IN F'LIFM, WELL NO: D-]2RI~ (GMS) ~Oh, INLET, KENAI, ALASKA COMF'UTATION TIME DATE 12:03:21 26-SEF'-80 RAGE NO. '2 TRUE ASURED DRIFF DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG )~F'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R P I N A T E S DISTANCE DIRECTION SEVERIT FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100F 3000. 40 0 S 60 E 3100. 40 0 S 58 E 3200. 40 0 S 61 E 3300. 40 0 S 62 E 3400. 40 0 S 63 E 100, 2757.92 865,46 2651,~2 100, 2834.53 927,35 2728,53 100, 2911,13 989o08 2805,13 100. 2?87,74 1050.15 2881,74 100, 3064,34 1110.87 2958.34 501.08 $ 730,05 E 885,47 S 55 32 E 534,19 S 785,14 E 949.63 S 55 46 E 566,81 S 840,52 E 1013.78 S 56 0 E 597,48-S- 897,01 E 1077,78 S 56 20 E 627,16 S 954.02 E 1141.70 S 56 41 E 0.64 1.29 1.93 0'"',4 0.04 3500. 40 30 s 62 E 3600. 40 45 S 63 E 3700. 40 30 S 62 E 3800. 40 0 S 62 E 3900. 40 0 S 64 E 4000. 40 0 S 65 E 4100. 39 30 S 66 E 4200. 39 0 S 65 E 4300. 38 45 S 64 E 4400. 38 15 S 64 E 4500. 38 0 S 65 E 4600. 37 45 S 67 E 4700. 37 30 S 64 E 4800. 36 45 S 6& E 4900. 36 15 S 66 E 5000. 35 15 S 72 E 5100. 35 30 S 64 E 5200. 35 0 S 64 E 5300. 3~ 15 S &3 E 5400. 37 45 S 62 E 100, 3140,66 1171.90 3034,66 656°?? S--1011,33 E 1206.00 S 56 5? E 100. 3216,56 1233.40 3110,56 687,06 S 1069,09 E 1270,82 S 57 16 E 100, 3292,46 1294,90 3186,46 717,12 S 1126,84 E 1335.68 S 57 32 E 100, 3368,78 1356,12 3262,78- 747,4&-$--II83,89 E 1400.10 S 57 44 E 100o~ 3445.39 ~.1416.64 3339,3? 776,64 S 1241,16 E 1464.12 S 57 58 E 100o .3521,9~,.~ 147&~58~ 341,5~ ~ ~~,18 E 1528,00 S 58 14 E lod,lOO°"~Z598~88'~'~&76 153..5o8~3492.88 . 830~3~S ~7.3& E 1591.45 S 58 32 E 31 1594o3~ '~38~0~3~~ ~e.'5'~;~.~' ~4t4.93 E 1654.27 S 58 48 E 100. 3754;17 1652.82~ 364e~3z~-- ee~ee E 1716.73 S 5? 0 E 100. 3832.43 1711.17 372~,43 911,37 S 1527.53 E 1778.75 S 5? 11E 100. 3911.10 1768.74 3805.10 937.95 S 1583.26 E 1840.23 S 59 21 E 100. 3990.03 1825.39 3884.03 962.92 S 1639.34 E 1901.22 S 59 34 E 100. 4069.23 1881.92 3963.23 988.24 S 1694.89 E 1961.95 S 59 45 E 100, 4148,96 1938,01 4042.96 I013,74-S 1749,58 E 2022.06 S 59 55 E 100. 4229.35 1992.89 4123.35 1037,93 S 1803,92 E 2081,21 S 60 5 E 100. 4310.51 2045,53 4204,51 1058,86 S 1858.44 E 2138.93 S 60 20 E 100, 4392,04 2098,09 4286,04 1080,53 S 1912,07 E 2196.26 S 60 32 E 100. 4473.71 2152.09 4367.71 1105,83 S 1963.95 E 2253.87 S 60 37 E 100. 4554.99 2206.77 4448.99 1131,82 S 2016,07 E 2312,05 S 60 41 E 100, 4634,85 ~_°~63.61 4528,85 1159,61 S 2069,45 E ~o379_.20 S &O 44 E 0.82 0.70 0,70 0.50 1,29 0.64 0.81 0.81 0.68 0.50 0.67 1 .~n,~ 1.42 0.50 3.64 4.64 0.50 I .38 1.62 5500. 40 0 S 60 E 5600. 40 15 S 61E 5700. 40 45 S 59 E 5800. 40 15 S 58 E 5900, 40 ~0 S 58 E 100. 4712.70 2323.41 4606.70 1190.03 S 2124.34 E 2434.95 S 60 45 E 100, 4789,16 2384,98 4683,16 1~1,~ 77 S 2180,43 E 2499,40 S 60 44 E 100, 4865,20 2447,20 4759,20 1254,24 S 2236,67 E 2564,33 S 60 43 E 100. 4941,24 2509.88 4835,24 1288,17 8 -~o~o~_~.05 E 2629,23 S 60 40 E 100. 5017.43 2572.54 4911.43 1322.50 S 2346.98 E 2693.94 S 60 36 E 2.58 0,~9 ,391 0!82- 0 25 ~'P, INON OIL CO. ~LLY VAF'DIN F'LIFM, WELL NO; I'~-12F<lq (bttS) ~O~, INLET, ~ENAI, ALASKA COMPUTATION TIME DATE 12:03:21 26-SEF'-80 PAGE NO. ~ TRUE ASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG ~EF'TH ANGLE DIRECTION LENGTH [IEF'IH SECTION TVD C 0 0 R Ii I N A T E S DISTANCE DIRECTION SEVERITY. FEET Ii M D FEET FEET FEET FEET FEET FEET D M DG/100FT 6000. 39 45 S 58 E 16100. 39 15 S 56 E i6200. 39 0 S 58 E ~6500. 38 45 S 58 E 6400. 39 0 S 57 E 100. 5093,89 2634.89 4987,89 1356.65 S 2401.63 E 2758.~2 S 60 32 E 100, 5171.05 2696.69 5065,05 1391.29 S 2454,97 E 2821.81 S 60 28 E 100. 5248,6~ 275E, 00 5142.63 1425.65 S 2507,89 E 2884,79 S 60 23 E 100. 5326.48 2818,72 5220.48 1458.91-8 -2561.12 E 2947.50 S 60 20 E 100. 5404.33 2879.57 5298.3~ 1492,64 S 2614.05 E 3010.19 S 60 16 E 0.75 1,37 1.29 0.o8 6500. 37 45 S 57 E 6600. 38 0 S 54 E 6700. 37 45 S 55 E 6800. 37 0 S 55 E 6900. 37 15 S 53 E 7000. 37 0 S 54 E 7100. 37 0 S 53 E 7200. 37 0 S 52 E 7300. 37 0 S 50 E 7400. 37 15 S 51 E 100, 5482,73 2939.90 5376.73 1526,45-8--2666,12 E 3072.17 S 60 12 E 100. 5561.66 2999.90 5455.66 1561.21 S 2716.70 E 3133.35 S 60 7 E 100, 5640,60 3060,13 5534,60 1596,86 S 2766,68 E 3194,45 S 60 0 E 100, 5720.06 3119.58 5614.06 1631,68-8--~'~81~.41 E 3254,92 S 59 55 E 100o 5799,80 3178,89 5693,80 1667,16 S 2865,23 E 3314.96 S 59 48 E 100, 5879,53 3238,29 ~ 5~?~,~3 ~ 1_7~;~'.m.~____, 75 E 3374,96 S 59 42 E ZOO 5959 39 3297o5~ 5853.39 ~7i~'Z3 E 79 S 59 35 E , . , ,1738._85~S 3434. 100, 6039 25 3356 94 5W33;-?~Jaj.l~~.~ ~009 87 E 3494,=~ 28 , * ~ · ~ S 59 E 100, 6119,12 3416,58 601~;~2'~i~1~a1~$>'~ ;~0~,64 E 3554,06 S 59 19 E 100. 6198.85 3476.47 6092,85 1851,75 S 3103,21E 3613.71 S 59 10 E i 1,25 1,86 0,66 0,75 1,23 0,65 0.60 0.60 1.20 0.65 - 7500, 36 30 S 51E 100, 6278.84 3535.94 6172.84 1889.51S 3149.84 E 3673,11 S 59 2 E 00 MD INTERF'OLATED SURVEY STATION 0.75 7600. 36 0 S 52 E 7700. 35 30 S 53 E 7800. 38 0 S 54 E 7900. 39 30 S 51 E 8000, 38 45 S 51 E 8100. 58 0 S 49 E 8200, 38 0 S 50 E 8300. 37 30 S 49 E 8400. 37 30 S 49 E 100. 6359,49 3594.47 6253,49 1926,32 S 3196,12 E 3731,74 S 58 55 E 100, 6440.65 3652.15 6334.65 1961,89 S 3242,47 E 3789.81 S 58 49 E 100, 6520,76 3711.03 6414,76 1997,48 S 3290.56 E 3849.38 S 58 44 E 100, 6598,75 3772,82 6492.75 2035,58 S 3340,21 E 3911,60 S 58 38 E 100. 6676.33 3835.36 6570.33 2075.29 S- 3389,25 E 3974,15 S 58 31 E 100, 6754,72 3897,01 6648,72 2115.19 S 3436,81 E 4035,55 S 58 23 E 100, 6833,52 3958.22 6727,52 2155,17 S 348~,62 E 4096,39 S 58 15 E 100. 6912,59 4019.09 6806,59 2194.93 S 3530.17 E 4156,90 S 58 8 E 100, &991,93 4079,67 6885,93 2234,87 S 3576,12 E 4217,02 S 58 0 E 0.77 -' 0.77 2.57 2.40 It 0,75 1,45 0 6~ ! 0 O0 RATHON OIL CO. :LLY VARDIN F'LTFH, WELL NO: !OK INLET, KENAI, ALASKA COMPUTATION TIME [;ATE 12:03;21 26-SEF'-~0 F'A~L NO. TRUE ASURED DRIFT [;RIFT COURSE VERTICAL VERTICAL SUBSEA R E. C T A N G U L A R C L 0 S U R E DOGLEG ~EF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TV[; C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT FEET D H D FEET FEET FEET FEET FEET FEET D M DG/100F' 8500. 39 15 S 52 E 8600. 39 0 S 57 E G700. 38 45 S 55 E 8800. 38 30 S 59 E 8900. 38 0 S 55 E 100. 7070.32 4141.25 6964.32 2274.35 S - 3624.01 E 4278,57 S 57 5;3 E 100. 7147.90 4203.14 7041.90 2310.98 S 3675.37 E 4341.54 S 57 50 E 100. 7225.75 4264.37 7119.75 2346.08 S 3727.40 E 4404.27 S 57 49 E 100. 7303.88 4325.01 7177.88 2380.07 S--3777.7;3 £ 4466.67 S 57 48 E 100. 7382.41 4385.16 7276.41 2413.78 S 3831.65 E 4528.56 S 57 47 E 2.56 ;3.16 1.28 9000. 39 30 S 58 E 9100. 41 0 S 57 E 9200. 41 15 S 57 E 9300. 37 45 S 56 E 9400. 38 0 S 55 E 9500. 30 45 S 54 E 9600. 28 15 S 54 E 9700. 27 30 S 54 E 9800. 26 45 S 55 E 9900. 26 30 S 56 E 100. 7460,39 4446.0? 7354.;39 2448.32 S--~J883.84 E 4571.13 S 57 46 E 100. 7536.71 4508.74 7430.71 2483.04 S 3938.33 E 4655.74 S 57 46 E 100. 7612.04 4572,65 7506.04 2518.86 S 399'3.49 E 4721.50 S 57 46 E 100. 7688.08 4635.88 7582.08 2554.70-S--4047.64 E 4786,43 S 57 45 E 100. 7765.93 4697.23 7659.93 2590.25 S 4099.36 E 4849,14 S 57 43 E 100. 7848.41 4752,58~ 774~41J 2 ~~.50 E 4905.47 S 57 41 E 100. 7935.44 4800e97 ~ 4954.61 S 57 3B E 7~9.44 ~651._95~S ~.13 E l oo. 8o23.84 484e.92 , 50 27 S 57 56 E zoo. .07 s04 .80 s s7 zs E 100. 8202.23 49~5.45 809~.23 27J1.2~ S 4297.00 E 5091.58 S 57 34 E 2.40 0.25 I .6;3 1.86 7.27 2.50 0.75 0.88 0,51 0000. 25 15 S 52 E 0100. 25 0 S 51 E '0200. 25 15 S 52 E '0;300. 24 45 S 52 E ,0400. 23 45 S 52 E 100. 8292.21 4978.33 8186.21 2756.94 S 4332.30 E 5135.13 S 57 32 E 100. 8382.74 5020.3& 8276.74 2785.37 S 4~65.53 E 5177,36 S 57 29 E 100. 8473.28 5062.39 8367.28 2809.80 S 4398.76 E 5219.59 S 57 26 E 100. 856;3.91 5104,17 845~.~1 2835,828- 4432.06 E 5261,66 S 57 2;3 E 100. 8655,09 5144.77 8549.09 2861.11 S 4464.43 E 5302,55 S 57 21 E 2.15 0.~ 0.50 1.00 '0500. 22 45 S 49 E LO600. 23 0 S 41E LO700. 22 45 S 42 E LO800. 23 30 S 41E 1,0900. 23 0 S 42 E 100. 8746.96 5183.93 8640.96 2886.21 S- 4494.88 E 5341.74 $ 57 18 E 100. 8839.10 5222.75 8733.10 2913.67 S 4522.35 E 5379,70 S 57 12 E 100. 8931.24 5261.60 8825.24 2942.79 S 4548.10 E 5417.12 S 57 6 E 100o 9023.20 5300,86 8917.20 2972.20 S 4574.13 E 5454.96 S 56 59 E 100. 9115.08 5340.31 9009.08 3001.76 S 4600.28 E 5493.01 S 56 52 E 1.55 3.12 0.46 0.85 0.64 LiO00. 23 0 S 41 E Ll100, 22 ~0 S 46 E [1~00.- 2~-~ 0 S 44 E !.1300. 22 15 S 47 E 11400. ~° 45 S 47 E 100. 9207.13 5379.36 9101.13 3031.03 S-4626.17 E 5530.70 S 56 46 E 100. 9299.35 5418.02 9193.35 3059.07 S 4652.78 E 5568.33 S 56 41 E 100. 9391.90 5455.87 9285.90 3085.84 S 4679.56 E 5605.42 S 56 36 E 100. 9484.54 5493.50 9378.54 3112.24 8 -4706.42 E 5642.38 S 56 31 E 100. 9576.93 5531,69 9470.93 3138.34 S 4734.41 E 5680.12 S 56 28 E 0.39 2.00 0.91 1.16 0.50 ,RATHON OIL CO. ,LL¥ VARDIN PLTFM, WELL NO~ D-12RD (GMS) IOK INLET, KENAI, ALASEA COMPUTATION TIME DATE 12~0J~21 26-SEF'-80 PAGE NO. 5 TRUE ASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG EF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R Ii I N A T E S DISTANCE DIRECTION SEVERITt FEET D M D FEET FEET FEET FEET FEET FEET D M DG/1OOF] 1500. 22 0 S 45 E 1600. 21 0 S 46 E 1700. 19 45 S 46 E 1800. 18 0 S 47 E 1850. 17 30 S 47 E 100. 9669.40 5569.72 9563.40 3164.78-S-- 4761.79 E 5717.56 S 56 23 E 1.07 100. 9762.44 5606.34 9656.44 3190.47 S 4787.93 E 5753.55 S 56 19 E 1.07 100. 9856.18 564~.12 9750.18 3214.65 S 4812.97 E 5787.81 S 56 16 E 1.25 100. 9950.80 5673.42 9844.80 3236;92-~4~B36.44 E-- 5819.69 S 56-12 E~ 50. 9998.42 5688.63 9892.42 3247.32 S 4847.58 E 5834.74 S 56 11E FINAL CLOSURE - DIRECTION: DISTANCE; r~ ~ '~ t [ +-1 Eastman / A PETROLANE COM~ REPORT of SUB-SURFACE DIRECTION.4L SURVEY Marathon 011 Company COMPANY Dolly Vardin WELL NAME Cook Inlet, Ecnai Alaska LOCATION JOB NUMBER A980GO021 TYPE OF SURVEYT Gyro DATE 9/~/~o SURVEY BY Andy Hickman OFFICE Alaska Eastman Whip, st oc k P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 TWX 910-881-5066~Cable: EASTCO September 26, 1980 Marathon 0il Company P.O. Box 2380 Anchorage, Alaska 99510 Well Number: Dolly Vardin Location: Cook Inlet, Kenai, Alaska Type of Survey: Gyro Multi-Shot Date: 9/25/80 - ~ Method of Computation: Radi~ Curvature Surveyor: Andy Hickman ~ '-i~ Job Number: A980GO021,- ATTN: Curtis Dowden ' ~ Dear Mr. Dowden, I am enclosing the original and one copy of the Gyroscopic Multi-Shot Survey run on the above mentioned well. We wish'to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, Gene Rutland District Surveyor Alaska District GR/cfw O~rect~onal Drillers / Sub-Sudace Surveyors/Instrument & Tool Rentals / Sales/Worldwide MARATHON OIL CO, DOLLY VAr<DIN F'LYFM, WELL NOg D-12RD (GMS) COOK INLET, RENAl, ALASRA GMS, 0-11850MD, SURVEYOR; A HICEMAN, DATE RUNg 25-SEP-80 12 DEG A/U NO: 790, 70 DEG A/U NOg 411, CAMERA NOg 1095 dOB NO; A980G0021 l RECORD OF SURVEY TANGENTIAL METHOD 'MARATHON OIL CO. DOLLY VARDIN PLTFH, WELL NO: D-12RD (GMS) COOK INLET, NENAI, ALASKA COMF'UTAIlON TIME DATE 00:02:56 30-SEF'-80 F'AOE NO. i TRUE ffEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG :~EF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D H D FEET FEET FEEl' FEET FEET FEET D H DG/100FT O. 0 0 0 O. 0,00 0.00 -106.00 0,00 0.00 0.00 0 0 0.00 100. 0 15 N 12 W 100. 100.00 -0.37 -6.00 0.43 N 0.09 W 0.44 N 12 0 W 0.25 200. 0 15 N 35 E 100. 200.00 -0'.46 94.00 0.78 N 0.16 E 0.80 N 11 30 E 0.20 300. 0 15 N 5 W 100. 300.00 -0.80 194.00 t~22--N 0.12 E 1.22 N 5 42 E Oink7 400. 0 15 S 81E 100. 400.00 -0.46 294.00 1.15 N 0.55 E 1.28 N 25 39 E 0 ~ 500. 0 30 S 52 E 100, 499.99 0.40 393.99 0,61 N 1.24 E 1.38 N 63 41 E 0.31 600. 0 45 S 6 E 100. 599.98 1.45 493.98 0.69 S 1.38 E 1.54 S 63 26 E 0.54 700. 2 45 S 69 E 100. 699,87 5,77 593.87 2,41S 5,86 E 6.33 S 67 39 E 2.50 800, 5 0 S 59 E 100, 799.49 14,16 693,49 6,90 S 13.33 E 15.01 S 62 38 E 2,34 900. 6 30 S 46 E lOOt~~ ~ 898.85 25,47 792,85 14,76 S 21.47 E 26.05 S 55 30 E 1,98 10~,:'~: 1097.51 4e~51 g91.51 _, ~ 30.65~s ~F~.20 E 100. 1392.44 102.54 1288.44 67.14 S 78.28 E 1000. 6 30 S 47 E 1100. 6 45 S 46 E 1200. 8 15 S 51E 1300. 10 45 S 47 E 1400. 12 15 S 46 E 37.29 S 52 55 E 48.98 S 51 16 E 63.53 S 51 12 E 81.94 S 50 15 E 103.11 S 49 23 E 0.11 0.28 1.63 2.58 1.51 1500. 14 15 S 43 E 1600. 16 45 S 46 E 1700. 19 0 S 52 E 1800. 22 30 S 56 1900. 24 45 S 56 E 100. 1489.37 100. 1585.12 100. 1679.67 100. 1772.06 100. 1862.88 127.15 1383.37 155.94 1479.12 188.13 1575.67 225.46 1666,06 266.31 1756.88 85.14 S 95.05 E 127.60 S 48 9 E 2.11 105,16 S 115.78 E 156.41 S 47 45 E 2.62 125,20 S 141.45 E 188.89 S 48 29 E 2'"~ 146.60 S- 173.16 E 226.88 S 49 45 E 3.,/ 170.01 S 207.87 E 268.54 S 50 43 E 2.25 2000. 27 30 S 55 E 2100. ~0 30 S 57 E 2200. 32 0 S 57 E 2300. 34 0 S 60 E 2400. 36 30 S 58 E 100. 1951.58 100. 2037.74 100. 2122.55 100. 2205.45 100. 2285,84 311.53 1845.58 360.85 1931.74 412.34 2016.55 465.91 2099.45 523.45 2179.84 196.50 S 245.69 E 314.60 S 51 21 E 2.78 224.14 S 288.26 E 365.15 S 52 8 E 3.15 253.00 S 332.70 E 417.97 S 52 45 E 1.50 280.96 S 381.13 E 473.50 S 53 36 E 2.58 312,48 S 431.57 E 532.82 S 54 6 E 2.75 2500. 39 0 S 59 E 2600. 40 15 S 57 E 2700. 40 15 S 56 E 2800. 40 0 S 57 E 2900. 40 0 S 59 E 100. 2363.55 100. 2439.87 100. 2516.20 100. 2592.80 100. 2669.41 584.05 2257.55 646.83 23~3.87 709.87 2410.20 772,33 2486.80 834.22 2563.41 344.89 S 485.52 E 595.55 S 54 37 E 2.57 380.08 S 5~9.70 E 660.11 S 54 51 E 1.79 416.22 S 593.27 E 724.71 S 54 57 E 0,65 451.22 S 647.18 E 788.95 $ 55 7 E 0,69 484.33 S 702.28 E 853.09 S 55 24 E 1.29 MARATHON OIL. CO. DOLLY VARDIN PLTFM, WELL NO: D-12RD (GMS) COOK INL£T, KENAI, ALASKA COMPUTATION TIME DATE 00:0~;56~ 30-SEF'-80 PAGE NO. 2 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT5 FEET D H D FEET FEET FEET FEET FEET FEET D M DG/100Fl 3000. 40 0 S 60 E 3100. 40 0 S 58 E 3200. 40 0 S 61 E 3300. 40 0 S 62 E 3400. 40 0 S 63 E 100, 2746,01 895.80 2640.01 100. 2822.61 957.98 2716.61 100. 2899.22 1019.23 2793.22 100. 2975.82 1080.13 2869,82 100. 3052.43 1140.66 2946.43 516.47 S 757.94 E 917.18 S 55 44 E 550.53 S 812.46 E 981.41 S 55 53 E 581.70 S 868.67 E 1045.45 S 56 12 E 61t,87~S-~ 925,43 E 1109.42 S 56 32 E 641.05 S 982.70 E 1173.31 S 56 53 E 0.64 1.29 1.93 o .,4 0 4 3500. 40 30 S 62 E 3600. 40 45 S 63 E 3700. 40 30 S 62 E 3800. 40 0 S 62 E 3900. 40 0 S 64 E 4000. 40 0 S 65 E 4100. 39 30 S 66 E 4200. 39 0 S 65 E 4300. 38 45 S 64 E 4400. 38 15 S 64 E 100. 3128.47 1202.19 3022.47 671.54 S--1040.04 E 1238.01 S 57 9 E 100. 3204.23 1263.65 3098.23 701.18 S 1098.21 E 1302.96 S 57 27 E 100. 3280.27 1325.18 3174.27 731.67 S 1155.55 E 1367.71 S 57 40 E 100. 3356.87 1386.08 3250.87 761.85-S 1212.30 E 1431.81 S 57 51 E 100~ .....3433.4Z ~,!446.22 3327.47 ~790.02 S 1270.08 E 1495.74 S 58 7 E 3664 looJ .74 E 174 . 7 S 5m 7 E 100~ ~821~48 1739.63 3715,48 924~2~ S 1555.38 E 1809.26 S 59 17 E 0.82 0.70 0.70 0.50 1.29 0,64 0.81 0,81 0.68 0.50 4500. 38 0 S 65 E 4600. 37 45 S 67 E 4700. 37 30 S 64 E 4800. 36 45 S 66 E 4900. 36 15 S 66 E 100. 3900.28 1796.85 3794.28 950.25 S 1611.18 E 1870.53 S 59 28 E 100. 5979,35 1852.92 3873,35 974.17 S 1667.53 E 1951.24 S 59 42 E 100. 4058.68 1909.88 3952.68 1000.86 S 1722.25 E 1991.95 S 59 50 E 100. 4138.81 1965.09 4032.81 1025.20-~ 1776.91 E 2051.45 S 60 1 E 100. 4219.45 2019.65 4113.45 1049.25 S 1850.93 E 2110.26 S 60 11 E 0.67 1.25 0.50 5000. 35 15 S 72 E 5100. 35 30 S 64 E 5200. 35 0 S 64 E 5300. 36 15 S 63 E 5400. 37 45 S 62 E 100. 4301.12 2070.29 4195.12 1067.08 S 1885.82 E 2166.79 S 60 30 E 100. 4382.53 2124.63 4276,53 1092.54 S 1938.01 E 2224.75 S 60 35 E 100. 4464.44 2178.29 4358.44 1117.68 S 1989.56 E 2282.01 S 60 40 E 100. 4545.09 2233.97 4439.09 1144.53 S 2042.25 E 2341.09 S 60 44 E 100. 4624.16 2291.98 4518.16 1173.27 S 2096.30 E 2402.30 S 60 46 E 3.64 4.64 0.50 1.38 1.62 5500. 40 0 S &O E 5600. 40 15 S 61 E 5700. 40 45 S 59 E 5800. 40 15 S 58 E 5900. 40 30 S 58 E 100. 4700.76 2353.55 4594.76 1205.41 S- 2151.97 E 2466.57 S 60 45 E 100. 4777.08 2415.12 4671.08 1236.73 S 2208.48 E 2531.19 S 60 45 E 100. 4852.84 2477.97 4746.84 1270.35 S 2264.4~ E 2596.43 $ 60 42 E 100. 4929.16 2540.48 4823,16 1304.59 S -2319.23 E 2660.97 S 60 39 E lO0. 5005.20 2603.31 4899.20 1339.01S 2374.30 E 2725.85 S 60 35 E 2.58 0,69 1.39 0.82 0.25 dARATHON OIL CO. DOLLY VARDIN F'LTF'M, WELL NO; D-12RD (GMS) COOK INLET, KENAI, ALASEA COMPUTATION TIME DA1'E 00:02:56 30-SEF'-80 PAGE NO; 3 TRUE HEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLE DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI FEET D M D FEET FEET FEET FEET FEET FEET D M DG/10( 6000. 39 45 S 58 E 6100. 39 15 S 56 E 6200. 39 0 S 58 E 6300. 38 45 S 58 E 6400. 39 0 S 57 E 6500. 37 45 S 57 E 6600, 38 0 S 54 E 6700. 37 45 S 55 E 6800. 37 0 S 55 E 6900 37 15 S 53 E 7000. 37 0 S 54 E 7100. 37 0 S 53 E 7200. 37 0 S 52 E 7300. 37 0 S 50 E 7400. 37 15 S 51 E 7500. 36 30 S 51E 100. 5082.09 2665.17 4976.09 1372.89 S- 2428.53 E 2789.73 S 60 31 E 0.75 100. 5159.53 2726.90 5053.53 1408.27 S 2480.99 E 2852.81 S 60 25 E 1.3~ 100. 5237.24 2787.78 5131.24 1441.62 S 2534.36 E 2915.69 S 60 22 E 1.2S 100. 5315.23 2848.33 5209.23 I474¥77-S--2587.44 E 2978.23 S 60 19 £ 0.25 100. 5392.94 2909.48 5286.94 1509.07 S 2640.22 E 3041.06 S 60 15 E ~6E 100. 5472.01 2968.97 5366.01 1542.41~S ~2691.56 E 3102.18 S 60 11 E 100. 5550.81 3029.47 5444.81 1578.60 S 2741.37 E 3163.40 S 60 4 E 100. 5629.88 3089.43 5523.88 1613.71 S 2791.52 E 3224.38 S 59 58 E 100. 5709.75 3148.37 5603~'~75 1648.23 S 2840.82 E 3284.34 S 59 5'~ E 100, 5789.3q ~208.04 5683.35 1684.66 S 2889.16 E 3344.44 S 59 45 E 100, 5869 · 32~7.18 )7~~-~ ~ 1~~I~J~1~o85 E 3404.33 $ 59 39 E 10~ 5949.07 3326'~.51 ~ 58.43.07 ~1756.2~S ~.91 E 3464.11 S 59 32 E z m .oo .zzE zs z.7 s E 100. 6108';8~ 344).77 60~~~~)~" ~'~~ ~.43 E 3583.17 S 59 15 E 100. 6188.40 3505.76 6082.40 1870.08 S 3126.47 E 3643.08 S 59 7 E 100. 6268.79 3564,71 6162.79 1907.51 S 3172.70 E 3701.98 S 58 59 E 7600 MD INTERPOLATED SURVEY STATION 7600. 36 0 S 52 E 100. 6349.69 3622.82 6243.69 1943.70 S 3219.02 E 3760.33 S 58 53 E 7700. 35 30 S 53 E 100. 6431.10 3680.07 6325.10 1978.65 S 3265.40 E 3818.10 S 58 47 E 7800. 38 0 S 54 E 100. 6509.90 3740.57 6403.90 2014.84 S 3515.20 E 3879.45 S 58 43 E 7900. 39 30 S 51 E 100. 6587.07 3803.61 6481,07 2054.87 S 3364.64 E 3942.49 S 58 35 E 0.6~ 0.6C 0.6( 1.2¢ 0.65 0.7t~ 2.5? 2.4C 8000. 38 45 S 51 E 8100. 38 0 S 49 E 8200. 38 0 S 50 E 8300. 37 30 S 49 E 8400. 37 30 S 49 E 8500. 39 15 S 52 E 8600. 39 0 S 57 E 8700. 38 45 S 55 E 100. 6665.05 3865.64 6559.05 2094.26 S 3413.28 E 4004.55 S 58 28 E 100. 6743.85 3926.91 6637.85 2134.65 S 3459.74 E 4065.29 S 58 20 E 100. 6822.66 3988.06 6716.66 2174.22 S 3506.91 E 4126.21 S 58 12 E 100. 6901.99 4048.63 6795.99 2214.16 S -3552.85 E 4186.32 S 58 4 E 100. 6981.33 4109,21 6875.33 2254.10 S 3598.79 E 424~.44 S 57 56 E 100. 7058.77 4171.76 6952.77 2293.05 9 3648.65 E 4309.38 S 57 51 E 100. 7136.48 4232.91 7030.48 2327.33 S 3701.43 E 4372.30 S 57 50 E 100. 7214.47 4294.21 7108.47 2363.23 S 3752.70 E 4434.82 S 57 48 E 0.75 1.4~ 0.62.- 0.7~ 0.0(, 2.5t 3.1~ 1.2E ~ARATHON OIL CO. DOLLY VARDIN PLTFM, WELL NO; D-12RD (GMS) COOK INLET, KENAI, ALASEA COMF'UTATION TIME DATE 00;02~56 30-SEF'-80 PAGE NO.' 4 TRUE ~EASURED DRIFT [;RIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DO~LEG IJEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TV[; C 0 0 R D t N A T E S DISTANCE DIRECTION SEVERIT] FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100F'' 8800. 38 30 S 59 E 8900. 38 0 S 55 E 9000. 39 30 S 58 E 9100. 41 0 S 57 E 9200. 41 15 S 57 E 100. 7292,73 4354.15 7186.73 2395,29-~S-- 3806.06 E 4497.06 S 57 49 E 100. 7371.53 4414.44 7265.53 2430.60 S 3856.50 E 4558.55 S 57 47 E 100. 7448.69 447S.98 7342.69 2464.31S 3910.44 E 4622.16 S 57 47 E 100. 7524.17 4539.73 7418.17 2500~04-S-~965.46 E 4687.76 S 57 46 E 100. 7599.35 4603.80 7493°35 2535.95 S 4020.76 E 4753.69 S 57 46 E 2.51 2.53 2.40 9300. 39 45 S 56 E 9400. 38 0 S 55 E 9500. 30 45 S 54 E 9600. 28 15 S 54 E 9700. 27 30 S 54 E 9800. 26 45 S 55 E 9900. 26 30 S 56 E 10000. 25 15 S 52 E 10100. 25 0 S 51 E 10200. 25 15 S 52 E 100. 7676.23 4666.18 7570,23 2571,7t-'-$ .... 4073.77 E 4817.60 S 57 44 E 100. 7755.03 4726.48 7649.03 2607.02 S 4124.20 E 4879.10 S 57 42 E 100. 7840.98 4776.72 7734.98 2637.07 S 4165.57 E 4930.12 S 57 40 E 100. 7929.06 4823.24 -7823.06-- 2684.90--S---4203.86 E 4977.36 S 57 38 E IOQo 8017o77~ 4868.61 7911.77 2692°04 S 4241.21 E 5025.44 S 57 36 E 10~, 8107.0& 47j~,~ ~~~ ~-- ' · .08 E 5068 41 S 57 34 E 10~; ~ 8196156 49,5~6,2~ 8~0.56 ,,~742.~_80jS ~.08 E 5113.01 S 57 34 E zoo. 82e7 oo E s ss..7 s s7 E 100. 8468.08 5082.45 8~2.08 2821~92, S 4415.15 E 5239.92 S 57 25 E 1.63 1.86 7.27 2.50 0.75 0.88 0.51 2.15 0.49 0.49 10300. 24 45 S 52 E 10400. 23 45 S 52 E 10500. 22 45 S 49 E 10600. 23 0 S 41 E 10700. 22 45 S 42 E 100. 8558.89 5123.84 8452.89 2847.70 S 4448,14 E 5281.60 S 57 22 E 100. 8650.42 5163.65 8544.42 2872.50 S 4479.88 E 5321.70 S 57 20 E 100. 8742.64 5202.14 8636.64 2897.87 S 4509.06 E 5559.97 S 57 16 E 100. 8834.69 5241.18 -872~.6~ 292-7.35 S -4534.70 E 5397.49 S 57 -9 E 100. 8926.91 5279.84 8820.91 2956.09 S 4560.57 E 5434.82 S 57 3 E 0°50 1o00 1 ~,5 0.46 10800. 23 30 S 41E 10900. 23 0 S 42 E 11000. 23 0 S 41E 11100. 22 30 S 46 E 11200. 22 0 S 44 E 100. 9018.62 5319.68 8912.62 2986~-t9 S 4586.73 E 5473.15 S 56 56 E 100. 9110.67 5358.74 9004.67 3015.22 S 4612.88 E 5510.92 S 56 50 E 100. 9202.72 5397.78 9096.72 3044.71S 4638.51E 5548.52 S 56 43 E 100. 9295.11 5436.01 9189.11 307t.30 S 4666.04 E 5586.12 S 56 39 E 100. 9387.83 5473.47 9281.83 3098.24 S 4692.06 E 5622.68 S 56 34 E 0.85 0.64 0.59 2.00 0.91 11300. 22 15 S 47 E 11400. 22 45 S 47 E 11500, 22 0 $ 45 E 11600. 21 0 S 46 E 11700. 19 45 S 46 E 100. 9480.38 5511.26 9374.38- 3124.07 S -4719.75 E 5660.02 S 56 30 E 100. 9572.60 5549.85 9466.60 3150.44 S 4748.04 E 5698.17 S 56 26 E 100, 9665.52 5587,29 7559,32 3176.93 S 4774,52 E 5734.89 S 56 22 E 100. 9758.68 5625.09 9652.68 3201.82 $--4800.30 E 5770.15 S 56 18 E 100. 9852.80 5656.85 9746.80 3225.30 S 4824.61 E 5803.40 S 56 14 E 1.16 0.50 1.07 1.07 1.25 MARATHON OIL CO. I.~OLLY VARDIN F'LTFM, WELL NO~ D-12RD (GMS) CO0~x INLE1, RENAl, ALASKA COMPUTATION TIME DATE 00:02:5& 30-SEF'-80 PAGE NO.', 5 TRUE ~'~EASURED DRIFI' DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLE~ DEF'TH ANGLE DIRECTION LENGTH DEP1H SECTION TVD C 0 0 R D I N A T E S ~ISTANCE [;IRECTION SEVERIT FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100F 11800. 18 0 S 47 E 11850. 17 30 S 47 E 100o 9947.90 5887.68 9841.90 ~246o~7 S 4847.21 E 5833o90 S 56 1I E 50~ 9995°59 5702.69 9889.59 ~256o63 $ 4858o21 E 5848.74 S 56 10 E 1.78 1o00 FINAL CLOSURE - DIRECTION; DISTANCE; S 56 DEGS ~ MINS 53 SECS E 5848.74 FEET /Ii Eastman/ Whipstock l A PETROLANE REPORT SUB-SURFACE DIREC TIONA L SURVEY RECEIVED S£P 5 0 1981 Naska Oil & Gas Cons. Commission _ Ma~ 011 Cb,mPanY CO. ANY Dolly Vardin ......... WELL NAME Cook,Inlet. K~nai Alaska LOCATION JOB NUMBER A980GO021 TYPE OF SURVEY Gyro Mult i-Sho t DATE ~i~-~1~ SURVEY BY Andy Hickman OFFICE Alaska MARATHON OiL CO, DOLLY VARDIN F'LTFM, WELL NO; D-12RD (GMS) COOK INLET, KENAI, ALASKA GMS, 0-11850MD, SURVEYOR; A HICKMAN, DATE RUN; 25-SEP-80 12 DEG A/U NO; 790, 70 DEG A/U NO; 411, CAMERA NO; 1095 .JOB NO: A980G0021 VERTICAL RECORD OF SURVEY ANGLE AVERAGING METHOD '~.ARAIHON OIL CO. DOLLY VARDIN PLTFM, WELL NO; D-12RD (GMS) COOK INLET, kENAI, ALASKA COMPUTATION lIME DATE 10~18~21 01-0Cr-80 PAGE NO. 1 TRUE ~EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEF'IH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITt FEET D M D FEET FEET FEET FEET FEET FEET D M [mG/100FT O, 0 0 0 O. 0,00 0000 -106.00 OJO0- - 0000 0.00 0 0 0,00 100, 0 15 N 12 W 100, 100,00 -0,19 -6000 0,21 N 0.05 W O,~ N 12 0 W 0.~5 200. 0 15 N 35 E 100. 200.00 -0.44 94.00 0.64 N 0.04 E 0.64 N 3 43 E 0.20 300. 0 15 N 5 W 100. 300.00 -0.67 194,00 ....... t,06-N ..... 0.15 E- 1,07 N 8 17 E 0.17 400. 0 15 S 81 E 100. 400.00 -0.66 294.00 1.36 N 0.47 E 1.44 N 19 12 E 500. 0 30 S 52 E 100. 499.99 -0.06 393,99 t.tO-N ...... t~07 E -1.54 N 44 20 E 0.31 600, 0 45 S 6 E 100, 599,99 0.99 493,99 0,14 N 1,60 E 1,61 N 84 50 E 0.54 700. 2 45 S 69 E 100, 699,94 4,03 593.94 2,28 S 3,46 E 4.14 S 56 39 E 2.50 800. 5 0 S 59 E 100. 799.71 10.36 .... 693~71 ...... 5~24-J:J ....... 9.54-E 10.88 S 61 13 E 2.34 900, 6 30 S 46 E I o O0 _ 899,---~_;~ 20,25 795,21 . 11,34 S 17,48 E 20 84 S 57 2 E 1 98 100. 1393.67 92.40 1287,67 1000. 6 30 S 47 E 1100. 6 45 S 46 E 1200. 8 15 S 51E 1300. 10 45 S 47 E 1400. 12 15 S 46 E E i 32.04 S 53 20 E E 43.51 S 51 31 E E 56.55 S 50 50 E E 73.05 S 50 25 E 70.76 E 92.95 S 49 34 E 0,11 0.28 1.63 2.58 1.51 1500. 14 15 S 43 E 1600. 16 45 S 46 E 1700. 19 0 S 52 E 1800. 22 30 S 56 E 1900. 24 45 S 56 E 100. 1491,00 100, 1587,37 100, 1682,54 100, 1776,05 100, 1867,67 115,31 1385,00 76.62 S 86.82 E 142.05 1481,37 95,68 S 105,55 E 172.58 1576,54 115,82 S 128,72 E 207,39 1670~05 -~36-~-6~ ..... 157,38 E 246,49 1761,67 159.05 S 190.61E 115.80 S 48 34 E 142.47 S 47 49 E 173.16 S 48 1E 208.42 S 49 2 E 248.25 S 50 9 E 2.11 2.62 2.90 2.25 2000, 27 30 S 55 E 2100, 30 30 S 57 E 2200. 32 0 S 57 E 2300, 34 0 S 60 E 2400, 36 30 S 58 E 100, 1957,46 100, 2044,92 100, 2130,41 100, 2214.28 100, 2295,94 E l= s 5o E 289.54 1851,46 1183.99 S °'~ , · 336,84 1938,92 211,10 S 267.09 E 340,44 S 51 41 E 387,25 2024,41 239,36 S 310,59 E 392.13 S 52 23 E 439,81 2108,28 267,82 S -357,03 E 446.32 S 53 8 E 495,38 2189,94 297,54 S 406,50 E 503,76 S 53 48 E 2,78 3,15 1.50 2,58 ~ 75 2500. 59 0 S 59 E 2600. 40 15 S 57 E 2700. 40 15 S 56 E 2800. 40 0 S 57 E 2900, 40 0 S 59 E 100, 2375.01 100. 2452,03 100, 2528,35 100, 2604,82 100, 2681.42 554,47 2269,01 616,17 2546,03 679.09 2422.55 741.84 2498,82 804.02 2575,42 329.53 S .... 458,70 E 363,33 S 512,79 E 398,99 S 566,67 E 434.56 S 620,41 E 468.62 S 674,92 E 564,80 S 54 18 E 628,46 S 54 41 E 693,04 S 54 51 E 757,46 S 54 59 E 821,66 S 55 14 E 2.57 1.79 0.65 0.69 1.29 'iARATHON Oil CO. £~OLL¥ VARDIN PL]F~, WELL NO: D-1.K[ (GMS) COOK INLET, KENAI, ALASKA COMPUTATION TIME DATE 10;18;21 01-0CT-80 PAGE NO. 2 TRUE ~EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N O U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVB C 0-0 R B I- N A T E S DISTANCE DIRECTION SEVERIT~ FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100FT 3000. 40 0 S 60 E 3100. 40 0 S 58 E 3200. 40 0 S 61E 3300. 40 0 S 62 E 3400. 40 0 S 63 E 3500. 40 30 S 62 E 3600. 40 45 S 63 E 3700. 40 30 S 62 E -3800. 40 0 S 62 E 3900. 40 0 S 64 E 4000. 40 0 S 65 E 4100. 39 30 S 66 E 4200. 39 0 S 65 E 4300. 38 45 S 64 E 4400. 38 15 S 64 E 100. 2758.03 865.76 2652.03 -501.24 S 730.30 E 885.77 S 55 32 E 100. 2834.63 927.65 2728.63 534.35 S 785.40 E 949.94 S 55 46 E 100. 2911.24 98~.39 2805.24 566.97 $ 840.79 E 1014.09 S 56 0 E 100. 2987.84 1050.46 2881.84 --577~5-$ ........ 8~7.28 E - 1078.09 S 56 20 E 100. 3064.45 1111.18 2958.45 627.33 S 954.29 E 1142.02 S 56 41 E 100. 3140.77 1172.21 3034.77 657.16-$'--I011~;60 E 1206.32 S 56 59 E 100. 3216.67 1233.71 3110.67 687.23 S 1069.36 E 1271.14 S 57 16 E 100. 3292.57 1295.21 3186.57 717.29 S 1127.11 E 1336.00 S 57 32 E 100~ 3368.89 1356.42 3262;8? ....... 747-o62-~--I184¥16 E 1400.42 S 57 44 E 100~,~.~.~445.49~ ~;416.95 3339.49 ,776.81 S 1241.43 E 1464.44 S 57 58 E 1 ~'-¢= = ~,64 1591 77 S 58 32 10~;~?-?>Z.676,42 15~;~ ~"Z~~~~,21 E 1 654 .59 S 58 48 E 100,'~ ~8~27~ .... 16~~ ~~~~~~~,86 E 1717,05 S 59 0 E 100. 3832.53 1711.48 3~6.53- 91'1~54',S 1527.81 E 1779.08 S 59 11 E 0.64 1.29 1.93 0.64 0...,44 0.82 0.70 0.70 0.50 1.29 0.64 0.81 0.81 0.68 0.50 4500, 38 0 S 65 E 4600. 37 45 S 67 E 4700. 37 30 S 64 E 4800. 36 45 S 66 E 4900. 36 15 S 66 E 100. 3911.20 1769.05 3805.20 938.12 S 1583.53 E 1840.56 S 59 21E 100. 3990.14 1825.70 3884.14 963.09 S 1639.62 E 1901.55 S 59 34 E 100. 4069.34 1882.24 3963.34 988.41S 1695.17 E 1962.29 S 59 45 E 100. 4149.07 1938.33 404J.07 I01-~;?~"~--15~49;87-~ 2022.40 S 59 55 E 100. 4229.46 1993.22 4123.46 1038.11S 1804.21E 2081.55 S 60 5 E 0.67 1.25 1.85 0.50 5000. 35 15 S 72 E 5100. 35 30 S 64 E 5200. 35 0 S 64 E 5300. 36 15 S 63 E 5400. 37 45 S 62 E 100. 4310.61 2045.88 4204.61 1059.05 S~ I858.76 E 2139.29 8 60 20 E 100. 4392.15 2098.49 4286.15 1080.74 S 1912.44 E 2196.68 S 60 32 E 100. 4473.82 2152.49 4367.82 1106.04 S 1964.31 E 2254.29 S 60 37 E 100. 4555.10 2207,17 4449.10 1132.03-S 2016.44 E- 2312.47 S 60 41 E 100, 4634.96 2264.01 4528.96 1159.81 S 2069.82 E 2372.62 S 60 44 E 3.64 4.64 0.50 1.38 1.62 5500. 40 0 S 60 E 5600. 40 15 S 61 E 5700, 40 45 S 59 E 5800. 40 15 S 58 E 5900. 40 30 S 58 E 100. 4712.82 2323.82 4606.82 1190.24-S .... 2124.71 E 2435.38 S 60 45 E 100. 4789.28 2385.39 4683.28 1221.98 S 2180.80 E 2499.83 S 60 44 E 100. 4865.32 2447.61 4759.32 1254.45 S 2237.05 E 2564,76 $ 60 43 100, 4941o36 2510.29 4835.36 1288o38-S---2292.42 E 2629.66 S 60 40 E 100. 5017.54 2572.96 4911.54 1322.71 S 2347.36 E 2694.37 S 60 36 E 2.58 0.69 1.39 0.82 0.25 ~:~,ARATHOtq OiL CO. ~IOLL_¥ VARDIN F'LIF'M, WELL NO: D l~f.,L (Gt~S) ~OOK INI. ET, KENAI, ALASKA COMPUTATION TIME DATE 10~18;21 Oi-OCT-80 PAGE NO. 3 TRUE ~EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT'_ FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100F7 6000. 39 45 S 58 E 6100. 39 15 S 56 E 6200. 39 0 S 58 E 6300. 38 45 S 58 E 6400. 39 0 S 57 E 100. 5094.01 2635.30 4988.01 1356.86 S~ 2402.01 E 2758.75 S 60 32 E 100. 5171.17 2697.11 5065.17 1391.50 S 2455.36 E 2822.24 S 60 28 E 100. 5248.75 2758.43 5142.75 1425.87 S 2508.28 E 2885.23 S 60 23 E 100. 5~26.60 2819.14 5220.60 14590t3-8--2561,50 E-- 2947,94 S 60-20 E 100. 5404.45 2880.00 5298.45 1492.85 S 2614.44 E 3010.63 S 60 16 E 0.75 1.37 1.29 0.25 6500. 37 45 S 57 E 6600. 38 0 S 54 E 6700. 37 45 S 55 E 6800~-~-37 ~0 $~55 E 6900. 37 15 S 53 E 7000. 37 0 S 54 E 7100. 37 0 S 53 E 7200. 37 0 S 52 E 7300. 37 0 S 50 E 7400. 37 15 S 51 E 100. 5482,85 2940.32 5376,85 1526,66 S--2666,50-E 3072.61 S-60 12 E 100. 5561.78 3000.33 5455.78 1561.44 S 2717.10 E 3133.80 S 60 7 E 100. 5640,72 3060.57 5534.72 1597.09 S 2767.08 E 3194.91 S 60 0 E 100~5720~18 3120.02 ~5614.18 1631.91 S -2816,80 E 3255.38-S 59 55 E 5693.92~ 667. S 2865 63 E 15 42 S 59 48 E 100~ 5799,9~.~179.33 ; 38 . 33 · 10~-~5959.51 3297 ~.9~.- 58..53 . 51 ~1739.08eS 53 E 3435.25 S 59 35 E 100~ 6039.38 335~;-~'~ 5~.~7~~~~ '~' 27 E 3494.98 S 59 28 E 100, ~119:,24~3417~O&~:~O~3~:2~Z';'~8~~"~"~ ~o04 E 3554.52 S 59 19 E 100, 6198,97 3476.91 6072,97 1851,9e.s 3103,61E 3614,i8 S 59 10 E 1.25 1.86 0.66 0.75 1.23 0.65 0.60 0.60 1.20 0.65 7500. 36 30 S 51E 100. 6278.97 3536.38 6172.97 1889.75 S 3150.25 E 3673.58 S 59 3 E 0.75 7600 MD INTERF'OLAI'ED SURVEY STATION 7600. 36 0 S 52 E 100. 6359.61 3594.91 6253.61 1926.56 S 3196.52 E 3732.21 S 58 55 E 7700. 35 30 S 53 E 100. 6440.77 3652.59 6334.77 1962.12 S 3242.88 E 3790.27 S 58 49 E 7800. 38 0 S 54 E 100. 6520.89 3711.49 6414.89 1997.71 S 3290.97 E 3849.85 S 58 44 E 7900. 39 30 S 51 E 100. 6598.88 3773.28 6492.88 2035.82 S 3340.63 E 3912.08 S 58 38 E 0.77 0.77 2.57 2.40 8000. 38 45 S 51 E 8100. 38 0 S 49 E 8200. 38 0 S 50 E 8300. 37 30 S 49 E 8400. 37 30 S 49 E 100. 6676,46 3835.82 6570.46 2075.53 S 3389.67 E 3974,63 S 58 31 E 100. 6754.85 3897.48 6648.85 2115.43 S 3437.23 E 4036.04 S 58 23 E 100. 6833.66 3958.69 6727.66 2155.42 S 3484.04 E 4096.87 S 58 15 E 100, 6912.73 4019.56 6806.73~- 2195.18 S 3530.59 E --4157.39 S 58 8 E 100. 6992.06 4080.13 6886.06 2235.11 S 3576.54 E 4217.51 S 58 0 E 0.75 1.45 0.62 0.79 0.00 8500. 39 15 S 52 E 8600. 39 0 S 57 E 8700. 38 45 S 55 E ~ ~o 60 S ~3624.44 E---4279.06 S 57 53 E 100. 7070.46 4141,73 6964.46 ~74. 100. 7148.03 4203.64 7042.03 2311.25 S 3675.81 E 4342.06 S 57 50 E 1000 7225.89 4264.87 7119.89 2346.34 S 3727.85 E 4404.79 S 57 49 E 2.56 3.16 1.28 ~AK'ATHON OIL CO. DOLLY VARDIN F'LTFh, WELL NO: fJ-12RD (GMS) COOK INLET, NENAI, ALASKA COMF'U]ATION TIME DATE 10:18;21 01-0CT-80 PAGE NO. 4 TRUE ~EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG T;EF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S D1SrANCE DIRECTION SEVERIT'~ FEET D M D FEET FEET FEET FEET FEET FEET D H DG/100F~ 8800. 38 30 S 59 E 8900. 38 0 S 55 E 9000. 39 30 S 58 E 9100. 41 0 S 57 E 9200. 41 15 S 57 E 100. 7304.01 4325.53 7198.01 2380.34 S 3780.20 E 4467.20 S 57 48 E 100. 7382.54 4385.68 7276.54 2414.06 S 3832.12 E 4529.11 S 57 47 E 100. 7460.53 4446.63 7354.53 2448.61 S 3884.31 E 4591.68 S 57 46 E 100. 7536.85 4509.28 74~0.85 248~2-S-- ~?~8.81 E 4656o~0 S 57 46 E 100. 7612.18 4573.18 7506.18 2519.14 S 3993.97 E 4722.06 S 57 46 E 2.51 2.53 2.40 1.6,.3 9300. 39 45 S 56 E 9400. 38 0 S 55 E 9500. 30 45 S 54 E 9600. 28 15 S 54 E 9700. 27 30 S 54 E 9800. 26 45 S 55 E 9900. 26 30 S 56 E 10000. 25 15 S 52 E 10100. 25 0 S 51 E 10200. 25 15 S 52 E 100. 7688.22 4636.42 7582.22 2554-.99 S-~-4048.12 E 4786.99 S 57 45 E 100. 7766.07 4697.77 7660.07 2590.54 S 4099.85 E 4849.70 S 57 43 E 100. 7848.61 475~.17 7742.61 262~.~2 S 4145.81E 4906.08 S 57 41E 100. 7935.65 4801.56 7829.65-~ 265~27-S' 4185.65 E 4955.22 S 57 38 £ 100~ ..... ~024.0~,~,~A847~50 7918.04 2679.75 S 4223.48 E 5001.88 S 57 36 E 10~"~811~.0~O''~ ~ ~' ~ ~ ~ ~ '~'~'~ '~ ~48~2.~_~ ~0~~ ~~.59 E 5047,41 $ 57 ~5 E 10 8202.44 49a6e04-~ mo~6.44 ,2 73 :1. .6~1~ $~__ ,~,~_~ __ ~z~l~"'53 E 5092.19 $ 57 34 E 10~i~292,41 4978,.~?:$I'~'~~'~2~~~ ~083 E 5135,75 S 57 32 E 100, 8473,4? ~062,~ 8367,4? 2810,12 S 439~.29 E 5220,21 S 57 26 E 1,65 1,86 7.27 2.50 0.75 0.88 0.51 ~ 15 0.49 0.49 lOJO0. 24 45 S 52 E 100. 8564,12 5104.77 8458,12 2836.14 S 4432.59 E 5262.28 S 57 23 E 10400, 23 45 S 52 E 100, 8655.30 5145,37 8549,30 2861,43 S 4464.96 E 5303,17 S 57 21 E 10500, 22 45 S 49 E 100, 8747,18 5184,54 8641,18 2886,54 S 4495,42 E 5342,37 S 57 18 E 10600, 23 0 S 41 E ~ ~100, 8839~51 5223,3? 87JJ',JI- '29I'4';02-~S-'4522,91 E 5380,-J5 'S 57-I2 E 10700, 22 45 S 42 E 100, 8931,45 5262,24 8825,45 2943,14 S 4548,66 E 5417.79 S 57 6 E 0,50 1000 0.46 10800, 23 30 S 41 E 10900, 23 0 S 42 E 11000, 2~ 0 S 41E 11100. 22 30 S 46 E 11200, 22 0 S 44 E 100. 9023.41 5301,50 8917.41 2972,55 S 4574,69 E 5455.62 S 56 59 E 100, 9115.29 5340.95 9009.29 3002,12 S 4600.84 E 5493.68 S 56 53 E 100. 9207.34 5380,00 9101,34 3031.38 S 4626,73 E 5531.36 S 56 46 E 100. 9299.56 5418.68 9193.56 3059,43 S 4653.35 E 5569.01 S 56 41E 100. 9392,12 5456.52 9286,12 3086,21 S 4680,13 E 5606,09 S 56 36 E 0.85 0,64 0.39 2,00 0.91 11300. 22 15 S 47 E 11400. 22 45 S 47 E 11500. 22 0 S 45 E 11600. 21 0 S 46 E 11700. 19 45 S 46 E 100, 9484.75 5494,16 9378.75 3112,60 S 4706,99 E 5643.06 S 56 31 E 100. 9577,14 5552.35 9471,14 3138.70 S 4734.98 E 5680.80 S 56 28 E 100. 9669.61 5570,38 9563.61 3165,15 S 4762.36 E 5718.24 S 56 23 E 100. 9762.65 5607.00 9656.65 3190.84 $ 4788.50 E 5754.23 S 56-19 E 100. 9856.40 5641.78 9750.40 3215.02 S 4813.55 E 5788.49 S 56 16 E 1.16 0.50 1.07 1,07 1,25 MARATHON OIL CO. ~,~ULLI' VARDIN PLTFM, WELL NO.~ D-12RD (GMS) ~,OOh, INLET, KENAI, ALASKA COMPUTA¥ION TIME DATE 10;18~21 OI-OCT-80 PAGE ~0. 5 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R-D I-N A T E S DISTANCE DIRECTION SEVERITY FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100FT 11800~ 18 0 S 47 E 100. 9951.02 5674°08 9845.02 32~7o2~$- 4837o01 E 5820o~7 S 56 12 E 11850. 17 ~0 S 47 E 50. 9998.64 5689.29 9892.64 3247.69 S 4848.16 E 5835o42 S 56 11 E FINAL CLOSURE - DIRECTION~ S 5& DEGS 10 HINS 58 SECS E DISTANCE; 58J5.42 FEET 1.78 1.00 Check Form for timely cc~pliance with our regulations. Operator, Well Name and Number Completion Report Well History Reports and Materials to be received by: ,//'- ~- ~ D~te Required Samples Mud Log Core Chips Date Received Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Digitized Log Data Yes Yes Remarks , OK' Document Transmittal Un,on 0~1 Company of Ca ta unlen DATE SUBMITTED ¸[TO H. W. Ku§ler J^~laska O&G Cons. Comm. J 3001 Porcupine Drive Anchorage, ak 99504 TRANSMITTFNG THE FOLLOWING FROM R. C. Warthen Onion Oil company PO Box 6247 ELPHONENO__. ncSorage, AK 99502 ENG 1 ENG 3 ENG TBU D-12 RD ;-GG 2", 5" Ii netic Tape #10707, 6lO10 LIS Format Printout FORM I-2M02 (REV 11-72) PRINTED IN U 5 A Form No. P-4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE ( 5. APl NUMERICAL CODE 50-733-20142-01 MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS REV. 3-1-70 .e OTHER OIL ~ GAS WELL WELL 2. NAME OF OPERATOR Un ion Oil Company of California* 3. ADDRF-~:$ OF OPERATOR P. O. Box 6247, Anchorage AK 99502 4. LOCATION OF WELL Leg B-l, Cond #10, Dolly Varden Plat~rm" 678'FSL, 1217'FWL, Sec 6-8N-13W-SM~-~- 6. LEASE DESIGNATION AND SERIAL NO. ADL-18729 7. IF INDIAN'ALOTTEE OR TRIBE NAME & UNIT FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. TBU D-12RD 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC. T. R. M. (BOTTOM HOLE OBJEC~iVE) , Sec. 8, T8N, R13W, SM 12. PERMIT NO. 80-82 13. REPORT TOTAL D~-I'IH AT END OF MONTH, CHANGES ll~![~ '~" ' 1~ ' ~IZE, CASINO AN cEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USEI~ PERFORATIONS, TESTS AND RESULTS FISHIN~, ]O~S. II, INK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. SEPTEMBER REPORT OF DRILLING OPERATIONS 09-01 Milled section from 9397'-9403'. Circ & POH. Tstd BOPE. Staged in hole w/ OE 9-5/8" csg scraper to 9360' rev metal cuttings from hole. POH. 09-02 Fin POH. RIH w/ section mill #5. Milled section from 9403'-9406'. POH. RIH w/ section mill #6. Milled section from 9406'-9416'. ( Presently have 51' section cut from 9-5/8" csg.) 09-03 09-04 -- POH. RIH w/ OE csg scraper. Rec circ to 9463', cleaning metal cuttings from hole. Circ long way, reducing visc of mud to 65 sec. POH. RIH w/ OEDP to 9458'. Placed 110-sk CI G cmt plug from 9458'-9250'. POH. POH. WOC. RIH w/ 8-1/2" bit. Tagged firm cmt @ 9313'. Drld hard cmt to 9370'. C&C mud. 09-05 9438'TD 09-06 9512'TD POH. Installed seals in hydromatic brake. PU DD & direc BHA. RIH w/ Eastman steering tool. Orientd BHA. Direc drlg 9370'-9438'. POH w/ steering tool. Fin RD steering tool & Dialog. POH w/ DP. RIH w/ new bit to 9438'. Press fm to mud equiv of 13.6 ppg. Drld 9438'-9512'. POH. RIH w/ new bit. 09-07 9768'TD Fin RIH w/ bit #2. Reamed 9365'-9512'. Drld 9512'-9720'. Circ & surv. POH. RIH w/ bit #3. Drld 9720'-9768'. *Marathon Oil Company - Sub-Operator oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. September Report of Drilling Operations Well TBU D-12RD Page 2 09- 08 9936 ' TD 09-09 10, IO0'TD 09-10 10,415'TD 09-11 10,538'TD 09-12 10,748'TD 09-13 10,834'TD 09-14 11,170'TD 09-15 11,445'TD 09-16 11,630'TD 09-17 11,945'TD 09-18 12,050'TD 09-19 12,050'TD 09-20 12,050'TD 09-21 12,050'TD Drld 8-1/2" hole 9768'-9920'. Circ & surv. Drld 9921'-9936'. POH LD BHA. PU DD & RIH. Cut & slipped drlg line. Worked tools to btm. RIH w/ steering tool. Oriented DD & drld from 9936'-9996'. POH. Tstd BOPE. RIH w/ bit #5. Reamed rat hole 9936'-9996'. Drld 9996'-10,100'. Drld 10,100'-10,230'. POH. RIH w/ bit #6. Drld 10,230'-415'. Drld 10,415'-10,455'. POH. RIH w/ DD to build angle. Direc OK. Could not build angle w/ various BHA. RU & RIH w/ Eastman steering tool. Oriented steering tool & DD 10,455'-526'. POH w/ steering tool. Found that connection above mule shoe on steering tool had become loose. Steering tool had malfunctioned. RIH w/ new steering tool. Oriented tool & DD from 10,526'-538'. DD from 10,538'-553'. POH. RIH w/ bit #8. Drld 10,553'-748'. Circ & surv. Made 15-std short trip. Circ. CBU. POH. RIH w/ bit #9. Drld 10,748'-834'. POH. RIH w/ bit #10 to 10,629'. Reaming to btm. Reamed 10,629'-10,834'. DRId 10,834'-11,043'. Made lO-std short trip. DRId 11,043'-11,170'. Drld 11,170'-11,415'. POH. RIH w/ bit #11. Ream 11,090'- 11,415'. Drld 11,415'-11,445'. Drld 11,445'-620'. POH. Tstd BOPE. RIH w/ bit #12. Drld 11,620'-11,630'. DRId 11,630'-945'. Projected TD is 12,050'. Drld 11,945'-12,050'. Made 30-std short trip. Circ & POH. RU Schl for open hole logs. SChl ran GR/SP/DIL, DIL/BHC, & FDC/CNL logs. Prep to run RFT. R IH w/ RFT. Tool stuck after one sample. Failed to pull tool loose. RU stripping eqpmt & RIH w/ DP stripping over WL. Tagged RFT fish @ 11,769' & pulled it into grapple. Prep to pull WL out of rope socket. Pulled WL out of rope socket of RFT tool. POH w/ WL. POH w/ DP & rec RFT tool. RIH w/ DP to !?~0~0'. Had 4' of fill. C&C hole & mud for 7" Inr POH RU & RIH w/ ~'~' 29# N-80 STATE OF ALASKA ALASKA{" ~ AND GAS CONSERVATION C(~.,MISSION MONTHLY REPORT OF DRILLING' AND WORKOVER OPERATIONS !1 Drdl,ngwell~ Redrill Workover operation [] 2 Name of operator Union Oil Company of California* 3 Address P. O. Box 6247, Anchorage AK 99502 4 Location of Well at surface Le9 B-l, Cond //10, Dolly Varden Platform 678'FSL, 1217'FWL, Sec 6-SN-13W-SM 5 Elevat,on ~n feet (~nd~cate KB, DF, etc ) 6 Lease Designation and Serial No 106.2 ' KB AD L- 18729 7 Permit No 80-82 8 APl Number 50- 733-20142-01 9 Umt or Lease Name Tradinq Bay Unit 10 Well No D- 12RD 11 Fmld and Pool McArthur River Field For the Month of. OCTOBER ,19 80 '12 Depth at end of month, footage drilled, fishing jobs, dIrectional drilling problems, spud date, remarks 12,050'MD No footage drilled. 10,188'TVD 13 Casing or I~ner run and quantities of cement, results of pressure tests NA '14 Coring resume and brief description NA 15 Logs run and depth where run NA 1 6 DST data, perforating data, shows of H2S, mmcellaneous data Perfd Hemlock, Bench 4' 11,496'-516'DIL 11,530'-570'DI L 17 I hereby certify that the foregoing ~s true and correct to the best of my knowledge *Marathon Oil Company - Sub-Operator SIGNED TITLE DATE NOTE--Report on th~s form ~s required for each calendar month, regardless of the status of operations, and must be flied in duphcate w~th the Alaska Od and Gas Conservation Commission by the 15th of the succeeding month, unless otherwme d~rected Form 10-404 Submit m duphcate Rev 7-1-80 Form No P~4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA · OIL AND GAS CONSEFiVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS !. WELL WELL OTHER 2. NAME OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage AK 99502 4. LOCATION OF WELL Leg B-l, Cond ~10, Dolly Varden Platform~ 678'FSL, 1217'FWL, Sec 6-8N-13W-SM 5. APl NUMERICAL CODE 50-733-20142-01 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18729 7. IF INDIAN-ALO'VrEE OR TRIBE NAME __ 8. UNIT FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. TBU D- 12RD 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC. T IL M. (BOTTOM HOLE OBJECTIVE) Sec. 8, T8N, R13W, SM 12. PERMIT NO. 80-82 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. SEPTEMBER REPORT OF DRILLING OPERATIONS 09-01 Milled section from 9397'-9403'. Circ & POH. Tstd BOPE. Staged in hole w/ OE 9-5/8" csg scraper to 9360', rev metal cuttings from hole. POH. 09-02 Fin POH. RIH w/ section mill #5. Milled section from 9403'-9406'. POH. RIH w/ section mill #6. Milled section from 9406'-9416'. ( Presently have 51' section cut from 9-5/8" csg.) 09-03 09-04 POH. RIH w/ OE csg scraper. Rec circ to 9463', cleaning metal cuttings from hole. Circ long way, reducing visc of mud to 65 sec. POH. RIH w/ OEDP to 9458'. Placed 110-sk CI G cmt plug from 9458'-9250'. POH. POH. WOC. RIH w/ 8-1/2" bit. T.__gged firm cmt(@ 9313'.~~ Drld hard cmt to 9370'. C&C mud. 09-05 9438'TD 09-06 9512' TD POH. Installed seals in hydromatic brake. PU DD & direc BHA. RIH w/ Eastman steering tool. Orientd BHA. Direc drlg -9438'. POH w/ steering tool. Fin RD steering tool & Dialog. POH w/ DP. RIH w/ new bit to 9438'. Press fm to mud equiv of 13.6 ppg. Drld 9438'-9512'. POH. RIH w/ new bit. 09-07 9768'TD Fin RIH w/ bit #2. Reamed 9365'-9512'. Drld 9512'-9720'. Circ & surv. POH. RIH w/ bit #3. Drld 9720'-9768'. *Marathon Oil Company - Sub-Operator 14. ! hereby cer~fy~at the foreg~ ~'~ ~l~cotrect SIGN~_,'Z/_f,'~'...~, ~'_~~_/~?t~'l~tt~ Dist. Drlg. Supt. DATE 10/17/80 ! NO~'[~eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. ( September Report of Drilling Operations Well TBU D-12RD Page 2 09-08 9936 ' TD 09-09 IO,IO0'TD 09-10 10,415'TD 09-11 10,538'TD 09-12 10,748'TD 09-13 10,834'TD 09-14 11,170'TD 09-15 11,445'TD 09-16 11,630'TD 09-17 11,945'7]] 09-18 12,050'TD 09-19 12,050'TD 09-20 12,050'TD 09-21 12,050'TD Drld 8-1/2" hole 9768'-9920'. Circ & surv. Drld 9921'-9936'. POH LD BHA. PU DD & RIH. Cut & slipped drlg Iine. Worked tools to btm. RIH w/ steering tool. Oriented DD & drld from 9936'-9996'. POH. Tstd BOPE. RIH w/ bit #5. Reamed rat hole 9936'-9996'. Drld 9996'-10,100'. Drld 10,100'-10,230'. POH. RIH w/ bit #6. Drld 10,230'-415'. Drld 10,415'-10,455'. POH. RIH w/ DD to build angle. Direc OK. Could not build angle w/ various BHA. RU & RIH w/ Eastman steering tool. Oriented steering tool & DD 10,455'-526'. POH w/ steering tool. Found that connection above mule shoe on steering tool had become loose. Steering tool had malfunctioned. RIH w/ new steering tool. Oriented tool & DD from 10,526'-538'. DD from 10,538'-553'. POH. RIH w/ bit #8. Drld 10,553'-748'. Circ & surv. Made 15-std short trip. Circ. CBU. POH. RIH w/ bit #9. Drld 10,748'-834'. POH. RIH w/ bit #10 to 10,629'. Reaming to btm. Reamed 10,629'-10,834'. DRId 10,834'-11,043'. Made lO-std short trip. DRId 11,043'-11,170'. Drld 11,170'-11,415'. POH. RIH w/ bit #11. Ream 11,090'- 11,415'. Drld 11,415'-11,445'. Drld 11,445'-620'. POH. Tstd BOPE. RIH w/ bit #12. Drld 11,620'-11,630'. DRId 11,630'-945'. Projected TD is 12,050'. Drld 11,945'-12,050'. Made 30-std short trip. Circ & POH. ~op en-nol-e logs. SChl ran GR/SP/DIL, DIL/BHC, & FDC/CNL logs. Prep to run RFT. RIH w/ RFT. Tool stuck after one sample. Failed to pull tool loose. RU stripping eqpmt & RIH w/ DP stripping over WL. Tagged RFT fish @ 11,769' & pulled it into grapple. Prep to pull WL out of rope socket. Pulled WL out of rope socket of RFT tool. POH w/ WL. POH w/ DP & rec RFT tool. RIH w/ DP to 12,050'. Had 4' of fill. C&C hole & mud for 7" Inr. POH. RU & RIH w/ 7", 29#, N-80 csg. September Report of Dr il( ~g Operations TBU Well D-12RD P~ge 3 09-22 12,050'TD 09-23 12,050'TD 09-24 12,050 ' TD 09-25 12,050'TD 09-26 12,050' TD 09-27 12,050'TD 09-28 12,050'TD 09-29 12,050'TD 09-30 12,050'TD Fin RIH w/ 7" Inr to 12,031'. Dropped ball & set BOT Inr hgr. HOWCO cmtd 7" Inr w/ 300 sx CIG w/ 1% CFR-2 & 0.3% Halad 22A followed by 700 sx CIG w/ 1% CFR-2, 0.3% Halad 22A, 3% KCI, & 1/4 #/sk flocel. PU to 8159' & rev out 150 sx. CIP @ 6:30 PM, 09-21-80. C&C cmt contaminated mud. POH w/ DP. Top of lnr ~ 9137', FC @ 11,904', CS ~ 11,987' btm of FS @ 12,031'. WOC. Tstd BOPE. RIH w/ DP. Tagged cmt @ 8540'. Started drlg cmt. Drld firm cmt to top of 7" Inr @ 9137'. POH. RIH to 9137' PU 88 jts 3-1/2" DP. Drld cmt 9137'-9169'. RIH & tagged cmt @ 11,731'. Drld firm cmt to 11,802'. Drld firm cmt to FC @ 11,904'. Tstd 9-5/8" csg & 7" Inr to 2500#--0K. POH. RU DA & ran CBL/GR. Good bond across Hemlock. Fair to good bond in Inr lap. RU Eastman to run gyro surv. Fin running gyro surv. RD DA. RIH w/ bit & scraper to top of 7" Inr @ 9137'. Circ. POH. RIH w/ HOWCO DST tools to dry test 7" Inr lap. Set pkr @ 9103' w/ 2000' of WC. Opened tool @ 4.'45 AM, 09-26-80. Recorded 1 hr flow period. SI tool @ 5:50 AM for 2 hr SI period. Fin dry test of Inr lap. No leak. POH w/ DST tools. Tstd BOPE. RIH w/ bit & scraper to PB @ 11,904'. Displ mud w/ FIW. POH. RU DA. RIH w/ JB & GR to 11,600'. RIH w/ 7" Otis WD pkr w/ seal bore est. Pkr would not go past top of Inr. POH. Added more bend to btm of seal bore ext. RIH w/ Otis WD pkr. Could not get Otis WD pkr into 7" Inr. POH. Modified btm of pkr seal bore ext. RIH w/ pkr--still could not get pkr into 7" Inr. POH. RIH w/ GR & JB to 11,600'. Went into top of Inr @ 9137' w/ JB & GR 3 times. First 2 times did not touch anything; third time set dwn but fell on thru. Cut full mule shoe on btm of seal bore ext. RIH w/ pkr. Seal bore ext went into top of line but pkr body hung. Worked pkr past top of Inr & RIH to 10,560'. PU to log clr & pkr &setting tools stuck @ 10,560'. Set pkr. Unable to pull setting tool from pkr. Pulled out of rope socket. POH w/ WL. RD DA. MU OS w/ 1-3/4" grapple on DP & RIH. Latched fish & pulled free w/ 40,000#. POH. Had 5000# drag on 1st 2 stds. Fin POH. Rec pkr setting tool. RIH w/ mill over shoe & tagged Otis WD perm pkr @ 10,586'DPM. Miolled to 10,588'--unable to mill any deeper. POH. RIH w/ mill over shoe #2. STATE OF ALASKA ALASK,~ '~IL AND GAS CONSERVATION (~ ,v~MISSION MONTHLY REPOR'I OF DRILLING AND WORKOVER OPERATIONS or,~i,ng we~l ]~( Redri I I Workover operation [] 2 Name of operator Union 0il Company of California* 3 Address P. 0. Box 6247, Anchorage AK 99502 4 Location of Well at surface Leg B-l, Cond #10, Dolly Varden Platform 678'FSL, 1217'FWL, Sec 6-8N-13W-SM 5 Elevatlonln feet (,ndmate KB, DF, etc) I 6 LeaseDes~gnatlonandSer~al No 106.2'KBI ADL-18729 7 Permit No 80-82 8 APl Number 50- 733-20142-0 9 Un,t or Lease Name Trading Bay Unit 10 Well No D- 12RD 11 F~eld and Pool McArthur River Field For the Month of OCTOBER ,19 80 12 Depth at end of month, footage drdled, fishing jobs, d~rect~onal drdhng problems, spud date, remarks 12,050'MD No footage drilled. 10,188'TVD 13 Casing or liner run and quant~tms of cement, results of pressur9 tests NA 14 Coring resume and brief description NA 15 Logs run and depth where run NA 6 DST data, perforating data, shows of H2S, mmcellaneous data Perfd Hemlock, Bench 4' 11,496'-516'DIL 11,530'-570'DIL 17 I hereby certify that the foregoing is true and correct to the best of my knowledge *Narathon 0il Company - Sub-Operator SIGNED TITLE DATE. NOTE--Report on th~s form is required for each calendar month, regardless of the status of operat,ons, and must be filed m duphcate w~th the Alaska Od and Gas Conservation Commmslon by the 15th of the succeeding month, unless otherwise d~rected Form 10-404 Submit irt duphcate Rev 7-1-80 TUBI,NG/CASING DETAIL WELL NO.: DATE: tern Descr i pt i on Set Jts Size Wt !Thread Grade Range Cor~c~ i t i on Lengt_h .From To ' I II ~ 3 vz" ~2~ ~.,. /.'-~ Z + 2~t.,7o ql ~0 ........ .., ... Og~.~ OC g,.~,q~ r,'e~ev~61~ g, It wlv~ ~. /B ._3 16.3¢ ..... __ y o............. : ........ o. ~3 ,3 ~ ~ ~ ,._ ..... ~ ~ - ~ ..... ,,. , ........ ~. 2~ ~ ~ ~ . ~v ,~ ~o ,,. 3. i,~l Z q ~ ¢. O~ ,. ~ ~ 2~ B~H ~'E~ I ~ ~a7.~3 Z ........ ~2~ 8V~ ~-~0 ~.o ~. ~ qlL~.7L ......... , ........ .... ? 2~ g~ W. B6 ~.:.~ ..... 3.13 ql~o.O¢ ........ ~3 ~ 2 e B~ ~ ~-Bo ! ~3o2 ~* ql4q. ~1 .~, .. ...... ~2~ ¢~H /, ic pu,o ~ ~ ........... ,, , C-L /~ ~/ 3 - So,,;~ cs c'Zx~ ~ I ~. /~ 3-q71.7L ................... . ~ ~ ? Z~ ,qu'i/- '/5, ~: i /1'/7. ~ 0 5~1 63 5ff .... ~ ......................... TUBII~G/CASING DETAIL WELL NO.: O- /2 £0 DATE: I0 / Z / g'~ BY' 7 8 ~o;~,-/ Item Des:riotion Set I0. [ Ets Size ' wt Thread Grade Range ' Condition L.ength From To _ 3 '~z" ~. 2 ~ g~/ /v- S0 ?v? q, ~ ~ (~ ~' ~ ~ ~ I ~1 9.~~ 8~ ~-~o I ~o. Z7 ~Z~. ~ ~ B ~ za 8~ ~ ~-8o I ~6. B~ 7~88 . , , _ C-~ ~ ~ ~ 6o~me a~ c~ ~: I ~. /~ ~q90.7q ................. _ ., ~, 2~ ~v~ ,~'~0 p~ 9, Iq ~qq~.9o _._ ...... 9.2~ ~v~ /~-ea ~? _., ~. ~ eoe3. ~ ,, 17 ~.Z~ ~~ ~.8o I ~/ 8. Z~ 9 l/Z, o~ ............ , -~ ,?.2d ~~ ~.~0 ~vp ~1 7V 9~3o. 31 ~ Z~ 8~ N-S~ j y~p _ , ~ /~ Ioo,3 ~g ........ ~ ~ ,, . .. ? Z~ ~ ~-~c j,,~ 3 ~ff Ioozq.B~ Io ~ Z~ o~N h,-~ I 3o~.z6 Ioozg fo TUBI,I,IG./CAS I NG DETAI L '% WELL NO. DATE BY: Item Description Set 'ts Size Wt Thread ..... G.r,ad_ eRange Condition Length From To · , .,. 9.,z''a' ~,.,W W...-[~a ?,,,,o 3, ~3 _'~_ ~ 9' 2:P-'- (~u /'/ ..//-6~D .... · I ..2'7~.,.q'0 t03'-~7.~7 .. 2 " f/ ,u . ga ........ /2 ! o. 1'7 . (~Z,,'t'f ~'~ /./ -~,~m," ¢:,~ ¢z,,~ .ii ~ fro 1,5- 1062-9 Z5 , 9. 2 ~ ~.,,..// W.....-~o.~,~,~ ... 3. ~ c I o G3¢,~/ ~ ~ 2'" K3~, -/-/ ,4/-£0 / 279,3 g IOG3g Go ........................ ? 2~' 8~,'/-/ /l/-?o ,.,~q,~ .... ~-. o t3. .. 1o~ ........ , I °/.Z~ ~,,-// ,A,/-~,O I 30.3"7 ) o f133.3,F .................. 0 ¥,s Xt~ s/-.ece 3.9 6 ....... ~3 Z~ 8,,-/-/ W-~O ?;,,~ '-/. 97 t C' e73.8G .... I ,~).,~' f3,,¢/ /v.8o I ~o,9 S toq 78.83 ~ .......... · 9 2 *' ~u,4- /t' "'" ..... · '" ....... -:? £,,.:',~ 3-. a ~ II 0o'~.'7 fo ........ / o~ ~ --/:or-- , o. 9 7 I I o ~H. ................... , ............ .socl~ . ~3. ~ ¢ I! olU. 8 I ....... p , ~(0 8.~,-,a ~ -..~ ' O. es'- IlO,Zl3.q7 ........................ 0 ~rts ~- ^,,,pie. _ t. ill 11037. ~7 ................... I ~ Zf ~,,,-FJ l.u-~(,, I :'0.: G ................. -' t U,., c~7 ,*' /: ,r/'~ 0 7S" IlOGq.$7 tlOTO ~?_ ...................... , -- . - ~CASING DETAIL WELL NO.: DATE: BY: Item Descri tion ~- /~ ~, ~' / - Set _Jts Size Wt Thread ,, Grade Range Condition Length From To -- J 8OT 7* dgd ~:~//~F' 0 ~Z qt~l. 97 9172.,79 ~ 7" ,,, 2 0~ ~ //-~ ~ .... I ~1. oo 119o~ q[ 119 ~6 ~i ,, , ,, ~ , , ,., ., ,.. ,.. , , ........ , , ,, , , ~ , , ,, .,. , , , ..... . , ,,., , ........ ~, ,,., . , ...... Remarks: FORM 484 REV 3--6~ ~ DA~E 0~tober 13, 1980 M'..RATHON OIL CORR,-ANY hISTORY Of OIL OR gAS Well FIELD McArthur Ri ver BLOCK WELL NO. D-12RD LEASE Trad lng Bay Unit SEC. 8 PARISH Kenai Pen ~ n- Alaska sula Borough STATE COUNTY MEASUREMENTS TAKEN FROM TWP 8N R. 13W 106 2' · , ELEV IToP OF OIL STRING ~ ELEV.~ TOP OF ROTARY TABLE . ELEV.~ GRD OR MAT ELEV. KB HISTORY PREPARED BY TITLE L. G. Haywood Secretary It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1980 · 08-13 08-14 08-15 08-16 08-17 08-21 08-22 08-23 08-24 08-25 08-26 08-27 12,381 'TD 12,299' PBTD 12,381 'TD 12,299 ' PBTD 12,381 ' TD 12,299'PBTD 12,381 'TD 12,299 ' PBTD 12,381 ~TD 12,299 ' PBTD 12,381 'TD 2,299'PBTD 2,381 ' TD 2,299' PBTD 2,381'TD !12,299'PBTD 12,381'TD 12,299'PBTD 12,381'TD 12,299'PBTD 12,381'TD 11,450'PBTD iO,050'PBTD WELL HISTORY - TBU WELL D-12RD (Marathon AFE 4674) Moving eqpmt from Rig 77 to Rig 76 for D-12RD. Moving eqpmt & RU. Working on drlg eqpmt & RU. RU. RU. Pul led BV. Disconnected GL line. Began bleeding gas off csg annls. Fin bleeding CP off. Loaded tbg & csg w/ FIW. Circ dwn tbg & up csg--tbg to csg leak is apparent. Displ FIW w/ gel led mud & circ. Set BPV in tbg hgr. ND tree. NU BOPE & tstd same. Circ & POH w/ 4-1/2" x 3-1/2" tbg. Found btm GLV washed out. Tstd BOPE; Began RIH w/ 6" bit & scraper for CO trip to top of pkr. Fin RIH. Tagged pkr @ 11,430'. Had 6' of fill on top of pkr. POH. PU pkr mill, JB, jars, & bumper sub. RIH to pkr @ 11,430'. Milled 7" pkr & pushed to 12,105'. C&C mud. POH. RIH w/ OEDP to lay cmt plug opposite perfs. Fin RIH w/ OEDP to 12,102'. Placed 120-sk CIG cmt plug from 12,102'-11,450' (Hemlock perfs @ 11,515'-12,096'). POH. PU 9 - 6-1/4" DC & bit & scraper. RIH to 10,250'. Could not circ. POH w/ wet string. LD plugged DC. RIH w/ bit & scraper. Fin RIH w/ bit & scraper to 10,250'. Circ & POH. RU DA & RIH w/ GR & JB to 10,200. POH. RIH w/ 9-5/8" Halliburton EZSV BP & set @ 10,050'. POH. RtH w/ CBL & logged interval 9200'-9650'. Good bond thruout interval. Better bond ~ 9308'-9390' & 9520'-9600'. Well History - TBU Well D-12RD Page 2 08-28 IO,050'PBTD 08-29 08-30 08-31 09-01 09-02 09-03 09-04 09-05 9438 ' TD 09-06 9512'TD 09-07 9768 ' TD 09-08 9936'TD 09-09 10, IO0'TD 09-10 10,415'TD 09-11 10,538'TD RD DA. MU Servco section mill & RIH to 9365'. Cut 9-5/8" section from 9365'-9374'. Milled section in 9-5/8" csg from 9374'-9375'. Circ & POH. RIH w/ section mill #2. Milled 9-5/8" csg from 9375'-9387'. POH to 9340'. Circ to clean hole. POH LD section mill. Staged in hole w/ OEDP, rev circ in an attempt to remove metal cuttings from hole--very little recovery. POH. RIH w/ section mill #3. Milled from 9387'-9389'. Milled section from 9389'-9391'. Circ & POH. Staged in hole w/ open-ended 9-5/8" csg scraper to 9360', rev metal cuttings from hole. POH. RIH w/ section mill #4. Milled from 9391'-9397'. Milled section from 9397'-9403'. Circ & POH. Tstd BOPE. Staged in hole w/ OE 9-5/8" csg scraper to 9360', rev metal cuttings from hole. POH. Fin POH. RIH w/ section mill #5. Milled section from 9403'-9406'. POH. RIH w/ section mill #6. Milled section from 9406'-9416'. ( Presently have 51' section cut from 9-5/8" csg.) POH. RIH w/ OE csg scraper. Rec circ to 9463', cleaning metal cuttings from hole. Circ long way, reducing visc of mud to 65 sec. POH. RIH w/ OEDP to 9458'. Placed 110-sk CI G cmt plug from 9458'-9250'. POH. POH. WOC. RIH w/ 8-1/2" bit. Tagged firm cmt @ 9313'. Drld hard cmt to 9370'. C&C mud. POH. Installed seals in hydromatic brake. PU DD & direc BHA. RIH w/ Eastman steering tool. Oriented BHA. Direc drld 9370'-9438'. POH w/ steering tool. Fin RD steering tool & Dialog. POH w/ DP. RIH w/ new bit to 9438'. Press fm to mud equiv of 13.6 ppg. Drld 9438'-9512'. POH. RIH w/ new bit. Fin RIH w/ bit #2. Reamed 9365'-9512'. Drld 9512'-9720'. Circ & surv. POH. RIH w/ bit #3. Drld 9720'-9768'. Drld 8-1/2" hole 9768'-9920'. Circ & surv. Drld 9921'-9936'. POH LD BHA. PU DD & RIH. Cut & slipped drlg line. Worked tools to btm. RIH w/ steering tool. Oriented DD & drld from 9936'-9996'. POH. Tstd BOPE. RIH w/ bit #5. Reamed rat hole 9936'-9996'. Drld 9996'-10,100'. Drld 10,100'-10,230'. POH. RIH w/ bit ~6. Drld 10,230'-415'. Drld 10,415'-10,455'. POH. RIH w/ DD to build angle. Direc OK. Could not build angle w/ various BHA. RU & RIH w/ Eastman steering tool. Oriented steering tool & DD 10,455'-526'. POH w/ steering tool. Found that connection above mule shoe on steering tool had become loose. Steering tool had malfunctioned. RIH w/ new steering tool. Oriented tool & DD from 10,526'-538'. ~11 History - TBU Well D-12RD ~ge 3 5-12 10,748'TD 9-13 10,834'TD 9-14 11,170'TD '9-15 11,445'TD )9-16 11,630'TD ])9-17 11,945'TD 09-18 12,050'TD 09-19 12,050'TD 09-20 12,050'TD 09-21 12,050'TD 09-22 12,050'TD 09-23 12,050'TD 09-24 12,050'TD 09-25 12,050'TD 09-26 12,050'TD 09-27 12,050'TD 09-28 12,050'TD DD from 10,538'-553'. POH. RIH w/ bit ~8. Drld 10,553'-748'. Circ & surv. Made 15-std short trip. Circ. CBU. POH. RIH w/ bit #9. Drld 10,748'-834'. POH. RIH w/ bit #10 to 10,629'. Reaming to btm. Reamed 10,629'-10,834'. Drld 10,834'-11,043'. Made lO-std short trip. Drld 11,043'-11,170'. Drld 11,170'-11,415'. POH. RIH w/ bit #11. Ream 11,090'- 11,415'. Drld 11,415'-11,445'. Drld 11,445'-620'. POH. Tstd BOPE. RIH w/ bit #12. Drld 11,620'-11,630'. Drld 11,630'-945'. Projected TD is 12,050'. Drld 11,945'-12,050'. Made 30-std short trip. Circ & POH. RU Schl for open hole logs. Schl ran GR/SP/DIL, DIL/BHC, & FDC/CNL logs. Prep to run RFT. RIH w/ RFT. Tool stuck after one sample. Failed to pull tool loose. RU stripping eqpmt & RIH w/ DP stripping over WL. Tagged RFT fish ~ 11,769' & pulled it into grapple. Prep to pull WL out of rope socket. Pull ed WL out of rope socket of RFT tool. POH w/ WL. POH w/ DP & rec RFT tool. RIH w/ DP to 12,050'. Had 4' of fill. C&C hole & mud for 7" Inr. POH. R~-& RIH w/ 7", 29#, N-80 csg. Fin RIH w/ 7" Inr to 12,031'. Dropped ball & set BOT Inr hgr. HOWCO cmtd 7" I nr w/ 300 sx C I G w/ 1% CFR-2 & 0.3% Halad 22A followed by 700 sx C! G w/ 1% CFR-2, 0.3% Halad 22A, 3% KCI, & 1/4 #/sk flocel. PU to 8159' & rev out 150 sx. CIP @ 6:30 PM, 09-21-80. C&C cmt contaminated mud. POH w/ DP. Top of lnr ~ 9137', FC ~ 11,904', CS ~ 11,987' btm of FS @ 12,031'. WOC. Tstd BOPE. R IH w/ DP. Tagged cmt @ 8540'. Started drlg cmt. Drld firm cmt to top of 7" Inr ~ 9137'. POH. RIH to 9137' PU 88 its 3-1/2" DP. Drld cmt 9137'-9169'. RIH & tagged cmt @ 11,731'. Drld firm cmt to 11,802'. Drld firm cmt to FC @ 11,904'. Tstd 9-5/8" csg & 7" Inr to 2500#--0K. POH. RU DA & ran CBL/GR. Good bond across Hem- lock. Fair to good bond in Inr lap. RU Eastman to run gyro surv. Fin running gyro surv. RD DA. RIH w/ bit & scraper to top of 7" Inr @ 9137'. Circ. POH. RIH w/ HOWCO DST tools to dry test 7" Inr lap. Set pkr @ 9103' w/ 2000' of WC. Opened tool @ 4:45 AM, 09-26-80. Recorded 1 hr flow period. SI tool @ 5:50 AM for 2 hr SI period. Fin dry test of Inr lap. No leak. POH w/ DST tools. Tstd BOPE. RIH w/ bit & scraper to 11,904'PB. Displ mud w/ FIW. POH. RU DA. RIH w/ JB & GR to 11,600'. RIH w/ 7" Otis WD pkr w/ seal bore ext. Pkr would not go past top of Inr--POH. Added more bend to btm of seal bore ext. RIH w/ Otis WD pkr. History - TBU Well D-12RD 4 -29 12,050'TD 7-30 12,050'TD 0-01 12,050'TD 0-02 12,050'TD 10-03 12,050'TD 10-04 2,050'TD 10-05 12,050'TD Could not get Otis WD pkr into 7" Inr. POH. Modified btm of pkr seal bore ext. RIH w/ pkr--sti I I could not get pkr into 7" Inr. POH. RIH w/ GR & JB to 11,600'. Went into top of Inr @ 9137' w/ JB & GR 3 times. First 2 times did not touch anything; third time set dwn but fell on thru. Cut full mule shoe on btm of seal bore ext. RI H w/ pkr. Seal bore ext went into top of line but pkr body hung up. Worked pkr past top of I nr & RI H to 10,560'. PU to log clr& pkr & setting tools stuck @ 10,560'. Set pkr. Unable to pull setting tool from pkr. Pul led out of rope socket. POH w/ WL. RD DA. MU OS w/ 1-3/4" grapple on DP & RIH. Latched fish & pul led free w/ 40,000#. POH. Had 5000# drag on 1st 2 stds. Fin POH. Rec pkr setting tool. RIH w/ mill-over shoe & tagged Otis WD perm pkr @ lO,586'DPM. Milled to 10,588'--unable to mill any deeper. POH. RIH w/ mill-over shoe #2. Milled on pkr @ 10,588'. Could not mill any deeper. Pkr junk ppears to be turning. POH. PU additional 4-3.4" DC & RIH w/ ~" bit. Dr Id on pkr making about 16". Pkr junk still turning. POH. RIH w/ new 6" bit. Fin RIH w/ 6" bit. Fin drlg Otis WD pkr & pushed pkr junk to 11,894'- Rev circ. POH. RU DA. RIH w/ JB & GR to 11,100' POH. DA set Otis WD pkr @ 11,014'DIL. POH. RD DA. RU & Rill w/ 3-1/2" prod tbg. Fin RIH w/ 3-1/2" prod tbg, Gator Hawking to 5000#. Landed tbg & tested seal assy & Otis WD pkr--OK. Spaced out tbg. ND BOPE. NU Xmas tree & started unloading FIW from tbg & csg. Fin unloading tbg & csg for drawdow~ prior to perfg. RU DA & perfd Hemlock Bench 4 11,496'-516' and 11,530'-570'DIL w/ 2.6" jet, 4 HPF, 180° phasing. RD DA. Placed well on prod @ 0700 hfs, 10-04-80. Well was GL to facilities @ WC of 48%. Bench 4, Hemlock Zn, producing @ rate of 2544 BFPD @ 1.5% WC (2506 BOPD). GLG = 3.3 MMCFPD, TP = 400 psi. Ri.q released @ 12 Midnight, 10-04-80. FINAL REPORT STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Forr~ 10-403 REV. 1-10-73 Subml t "1 ntentions" in Trlpllcate & "Subsequent Reports" in Duplicate 5. APl NUMERICAL CODE 50-i33-20156-01 6. LEASE DESIGNATION AND SERIAL NO. · ADL 18777 ' 7. ,F ,NO,AN. ALLOTTEE OR TH,BE NAME O,L k-~ GAs WELLL ~ WELLL--J OTHER NAME OF OPERATOR 8. UNIT, FARM OR LF_~$ENAME Union Oil Co. of California* Trading Bay Unit ADDRESS OF OPERATOR 9. WELL NO. 909 W. Ninth Ave., Anchorage, AK 99502 K-12Rd (44-18) 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.) 4. LOCATION OF WELL At su~ace 735' N & 140' W of SE Corner Sec 17, T9N, R13W, SM 13. ELEVATIONS (Show whetl3er DF, RT, GR, etc.) K- R. 1 DD ' n hOxr~ MT,T,W Check Appropriate Box To Indicate Nature of Notice, Re lO. FIELD AND POOL. OR WILDCAT McArthur River - Hemlock 11. SEC., T., R., M., {BOTTOM HOLE OBJECTIVE) SEC 18, T9N, R13W, SM 12. PERMIT NO. )orr, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Reperf Existing Intervals SUBSECIUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING · SHOOT lNG O R AC I D I ZING ABAN DO NMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, includmg estimated date of starting any proposed work. -We propose to reperforate the following intervals: -- 11037-11054 DIL 11072-11175 DIL Subsequent Wor~f Repo~ecl *ARCO Oil and Gas Company, Suboperato~ 16. I hereby certify.[hat the foregoing Is true and correct ADistrict Engineer SIGNED ( ..... TITLE (This space for State office u~) ,Z'l// , APPROVED BY / TITLE - ~ ' DATE PAT E 9/]6/80 Subsequent Work Reported See Instructions On Reverse Side on Form No ..... Da. tea ._/._./__. ; $- I-?0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMII~EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WKLL WtL~ 2 NAME OF OPERATOR Union Oil Company of California* P. O. Box 6247, Anchorage AK 99502 4 ~OCA~ON OF ~ Leg B-l, Cond #10, Dolly Varden Platform 678'FSL, 1217'FWL, Sec 6-8N-13W-SM SUBMZ'r ~T DTJPT~TCATE AP1 NLT~ER/CAL CODE 50-753-20142-01 6 LEASE DESiGBIA'I'ION AND SERIAL NO ADL- 18729 ? IF IAIDiA~ AL,OTi~ OR TRIBE NAME 8 L~IT FARM OR LEASE NAME Tradin9 Bay Unit TBU D-12RD 10 ~-!!~t~D A_ND POOL OR WILDCAT McArthur River Field I1 SF.C T R, M (BO'FI'OM HOLE Sec. 8, T8N, R13W, SM 12 P~MIT NO 80-82 13 REPORT TOTAL DEPTH AT END OF MONTH, CHA. NGF. S IN HOLE SIZE, CASING AND CLWIENT!NG JOBS INCLUDING DEPTH SET AND VOLIIIVrEs USED PERFORATIONS TESTS AND RESULTS FISHING JOl~ JUNK LN HOLE AND SIDE-TRACKED HOLE A_NTD ANY OTI-IF_,~ SIGNIFICANT CHA~GES IN HOI.~ CON'DITIONS AUGUST REPORT OF DRILLING OPERATIONS 08-13 12,381'TD 12,299'PBTD Moving eqpmt from Rig 77 to Rig 76 for D-12RD. 08-14 12,381 'TD 12,299'PBTD 08-15 12,381 'TD 12,299 ' PBTD 08-16 12,381 'TD 12,299 ' PBTD 08-17 12,381 'TD 12,299 ' PBTD Moving eqpmt & RU. Working on drlg eqpmt & RU. RU. RU. 08-21 12,381'TD 12,299'PBTD Pulled BV. Disconnected GL line. Began bleeding gas off csg annls. 08-22 12,381'TD Fin bleeding CP off. 12,299'PBTD & up csg--tbg to csg mud & circ. Loaded tbg & csg w/ FIW. C irc dwn tbg leak is apparent. Displ FIW w/ gel led 08-23 12,381'TD 12,299'PBTD Set BPV in tbg hgr. ND tree. NU BOPE & tstd same. 08-24 12,381'TD 12,299'PBTD Circ & POH w/ 4-1/2" x 3-1/2" tbg. Found btm GLV washed out. Tstd BOPE. Began RIH w/ 6" bit & scraper for CO trip to top of pkr. *Marathon Oil Company - Sub-Operator SmN~D.~~'') ~'L ~'"~"~'~-~'"~ =~ Dist. Drl~. Supt. ~.~ 9/11/~0 ~TE--Regort on this fora is required for ~ calendar ~th~ regardless 0f the status of operations, and must ~ filed In dupli~te with t~e oil and gas conservatbn commiflee bythe 15~ of the suoc~ding mn~, ~le~ Otherwise d,rected. August Report of Drilling Operations Well TBU D-12RD Page 2 08-25 12,381'TD 12,299'PBTD 08-26 12,381'TD 11,450'PBTD 08-27 IO,050'PBTD 08-28 IO,050'PBTD 08-29 08-30 08-31 Fin RIH/ Tagged pkr ~ 11,430'. Had 6' of fill on top of pkr. POH. PU pkr mill, JB, jars, & bumper sub. RIH to pkr @ 11,430'. Milled 7" pkr & pushed to 12,105'. C&C mud. POH. RIH w/ OEDP to lay cmt plug opposite perfs. Fin RIH w/ OEDP to 12,102'. Placed 120-sk CIG cmt plug from 12,102'-11,450' (Hemlock perfs ~ 11,515'-12,096'). POH. PU 9 - 6-1/4" DC & bit & scraper. RIH to 10,250'. Could not circ. POH w/ wet string. LD plugged DC. RIH w/ bit & scraper. Fin RIH w/ bit & scraper to 10,250'. Circ & POH. RU DA & RIH w/ GR & JB to 10,200. POH. RIH w/ 9-5/8" Halliburton EZSV BP & set @ 10,050'. POH. RIH w/ CBL & logged interval 9200'-9650'. Good bond thruout interval. Better bond @ 9308'-9390' & 9520'-9600'. RD DA. MU Servco section mill & RIH to 9365'. Cut 9-5/8" section from 9365'-9374'. Milled section in 9-5/8" csg from 9374'-9375'. Circ & POH. RIH w/ section mill #2. Milled 9-5/8" csg from 9375'-9387'. POH to 9340'. Circ to clean hole. POH LD section mill. Staged in hole w/ OEDP, rev circ in an attempt to remove metal cuttings from hole--very little recovery. POH. RIH w/ section mill #3. Milled from 9387'-9389'. Milled section from 9389'-9391'. Circ & POH. Staged in hole w/ open-ended 9-5/8" csg scraper to 9360', rev metal cuttings from hole. POH. RIH w/ section mill #4. Milled from 9391'-9397'. Ouly 22, 19a0 ME. Robert T. Anderson District Land Manager union Oil Company of California P. Os Box 6247 Anchoragem Alaska 99502 Re: Trading Bay Unit D-12RD Union Oil Company of California Sur. Loo. t 678'FSL, 12170FWL, See,~.'.6, TSN, R13W, ~Bottoltthole Loc.~ 1450eFWL, 20e0*F~L, sec. 8, ~sH, R13W, SM. Dear MF. ~closed ~s t~ tpproved a~l~cat~on ~ove referenced wel 1. Well s~ples, core chips and a mud log are not r~ulred. A directional sudsy~ Lo r~u~red, l~ available, a ta~ contatn- ~ng ~e digitized 1~ tnfo~atton on all logs shall be sub- mitt~ for ~tng ~cept e~r~men~l logs, velocity 8u~eys and d~eter ~n~ rivers ~n Alaoh and 2heir drainage s~stem8 have ~en clasmif~ as ~~ant f~ ~e S~tng or migration of an~r~ou.s f~. ~erations ~n ~ese ~e.as are subject ~6.50,870 ~d ~ regulations pr~ulqa~ ~eunder (T~tle A.lash M.~n~s~at~ve ~e). Prior you ~y ~ con~a~ ~ ~ Hab~t Coord~nator*$ off,ce, ~r~ent of F~oh and Pollu~ion of an~ wakers o~ ~e State ~s prohib~ed by AS 46, Chapter 3, ~cle 7 and the r~ulat~ons pr~ulgat~ thereunder (T~tle 18, Alaska MmLn~strat~ve C~e, F~eral Water Pollution Control ~t, Hr. l~bert T. Anderson Trading Bay Unit D-12RD -,2- July 22, 1980 ocemeno~g operations you may be contacted by a representative of the I:M~artmont of Environmental Conservation. Purguent to A8 38.40, Local Hire Under State Leases, the Alaska Det~rtment of L~ ~, ~L~ noti~A~ o~ ~ Assuage o~ th~s To a~d us Lu scheduling £~eld wo~k, ve would appreciate your s~. ~ ~uld el~ like ~ ~ no~ed as ~at a repre- s~ta~/~ of tb ~so~on ~y ~ present ~o w~ess testing of bl~ut ~ent~ ~L~ent ~ore nr~ace casing sh~ ~s ~'t11~. In tho event of suspension or abandonment, please gL.ye thLs o£~t~0 &deq'~&te cdr&nee nott£.~Loat~on os that we may have a Very t~ly yours, '. loyle . Hamilton ~C~&t~ Of BY ORDER O~ T~E COMMISSION Alae~ Otl Enclosure ce~ ~epartmant of Fish & ~ame, Habitat Section v/o anal. Depa:r~t of Env1ronmentel Conse~atton Department of Labor;. Supervisor, Labor Law Compliance Div~s~Lon w/o encl. Un~on O~1 and Gas [~",son' Western Region Union O~1 Company et California P O. Box 6247, Anchorage, Alaska 99502 Telephone. (907) 276-7600 union Robert T Anderson D~stnct Land Manager July 18, 1980 Mr. Hoyle Hamilton State of Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska Permit to Drill or Deepen TBUS D-12 Rd. (22X-8), Dolly Varden Platform, McArthur River Field State Lease No. ADL-18729 Dear Mr. Hamilton: Enclosed for your further handling are three (3) copies of the above captioned Permit to Drill. Also enclosed is our check #19032 in the amount of $100.00 to cover the filing fees. Very truly yours, sk Enclosures (4) J 0L 1 8 l~orm I0-- 401 ~ I-I--?1 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE TYPE Or WORK PERMIT TO DRILL OR DEEPEN i DEEPEN [] DRILL ~{ b TYPE or WELL OIL ~ OASD WELL WELL SUBMIT IN (Other ,nstruetions reverse side) API #50-733-20142-01 6 LEASE DW~IGNATION A. ND S~I:tlAL NO ADL-18729 IF INDIAN. A.LIA)i~i~k4~ OR TRI~E NA.M~ ---- S UNIT, FARM OR LEASE NAME Trading Bay Unit D- 12RD 10 FIELD AND POOL OR WILDCAT McArthur River Field 11 SEC, T R M, (BOTTOM HOLE OBJECTIVE) Sec. 8, T8N; R13W; SM Amour $100,000 I? NO ACRES ASSIGNED TO THiS WELL 80 20 ROTARY OR CABLE TOOLS Rotary 2 NAME OF OPERATOR Union Oil Company of California* 3 ADDRES~ O~F OPERATOR P. O. Box 6247; Anchora.qe AK 99502 4 LOCATION OF WELL Do I I y Varden P I atform At surface 678'FSL, 1217'FWL, Sec. 6, T8N, R13W, SM, Leg B-l, Cond 10 At proposed prod zone 1450'FWL~ 2000~FNL~ Sec. 8; T8N; R13W~ SM 13 DISTANCE IN MILES AND DIRECT[ON FROM NEAREST TOWN OR POST OFFICE* Approximately 21 mi les NW of Kenai~ Alaska 14 BOND INFORMATION TYpE Statew i de surety and/or No United Pacific Insurance Co. B-55502 15 DISTANCE FROM PROPOSED* I16 NO. OF ACI~-.S IN LEASE LOCATION TO NEAREST PROPERTY OR LEASE LIN~', FT 3500' 3085 (Also tO nearest drlg, umt, if any) 1R DISTANCE FROM PROPOSED LOCATION'* ] 19 PROPOS~T) D~PTH TO NEARES'I' WELL DRILLING, COMPLETED, [ 1 2,262 ' MD OR APPLIED FOR, FT 300' west of D-12 BHL IO,150'TVD ELEVATIONS (Show whethcr DF, RT, CH, etc ) KB 106.2' above MSL 22 APPROX DATE WORK WILL START* Au.qust 10, 1980 23 PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRAI)~ S~"I"rlNG DEPTH quant~t of cement .,, 8-1/2" 7" 29~ N-80 12,262'MD Approx, 425 sx , ,, , , , SEE ATTACHED SHEET JUL 1 8 1980 *Marathon Oil Company - Sub-Operator Ancl]u~,~ IH ABO~ SPA~ D~BE ~O~S~ ~R~ If ~l is to dee~n 'give ~ on present p~u~lve zo~ ~d pr0~ ~W preclusive ~ne J%~l 1S W arlll or ~n d~tonally, glve ~Tt~ent ~ on s~Dsu~a~ ~t~ ~d meas~d ~d ~ue ve~cal dept. GI~ blo~u~__~ pre~e~ter- pwsram S,G~_. ~_% - :~. f- - ,, ,, · --- ~.--~5~Y~;--____L'~', u.n July 19 1980 u~ Dist Land Mar. T_ (This space for State office use) JSAMPLES AND CORE CHIPS R.E~ [] %'~s ~.~NO DIR~C~ONAL SURVEY R~U-mmD ~YES [2] NO ~C;~DZ~ONS or A~P~OVA~, ,~ ~-~'. JM.U,D LOG [] %-ms, ]~o A.PI. ~CAL CODIe ~'o- 75 ::1- 2-o15'2.-o I ~ , ,1980 07/22/80 _ DAT~ P~P. MIT NO_ ~ O '- f ~.. APPROVAL DAT~ ... r,,, cb ,s%,oN *s.. o. R.v.. S,d. --t Attachment to Permit to Drill Well D- 12RD Objective: Plug the existing wellbore, sidetrack at 9453'MD in 9-5/8" casing, and drill 2809' of 8-1/2" hole to a new location with the Hemlock top approximately 1450'FWL, 2000'FNL, Sec. 8, T8N, R13W, SM. Run and cement 7" liner with gas lift equipment and complete the well as a Hemlock producer. Procedure: 1. Skid Rig #76 over Well D-12, conductor #10, leg B-1. 2. Bleed csg & tbg to 0 psi. Bullhead well down tbg w/ FIW. Open circ slv @ 10,400'. Circ well w/ FIW. Chg over to drlg mud. 3. Install BPV. ND tree. NU & test 13-5/8" 5000# BOPE. BOPE will be tstd weekly & reported. 4. Pull tbg. Mill perm pkr ~ 11,435'. 5. RIH w/ OEDP to plug back across existing perfs w/ CIG cmt from 12,100'-11,500' (approx 110 sx). Perfs from 11,515'-12,096'. 6. Set perm BP in 9-5/8" csg @ 10,000'. 7. Run CBL/GR across KO area from 9400'-9550'. If necessary, RIH w/ WL & perf 2' w/ 2 HPF (9473'-9475'). Set cmt rtnr & sqz cmt these perfs. Drill out rtnr & CO to 9700'. 8. Mill section in 9-5/8" csg (approx 9433'-9513'). 9. Lay KO plug (9300'-9550', approx 100 sx). 10. CO to 9453'. Run DD assy w/ diamond bit & KO. 11. Drill 8-1/2" directional hole to TD (approx 12,262'MD; 10,150'TVD) according to directional program. 12. Run 7", 29#, N-80, Butt Inr from TD to 9250'. Cmt w/ approx 425 sx CIG. RIH tbg string w/ gas lift equipment and complete as Hemlock producer. There are no wellbores within 200' of the proposed well other than the existing D-12. , ~ - MARATHON -- DOLLY VARDEKI PLATFORM -- L U 0 o Mu~! Pon Flowlir~¢ ~ 13 5,ooo A~nu~r Oqvd~il ) (Pipe 5,000 - Kill Liha-, ~ -- Chok6 Lina- 3,5,00 Dr~,, D~ck Floor, / ~ ~ ' ' o' " Riser 6 ~OP Stack For tO , , I jU¢ ,, Wall Room Floor.. ,,< %----- 2 Ff. 5pool 12",,, 5,000*~ Oasins Head w/Flgnaecl Outlets i Valves C.,ollar 13 z/6' Surf~ae Oa~i~8 ~onductor o0-25 PAN AM R ST IO I 35 ! FC-! FC -IA D-14 , IA t LEGEND COMP. PROD. B-I INJ. B-I e ABAND, PF~Sr,,. B-I 15 .~ ABAND. INJ. B-I {) 0 BENCH-I 'WELL PTS. 2000' 4000' 6000' iii i ii i ii FEET I III I MARATHON OIL COMPANY ANCHORAGE DIVISION Scale' i": 20oo' Date FEB 1979 TRADING BAY UNIT · McARTHUR RIVER FIELD TOP HE MLOCK BENCh,- I CONTOUR INTERVAL ~--- I00 FT. Author'. D ATCHISON/ L H. Fde no / TBU D-12RD Scale = 1" = 1000' TVD °i 1000 ' 2000 ~. 3000. _ 4000-- 5ooo- 6000, 7000L. 8000L 90001 go 000 '__'_ 1 1518' O' !000' 2000' 3000' I I 1217.4' ~.~42' 6140' . ORIGINAL HOLE COURSE S59°E NEW HOLE COURSE S43°20'E TURN 16° RIGHT 4000' 5000' ! ~8' ~55' 2000~ S43~20'E 2142~ 50' · Tbs. 4857' Drop 6° Angle Orlglnal Hole ~KOP ~ 9453'MD; 7805tTVD Angle = 39o15' X~9716,MD \~61 'MD \ ~I0,994'MD Average Angle \ ~,' 33024~ \ 364' MD ~ 11,49! HqD Hemlock Top @ 9400'TVD; 11~ ..... \\~12,274'MD TD ~e IO, 150'TVD; 12,262'MD \\ ~12,381'MD 60OO --0' . 1000' 2000' 91' JAY S. HAMMOND, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION July 18, 1980 3001 PORCUPINE DR/VE ANCHORA GE, ,4LASKA 99501 ADMINISTRATIVE APPROVAL NO. 80.35 Re: Application of Union Oil Company of California, operator of the Trading Bay Un~_~ to drill, complete and produce the ~t D-12RD~ell as a part of the pressure main- e~ance project approved by Conservation Order No. 80. Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Anderson: The referenced application was received on July 18, 1980 and stated that the drilling, completion and production of the Trading Bay Unit D-12RD well will provide a crestal final with- drawal point in the Hemlock Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion and production of the referenced well pursuant to Rule 5 of Conservation Order No. 80. Yours very truly, Harry W. Kugle~ Commi s s ione r BY THE ORDER OF THE COMMISSION CHECK LIST FOR NEW WELL PERMITS Item Approve Date (1) Fee ~___ 7 - ~-~o.~ (3) ~fff~tn ~~ / Company (/:~ , ~-~_. Yes No 1. Is the permit fee attached ....................................... 2. Is well to be located in a defin~'po~l ....... 3. Is a registered survey plat attached ................................ / 4. Is well located proper distance frcm property line .................. / 5. Is well located proper distance frcm other wells .............. / 6. Is sufficient undedicated acreage available in this pool ........... ~.~f~g .... 7. Is well to be deviated ............................................ 8 Is operator the only affected party ......... i i ' ' 11. Is a conservation order needed ...... ~. ......... " ......... / 12. Is administrative approval needed · · /- 13. Is conductor string provided ........................................ ~ 14. Is enough cement used to circulate on conductor and surface ......... ~/~/~ (4) Cas~. /~ ?-~/-~o 15. Will c~ment tie in surface and intermediate or production strings ... F/~/~ ~'16. Will cement cover all known productive horizons ..................... /~p Lease &Well No. Remarks 17. Will surface casing protect fresh water zones ....................... 18. Will all casing give adequate safety in collapse, tension and burst.. ~M? . ( 5 ) BOPE ~/D 2,-~o 19. Does BOPE have sufficient pressure rating - Test to 3o~O psig .. ~ ~- Approval Recked: rev: 03/05/80 Well Histocy File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 11 000000 11 000000 1111 O0 O0 1111 O0 O0 11 O0 0000 11 O0 0000 11 00 00 00 11 00 00 00 11 0000 00 11 0000 O0 11 O0 O0 1] O0 O0 111111 000000 111111 000000 7777777777 7777777777 77 77 77 77 7; 77 77 77 77 77 77 77 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 OO O0 000000 000000 1777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 666666 11 bUbb66 11 66 1111 66 111l 66 11 6666666b 11 b~SbSb66 il 66 66 11 66 6b 11 bb 6b 11 6b 66 11 666666 111111 bb66o6 111111 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 11 1i 1111 1111 11 ll 11 11 [1 ll 11 11 111111 111111 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 ,START* Ufik~ PCAL [lOZO7,61010J jOB MONITt{R SwS KLIOE40 SEP 80. ,START* ,START* tJSE~ PCAL [10707,blOlOJ dUB MON1TO~ 6~$ ELIOE40 8kP-uO. *START* ,START* USER PCAL [10707,blOlOJ dUB MONIT(IR b~S KLIOE40 SkP-80. ,START* ,S'I'AR~I, USER PCAL [10701,b10101 JOB MONIT~iR b~,IS kL10k40 SEP-80. ,START* OFFER PCAb [lO!O7,blOlO] dU~ MONI]'t)P SwS KLIOE40 5kP 80. *START* VERIPt SEQ. VERIFY SEQ. VERIFY SE~. VERIFY SE~. 6199 DAlE 25-SEP-80 6199 DATE 25-SEP-80 6199 DATE 25-5EP-80 6199 DAlE 25-SEP-80 6199 DATE 25-SEP-80 17:14:18 17:14:18 17:14:18 17:14:18 17:14:18 VV VV VV VV VV VV VV V¥ VV VV VV VV VV VV vv VV EE hk ~R VV EE ~ R~ VV EE ~H PH VV ~E HH ~R VV EEEE~EEE HkRRRRR~ VV EE~EEEEE RkRRPR~H VV EE ~H R~ VV EE HH RR EE ~H ~ EEEkEEEEEE P~ RR EEEEkEEEEE HR RH IlliII IIllII I! Il 1I II I1 II II I1 I1 II illiii IIIII1 YX YY YY YY X~ XX 000000 000000 222222 000000 000000 222222 O0 O0 O0 O0 22 22 O0 O0 O0 O0 22 22 O0 no00 O0 0000 22 O0 0000 O0 o000 22 O0 O0 O0 O0 O0 O0 22 O0 oO O0 O0 O0 O0 22 0000 O0 0000 O0 22 0000 O0 0000 O0 22 O0 O0 O0 O0 22 O0 O0 O0 O0 22 000000 00000o 2222222222 000000 000000 2222222222 *START* USE}{ PCAL [10707,61010] dUB VERIFY SEQ. 6199 DATE 25-5EP-$0 MUNITUR SWS KLIOE40 SEP-80. *START* ~'ILE: DS~H:VEHl~Y.O02<057>l10707,610101 CREATED: 25-SEP-80 lb:54:56 P~INTtD: 25-$EP-80 17:14:44 QUEUE SWIICHES: /~ILE:ASCII /CUPIES:I /SPACING:! /LIMIT:84 /fORMS:NURMAL 17:14:18 ,SCHLUMBERGER C(}MPUTING CEN'IER 10107~61010 REEL I,i,,NG'IH: 1 {2 BYTES REEL NAME: P.C.A.L. SERV1Ck NAME: EDIT REEL CUN'I1NUAIION NUMBER: Ol PRLVIUUS REED NAME: C()MMLN~S: ~lfi ~UMMAT CUS~L)~ER ~LAPk DAZE: 80/ 9/24 TAPE HEADER LENG%'H: 152 TAPE NAME: blOlO DATE: 80/ 9/24 SERVICE NAME: EDiT TAPE CONTINUATION NUMBER: O1 PREVIUI)~ %APE NAME: COMMENT6: TAPE COMMENTS RUN (JNE/DAIE LtIGGLD 18-SEP-80/CASING SiZE 9.620 a 9370/~1T SIZE 8.5 ~ 12050/lYPk ~LUID 6PE~SENE-RESIN/DENS 9.4/PR IO.O/VISC 58.0 SEC/ FLUID I~[]SS 9.2 ML/RM 1.79 0 62 DF/RMF 2.55 @ 62 DF/~MC 2.84 0 62 DF/ FILE obADEH LENGIH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM PhXSICAL RECORD LENGTH: PREVIUUS fILL NAME: 1024 BYTES WELL ,51'l'k INbLJRMATIUN I~ECORD l,kNG IH: COMPANY HELL: f lkLU: RANGE: S~C 1 iON C()UNT~: I 77 BY'lES MARAIHUN OIL CO. TBU D-12 RD. MCARTHUR RIVER 8N 6 KkNA[ S'rA'IE: ALASKA DATA P[JRMAI SPkCI~ICAIlUN LENG1H: hlU DXTES DATUM SPECIP ICATION TxPE ENTR~ 1 2 4 5 6 7 9 10 11 [2 l] lq 15 lC [UUh SVIJRD~ UNITS DkPI ~T SP Dl6 MV lLD DIE OHM~ IbM [)Ih OHMM SFbU DIE OHMM GR BHC GAPI bT BHC U8/~ GR CNG GAPI CALl CNG IN DRHO P DC G/C NPNI CNG PU HMOH CN6 G/C] NMA'I CML C/C NCNL CNG CPS ECNL CNG CPS OEP'IH MNEMONIC VAGUE 120~5.000 8P 19.281 GR 44.688 DRHO 0.081 NCNL 2078.000 12O00.000 6P 19.719 GR 49.025 D~Ht) 0.176 NCNb 2210.000 11900.000 MP 24.781 GP 54.844 DRHU 0.081 NCNb 2714.000 i 1 800. 000 SP -40.719 GR 45.250 DRHU 0.125 NCNb 4380.000 11700.000 SP -b0.719 GR 48.750 DHHt) 0.045 NCNL 4880.000 lib00.000 8P -2&.7St GR 62.938 D~HU O. 122 NCNb 3226.000 I 1500. 000 SP -47.219 GR 47.156 D~HU 0.O7J 1 AP1 AP1 0 0 7 1 7 12 7 12 7 22 60 52 42 31 42 28 42 44 42 68 42 ~5 42 42 42 34 42 34 MNEMONIC ILD DT NPHI ~CNL ILO DT NPHI FCNL ILD DT NPH1 [CNG ILD DT NPH1 FCNb ILO UT NPHI f'CNL iLO DT NPHI ECN6 1LD DT NPHI REP CODE ENIR~ 66 0 AP1 AP1 FILL# StZL EXP PROC SAM 0 0 0 4 0 0 0 0 0 4 0 0 46 0 0 4 0 0 1 44 0 0 4 0 0 I 0 0 4 0 0 ! 32 0 O 4 0 0 1 32 0 0 4 0 0 1 32 0 0 ~ 0 0 1 1 0 0 ~ 0 0 1 0 0 0 4 0 0 1 3 0 0 4 0 0 1 1 0 0 4 0 0 1 1 0 0 4 0 0 1 92 0 0 4 0 0 1 9] 0 U 4 0 0 1 VALUE MNEMONIC VALUE 3.197 ILM 8.330 95.000 GR 105.938 20.150 RHUB 2.]81 729.500 2.941 iLM 2.275 77.750 GR 57.531 48.584 RHOB 1.938 475.750 4.61] ILM 4.207 79.563 GR 59.563 26.758 RHOB 2.113 928.000 8.188 ILM 8.510 70.750 GR 49.313 1].525 RHOB 2.~20 2562.000 48.938 ILM 15.891 68.375 GR 54.500 12.695 RHUB 2.459 2774.000 17.969 ILM 12.6~8 76.563 GR 74.500 2~.486 RHOD 2.447 1322.000 43.281 IbM 24.063 6q.56] GR 54.781 12.646 RHO~ 2.451 REP DbPT SHiF% 68 0 0 68 0 0 68 0 0 68 0 0 68 0 0 68 0 0 68 0 0 68 0 0 68 0 0 68 0 0 68 0 0 68 0 0 68 0 0 68 0 0 b8 0 0 MNEMONIC VAbU£ SFbO b.148 CAbI 8.500 NRAT 2.695 SFLU 2.297 CALl 13.688 NRA£ 4.039 SFGU 8.289 CALl 9.867 NRAT 2.b37 SFbU 9.117 CALl 8.328 NRA~ 1.629 SFLU 41.031 CA6i 9.125 N~AT 1.640 SFbU 17.938 CALl 8.797 NRAT 2.330 SF{.,U 4b.875 CALl 8.67~1 NRAI 1. 8 ltq00.000 300.000 200. 11100.000 llO00.O00 10900.000 1O800°000 107OO. 000 10600.000 10500,000 1040O.00O 10300.000 NCNb SP GR NCNb GR DHHU NCNb SP Gg DRHO NCNb 8P NCNL MNEMUNIC GR NCNb SP GR DRIiO NCNb DbHU NCNL Si-, GH DFttiO NCNb SP GP DRHO NCNb SP GH DHHU NCNb ,..,$ P Gi~ DRHf} NC NI., 4300. -3. 98. O. 2520. 43. 0. 4230. -29. 44. -0. 1962. -8. 77. 2450. VALU -53. 62. 0. 4184. -3b. 72. O. 2702. -28. O, 5058. -76. 52. --0. 4504, -24. 38. -0. 1497. -27. 86, O. 2550. -87. 57. 0. 4066, -41. 115. 000 219 250 O0O 000 219 023 000 219 563 022 000 719 503 011 000 E 719 625 O02 000 781 31J 000 219 813 077 000 75O 4O6 004 000 31~ 750 023 000 219 188 000 313 781 05b OOO 719 125 FCNb ILO DT NPH I FCNL iLD DT NPHI FCNL ILD DT NPHI FCNL IbD DT NPHi FCNL MNEMUN1C DT NPH1 FCNL iLD DT NPHI FCNL 1LD DT NPH1 FCNL ILD DT NPHI FCNL ILD DT NPHI FCNL ILD DI NPHI FCNL DT NPHI FCNL ILD DT 2006.000 10.398 75.375 30.17o 857.500 10.367 b4.375 17.920 1992.000 26.031 112.375 64.063 361.000 8.188 96.56t 45.117 614.500 VALUE 11.188 75.188 18.457 1963.000 6.402 77.56] J0.273 8%8.500 12.063 75.000 27.344 1071.000 5.996 74.563 17.773 2~b6.000 2~.922 130.750 67.480 259.000 22.141 111.561 60.645 421.000 4.094 80.750 21.289 17{4.000 12.961 72.375 IbM GR GR RHO~ IbM GR RHOB GR RHO~ MNEMONIC G~ ILM RHOB 1LM GR RHOB IbM GR RHOB GR RHUB ILM RHOD GR 9.258 96.750 2.561 11.711 46.844 2.]87 14.922 52.094 1.51~ 8.3Jb 79.125 2.289 VALUE 12.195 71.688 2.424 5.910 75,56t 2.631 10.438 95.4{8 2.475 7.363 58.750 2.439 11.891 39.281 1.287 2].094 99.938 1.751 5.199 58.563 2.400 12.086 113.188 SFLU CALl NRAi 8FLU CALl NRA'£ SFLU CALl NRAT 6FLU CALl NRAI MNEMONIC 8FLU CALl NRAT SFLU CALl NRAT SFLU CALl NRAT SFLU CA~I NRAT SFLU CALI NRA'£ SFLU NRAT SFLU CALl NRA~' SFLU CALl 10.297 10.023 2.877 7.219 18.875 1.968 45.U75 11.922 4.855 8.J20 10.009 3.762 VALUE 16.750 9.133 2.021 10.320 10.078 2.887 10.469 10.000 2.684 19.578 9.250 1.987 4b.875 20.203 5.262 68.500 10.242 4.594 12.445 8.703 2.1t6 21.859 10.1;2 ' 10200.000 O100.00o 0000.000 qgOO.O00 9800.000 9700,000 9600.000 9500. 000 9400,000 9300.000 9d00.000 q I 0(}. go0 DRtlU NCNL SP GR DRHU NCNb SP [)PHC] NCNb Si-' l)~HO NCNb MNLMUNIC SP I)RHU N C N L SP G~ DRH(} NCNB SP GP DI~HLI NCNL ,S P GR DRHO NCNb SP G~ DHHU NC N L 6P G~ DRHU NCNb DRHU NCNb DHHU NCNb 8P 273 ,,9 5 ]59 -5 8 VA -2 ,]09 ,-9 6 -4 322 -7 5 350 -9 5 45? -7 7 . 217 4 219 -101 O. . 4. O. 4. 7. O. O. 2. 6. 2. O. O. LO 9. O. O. O. 1. O. 4. 1. 1. O. 4. 9. 5. O. O. 4. 3. O. 2. O. 1. O. 8. 6. 7. O. 0. 7. 3. O. 2. 9. 058 000 250 781 O34 000 719 188 011 000 :144 188 115 000 E 06] 313 084 000 81t 500 054 000 500 875 OJO 0 O0 000 125 009 000 500 656 010 000 000 250 105 000 500 781 542 000 500 125 602 000 250 NPHI ILD DT NPHI fCNL 1LD DT NPH [ FCNL 1LO DT NPHI FCNL MNEMONIC DT NPHI FCNL ILD DT N PHi fCNL NPHI FCNL DT NPHI FCNb DT NPHI FCNL ILO DT NPHi ~CNL ILl3 DT NPH1 FCNL ILO DT NPHI ~CNL ILD 29.102 902.500 19.828 84.000 22.705 1494.000 q.609 75.750 29.492 916.500 11.992 85.188 25.732 1322.000 VALUE 14.01~ 74.750 28.070 1032.000 5.582 85.750 22.998 1477.000 8.830 71.188 25.148 1230.000 7.902 87.750 21.973 1504.000 6.309 76.563 17.432 2080.000 5.961 84.188 17.822 1228.000 4.797 64.~75 27.588 70{.000 4.602 30.188 29.102 705.500 -999.250 RHUB IbM G~ RHOB ILM GR ILM GR ~HOU MNEMONIC ILM GR ~HOB IbM RHO~ G~ RHUU GR RHUB GR RHOB RHOB GR RHOB GR RHOB 2.535 17.609 bO.SOO 2.381 9.125 123.313 2.605 11.992 74.125 2.283 VALUE 11.938 118.063 2.~88 6.664 69.625 2.]67 79.188 2.55] 8.555 58.781 2,{67 8.367 55.313 2.422 6.844 78.875 2.422 2000.000 43,719 -999.250 2000,000 53.875 -999.250 -999.250 NRA~ SFLU CALl NNAT SFLU CA6I NRA~ SFLU CALl NRAT MNEMONIC 8FbU CALl NRA~ SFLU CALI NRA~ SFLU CALl NRAT SFLU CALl NRAT SFLU CALl NRAI SFLU CALl NRAT SfbO CALk NRA'i SFUU CA~ NRAT 6~LU 2.U18 1~.250 8.945 2.289 10.273 10.141 2.840 16.813 8.750 2.477 VADUE 13.51U 9,914 2.729 11.148 8.~3 2.285 9.984 11.000 2.604 12,445 9,391 2.277 18.328 9.742 2.004 7.125 20.20~ 2.357 108.063 9.063 2.918 20.031 9.063 2.998 -999.25,0 8900.000 DLP'IH 8@00.000 ~700.000 8~00.000 85O0,000 8400.000 8t00.000 ~200. O00 B I O0. 000 8000.000 MN GR -999 D~HLt - 0 NCNI, 2050 SP -1019 GR -999 DRHO -0 NCNL 1619 SP -1019 GR -999 DRttU -0 NCNb 2486 EMUNIC VAL SP -1019 GR -999 DRHU -0 NCNb 1414 SP -1019 GR -999 DRHU =0 NCNL lb25 SP -1019 GR -999 DRHU -0 NCNL 1484 SP -1019 GR -999 D~HU -0 NCNb 1503 SP -1019 G? -999 DRHO -0 NCNb 1708 SP -1019 GR -999 U~n[] -0 NCNb 1274 .250 .50] .000 .250 .250 .506 .000 .250 .250 .558 .000 UE .250 .250 .739 .000 .250 .250 .889 .000 .250 .250 .bO0 .000 .250 .250 .514 .000 .250 .250 .566 .000 .250 .250 .000 6P -1019.250 G~ -999.250 DRHU -0.472 NCNb 1570.000 SP -1019.250 GR -999.250 DRHO -0.802 NCNb 154~.000 SP -1019.250 GR -99g.250 DHHU -0.O5b NCNb 1207.000 MN DT NPHi FCNL OT NPHI ILO DT NPHI FCNL EMUNIC 1LD DT NPHI FCNL DT NPMi ~CNL DT NPHI FCNL iLD DT NPHI FCNL ILD DT NPH] FCNL ILD OT NPHI F'CNL ILD DT NPHI FCNL OT NPHI FCNb D '[ NPHI FCNL -999.250 27.441 094.500 -999.250 -999.250 42.480 404.750 -999.250 -99q.250 22.217 876.500 VALUE -999.250 -999.250 64.404 252.875 -99g.250 -999.250 4q.02] 378.500 -99g.250 -999.250 45.264 371.000 -999.250 -999.250 50.635 332.250 -99q.250 -999.250 ~5.840 509.250 -99g.250 -999.250 70.020 247.000 -99g.250 -99g.250 46.289 400.750 -999.250 -99q.250 44.4]4 ]86.500 -999.250 -99q.250 58.691 293.3?5 GR RHUB GR RHOB ILM GR MNEMONIC G~ RHUB IbM GR IbM RHOB ibm GH RHUB GR RHOB ILM GR IbM GR RHOB ILM RHOD ibm G~ RHUU i999.250 -999.250 36.250 -999.250 -999.250 31.922 -999.250 VALUk -999.250 47.4]8 -999.250 -999.250 52.15b -999.250 -999.250 54.688 -999.250 -999.250 50,550 -999.250 -999.250 34.875 -999.250 -999.250 37,781 -999.250 -999.250 65.000 -999.250 -999.250 57.844 -999.250 -999.250 44.594 -999.250 CALl NRA] SFbU CALl NRAI' SFbU CALl NRA~ MNEMONIC SFLU CAbI NRAI 8FLU NP, AT SFLU CALl NRAT SFLU CALl NRAT SFLU CALl NRAf SFLU CALl NRAI SFLU CALl NRAT SFLU CALl NRAT SFLU CALl NRAT 9.039 2.910 -999.250 9.000 3.734 -999.250 8.992 2.52! VALU~ -999.250 8.992 4.934 -999.250 8.977 4.094 -999.250 8.959 3.885 -999.250 8.945 4.180 -999.250 8.961 3.359 -999.250 8.945 5.242 -999.250 8.969 3.943 -999.250 8.992 3.840 -999.250 8.9bl 4.621 7900. 000 7~00.000 DkPTH 7700.000 7bO0.O00 7500.000 7400.000 7300.000 1200.000 7100.000 7000.000 b900.000 O800.000 b}' -1019.250 G~ -999.250 DRHU -0.47@ NCNb 1542.000 SP -1019.250 GR -999.250 DRHO -0.547 NCNb 1354.000 Mmt',mt)N lC VA brOE 5P =1019.250 GR -999.250 DRHU -0.446 NCNb 1B16.O00 SP -1019.250 GE -999.250 ORttO '0.587 NCNb 1153.000 5P -1019.250 GR -999.250 DHHU -0.587 NCNL 1359.000 SP -1019.250 GR =999.250 D~HO -0.494 NCNb 1841.000 SP -1019.250 G? =999.250 DHHU -0.520 NCNb lO69.000 SP -1019.250 GR -999.250 DRHt] -0.450 NCNb 1505.000 SP -1019.250 GR -999.250 [)HHO -0.47~ NCNL 1472.000 SP -1019.250 GR -999.250 DRHU -0.529 NCNb 134~.000 SP -1019.250 GH -999.250 D~HO -0.540 NCNb 1371.000 SP -1019.250 G~ -999.250 DEBO -O.bO0 NCNb 1517,000 ILD DI NPHI FCNb Ibb DT NPH1 ~CNL MNEMONIC lbo DT NPNi FCNL ILD DT NPHi fCNb ILD o'r NPHI FCNL ILD DT NPnl FCNL lbo DT NPHI FCNL iLD DT NPMI FCNL ILO DT NPHI FCNb ILD DT NPHI FCNL iLO DT NPHI FCNL ILD DT NPH1 FCNL -99q.250 -999.250 {7.461 ~17.250 -999.250 -999.250 54.102 28{.750 VALUE -99q.250 -999.250 2q.736 bl3.O00 -999.250 -999.250 01.42o 259.250 -999.250 -999.250 54.44] 290.000 -999.250 -999.250 41.650 472.500 -999.250 -999.250 4t.213 398.500 -999.250 -999.250 41.162 405.250 -999.250 -999.250 45.654 ~27.000 -999.250 -999.250 50.977 ~14.250 -999.250 -999.250 52.191 297.500 -999.250 -999.250 40.674 420.500 iL~ GR RHUB IbM G~ MNEMONIC ibm GR RHUU GR ~HOD iLN GR RHU~ Ibm GR RHUB RHUU IbM GR RHUB ibm GR IbM RHO~ iLM GR RHUB ILM GR RHOU -999.250 50.406 -999.250 -999.250 26.938 -999.250 VALUE -999.250 34.o88 -999.250 -999.250 55.063 -999.250 -999.250 50.563 -999,250 -999.250 5/.813 -999.250 -999.250 41.938 -999.250 -999.250 O0.219 =999.250 -999.250 57.219 -999.250 -999.250 54.4]8 -999.250 -999.250 -999.250 -999.250 48.000 -999.250 CALl NRAT SFLU CALl NRAT MNEMONIC SFLU CALl NRAI SFbU CALl NRAT SF~,U CALl NRA'.[.' SFLU CALl NRA~ SFLU CALl SFLU CALl NRAT SFbU CALl NRA~ SFbU CALl NRA~ CALl NRA'I S~bU CAbI NRAT -999.250 8.992 4.004 -9~9.250 9.000 4.351 VALUE -999.250 8.9bl 3.035 -999.250 8,992 4.773 -999.250 8.992 4.]91 -999.250 8.992 3.688 -999.250 9.015 3.773 -999.250 8.992 3.b60 -999.250 9.016 3.908 -999.250 8.961 4.199 -999.250 8.984 4.266 -999.250 8.984 3.6~5 6700.000 ~bO0.O00 6500.000 6400.000 300. 000 6200.000 blO0.O00 6000.000 59O0. 000 5800.000 5 ?00. 000 5bOO. 000 8P -1019.250 ILL GR -999.250 UT D~HO -0,600 NPHI NCNL 1591,000 fCNL MNEMUNiC VAbUE MNEMUNIC 8P -1019.250 G~ -999.250 DRHU -0.b89 NCNI, 1231.000 SP -101q.250 GR -999.250 DRHU -0.469 N('NL 1665.000 SP -1019.250 GR -999.250 D~HU -0.548 NCNb 1485.000 SP -1019.250 GH -999.250 DH[lO -0.448 NCNL 1493,000 8P -1019.250 GR -999,250 DRHO -0.493 NCNb 135t.000 SP -1019.250 GR -999.250 DRHU -0.602 NCNb 1214.000 8P -1019.250 GR -999.250 DRHU -0.348 NCNb 1545,000 SP -1019.250 GR -999.250 DRHU -0.465 NCNL 1520.000 SP -1019.250 G~ -999.250 DRHU -0.479 NCNb 1447.000 SP -1019.250 GR -999.250 DHittJ -0.340 NCNb 1927.000 SP -1019.250 GR -999.250 DRHiJ -0.52t iLO DT NPHi FCNL DT NPHi fCNL ILO DT NPHI fCNL ILL DT NPHI ILL DT NPHI FCNL iLL DT NPHI ~CNL ILD DT NPH1 FCNL ILD DT NPHI FCNL 1LD DT NPHI FCNb iLD D% NPHi FCNL ILL DT NPHI -999.250 -q99.250 53.125 355.500 VALUE -999.250 -999.250 71.289 20~.750 -999.250 -999.250 46.240 397.250 -99q.250 -999.250 45.752 360.750 -999.250 -99q.250 45.159 339.250 -999.250 -999.250 52.246 293.750 -999.250 -999.250 68.311 220.750 -999.250 -999.250 47.314 ]80.000 -999.250 -999.250 51.56{ ~36.750 -999.250 -999.250 49.023 311.250 -999.250 -999.250 45.898 428.250 -g9g.250 -999.250 ~o.420 ILM GR G~ RHUb GR RHG~ IbM GR GR RHOD IbM G~ RHU~ IbM GR RHOB 1bM GR RHUD IL~ GR RHU~ IL~ GR RHOB ILM GR RH(Jt~ ILM GR -999.250 56,250 -999.250 VALUE -999.250 34.438 -999.250 -999.250 55.594 -999.250 -999.250 57.125 -999.250 -999.250 67.250 -999.250 -999.250 67.0~3 -999.250 -999.250 17,516 -999.250 -999.250 67.313 -999.250 -999.250 49.000 -999.250 -999,250 53.313 -999,250 -999.250 41.719 -999.250 -999.250 40.344 -999.250 SFLU CALl NRA~ MNkMON1C SFLU CALl NRAI' S fLU CALl NRA~ 8FLU CALl NRAT SFLU CALl N RA'I 8FLU CALl 6FLU CALk NRAT SFLU CALl NRAT SFLU CALl NRAT CALl NRAT CALl NRAT SFLU CALl N RA~I -999.250 8.953 4.316 VAbUI~ -999.250 8.984 5.31] -999.250 8.984 3.939 -999.250 8.984 3.912 -999,250 U.992 3.895 -999.250 9.0O8 4.206 -999.250 9.055 5.14U -999.250 9.0lb 3.998 -999.250 9.008 4.230 -999.250 9.109 4.090 -999.250 9.039 3.922 -999.250 8.992 3,072 5500.000 54U0.00() 5300.000 5200.000 5100.000 5000.000 4900,000 4800.000 4'100.000 4600,000 4500.000 UEPltt 4400.0U0 MN IqCN L SP GR DRigU NCNL GR DRMO NCNb SP DRHU NCNb 8P GR D,HHLJ NCNb DHHU NCNL 8P NCNI, 8P GI~ DHFIfJ NCNL SP DRHU NCNb SP (iH DRH(! NCNb SP DRHU NCNb GR DRHU NCNb MNEMUJN lC SP 2412.000 VALUE -1019.250 -999.250 -0.483 1~61,000 -1019,250 -999.250 -0.872 1568.000 -1019.250 -999.250 -0.582 1235.000 -1019.250 -999.250 -0.433 1394.000 -1019.250 -999.250 -0.574 1503.000 -1019,250 -999,250 -0,4fib 1890.000 -1019,250 -999.250 -0.486 1321,000 -1019.250 =999,250 -0.~95 1702,000 -1019.250 -999.250 -0.421 1500.000 -101q,250 -999.250 -0.41G 2150,000 -1019.250 -999.250 -0.540 1692.000 VALUE -1019,250 ~N FC NL I~MON lC 1LD DT NPH[ FCNL ILD DT NPHI FCNL ILD DT NPHI FCNb I L,O OT NPHI FCNL, ILL D~ NPHI FCNL ILD DT NPHI FCNL DT NPHI FCNL ILD DT NPHI ?CNL ILL DT NPHI FCNL ILD DT NPH1 I'CNb DT NPHI FCNL MNEMONIC 1LD 743.500 VALUE -99q.250 -999.250 43.604 358.750 -999.250 -999.250 42.822 413.750 -999.250 -999.250 56.504 231.750 -999.250 -9qq.250 52.295 285.250 -999.250 -999.250 38.135 446.500 -999.250 -999.250 ]7.744 528.000 -999.250 -999.250 55.170 286.000 -999.250 -999.250 41.309 438.000 -999.250 -999.250 45.240 395.750 -99g.250 -999.250 28.062 009.500 -99q.250 -99q.250 42.~20 445. 50 VALIIk -999.250 MNEMONIC GR RHUB RHLIB GR GR ILM GR RHUH 1LM GR RHOB GH HHU~ IbM GR RHOB ibM GR GR RHUB IbM GR MNEMONIC IbM VALUE -999.250 45.281 -999,250 -999.250 J4.406 -999.250 -999.250 35.063 -999.250 -999.250 50.]75 -999.250 -999.250 34.219 -999.250 -999.250 49.188 -999.250 -999.250 59.656 -999.250 -999.250 54,219 -999.250 -999,250 49.469 -999.250 -999.250 34.56J -999.250 -999.250 46.563 -999.250 VALUE -999,250 MNEMONIC SFLU CALl NRA'[ SFUU CALl NRAT SFLU CALl NRAT SFLU CAb1 NRAI 8FLU CALl NRAT Si. LU CAUl NRAT SFUU CALl NRA'I SFLU CAb1 NRAT 8FLU CA6I NRAI SFLU CALl NRAT SFLU CALl NRA'[ MNEMONIC 8FLU VALUE -999.250 9.039 3.793 -999.250 9.023 3.754 -999.250 9.010 5.051 -999.250 9.016 4.270 -999.25u 8.992 3.495 -999.250 9.016 3.473 -999.250 8.984 4.430 -999.250 9.008 3.568 -999.250 9.008 3.939 -999.250 8,992 2,917 -999.250 8.992 3.755 VALU~ -999.250 4300.000 4200.000 4100.000 4000. OOO 3900.000 3800.000 3700.000 3000.000 3500. O00 3400. 000 DLP'I H ~,300. 000 DI~HU NCNb SP DRHU NC Mi, SP DR[t(I NCNL SP G~ DI~I-IU NC Nb GR DRHU NCNL SP GR DRHIJ NCNb 6P GI~ DRHU NCNb 8P DRHO NCNb SP GR DRHU NC Nb SP GR DRHU NCNL bP GI~ DRHO NCNb MNLMONIC 8P GR DRHO NCNb -999.250 -0.]64 2418.000 -1019.250 -999.250 -0.525 1207.000 -101q.250 -999.250 -0.37~ 1684.000 -1019.250 -999.250 -0.483 1810.000 -1019.250 -999.250 -0.464 1772.000 -1019.250 -999.250 1395.000 -1019.250 -999.250 -0.399 1548.000 -1019.250 -999.250 -0.470 1173.000 -1019.250 -999.25O -0.380 1370.O00 -1019.250 -999.250 -0.334 1091.000 -1019.250 -999.250 -0.285 1547.000 VALUE -1019.250 -999.250 -0.312 1643.000 DT NPHI ~CNL ILD DT NPHI FCNL DT NPH[ FCNL DT NPHI FCNL ILD DT NPHI FCNL DT NPHI FCNL ILD DT NPHI FCNL lED DT NPHI FCNb ILD DT NPHI FCNL ILD DT NPHi ~CNL IbD DT NPHI FCNL MNEMONIC iLO NPH I ~,CNL -99q. 22. 828. -999. -999. 58. 246. -99q. -999. 38. 437. -999. -999. 4~. 488. -99q. -999. 36. -999. -99q. 52. 317. -99q. -999. 41. 384. -99q. -999. 72. 191. -999. -990. 45. 357. -999. -999. 41. 458. -999. -999. 50. ]55. V ALU -999. -999. 40. 429. 25O 852 000 250 250 203 375 250 250 9lb 750 250 250 652 250 25O 25O 816 000 250 250 393 500 250 25O 895 750 250 250 007 375 25O 25O 313 000 25O 250 943 250 250 250 928 000 E 250 25O 82O 750 GR RHUB GR RHOB IbM GR RHO8 GR RHUB 1bM ibm GR RHUB ILM GR IbM GR RHUB RHUB GR RHUB ILM MNEMONIC GR RHOB 45.5{1 -999.250 -999.250 54.000 -999.250 -999.250 42.219 -999.250 -999.250 44.781 -999.250 -999.250 42.750 -999.250 -999.250 55.188 -999.250 -999.250 41.156 -999.250 -999.250 33.15b -999.250 52. 6 -999.250 -999.250 49.250 -999.250 -999,250 51.656 -999.250 VALUE -999.250 39.7~9 -999.250 CALl NRA'I SFLO CALl NRA'f SFLU CALl NRA~ SFLU CALl NRAT 8FLU CALl NRAT 8FLU CALl NRAT SFLO CALl NRAT Si,'bU CALl NRAI SFLU CALl NRAT 8FLO CALl NRAT SFLU CALl NRAT MNEMUNIC SFLU CALl NRA1 8.969 2.656 -999.250 8.984 4.594 -999.250 8.945 3.539 -999.250 8.945 3.797 -999.250 8.945 3.422 -999.250 8.938 4.273 -999,250 8.922 3.701 -999.250 8.320 5.383 -999.250 8.461 3.887 -999.250 8.609 3.705 -999.250 8.477 4.195 VALUE -999.250 8.563 3.b41 i200.000 SP -1019.250 GR -999.250 DRHO -0.311 NChL 1365.000 ~100.000 6P -1019.250 G? -999.250 DRHU -0.404 NCNb 1439.000 JO00. 000 8P -1019.250 GR -999.250 D~HLJ NCNb 1265.000 2900.000 SP -1019.250 GR -999.250 DRttU -0.408 NCNL 1815.000 2U00.000 SP -1019.250 GR -999.250 OHHU -0.340 NCNb lb28.000 2700.000 8P -1019.250 GR -999.250 D~HU -0.409 NCNb 1537.000 2600.000 8P -1019.250 GH -999.250 DRHU -0.4t2 NCNL 1731.000 2538.000 8P -1019.250 GH -999.250 t)HHU -0. 495 NCNb 1 ~115. 000 $IJMMAI4X U[' DA'[A PJ:,CURD,5 NUMBEM OF IqtsCUFtD,5: I191 bEmGIH [JF l-,tf,.COHD$: 966 BYTES L~NGIM [Jl* LAS'I RECORD: 90b BYTES ILD DT NPHI ECNL iLL UT NPHI FCNL ILD DT NPHI FCNL iLD DT NPHI FCNL DT NPHi FCNL ILD DT NPHI fCNL IBD DT NPHi FCNL DT NPHI FCNL -999,250 -999.250 48.920 3]g.250 -999.250 -999,250 54,883 311,500 -999,250 -999,250 18,340 270.000 -999,250 -999,250 41,748 451,750 -999,250 -999,250 44,33~ 415,500 -999,250 -999,250 42,725 378,000 -99q,250 -999.250 45.313 397.000 -999.250 -999.250 64.893 251.000 ibm GR ILM ibm GR GR RHOt~ GR RHUB iLM GR RHOW IbM GR ILM GR RHOB , , * , , , * * ,: .., , ,. 1024 BYIE$ FiLE II~A1LEH LENGTH: LF, NG'IH: b2 DYTE~ FILE NAME: tDIT .001 MAXIMUM PHYSICAL RECUHD NEXI ~ILE NAME: -999,250 53.813 -999,250 -999,250 40,719 -999,250 -999,250 47,b25 -999,250 -999,250 43,094 -999,250 -999,250 45,188 -999,250 -999,250 46,969 -999,250 -999.250 49,844 -999,250 -999.250 31.219 -999,250 CASI NRAT 8FbU CABI NRAI CALl NRAI SFbU CAbI NRAT $FbU CALl NRAi SFLU CALI NRAT SFLU CALl NRAT CALL NRAT -999,250 8,523 4,080 -999,250 8,586 4.414 -999,250 8,555 4,055 -999,250 8,586 3,693 -999,250 8.711 3,8]4 -999,250 8,648 3,74b -999.250 8,703 3,889 -999.250 8.703 4.961 T~PE £~ILE~ TAPE NANE: bl010 ~R~[CE NANE: EDIT TAPE CONIiNUA~I{JN NEXl IAPE COMM~NIS: O1 DATE: 80/ 9/24