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Home My WebLink About187-109Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/19/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240319 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 12/5/2023 AK E-LINE Plug/Cement/Cutter GP ST 18742 37 (AN 37) 50733203940000 187109 11/12/2023 AK E-LINE PERF IRU 241-01 50283201840000 221076 2/25/2024 AK E-LINE Perf/GPT KU 13-06A 50133207160000 223112 2/9/2024 AK E-LINE GPT MPU CFP-02 50029212580000 184242 3/13/2024 READ CaliperSurvey NCIU A-18 50883201890000 223033 12/13/2023 AK E-LINE GPT/Plug/Perf PBU L-122 50029231470000 203051 3/2/2024 AK E-LINE LowerPatchPacker PBU L4-14 50029219730000 189098 11/22/2023 AK E-LINE PERF SRU 241-33B 50133206960000 221053 3/4/2024 AK E-LINE GPT/Cmnt/CIBP/Perf Please include current contact information if different from above. T38648 T38649 T38650 T38651 T38652 T38653 T38654 T38655 T38656 GP ST 18742 37 (AN 37)50733203940000 187109 11/12/2023 AK E-LINE PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.21 11:50:20 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/15/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240315 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 12/6/2023 AK E-LINE Cement-JetCut BCU 13 50133205250000 203138 2/11/2024 AK E-LINE CIBP-Perf BCU 19RD 50133205790100 219188 2/20/2024 AK E-LINE Perf-CIBP BRU 232-26 50283200770000 184138 11/26/2023 AK E-LINE GPT-PLUG-PERF BRU 244-27 50283201850000 222038 2/27/2024 AK E-LINE GPT-Perf GP ST 18742 37 (AN- 37) 50733203940000 187109 11/22/2023 AK E-LINE Perf KBU 22-06Y 50133206500000 215044 11/3/2023 AK E-LINE GPT-PERF KBU 42-6 50133205460000 204209 2/16/2024 AK E-LINE Patch PBU L-122 50029231470000 203051 12/7/2023 AK E-LINE Patch NCIU A-12B 50883200320200 223053 12/6/2023 AK E-LINE Perf-GPT NCIU A-17 50883201880000 223031 12/10/2023 AK E-LINE Perf-GPT NCIU B-02 50883200900100 197210 3/9/2024 AK E-LINE GPT-Perf SRU 241-33B 50133206960000 221053 3/6/2024 AK E-LINE GPT-Cmnt-CIBP- Perf Please include current contact information if different from above. T38630 T38630 T38631 T38632 T38633 T38634 T38635 T38636 T38637 T38638 T38639 T38640 T38641 GP ST 18742 37 (AN- 37)50733203940000 187109 11/22/2023 AK E-LINE Perf Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.18 08:49:06 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/28/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240228 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# AN-37 50733203940000 187109 11/8/2023 HALLIBURTON RBT KBU 31-18 50133206490000 215024 2/22/2024 HALLIBURTON PressTemp KBU 42-6 50133205460000 204209 2/23/2024 HALLIBURTON PPROF KU 31-07X 50133204950000 200148 2/2/2024 HALLIBURTON PressTemp MPU C-13 50029213280000 185067 2/23/2024 READ CaliperSurvey MPU C-14 50029213440000 185088 2/23/2024 READ CaliperSurve MPU L-43 50029231900000 203224 2/14/2024 READ CaliperSurvey MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON COILFLAG TBU M-20 50733205870000 209093 1/1/2024 HALLIBURTON COILFLAG Please include current contact information if different from above. T38535 T38536 T38537 T38538 T38539 T38540 T38541 T38542 T38543 2/29/2024 AN-37 50733203940000 187109 11/8/2023 HALLIBURTON RBT Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 09:17:32 -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: ______________________ 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 11,741 feet See schematic feet true vertical 10,899 feet 11,282 feet Effective Depth measured 3,732 feet N/A feet true vertical 3,591 feet N/A feet Perforation depth Measured depth 3,673 feet True Vertical depth 3,701 feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2 # 5,814 (MD) 5,488 (TVD) Packers and SSSV (type, measured and true vertical depth) N/A & N/A 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:Granite Point Gas 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 5 323-503 Sr Pet Eng: 10,490psi Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager N/A 268 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) 0 Gas-Mcf MD 268 N/A 31 Size 267 614 0 00 0 00 13-3/8" 9-5/8" 9,910psi 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 187-109 50-733-20394-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018742 Granite Point / Granite Point Gas Granite Pt St 18742 37 Plugs Junk measured Length measured TVD Production Liner 10,150 790 1,989 Casing Structural 9,389 9,886 5" 10,150 10,687 11,644 10,804 571 3,522 615Conductor Surface Intermediate 30" 20" 6,620psi 10,000psi 2,125psi 5,020psi 7,930psi 10,900psi 3,522 3,390 Burst Collapse 1,500psi 2,260psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.12.21 10:39:07 - 09'00' Dan Marlowe (1267) By Grace Christianson at 1:55 pm, Dec 21, 2023 _____________________________________________________________________________________ Updated By: JLL 12/04/23 SCHEMATIC Anna Platform Well: AN-37 Last Completed: 06/2008 PTD: 187-109 API: 50-733-20394-00-00 PBTD =4,717 TD =11,741 Max Hole Angle = 31 @ 8200 Dog Legs: 4.1° @ 1400 C-5 5 1 2 20 Top of Fill 11,252 3 13-3/8 9-5/8 7-5/8 C-6 C-7 30 3,716 DV Tool 4 5 TOC @ 3,130 Bel 109 Bel 103 Bel 110 Bail Fill to 3,701 11/28/23 RKB to Sea Level (MLW) = 127 KB 33.4 CASING DETAIL Size Wt Grade Conn ID Top Btm 30 320 STR Weld Surf 268 20 133 X56 19 Surf 615 13-3/8 68 N-80 Butt 12.415 Surf 3,522 9-5/8 53.5 N-80 Butt 8.535 Surf 10,150 7-5/8 39 C-95 FL4S 6.625 9,897 10,687 5 18 L-80 Butt 4.276 10,440 11,644 TUBING DETAIL 3-1/2 9.2 N-80 Butt 2.992 Surf 5,814 JEWLRY DETAIL No Depth (MD)ID Item 33.40 Hanger 1 3,732 CIBP (11/21/23) 2 3,806 CIBP (11/15/23) 3 5,814 2.992 3-1/2 N-80 9.2# Buttress Kill String 4 5,775 Northern Solutions Pump through cement retainer (10/3/23) 5 10,672 Spiral Plug with 25 cement (ToC = 10,647 MD) (10/3/23) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status B110 3,673 3,701 3,535 3,563 28 11/22/23 Open (Re-perf w/ 10 strip gun) B109 3,738 3,754 3,596 3,612 16 11/16/23 Isolated (Re-perf w/ 10 strip gun) B103 3,812 3,842 3,667 3,695 30 11/14/23 Isolated (Re-perf w/ 10 strip gun) C-5 10,714' 10,784' 9,912' 9,997' 70' 8/31/1996 Abandoned (10/3/23) C-5 10,716' 10,784' 9,913' 9,977' 68' 5/4/1988 Abandoned (10/3/23) C-5 10,798' 10,882' 9,991' 10,070' 84' 5/4/1988 Abandoned (10/3/23) C-5 10,798' 10,882' 9,991' 10,070' 84' 8/31/1996 Abandoned (10/3/23) C-6 11,076' 11,091' 10,254' 10,269' 15' 8/31/1996 Abandoned (10/3/23) C-7 11,154' 11,176' 10,329' 10,351' 22' 8/31/1996 Abandoned (10/3/23) C-7 11,225' 11,237' 10,398' 10,410' 12' 3/14/1988 Abandoned (10/3/23) C-7 11,225' 11,236' 10,398' 10,409' 11' 8/31/1996 Abandoned (10/3/23) C-7 11,307' 11,346' 10,477' 10,515' 39' 3/14/1988 Abandoned (10/3/23) C-7 11,380' 11,446' 10,548' 10,612' 66' 3/14/1988 Abandoned (10/3/23) OPEN HOLE / CEMENT DETAIL 20"26 Hole: Pumped 900sxs of 13.7ppg Class G lead followed by 500sxs of 15.9ppg tail cement.Saw cement to surface. 13-3/8" 17-1/2 Hole: Pumped 1800sxs of 14.7ppg Class G lead followed by 500sxs of 15.9ppg tail cement. No cement to surface. Performed top job down 1-1/8 tubing from 207. Pumped 234sxs of 16.0ppg class G with good returns.Cement noted to surface. 9-5/8" 12-1/4" Hole: Pumped 250sxs (2.19 yield = 97 bbls) 12.5ppg class G lead cement followed by 500sxs (104bbls) of 15.8ppg class G tail cement with full returns.6/14/08 USIT shows cement up to 6260 md. Pumped 2nd stage cement job through DV collar at 3716 MD with 500sxs (100bbls) 15.8ppg class G cement. 6/14/08 USIT log shows good cement from 3590 3760 MD with partial cement extending as deep as 3860 and as high as 3530 MD. 7-5/88-1/2 Hole: Pumped 300sxs of 15.8ppg class G cement. Full returns.3/6/88 CBL shows ToC at ToL. 5 6-1/2 Hole: Pumped 768sxs of 15.8ppg class G cement. 3/6/88 CBL shows top good cement at 10,940 MD. 3/1/88 Liner lap below a test packer set at 10,400 passed to 3000psi for 30 minutes.Liner lap has cement integrity (no packer, just hanger). 3-1/2Pumped 180 bbls cement, bumped plug 8 bbls early @42 bbls displacement ToC in tubing = 4,717 (11/7/23 SL tag). 172 bbls cement into IA, with 8% losses.ToC at 3,130 MD (11/8/23 CBL) Fish 11,282 APRS Jet Cutter String Inside 2-7/8 Tubing (Fish Length = 199.48) 10,787 GHOST: BHA Assembly 192 Fish, off of sidetrack bore Well Name:GPF AN-37 API #:50733203940000 Field:Granite Point Field Start Date:10/1/2023 Permit #:187109 Sundry #:323-503 End Date:11/29/2023 10/1/2023 10/3/2023 10/31/2023 11/2/2023 11/6/2023 11/8/2023 11/12/2023 11/13/2023 11/14/2023 Activity Report Travel to Anna platform. PJSM/JSA/PTW w/production. Transfer cement from pods. Fill 400 bbl OTT w/FIW. Prep wellhead Tbg, FL, and IA w/2" 1502 flanges. Pre-load 1.75" composite ball on swab. Load 3" wiper plug on top of ball. LOTO swab valve. R/U HP ball drop manifold to tree cap flange. SDFN. PJSM w/Production & OE. PT cement lines 250 psi low / 2500 psi high. Establish circulation Tbg x IA and step rate 1-4 bpm w/FIW. Strap tanks. Pump cement job as per program: 180 bbls of 15.8 ppg cement down tubing taking returns up IA. At 180 bbls cement away, launch 1.75" ball and 3" wiper plug. Confirm ball and wiper plug cleared surface. Pumped 42 bbls of FIW displacement and bumped plug 8 bbls early. Discuss plan forward w/OE. Bleed tubing pressure to 1500 psi and lock in pressure on tubing. Calculated Tbg TOC = 4,855'. Calculated IA TOC w/10% losses = 3,184'. Blow down surface lines and get final tank straps. RDMO cement equipment and release crew. MIRU EL. PT to 250low / 2500 high. Set plug at 10,672'. Dump 2' of ceramic beads, and 3' cement. RDMO to WoC PT to 250low / 2500 high. GPT, Dump cement up to 10,647'. Set cement retainer MIT-IA Passed to 2300psi MIT-T Passed to 2000psi Travel from Stealhead to Anna Platform. Permit/PJSM with Operations. Rig up AK Eline. PT PCE 250psi Low / 2500psi High. RIH with GR/CCL/Press/Temp Log. Find Fluid Level at 4404'. Tag TOC at 4653'. Pooh. Secure well and lay down for the night. Pick up Lubricator. Make up & RIH with 2-3/8" x 30' Perf Gun #1. Rig up Slb N2 to Eline pump'n sub. N2 pump PT 250 Low/2500psi High. Pressure up Tbg to 1136psi. Correlate & Perforate Interval: 3812' - 3842'. See small pressure change. Pooh. All shots fired. Perf Gun covered with what apears to be formation mud. Give sample to Ops. Turn over to Ops to try and flow. Ops bled Tbg to 500psi with no pressure build up. Run GPT Log. Nearly Tagged at 3809' then fell thru. Continue RIH. See FL at 4294'. Tag TOC at 4647'. Puh to 3000'. Ops bled Tbg to 76psi. RBIH with GPT. Tag at 4647' (same depth). Unable to find Fluid Level. Pooh. Press/Temp sensors plugged with gunk. Lay down for the night. SITP built less than 10psi overnight from 76psi to 83psi. Pick up Lubricator. RIH with 2.66 G-Ring with spangs & CCL. Tag at 3823. Pick up, RBIH and fall right thru. Drift clean to 4050. Reciprocate through trouble area. Pooh. RIH with 2.5 x 10 Spiral Strip Gun (41 charges total). Pressure up well with N2 to 509psi. Re-perf interval 3812 3822. Pooh. Turn over to Ops to try and flow with no success. Run GPT Log. Tag at 4239' (408' higher than yesterdays tag at 4647'). No fluid level seen. Pooh. RIH with 2.77" G-Ring with spangs & CCL. Daily Operations: Run CBL. Field pick ToC at 3120' MD. Drift Dummies Page 1 of 2 Well Name:GPF AN-37 API #:50733203940000 Field:Granite Point Field Start Date:10/1/2023 Permit #:187109 Sundry #:323-503 End Date:11/29/2023 11/15/2023 11/16/2023 11/18/2023 11/19/2023 11/21/2023 11/22/2023 11/28/2023 11/29/2023 Activity Report Daily Operations: SITP has built form 500psi to 740psi over last 48hrs. RU SL. PT to 250 low / 2500 high. Fished out EL toolstring and strip gun at 3693', full recovery. All shot fired. RIH w/2.80" g-ring tag 3804'. L/d SL SITP 1096psi. R/u EL, RIH and Perf BEL-109 sands at 3738-3754',POOH, all shots fires guns dry.Bleed well to 500psi, monitored pressure trend flat line. RIH with 10' strip gun, pref 3743-3753', tool stuck. Worked line to 1750lbs with jar hits moved ~3'. Held wire with 1750lbs of tension and came free. POOH confirmed wire pulled out of rope socket. Secured well SDFN. SITP built form 85psi to 105psi overnight. R/u AK E-line, RIH w/CCL and 2.66" GR tag fill high 3293', Unable to work down. RIH w/CCL and slimhole (1.75" max OD), tag at 3295'. Pressure up to 2500psi with N2 and push fill away. RIH w/CCL and slimhole 1.75" max OD, tag 3847'. RIH w/2.52" GR tag 3900'. RIH w/GPT tag 3900' log to 3100' no fluid found. Town thinks the gunk is likely from behind 9-5/8" casing. Decide to plug back. RIH w/2.50" CIBP correlate and set top of plug at 3806'. SDFN. SITP has built from 55psi to 100psi over past 5.5 days. BAIL FILL FROM 3672'KB TO 3701'KB - DISCOVER Strip gun DEBRIS below existing bottom perf. - DIFFICULT TO GAIN HOLE . bleed SITP to 0psi SITP still 0 psi. SL find FL at 2400'. Given 1200'+ of water influx, BEL-110 appears to be wet. tagged mid-perf at 3690'. work bailer to 3700'. Get soupy mud. Project complete. No extended flow test needed. R/u SL, RIH 2.8" G-ring found FL at 3480', continued RIH and tag 3804'md. POOH. RIH w/2.5" bailer to 3804' retrieved fluid sample. POOH. R/d SL and released crew. SITP built form 80psi to 180psi over last 48hrs. Given 300'+ of water influx, appears BEL-109 is wet. Decide to plug back. Pressure up well t/ 2500/3000psi w/N2 to push fluid away, R/U e-line RIH w/ GPT verify fluid level @ top of perfs 3738' good, RIH w/2.75" CIBP, set @ 3732', POOH, tubing pressure 2443psi, SDFN Bleed well down t/1100psi, RIH perf B-110 3673-3701',with 2 3/8" gun bleed down t/200psi rih w/ strip gun re-shoot 3683-3693, did get blown up hole some but no pressure increase open well to flare bleed down t/55psi, RIH w/ 2.5" strip gun set down @ 3673' unable to pass. POOH r/d e-line had silt/clay on bottom of gun. Page 2 of 2 3847'. RIH w/2.52" GR tag 3900'. RIH w/GPT tag 3900' log to 3100' no fluid found. Town thinks the gunk is likely from behind 9-5/8" casing. Decide to plug back. RIH w/2.50" CIBP correlate and set top of plug at 3806'. SDFN. SITP still 0 psi. SL find FL at 2400'. Given 1200'+ of water influx, BEL-110 appears to be wet. tagged mid-perf at 3690'. work bailer to 3700'. Get soupy mud. Project complete. No extended flow test needed. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/25/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231025 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 241-23 50283201910000 223061 9/27/2023 AK E-LINE CBL BRU 241-23 50283201910000 223061 10/4/2023 AK E-LINE GPT/Plug/Perf GP ST 18742 37 50733203940000 187109 9/30/2023 AK E-LINE Plug IRU 41-01 50283200880000 192109 9/22/2023 AK E-LINE Perf/GPT LRU C-02 50283201900000 223057 9/28/2023 AK E-LINE Perf LRU C-02 50283201900000 223057 9/25/2023 AK E-LINE Perf/GPT MPU K-13 50029226550000 196040 10/1/2023 AK E-LINE GPT/Plug/Perf NCI A-05 50883200250000 169032 9/27/2023 AK E-LINE Perf Please include current contact information if different from above. T38097 T38097 T38098 T38099 T38100 T38100 T38101 T38102 10/25/2023 GP ST 18742 37 50733203940000 187109 9/30/2023 AK E-LINE Plug Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.25 11:33:48 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,741 11,282 Casing Collapse Structural Conductor 1,500psi Surface 2,260psi Intermediate 6,620psi Production 10,000psi Liner 10,490psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Production Test, N2 907-777-8503 Operations Manager Perforation Depth TVD (ft): 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. Ryan Rupert ryan.rupert@hilcorp.com Authorized Name and Digital Signature with Date: Tubing Size: Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 TVD Burst 10,900psi AOGCC USE ONLY 9,910psi 9.2# / N-80 5,814' Tubing Grade: Tubing MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018742 187-109 GRANITE PT ST 18742 37 (AN-37)CO 76A UndefinedGranite Pt 7,930psi 3,522' Length 50-733-20394-00-00 Hilcorp Alaska, LLC 3,522' MD 267' PRESENT WELL CONDITION SUMMARY 268' Size 571' 790' 5" See Attached Schematic 9,886'7-5/8" 268' 30" 20" 10,150' September 15, 2023 11,644'1,989' 3-1/2" 10,804' 9,389' 10,687' Perforation Depth MD (ft): 10,150' 2,125psi 5,020psi 614' 3,390' N/A2,081psi Middle Kenai Oil 9-5/8" 615' N/A N/A 10,899 11,252 10,423 13-3/8" See Attached Schematic 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 4:08 pm, Sep 01, 2023 323-503 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.09.01 11:40:28 - 08'00' Dan Marlowe (1267) MDG 9/14/2023 Well Class after proposed work: 10-404 DSR-9/1/23 Gas Well Status after proposed work: Tyonek perfs must be squeezed as described by bjm notes in attached procedure before perforating Beluga. Perforate New Pool Statewide spacing governs the Undefined Gas Pool. MDG BJM 9/14/23 Waiver of 20 AAC 265(d) approved for temporary 30 day flow test without SSSV. 09/15/23 RBDMS JSB 091523 Gas Production Test Well: Anna-37 Well Name:Anna-37 API Number:50-733-20394-00-00 Current Status:Long term Shut-in Water injector Permit to Drill Number:187-109 First Call Engineer:Ryan Rupert (907) 301-1736 (c)Leg #2 (East corner) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:2628 psi @ 5,475’ TVD 0.48pi/ft gradient to deepest proposed Tyonek perf Max. Potential Surface Pressure: 2081 psi Using 0.1 psi/ft Brief Well Summary Anna-37 is a long term shut in well. It was an oil producer since drilled in 1988 until the rates were uneconomic in 2001. Water injection was approved with a variance in place for packer-less injection. In 2008 Chevron performed a RWO to convert the well to a water injector with a packer. The RWO was aborted when a leak in the 9-5/8” casing was discovered around a DV collar at 3700 -3808’ MD. There are some potential gas sands in this well. This production test targets Beluga Gas Sands, and the Tyonek gas sands opportunistically. The original completion in 1988 included a 9-5/8” DV collar at 3716’ MD. A USIT run in 2008 shows cement across the below gas sands behind the 9-5/8” casing. Hilcorp proposes to cement the existing kill string in place, and perforate/test the Tyonek gas sands, and then the Beluga gas sands. Hilcorp is requesting to production test these sands without an SSSV to evaluate the economic viability for long term production. A functional SSV system will be in place for the duration of the test. If viable long term, a functional SSSV would be installed (future sundry). The goal of this project is to production test Tyonek, then Beluga gas sands for full time production. Hilcorp is requesting to production test these sands without an SSSV to evaluate the economic viability for long term production. Gas Production Test Well: Anna-37 Pertinent information: - Max inclination down to perf interval: 31 degrees at 8200’ MD - Reservoir sections o Gas pool No gas pool defined for Granite Point Field Statewide requirements apply The below proposal conforms with these requirements o Beluga gas sands: 3,407’ – 4,263’ MD (3,280’ - 4,089’ TVD) o Tyonek gas sands: 4,263’ – 9,853’ MD (4,089’ – 9,124’ TVD) o Top Middle Kenai oil pool is at 9,853’ MD / 9,124’ TVD. (To be abandoned as part of this procedure) - Production test o Hilcorp requests to test the gas sands for no more than 30 total days of total on time o Production to be routed into existing facilities and sold o Production will be measured for production accounting / regulatory tracking -SSSV: Hilcorp requests a waiver to 20 AAC 25.265(d) to produce this well without an SSSV for no more than 30 days of total ontime Well History: - 2008: Chevron performs RWO to convert to full time water injector o 6/13/08: Casing MIT above a test packer set at 10,023’ MD FAILED Bled from 2700psi to 2000psi in 18 minutes Took ~7.3bbls to fill casing after each 30 minute attempt (0.25bpm LLR) o 6/14/08 MIT of 9-5/8” casing PASSED against an RTTS set at 3700’ MD o 6/15/08: USIT run from 9900’ to surface for caliper and cement evaluation (see schematic for results) o 6/16/08: Plug set at 10,450’ MD RTTS set at 3808’ MD MIT of 9-5/8” casing from 3808 – 10,450’ MD PASSED to 2700psi Leak is between 3700 – 3808’ MD (likely DV collar at 3716’ MD) o 6/27/08: Could not recover fish in 5” liner. Suspended RWO operations - April-2002: final month of water injection. Injected ~95kbbls water (~370bwpd average) - June-2001: water injection started - March-2001: Oil production rates down to <5bopd - 1988: D&C as oil well on jet pump Gas Production Test Well: Anna-37 EL abandon Oil pool: 1. MIRU EL 2. PT lubricator to 250psi low / 2500psi high 3. RIH and set expandable plug at ±10,675’ MD 4. Dump bail 25’ cement on top of plug to isolate oil pool (19 gallons) 5. RDMO EL Cement Kill String: 1. MIRU cementers 2. PT cement lines to 2500psi 3. Establish circulation down tubing and up IA 4. Pump volumetric cement job cementing kill string in place as follows: a.Target ToC in IA at 3000’ (above Beluga gas sands, and above 13-3/8” shoe) b. Pump 168bbls cement adjusting for any losses out leaking DV collar c. Leave 2bbls (230’) inside bottom of kill string (new PBTD =±5,584’ MD) 5. WoC 6. MIT-IA against new cement packer to 2200psi (charted) Gas Production Test Well: Anna-37 Tyonek E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. RIH and perforate individual Tyonek gas sands within the interval below per RE/Geo 4. RDMO EL Beluga E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3.Set CIBP within 50’ of top Tyonek perf and dump bail 25’ cement on top (10gal). Skip this step if no Tyonek perf’d prior. 4. RIH and perforate Beluga gas sands per RE/Geo 5. RDMO EL CONTINGENCY: (if any zone makes unwanted solids or water) 1. RU nitrogen to 3-1/2” kill string and PT lines to 2500psi 2. Pressure up on tubing and displace water back into formation 3. MIRU E-line and pressure control equipment 4. PT lubricator to 250psi low / 2500psi high 5. Set 3-1/2” CIBP or patch per OE 6. RDMO Nitrogen and EL Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Standard well procedure – N2 operations Zone Top MD Bottom MD Top TVD Bottom TVD Tyonek ±4,700’ ±5,700’ ±4,489’ ±5,384’ Zone Top MD Bottom MD Top TVD Bottom TVD TOTAL B110 ±3,673’ ±3,701’ ±3,535’ ±3,563’ ±28 B109 ±3,738’ ±3,754’ ±3,596’ ±3,612’ ±16 B103 ±3,812’ ±3,860’ ±3,667’ ±3,712’ ±48 This step 3. not required if Tyonek squeeze was performed as shown above. Tag & PT TOC in tbg per 20 AAC 25.112(g)(2). -bjm Squeeze cement through Tyonek perfs before adding Beluga perfs. Squeeze enough cement to place 100' above and below Tyonek perfs outside 9-5/8" casing, and leave equivalent height of cement inside tubing. -bjm Run CBL from tubing tail to above TOC. Submit results to AOGCC and obtain approval before proceding with perforations. -bjm _____________________________________________________________________________________ Updated by DMA 07-07-23 SCHEMATIC Anna Platform Well: AN-37 Last Completed: 06/2008 PTD: 187-109 API: 50-733-20394-00-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 30”320 STR Weld Surf 268’ 20”133 X56 19”Surf 615’ 13-3/8”68 N-80 Butt 12.415”Surf 3,522’ 9-5/8”53.5 N-80 Butt 8.535”Surf 10,150’ 7-5/8”39 C-95 FL4S 6.625”9,897’10,687’ 5”18 L-80 Butt 4.276”10,440’11,644’ TUBING DETAIL 3-1/2”9.2 N-80 Butt 2.942”Surf 5,814’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 33.40’Hanger 1 5,814’5,488’2.942”3-1/2” N-80 9.2# Buttress Kill String PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status Description C-5 10,714'10,784'9,912'9,997'70'8/31/1996 Open 2-1/8" Enerjet @ 6 SPF @ 90D C-5 10,716'10,784'9,913'9,977'68'5/4/1988 Open 3.375" 4 - 500 SPF @ 90D, 272 C-5 10,798'10,882'9,991'10,070'84'5/4/1988 Open 3.375" 4 - 500 SPF @ 90D, 336 C-5 10,798'10,882'9,991'10,070'84'8/31/1996 Open 2-1/8" Enerjet @ 6 SPF @ 90D C-6 11,076'11,091'10,254'10,269'15'8/31/1996 Open 2-1/8" Enerjet @ 6 SPF @ 90D C-7 11,154'11,176'10,329'10,351'22'8/31/1996 Open 2-1/8" Enerjet @ 6 SPF @ 90D C-7 11,225'11,237'10,398'10,410'12'3/14/1988 Open 3.375" 4 SPF @90D, 48 C-7 11,225'11,236'10,398'10,409'11'8/31/1996 Open 2-1/8" Enerjet @ 6 SPF @ 90D C-7 11,307'11,346'10,477'10,515'39'3/14/1988 Open 3.375" 4 SPF @90D, 156 C-7 11,380'11,446'10,548'10,612'66'3/14/1988 Open 3.375" 4 SPF @90D, 164 OPEN HOLE / CEMENT DETAIL 20"26” Hole: Pumped 900sxs of 13.7ppg Class G lead followed by 500sxs of 15.9ppg tail cement.Saw cement to surface. 13-3/8" 17-1/2” Hole: Pumped 1800sxs of 14.7ppg Class G lead followed by 500sxs of 15.9ppg tail cement. No cement to surface.Performed top job down 1-1/8” tubing from 207’. Pumped 234sxs of 16.0ppg class G with good returns.Cement noted to surface. 9-5/8" 12-1/4" Hole: Pumped 250sxs (2.19 yield = 97 bbls) 12.5ppg class G lead cement followed by 500sxs (104bbls) of 15.8ppg class G tail cement with full returns.6/14/08 USIT show’s cement up to 6260’ md. Pumped 2nd stage cement job through DV collar at 3716’ MD with 500sxs (100bbls) 15.8ppg class G cement. 6/14/08 USIT log shows good cement from 3590 – 3760’ MD with partial cement extending as deep as 3860’ and as high as 3530’ MD. 7-5/8”8-1/2” Hole: Pumped 300sxs of 15.8ppg class G cement. Full returns.3/6/88 CBL shows ToC at ToL. 5” 6-1/2” Hole: Pumped 768sxs of 15.8ppg class G cement. 3/6/88 CBL shows top good cement at 10,940’ MD.3/1/88 Liner lap below a test packer set at 10,400 passed to 3000psi for 30 minutes.Liner lap has cement integrity (no packer, just hanger). Fish 11,282’APRS Jet Cutter String Inside 2-7/8” Tubing (Fish Length = 199.48’) 10,787’GHOST: BHA Assembly – 192’ Fish, off of sidetrack bore _____________________________________________________________________________________ Updated by CRR 08-30-23 PROPOSED Anna Platform Well: AN-37 Last Completed: 06/2008 PTD: 187-109 API: 50-733-20394-00-00 PBTD =11,575’ TD =11,741’ Max Hole Angle = 31 @ 8200’ Dog Legs: 4.1° @ 1400’ C-5 5” 1 20” Top of Fill 11,252 3 13-3/8” 9-5/8” 7-5/8” C-6 C-7 30” 3,716 DV Tool B110 B109 B103 Tyonek RKB to Sea Level (MLW) = 127’ KB 33.4’ 2 Top Middle Kenai Oil Pool @ 9853’ MD Top Tyonek Gas Sands @ 4263’ MD Top Beluga Gas Sands @ 3407’ MD CASING DETAIL Size Wt Grade Conn ID Top Btm 30” 320 STR Weld Surf 268’ 20” 133 X56 19” Surf 615’ 13-3/8” 68 N-80 Butt 12.415” Surf 3,522’ 9-5/8” 53.5 N-80 Butt 8.535” Surf 10,150’ 7-5/8” 39 C-95 FL4S 6.625” 9,897’ 10,687’ 5” 18 L-80 Butt 4.276” 10,440’ 11,644’ TUBING DETAIL 3-1/2” 9.2 N-80 Butt 2.942” Surf 5,814’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 33.40’ Hanger 1 5,814’ 5,488’ 2.942” 3-1/2” N-80 9.2# Buttress Kill String 2 ±4,675’ ±4,467’ Plug w/ 25’ cement; TOC @ ±4,650’ 3 ±10,675’ ±98,75’ Plug w/ 25’ cement; TOC @ ±10,650’ Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status B110 ±3,673’ ±3,701’ ±3,535’ ±3,563’ ±28’ Proposed TBD B109 ±3,738’ ±3,754’ ±3,596’ ±3,612’ ±16’ Proposed TBD B103 ±3,812’ ±3,860’ ±3,667’ ±3,712’ ±48’ Proposed TBD Tyonek ±4,700’ ±5,700’ ±4,489’ ±5,384’ ±1,000’ Proposed TBD C-5 10,714' 10,784' 9,912' 9,997' 70' 8/31/1996 Isolated C-5 10,716' 10,784' 9,913' 9,977' 68' 5/4/1988 Isolated C-5 10,798' 10,882' 9,991' 10,070' 84' 5/4/1988 Isolated C-5 10,798' 10,882' 9,991' 10,070' 84' 8/31/1996 Isolated C-6 11,076' 11,091' 10,254' 10,269' 15' 8/31/1996 Isolated C-7 11,154' 11,176' 10,329' 10,351' 22' 8/31/1996 Isolated C-7 11,225' 11,237' 10,398' 10,410' 12' 3/14/1988 Isolated C-7 11,225' 11,236' 10,398' 10,409' 11' 8/31/1996 Isolated C-7 11,307' 11,346' 10,477' 10,515' 39' 3/14/1988 Isolated C-7 11,380' 11,446' 10,548' 10,612' 66' 3/14/1988 Isolated OPEN HOLE / CEMENT DETAIL 20"26” Hole: Pumped 900sxs of 13.7ppg Class G lead followed by 500sxs of 15.9ppg tail cement.Saw cement to surface. 13-3/8" 17-1/2” Hole: Pumped 1800sxs of 14.7ppg Class G lead followed by 500sxs of 15.9ppg tail cement. No cement to surface. Performed top job down 1-1/8” tubing from 207’. Pumped 234sxs of 16.0ppg class G with good returns.Cement noted to surface. 9-5/8" 12-1/4" Hole: Pumped 250sxs (2.19 yield = 97 bbls) 12.5ppg class G lead cement followed by 500sxs (104bbls) of 15.8ppg class G tail cement with full returns.6/14/08 USIT show’s cement up to 6260’ md. Pumped 2nd stage cement job through DV collar at 3716’ MD with 500sxs (100bbls) 15.8ppg class G cement. 6/14/08 USIT log shows good cement from 3590 – 3760’ MD with partial cement extending as deep as 3860’ and as high as 3530’ MD. 7-5/8”8-1/2” Hole: Pumped 300sxs of 15.8ppg class G cement. Full returns.3/6/88 CBL shows ToC at ToL. 5” 6-1/2” Hole: Pumped 768sxs of 15.8ppg class G cement. 3/6/88 CBL shows top good cement at 10,940’ MD. 3/1/88 Liner lap below a test packer set at 10,400 passed to 3000psi for 30 minutes.Liner lap has cement integrity (no packer, just hanger). Fish 11,282’ APRS Jet Cutter String Inside 2-7/8” Tubing (Fish Length = 199.48’) 10,787’ GHOST: BHA Assembly – 192’ Fish, off of sidetrack bore STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. • yw\�\�j/j�s� THE STATE Alaska Oil and Gas "' °fALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O LA5_1°' Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Luke Keller Drilling Engineer SCANNED MAY 9 2014 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite PT ST 18742 37 (AN 37) Sundry Number: 313-614 Dear Mr. Keller: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. 'oerster 2 � Chair DATED this / day of December, 2013. Encl. Ago ► D STATE OF ALASKA 11 ,,\'' NOV 21 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION i1,' APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug for Redrill 0• Perforate New Pool 0 Repair Well 0 Change Approved Program 0 Suspend❑ Plug Perforations❑ Perforate ❑ Pull Tubing 0 Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory 0 Development 0 187-109 3.Address: Stratigraphic 0 Service 0 6.API Number. 3800 Centerpoint Drive,Suite 100,Anchorage,AK 99503 50-733-20394-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? NA _ Granite PT ST 18742 37(AN-37) • Will planned perforations require a spacing exception? Yes 0 No Q --7- 9.Property Designation(Lease Number): 9a.li 10.Field/Pool(s): ADLO18742 C Granite Point Unit/Middle Kenai Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,741' , 10,898' • 11,252' 10,423' NONE 11,282'MD - Casing Length Size MD TVD Burst Collapse Structural 268' 30",320#,Weld 268 267' Conductor 571' 20",133#,K55 615' 614' 2,125 psi 1,500 psi Surface 3,522' 13-3/8",68#,N80 3,522' 3,390' 5,020 psi 2,260 psi Intermediate 10,150' 9-5/8",53.5#,N80 10,150' 9,389' 7,930 psi 6,620 psi Production 790' 7-5/8",39#,S95, 10,687' 9,886' 10,900 psi 10,000 psi Liner 1,989' 5",18#,L80 11,644 10,804' 9,910 psi 10,490 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Attached / Attached 3.5" N80 9.2#Buttress 5,814' Packers and SSSV Type: NA Packers and SSSV MD(ft)and ND(ft): NA 12.Attachments: Description Summary of Proposal Q • 13.Well Class after proposed work: 1�ty Detailed Operations Program p BOP Sketch 0 • Exploratory ❑ Stratigraphic❑ Development[1 Service [✓1' t`\4)' 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/15/2013 Oil t, Gas ❑ WDSPL ❑ Suspended [2f 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: ( GSTOR 0 SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Luke Keller Email Ikeller(a,hilcorp.com Printed Name Luke Kell r Title Drilling Engineer Signature idLlone 9077778395 Date 11/21/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity , BOP Test MechanicalIntegrityTest ❑ Location Clearance El Other: 300e i !S•, Qo l GS 14— ��o 7 J— RBDMS`� MAY 0 9 2014 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /(, 14 0 APPROVED BY Approved by: ae6 ,t, COMMISSIONER THE COMMISSION Date: (Z – 3‘ — /d3 ci,bno en„.en Form 10-403(Rev ed10/ 01 ) A pro „..10- /p v p a a or 2 onths from the date of appr7ral. Attachments in Duplicate ►llzl1 I� (\ I f1 , itAt 'i'/f'.ZG•l3 11 Hilcorp Luke Keller Hilcorp Alaska, LLC Emu Co Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 11/21/2013 Tel 907 777 8369 Email Ikeller@hilcorp.com Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Anna Platform, Granite PT ST 18742 37(Anna 37) Dear Commissioner, Enclosed for review and approval is the 10-403"Plug for Redrill"to permanently plug and abandon the Granite PT ST 18742 37 wellbore.v This well has been selected for re-2-1112-1i the new well will be called Granite PT ST 18742 37A. Anna 37 is currently shut in. It was last used as a dual string producer, but an attempt was made to convert the well to a water injector.' In 2008, Chevron conducted some MITs of the wellbore and J J S determined the DV tool in the 9-5/8" casing to be leaking (3,716' MD). A successful test of the doll/ . 4%) wellbore from 3,808'to 10,450'to 2700 psi was conducted on 6-17-2008. wt`' .,eft' to �/ ika c t`' Z 1 � doll d � g`d �` A summary of the operations within this sundry are detailed below: ACV(• u04 G� 4 f� • Kill well, Remove tree, N/U &test BOP. �- t QUI.La trit ,N c� ,fq • Pull 3-1/2" kill string. �L �U�,gyv �� ,�e� • P&A wellbore with cement. �� 1 (,N� t��'� Piilk • Set&test CIBP at 3,650'. (9-5/8"53.5#N-80). v ``4'n �pl►� • Cut and pull 9-5/8"casing to 2500' MD. ` iry 1 • Clean out run with 12-1/4"clean out assy. i�L 1 • Run and set Whipstock, mill 12-1/4"window at 2500', FIT to 12 ppg. A separate 10-401 will be submitted to the AOGCC that will cover operations related to drilling and completing the new wellbore,Anna 37A. Slot recovery operations are expected to commence approximately December 15th, 2013 depending on the progress of other ongoing projects on the Monopod and Anna Platforms. If you have any questions, please don't hesitate to contact myself at 777-8395 or Paul Mazzolini at 777-8369. Sincerely, r XI' Luke Keller Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 H Hilcorp Alaska, LLC Anna 37 Slot Recovery Program Anna Platform Rig 428 Granite Point Field Revision 0 Nov 14th, 2013 . El I Anna Slot Recove#ry37 Procedure Hilcorp Enemy Company Contents 1.0 Background/Objective 2 2.0 Plug &Abandonment Plan Summary 2 3.0 Well Information 3 4.0 BOP Test Summary 4 5.0 Kill Well/N/D Tree 5 6.0 BOP Installation & Test 5 7.0 Pull 3-1/2"tubing and P&A wellbore 6 8.0 Cut and Pull 9-5/8"casing. 7 9.0 Mill 12-1/4"Window 9 9.1 M/U below clean out assy and TIH to top of 9-5/8"casing stub at 2500' MD. 9 10.0 Whipstock Setting Procedure: 11 11.0 Drilling 12-1/4"Hole Section 13 12.0 BOP Schematic 14 13.0 Wellhead Schematic 15 14.0 Anna Slot Diagram 16 15.0 Existing Wellbore Diagram 17 16.0 Planned Wellbore Diagram 18 17.0 Anna Directional Survey 19 18.0 MASP Calculations 22 Anna Platform II #37 Slot Recovery Procedure Hilcorp Energy r 1.0 Background/Objective Anna 37 has been identified as a candidate for redrilling,targeting the Hemlock formation to the South. Integrated subsurface and 3-D geological interpretations, in conjunction with subsurface and previous production data indicate that oil reserves are unbooked and not recoverable in existing wellbores. Anna 37 is currently shut in. It was last used as a dual string producer, but an attempt was made to convert the well to a water injector. In 2008, Chevron conducted some MITs of the wellbore and determined the DV tool in the 9-5/8"casing to be leaking(3,716' MD). A successful test of the wellbore from 3,808' to 10,450' to 2700 psi was conducted on 6-17-2008. Objectives of the slot recovery are: • Permanently plug and abandon the Anna 37 wellbore to a depth of 3,650' MD. • Cut and pull the 9-5/8"casing to a depth of 2500' MD(where TOC is calculated in the 9-5/8"x i 13-3/8"annulus). • Run a whipstock and mill 12-1/4"window in the 13-3/8"casing at 2500' MD. 2.0 Plug& Abandonment Plan Summary The following procedure covers steps necessary to: I 1 • Kill well,Remove tree,N/U&test BOP. • Pull 3-1/2"kill string. �C • P&A wellbore with cement.�� • Set&test CIBP at 3,650'.(9-5/8" 53.5#N-80). li • Cut and pull 9-5/8"casing to 2500' MD. DV t' 3 7l L K b • Clean out run with 12-1/4"clean out assy. It • Run and set Whipstock, mill 12-1/4"window at 2500',FIT to 12 ppg. A separate drilling&completion procedure will be issued that details the drilling and completion of Anna ll 37A as follows: `e • Drill 12-1/4"hole. Run and cmt 9-5/8"production casing. �•1 • Drill 8-1/2"hole. Run and cmt 7"production liner. • Complete well. 114 lej- Aa Page 2 of 22 Revision 0 March,2013 Anna Platform #37 Slot Recovery Procedure Hilcorp Bum Company 3.0 Well Information Well Anna 37 Anna Leg&Slot designation Leg#2(East Corner),Slot#8 Current Completion Type: 3-1/2"kill string to 5,814' Field/Reservoir Name: Granite Point Field/Middle Tyonek C Oil Pool Well TD,MD/TVD: 11,741'MD/10,898'TVD PBTD 11,575'MD/10,737'TVD Maximum Anticipated Surface Pressure: 1718 psi Current Reservoir Pressure(estimated): 2792 psi Reservoir Temperature: C-1: 164 deg F C-8: 180 deg F 9-5/8"x 13-3/8"Annulus Pressure: 9-5/8"x 3-1/2"Annulus Pressure: 3-1/2"Tubing Pressure: Work String: 5.5"24.7#S-135 HT-55(Rental string from Weatherford) RKB—MSL: 121'AMSL RKB—THF: 43' Water Depth 71' P&A AFE No.: TBD P&A AFE Amount: TBD Drilling Contractor/Rig Name: Inlet Drilling Co/Rig 428 Page 3 of 22 Revision 0 March,2013 Anna Platform #37 Slot Recovery Procedure li rp emyC Company 4.0 BOP Test Summary The AOGCC has specified that Hilcorp operations follow a(1) week test frequency throughout the slot recovery phase. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. Test BOP equipment to 250/3000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test). Hole Section Equipment Test Pressure (psi) • 13-5/8" Shaffer 5M annular • 13-5/8" 5M Schaffer LXT Double gate Initial Test: o Top Cavity: 2-7/8" x 5-1/2" VBR 250/3000 o Btm Cavity: Blind Ram (Annular 2500 psi) Slot Recovery • Mud cross • 13-5/8" 5M Cameron U single gate Subsequent Tests: o 9-5/8" fixed casing ram 250/3000 • 3-1/16" 5M Choke Manifold (Annular 2500 psi) • Standpipe, floor valves, etc Required AOGCC Notifications: 24 hours notice prior to spud 24 hours notice prior to testing BOPs 24 hours notice prior to cement operations Page 4 of 22 Revision 0 March, 2013 Anna Platform #37 Slot Recovery Procedure Hilcorp Energy Company 5.0 Kill Well/N/D Tree 5.1 Prior to skidding rig onto leg#2, slot 8: 5.2 Check 3-1/2"x 9-5/8"annulus for pressure. Check 3-1/2"tubing for pressure. 5.3 Ensure necessary flange(s)installed on tubing head side outlet(9-5/8"x 3-1/2"annulus)to facilitate circulating hose installation. 5.4 R/U and pump down tubing,taking returns up 3-1/2"x 9-5/8"annulus. Circ as much as needed to establish clean fluid from 5814' to surface. • Keep up with volumes pumped vs volumes returned to establish loss rate and total losses. • If losses encountered, consider spotting a sized salt(or other LCM pill)outside the kill string. 5.5 Install a(2)way check valve in tubing hanger. Test above(2)way check to 3000 psi. 5.6 N/D production tree. • Check and clean lift threads on tubing hanger. 5.7 Skid rig over leg#2, slot 8. 6.0 BOP Installation & Test 6.1 N/U 13-5/8" 5M BOP assy configured as follows: o BOP configuration f/top down: Annular/Double Gate/Mud Cross/Single Gate • Double Ram: 2-7/8"x 5-1/2"VBR in top cavity, blind ram in bottom cavity. • Single Ram: 9-5/8"fixed casing ram. o N/U bell nipple. 6.2 Run BOP test assy,M/U to hanger lift threads &test BOPs to 25%30QQ psi for 5/5 min. a. Test annular on 3-1/2"test joint to 250/2500 psi for 5/5 min. b. Test VBR on 3-1/2"and 5-1/2"test joint. c. Test casing ram on 9-5/8"test joint. d. L/D test assy. e. Test blind rams against(2)way check. 6.3 Pull TWC. 6.4 Mix 400 bbl 9.5 ppg drilling fluid in preparation for casing cutting and pulling operations. Page 5 of 22 Revision 0 March,2013 • • • Anna Platform #97 Slot Recovery Procedure Hilcorp Energy Company 7.0 Pull 3-1/2" tubing and P&A wellbore. 7.1 R/U Weatherford casing crews for handling 3-1/2"tubing. • Ensure a XO to 3-1/2"IBT is on the rig floor and M/U to FOSV and ready to be stabbed. 7.2 M/U 3-1/2"tubing hanger landing joints&RIH. M/U to tubing hanger. 7.3 Pull tubing hanger. • Ensure there is no trapped pressure on the 9-5/8"x 3-1/2"tubing annulus. • Max overpull on the 3-1/2"9.2#IBT is 159,090 lbs. 7.4 POOH&L/D 3-1/2"9.2#IBT tubing. • Install thread protectors on both ends. 7.5 Send the hanger in to the"Squirrel Hut"for inspection&cleaning. 7.6 M/U 1500' 2-7/8"cmt stinger assy. 7.7 RIH and tag top of fill at 11,252' MD. 7.8 CBU and prep for cmt job. 7.9 Balance a 23 bbl, 15.4 ppg cmt plug from 11,252' to 10,240' MD. This will be 200' above the (1'` 5" liner top. ".' ' o 7.10 TOH to 9500' MD. Drop a DP wiper ball,circ B/U and rotate string to clear of cmt. 7.11 TOH to cmt stinger. M/U RTTS and hang off 1500' cmt stinger below mud line. Test above RTTS to 3000 psi/ 15 min. ot.0 7.12 N/D BOP. N/D tubing head. Tack weld 9-5/8" segments to 9-5/8"casing stub to ensure slips come out wi g when pulled. Don't weld segments to body—only weld segments to pipe. 7.13 N/U BOP, 13-5/8" 5M riser&3' 13-5/8"5M spool,test new breaks to 250/3000 psi for 5/5 min. Test against cup tester and VBR(or annular). 7.14 Pull RTTS,ensure to check for pressure build up below before unseating as pressure may have built up below the packer during cmt curing process. POOH and L/D RTTS. 7.15 Install a 9-5/8"53.5#casin scra er in the 5-1/2"workstring so that it will wipe down to+/- 4000' if the cmt p ug is tagged as planned at 10,240' MD. (this will wipe the casing in per paration for running the CIBP. 7.16 If TOC is not located by 10,600' (100' above top perf,top perf is at 10,716' MD),we will have to locate TOC and balance another cmt plug. Sa3� ncikr 3 80 7.17 Set down 5— 10k on cmt plug. Test casing to 500 psi/30 min. TOH and L/D cmt stinger. a••''� /4( Page 6 of 22 Revision 0 March, 2013Aat (5-"ii.dv 49'\"\\( ./114/YeAb'" D V • • • Anna Platform #.1,7 Slot Recovery Procedure Hilcorp �Je-C11'6 Energy Company 7.18 R/U e-line and set CIBP at 3,650' MD. Test CIBP to 500 psi/30 min. 8.0 Cut and Pull 9-5/8" casing. 8.1 Check pressure on 9-5/8"x 13-3/8" annulus. If pressure is not zero, notify drilling engineer or drilling manager. 8.2 M/U below casing cutting assy: BHA Connection Length OD 8-3/8"OD Non rotating stab 8-1/4"multi string cutter with 3.5"tungsten carbide knives 8-3/8"OD Non rotating stab Float Sub Magnet 5-1/2"DP • Ensure that the max opening of the multi-string cutter has been tested with a ring gauge in the shop. We do not want to cut the 13-3/8"casing. • Surface test the multi string cutter prior to running in the hole. Bring the flowrate up slowly and record the minimum flowrate to fully open the knives. • Once the test is completed, secure the knives in the retracted position prior to running in the hole to prevent inadvertent extension and possible damage to the knives. • RIH at a moderate speed. 8.3 TIH to position casing cutters at 2500' MD. Locate nearest coupling with cutters and ensure a cut is not made at a connection. ^- 8.4 Displace well to 9.5 ppg mud. • Note: this mud system will not be used to drill with. We will dump this system prior to drilling the 12-1/4"hole section. 8.5 Ensure to have magnets rigged up in ditch to catch metal debris. 8.6 Record P/U and S/O weights,establish free rotating torque at the recommended cutting rpm (80 rpm). 8.7 Slowly bring on pumps to 500 psi. The cut will be made when a pressure drop is seen. Page 7 of 22 Revision 0 March,2013 . • Anna Platform 417 Slot Recovery Procedure Hilcorp Ham Company • It is anticipated to take 15—30 minutes to perform the cut. If the casing is free and in tension,the stand pipe pressure loss will be sudden. If the casing is stuck or in compression,the pressure decrease will be more gradual. • Monitor the 9-5/8"x 13-3/8"annulus pressure while cutting the casing. An imbalance in MW may show up at the gauge. 8.8 Shut off mud pump. Monitor well on trip tank for 15 min. Ensure the annulus has no pressure. CBU to see if any gas has migrated into the wellbore. 8.9 Close pipe ram and attempt to circulate down the 9-5/8"casing,taking returns at the casing head side outlet(9-5/8"x 13-3/8"annulus). • If communication is observed, circ a few B/U depending on flow rates that can be achieved. • If communication is not observed,pull up to—2400' and cut casing again. • Attempt to circulate again down 9-5/8"and up 9-5/8"x 13-3/8"annulus. • If circulation is still not possible, consult with Anchorage drill team for plan forward. 8.10 POOH w/casing cutter assembly. Rack back knife assy in derrick if possible. 8.11 M/U flush tool and flush out debris from behind the 9-5/8"casing stub in the wellhead. POH w/flush tool. 8.12 RIH w/9-5/8"casing spear and engage 9-5/8"casing. BHA Connection Length OD Spear Pack-off Itco Spear 9-5/8" 53.5# spear grapple Spear extention Spear stop sub 8.13 Slowly P/U on the casing hanger. • Determine weak point in string. 9-5/8" 53.5#L-80 BTC casing yield strength is 1244k. • If unable to pull hanger,discuss forward plan with Anchorage Drill Team. 8.14 L/D Spear assy. POOH and L/D 9-5/8"casing. Page 8 of 22 Revision 0 March,2013 • Anna Platform #37 Slot Recovery Procedure mC Emmy Company 9.0 Mill 12-1/4" Window 9.1 M/U below clean out assy and TIH to top of 9-5/8"casing stub at 2500' MD. • Ensure BHA components have been inspected previously. • Caliper and drift all BHA components before running them in the hole. • Drift DP prior to RIH • Lightly wash and ream any tight spots as noted. • Orient UBHO to starter mill-and check to ensure gyro fits in profile. BHA Connection Length OD 12-1/4"taper mill 12-1/4" Watermelon Mill 12-1/4" Flex Joint 8" Upper Watermelon 12-1/4" Mill 1 jt 5-1/2"HWDP Float Sub UBHO Jar Remaining HWDP 9.2 Tag the top of the 9-5/8" stub lightly. Do not set down more than 5k or rotate the string with weight down on the stub. • Pump viscous sweeps as necessary to carry debris/scale out of the wellbore. • Rotate and reciprocate string while circulating as necessary to clean up hole. The objective is to clean out well in preparation for running Whipstock. 9.3 TOH and rack back clean out assy. 9.4 Run CCL to determine 13-3/8"coupling locations. 9.5 Run and set CIBP-5' t ex osed 13-3/8"coupling(so we do not mill window across a coup mg). et, ZSp J y4.� -� �- b v'p 9.6 Bring Whipstock to rig floor on the pipe skate. Do not slam into bottom of Whipstock with pipe skate. 9.7 Pick up Whipstock per Baker rep using the Baker Whipstock handling system using air hoist. Allow assy to hang while Baker Rep inspects and removes shear screws as needed and any safety screws. Note: Anchor should be pinned with 6 shear screws initially. Shear screws are rated for 6,630 lbs each. REMOVE 3 screws for a set down shear of 6,630 x 3=19,890 lbs. Page 9 of 22 Revision 0 March,2013 Anna Platform 7 Slot Recovery Procedure Hilcorp En«gyComPanY Note: Attach mills to Whipstock with (I) 45k mill shear bolt. 9.6 If needed, open BOP Blinds. 9.7 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 9.8 Release pick up system at this point, Make up mills. 9.9 With the top drive, pick the assembly and position the starting mill to align with the hole in the slide. The Baker Rep will instruct the driller when the slot is lined up,the shear bolt then can be made up by the Baker Rep. 9.10 The assembly can now be picked up to ensure that the shear bolt is tight. 9.11 Remove the handling system. 9.12 Slowly run in the hole as per Baker Rep. run extremely slow through the BOP &wear bushing. 9.13 Run in hole at 1 1/2 to 2 minutes per stand. 9.14 Fill every 15 stands or as needed, do not rotate or work the string unnecessarily. 9.15 Orient at least 30' —45' above the 9-5/8" stub. Ensure to have gyro personnel and equipment as well as a wireline unit R/U and ready. WindowMaster G2 System on TorqueMaster BTA BHA#1 Connection Length O.D. BOTTOM TRIP ANCHOR WINDOWMASTER G2 WHIPSTOCK WINDOW MILL NEW LOWER WATERMELON MILL _ FLEX JOINT UPPER WATERMELON MILL ljt - HWDP FLOAT SUB UBHO X-O sub + 30 jts-HWDP CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY Page 10 of 22 Revision 0 March, 2013 . • . . in Anna Platform #37 Slot Recovery Procedure Hilcorp Energy Company 10.0 Whipstock Setting Procedure: 10.1 With the bottom of the Whipstock 30—45' above the CIBP, measure and record P/U and S/O weights. Run gyro survey to orient Whipstock face. Ensure to make multiple checks of the Whipstock orientation to ensure the gyro is seating in the UBHO correctly. 10.2 Orient Whipstock to desired direction by turning DP in `/a round increments. P/U and S/O on DP to work all torque out(Being careful not to set BTA). Whipstock Orientation Diagram: 30 L 70L 211111 6it,vd,rft- '1111/' i ilge\40 5 Desired orientation of the Whipstock face is 30L to 70L. Hole Angle at window interval (2,000' MD) is 20.8 deg. Planned wellbore azimuth after kicking off is 65 deg 10.3 Once Whipstock is in desired orientation, slack off and tag 9-5/8" stub to set Bottom Trip Anchor. (J 10.4 Set down 18-25K on anchor to trip, P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (45k shear value). 10.5 P/U 5-10' above top of Whipstock. 10.6 Displace to 9.2—9.6 ppg 2% KC1/Clayseal/GEM drilling fluid (if not done previously). 10.7 Record P/U, S/O weights, and free rotation. Slack off to top of Whipstock and V with light weight and low torque. Mill window. Utilize 4 ditch magnets on the 1 surface to catch metal cuttings. 4'M' age 11 of 22 Revision 0 March, 2013 1 • Anna Platform #37 Slot Recovery Procedure Hilcorp Enagy ComMo7 10.8 Install catch trays in shaker underflow chute to help catch iron. 10.9 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. 10.10 Estimated metal cuttings volume from cutting window: 13-3/8" 68#N-80 Cuttings Weight Window Length Casing Weight Min(Ibs) Avg(Ibs) Max(Ibs) 20 68# 10.11 Drill approx. 20' rat hole to accommodate the drilling assembly. Ream window as needed to assure there is little or no drag. After reaming, shut off pumps and rotary(if hole conditions allow) and pass through window checking for drag. 10.12 Circulate Bottoms Up until MW in=MW out. 10.13 Conduct FIT to 10 12ppg EMW. • (12—9.2) * 0.052 * 1973' tvd=288 psi Note: Offset field test data predicts frac gradients at the window to be bwtn 14.4 ppg and 15.4 ppg. A 12 ppg FIT results in a 2.8 ppg kick margin while drilling the interval with a 9.2 ppg fluid density. 10.14 Slug pipe and POOH. Gauge Mills for wear. 10.15 Should a second run be required pick up the following BHA. Back Up Mills Connection Length O.D. WINDOW MILL NEW LOWER WATERMELON MILL FLEX JOINT UPPER WATERMELON MILL FLOAT SUB X-O sub 30 jts-HWDP 4" HT-38 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY! Page 12 of 22 Revision 0 March,2013 • Anna Platform #37 Slot Recovery Procedure Hilcorp 11.0 Drilling 12-1/4" Hole Section 11.1 M/U 12-1/4" directional BHA. A separate procedure will be issued for the drilling and completion of Anna 37A which includes: • Drill 12-1/4"hole, run 9-5/8"casing • Drill 8-1/2"hole, run 7"production liner • Complete well with dual string Page 13 of 22 Revision 0 March, 2013 Anna Platform #/7 Slot Recovery Procedure Hilcorp Energy Company 12.0 BOP Schematic (Stack up on left will be used while pulling 3-1/2"prod tubing, Stack up on right will be used after removing tubing head). A•/W hard pucks' Ad95aua,a+•R dal nary role.etese, Ite Fl. 9111111111111 et f et ,I ISI , �a� z • 1 � � �. < a 2*,;S Voll 2:.....;...:.>. , EM "�""" weI,,.x,1■ •I , oI ! L . ;Nos ,.,.. I!iJ1il ' 2F. t1 )'' swassiesto licier leer llbn!Y1,1,11yAR \3SEX4i ShnM!! •9xvnrt i eu „Nu` ,.- 13!,34 IL•71T1,WI,t 1 ri ‘ 1 ali rf ' I ..!Millie 1 .._—_.. . . . ., 1;1 1 `al f.113,„,„Ax ® ' . 133tlf4 A l1-4.0..0,..In! .7 [ �� 111 7� [ i�fti II'''. � 'Mir* rl ir mom 00 Page 14 of 22 Revision 0 March, 2013 1 Anna Platform #3 7 Slot Recovery Procedure Hilcorp Energy Company 13.0 Wellhead Schematic An-37RD Tub: ,.,hanger,CIW-DCB- 20X13318X9518X FBB, 1X3'VEUElift X3'Y 3'4 l3TC susp,w.+3"type H BPV profile, 118"non-continuous control line pod BHTA,Bowen, 3 118 10M FE X 3' Bowen quick union II 111 l., -alio Valve,lower master. CIW-FC, ilifillwrip; 3 118 10M FE. HWO, o f j � ,P FF trim ; � (� Adapter,CIW, 11 5M FE X 3 1116 10M Stdd,6V,slick :rod test good 25015000 I I 1, int neck pocket,7/2"control 6110±2010 ----._,. ._... r • .. outlet .�� t>att>. Tubing head,CIW-DCB, I t t , ,i,_ 135185MX115M,w.'2• 2 1/16 5M SSO,X-bottom ItI Itl Valve,CIW-F,2 1116 5M prep f FE, HWO :I , [trA,1 7 mitt Alia -. ! w. in -:= —Vain test good 2501251X` Casing spool,OCT-22. 1 • • 9 21 %2MX135185M / INK IN 6,10/2010 v;?2 2 1116 5F.!E FO, iNg lit li u l Valve,OCT-20,2 1116 3M 00 bottom prep • • ;/� ♦ FE, HWO k iiiZ"` III lit Casing head,OCT-22, Void lest good 21Y.2MXSOW.vr,' r—• 0� 10 2-211162MEFO 111 id III — _ no -r'' . 1i Iti ,f Iiflj'tikitel ,OCT-20,21116 2M a FE, HWO ElmP Page 15 of 22 Revision 0 March, 2013 . . H Anna Platform # 7 Slot Recovery Procedure Hilcorp Energy Company 14.0 Anna Slot Diagram ANNA PLATFORM WELLSLOT DIAGRAM SHALE 01 /01 /12 SHALE WATER SHAKER SHAKER FLOOnD 0 ❑ 51 7RD2 WATER 39 4RD FLOOD 7ic Q sit 11RD - •\28RD2 32RD 36 ,// FERE PUMP A A )I. 5O27RD .ti, ,,,:t:',' t ' f 17 4A . /1., 7;1," ' Wr 52 3RD 4 1 r 8 Leg #1 1, Leg #2 . North Corner East Corner / Ad / to A INTAKE ' / 0 it ❑DISCHARGE Producer Dual Gas Well Injector Completion SHALE er 25 23RD SHAKER 46 MUC! 3 V ,e V," ///d' D ,,,,/ ( 0,i-f. i iiiSEWAGE fro 5 19 /�'' �` WATERA r 29 e P SHALE 0 PRODUCED ;f ,'f „,e, FLOOD } ' it SHAKER WATER WATER WATER ❑ ,� 0 FLOOD FLOOD A A 26 /$ 1: 13RD .% 9 iil 4 5 33 �� e 21 WATERROOD i Leg #4 Leg #3 West Corner South Corner b Page 16 of 22 Revision 0 March,2013 • Anna Platform #37 Slot Recovery Procedure Hilcorp Energy Company 15.0 Existing Wellbore Diagram euro Operational Shutdown Well Schematic June 27,2008 ANNA Platform An-37 tom,.,,.4111111 API 50-733-20394 PTO. 187-109 41431414r tori(WM..ter - �_...._. -.._.. .,,...�,...,,.... .,...,�,,.. 143 11.4 Hc_.. gement CMI Size Typo WT Grade CONN ID torp 61M Size Se4 las To 30' Sfructurar 320 STR Weld Surf 266 Drtuen 20" Conductor_ 133 X56 19' 44' , 615 26" 1308 sx Surf 13.318 Sur Pipe_! 68 N80 Buttress 12.415 Sief 3522' T745',, 25,13sx Surf srA9u 9.518 Sur C$fi 83`5 1480 Butless 8.535 Surf 10,150- 12-25" 1250 sx 7.5'8 CSG 39 C.95 FL4S 8.028 9057' 10,60T 8.5' 300 sx 13307 Y'r • ,,+,,ows� liner 18 180 BWtrtsss 4.276 10,440 11644 7' 768 sx 7 1!(NT BMT Plastic Coated Tubing 3 5` Tubing 9.2 LOU Button's 2.942 Surf 5814' rm- Depth ID Jewelry DescriptionDescriptio ►err.13,1 in Apgroxirnare Notes 33.40` Hanger 2 34.4' 2 942 , 5914' 3-112'N80 9.24 Buttress K41511419' 1;331 733 1C 94' DATE INTERVAL DESCRIPTION ZONE 03,14,M6 it 22$--11297' 3 375'4 SPF 4 00D.4* C-7 ©CTG Rotating Hours c•6 20' 61 5 Rotating H0ltr9 11,307-11346 3.375'4 SPF Y SOD 166 C-7 13.316' 373 Rotatua9 Hauls 11.360'-11;446' 3 375'4SPF 00D 164 C-7 9-5.78' 574 Rafating f tpurs 7-518' , 188 Ratarxlg Haws 050316 10.716'-10.704' 3 375'4-507 SPF 000 272 C'S 1•s, ' 5'Liner 59 ROISOn9 Hours 13.736'-70.087' 3 375'4.S00 SPF x,19013 336 C-S `41 uao31,116 13.714-10.704' 2-16'Er*-t a 6 SPI ono C-S Ito 10,796-10,062 2.166'Enerlet a 6 SPF Q,@ 90D GS reser 11.076'-11.091' 2-V6'Eee e(f56SPFe90D C-8 P97D-11,576' 7D-11,741' 11,164'-11.176' 2.116'Enenet a 6PF S .000 C-7 VAX► pORME-me o. 11.325'-11,238' 2-116'Fner:41aeSPF 900 C-7 Fish to Hole A 11.282 APRS JeI Cutler Sarrng Ireete 2.78'8'Tubing!Fish Length tt 199.461 u DOGLEGS-4 1 fg 1400' GHOST.10.787' BHA Assembly 192'Fish,off of Nee trace tore l!`-SCLAu-3._4..27_2006 1'.tLStriti&di _....---_ I've I o1`1 1R 4 77_71X18 Page 17 of 22 Revision 0 March, 2013 rAnna Platform #57 Slot Recovery Procedure Hilcorp Energy Company 16.0 Planned Wellbore Diagram II Steelhead Platform SCHEMATIC wEIL#:Anna 37A 11/15/2013 11,1,orp 13.41.3.1.1.1. r. Casing Detail L�,. SIZE V,? CF�CrS 'tit4N ID TO; 6TN1. 20 :: `;y� 3C 32C° STR - • Surf 263 s*;.i •r 2G 133r K-56 - 19 Surf 615' l51 • y 13-3/8 68 t:-8C E 12.415 surf 3522 n fi'z 1 p Ct/3 1 y �Z roe 9-5/8' 533 %..8Z E': 3335 25CC' le 15C' *4 'C't°ly ▪''' 7-5/8' 35 _ -5 F,..45 6.625 ?,897' ic,68' r -...Cj” '^. . 5' is ....s7 E:':-e:: 4.276 1:44e 11,644 FLLr Pv 3 37/A I*. ��r Item item — lNO Depth itetem 1 2,480 Planned Tap of window 2 2.500' CIBP/9-5f8"cas ina stub 3 3,850' CIBP b v le._,..,k-S ll t. TQC L� 10,240' rs,ra,. s" e TD:11,741'MD/9,972'TVD Page 18 of 22 Revision 0 March, 2013 Anna Platform II497 Slot Recovery Procedure Hilcorp Energy Company _17.0 Anna 17 Directional Survey AN-37 API 50-733-20394-00 PTD: "187-109" TABLE OF SURVEY STATIONS STA MD INCL AZIPI TVDSS N-1-;S- E+1,A1- DLS # ft deg deg ft ft ft deglOOFT 77 c==TIE POINT ==> -106.00 0 00 0.00 - 1 0 0 0 -106.00 0.00 0.00 - 2 100 0.17 262.63 -6.00 -0.02 -0.15 .17 deg!C ft 3 200 0.23 240.7 94.00 -0.14 -0.47 _1 deg/C ft 4 300 0.85 24.12 194.00 0.44 -0.34 1.04 deg/C ft 5 400 3 25.77 293.93 3.48 1.10 2.15 de./C ft 6 500 3.43 24.12 393.78 8.56 3.46 .44 deg/C ft 7 600 3.62 25.65 493.59 14.14 6.05 .21 de•/C ft 8 700 4.68 43.9 593.33 19.93 10.24 1.68 deg!C ft 9 800 5.13 65.13 692.97 24.75 17.13 1.86 deg!C ft 10 900 5.95 71.38 792.50 28.28 26.10 1.02 deq/C ft 11 1000 6.12 85.42 891.95 30.36 36.32 1.48 deg/C ft 12 1100 7.32 82.9 991.27 31.57 47.96 1.24 deg/C ft 13 1200 8.82 77.35 1090.27 34 04 61.76 1.69 deg!C ft 14 1300 12.15 76.53 1188.59 38.17 79.48 3.33 deg/C ft 15 1400 16.28 76.17 1285.51 43.50 103 45 4.15 deg/C ft 16 1500 18.93 78,97 1380.82 49.48 133.09 2.66 deglC ft 17 1600 20.62 79.67 1474.92 55.74 166.34 1.71 deg/C ft 18 1700 20.88 79.72 1568.43 62.08 201.20 .26 de.IC ft 19 1800 20.83 79 1661.88 68.65 236.18 .26 deg/C ft 20 1900 20.96 79.1 1755.29 75.43 271.22 .15 deg/C ft 21 2000 20.85 78 63 1848.71 82 32 306.24 .21 deglC ft 22 2100 21.13 78.72 1942.07 89.35 341.36 .28 deg/C ft 23 2200 21.07 78.17 2035.37 96.57 376.63 .21 deg/C ft 24 2300 20.37 78.07 2128.90 103.85 411.26 .7 deg/C ft 25 2400 20.32 78 2222.66 111.06 445.27 .06 deg/C ft 26 2500 20.08 78.23 2316.51 118.17 479.06 .25 deg/C ft 27 2600 19.83 77.87 2410.50 125.23 512.45 .28 deg/C ft 28 2700 19.37 78.3 2504.71 132.16 545.27 .48 deg/C ft 29 2800 19.18 78.02 2599.10 138.93 577.58 .21 deg/C ft 30 2900 18.95 77.8 2693.62 145.77 609.52 .24 deq/C ft 31 3000 18.93 77.97 2788.20 152.59 641.25 .06 deg/C ft 32 3100 18.48 78.6 2882.92 159.10 672.65 _49 deg/C ft 33 3200 18.22 78.87 2977.84 165.25 703.53 .27 deg/C ft 34 3300 17.65 79.7 3072.98 170.98 733.78 .62 deg/C ft 35 3400 17.55 79.58 3168.30 176.42 763.53 .11 deg'C ft 36 3500 17.23 80.05 3263.73 181.70 792.94 .35 deg/C ft 37 3600 17.2 80 1 3359.25 186.80 822.09 .03 deg.lC ft 38 3700 17.88 79.77 3454.60 192.07 851.77 .69 deg./C ft 39 3800 18.77 79.77 3549.52 197.66 882.71 .89 de.IC ft 40 3900 19.45 81.05 3644.01 203.10 914.99 .8 deg/C ft Page 19 of 22 Revision 0 March, 2013 . in + Anna Platform #A7 Slot Recovery Procedure Hilcorp Energy Company AN-37 API 50-733-20394-00 PTD: "187-109" TABLE OF SURVEY STATIONS STA MD INCL AZIM TVDSS N+ S- E+,W- DLS # ft deg deg ft ft ft degf100FT 41 4000 20.37 81.12 3738.04 208.38 948.63 .92 deg'`C ft 42 4100 20,63 81.35 3831.64 213.74 983.40 .47 deg!C ft 43 4200 21.67 81.73 3924.84 219.07 1019.25 .85 deg'C ft 44 4300 22.15 81.62 4017.62 224 47 1056.17 .48 deg'C ft 45 4400 23 881.6 4109.95 230.08 1094.15 .85 deg/C ft 46 4500 23.95 81.85 4201.68 235.81 1133.57 .96 deg!C ft 47 4600 24.83 82.72 4292.75 241.34 1174.49 _95 deg'C ft 48 4700 25.72 63.03 4383.18 246.64 1216.86 _9 deg!C ft 49 4800 26.13 83.48 4473.11 251.77 1260.26 .45 de./C ft 50 4900 26.85 83.08 4562.62 256.99 1304.57 .74 deg`C ft 51 5000 27.17 83.15 4651.71 262.44 1349.66 .32 deg'C ft 52 5100 27.47 82.85 4740.55 268.03 1395.21 .33 deg/C ft 53 5200 26.3 82.92 4829.74 273.63 1440.08 1.17 de.!C ft 54 5300 26.52 82.27 4919.31 279.37 1484.19 .36 deg!C ft 55 5400 26.23 82.22 5008.90 285.36 1528.21 .29 deg/C ft 56 5500 26.22 81.82 5098.60 291.50 1571.97 .18 deg!C ft 57 5600 26.23 81.8 5188.31 297.79 1615.71 .01 deg!C ft 58 5700 25.57 81.2 5278.27 304.24 1658.91 .71 deq/C ft 59 5800 24.73 81.08 5368.79 310.79 1700.90 .84 deg.!C ft 60 5900 24.45 81.2 5459.72 317.20 1742.02 .28 deg'C ft 61 6000 24.62 81.88 5550.69 323.31 1783.09 .33 deg!C ft 62 6100 24.42 81.88 5641.67 329.17 1824.17 .2 deg!C ft 63 6200 24.07 81.68 5732.85 335.04 1864.82 .36 deg!C ft 64 6300 23.95 8235 5824.20 340.69 1905.11 .3 deg!C ft 65 6400 23.92 82.95 5915.60 345.88 1945.35 ,25 deg/C ft 66 6500 23.25 83.62 6007.24 350.56 1985.08 .72 deg!C ft 67 6600 23.13 83.35 6099.16 355.03 2024.21 .16 deg!C ft 68 6700 23.37 81.65 6191.04 360.19 2063.34 .71 deg'C ft 69 6800 23.37 81.42 6282.84 366.03 2102.57 .09 deg.!C ft 70 6900 23.15 81.85 6374.71 371.77 2141.64 .28 deg!C ft 71 7000 22.58 82.05 6466.85 377.21 2180.12 .58 deg'C ft 72 7100 22.43 82.48 6559.24 382.37 2218.04 .22 deg!C ft 73 7200 22.15 82.53 6651.77 387.31 2255.65 .28 deg!C ft 74 7300 22.3 82.07 6744.34 392.38 2293.13 23 deg!C ft 75 7400 22.03 82.75 6836.95 397.37 2330.53 .37 deg!C ft 76 7500 22.93 82.37 6929.35 402.32 2368.44 .91 deg'C ft 77 7600 24.28 82.33 7020.98 407.65 2408.13 1.35 deg!C ft 78 7700 25.15 83.12 7111.82 412.94 2449.60 .93 de./C ft 79 7800 26.08 83 7201.99 418.16 2492.52 _93 deg'C ft 80 7900 26.78 83.23 7291.54 423.50 2536.70 .71 deg!C ft Page 20 of 22 Revision 0 March, 2013 r Anna Platform #37 Slot Recovery Procedure Hilcorp Energy Company AN-37 API 50-733-20394-00 PTD: "187-109" TABLE OF SURVEY STATIONS STA MD INCL AZIM TVDSS tJ+;S- E4-W- DLS # ft deg deg ft ft ft deg:1OOFT 81 8000 28.35 84.6 7380.18 428.39 2582,72 1.69 deg/C ft 82 8100 30.32 86.2 7467.36 432.30 2631.55 2.12 deg/C ft 83 8200 31.02 86.77 7553.37 435 42 2682_46 .76 deg/C ft 84 8300 30.72 86.42 7639.20 438.47 2733.68 .35 deg/C ft 85 8400 29.82 86.72 7725,57 441.49 2783.99 .91 deg/C ft 86 8500 29.05 86.98 7812.66 444.19 2833.06 .78 deg'C ft 87 8600 27.97 86.97 7900.53 446.71 2880.73 1.08 deg/C ft 88 8700 25.8 87.83 7989.72 448_77 2925.89 2.2 deg/C ft 89 8800 25.07 88.68 8080.02 450.08 2968.82 .82 deg.'C ft 90 8900 25,85 88.97 8170.31 450.96 3011.80 .79 deg'C ft 91 9000 26.58 89.43 8260.02 451.58 3055.97 .76 deg.'C ft 92 9100 27.48 89.85 8349.10 451.86 3101.41 .92 deg/C ft 93 9200 27.48 90.38 8437.82 451.77 3147.56 .24 deg!C ft 94 9300 27.83 90.33 8526.39 451.48 3193.97 .35 deg/C ft 95 9400 27.62 90.72, 8614.91 451.05 3240.49 .28 deg/C ft 96 9500 27.2 91.22 8703.69 450.28 3286_52 _48 deg/C ft 97 9600 27.18 91.37 8792.64 449.24 3332.20 07 deg.'C ft 98 9700 27.1 91.67 8881.63 448.03 3377.80 .16 deg/C ft 99 9800 26.95 91.97 8970.71 446.59 3423.22 .2 deq!C ft 100 9900 27.03 92.37 9059.81 444.87 3468.57 .2 deg/C ft 101 10000 27 93.28 9148.90 442.63 3513.93 .41 deg!C ft 102 10100 26.72 94.3 9238.12 439.65 3559.02 .54 deg/C ft 103 10200 25.02 96.83 9328.09 435.45 3602_44 2.03 deg/C ft 104 10300 22.87 102.13 9419,49 428.85 3642.44 3.04 deg/C ft 105 10400 21.77 102.72 9512.00 420.68 3679_53 1.12 deg.!C ft 106 10500 21.3 102.65 9605.02 412.62 3715.34 .47 deg/C ft 107 10600 20.65 103.1 9698.39 404.65 3750.23 .67 deg/C ft 108 10700 19.5 105.08 9792.32 396.31 3783.53 1.34 deg.'C ft 109 10800 19.65 105.43 9886.54 387.49 3815.85 .19 deg/C ft 110 10900 19.9 108.02 9980.64 377.75 3848.24 .91 deg'C ft 111 11000 17.02 107.33 10075.48 368.13 3878.40 2.89 deg!C ft 112 11100 16 109.72 10171.36 359.12 3905.35 1.23 deg/C ft 113 11200 14.88 113.08 10267.75 349.43 3930_14 1.43 deg/C ft 114 11300 13.88 119.02 10364.62 338.58 3952.44 1.78 deg/C ft 115 11400 14.23 123.1 10461.63 326.05 3973.22 1.05 deg.'C ft 116 11500 14.48 127.57 10558.51 311.71 3993.43 1.14 deg/C ft 117 11575 13.73 130.67 10631.25 300.20 4007.61 1.42 deg9C ft 118 11741 12.5 133 10792.92 275.10 4035.69 .81 deg/C ft Page 21 of 22 Revision 0 March, 2013 Anna Platform #37 Slot Recovery Procedure Hilcorp Energy Company 18.0 MASP Calculations Maximum Anticipated Surface Pressure Calculation Plug and Abandonment Hilcor Anna 37 Cook Inlet,Alaska MD ND Top 2,500 2,422 Bottom 11,252 10,418 Anticipated Formations and Pressures(based off fluid level shot In June 2012 assuming.433 gradient in weilborej: Formation TVD Est Pressure Dil/Gas/Wet PPG Grad Temp Cl 9,308 2172 4.5 0.233 164 C3 9,653 2321 4.6 0.240 168 C4 9,818 2393 4,7 0.244 169 C5A 9,913 2434 4.7 0.246 170 C58 9,991 2468 4.8 0.247 171 C6 10,092 2511 4.8 0.249 172 C7A 10,337 2617 4.9 0.253 175 C78 10,371 2632 4,9 0.254 176 C7C 10,479 2679 4.9 0.256 177 C7D 10,548 2709 4.9 0.257 177 C8A 10,697 2773 5.0 0.259 179 C88 10,738 2791 5.0 0.260 180 Offset Well Mud Densities Well Max MW Top(TVD) lottom(TVD Date Anna 17 9 ppg 3,500 10,020 1977 GP 13-11 RD 9.8 ppg 3,975 10,100 1992 GP#t 50 9.4 ppg 3,880 9,851 1992 Anna 03 RD 10.5 ppg 7,755 10,219 1994 Assumptions: 1. Hydrostatic gradient of 0.433 used for fluid in wellbore when fluid level shot. MASP from pore pressure(wellbore evacuated to gas from C8) 10,738(ft)x 0.260(psi/ft)= 2792 psi 2792(psi)-(0.1(psi/ft)*10738(ft))= 1718.2 psi I Summary: 1. MASP during workover is governed by pore pressure and wellbore evacuated to gas from the C8 sand (1718 psi). Page 22 of 22 Revision 0 March, 2013 Page 1of1 Subject: FW: INTENT PLUG for RE-DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE-DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE-DRILL WELLS (IPBRD)Type Work Code in RBDMS / 1. When a Form 10-403 is submitted requesting approval to plug a well for redrill,the initial reviewer(Art J or Steve D.)will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). / 2. On the Form 10-403 if"Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve J D. will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10-403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10-407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re-drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10-407. Steve will also change the status on the 10-407 form to SUSPENDED, and will date and initial his change. If Steve does not see the"Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10-407 into RBDMS. 5. When the Form 10-407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D.will also review the list of suspended wells for accuracy. Thanks, Steve D. STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Stimulate Other Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver ^ Time Extension^ / Change Approved Program ^ ..Dperat. Shutdown ,/ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Develo ment p ^ Exploratory^\ • 187-109 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service0 • 6. API Number: ~`~ 50-733-20394-00 ' 7. KB Elevation (ft): ~ I 9. Well Name and Number: ~~ Granite PT ST 18742 37 (AN-37) 8. Property Designation: '° 10. Field/Pool(s): ADL0018742 [Anna Platform] Granite Point Unit /Middle Kenai Oil ` 11. Present Well Condition Summary; Total Depth measured 11,741 feet Plugs (measured) N/A true vertical 10,898 • feet Junk (measured) 11,252 (fill) Effective Depth measured 11,252 feet true vertical 10,423 feet Casing Length Size MD TVD Burst Collapse Structural 268' 30" 268' 267' Conductor 571' 20" 615' 614' 2125 psi 1500 psi Surface 3,522' 13-3/8" 3,522' 3,390' 5020 psi 2260 psi Intermediate 10,150' 9-5/8" 10,150' 9,389' 7930 psi 6620 psi Production 790' 7-5/8" 10,687' 9,886' 10900 psi 10000 psi Liner 1,989' 5" 11,644' 10,804' 9910 psi 10490 psi ~,9 ~~l~»~~~~ ~~[ ~n ~~~ ~' c Perforation depth: Measured depth: See Attached Schematic t True Vertical depth: See Attached Schematic Tubing: (size, grade, and measured depth) 3-1/2" L-80 9.2# 5,814' Packers and SSSV (type and measured depth) NiA N/A P , 12. Stimulation or cement squeeze summary: N/A ~ `; Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 370 0 Subsequent to operation: 0 0 0 380 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^ Service ^~ , Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ Q ~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-113 Contact Jack Newell 263-7832 Printed Name Timothy C. Brandenburg Title Drilling Manager .~~~ Phone 276-7600 Date 8/6/2008 ~~3 Signature `"°"' - ~ '` .~.,........ .... ...~ ~,' J..r Q~ ~ y ~ ~Q 9.3.QB Form 10-404 Revised 04/2006 °~m~ e;z0',j~'~' V ~ ~ ~ Submit Ori ' al O~nl °l '/~ "~""" Operational Shutdown Well Schematic ~~ June 27, 2008 ANNA Platform An-37 API 50-733-20394 PTD: 187-109 ~ to Sea Lrael (MLN) = 727 Fa3 33.4 L sy6"- to,t sv 7dI6'-10,66!' Tap ar ai 77,252 wTa~i aKr estR 8'-11,694" A"~ f''7}# P87D=11,575' 7D=11,741' MAXHCIE PNGLE =3108200' Size Type WT Grade CONN ID Top BTM Hole Size Cement Sacks CMT Top 30" Structural 320 STR Weld Surf 268' Driven 20" Conductor 133 X56 19" 44' 615 26" 1308 sx Surf 13-3/8 Sur Pipe 68 N80 Buttress 12.415 Surf 3522' 17.5" 2543 sx Surf 9-5/8 Sur CSG 53.5 N80 Buttress 8.535 Surf 10,150' 12.25" 1250 sx 7-5/8 CSG 39 C-95 FL4S 6.625 9897' 10,687' 8.5" 300 sx 5 Liner 18 L80 Buttress 4.276 10,440 11,644' 7" 768 sx 3.5" Plastic Coated Tubing Tubing 9.2 L80 Buttress 2.942 Surf 5814' # Depth ID Approximate Depths 1 33.40' 2 34.4' 2.942 3 5814' OCTG Rotating Hours 20" 61.5 Rotating Hours 13-3/8" 313 Rotating Hours 9-5/8" 574 Rotating Hours 7-518" 188 Rotating Hours 5" Liner 59 Rotating Hours Jewelry Description Hanger 3-1/2" N80 9.2# Buttress Kill String" 03/14/88 11225' - 11237' 3.375" 4 SPF @ 90D, 48 C-7 11,307 - 11346 3.375" 4 SPF ~ 90D 156 C-7 11,380' - 11,446' 3.375" 4SPF @ 90D 164 C-7 05/04/88 10,716' - 10,784' 3.375" 4 -.500 SPF ~ 90D 272 C-5 10,798' - 10,882" 3.375" 4 -.500 SPF ~ 90D 336 C-5 08/31/96 10,714' - 10,784' 2-1 /8" Enerjet ~ 6 SPF @ 90D C-5 10,798 - 10,882' 2-1 /8" Enerjet ~ 6 SPF @ 90D C-5 11,076' - 11,091' 2-1 /8" Enerjet @ 6 SPF ~ 90D C-6 11,154' - 11,176' 2-1 /8" Enerjet ~ 6 SPF ~ 90D C-7 11,225' - 11,236' 2-1 /8" Enerjet ~ 6 SPF ~ 90D C-7 Fish In Hole A. 11,282' APRS Jet Cutter String Inside 2-7/8" Tubing (Fish Length = 199.48') ~ DOGLEGS: 4.1 @ 1400' GHOST: 10,787': BHA Assembly: 192' Fish, off of side track bore WBD An-37 6 27 2008 Kill String.doc Paee l of 1 JRN 6 27 2008 • • Chevron Chevron -Alaska Daily Operations Summary Well Name Field Name API/UVN Lease/Serial CHEYNO License No./Props... Orig KB FJev (ftKB) Water Depth (R) AN-37 GRANITE PT, MIDDLE 507332039400 ADL0018742 IP3096 1871090 52.1 - -_-_ . Jobs - ~ -~_ --~-~ ~ - .. Job Cat Type - - AFE No. QC Eng Workover Workover UWDAK-R8030 --- wily OperaUQttt3 6/5/2008 00:00 - 6/6/2008 00:00 Operations Summary PJSM - MIRU Rig 428 -Prepare to workover well -Simops planning with platform production personnel. 6/6/2008 00:00 - 6/7/2008 00:00 Operations Summary PJSM -Circulate well down long and short strings -Set BPV's, ND Tree. Contacted AOGCC Jim Regg whom waived witness to BOP test. sn/2oos oo:oo - s/s/2oo8 00:00 Operations Summary PJSM - NU BOP, Test surface lines and body's -prepare for dual tubing string decompletion. 6/8/2008 00:00 - 6/9/2008 00:00 Operations Summary PJSM - test witness waived 250 si low / 3000 si hi h conducted, assed, RU dual string equipment -Circulate well - POH hanger -POOH ~~ dual tubing string, long string has scale BU (built up) on outside. 6/9/2008 00:00 - 6/10/2008 00:00 Operations Summary PJSM/ Simops - Continue to POOH 3-1/2"dual completion string -Static fluid loss rate 1 BPH -Safety intervention performed by Equilibria 6/10/2008 00:00 - 6/11/2008 00:00 Operations Summary PJSM/Simops -Review plan forward - Contine to POOH 3-112" Dual Completion. Contacted AOGCC Jim Regg who waived witness to upcoming BOP test. 6/11/2008 00:00 - 6/12/2008 00:00 Operations Summary PJSM -RIH 5" x 7-5/8" Tandem Scraper Assy -POOH Scraper Assy after scraper run. Test BOP 250 psi low / 3000 psi high, passed. Witness waived by AOGCC 6/12/2008 00:00 - 6/13/2008 00:00 Operations Summary PJSM - RIH w/ 5" & 7-5/8" scrapewr BHA, Circulate well clean -POOH 6/13!2008 00:00 - 6/14/2008 00:00 Operations Summary PJSM - RIH w/ HES Champ packer, attempt to test 9-5/8" casing & 7-5/8" liner lap from 10,023' to surface -Pressure bled t/ 2000 PSI in 18 minutes -Hole took calculated fill on TOH (trip out of hole) - RIH w/ 9-5/8" scraper assembly -Circulate well Gean, sludge, no significant soilids - POOH w/ 9-5/8" scraper assembly and HES Champ packer. 6/14/2008 00:00 - 6/15/2008 00:00 Operations Summary PJSM - RIH w/ packer assembly testing casing. Set packer @ 3700', test casing OK, RIH to 3800' tested casino, did not hold - DV collar suspect, POOH - RIH log w/ USIT logging tools to 9900'. Contacted AOGCC of upcoming BOP test @ 18:00 by email and North Slope message recorder. 6/15/2008 00:00 - 6/16/2008 00:00 Operations Summary PJSM - SOA BOP Test 250 asi low ! 3000 asi high. passed. Witness waived by AOGCC Lou Grimaldi, perform accumulator pre-charge test, no failures - _ __ MU 7-5/8" RBP (retrievable bridge plug) w/ setting tool -RIH tag top of 7-5/8" liner @ 9,897', enter 7-5/8 RIH t/ 10,450, set 7-5/8" RBP - POH DP and setting tool 6/16/2008 00:00 - 6/17/2008 00:00 Operations Summary PJSM -Pressure test to 2700 PSI 9-5/8" x 7-5/8" casing from 3808' - 10,450', Test ood - POH 9-5/8" RTTS, RIH POH RBP in 7-5/8" 6/17/2008 00:00 - 6/18/2008 00:00 Operations Summary PJSM - RU Wireline unit - RIH w/ lead impression block, Tag fill @ 10,730' - MU CO (Dean out) and fishing BHA - RIH to top of fill 6/18/2008 00:00 - 6/19/2008 00:00 Operations Summary PJSM -RIH, Tag fill @ 10,723' -Clean out to 10,931' -Flow Test well -Change BHA 6/19/2008 00:00 - 6/20/2008 00:00 Operations Summary PJSM - MU BHA, RIH, Wash and ream, circulate @ 4 BPM, 750 PSI, pump Hi-visc sweep @ 11,252' ,POOH 6/20/2008 00:00 - 6/21/2008 00:00 Operations Summary PJSM- Circ. & condition hole, Trip out to top of 5" liner dragging junk/debree, RIH and wash/ream/mill from 11252' to 11255' stalling w/high torque, pump out to TOL 5" dragging junk/debree, POH and change BHA, P/U BHA #3 RIH with 4 1/8" Overshot & Grapple to 6679' • ~ ~Chrevrpn Chevron -Alaska Daily Operations Summary Well Name Field Name API/U W1 Lease/Serial CHEVNO License No./Prope... Orig KB Elev (ftK6) Water Depth (ft) AN-37 GRANITE PT, MIDDLE 507332039400 ADL0018742 IP3096 1871090 52.1 pall O eratlons 6/21/2008 00:00 - 6/22/2008 00:00 Operations Summary Notified AOGCC of upcoming BOP test. No reply, conversations with Tom MaunderPJSM - TIH to 10981' ,found tight spot/obstruction. Attempt to wash through with no success, attempt to ream through with no success, circulate hole while discuss with town, POOH and lay down 4 1/8" overshot assy. Test ROPE 250 psi low / 3000 psi high, passed. 6/22/2008 00:00 - 6/23/2008 00:00 Operations Summary PJSM -Complete SOA BOPE Test, PU overshot BHA Assv - RIH to TOL 5" @10469' Reverse circ. & establish parameters, Trip in hole to 11189' and wash down to 11252' and tag fish and set down 15k, pick up 5' and reverse circulate. 6/23/2008 00:00 - 6/24/2008 00:00 Operations Summary PJSM- Displace well over to Gean FIW (filtered Inlet water) from Production by reverse circulating @ 4 bpm with 1000 PSI -Flow check- Static -Hung up at 10981 tt. work stuck pipe & free pipe by jarring up, -POOH, UD DCs (drill collars) & overshot assy. (No Fish) 6/24/2008 00:00 - 6/25/2008 00:00 Operations Summary PJSM - RIH w/ 3-1/2" Tubing & DP (drill pipe) - MU E-Line & Camera for downhole picture -Circulate and condition hole for camera 6/25/2008 00:00 - 6/26/2008 00:00 Operations Summary PJSM - RU E-line, downhole camera -RIH for pictures of fish, estimate 9' fill on top -tight spots in liner, did not note visible problems - POH w/camera - CO fill to top of fish - RU E-line, camera, RIH. --~ 6/26/2008 00:00 - 6/27/2008 00:00 Operations Summary PJSM - RIH w/ Camera tp depth, Fill or obstruction above fish, did not get good picture - POH DP to 3-1/2" 9.2# - 5814' tubing kill string -circulate FIW w/ Aldacide, land hanger -pressure test hanger _ 6/27/2008 00:00 - 6/28/2008 00:00 Operations Summary PJSM - ND BOPE, NU Tree, Test tree void to 5000 psi -Hold 30 minutes, OK, Pull BPV -Set 2-way check test tree to 250 PSI LOw/ 5000 PSI Highh, 30 minutes each -Pull 2-way check _ Release rig 7/25/2008 00:00 - 7/26/2008 00:00 Operations Summary ChE!Vf OC9 ~nCisco Castro Chevron North erica Exploration and Production _~' Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 ~'``' Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE July 7, 2008 To: AOGCC Mahnken, Christine R ~~.Q,~N~~ JUL ~ ~ 208 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 WELL LOG TYPE SCALE LOG DATE INTER`JAL RUN # B-LINE Cp NOTES -LAS, LOGGED PDS, DLIS GRANITE POINT ST 18742 37 USIT 5" 14-Jun-08 200-9874 PS-1 1 1 LAS, PDS PACKER SETTING SCU 436-08 RECORD 5" 9-Jun-08 5746-5940 2 1 1 PDS COMPLETION SRU 34-28 RECORD 5" 1-Jul-08 5940-6228 1 1 1 PDS m TBU K-25 USIT 5" 11-Jun-08 200-6463 PS-1 1 1 PDS,LAS sip -!~ ~ ~~ ~~~ ~. ~ f ~~ ~~ t ~ ~~ vi ~ ~~ ~ -l d'~ ~~~~~ Please acknowledge,>receipt by signing and returning one copy of this transmittal ar-FAX to `907 263 7828. ~: Received ey:; '~ ! ~' ~~ ,_----~ ~ ~ Date: • C S ~ ~ ~ ~~ SARAH PALIN, GOVERNOR ALASIfiA OIL A11TD CirA.f! 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'I'IO1~T CODiDIISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 (,~ Anchorage, AK 99519 ~ ~ d J ~~ Re: Granite Point FYeld, Middle Kenai Oil Pool, Granite PT ST 18742 #3? (Anna 37) Sundry Number: 308-214 ~~,~~~,~ JU~~ ~ 2008 Dear Mr. Brandenburg: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~~~ Daniel T. Seamount, Jr. Chair DATED ~ day of June, 2008 Encl. STATE OF ALASKA ~~ ALA OIL AND GAS CONSERVATION COMI~ION ~'~~ ~ v ~"J~ APPLICATION FOR SUNDRY APPROVALS ~~~ ~ ~ - I ,1.~ ~ 20 AAC 25.280 N v 1. Type of Request: Abandon^ Suspend ^ Operational shutdown^~ Perforate ~ e ~ m~~l~~] i , , QQ ,,,, Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Exteri3itf~~ '~ 8~0 Change approved program^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Welt Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 187-109 ~ 3. Address: Stratigraphic ^ Service ^i 6. API Number: PO Box 196247, Anchorage, Alaska 99519 50-733-20394-00-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No 0 Granite PT ST 18742 #37 Anna-37 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): , ADL0018742 Cook Inlet Basin, GP, Anna, Offshore 106' KB - MSL Granite Point Unit /Middle Kenai Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11741' 10898' ~ 10575' 9779' NONE 11,282' MD Casing Length Size MD TVD Burst Collapse Structural 615' 20", 133#, K55 615' 615' 2125 1500 Conductor Surface 3522' 13-3/8", 68#, N80 3522' 3389' 5020 2260 Intermediate 10,150' 9-5/8", 53.5#, N80 10,150 9839' 7930 6620 Production 790' 7-5/8", 39#, 595, 9897' 10,687' 9157' 9866' 10,900 10,600 Liner 1204' 5", 18#, L80 10,440' 10,741' 9651' 9937' 10,140 10,490 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Attached Attached 3-1/2", 9.2#, L80 5800' Packers and SSSV Type: Packer-less Completion (no flow) Packers and SSSV MD (ft): Packer-less Completion 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service^ 15. Estimated Date for Jul-08 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ Q WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Newell - 263-7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 263-7657 Date 6/19/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ ~ ~ y i - pc-~ ~E ~ ~`;: ( c' ~~ -C'~ ~~s~~`'sl: ~ ~'~ `l R~E ~ ~~~~ ~` ~ e ~ ~ ,. 7 -~ ~ ,r 5 C.: C1'~c ~1t C~: ,US ~~E ~'t ~.., iL.Ot;,C~~.-vim ~ ~'~~..~,~ Subsequent Form Required: ~-1~~~ • •~-- ~~ ~`l S ~~-`~ ~'~, APPROVED BY ~ 2 ~ Approved by: COMMISSIONER THE COMMISSION Date: ~ O rr Form 10-403 Revised 06/2006 V ~ ~ ~ ~ ~! H L "~ ~~ ~*~ ~ ~~~~ ~ ~ ?(~0~ Submit in Duplicate Chevron 909 West 9Th Avenue Anchorage, Alaska 99501 ADL18742, Granite Point Unit Perforation Data: ANNA 37 DATE INTERVAL MD INTERVAL TVD INTERVA L SUBSEA Footage DESCRIPTION ZONE TOP BTM TOP BTM TOP BTM 3/14/198 11,225' 11,237' 10,356' 10,365' -10,251' -10,260' 12' 3.375" 4 SPF @ 90D, 48 C-7 11,307' 11,346' 10,429' 10,466' -10,324' -10,361' 39' 3.375" 4 SPF @ 90D 156 C-7 11,380' 11,446' 10,503' 10,558' -10,398' -10,453' 66' 3.375" 4SPF @ 90D 164 C-7 5/4/198 10,714' 10,784' 9,893' 9,956' -9,788' -9,851' 70' 3.375" 4 -.500 SPF @ 90D 272 C-5 10,798' 10,882' 9,965' 10,047' -9,860' -9,942' 84' 3.375" 4 -.500 SPF @ 90D 336 C-5 8/31/199 10,714' 10,784' 9,893' 9,956' -9,788' -9,855' 70' 2-1/8" Enerjet @ 6 SPF @ 90D C-5 10,798' 10,882' 9,965' 10,047' -9,860' -9,942' 84' 2-1/8" Enerjet @ 6 SPF @ 90D C-5 11,076' 11,091' 10,219' 10,238' -10,114' -10,133' 15' 2-1/8" Enerjet @ 6 SPF @ 90D C-6 11,154' 11,176' 10,292' 10,311' -10,187' -10,206' 22' 2-1/8" Enerjet @ 6 SPF @ 90D C-7 11,225' 11,237' 10,356' 10,365' -10,251' -10,260' 12' 2-1/8" Ener'et 6 SPF 90D C-7 Proposed Perforation Intervals DATE INTERVAL MD INTERVAL TVD INTERVA L SUBSEA Footage DESCRIPTION ZONE TOP BTM TOP BTM TOP BTM Proposed 10,715' 10,770' 48' 2-7/8" PJ Omega @ 6 SPF @ 60D C-5 Proposed 10,770' 10,785' 7' C-5 10795' 10,880' 75' C-5 Proposed 11,155' 11180' 14' 2-7/8" PJ Omega @ 6 SPF @ 60D C-7 11,315' 11,350' 25' Proposed 11,390' 11,450' S0' 2-7/8" PJ Omega @ 6 SPF @ 60D C-7 • Chevron ~ ~ Granite Point Field AN-37 Re-Completion Revision #l: 06/19/2008 This revision is for notification of an "Operational Shutdown per 20 AAC 25.072. Evaluation and testing of well An-37 we discovered the DV collar at 3716' MD - 3577' TVD has lost integrity. The balance of the well casings has integrity as determined by fluid pressure testing. We will be securing the well for an operational shutdown until arrival of an expandable 9-5/8" casing patch and running tools arrive at location. We will be running expandable casing patch across the previous measured test depths of 3700' to 3800' when we resume operations after this operational shutdown. We are expecting to be back on this well during this drilling and workover program. We are currently performing the clean out of the well per the planned program. OBJECTIVE: • De-completion of the AN-37 dual completion for single completion, as an enhanced oil recovery water injection well. PROCEDURE SUMMARY: • Rig work: CO Run to TD of 5" Liner, Gauge 5", Tag bottom goal at time of operational shutdown) • PU RIH 3-1/2" kill string to ± 5800', Land hanger- PT hanger seals _ • ND BOP NU Tree - PT Tree , ~`~ S ~~f~ "'~,'~+Ck-~ • Operational Shutdown - Wait on expandable casing patch repair materials. • MORU drilling rig over well, RU LP & HP Mud lines • Circulate well, Kill well, Set BPV - ND Tree, NU BOPE -Perform SOA BOP Test • POH Kill String -RIH, Continue with planned program, • Re-Perforate intervals per Chevron approved perforation sheet. • PU-RIH planned completion -set (Internal plastic coated pipe) • ND BOP - NU Tree - PT Completion • RD: skid off drilling rig on Anna platform leg 2, slot 8 • Operate well as FOR water injector AN-37_ Recomplete_Objective_Procedure_Summary_Rev_1.doc REVISED BY: JRN 06/19/08 Operational Shutdown 'r Proposed Well Schematic June 2008 ANNA Platform An-37 API 50-733-20394 PTD: 187-109 w~co s~ ~ Intivu-= izr ~~x sa' ~s.aia'- 9518"- tg75o ~s~s"- ~0.68T Size Type WT Grade CONN ID Top BTM Hole Size Cement Sacks CMT Top 30" Structural 320 STR Weld Surf 268' Driven 20" Conductor 133 X56 19" 44' 616 26" 1308 sx Surf 13-3/8 Sur Pipe 68 N80 Buttress 12.415 Surf 3522' 17.5" 2543 sx Surf 9-5/8 Sur CSG 53.5 N80 Buttress 8.535 Surf 10,150' 12.25" 1250 sx 7-5/8 CSG 39 C-95 FL4S 6.625 9897' 10,687' 8.5" 300 sx 5 Liner 18 L80 Buttress 4.276 10,440 11,644' 7" 768 sx 3.5" Plastic Coated Tubing Tubing 9.2 L80 Buttress 2.942 Surf 5800' i G/Tod a~rr es~cr # Depth ID Approximate Depths Jewelry Description 1 33.40' Hanger 2 34.4' 2.942 3-1/2" N80 9.2# Buttress Kill String" PBTD=11,575' TD=11,741' MAX HOLE AtVGLE = 31(uj8200' DATE INTERVAL DESCRIPTION ZOO 03/14/88 11225' - 11237' 3.375" 4 SPF @ 90D, 48 C-7 OCTG Rotating Hours 20" 61.5 Rotating Hours 11,307 - 11346 3.375" 4 SPF @ 90D 156 C-7 13-3/8" 313 Rotating Hours 11,380' -11,aa6' 3.375" 4SPF @ 90D 164 C-7 9-5/8" 574 Rotating Hours 7-5/8" 188 Rotating Hours 05/04/88 10,716' - 10,784' 3.375" 4 -.500 SPF @ 90D 272 C-5 5" Liner 59 Rotating Hours 10,798' - 10,882" 3.375" 4 -.500 SPF @ 90D 336 C-5 08/31196 10,714' - 10,784' 2-1 /8" Enerjet @ 6 SPF @ 90D C-5 10,798 - 10,882' 2-1 /8" Enerjet ~ 6 SPF @ 90D C-5 11,076' - 11,091' 2-1/8" Enerjet @ 6 SPF @ 90D C-6 11,154' - 11,176' 2-1/8" Enerjet @ 6 SPF @ 90D C-7 11,225' - 11,236' 2-1/8" Enerjet @ 6 SPF @ 90D C-7 Fish In Hole A. 11,282' APRS Jet Cutter String Inside 2-7/8" Tubing (Fish Length = 199.48') GHOST: 10,787': BHA Assembly: 192' Fish, off of side track bore DOGLEGS: 4.1"@ 1400' An-37 6 19 2008 Kill String.doc Page 1 of I JRN 6 19 2008 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, June 12, 2008 3:06 PM To: 'Walsh, Chantal [Petrotechnical]' Cc: Newell, Jack R [FEP]; Nienhaus, Doug R; Tyler, Steve L Subject: RE: Anna 37 Sundry number 308-113 /Permit to drill number 1ff7109 Chantal, Thanks for the information. No additional paperwork is needed. Adding new perforations within the same pool and reperforating intervals already shot are activities that do not require a sundry if done "stand alone". See the "activity matrix" attached to CO 351A. The actual operations should be reported in the operations summary filed with the 404. Call or message with any questions. ~~~~~®JUN ~. ~ 2~0~ Tom Maunder, PE AOGCC From: Walsh, Chantal [Petrotechnical] [mailto:WalshC@chevron.com] Sent: Thursday, June 12, 2008 2:59 PM To: Maunder, Thomas E (DOA) Cc: Newell, Jack R [FEP]; Nienhaus, Doug R; Tyler, Steve L Subject: Anna 37 Sundry number 308-113 /Permit to drill number 187 109 Tom, For the Anna 37 injector well (Sundry #308-113/ Permit to drill #187-109} we are currently working over, we would like to perforate the following intervals prior to rerunning the completion: 48' of C-5 within 10,715' -10,770' 7' of C-5 within 10,770' - 10785' 75' of C-5 within 10.795' -10,880' 14' of C-7 within 11,155' -11,180' 25' of C-7 within 11,315' - 11,350' 50' of C-7 within 11,390' -11,450' Please let me know if you require further information for this approval. Chantal Walsh Engineer Chevron Alaska (907)263-7627 6/13/2008 • • ,.~.~. ~~ ~ ~ , ~`~,~ .J ~ ~"' ~., - ~ SARAH PALlN, GOVERNOR ~.~r ~ .! °~~~ ~~ ~ ~ ~.~- -~ °-~333iN 7th AVENUE, SUITE 100 CO1~ST'iR~ATIOI~T CO1~II-IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 APR 20D~ Re: Granite Point Unit, Middle Kenai Oil Pool, Granite PT ST 18742 #37 (Anna-37) Sundry Number: 308-113 ~~-1 Dear Mr. Brandenburg: \~~ 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided iri 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of April, 2008 Encl. ~~~~~~ &&,q~ STATE OF ALASKA ,~• ;~, Q ~~ RLASKA OIL AND GAS CONSERVATION COM~ION PR O APPLICATION FOR SUNDRY APPROV ~ ~~~ Zo AAC Zs.2so ~ Oil & Gas Co am~~,sion 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ ~e Other^ Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Run Completion • Change approved program^ Pull Tubing Q • Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Chevron/ Union Oil Company of California Development ^ Exploratory ^ 187-109 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, Alaska 99519 50-733-20394-00-00 • 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ ° Granite PT ST 18742 #37 (Anna-37 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL018742 Cook Inlet Basin, GP, Anna, Offshore 106' KB - MSL Granite Point Unit /Middle Kenai Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11741' 10898' 10575' 9779' NONE 11,282' MD Casing Length Size MD TVD Burst Collapse Structural 615' 20", 133#, K55 615' 615' 2125 1500 Conductor .Surface 3522' 13-3/8", 68#, N80 3522' 3389' 5020 2260 Intermediate 10,150' 9-5/8", 53.5#, N80 10,150 9839' 7930 6620 Production 790' 7-5/8", 39#, S95, 9897' 10,687' 9157' 9866' 10,900 10,600 Liner 1204' 5", 18#, L80 10,440' 10,741' 9651' 10,898' 10,140 10,490 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Attached Attached LS3-1/2" 9.2#, Buttress LS: L80, Above Cavity Pump LS Surf - t/9748' LS: 2-7/8", 6.4# Buttress LS: N80, Below Cavity Pump LS: f/ 9770' t/10,660' SS:3-1/2" 9.2#, Buttress SS: L80 SS: 9739' Packers and SSSV Type: Packer-less Completion (no flow) Packers and SSSV MD (ft): Packer-less Completion 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch 0 Exploratory ^ Development ^ Service 0 15. Estimated Date for May-08 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Newell - 263-7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature .~ ~,, P 263-7657 Date 3/19/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _ ~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: ~~r\ ~~ ` ~ ~~ ~ ~, ~®~ S ~Ov~C D rC ~4~. ~ 0~ ~ C'~t~G_ \ S Sv~.~rZsS ~ ~~ ~O +iM ~~ ~C~.~ . ~ j C ~ ~ ~.~i~.*k ftj~~± ~~ ,~ L~~~ Subsequent Form Required: ~Q APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: _ ~ ~ 1~, .~.oE Chevron 909 West 9Th Avenue Anchorage, Alaska 99501 ADL18742, Granite Point Unit Perforation Data: ANNA 37 DATE INTERVAL MD INTERVAL TVD INTERVA L SUBSEA Footage DESCRIPTION ZONE TOP BTM TOP BTM TOP BTM 3/14/198 11,225' 11,237' 10,356' 10,365' -10,251' -10,260' 12' 3.375" 4 SPF @ 90D, 48 C-7 11;307' 11,346' 10,429' 10,466' -10,324' -10,361' 39' 3.375" 4 SPF @ 90D 156 C-7 .11,380' 11,446' 10,503' 10,558' -10,398' -10,453' 66' 3.375" 4SPF @ 90D 164 C-7 5/4/198 10,714' 10,784' 9,893' 9,956' -9,788' -9,851' 70' 3.375" 4 -.500 SPF @ 90D 272 C-5 10,798' 10,882' 9,965' 10,047' -9,860' -9,942' 84' 3.375" 4 -.500 SPF @ 90D 336 C-5 8/31/199 10,714' 10,784' 9,893' 9,956' -9,788' -9,855' 70' 2-1/8" Enerjet @ 6 SPF @ 90D C-5 10,798' 10,882' 9,965' 10,047' -9,860' -9,942' 84' 2-1/8" Enerjet @ 6 SPF @ 90D C-5 11,076' 11,091' 10,219' 10,238' -10,114' -10,133' 15' 2-1/8" Enerjet @ 6 SPF @ 90D C-6 11,154' 11,176' 10,292' 10,311' -10,187' -10,206' 22' 2-1 /8" Enerjet @ 6 SPF @ 90D C-7 11,225' 11,237' 10,356' 10,365' -10 251' -10,260' 12' 2-1/8" Eneret 6 SPF 90D C-7 • Chevron ~ ~ Granite Point Field AN-37 Re-Completion Revision #0: 03/07/2008 OBJECTIVE: • De-completion of the AN-37 dual completion for single completion, as an enhanced oil recovery water injection well. PROCEDURE SUMMARY: • Prepare well for workover operations coordinating with platform operations • MIRU: skid over drilling rig on Anna platform to Leg 2, slot 8, well #An-37, blind as needed • Flow check well for well work operations, circulate well (kill well) • Open LS & SS, set mechanical plugs in strings, bleed any pressure from hanger, ND tree. • NU BOPE per arrangement, align BOP, orient rams for dual string completion, RU all lines for LP & HP mud equipment, PT all BOPE. ~-~ ~o~".ic-~ ~.~;,~~.~ejC.- ~St.©f~p,C~>~'~~~~I "~°'~o`~~'~+~C-~`? • Dual completion operations -hanger and surface disconnections. ~ ~~ ~,~ • POH w/dual completion, lay down same. • PU CO BHA -Watermelon Mill, Scraper run 9-5/8" casing to top of 7-5/8" casing, POH: Scraper run 7-5/8" casing to top of 5" liner, circulate hole, POH • Wireline work: CO Run to TD of 5" Liner, Gauge 5", Tag bottom • PU RTTS Tool, RIH t/ depth above 5" liner hanger, circulate well bore to condition well fluid - POH • Set RTTS and pressure test casing(s) per Area Injection Order #6, Rule #6 -Release RTTS, POH • PU-RIH planned completion -set (Internal plastic coated pipe) • ND BOP - NU Tree - PT Completion • RD: skid off drilling rig on Anna platform leg 2, slot 8 • Operate well as FOR water injector AN-37 Recomplete Objective and Procedure Summary.doc REVISED BY: JRN 03/07/08 • ANNA Platform AN-37 Well Bore Diagram AN-37 API 50-733-20394-00 PTD: "187-109" ~m~~B1iB,l,~~,=,~ Spud: Granite Point Well 18742 No 37 @ 03.30 hours, November 2, 1987 I~ xta a xr unite Point Field II AN-37 Completed 4/20/88 Size Type WT Grade CONN ID Top BTM Hole Size Cement CMT Sacks To 30" Structural 320 STR Weld Surf 268' Driven 20" Conductor 133 X56 18.730" 44' 616 26" 1308 sx Surf 13-318 Sur Pipe 68 N80 Buttress 12.415 Surf 3522' 17.5" 2543 sx Surf 9-5/8 Sur CSG 53.5 N80 Buttress 8.535 Surf 10,150' 12.25" 1250 sx 7-5/8 CSG 39 S00-95 Buttress 6.625 9897' 10,687' 8.5" 300 sx 5 Liner 18 L80 Buttress 4.276 10,440 11,644' 7" 768 sx Tubing -Long String 3.5" P- Tubing 2.875" P-Tubing Tubing -Short String 3.5" P-Tubing 9.2 6.4 9.2 L80 N80 N80 SCBT SCBT SCBT 2.992 2.441 2.992 Surf 9770' Surf 9748' 10,699' 9738' Upper Long String Lower Long String Short String # Depth ID Jewelry Description Long String 1 33.40' CIW Split DCB Hanger 2 34.4' Tubing 3-1l2" L80 9.2# Buttress 3 9747.6' KOBE 3" DBL "B" Pump Cavity Assembly,3" x 1-3/4" x 1-1/2" OD" 5-3/4" 4 9770.3' X-Over: 2-7/8" 8 RND x 2-7/8" Buttress 10 699' Tubing 2-7/8" N80 6.4# Buttress, E-Line Jet Cut 5 , Short String 1 33.40' CIW Split DCB Hanger 34 4' Tubing 3-1/2" N80 9.2# Buttress (9703.28' 7 . 8 9737.68' X-Over: 3-1/2" Buttress x 2-3/8" 8 RND 9 9738.98' Pup Joint: 2-3/8" N80 8 RND 4.6 # 3 9747.6' Kobe 3" DBL "B" Pump Cavity Assembly NOTE: All 3-1/2" Tubing have Atlas-Bradford Couplings OCTG Rotating Hours 20" 61.5 Rotating Hours 13-3/8" 313 Rotating Hours 9-5/8" 574 Rotating Hours 7-5/8" 188 Rotating Hours 5" Liner 59 Rotating Hours DOGLEGS: 4.1"@ 1400' Fish In Hole ~_ ~ _._.._.____ __ A. 11,282' APRS Jet Cutter String Inside 2-7/8" Tubing (Fish Length = 199.48') GHOST: 10,787': BHA Assembly: 192' Fish, off of side track bore DATE INTERVAL DESCRIPTION ZONE 03/14/68 11225' - 11237' 3.375" 4 SPF @ 90D, 48 C-7 11,307 - 11346 3.375" 4 SPF ~ 90D 156 C-7 11,380' - 11,446' 3.375" 4SPF @ 90D 164 C-7 05/04/88 10,716' - 10,784' 3.375" 4 -.500 SPF ~ 90D 272 C-5 10,798' - 10,882" 3.375" 4 -.500 SPF ~ 90D 336 C-5 08/31/96 10,714' - 10,784' 2-1/8" Enerjet @ 6 SPF ~ 90D C-5 10,798 - 10,882' 2-1/8" Enerjet ~ 6 SPF ~ 90D C-5 11,076' - 11,091' 2-1/8" Enerjet ~ 6 SPF @ 90D C-6 11,154' - 11,176' 2-118" Enerjet ~ 6 SPF ~ 90D C-7 11,225' - 11,236' 2-1/8" Enerjet @ 6 SPF ~ 90D C-7 An-37 Schema 3 2008 Rl.doc Paee 1 of 1 JRN Rl PBTD =11,575 TD =11,741' MAX HDLEANGLE = 31 @8200' • w~eo sea ~ crtivq =1T!' ~ 3aa 3715 WTod 3758' Gvir BSKi ~' i~ .~ - per . ~, sya'-1g15Q~'- ~ ,,~J r~ :! ' a '~ i~ ,r .°i ~i ~ ~~ 7~5~6"-lgssr • Size Type WT Grade CONN ID Top BTM Hole Cement C11` Size Sacks T- 30" Structural 320 STR Weld Surf 268' Driven 20" Conductor 133 X56 19" 44' 616 26" 1308 sx Surf 13-3/8 Sur Pipe 68 N80 Buttress 12.415 Surf 3522' 17.5" 2543 sx Surf 9-5/8 Sur CSG 53.5 N80 Buttress 8.535 Surf 10,150' 12.25" 1250 sx 7-5/8 CSG 39 S00-95 Buttress 6.625 9897' 10,687' 8.5" 300 sx 5 Liner 18 L80 Buttress 4.276 10,440 11,644' 7" 768 sx 3.5" Plastic Coated Tubing P-Tubing 9.2 L80 H533 2.942 Surf 10,375' Plastic Coated Tubing Pin ID 2.942 TK69 Internal Coating Process # Depth ID Jewelry Description Approximate Depths 1 33.40' Hanger 2 34.4' Plastic Coated Tubing 3-1/2" N80 9.2# Hydril 533 w/ CB Ring "R2, 340 Jnts" 3 10,400 Anchor Seal Assembly 4 10,400' 7-5/8" Hydraulic Set Packer (OD Min Run: 6.466") 4 5 L=10' 2.942" Plastic Coated Tubing Pup 3-1/2" L80 9.2# Hydril 533 w/ CB Ring "10' Pup" 6 X Profile 13 Chrome Nipple H563 Connection 7 L=20' 2.942" Plastic Coated Tubing Pup 3-1/2" L80 9.2# Hydril 533 w/ CB Ring "20' Pup" 8 10,450' Mule Shoe -Wire Line Entry Guide H563 Connection PC w/ Ball Seat SO Assy NOTE : All 3-1/2" Tubing has Hydril 533 Connection, 2.867 Drift, H563 Collar OD 4.250" 8'-11.644' ~'~:.:.~?7~ PB'iD=11,575 TD=11,741' MAX HOLEANC,LE=31 (rD8200' OCTG Rotating Hours 20" 61.5 Rotating Hours 13-3/8" 313 Rotating Hours 9-5/8" 574 Rotating Hours 7-5/8" 188 Rotating Hours 5" Liner 59 Rotating Hours 03/14/88 11225' - t 1237' 3.375" 4 SPF ~ 90D, 48 C-7 11,307 - 11346 3.375" 4 SPF (61 90D 156 C-7 11,380' - 11,446' 3.375" 4SPF ~ 90D 164 C-7 05/04/88 10,716' - 10,784' 3.375" 4 -.500 SPF ~ 90D 272 C-5 10,798' - 10,882" 3.375" 4 -.500 SPF ~ 90D 336 C-5 08/31/96 10,714' - 10,784' 2-1/8" Enerjet ~ 6 SPF ~ 90D C-5 10,798 - 10,882' 2-1 /8" Enerjet (~ 6 SPF @ 90D C-5 11,076' - 11,091' 2-1/8" Enerjet ~ 6 SPF C~ 90D C-6 11,154' - 11,176' 2-1/8" Enerjet ~ 6 SPF ~ 90D C-7 11,225' - 11,236' 2-1 /8" Enerjet @ 6 SPF ~ 90D C-7 Fish In Hole A. 11,282' APRS Jet Cutter String Inside 2-7/8" Tubing (Fish Length = 199.48') DOGLEGS: 4.1 °@ 1400' GHOST: 10,787': BHA Assembly: 192' Fish, off of side track bore An-37 Proposed 3 2008.doc ~ PaQe 1 of 1 JRN 3 07 2008 • AN-37 BOP Stack up Bottom of Rotary Table Anna 37 AIO 6.005 Complia~Temp Survey Page 1 of 1 • Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp@chevron.com] ~~ ~ ~ ~~ Sent; Thursday, April 20, 2006 2:38 PM To: Thomas Maunder; James Regg Cc: Martin, J. Hal Subject: Anna 37 AIO 6.005 Compliance Temp Survey Attachments: AN-37 Temp Survey 5-31-03 vs 6-19-05.zip Jim & Tom, ®~ ~~ls~~ C Found three more wells with the same situation as An-38. I'll send them in separate a-mails because of the size of each attached file. Anna 37, AIO 6.005 (PTD 187-109) was also approved on 3/29!05. The temp survey used for the admin approval was conducted on 5!31/03. Our follow up compliance temp survey was completed on 6/19/05. Apparently this temp survey was not sent to you last year. Even though routine scheduling would use the AIO 6.005 approval date of 3/29/05 as the anniversary date for compliance issues for this well, because the AA was so late getting processed (over 21 months), we did afollow- uptemp survey at the 24 month mark from the previous temp survey date (5/31/03) and not from the AA approval date. This seems to be more along the intent of the approved process for scheduling compliance temp surveys. Bottom line is that the overlaid temp plots on An-37 show great similarity and indicate very stable downhole containment of the injection fluids. There is an interesting repeated temperature kick just as the temp tool enters the fluid in the tubing. In addition, the daily rates and pressures for this well are being sent to you monthly and appear to show expected changes in the pressures as operating conditions change. Please call me to discuss if there is any confusion. Larry 263-7661 «AN-37 Temp Survey 5-31-03 vs 6-19-05.zip» ~~ ~ 4/3/2008 I~ • Maunder, Thomas E (DOA From: Ruff, Christopher A (ruffct~unocal.com] ' Sent: Monday, April 15, 2002 2:07 PM ~h~c~ ~~~`~`® To: 'Tom Maunder' Cc: Cole, David A; Dorman, Allen; Delago, Paul A; Myers, Chris S; Moultrie, Dan R Subject: RE: Anna 37 Injector Shut-in due to anomalous injection rates and pressure The information is recorded daily. The well acted up between the times when it is normally recorded. Therefore it won't actually show up in the data if the problem doesn't last more than 24 hours -----Original Message----- ~'rom: Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, April 15, 2002 2:01 PM To: Ruff, Christopher A Cc: Cole, David A; Dorman, Allen; Delago, Paul A; Myers, Chris S; Moultrie, Dan R Subject: Re: Anna 37 Injector Shut-in due to anomalous injection rates and pressure Chris, et al: Thanks for the notification. In looking at the pressure and rate information you have provided, I don't see the anomaly that prompted the action to SI. Regardless, from what is related in the platform note it looks like the system is working. Please keep us informed regarding what can be determined. Tom Maunder, PE AOGCC "Ruff, Christopher A" wrote: > Tom, > The field observed anomalous injection rates and pressures for this > well on > Monday morning. When I arrived at work on Monday morning I had the > field shut-in the well as a precautionary measure. > As you know this well is one of the packerless Anna injectors and was > injecting under a variance. We plan to keep this well shut-in and are > developing a plan to determine if we will be able to inject into it in > the future. > Unocal will inform you as our plan develops. > Please give me a call if you have any questions. > I have attached the last month's injection information. > Report Name Tbg String Time Period Date Created > Waterflood Injector We11 Status AN 37-42 Last Month > 4/10/02 > Date Length Volume Tbg Press Csg Press Outer Csg Press > Comments > (hours) (bpd) (psi) > 4/9/2002 0 0 > 4/8/2002 10 218 > 4/7/2002 24 219 > 4/6/2002 24 199 > 4/5/2002 24 220 > 4/4/2002 24 252 > 4/3/2002 24 246 (psi) (psi) 0 0 295 0 100 286 3415 3415 290 3325 3325 295 3320 3320 290 3260 3260 295 3455 3455 295 1 • > 4/2/2002 24 250 3420 3420 555 > 4/1/2002 24 255 3405 3405 300 > 3/31/2002 24 261 3469 3450 302 > 3/30/2002 24 264 3459 3450 302 > 3/29/2002 24 262 3445 3440 306 > 3/28/2002 24 261 3438 3430 308 > 3/27/2002 24 260 3414 3400 309 > 3/26/2002 24 233 3364 3350 309 > 3/25/2002 24 262 2850 2850 306 > 3/24/2002 24 264 3415 3415 310 > 3/23/2002 24 264 3405 3405 310 > 3/22/2002 24 273 3450 3450 315 > 3/21/2002 24 273 3435 3435 315 > 3/20/2002 24 272 3410 3410 320 > 3/19/2002 24 271 3370 3370 325 3/18/2002 24 290 3330 3330 330 > 3/17/2002 24 246 3273 3300 0 > 3/16/2002 24 223 3434 3425 0 > 3/15/2002 24 219 2516 2500 0 > 3/14/2002 24 60 2320 2400 0 > 3/13/2002 0 0 0 0 0 > 3/12/2002 0 0 3 50 0 > 3/11/2002 24 362 3209 3200 0 > Chris Ruff > > -----Origina l Message----- > > From: Delago, Paul A > > Sent: Monday, April 08, 2002 6:23 AM > > To: Ruff, C hristopher A > > Subject: Anna37 > > > > Chris, > > I believe we fractured well 37 this mo rning. The cho ke has been set > > at full open and taking a little over 200bb1s a day. Early this > > morning manif lod pressure fe ll way off and we found 37 injecting at > > 1200+bpd rate .......Paul > > > > Paul Delago > > Lead Operator > > Unocal Platfo rm Anna > > 907-776-6620 > > 2 • Maunder, Thomas E (DOA From: Tom Maunder [tom_maunderQadmin.state.ak.us] (' Sent: Tuesday, August 14, 2001 5:00 PM ~~~~. ~r ~~~ ` To: Ruff, Christopher A Subject: Re: Anna Waterflood Surtace Facility problems and the planned Temp Surveys for An 21, 25, 37 and 38. Attachments: tom maunder.vcf tom_maunder.vcf (645 B) Chris, Your plan looks good and takes in consideration your equipment concerns. Good luck. Tom "Ruff, Christopher A" wrote: > Tom, > I just finished reviewing the problems that we have run into on the > Anna platform and wanted to give you an update. > * The wellheads for AN 21, 25, 38 and 39 need to be customized to hook > up the lubricator for the slickline rig and the estimated delivery for > the part is around the third week in September, so the temp surveys > are on hold until that time. > * There have been some minor leaks in some of the surface piping > around the sand filters and we are planning to make piping repairs to > the system starting in a couple weeks. Unfortunately I was hoping to > coordinate the temp surveys with the shut-down for these repairs. > So, unless you have any problems with this...the current plan is: > 1) Shutdown the waterflood to make the repairs (estimated 4 week > shutdown) > 2) Bring the all waterflood back on including the 4 new wells > 3) After an appropriate period of time (at least 14 - 30 days), we > will run the temp surveys > 4) Complete the final analysis to obtain the Variances on these 4 wells. > Piease let me know what you think of the plan. Meanwhile I am still > working on a plan for AN 32nD and AN 26. > Chris Ruff > Senior Petroleum Engineer > Unocal Alaska > 907-263-7830 > ruffc@unocal.com 1 • Maunder, Thomas E (DOA • From: Ruff, Christopher A [ruffc@unocal.com] Sent: Wednesday, August 08, 2001 3:59 PM l~a:~~~t"~.C~ ` To: 'Tom Maunder' Cc: Dolan, Jeff J; Moultrie, Dan R; Dorman, Alfen; Delago, Paul A; Myers, Chris S; Cole, David A Subject: RE: Step Rate Tests Results for Anna 21, 25, 37 and 38 Attachments: AN 21 Step Rate Test.xfs; AN 25 Step Rate Test.xis; AN 37 Step Rate Test.xfs; AN 38 Step Rate Test.xls ~ ~~ ~ AN 21 Step Rate AN 25 Step Rate AN 37 Step Rate AN 38 Step Rate Test.xls (31 K... Test.xis (30 K... Test.xis (31 K... Test.xls (33 K... Yes, we are going to limit our rates as stated below, but plan to run further tests in the future that will allow us to increase the rates to the mechanical limit. Here are better summaries of the data and the limits. Delete the files sent previously. I have hardcopies of the files in the mail. Chris -----Original Message----- From: Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, August 08, 2001 12:58 PM To: Ruff, Christopher A Subject: Re: Step Rate Tests Results for Anna 21, 25, 37 and 38 Chris, Thanks for the information. I need to look at the well drawings and refresh my memory. Only real question I have right now is with regards to An 38. Since it appears that the frac pressure was reached, will you be lowering the injection pressure to stay below it?? Tom "Ruff, Christopher A" wrote: > Tom, > Here is the data from the step rate tests on the above wells. We > didn't run > a SRT on Anna 32RD and 36 because we haven't finished the conversion yet. > The SRT's went very well. Unfortunately, due to a miss communication, > the SRT's weren't run up to the mechanical limits. The tests were > designed to run up to the mechanical limits {70% of the casing burst > strength or the maximum injection pressure for the pumps, 5000 psi). > Anna 37 and Anna 38's > tests are complete tests and this is the final submission, but Anna 21 > and Anna 25's tests were stopped early due to ambiguous instructions. > The Anna 36 conversion is on hold for at least 6 months, we want to > wait for > a response before converting this well. The Anna 32RD conversion is on > hold until we have time to analyze the casing pressure further. It > looks like there has always been some pressure on the outer casing 1 > that can't be permanently bled off. We are working on a diagnostic plan. > Based on these tests and the casing burst strengths, the plan is to > limit the injection pressures as follows. > CONCLUSIONS Maximum Injection Pressure and reason for limit > An 21 3660 (Test stopped before reaching Frac Pressure or casing limit of > 4774 psi) > An 25 3400 (Test stopped before reaching Frac Pressure or casing limit of > 4025 psi) > An 37 4730 (Test stopped before reaching Frac Pressure or casing limit of > 6566 psi) > An 38 3820 (Apparent Frac Pressure observed at 3820 psi) > After we complete the temp survey's on these wells and make some > surface facility repairs we will rerun the SRT's for AN 21 and AN 25 > if we decide we > want to increase the injection pressure above the pressure which the current > tests have been run. > Chris > «AN 21 Step Rate Test.xls» «AN 25 Step Rate Test.xls» «AN 37 > Step Rate Test.xls» «AN 38 Step Rate Test.xls» > > Name: AN 21 Step Rate Test.xls > AN 21 Step Rate Test.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) > Encoding: base64 > Name: AN 25 Step Rate Test.xls > AN 25 Step Rate Test.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) > Encoding: base64 > Name: AN 37 Step Rate Test.xls > AN 37 Step Rate Test.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel} > Encoding: base64 > Name: AN 38 Step Rate Test.xls > AN 38 Step Rate Test.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) > Encoding: base64 2 AN-37 Step Rate Test Frac Pressure and Infectivity Analysis 5000 4500 4000 3500 as ya 3000 d 2500 a rn 2000 3 1500 1000 500 0 Q a Q Q Q Q Q a Q M O N M O ~ N ~ r <V ~ N M d' (O f~ d0 O ~ ~ ~ ~ ~ ~ ~ ~ r O O O O O O O O ~ O O O O O O O O O M M M M (\ M M M - 1200 1000 800 a a~ r 600 ~ 0 d c 400 200 0 a O r O O M • • 4/3/2008 \\Ak-Anchorage\Groupsi00E\OOEFields\GPFWnna\WaterfloodWN 37 Step Rate Test.xis 1:33 PM ANNA-37 Step Rate Test Frac Pressure and Infectivity Analysis 5000 4500 4000 ~ 3500 as y 3000 a as 2500 a rn c 2000 1500 1000 500 0 0 200 400 600 800 1000 1200 Rate (bwipd) \\Ak-Anchorage\Groups\OOE\OOEFields\GPF\Anna\Waterflood\AN 37 Step Rate Test.xls 1400 4/3/2008 1:33 PM • • • Anna Injection well test sheet top test w en max mum a owa e n ect on pressure s rest e Well # Date /Time 12ate Tbg psi Csg psi Choke Comments Well -ANNA-37 bw d 13 3/8 e toe ac a es er ow s a i ¢e or several days (Hook up chart to tbg pressure at this point) 7/30/01 1:00 AM 230 613 436 og ac ua ra a an pressures before opening up well 7/30/01 2:00 AM 227 623 436 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/30/01 2:00 AM 312 653 436 og ac ua ra a an pressures before opening up well 7/30/01 3:00 AM 305 1030 439 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/30/01 3:00 AM 402 1069 441 og ac ua ra a an pressures before opening up well 7130/01 4:00 AM 386 1456 442 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/30/01 4:00 AM 502 1497 444 og ac ua ra a an pressures before opening up well 7/30/01 5:00 AM 481 2013 450 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/30/01 5:00 AM 608 2066 450 og actua ra a an pressures before opening up well 7/30/01 6:00 AM 580 2695 453 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/30/01 6:00 AM 696 ' 2777 455 og actua ra a an pressures before opening up well 7/30/01 7:00 AM 670 3283 456 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/30/01 7:00 AM 800 3428 458 og ac ua ra a an pressures before opening up well 7/30/01 8:00 AM 732 3716 461 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7130/01 8:00 AM 900 3822 461 og ac ua re a an pressures before opening up well 7/30/01 9:00 AM 910 4500 469 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) 7/30/01 9:00 AM 1004 4610 469 og ac ua ra a an pressures before opening up well 7/30/01 10:00 AM 860 4730 468 og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) og ac ua ra a an pressures before opening up well og ac ua ra a an pressures after opening well up (attempt to increase rate 100 bwpd) CONTINUE SPREADSHEET IF NEEDED \\Ak-Anchorage\Groups\OOE\OOEFields\GPFWnna\Waterflood\AN 37 Step Rate Test.xls 4/3/2008 2:45 PM ) @ìTIi\\1IIErrnlE®n ® ~ rr ® ji'/ @ u lru J It ~ If U1H1LfÙ @ lJ~Ln1 . AIJASIiA OIL AND GAS / CONSERVATION COMMISSION " j ) FRANK H. MURKOWSKI, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.005 Mr. Larry Greenstein Production Technician U nocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 SCANNED 14 PR 2 0 2.005 RE: Granite Point State 18742 #37 [aka Anna #37] (PTD 187-109) Request for Administrative Approval AIO 6 Dear Mr. Greenstein: Per Rule 9 of Area Injection Order ("AIO") 006, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal")'s request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. The subject well is not completed with a packer and there is no plan to workover the well to install a packer. 2. Several similarly equipped wells on Anna Platform were previously converted to service wells beginning in 2000 according to a procedure developed by Unocal and approved by the Commission. 3. Unocal was authorized to convert Anna 37 from producer to injector via Sundry permit 300-218 approved October 25, 2000. 4. As required by the conversion Sundry permit, Unocal has been recording daily in- jection rates and well pressures and has been reporting this information to the Commission monthly. In support of this application, Unocal has submitted the re- sults of temperature logs obtained in compliance with the conversion Sundry permit and a graphical maximum operating pressure determination. 5. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. The monthly rate/pressure information has not indi- cated any pressure integrity loss. 6. The pressure information gathered with the temperature survey indicates that the bottomhole pressure in the vicinity of Anna 37 is low and insufficient to support a fluid column to surface. According to the injection report, there has not been any 1\ .. Mr. Larry Greenstein March 29, 2005 Page 2 of2 ) ) injection since May 2002. A similar low reservoir pressure was shown on Anna 5. 7. The original analysis performed for the conversion in October 2000 is still valid. 8. An aquifer exemption is in effect below Cook Inlet for Granite Point Field [40 CFR 147.1 02(b )(2)(i).] Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Granite Point State 18742 #37 [aka Anna #37] is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record wellhead pressures [TII/O] (tubing/inner annu- lus/outer annulus) and injection rate daily and submit this information to the Commission monthly; 3. Unocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 4. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and 5. After well shut in, AOGCC approval shall be required to restart injection. 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 rehearing. A request for rehearing is consid- ered 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~ Daniel T. Seamount, Jr. Commissioner ) Unocal Alaska ) Union Oil Company of California 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7661; Fax (907) 263-7847 UNOCALe S'·, r' i~ !ì\,j Ii\. ~ E' "þ'") {\ i) n ~) f! 'j ['j n s ~. v..r'\~~~" ~:-e' Ji~l n ,""r \~~ l. I V~..f Larry P. Greenstein Prodction Technician Date: February 17, 2005 Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W. ¡th Ave., Suite #100 Anchorage, AK 99501-3539 Attn: Tom Maunder Administrative Approval Request Well No. An-37 Injector Anna Platform Granite Point Field Dear Chair Norman, Unocal requests administrative approval under Area Injection Order 6, Rule 9 for the continuation of injection of non-hazardous Class II fluids for the Anna Platform Well No. An-37 Injector (Permit # 187-109) in Granite Point Field. To support this request, Unocal submits the following information and documentation: 1 . Schematic (attached). 2. Temperature survey comparison plot (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief/relevant well history (below and attached). This well was drilled as a producer in December of 1987. Per the attached well history, it was converted to a waterflood injector and has been injecting with a variance since June of 2001. The well has been shut-in since July of 2004. Injection was authorized after a review of the well's construction and demonstration of integrity via temperature logs and step rate injection tests according to a procedure titled IIProcedures to Obtain Variances on Packerless Wells (Version 4) dated February 9,200011. This procedure was cooperatively developed by Unocal and the Commission in accord with 20 ACC 25.450(a), that allows the Commission to authorize less stringent well operating and construction requirements where injection does not occur into, through or above fresh water. In addition, please note that Granite Point Field has an auquifer exemption per EPA 40 CFR 147.102 (b)(2)(i). The temperature survey run on 5/31/2003 matches the last survey run on 11/23/2001 in character showing no cooling anomalies above the packer. This indicates that injection is occurring only ) ) into the Tyonek C-Sands. Also, the plotted daily monitoring, which is reported monthly, hasn't shown any unexplainable rate or pressure responses from this well. Unocal will continue to monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7661 or Hal Martin at 263-7675. Sincerely, /) f?~' ,'.- I.' d !~Á/vU,' ~, '~ /Áht" t/ -v- - (/ Larry P. Gr~enstein cc: Dave Cole Hal Martin MIT book Well File ~//b~'*ro~844' 1117S' 10 1'741' .. .. l'07ta-1071W 1 0718-1 OIIZ' 11f125-t11Sr 11æ7-11" 11310-11441' ~ r.,~ Date spud DotII 11-o1-tt1 ."... ... .lrlßl ~ 2. IIat _I. GJI. ........ ~ I .. 11. nœ. 1t1-' S.IL ....... Le ~ ... 1D - 2M' .... 4013' fD. ,. ....... It74" II» ''''1VD 1157S' W, b~- ... .tl' WI." Oftt 13 ~ ..... .. .t 311II' W230G ... Oftt . .... CIIIIrW ..a .. 101., W'iDO .. Crnt 7 Ø' ..... Nt twt-tC11117 IiIIDO .. Cmt r. 181,....... 10440-1'.... ."... CIfIt 0-& 1:=:1= ~ ~ ~"./. "f /1'-- cll -: II ø,..¡, ~/jt:llf I /, C~:~'I - I'~ u f' 0-'11" If, f U':ft4... --'-. I -, 7(J~ 6J¡:=r-c~ t'fMJ.Jsfi} 1/ z..,z. ,_o5_ m ICIPD x 74 ..-0 X II IØD i IE! I ?fet l La f ¿ 'bt'tfpd 7Zf> ~ ; . ~f!;f (-~6) 7 . '.1- Hone '1-18-17 & œ-ø__...... 11-1....7 02-27_ fill - 12-17-87 a, 01... caNDIAR t2-t7-17 01 01 . CHM 01-'...... ~ cø-1o-11 ""'" .... .... ..... ~ . , IC I "3~-~ <__ ' ,- 4 }I , 1ø-.., , , =.. 1...,. . 13 ~. IS ... CM 3S2r'-" '.. .MI" ~ CM lel1. I '. .... tSSf CM e1S" .. f' ... - "'i IS~ - .- ..... A. 3 v.r ... M-IO let: IIOÐ 1M W1W .. 3 fIr~~31Jr''''''X-o rrw c. J~................"'" IfW OJ- run ......... ) .~: . ~ ~ ¿. 34' ~ .,.. 17_ wnr 1771' .c 1cmw 10101' 1"- t.nt .... , Dual1IIOSf; ·3 MCUDD t :s ~ IHD =: IICID ~ 4. ~ ~ ;r .". I. 2 7"" m. I TJr lUll X-o .. 11# N-8D laM T" ~ 11/r X 2 7':::: x..;.o ¡,.. ~ "- ."1.... ~-'-IJIIDn._~ '2 A .. GRANITE POINT AElD GP ADL 18142 Wen No. 37 ,LOWER KENAI SANDS PlATFORM ANNA ~ 1 ... I ' ~= LoIIr"I-;-.'-'.I¡¡ .... .~AfI. PKIt. 11IIII CINcI ... .- .... ,... ,... ....... 1D: .. CIIIngt Dr. JIIIl: · 11 000 : · 11500: ¡PBTD = 11575' 12000 . -1000 -500 30 40 o r 500 ~ -.e ~. 1 000 ~; 1500 ¡ 2000 ~ 2500 I 3000 I 3500 4000 . Ë ~ " 4500 ti.-.¡ , ' , · 1~ 5000 - 5500 -t "j · 'J 6000 ~ :\-\~ ... ~ ~ 6500 j ~-m 7000 I ~\-1~ 7500 -'I" 8000 8500 9000 9500 10000 ~ 1 1 0500 ~I .--- ') ) Anna Platform An 37 Temp Survey 5/31/03 MIT vs 11/23/01 MIT 50 60 70 80 TEMPERATURE(DEG F) 90 100 110 120 180 130 140 150 160 170 I ¿ i. I I -- ----.0 ~...,. '_ ~, -I /; \ \ \ -5/31/03 TEMP RIH, SI=12HRS -11/23/01 Temp RIH - 5/31/03 PRES RIH, SI=12HRS -CCL '_JPKR @ 9771 PERFORATIONS C-5 10714-10784 C-5 10798-10882 C-6 11076-11091 C-7 11154-11176 C-7 11225-11237 C-7 11307-11346 C-7 11380-11446 IBHP= 2077 PSI " ~ ~ II :!II !! ::10 " 1. ~ , . a 1\ !I n D o 500 1000 1500 2000 2500 PRESSURE(PS¡G) ~' An-37 Maximum Allowable Operating Pressure Grapt o 1,000 2,000 3,000 Pressure (PSI) 4,000 5,000 6,000 \ " Variable Definitions \ - - -RP -=-Re-selVoirPressure---- ---------~ '\ CYP = Casing Yield Pressure \ SF = Safety Factor (70% for working annulus; 45% for o~ter annuli) HP = Internal Fluid Hydraulic Pressure \ MASP = Maximum allowable surface working pressure \. ~~ Graphical calculation method Inside pressure potential == Outside pressure containment Therefore HP + MASP = RP + (CYP * SF) Rearranging MASP = RP + (CYP * SF) - HP ~ Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft _Prnnllrtinn r.vp rm 70% '\ \ \- " " \ \ 7,000 8,000 9,000 Run date 2/16/2005 10:23:44 AM Safe operati 19 ressures (suñace gauge) Production = 55, ,8 p i. @ 70% nominal casing yield Intermediate = SJ3 p " limited by fracture pressure at shoe Surface = 163 P ,i. liml d by fracture pressure at shoe Current Pre~§ine Ladh1g§ CSGPRESS2 = J CSGPRESS3 = 1350 CSGPr~ESS5 = 5 Casing Deta Is Liner Hanger = ~'#, internal ~'eld = N/A psi from 11641' to 11644' MD' Liner Reentry Jc nt = 5" #, intc-nal yield = N/A psi from 11637' to 11644' MD' Liner Casing =~' 18#, N-80 int~ °nal yield = 10140 psi from 10536' to 11644' MD' Liner Flcollar = ~'#. internal yie i = N/A psi from 11642' to 11644' MD' Liner Casing = e' 18#. N-80 inten al yield = 10140 psi from 11560' to 11644' MD' Liner Floatshoe : 5" #, internal yi~ d = N/A psi from 11642' to 11644' MD' Liner = 7.625" 3....#. S-95 internal ykld = 10900 psi from 9897' to 10687' MD' Production Casi g = 9.625" 53.5#, t-..-80 internal yield = 7927 psi from 6470' to 10150' I Production Stgc"'lIar = 9.625" #, inte 1al yield = N/A psi from 10147' to 10150' MD' Production casi g = 9.625" 53.5#, N-Q>O internal yield = 7927 psi from 3718' to 10150' I Production ShoE.. = 9.625" #. internal Y".ald = N/A psi from 10148' to 10150' MD' Intermediate Ca ~ing = 13,375" 68#, N-~ internal yield = 5020 psi from 40' to 3522' MC Intermediate Sh...e = 13.375" #, internal Jield = N/A psi from 3520' to 3522' MD' Surface Casing : 20" 133#, X-56 internal field = 2125 psi from 42' to 615' MD' Surface Shoe = 20" #, internal yield = N/AJsi from 613' to 615' MD' Casing Para lleters J Assumption Production casi~ yield @ 70% of nominal w fluid weight of 0.433 #/ft Intermediate cas 'ng yield @ 45% of nominal Ih fluid weight of 0.433 #/ft Surface casing ~~éld @ 45% of nominal with fl Fracture gradier: = 0.7 #/ft API : 5073320 ~9400 Permit: 187109' Workbook: An-17 Casing Pressure Analysis @70 pe ----.........-_~~~u.-r>_........-........,_. \ '0 o~-. '__.... ,~ (:~ j ~, t ) ) .. ..-.... ,"-', NOTE TO FILE In Re: Anna 37 (18742 #37). II PTD (187-109) ,~Q~;t\~\ Unocal has applied to convert this production well to an injector. Since the well does not have a packer in it. Mj demonstration m us1 be by other means. The welt was drilled beginning in late 1987 and was completed in March. 1988. There is very little information available in the AOGCC wen file. Like wells -38 and -36, it does not appear that any of the original pel1orations have been altered since the original completion. Some of the origJnal zonas have been re-perfed and additional perforations have been added, but aU are below the top of the original perfs. Unocal has provided a copy of the eBl run March 6. 1988. A copy of the logJs not available in the AOGCC well files. Passes for the 7-5/8" liner and 511 liner are presented. A clear cement top is shown at 10940' in the 5" liner, Bond quality looks very good from 10940' to TD. From the 7 _5/aJJ shoe at 10687' to 10940', bond quality is very poor, The d rUling record indlcates that Amoco became stuck twice in that interval and lost BHAs each time. There are two perforated zones in this interval. The VDL presentation shows that there Is likely a mlcroannulus {at best} in this interval. Bond interpretation In the liner lap from 1 0687t - 10440' is not possible due to the 2 strings of pipe present. Above the 5Ø liner top, both tool runs indicate the 7-5/8" lìner is well bonded. Given the excellent signal above the 5" liner top, 1t is likely that the lower portions of the 7-S/Bn liner are bonded as well. MI is ind ieated. Subject to Unocal complying with the requirements of the attached ~Procedures to Obtain Variances on Packerless Wells (version 4) February 9 2000"þ I recommend approval to convert Anna 37 (187-109) as proposed. ~ ?Yþu~ Tom Maunder \0/ - aè) , Petroleum Engineer ' ~ ÚIJ ¿,,¿, I'r #¿ ~~ ~1J1A\1JŒ (ll~ fÆ FRANK H. MURKOWSKI, GOVERNOR AIfASKA OIL AND GAS CONSERVATION COMMISSION November 16, 2004 333 w. -pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Larry Greenstein Production Technician UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: Granite Point State 18742 #32RD (Anna-32RD) Granite Point State 18742 #37 (Anna-37) PTD: 187-063 Sundry Application: 304-305 PTD: 168-036 Sundry Application: 304-306 PTD: 188-034 Sundry Application: 304-307 PTD: 167-014 Sunòry App~1cation: 304-318 ( PTD: 187-109 Sundry Application: 304-327 ) Granite Point State 18742 #25 (Anna-25) Granite Point State 18742 #38 (Anna-38) Granite Point State 18742 #5 (Anna-5) Dear Mr. Greenstein: We are returning, without approval, the Applications for Sundry Approval (Form 403) relating to the above-referenced wells, because the relief you request needs to be sought through a different procedure. AIO 6 regulates injection activities on Anna and Bruce Platforms in the Northern Portion of Granite Point Field. When an injection well exhibits an integrity loss, the injection order requires that the Commission þe notified and that the Operator submit a plan for corrective action. Corrective action for purposes of an integrity loss means proposing to accomplish the physical well work necessary to repair the integrity loss. A corrective action plan should be submitted as an attachment to Form 403 per usual practice. If it is proposed to keep a well in operation without accomplishing a repair that would restore complete integrity, a request for Administrative Relief ("AR") in accord with Rule 9 of AIO 6 should be submitted. If you desire to request AR, your application should be similar to the attachment submitted with the sundry, however it should also include an evaluation/verification of the remaining barrier(s) that serve to confine injection fluids to the wellbore, SCANNEC NOV 2 4: 2004 consideration of trapped pressures and the consequence thereof in any wellbore "space" and an explanation of the management decision not to repair the well. F or these particular wells, it is acknowledged that none of the wells are equipped with packers, ordinarily a standard piece of completion equipment for injection wells. Injection was previously authorized for 4 of these wells (Anna-5 is a new application) after a review of the wells' construction and demonstration of integrity via temperature logs and step rate injection tests according to a procedure entitled, "Procedures to Obtain Variances on Packerless Wells (version 4) dated February 9, 2000". This procedure was cooperatively developed by Unocal and the Commission in accord with 20 AAC 25.450 (a), that allows the Commission to authorize less stringent well operating and construction requirements where injection does not occur into, through or above fresh water. All aquifers within 'l4 mile of Granite Point Field are exempt according to 40 CFR 147.102 (b)(2). Should you have any questions on this process, please contact Jim Regg at 793-1236 or Tom Maunder at 793-1250. Q:.' ~ian "- BY ORDER OF THE COMMISSION DATED this Œday of November, 2004 Encl. Unocal Alaska Union Oil Company of California 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7661; Fax (907) 263-7847 UNOCAL8 Larry P. Greenstein Prodction Technician RECEIVED Date: August 17 A~'t 3 2004 Ataska ou & Gas Cons. Commission State of AräskaAnchorage Alaska Oil and Gas Conservation Commission 333 W. ih Ave., Suite #100 Anchorage, AK 99501-3539 Attn: Tom Maunder Re: Granite Point Field An-37 Water Injector Request for Continuation of Variance Dear Mr. Maunder, This letter is to request a continuation of the MIT variance for the Anna Platform An-37 water injector. (Permit # 1871090 API # 50-733-20394-00). This well has tubing / casing communication and has been injecting with a variance since June 2001, although recently the well has been mostly shut-in. The temperature survey run on 5/31/2003 matches the last survey run on 11/23/2001 in character showing no cooling anomalies above the packer. This indicates that injection is occurring only into the Tyonek C-Sands. I n support of this request, the temperature survey comparison plot and 10-403 sundry have been attached. Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7661 or Hal Martin at 263-7675. Si~n.cere.IY.. P~ .4,. /).,. .. +... '.- /71 ~- .' /1 ,1M~)~ j 0 < - ua Larry P. Greenstein cc: Dave Cole Hal Martin MIT book Well File ,--"'~._;~' 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: RE('L""1:,r-'1 AU ~'7:, ?nnA . '" " ",o)~IQn Perforate 0 MD'túJJ. UAirfnfHàf![J\spo~.'LI Stimulate 0 Tim~. ~nçhOraQ'ther0 Re-enter Suspended Well 0 VARIANCE 5. Permit to Drill Number: Abandon 0 Suspend 0 Alter casingD Repair well 0 Change approved programD Pull Tubing 0 2. Operator Name: UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 11. Total Depth MD (ft): 11741' Total Depth TVD (ft): 1 0899' Exploratory 0 Service 0 6. Number: \ -733-20394-00 9. Well Name and Number: (y Anna - 37 'YJ~$\Q\. ""J.. ~ /1" ¡ 10. Field/Pools(s): l ~ V Middle Kenai 'C' Sand PRESENT WELL CONDITION SUMM Y /\ " \ v Effective Depth MD (ft): Effective DePth, D (ft): PIUØ...~ (~~,_a~1: ~ ~nk (measured): 11575' 10737' \ noJe \:\ \J~\ \ none Size MD J.) TVD \\ \1' Collapse 20.'33# 615' ^\ \') \ Y~°rÿ\ 1500 psi 133/8" 68# N-80 ~. ~. 'f\ w 10$ ~o~! 2260 psi 9 5/8" 53.5# N-80 10 \ \ \ :89' , 0 psi 6620 psi 7 5/8" 39# S-95 fJ 97:' - 1 068\" ~ 915. .7' - '/"¥' f\ \:Y0900 psi 9980 psi :1 40' -11644' 96~1(~44' \ \ 10140 psi 10490 psi Perforation Depth TVD ( T . g Size: \\~ing Grade\ Tubing MD (ft): 9893'-9956',9965'-10047', ng string 31/2./2.7/8" () \ \.2# L-80 I 6.4# N-80 9748' 19770'-10898' i~HEm~:: :~~;~:::~" hortstring3t/2" Y:~\ 92#L~0 9739' Development 0 0 3. Address: P.O. BOX 196247 ANCHORAGE, AK 99519 Stratigraphic 7. KB Elevation (ft): 105' 8. Property Designation: Granite Point 18742 Casing Length Structural 615' Conductor Surface 3522' Intermediate 10150' Production 790' Liner 1204' Perforation Depth MD (ft): 10714'-10784',10798'-10882', 11076'-11091', 11154'-11176', 11225'-11237', 11307'-11346', 11380'-11446' Packers and SSSV Type: Packers and SSSV MD (ft): 12. Attachments: Detailed Operations Program 14. Estimated Date for 0 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Service 0 Date: Oil 0 WAG 0 Gas 0 GINJ 0 Plugged WINJ 0 0 Abandoned 0 0 Commencing Operations: 16. Verbal Approval: NIA WDSPL Commission Representative: 17. I hereby certify that the foreg . g is true and correct to the best of my knowledge. Contact p~inted Name ~ Larry P'.~ d Title Production Technician SIgnature ~1 ~ W' -&!-one ~:6=~'SSION USE ONLY Date Larry P. Greenstein @ 263-7661 8/17/2004 Other: Notify Commission so that a representative may witness Sundry Number: ,30-,/ -<3;¿ 7 Plug Integrity BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 RBDMS 8Fl NOV 2 2 2D04 ORIGINAL Approved by: COMMISSIONER BY ORDER OF THE COMMISSION Date: Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE Submit in Duplicate 1 0500 . . 11000 : . . 11500 : : I~B~D.= 1.15:5' - 12000 "\ -1000 ',. .. >¡, 30 40 O~ 500 ~ 1000 ~ 1500 I 2000 - 2500 3000 3500 4000 4500 5000 - 6500 7000 7500 8000 8500 9000 9500 10000 Anna Platform An 37 Temp Survey 5/31/03 MIT vs 11/23/01 MIT TEMPERA TURE(DEG F) 50 60 70 80 90 100 110 120 130 140 150 160 170 180 . ¿-~ . ~ ¿ -5/31/03 TEMP RIH, SI=12HRS -11/23/01 Temp RIH -5/31/03 PRES RIH, SI=12HRS -CCL _JPKR @ 9771 PERFORATIONS C-5 10714-10784 C-5 10798-10882 C-6 11076-11091 C-7 11154-11176 C-7 11225-11237 C-7 11307-11346 C-7 11380-11446 iBHP= 2077 PSI .. .. . . .. .. .I....a. .. .. .. . .. . . . I .. .. .. I a -500 0 500 1000 PRESSURE(PSIG) 2000 2500 1500 Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harfisonb(~unocal.com UNOCAL Beverly Harrison Business Ventures Assistant 6/17/2003 To: AOGCC Lisa Weepie 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL - ~:.,INTERV~AE..',,~.~ 't:;;.'~i~iNE;'.'i .:FILM? ~CDi' ..... COMPLETION RECORD- 2.5" HSD A-15RD POWER JET 2506 HMX 5INCH 5/1/2003 11750-12550 2 1 1 AN-13RD2 RST SIGMA MODE 5INCH 5/22/2003 3400-4650 2 1 1 AN-19 RST SIGMA MODE 5 INCH 5/22/2003 3400-4650 2 1 1 AN-37 EST SIGMA MODE 5INCH 5/22/2003 3100-4250 2 1 1 COMPLETION RECORD-2.5" HSD G-12RD3 POWERJET6SPF 5 INCH 5/10/2003 12400-13610 2 1 1 2 1/2" HSD PWER JET 2506, HMX 3 1/2" ~GRINER-1 HALLIBURTON PLUG 5INCH 4/19/2003 250-1780 1 1 1 GRINER-1 CEMENT MAP 4/8/2002 0 0 1 TEMPERATURE SURVEY-CEMENT TOP KGSF-3 IDENTIFICATION PBMS 2 INCH 6/4/2003 3500-7020 1 1 1 COMPLETION REPORT- 2.5" HSD M-5 POWERJET, 6SPF 5INCH 4/16/2003 3600-3900 2 1.56"1606 HMX, TUBING PUNCHER /SRU223-28 COMPJETION RECORD 5INCH 5/25/2003 1580-5606 1 1 x 3.5 HALLIBURTON CAST IRON PLUG SRU223-28 CEMENTDUMP BAILER 5INCH 5/24/2003 1662-5665 1 1 1 Please acknowledge receipt by signing and returning one-copy of this transmittal or FAX to (907) 263-7828. Received By."~ 7%~? 0 ,,~'_~' ,-Ql;~2-,t~, ./y'x, Date: ,]n,,I '7.,,', '""'""~ ............... ~..t~.~'.~ ~:,,.~,,,~ ,'.?.]~,~') JAM. 1.2003 ?:31AM M0.073 P.8/8 Monthly InJactor Variance AN 87.42 Dec 2002 5G?.~8~03~t00 ANNA PLATFORM 111/2003 D~te Mrs On Volume Injected TBG Prmss 9.GJs CSG Press 13,,~76 C~g Press C;omment~__ 12/1/2002 0 0 0 0 372 12/2/~n~ ......... 0 O 0 .0 369 ........ 12/3/2002 0 0 0 0 370 12/4/2002 0 0 0 0 3?0 _ .......... ~15/2002 0 0 0 0 370 _ 12~nn; 0 ..... 0 0 0 - 369 12/7121}02 0 0 0 0 370 12/8/2002 0 '0 0 0 369 __ 12/9/2002 0 0 0 0 372 12/10/2002 0 0 0 0 36? .., 12/1112002 0 0 0 0 12/12/2002 0 0 0 0 370 12/1:372002 ....... 0 0 0 0 ..... 36~) _ 12114/2002 0 0 0 0 369 12/16~002 0 0 0 0 36,7=. 12/.'1.7, ,/20p,2 0..... 0 0 o, _ aSS _ 12/1812002 0 0 0 0 387 t2/19/2002 0 0 0 0 36~l 12/20/2002. --- O' O 0 0 367 12/21/2002 0 0 0 ' 0 367 12~/~002 0 0 0 0 867 T2/;3/2002 0 0 0 0 12/24/2002 ...... 0 0 0 - 0 36~ .... 12125/2002 0 0 0 0 367 12/26/2002 0 0..... 0 0 367 1212712002 0 0 0 0 367 12/26/2002 "-0 0 0 0 367 'i'2~2912002 0 '0 0 0 367 12/30/2002 0 0 0 0 :369 121:31/2002 .... 0 0 · ~GANNED ~AR 1 0 2003 ~OV. ?.~00~ ?:~B~M ~0.?~ P.g×~ ---' Date Hfs On Vamme In,cad TGG ?rill ~___~_~._ CS6 Prlli J3.376 ~g K[~ Commen~ 91112~ 0 - O O O 375. 91~2~2 O 0 O O 3?8 91312002 o 0 0 ~ 6~4t~002 - 0' -O 0 0 3?6 -" 01~2002 0 0 0 0 3?5 ~d/2OO2 O O 0" Q .376 ~002 O O '"b 0 373 61~12002 0 O O 0 373 9~12~2 O ' O O ..0- 9110~2 O 0 0 0 372 61~312002 0 0 0 O 372 ' 6114/~ 0 0 0 0 370 9115~=~n~ 0 O 0 O 370 _ 9116!20~? 0 0 0 O 373 911 ~/~ 0 0 0 O 370 611W2002 0 0 ..... 0 0 373 911g!2Pn~ O O O 0 370 912~2002 b ~ O 0 370 _ 912112002 0 0 0 0 9122/~002 0 0" o 0 367 ~123120~2 ' .,~ 0 O 0 370 _ 612~12~2 ~ 0 O 0 370 Ol~l~O-2 0 O o ' 0 9/2612002 0 0 O' 0 370 9/~12002 -' 0 0 0 0 370 91~6120D2 0 0 0 - o 37Q 91291~2 0 0 0 0 ' 370 _ -' ~13012~. O o o 0 372 SEP. 1,2002 6:43AM M0.431 P.?/9 Tbg ........................... ,,,,.,, I ,.o,,, I .,,,,.o ,,,,,,,rm ~onthly Inje~tpr_V_arian~ AN 37-42l Aug I 200.2,_.1' 5,07332F_+11 ANNA PI,,ATFORN 9/902 Volu~;' Tla, G 9,625 CS$ -- Date Hr~ On Injected ~ ~ 13.375 ca~ Pre~ Commen'cs 8/~2'bo2 o o o 8/2/2002 0 0 0 0 370 813/2002 0 0 0 0 370 8/4/2002 0 0 0 0 370 61512002 0 0 0 ...... 0 ..... 370 8/612002 0 0 0 0 370 B/712002 0 0 0 0 365 818/2002 0 0 0 0 365 ..... 819/2002 0 0 0 0 367 8110/2002 0 0 0 0 ;366 0/11/2002 0 "0 "' 0 0 811 P../2002 0 ............. '0 0 0 367 8113/2002 0 0 0 0 367 8114/2002 0 0 0 0 ~67 8115/2002 0 0 0 0 370 8~/,'16/2002 0 0 0 0 370 8117/2002 0 0 0 0 373 811612002 0 O 0 0 372 81191200~ .... 0 0 0 0 370 8/2012002 O 0 0 0 367 8/2112002 0 0 0 0 369 8/22/2002 0 0 0 0 3,70 '- ~23/2002 0 0 0 0 373 8/24/2002 0 0 0 0 372 8/25/2002 0 0 0 0 370 ~;~6/2002 0 0 0 0 ~75 8/2712002 0 0 0 0 375 812812D02 0 0 0 .......... '0" ........ 3~0 8/29/2002 0 0 0 0 375 613012002 O 0 0 0 3~5 8131/2002 ...... O' ' 0 0 0 375 ~ANNEP NiAR 1 0 2003 N l'bg Report Name Strin~l Month Year APl No Platform Date Created MontM¥ InjectorVadanc~ AN 3742 Jul 2~D2 5.07332E+.'i,,,,1 ANNA PLATFORM Volume TBG 9.625 CSG Date Hfs On Injected Press Press 13.37'5 Csj~[ Press Com..merits 71t/2002 0 0 0 0 348 7/2?2002 0 0 0 ~'" 34,5 7/3/2002 0 0 0 0 345 714/2002 0 0* 0 0 345 ?;~/2oo2 o o o o 345 7/~2oo2 %" o o o ~o' 7/7/2002 0 0 0 0 345 718/2002 0 0 0 0 347 7~9~2oo2 ' 7110/2002 0 0 0 0 344 7'!11/2002 0 0 0 0 342 7112/2002 0 0 0 0 341 7113/2002 0 O 0 0 34t 7114/2002 0 0 0 O' 348 71t 5/2002 0 0 0 0 355 7116/2002 0 7/17/'2002 0 0 0 0 355 7i~8t2002 O 0 0 0 355 7/'1g/2002 O 0 0 O 3~,~ 7120t2002 0 0 0 - 'O 355 7~'2112002 O 0 0 0 355 7.~22K2002 (} 0 0 0 353 7/23/2002 0 0 0 O 355 7.~24/2002 0 0 0 0 358 7/25/2002 0 0 0 0 358 7/26/2002 0 0 0 0 358 7/27/2002 0 0 0 0 363 7/28/2002 0 0 "O 0 364 7/29/2002 0 0 0 0 365 7130/2002 0 0 0 ~)" 36~ 7/3'r/2002 0 0 O 0 365 ~G~NNED ~AR ~ 0 2003 RECEIVED AUG 0 I Z00Z MAY. 1. ~00~ 9: 59AM NO. 806 P. ?×8 Report Name Tbg String Time Period Date Created Waterflood_!nject0'~'W~ll S~tus AN 37.42 Last Month ,611102 Outer Csg Length Volume Tbg Pree$ iC~g Press Pre;; Date (hours) (bpd) (psi) (psi) (psi) 4/30/200~ ..... 0 0 0 0 ~ 1 ~ 4,/29/2002 0 0 0 ' 0 323 412812002 ...........~ .......... 0 ........ 0 0 0 322 4127/2002 0 0 0 0 322 412~/2002 0 0 0 0 322 4125/2002 ......... . 0 .... ~. 0 0 0 ~ 320 ~.-: ...... 4/24/2002 ,0 0 0 0 ..320_,_ 412312002 0 0 0 0 320 4/22/2002 0 0 0 0 323 4/21/2002 0 0 0 0 323 4/20/2002 0 0 0 0 327 411912002 0 0 0 0 32'7 4/18/2002 0 0 0 0 326 4/17,/,2, ,0.0,,2 .... 0 0 0 0 323 4/16/2002 0 0 0 0 322 4/15/2002 0 0 0 0 322 _4/.!4/2 02 ........... 0 0 0 0 3 .o 4/13/2002 0 0 0 0 315' 4/12/2002 0 0 0 0 316 4/11/2002 0 0 0 0 311 4/10/2002 0 0 0 O' 308 419/2002 0 0 0 0 295 4/8/2002 10 218 0 100 286 4/7/2002 24 219 3415 3415 290 41612002 24 199 3325 3325 295 4/512002 24 220 3320 3320 290 4/4/2002 24 252 3260 3260 295 4/3/2002 24 246 3455 3455 '.. ~9_~' _--_~ 4/2/2002 24 250 3420 3420 5,55 4/112002 24 265 3405 3405 300~ End of Report 5CANNED UAR 1 0 21103 APR~ 1.~00~ 8:31AM M0.659 P.3/8 Report Name String._. Month Y, ar APl No Platform Date created Monthly injector Varianc~ AN 37-421 Mar 2002 5,07332E+1i ANNA PLATFORMI 411102 ........ Volume TBG 9.~ GSG Date Hm On Inje=ted , Press Press 13,375 csg Press i Comments 3/112002 24 286 3402 3350 0 3/2/2002 ......... 24 236 34b'5 3350 0 ............ 3i3/2002 24 293' 3272 3250 0 3/412002 .......24 308 33~0 3300 0 31§12002 24 304 3315 3310 0 3/6/2002 '" 24 301 '" 3323 3300 0 .... 3/7/2002 .... 24 ~ 303 '3'~'31 .3330 0 318/2002 24 ........ 309 3331 3330 Q 3/9/2002 22 288 3319 3310 0 311012002 24- 282 3209 3200 0 '- 3ll 1,~,2002 24 ..... 3,82 3209 3200 0 3112/2002 24 0 3 50 0 3113/2002 24 0 0 0 0 3(14/2002 24 " 6D 2320 '" 2400 0 3/15/2002 .... 24 219 2516 ...... 2500 3/1612002 24- ....22_3 3434 3425 0 3/17/2002 24 246 ~ 3273 3300 0 3/18'/20'0,2 24 290" 3330 3330 3/1912002 24 271 3370 3370 .... 0 31~_0)2'1~02 24 272 .......... i'.3410 3410. 0 ., 3)'2i i2~)',02 24 273 3435 3435 0 3122/2002 24 273 ..... 3_450 3450 .... . 0 3/23/2002 24 264 3405 3405 0 ..... 3/24/2002 .... 24 ' 264 3415 - 3415 ........ 0 .... 312512002 24 262 2850 2850 0 312612002 24 ..... 233 3364 3350 0 3/27~'2'd02 . 24 260 3414 3400 0 3/2812002 ...... '2'4 261 3438 ' 3430 O' __ -- 3/2912002 24 262 3445 3~4.40 0 313012002 24 ..... 264 3459 3450 0 313112002 24 2§1 3469 3450 0 En~l ef Repon GANNED 1 0 JUN. 2.2002 G:20~M ~Histarica! Data >Wells ~dltatus (daily info) ~,Wuterlllood Irljeclom --' ..... Select Time Select Tbg lAN 37-42 ~ Period: String: .- Report Name Tbg String Time Period Waterflood Injector Well Status AN 37-42 Last Month Length Volume Tbg Press csg Press Oete (hours) (bpd) (psi) (psi) 5/[/QZ 0 0 0 0 S/3I./02 O 0 0 0 s/~o/o2 o o o o 5/29/02 0 0 0 O 5/28/Q~ 0 0 o tI ~;/Z7/02 0 0 0 0 5/26/02 0 0 0 0 5/25102 0 0 0 0 5/2~tf02 0 0 0 0 5/23/02 0 0 0 0 5/22/02 0 o 0 o s/211o2 0 0 0 Q 5120102 0 0 0 0 S/19/02 0 0 0 0 S/~8/02 0 0 0 0 5t17/0Z 0 0 0 0 ~/16/o2 0 o 0 o 5115102 0 0 0 0 ~/14/02 0 0 0 0 51131(}2 0 0 0 0 5/~2/02 0 0 0 O 5/1 tl02 0 0 o O 5110102 0 0 0 0 sRto2 o o o o 518/02 0 0 0 0 5/?/02 0 0 0 0 516102 0 0 0 0 SI5/02 0 0 0 0 ~/4/02 0 0 0 0 S/3/02 0 0 0 0 I. Lasi Uont~ Date Created 612102 Ooter Csg Press (psi) 325 325 320 320 3.14 317 316 295 278 270 264 27O 275 Comments RECEIVED JUN O AlaskaOJt & Gas Co~s. (:~miss~Jr~ End of Report ht~:/Jcodiak,anchortown.unocal,comJda/templates/tabular.asp 6/2~2002 Unocal Corporation Alaska Business Unit 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL ) January 12, 2002 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Re: ANNA-37 Variance Request Dear Tom: Unocal is requesting a 2-year variance for ANNA-37 (Permit# 87-109). The plan is to rerun the temperature survey every two years, report the daily dates/pressures monthly to the AOGCC and monitor the rates/pressures daily using Unocal's web-enabled surveillance system. The attached baseline and follow-up temperature surveys show no anomalies indicating injection is occuring anywhere except into the Tyonek C-Sands. Please review the attached data and approve the variance. If you have any questions, please call me at 263-7830 or email me at ruffc@unocal.com. Sincerely, Senior Reservoir Engineer Cook Inlet Waterflood Management \XAk-Anchorage\GroupsXAOGCC\CorrespondencesXAN-37 2002-01-11 Variance cover letter.doc Jeff Dolan STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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: X Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Development: 105' KB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Granite Point 18742 P.O. BOX 196247 ANCHORAGE, AK 99519 Service: X Middle Ground Shoals 4. Location of well at surface 8. Well number Leg 2, Slot 8, 787' FNL, 605' FEL, Sec. 12, T10N, R12W, SM Anna-37 At top of productive interval 9. Permit number 359' FNL, 1697' FEE Sec. 7, T10N, R11W, SM 87-109 At effective depth 10. APl number 50- 733-20394-00 At total depth 11. Field/Pool 512' FNL, 1597' FEL, Sec. 7, T10N, R11W, S.M. Middle Kenai "C" Sands 12. Present well condition summary Total depth: measured 11,741' feet Plugs (measured) true vertical 10,899' feet Effective depth: measured 11,575' feet Junk (measured) true vertical 10,737' feet Casing Length Size Cemented Measured depth True vertical depth Structural 615' 20" 1308 sx 615' 615' Conductor Surfaoe 3522' 13-3/8" 2,543 sx 3522 3389 Intermediate 10,150' 9-5/8" 1250 sx 10,150 9389 Production 790 7-5/8" 300 sx 9,897 10,687 9157 9866 Liner 1204 7" 768 sx 10,440 11,644 9651 10744 Perforation depth: measured See Attachment true vertical See Attachment Tubing (size, grade, and measured depth) Long String 3-1/2", 9.2#, L-80, Buttress @ 9748' & 2-7/8", 6.4#, N-80, Buttress f/9770' to 10,898' Short String 3-1/2", 9.2#, L-80, Buttress @ 9739' Packers and SSSV (type and measured depth) 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ., ..... Title: Senior Reservoir Engineer Date: 1/8/2002 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No~.~,,.. ,-,, ,~ ~.,, · · Plug integrity. BOP Test Location clearance ........ .. ~,~ Mechanical Integrity Test~"~, Subsequent fo rm requi red 10- ~_.~l~t .~1~~~~[~ ~t,~ ~-.~.~ ' Commissioner Date Approved by order of the Commissioner ¥~A.~,~ , · Form 10-403 Rev 06/15/88 OR !GINAL SUBMIT IN TRIPLICATE Anna 37 Perforations MD TVD Subsea Zone Top Btm Top Btm Top Btm Amt Comments C-5 10,714' 10,784' 9,893' 9,956' -9,788' -9,851' 10,798' 10,882' 9,965' 10,047' -9,860' -9,942' C-6 11,076' 11,091' 10,219' 10,238' -10,114' -10,133' C-7 11,154' 11,176' 10,292' 10,311' -10,187' -10,206' 11,225' 11,237' 10,356' 10,365' -10,251' -10,260' 11,307' 11,346' 10,429' 10,466' -10,324' -10,361' 11,380' 11,446' 10,503' 10,558' -10,398' -10,453' 70' 84' 15' 22' 12' 39' 66' 0 0~ 500' 1,000' 1,500' 2,000' 2,500' 3,000' 3,500' 4rO00~ 4,500' 5,000' 5,500' 6,000' 6,500' 7,000' 7,500' 8,000' 8.500' 9,000' 9,500' i0,000' 10,500' i 1,000' 11 500' Anna An-37 Comparison Temperature Su~eys 10127/00 vs 11/23/01 20 40 60 80 100 120 140 160 180 200 1/23/01 Temp Survey GRANITE POINT FIELD GP ADL 18742 Well No. ~7 ,LOWER KENN SANDS PLATFORM ANNA t2 7.~' ~ · 2 ?/e" B~ X-O j IMINI ~ 7-Q5-,~ 223 8QPD X 74, BIIPO X le IdCl~ 11-II1.,.47 12-17-87 12-17-87 02-14-4B 03-10-08 t0711-107~q ~ 11~07-11341' 113e0-11444' 10440-T0 11844' 113 11741' UNOCAL ) APl #733-20394-00 Granite Point Field Well # An-37 Slickline Proposal Revised 10/20/00 Rev #1 Assembled by Steve Tyler Objectives: Wireline Problems: Tubing Size: Elevations Minimum I.D. Max Deviation: Perforations: 1 Qualify wellbore integrity, with temp surveys, to convert to an active injector. Gauge tbg, Tag Fill. Run Temperature Survey. Place well on Injection for 1 month. Re-run Temp Survey LS 3-1/2", 9.2#, N-80, Buttress Surf. to 2-7/8", 6.4#, N-80, Buttress 9748' to SS 3-1/2", 9.2#, N-80, Buttress Surf. to 2-3/8", 4.6#, N-80, Buttress 9738' to 9748' 10,699' 9738' 9745' Kobe Cavity 9748'to 9770' Cuttbg 10,699' Kobe Cavity 2.687" 9768' 3-1/2" x 2-7/8" XO 2.441" 9770' Max 31.02° @ 8700' Zone Top Btm Amt C-5 C-6 C-7 10,714' 10,784' 10' 10,798' 10,882' 20' 20' 11,076' 11,091' 30' 65' 11,154' 11,176' 94' 11,225' 11,237' 70' 11,307' 11,346' 15' 11,380' 11,446' 15' Brief History or Discussion · An-37 Temp Survey Procedure10-20-00 rev 1 .doc 10/19/00 Slickline Procedure An-37 I. Well Preparation [Prior to Slickline Work] 1. Circulate pump from well. I1. Slickline Work [Gage tbg, Run Temp Survey] Hold safety meeting with production, and slickline personnel. NOTE: This is an H2S Facility. Ensure that lubricator can be bled off to facility system. . 2. Establish tag out procedure for wellhead valves while wireline is in the well. 3. Spot SCBA's for rig up/rig down operation. 4. Production will issue a "Safe Work" permit for Slickline work. Establish that well room is free of gas and H2S. Establish whom slickline personnel is to contact for pressure test and to operate wellhead valves. pump-in sub with a valve is required below the wireline BOP's. Open well room exterior door prior to breaking lubricator. RU slickline unit, BOP's and lubricator onto long string. Pressure test to 1500 psi. MU equalizing prong onto tool string. 8. RI and shear Kobe knock-out plugs in standing valve. POOH. 9. BO equalizing prong. MU pulling tool. RI and retrieve standing valve. 10. MU 2.25" gauge ring onto slickline tools string. 11. RI and tag fill ( Last tag was on 8/30/96 @ 11,282' ) [2.687" ID through Cavity @ 9748']. POOH. BO GR. 12. Set temperature survey tool and pressure/temp bomb up so the first data point starts in 30 minutes. The remaining data points are at 1 second and 1.75 second, on pressure/temp bomb, intervals. 13. Record time gages are started and the time slickline starts in the hole. (Keep time record within an accuracy of 5 seconds ) 14. MU Temperature probe onto wireline tool string. Wait till bombs are "awake". 15. RIH at 60' per min making 2 minute stops every even 1,000' to fill tagged depth [2.687" ID through cavity @ 9748']. Record time and depth at each stop. (Keep time record within an accuracy of 5 seconds ) 16. Wait 5 minutes at fill tagged depth. POH at 60 ft per min. making 2 minute stops every even 1,000'. (Keep time record within an accuracy of 5 seconds ) 17. Once out of hole down Icad data. Insure data is good prior to releasing Slickline. 18. RD Slickline. Put well on injection. . Note: a 6. 7. An-37 Temp Survey Procedure10-20-00 rev 1 .doc PAGE #2 8/4/99 III. lm . w 7~ . Slickline Work After One (1) Month of Injection [Gage tbg, Run Temp Survey] Take well off injection 12 hrs prior to rigging up slickline RU slickline unit, BOP's and lubricator onto long string. Pressure test to 1500 psi. Set temperature survey tool and pressure/temp bomb up so the first data point starts in 30 minutes. The remaining data points are at 1 second and 1.75 second, on pressure/temp bomb, intervals. Record time gages are started and the time slickline starts in the hole. (Keep time record within an accuracy of 5 seconds ) MU Temperature probe onto slickline tools string. Wait till bombs are "awake". RIH at 60' per min making 2 minute stops every even 1,000' to fill tagged depth [2.687" ID through cavity @ 9748']. Record time and depth at each stop. (Keep time record within an accuracy of 5 seconds ) Wait 5 minutes at tagged fill depth. POH at 60 ft per min. making 2 minute stops every even 1,000'. (Keep time record within an accuracy of 5 seconds ) Once out of hole down load data. Insure data is good prior to releasing Slickline. 9. RD Slickline. Put well on injection. An-37 Temp Survey Procedure10-20-00 rev 1 .doc PAGE #3 8/4/99 Ui.JCAL ALASKA RESOUR .,,=S WELL SERVICE REPORT Date: Wireline Company: Work Being Done: Present Operations: UNOCAL Supervisor: Wireline Unit Number: Zero Wireline at: Minimum Tubing ID: 3/29/01 Pollard Wireline Inc. Pull Stending Valve Complete D. Moultrie Anna Unit Tubing Hanger Well Number: Location: AFE# / Charge Code: Wireline Crew: Total Wireline Miles: Max Depth (KB): Well KB: Max Tool OD: An-37 Anna Dille¥/Tomlinson 3 9880' 34' 1.50" Time Operation Details 13:30 R/U on A-37 15:00 RIH w/Equalizing Prong to 9850', beat down, POOH 16:30 RIH w/Pulling Tool to 9850', POOH w/Valve 18:00 R/D, clean up area, stand-by for Chopper 20:30 Depad for OSK 21:00 Arrive at OSK ....... ..... Tool Cost: 5 of 12 hr min $625.00 3 add hrs $300.00 ,,, Work String Detail: RS, KJ, 10' Stem, OJ, SJ Description of any None tools or debris left in the hole: Brief Summary of Pull Standing Valve Total Work Comleted: Total Hours Worked 8 Total Tool Cost N/A Total Hour Cost $925.00 Well Downtime Hr. Ticket # '1 Daily Cost: $ P-564 925.00 Day # '1 Cumulative Cost: $ H2S PPM 925.00 Wire Test 23 Approved by: Code: U ,. CAL ALASKA RESOURL,.-'S WELL SERVICE REPORT Date: Wireline Company: Work Being Done: Present Operations: UNOCAL Supervisor: Wireline Unit Number: Zero Wireline at: Minimum Tubing ID: 11/23/01 Pollard Wireline Inc. Temp & Pressure Survey Done G. Brown Anna Unit Tubing Hanger 2.44" Well Number: Location: AFE# / Charge Code: Wireline Crew: Total Wireline Miles: Max Depth (KB): Well KB: Max Tool OD: An -37 Anna AFE # 143917 D. Pollard/Tomlinson/Kroto 8 11265' 36' 2.25" Time Operation Details 06:00 Catch Chopper to Anna 07:00 Had Orientation, started R/U 09:00 Had Pre-W/L safety meeting 10:00 RIH w/2.25" GR to 9827', set down, work tools, drop through to 11265' KB, POOH, had counter wheel problems, had to stop and fix 15:00 Set up Survey, RIH making stops every 100', going 60' a min 23:44 OOH, check data, data - good, Rig over to AN-38 Tool Cost: 3 man crew $2,080.00 6 add hrs $900.00 2.25" GR $50.00 Single Electric Gauge $650.00 Single Quick Temp Gauge $800.00 Work String Detail:i (1.5" TS) RS, K J, 10' Stem, K J, O J, Spangs Description of any NONE tools or debris left in the hole: Brief Summary of Did Temp & Pressure Survey using Quick Temp & Pressure Tools Total Work Comleted: Total Hours Worked Well Downtime Hr. Approved by: 18 Ticket # '1 Daily Cost: $ Glynn Brown Total Tool Cost $1,500.00 P-656 4,480.00 H2S PPM Total Hour Cost $ 2,980.00 Day # :1 1 Cumulative Cost:I $ 4,480.00 Wire Test Code: AFE # 143917 Pollard Wireline Inc. Survey Data Sheet Location Anna Well # AN-37 Date 11/23/01 Gauges On 15:50:07 Gauges Off 23:43:07 Bomb Serial # Depth KB Arrive Leave Duration Lub 16:07:00 16:17:00 10 min 1000' 16:34:26 16:36:26 2 min 2000' 16:52:50 16:54:50 2 min 3000' 17:11:28 17:13:28 2 min 4000' 17:30:15 17:32:15 2 min 5000' 17:49:15 17:51 '15 2 min 6000' 18:07:28 18:09:28 2 min 7000' 18:25:50 18:27:20 2 min 8000' 18:43:21 18:45:21 2 min 9000' 19:02:19 19:04:19 2 min 10000' 19:21:33 19:23:33 2 min 11000' 19:41:09 19:43:09 2 min 11250' 19:47:45 19:52:45 5 min 11000' 19:56:57 19:58:57 2 min 10000' 20:15:05 20:17:05 2 min 9000' 20:33:24 20:35:24 2 min 8000' 20:51 '10 20:53:10 2 min 7000' 21:09:40 21:11:40 2 min 6000' 21:28:13 21:30:13 2 min 5000' 21:46:40 21:48:40 2 min 4000' 22:05:13 22:07:13 2 min 3000' 22:23:02 22:25:02 2 min 2000' 22:41:07 22:43:07 2 min 1000' 22:58:59 23:00:59 2 min Lub 23:17:32 23:29:00 10 min Turn off Encoder at 23:44:20 STATE OF ALASKA ALASKA O' -AND GAS CONSERVATION .,OMMISSION APPLICATION FOR SUNDRY APPROVALS Ype of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair w~ll: Plugging: Time extension: Stimulate'i" Change approved program: Pull tubing: Variance:~ Perforate: Other: X 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address 5. Type of well: Development: X Exploratory: Stratigraphic: Service: P.O. BOX 196247 ANCHORAGE, AK 99519 4. Location of well at surface Leg 2, Slot 8, 787' FNL, 605' FEL, Sec. 12, T10N, R12W, At top of productive interval 359' FNL, 1697' FEL, Sec. 7, T10N, R1 lW, SM At effec~ve dep~ 512' FNL, 1597' FEL, Sec. 7, T10N, R11W, S.M. 6. Datum elevation (DF or KB) 105' KB MSL feet 7. Unit or Property name Granite Point 18742 Middle Ground Shoals 8. Well number Anna-37 9. Permit number 87-109 10. APl number 50- 733-20394-00 11. Field/Pool Middle Kenai "C" Sands 12. Present well condition summary Total depth: measured true vertical 11,741' feet Plugs (measured) 10,899' feet Effective depth: measured 11,575' feet Junk (measured) true vertical 10,737' feet DUPLICATE Casing Length Size Cemented Structural 615' 20" 1308 sx Conductor Surface 3522' 13-3/8" 2,543 sx ~ Intermediate 10,150' 9-5/8" 1250 sx Production 790 7-5/8" 300 sx Liner 1204 J ~ 768 sx Perforation depth: measured .... See Attachment Measured depth 615' 3522 10,150 9,897. 10,687 10,440 11,644 True ve~icaldepth 615' 3389 9389 9157 9866 9651 10744 true vertical See Attachment Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Long String 3-1/2", 9.2#, L-80, Buttress @ 9748' & 2-7/8", 6.4#, N-80, Buttress f/9770' to 10,898' Short String 3-1/2", 9.2#, L-80, Buttress @ 9739' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: Conversion to a Water Injector 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Name of approver Date approved Oil: Gas: Suspended: Service: 17. I hereby certi~/~ Signed: ~~the regoing i true and correct to the bestTitle:Of my~~,~./~¢,,,'~;v~,,~kn°wledge' . FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity .... .BOP Test Location clearance. Mechanical Integrity Test .~. Subsequent form required 10- ~1,-~ Approved by order of the Commissioner ' -' t . l:: _')t.;'r' ORIGINA-. Si£SN D Taylor Seamount Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Procedures to Obtain Variances on Packerless Wells (version 4) February_ 9, 2000 It is preferred that wells have been shut-in for an extended period of time. Injection fluid will normally be filtered Cook Inlet water at --55 deg F. 1. Do a base line temperature profile from'surface to top of peris. 2. Start injection - after 14 days, run a standard step-rate-test per SPE recommended procedure. Run test to maximum allowable pressure. Repeat step-rate-test after injection pressures have stabilized. 3. After 30 days of injection, run a temperature profile making stops as in the baseline survey (if appropriate) and hang recorder in well. Note: if the stops used in the baseline profile are not appropriate, make appropriate stops in this profile and use in all subsequent surveys in this well. 4. After 48 hours, retrieve recorder and run a temperature profile from the perfs to the surface using the appropriate stops. 5. After retrieving the recorder, run in hole with high speed recorder which was used for Step #1. 6. Compare the series of profiles to the baseline. 7. Evaluate all data from the temperature profiles and the step-rate-test to determine if the there are indications of leaking casing and or upward flow behind the casing. 8. If the conclusion is that there are no casing leaks above the zone and no upward flow behind the pipe, the well can be put back on injection. 9. Daily injection rates and tubing and surface casing pressures will be recorded daily and reported to the AOGCC monthly. 10. If injection rates or pressures or surface casing pressure indicate the possibility of a casing leak, the well will be immediately shut-in and the ^OGCC notified; future operations will then be as agreed. 11. The well will be tested every two years for mechanical integrity as in the above steps or by another procedure acceptable to the AOGCC. Zone C-5 MD Top Btm 10,714' 10,784' 10,798' 10,882' C-6 11,076' 11,091' C-7 11,154' 11,176' 11,225' 11,237' 11,307' 11,346' 11,380' 11,446' Anna 37 Perforations TVD Subsea Top Btm Top Btm 9,893' 9,956' -9,788' -9,851' 9,965' 10,047' -9,860' -9,942' Amt 70' 84' Comments 10,219' 10,238' -10,114' -10,133' 15' 10,292' 10,311' -10,187' -10,206' 10,356' 10,365' -10,251' -10,260' 10,429' 10,466' -10,324' -10,361' 10,503' 10,558' -10,398' -10,453' 22' 39' 66' ORANITE POINT FIELD OP ADL 18742 Well No. 37 ,LOWER KENAI SANDS PLATFORM ANNA I0~ I~-I~11. 11741' lid 108~' ~ 11575* Butt X-O g771' Irllld ~ 7~ 223 ~ X 74 ~ X lB ~ 11-18-87 11-1H7 12-17-~ 20". t33J~ 13 3/f'o 88~7 to 1Q~87' 11~,5-.11~7' 113O7-11344' 11380-11444' ISgTl) 11.~75' 19 11741' 10440 TO 11~4' . ^I'INA Platform Leg 2, Conductor 8 T)/onek Sands ~13.0- 615.0' SHE / J715.0- 3716.5' SICC0tI3R 7/.5 - ~b22.0' 13.g" OD ~.OOt/fl: N-JtO SUI~ C$ ~0.0 - ~22.0' ~OE AN $7-2 Granite Point Field APl 50-733-20394-00 ~... ADL 18742 Tbg,.,,d Flng Depth 3L40 FL ~ax. Dev. ~t Perfs. 28 Deg, 3~,4- X4' HANER CIY/Sp[~ DCB T~g I-tang~ 33.4- 34.4' HANG~ C~ Spld: DOB ~g Hanger 9807.5- 9906.9' HAN(;ER Baker 5,t4 - 10147.9' 9,ii25" OD 5,S,~/ft N-80 PROD CSi~ 10147,9 - 10150.0' SHE. 10440.0 - 104,12.6' 9906.9 - 10685,2 7,625" OD 59.00~/ft Soo--95 UNEIt 1~2..ti - 1~9J' REENflt? JOINr Tiel~ck Sleeve 10~,2- 10687.0' SHOE Baker 11~2.$- 1164.,~.9' FLOAT~JtOE ID6,9 - 11558.~' FLCOLLAR 10449.5-11642,3' 5,000" OB 18.00Jif[N-80 UNEtt 11575,0-11600,0' Fill 5/6/88, PBD Re~rted 11~.0-11741.0' ~ENT PLUC 9747.6 - 97703' RJJC Kobe Y DBL "8" Pump Cavi~ ~.4.- 9747.6' ~.500" OD 9.20t/ft li-80 ~1; LONC S1RI~ ~.4-,97,E7' ~.~"'OD 9.20J/fl. N-§O IBG SHORT SIRINg 97,~9.0- 9747.6' 2.b"/~" OD 4.60t/fl. N-ttO TBI; SHORT S'IRINC 97~7.7- 97~9,0' CR(i~ ~ 1/2" Btc x 2 ~747.6 - 9T/03' LJJC Kobe ~" "B" Pump Cov~ ~9770.3- 10704.,5' 2.875" O0 6,,lOt/fi N-~'IBC'LONg SlilNC cmo 2 2 1070~,5 - 10705.7' CROSSOVER 2 7/1~" 1070§,7 - 10706.7' PORTED NIPPLE Baker Ported Sub 07:]0.2 - 107~Z5' Baker Mech, F'idn9 Head 072,5 - 10898.5' PERFSUB ~kerb 5/8" PerL (;un KB ELD/: 105' 'PAD: 11575' JPumping Oil Well Spud On 11/1/87 TI): 11741' Last ~//0 4/23/88 · ANNA Platform llg2, Conductor 8 onek Sands 9807.5 - 9g06.9' HANG~ Baker 3:L4 - 101¢.g' 9,625" OD 53.50J/ft N-§O P~ CSC; 10147.g - 10150.0' SHOE 9~.9-10685.;? 1.625" OD ~.OOt/ft S~95 UNER 10685,2- 10687,0' SHOE Baker AN ~7-2 Gr<]nite Point Field APl 50-7~-20~94-00 Em PBTD: 11575' TO: 11741' ADL 1814.2 Tbg...~d Flng Depth b3,~ Ft, Max. Dev. ~,t Parrs. 28 Deg. 9747.6 - 9770,5' RJJC Kc~ 5"~ "B" Pump Cavit7 g757.7-g7~9.(~ CROSSOVER 51/2" Btc x 2 ~747.6- gnO.3' ~C Kobe }" "B" ~mp ~0.~-9~.~' cm~ 7/~" ~D ~: 7/~" ~c 10705.7 - 10706.7' PORED NIPPLE Baker Perm Sub 1070{,~- ~0705.7' c~osso~ ~ 7¢' ~tc x 2 7/~" ~ ~om.o-1071~.0' Pm 2HPF, ~/~/~ 10716.0 - 10784.0' P~FS C-5, Prod, ~PF, 68', B<]k~r 5 ;~/8" Tg~ (;un, 5/¢8 10728,0-107~).0' PBF'S 2HPF, 3/6/88 Pumping Oil Well Spud On 11/1/87 Last ~//0 4/23/88 ANNA Plcl~form Leg 2, Conductor 8 Txonek Sands 11556.9 - 11558.8' FLCO~ 11575.0 - 11600.0' Fill 5/6/88, PBD Reported 11600.0 - 11741.0' ®~ PLUG s,o 7' OD N- O UNto AN S/-2 Granite Point Field APl 50-733-20394-00 KB ELEV: 105' PBI'D: 11575' TD: 11141' .... ADL 18742 Tbg .ad Flng Depth ~5,40 Ft, · Max. Dev. At Perfs. 28 Deg. 10728,0-10730.0' PERFS 2HPF, 3/G/88 1078t0-10784.0' PERFS 2HPF, 3/6/88 10788,0-1088~.0' PERFS C-5, Prod, 4HPF, 84', Baker ~ ~/8" TCP Gun, 5/4/88 1~7~.0- lOaO' Pm ~HPF, 3/~/8~ 10730.2 - 107~2.5' Baker Mech. Fidn9 Head 107,]2.5 - 10898.5' PERF'SUB Baker ,~ 5/§" Perf. (;un 11225.0 - 112Y/.0' PERFS C-5, Prod, 4HPF, 12', Baker ,~ ~5/8" TCP Bun, 5/4./88 11307,0-lla4G, O' PERFS C-7, Prod, 4HPF, 3g', Baker 3 ~/8" TCP C, un, 3/14/8J 11,,z80.0- 1144~.0' PERFS C-7, Prod, 4HPF, G6', Baker 5 :~/8" I'CP gun, ~/14/81 Pumping Oil Well Spud On 11/1/87 Last ~//0 4/23/88 Anna 37 Perforations MD TVD Subsea Zone Top Btm Top Btm Top Btm C-5 10,397' 10,459' 9,297' 9,345' -9,170' -9,218' 10,483' 10,578' 9,369' 9,441' -9,242' -9,314' · Amt 62' 95' Comments C-6 10,663' 10,675' 9,513' 9,521' -9,386' -9,394' 12' C-7 10,918' 10,962' 9,715' 9,755' -9,588' -9,628' 11,013' 11,031' 9,796' 9,812' -9,669' -9,685' 44' 18' C-8 11,224' 11,262' 9,964' 9,994' -9,837' -9,867' 11,275' 11,295' 10,000' 10,014' -9,873' -9,887' 38' 20' Description Summary to Convert Anna Producers into Injectors Anna 21 · Gage Tbg. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 25 · Gage Tbg. · Run "Baseline" Temp Survey. · Place on injectiOn for 1 month. Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 26 · Gage Tbg. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 32 · Gage Tbg. · Cut Tbg to drop guns. · Gage ring tag guns. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 37 · Gage Tbg. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. Anna 38 · Gage Tbg. · Cut Tbg to drop guns. · Gage ring tag guns. · Run "Baseline" Temp Survey. · Place on injection for 1 month. · Run Temp survey. Compare to "Baseline" Temp Survey to pass MIT. AUC. 2 ~ ..... " Alaska O; & Cas C.~',;:~;. :',', ....... '~,'n.oo,or~i~-~; gnchoraqe i/! !i! iili .".!i / / 11/ 44-11 9 \ x,,, / / / / [ / / / : , ,' / f / / / , ;' : ! / / ! / ; · i / / ,. ~ ! i f ; i ~ i i i / ~ / i / / ,' / / , / .,' / i 31.-2 / / / :, / / / i / / / ,' / / / / 32 / ,./ / ; , / , / ; i / / / / / i / / / ; / i / / ., :,. .., : i I / // i i / / x ~ · ! ;' I z / / ,/ :- , , , ,. i ! i i / / / / ,' / / i // / iI // / · // 1/ i / / ./',,Ug _,.uuu ,,,. ;.. ~ ~ A. laska Gi & '..',b, as ,,..,ans. OcmmisJun Anchorafe STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Pull tubing: Alter casing: Repair x 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: 105' KB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Granite Pt. St. 18742 P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: X 4. Location of well at surface 8. Well number 834' FNL, 676' Fl=L, Sec. 12, T10N, R12W, SM An-37 At top of productive interval 9. Permit number/approval number 3121' FNL, 1283' FEL, Sec. 12, T10N, R12W, SM 87-109 At effective depth 10. APl number 50-733-20394-00 At total depth 11. Field/Pool 3447' FNL, 1870' FI=L, Sec. 1, T10N, R12W, S.M. Middle Kenai "C" sand 12. Present well condition summary Total depth: measu red 11,741' feet Plugs (measu red) true vertical 10,899' feet l=ffective depth: measured 11,575' feet Junk (measured) true vertical 10,737' feet Casing Length Size Cemented Measu red depth True vertical depth Structural Conductor 615' 20" 1308 sx 615' 615' Surface 3,522' 13-3/8" 2543 sx 3,522' 3,389' Intermediate 10,150' 9-5/8" 1250 sx 10,150' 9,389' Production 790' 7-5/8" 300 sx 9,897' - 10,687' 9,157 - 9,866' Liner 1204' 7" 768 sx 10,440- 11,644' 9,651 - 10,744' Perforation depth: measu red See attachment true vertical See attachment Tubing (size, grade, and measured depth) Long Stdng 3-1/2", 9.2#, L-80, Buttress @ 9748' & 2-7/8", 6.4#, N-80, Buttress f/9770' to 10,898' Short String 3-1/2", 9.2#, L-80, Buttress @ 9739' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measu red)6 ,,. P ECEIVED AUG 1 0 2001 Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data Anch0raae OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing PresstYre Prior to well operation 7 26 86 100 110 Subsequent to operation (.~ ~V'") - 396 3400 3455 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: , ,, Daily Report of Well Operations: Oil: Gas: Suspended: Service: x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Title: ¢ ~,~.~ -'" Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATl= ~ Zone C-5 Anna 37 Perforations MD TVD Subsea Top Btm Top Btm Top Btm 10,714' 10,784' 9,893' 9,956' -9,788' -9,851' 10,798' 10,882' 9,965' 10,047' -9,860' -9,942' C-6 11,076' 11,091' 10,219' 10,238' -10,114' -10,133' C-7 Amt 11,154' 11,176' 10,292' 10,311' -10,187' -10,206' 11,225' 11,237' 10,356' 10,365' -10,251' -10,260' 11,307' 11,346' 10,429' 10,466' -10,324' -10,361' 11,380' 11,446' 10,503' 10,558' -10,398' -10,453' Comments 70' 84' 15' 22' 12' 39' 66' 8/9/01 8:56 AM An-37 10-404.xls Attachment NOTE TO FILE In Re: Anna 37 (18742 #37)...PTD (187-109) Unocal has applied to convert this production well to an injector. Since the well does not have a packer in it, MI demonstration must be by other means. The well was drilled beginning in late 1987 and was completed in March, 1988. There is very little information available in the AOGCC well file. Like wells -38 and -36, it does not appear that any of the original perforations have been altered since the original completion. Some of the original zones have been re-peried and additional perforations have been added, but all are below the top of the original peris. Unocal has provided a copy of the CBL run March 6, 1988. A copy of the log is not available in the AOGCC well files. Passes for the 7-5/8" liner and 5" liner are presented. A clear cement top is shown at 10940' in the 5" liner. Bond quality looks very good from 10940' to TD. From the 7-5/8" shoe at 10687' to 10940', bond quality is very poor. The drilling record indicates that Amoco became stuck twice in that interval and lost BHAs each time. There are two perforated zones in this interval. The VDL presentation shows that there is likely a microannulus (at best) in this interval. Bond interpretation in the liner lap from 10687' - 10440' is not possible due to the 2 strings of pipe present. Above the 5" liner top, both tool runs indicate the 7-5/8" liner is well bonded. Given the excellent signal above the 5" liner top, it is likely that the lower portions of the 7-5/8" liner are bonded as well. MI is indicated. Subject to Unocal complying with the requirements of the attached "Procedures to Obtain Variances on Packerless Wells (version 4) February 9 2000", I recommend approval to convert Anna 37 (187-109)as proposed. Tom Maunder Petroleum Engineer :rG RELE.=E :~?_. LL DATA Liner: -ubin=: Hole Size Packer ~~' ~ T'~; Set at Y~CF~_NiC;T. iNTEGRXTI' - P.~JtT Annulus Press Test: lP ; 15 rain ; 30 rain . .w~--~CF3-N!CAL iNTEGRiTY - PART ~2 Cement Volumes :' g~mt. ,~ner ~:i:,~.~:~L ; ; . Theore:ical TOC Cement Bond Log (Yes or No) CBL Evaluation, zone above perfs 3" Production Log :. Type Evaluation CONCLUSIONS: Part fl: GRANITE POINT FIELD GP ADL 18742 Well No. :~7 ,LOWER KENAI SANDS PLATFORM ANNA ~)ud l)~ 11,,...01,,,..~7 ~ 1~ 1"101~ 111121. ~ I09' 11741' 115'J~ 13 3V8' Ill~ OlilnI_ iMM ~22' w23(w ~lI (Im~ e a/?, _s3.~,_cIMi 7 ~va"~_ 3If,-Llne. ~. 11~, Line' 1/2" .4BC,-MOD X 3 1/2' 8 IqD X-.O c. 2 a/a", 4~6L N-ao I~O PuP i~46. 7~ 223 ~ X 74 ggl~D X 9B ~ 11-18--47 11-1H7 12-17~ g~O7 lo 10M7' 11225-11237' 113O7-11344' 11380-11444' ~". ll~I line. 10440'1'0 11~t.4' FOLD HERE . GRANITE POINT COMPANY AMOCO PRODUCTION CO o 13 i- 3: 3> ~_88~ o > ~ ~ > ® The well name, location and borehole reference data were furnished by the customer. All interpretations are opinions based on inferences from electrical or other measuremen[s and we cannot, and do not guarantee the accuracy or correctness of any interpretations, and we shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, costs, damages or expenses incurred or sustained by anyone resulting from any interpretations made by any of our officers, agents or employees. These interpretations are also subject to Clause 4 of our General Terms and Conditions as set out in our current Price Schedule. Run NO. 4 Service Order I~1o. 240496 Drilling Fluid Level 0.0 F Salinity Rmf ~ BHT @ 16]. DEGF Rmc ~ BHT @ 161. DEGF Logging Speed 2000.0 F/HR Equipment Data Tool Number 1 Tool Number 2 CNC-A 1338 SLS-WA 633 SLC-MA 142 Tool Number 3 Tool Number 4 ~GC-JC 2523 Tool Number 5 ;AL-RA 1274 Tool Number 6 Tool Number 7 TOOl Number 8 Tool Number 9 Tool Number 10 Tool Number 11 Tool Number 12 , REMRRKS: TIED IHTB DIL RUH 11/18/87 TT~ (US 400.00 CCL -19.00 0,0 ~00.00 1.0000 100.00 II C~L (MV ) 0.0 CI~L (I~V 50.000 SO,O00 ) 100.00 I I V~L (US) ~00.00 1~00.0 CP 30.~; FILE 05-MAR-88 12':01 5"/100 ' 9900 9900 :1.0000 %0100 :%0~0 CP 30, ~E TT~ (US ) 400,00 200.00 1030 1040 S"/lO0' FILE 7 05-[4AR-88 16~32 ' CP 30.EE /"~'~E ? 05-MAR-88 16137 TTE (US 400.00 200.00 CCL C~L <NV -19.00 1,0000 0.0 50.000' OR (ORPI) C~L (NV O.O 100.00 50'~-~'-00 100,00 200.00 1200.0 SENSOR MEASURE POINT TO TOOL ZERO SRAT 8.2 FEET AMPL 8.2 FEET TT1 8.2 FEET C~L 8.2 FEET TT$ 8,2 FEET TT2 8,2 FEET TO 8,2 FEET TT4 8,2 FEET SLTT 8,2 FEET TT $,2 FEET GR 35.7 FEET SC~L 8,2 FEET NCNL 27.7 FEET FCHL 27,? FEET CCL 39,3 FEET TENS 8,2 FEET NOIS 8.2 FEET NRAT 27.? FEET PARAMETER~ HAME VALUE UNIT NAME VALUE UNIT ~HS CASE CSIZ 5.00000 IN FCH9 CSID BS 6.25000 IN CSTR 1500.00 PSIA CWEI 18.0000 L~/F COTS 100,000 SPFS R-H ~TF 189,000 US/F 9TM 56.0000 US/F DSIN 5 US DDEL 200 US PSNR 2.27500 DNCO 512 HATR SAND HC NMUD 8,40000 L~/G 400.00 200,00 CCL -19.00 1.0000 GR (GAPI) CgL (NV ) 0,0 50,000 __ CltL(HV ) ~9.009 100.00 ~00.00 YDL (US) lgO0.O CP 30.22 FILE 6 05-NAR-S8 16~34 I ' ! '"~i fi i i iii5''/100"~I il ! I I[ 10400 10500 ..~10 ~00 10600 -/~. 10700 11000 11100 L 11200 11300 11400 CP 30, ~ 11500 CC~ 1"1'2 S"/IO0' FILE OS-MAR-88 15~45 TTE (US ) 400.00 EO0.O0 CCL -19,00 1,0000 OR (OAPI) 9,9 190.00 . _ CBL (NV ) 0.0 SO.O00 __COg (NV ) $0.000 ~00,00 VDL (US ) 1200.0 SENSOR MEASURE POINT TO TOOL ZERO SRAT 8.~ FEET TT1 8.~ FEET TT3 8.E FEET TO 8.~ FEET SLTT 8,E FEET GR 35,2 FEET NCNL ~?,? FEET CCL 39,3 FEET MOlS 8,~ FEET AMPL 8,~ FEET COL 8,; FEET TT~ 8.~ FEET TT4 $.~ FEET TT $,2 FEET $CDL $.~ FEET FCML 27.7 FEET TENS $,~ FEET NEAT ~7.7 FEET PARAMETERS NAME VALUE UNIT NAME VALUE UNIT ~HS CASE CSIZ 5.00000 IH FCHD CSID ~S 6.~5000 IN CSTR 1500,00 PSIA CNEI 16,0000 COTS 100,000 SPFS R-H DTF 189,000 US/F DTM 56.0000 US/F DSIM 5 US DDEL ~00 US PSMR ~.27500 DHCD MATE SAND HC NMUD 8.40000 TTE (US ) -400.00 ~00.00 CCL COL (NV ) -19.00 1.0000 0.0 50.000 OR (GAPI) CBL (MV ) VOL (US ) 0.0 100,00 ~0,000 lO0.O0 ~00,00 1200,0 40,0 . O0 :~00 · O0 -19.00 1.0000 6R (OAPI) o.o 19~,99 f -. CBL (HV ) 0.0 50.000 CBL (HV ) ;;9,999 lOO.OO VDL (US ~00,00 1~00,0 CP 30.22 RelatJv F I LE ~ Bearln 05-MAR-88 15.' 44 REPEANIf SECTION 5"/100 ' REPEAT SECTION 11300 11400 11500 --j I~, ~t I I 'II ~"~100 ' ~£P£AT ~$EOTION ~£PEAT SECTION I TT~ ~US 400,00 ~00,00 -1~,00 1,0000 0,0 ~0,000 GR (GAPI) ¢~L (MV ) VDL 0.0 100.00 50.000 10019~ ~00.00 SEHSOR MEASURE POIHT TO TOOL ZERO SRAT 8.~ FEET AMPL 8.~ FEET TT1 8.~ FEET C~L 8.~ FEET TT3 8.~ FEET TT~ 8.~ FEET TO $.2 FEET TT4 8.~ FEET SLTT 8.a FEET TT 8.2 FEET GR 35.? FEET SC~L 8.~ FEET HCHL ~7,? FEET FCHL ~?,? FEET COL 39,3 FEET TEHS 8,~ FEET HBIS 8.~ FEET HART ~?,7 FEET PARAMETERS MAME VALUE UHIT HAME VALUE UHIT ~H~ CASE CSlZ 5,00000 IH FCHD CSID ~S 6,~5000 IH CSTR 1500,00 P$IA CWEI 18,0000 L~/F COTS 100,000 SPFS R-H ~TF 189,000 U~/F DTM 56,0000 US?F PSMR ~.~7500 DWCD 51~ MATR SAHD HC WMUD 8,40000 L~/G DEFDRE SURVEY CALIDRATIDM SUMMARY PERFORMED! 05-MAR-88 1~845 PROGRAM FILE: CgS (VERSIDH 30 · ~ 87/0~/10 87/0~/09) SGTE DETECTDR CALI~RATIDH SUMMARY MEASURED ~KGD JIG CALIBRATED UHITS GR 15 159 158 GAPI CNTA DETECTOR CALIDRATIOH SUMMARY HRAT TAHK JIG IHPUT CALIBRATED MEASURED CALIBRATED ~.~7500 2.158 ~.330 ~.~10 CP 30. ~P FILE 0 COMPANY AMOCO pRODucTION CO. WELL FIELD BOROUGH GP 18742 ~37 GRANITE POINT KENAI 05-MAR-88 1~:45 STATE ALASKA SCHL. SCHL. DRLR. Elev: FR 11576.0 F TD 11585.0 F TD 11600.0 F KB 105.0 F DF GL W. D. Ford Regional Production Manager Amoco Production Company Denver Region 1670 Broadway P.O. Box 800 Denver. Colorado 80201 303-830-4040 May 4, 1990 State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Attn: Robert P. Crandall File: JLH-113-WF Completion Reports Granite Point 18742 #37 Granite Point 18742 #28RD Granite Point 17587 #6 Attached please find an original and one copy of the form 10-407, Completion Report for the above referenced wells. Attached to the Completion Report is a copy of the daily well · summary of operations as required. If you have any questions or need further information, please contact Julie Victor at 303-830-4009. JAV/nmh Attachment JLHll3.jav disk 210 RECEIVED MAY 0 8 Alaska 0il & Gas Cons. Commission ,.~. ~nchora~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COISL%IISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DESCRIPTION RECEIVED Alaska Oil & Gas Cons. Commissiori Anchorage DA TED: ~ Copy sent to sender YES, ---- NO ~ STATE OF ~ALASKA ALASKA OIL kWD GAS CONSERVATION C~ISSION 3001 Porcupine Drive Anchorage, Alaska 9S501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted via ~ ~-~- is hereby acknowledged: Copy sent to sender !ES, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL)~ GAS [] SUSPENDED [] ABANDONED. . [] SERVICE [] ~'i¥-'~ ' .'~¥'."i' 7. Permit Number 2. Name of Operator Amoco Production Company ~ ",,','- ........ :. ~ 87-109 3. Address ~; :',~h~'~_...~.~,'~._~,]~ 8. APl Number P.0. Box 800, Rm. 1833, Denver, CO 80201~?m~-._~. ,~ 50- 733-20394-00 4. Location of well atsurfaceLeg 2, S10t 8, platform Ann~ ........... ~ 9. Unit or Lease Name 787' FNL x 605' FEL, Sec, ti0n 12-T10N-R12W, S. ]~i GP 18742 At Top Producing lnterval10716 MD, 9913' TVD, .~'~/~ .I 10. WellNumber 395' FNL x 3184' FWL, Section 7-T10N-R11W, S. ~ 37 At Total Depth 1157 5' MD, 10737' TVD ~ ~ 1. Field and Pool ~(tg~' FNL x 34~" FWL, Section 7-T10N-R11W, S... Middle Kenai Sands 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 105' ADL 18742 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 11/1/87 2/13/88,, ~ J-/,/-,F~'I 77feetMSL 1 17. Total Depth (MD~'~VD) ~18. Plug Back Depth (MD+l-VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 11741' 108~2Z' 11575' 10737' YES[A NOEl], N/A feetMD N/A 22. Type Electric or Other Logs Run See attached list 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 133# X56 0 615" '26" 1.,308 sx 13-3/8" 68# N80 0 3522" 17-1/2" 2,300 sx top job '243 sx 9-5/8" 53.5# N80 0 10150' 12-1/4" StaDe 1-750 sx, StaDe 2-500 sx 7-5/8" 39# S00-95 9897 10687' 8-1/2" 300 sx 5" 18# N80 10440 11644' 7" 768' sx 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5 Dual 9770' N/A See Attached List 2,7/8" Tail 10706' .. 26. ACID, FRACTURE, cEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL' USED ,, N/A ,, , , .... 27. PRODUCTION TEST , , Date First Production I Method of Operation (Flowing, gas lift, etc.) 5/6/88I Hydraulic Lift Date of Test Flours Tested PRODUCTION FOR OIL-BBL G'AS-MC'F wATER~BBL CHOKE SIZE 'IG'AS-OILRATIO 7/5/88 2 TESTPERIOD I~ 18.6 8.2 6.2 N/AI 441 , , Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 100 80 24-HOUR RATE ~ 223 98 74 40.4o API at 600 F 28. CORE DATA ,, , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ,, Form 10-407 Submit in duplicate Rev. 7-t~80 CONT!~'.~' JED ON REVERSE SIDE ~ 29. 30. GEOLOGIC MARKERS FORMATION TESTS ,,_ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Tyonek C-1 10,145' 9,384' Perfed C-7 intervals 11,225-11,237', Tyonek C-2 10,277' 9,503' 11,307-11,345', and 11,380-11,446' on Tyonek C-5 10,686' 9,885' 3/14/88. These intervals pump tested Tyonek C-6 10,882' 10,069' 290 BOPD, 388 BWPD, with G0R = 616 on Tyonek C-7 11,237'. 10,409' 3/29/88. Flowing tubing pressure, casing Tyonek C-8 11,475' 10,640' pressure, and gravity not recorded. The C-5 sands were perforated on 5/4/88 and the combined C-5, C-7 production test is shown on line 27. .. 31. LIST OF ATTACHMENTS Attachment .... 1 - Logs Run; Attachment 2 - Perforation Open to Production, Attachment.. 3 - Dail 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Sum~ Signed ./ Title Admin. Supv. Date 5/2/90 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 Logs ATTACHMENT #1 Run ON GP 18742 #37 DIL/SP/GR LDT/CNL/GR PI/SP/GR LDT/CNL/GR PI/SP/GR/LDT PI/SP/GR '~ FMS CBL/VDL/GR CNL/GR Array S6nic Date 11/18/87 11/18/87 12/17/87 12/17/87 02/14/88 02/27/88 02/27/88 03/06/88 03/06/88 03/10/88 Company Schlumberger II II II II II II II II II ATTACHMENT #2 Perforations Open to ~roduction ToP MD (TVD) Bottom MD (TVD) 10716' (9913) 10784' (9977) 10798' (9991) 10882' (10070) 11225' (10398) 11237' (10409) 11307' (10477) 11346' (10515) 11380" (10548) 11446' (10612) Perf Size · 5n ,5II · 5II · 5II · 511 Net Foot 68' 84' 12' 39' 66' Shot/ Foot OPERATIONS SUMMARY f BHL 18742 W.11 No. 37 11/01/87 Spud Granite Point 18742 No. 37 at 0330 hours, November 2, 1987 with 17.5" hole on Platform Anna. 11/03/87 Mill pinched 30" conductor casing from 260'-275'. Open hole to 26" with hole opener. 11/10/87 Set and cement 20" 133# casing to 616'. Pumped 900 sacks Class "G" at 13.7 ppg and 500 sacks Class "G" at 15.9 ppg. Cement to surface - full returns. 11/13/87 Directionally drill 17.5" hole. 11/19/87 Set and cement 13-3/8" 61#, 68# to 3525'. Pumped 1800 sacks Class "G" at 14.7 ppg and 500 sacks Class "G" at 15.7 ppg. No cement to surface - perform top job with 234 sacks Class "G" at 16.0 ppg - good returns. 11/21/87 Perform leak-off test to 16.0 ppg EMW at 3533'. 11/22/87 Circulate gas through choke at 3743' with 5800. units of background gas. 11/28/87 Ream coal stringers from 6755'-6858' with large ..amounts of coal over the shakers. Squeeze Soltex pill to stabilize coals. 12/12/87 Drilling at 9600'. Spot and squeeze Soltex pill at 5515' to stabilize coals. 12/19/87 Drill 12.25" hole to 10,175'. Set and cement 9~5/8'' 53..5# casing to 10,150'. Pumped 250 sacks Class "G" at 12.5 ppg and 500 sacks Class "G" at 15.8 ppg on the first stage - full returns. Second stage pumped 500 sacks Class "G" at 15.8 ppg from DV tool set 3716'. 12/22/87 Perform leak-off test to 16.0 ppg EMW at 10,175'. 12/23/87 Drilling 8.5" hole. Work stuck pipe at 10,390' - free. 12/28/87 Stuck pipe at 10,989' - left fish in hole - Plug back to 10,600' with 150 sacks Class "G" cement. 01/05/88 Unable to get off cement plug - pump second 150 sack Class "G" plug back to 10,556'. ~ ~~%~f~,~~~_ 01/06/88 Sidetrack around fish with mud motor assen~>l~.~ 01/17/88 Work stuck pipe at 11,037'. Spot mineral oil pill with no success. Back-off at 10,024' and begin fishing operations.- 01/26/88 Recover parts of fish down to 10,380'. Pump 400 sacks Class "G" cement sidetrack plug back to 10,190'. 01/31/88 Set and cement 7-5/8" 39# casing from 9905' to 10,687'. Pumped 300 sacks Class "G" cement at 15.8 ppg with full returns. 02/03/88 Drilling 6.5" hole. Perform leak-off test to 16.0 ppg EMW at 10,723'. 02/12/88 Attempt to log at 11,700' with drillpipe conveyed logging tools with no success - stuck tools and had to fish. 02/28/88 Set and cement 5" 18# liner from 10,440' to 11,652' Cement with 768 sacks Class "G" cement at 15.8 ppg FILE: B:GP37.SUR RADIUS TRAD. UNITS OF CURVATURE METHOD VERTICAL SECTION OR CLOSURE DIRECTION IS 1990-05-11 85.10 DEGREES 06:14 /b MEAS. SURVEY DEPTH NORTH EAST DEPTH INCL. DIR. (TVD) -SOUTH -WEST 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 4500.O0 46OO.0O 4700.00 4800.00 4900.00 .00 .00 .17 S82.63W 100.00 -.02 -.15 .23 S60.70W 200.00 -.13 -.47 .85 N24.12E 299.99 .35 -1.00 3.00 N25.77E 399.93 3.40 .41 3.43 N24.12E 499.77 8.48 2.78 3.02 N25.OSE 599.59 14.06 5.37 4.68 N43.gOE 099.32 19.98 9.48 5.13 N65.13E 798.96 24.92 10.40 5.95 N71.38E 898.49 28.49 25.36 6.12 N85.42E 997.93 30.60 35.64 7.32 N82.gOE 1097.24 31.79 47.28 8.82 N77.35E 1196.25 34.20 61.10 12.15 N76.53E 1294.57 38.31 78.82 16.28 N78.17E 1391.48 43.69 102.78 18.93 N78.97E 1486.79 49.68 132.42 20.62 N7g.67E 1580.89 55.95 165.67 20.88 N79.72E 1674.41 62.29 200.52 20.83 N7g.OOE 1767.85 68.86 235.51 20.98 NTg.10E 1861.27 75.64 270.54 20.85 N78.63E 1954.08 82.53 305.57 21.13 N78.72E 2048.05 89.56 340.69 21.07 N78.17E 2141.34 96.78 375.96 20.37 N78.07E 2234.87 104.06 410.59 20.32 N7B.OOE 2328.64 111.27 444.59 20.08 N78.23E 2422.48 118.38 478.38 19.83 N77.87E 2516.48 125.44 511.77 19.37 N78.30E 2610.69 132.37 544.59 19.18 N78.02E 2705.08 139.14 576.90 18.95 N77.80E 2799.60 145.98 608.84 18.93 N77.gTE 2894.18 152.80 640.58 18.48 N78.60E 2988.90 159.31 671.98 18.22 N78.87E 3083.81 105.46 702.86 17.05 N79.70E 3178.90 171.18 733.11 17.55 N79.58E 3274.27 176.62 762.86 17.23 N80.O5E 3369.70 181.91 792.27 17.20 N80.IOE 3465.22 187.01 821.43 17.88 N79.77E 3560.57 192.27 851.10 18.77 NTg.77E 3655.50 197.80 882.04 19.45 N81.05E 3749.99 203.31 914.32 20.37 N81.12E 3844.01 208.59 947.96 20.83 N81.35E 3937.62 213.95 982.74 21.07 N81.73E 4030.82 219.28 1018.59 '22.15 N81.O2E 4123.59 224.68 1055.51 23.00 N81.60E 4215.93 230.29 1093.49 23.95 N81.85E 4307.05 230.02 1132.91 24.83 N82.72E 4398.73 241.56 1173.83 25.72 N83.03E 4489.15 246.80 1210.19 20.13 N83.48E 4579.09 251.99 1259.61 26.85 N83.0~ 4668.5Q 257_21 VERT. SECTION -.15 -.48 -.98 .64 3.35 6.31 10.81 18.06 27.24 37.63 49.33 63.28 81.25 105.51 135.49 169.09 204.30 239.05 275.06 310.47 345.gg 381.07 416.71 451.13 485.33 519.12 552.34 585.03 617.36 649.49 681.26 712.48 743.00 773.10 B02.81 832.25 862.21 893.46 920.03 959.96 995.01 1031.14 1068.35 1106.62 1146.34 1187.54 1230.17 1273.83 131R_3R CLOSURE DIST. DIR. DOG LEG 0 S83W .2 0 S75W .0 1 N71W 1.0 3 N 7E 2.2 9 N18E .4 15 N21E .2 22 N25E 1.7 30 N33E 1.9 38 N42E 1.0 47 N49E 1.5 57 N5OE 1.2 70 N61E 1.7 88 N64E 3.3 112 NO7E 4.1 141 NOgE 2.7 175 N71E 1.7 210 N73E .3 245 N74E .3 281 N74E .2 317 N75E .2 352 N75E .3 388 N7OE 424 N76E 458 NTOE 493 NTOE 527 N70E 560 N76E 593 N76E 626 N77E o5g N77E 091. N77E 722 N77E 753 N77E 783 N77E 813 N77E 842 N77E 873 N77E 904 N77E 937 N77E 971 N78E 1006 N78E 1042 N78E 1079 N78E 1117 N78E 1157 N78E 1 1198 N78E 1 1241 N7gE 1285 N7gE l~?q N7qF .0 1.1-1 co ~ .3 .3 ~ .6 .1 .3 .0 .7 .9 .8 .9 .5 .9 .5 .9 .0 .0 .9 .5 _7 5100.00 '5200.0~ 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 7600.00 7700.00 7800.00 7900.00 8000.00 8100.00 8200.00 8300.00 8400.00 8500.00 8600.00 8700.00 8800.00 8900.00 go00.O0 9100.00 9200.00 9300.00 9400.00 9500.00 9600.00 9700.00 9800.00 9900.00 10000.00 10100.00 10200.00 10300.00 10400.00 10500.00 10600.00 10700.00 10800.00 10900.00 11000.00 11100.00 11200.00 11300.00 11400.00 11500.00 27.41 26.30 26'52 26.23 26.22 26.23 25.57 24.73 24.45 24.62 24.42 24.07 23.95 23.92 23.25 23.13 23.37 23.37 23.15 22.58 22.43 22.15 22.30 22.03 22.93 24.28 25.15 26.08 26.78 28.35 30.32 31.02 30.72 29.82 29.05 27.97 25.80 25.07 25.85 26.58 27.48 27.48 27.83 27.62 27.20 27.18 27.10 26.95 27.03 27.00 26.72 25.02 22.87 21.77 21.30 20.65 19.50 19.65 19.90 17.02 16.00 14.88 13.88 14.23 14.48 N82.85E N82.g2E N82.2/E N82.22E N81.82E N81.80E N81.20E N81.08E N81.20E N81.88E N81.88E N81.68E N82.35E N82.gSE N83.O2E N83.35E N81.65E N81.42E N81.85E N82.05E N82.48E N82.53E N82.07E N82.75E N82.37E N82.33E N83.12E N83.00E N83.23E N84.60E N86.20E N86.77E N86.42E N86.72E N86.g8E N86.97E N87.83E N88.68E N88.g7E N89.43E N8g.85E S89.62E S89.67E S89.28E S88.78E S88.63E S88.33E S88.03E S87.63E S80.72E S85.70E S83.17E S77.87E S77.28E S77.35E S76.gOE S74.92E S74.57E S71.98E S72.67E S70.28E S66.92E S60.g8E S56.gOE S52.43E 484§.b3 4935.72 5025.28 5114.87 5204.58 5294.29 5384.24 5474.76 5565.69 5656.66 5747.64 5838.82 5930.17 6021.57 6113.22 6205.14 6297.02 6388.81 6480.69 6572.83 0665.21 6757.74 6850.31 6942.92 7035.32 7126.95 7217.79 7307.96 7397.51 7486.15 7573.33 7659.34 7745.17 7831.54 7918.63 8006.50 8095.69 8185.99 8276.28 8366.00 8455.07 8543.79 8032.30 8720.88 8809.66 8898.61 8987.59 9076.08 9165.78 9254.87 9344.08 9434.06 9525.45 9617.95 9710.97 9804.35 9898.27 ggg2.4g 10086.59 10181.44 10277.31 10373.70 10470.57 10507.58 10664.45 20U.2b 273.85 279.59 285.58 291.71 298.01 304.40 311.01 317.42 323.53 329.39 335.20 340.91 346.10 350.78 355.25 300.40 366.24 371.99 377.43 382.58 387.52 392.59 397.58 402.53 401.80 413.15 418.38 423.71 428.62 432.55 435.67 438.72 441.74 444.44 446.96 449.01 450.32 451.20 451.82 452.11 452.01 451.72 451.30 450.52 449.48 448.27 446.83 445.11 442.87 439.89 435.66 428.97 420.80 412.74 404.76 396.41 387.59 377.86 308.24 359.22 349.50 338.60 320.08 311.74 1394.bb 1439.42 1483.53 1527.54 1571.30 1615.04 1658.24 1700.23 1741.35 1782.42 1823.50 1864.15 1904.44 1944.68 1984.42 2023.54 2062.67 2101.91 2140.98 2179.45 2217.38 2254.98 2292.47 2329.87 2367.78 2407.46 2448.94 2491.85 2530.04 2582.05 2630.88 2681.80 2733.02 2783.33 2832.40 2880.00 2925.24 2968.16 3011.14 3055.31 3100.76 3146.93 3193.34 3239.86 3285.89 3331.57 3377.17 3422.59 3407.94 3513.32 3558.40 3001.82 3641.83 3678.92 3714.73 3749.63 3782.92 3815.24 3847.64 3877.80 3904.75 3929.53 3951.83 3972.63 3992.85 lqUg. D~ 1454.71 14g9.11 1543.43 1587.51 1631.57 1675.11 1717.45 1758.90 1800.30 1841.69 1882.63 1923.22 1963.72 2003.08 2043.01 2082.41 2121.95 2161.32 2200.07 2238.20 2276.12 2313.80 2351.51 2389.07 2429.63 2471.37 2514.54 2558.99 2005.23 2054.21 2705.22 2750.53 2806.93 2850.07 2903.80 2949.00 2991.92 3034.86 3078.97 3124.33 3170.38 3216.67 3263.05 3308.92 3354.43 3399.84 3445.O5 3490.18 3535.30 3580.08 3623.11 3062.58 3699.02 3734.20 3768.48 3801.12 3832.77 3864.43 3893.87 3920.14 3944.20 3965.71 3985.61 4004.81 lqZU 1465 1510 1554 1598 1642 1686 1728 1770 1812 1853 1894 1935 1975 2015 2054 2094 2134 2173 2212 2250 2288 2326 2354 2402 2442 2484 2527 2571 2617 2666 2717 2768 2818 2807 2915 2959 3002 3045 3089 3134 3179 3225 3271 3317 3362 3407 3452 3496 3541 3585 3628 3667 3703 3738 3771 3804 3835 3866 3895 3921 3945 3966 3980 4005 N79E N79E N79E N79E N80E N80E NSOE NSOE N80E N80E N80E N80E NSOE NSOE NSOE NSOE N80E N80E N80E NSOE N80E NSOE N80E NSOE N80E N80E NSOE N81E N81E N81E N81E N81E N81E NB1E N81E N81E N81E NB1E N82E N82E N82E N82E N82E N82E N82E N82E N83E N83E N83E N83E N83E N83E N83E N84E N84E N84E N84E N84E N85E N85E N85E N85E N85E N86E .d 1.2 .4 .3 .2 .0 .7 .8 .3 .3 .2 .4 .3 .2 .7 .2 .7 .0 .3 .6 .2 .3 .2 .4 .9 1.4 .9 .9 .7 1.7 2.1 .8 .3 .9 .B 1.1 2.2 .8 .B .8 .9 .2 .4 .3 .5 .0 .2 .2 .2 .4 .5 2.0 3.0 1.1 .5 .7 1.3 .2 .9 2.g 1.2 1.4 1.B 1.1 1.1 11741.00 12.§0 S4/.OOE IoBgB.BD Z/D.Og 4O~D.U~ 4U~4.4~ 4U~ N~o~ .~ · . · TELECOPY NO ~ (907) 276-7542 April i7, 1990 Jutie Victor Amoco Production Co. P. O. Box 800 Denver, CO 80201 Dear Julie = As per our phone conversation today, I am returning the enclosed form 10-407 Completion Reports for Granite Point wells 37 and 28 RD. The date of completion of these wells (defined on page 37 of our regulations) as reported on these forms cannot be correct. Also 'the operations s~ry submitted for these wells does not satisfy the requirements stated in regulation 20 AAC 25.070(a)(2), (page 15). Note that a completed form 10-407 is required of the operator within 30 days after completion, abandonment or suspension of a well. Please advise me directly if any further difficulty is encoun- tered in fulfilling these requirements. very t~ly yours, ~-~ ~ ~ ~ ,~ .~ ~-~-~' / ~ ~5~ /i Sr. Petrole~ GeOlogist Enclosured dlf:t0.~C.3 W. G. Smith District Manager December 21, 1987 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: C. V. Chatterton, Chairman File: FEW-O56-WF Gent 1 emen: BOPE Test ..~.-" .~ Granite Point 18742 Well No. 37 Amoco Production Company., ........ Post Office Box 100779 "-i,'":i ' _. Anchorage, Alaska 99510 ., 907-562-2147 , .:]~:_,,, ,,- ..... .t ~ .,- ~ ',,' - f g'..': , -; ~ . '' ,, . ...... · Pursuant to your verbal request (Reference Telecon R. L. Grainger - Mike Minder, AOGCC 12-19-87), attached is the BOPE Test Report for the subject well. Very truly yours, W. G. Smith District Manager Attachment KWU/mml 010/kwu gEC 2 1987 Gas ConS, commissio~ Anchorage NO., AMOCO PRODUCTION COMPANY .... "- -OFFSHORE B. O, P. AND EQUIPMENT TEST ,,-:';-'" . 7:_u,'.Lit-_ , .. ~.. ....... , - ,..,,~,~,. ,, :..~, ~' .... ITEM' ANNULAR B.O.P, UPPER PIRE RAMS MIDDLE PIPE RAMS LOWER PIPEr RAMS VARIABLE POR~ RAMS BLIND RAMS AUTOMATIC CHOKE ALTERNATE CHOKE CHOKE MANIFOLD CHOKE LINE & VALVES KILL LINE & VALVES UPPER KELLY COCK LOWER KELLY COCK, D.P. SAFETY VALVE D.P: SAFETY VALVE INSIDE EI,O.P, VALVE IN.SIDE~ B~O,P. VALVE STANDPIPE& MAN LOW' TEST t., 'i I FUNCTION TEST REMOTIE BJ O. P. CONTROL YES COMPANY REP: 43 0 ,",~ T,."7_ .,'~ (':? p.m'-p, M'EMORAN [5--,~M State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION FleE ~O: D. BDF. 72 TELEPHONE NO: THRU: FROM: Michael T Minder~'~~ Sr Petroleum Engineer Bobby. Foster Petroleum Inspector SUBJEC"E BOP Test Amoco Platform Anna Well #GP-37 Permit #87-109 Granite Point Field riday, November 20, 1987: The test began at 9:00 a.m. and was 0ncluded"at "%0":30' a'm. As the attached BOP test report shows, there were no failures. In s~ary, I witnessed the BOP test on Amoco's well #37 on the Amoco platform. Attachment 02-001A (Rev. 8~85) O&g 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report inspect or/~--~~i~ /---_; J Operator y~~~ Location: Sec /~ T/~//R//?.~ Drilling Contractor ~~~/z~_/~ Rig Lo~J~on, General ~/~/~ Well Sign General Hous ekeepingj~_Rig Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors Visual Audio ,/ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures Date . Representative Casing Set 8~. ~ ft. Representative ACCUMULATOR SYSTEM Full Charge Pressure ~ 9'~? ~" psig Pressure After Closure /~0 psig Pump incr. clos. pres. 200 psig. rain Z/~-s ec. Full Charge Pressure Attained: min ~/' sec Controls: Master / Remote ~.5_Blinds switch coverz~...~ Kelly and Floor Safety Valves Upper Kelly / Test Pressure Lower Kelly / Test Pressure~~ Ball Type / Test Pressure Inside BOP / Test Pressure .~/~ / Choke Manifold ~~-Test Pressure NO. Valves ,/~ No. flanges /~ Adjustable Chokes Hydrauically operated choke / Test Time / ~:;,,-' hrs. Repair or Replacement of failed equipment to be made within -- days and Inspector/ Commission office notified. Remarks-'. Distribution orig. - AO&GCC cc - Operator cc - Supervisor October 26, 1987 W. G. Smith Dis trict Manager Amoco Production Company P. O. Box 100779 Anchorage, Alaska 99510-0779 Telecopy.. (907) 276-7542 Re: Granite Point State 18742 No. 37 Amoco Production Company Permit No.. 87-109 Sur. Loc. 787'-FNL, 605'FEL, Sec. 12, T10N, R12W, SM. Btmhole Loc. 680'FNL, 3777'FWL, Sec. 7, T10N, RllW, SM. Dear Mr. Smith: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very truly ~o?rs, ~"Lonnie C. ~ Smith Co--is s ioner Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE CO~R~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-562-2147 October 21, 1987 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Attention' Mr. C. V. Chatterton File: FEW-133-WF Application for Permit to Drill Granite Point 18742 Well No. 37 Platform Anna, Cook Inlet, Alaska Attached in triplicate is a completed State of Alaska'Form 10-401, Application for Permit to Drill for Granite Point 18742 Well No. 37. We propose to directionally drill this well from Platform Anna, utilizing Leg 2, Slot 8 to a target location at the top of the Middle Kenai Sand C-5 zone, -9900 feet subsea, 550 feet FNL, 3,250 feet FWL, Section 7, TION, R11W, Seward Meridian. This well is to be completed as a producing well to recover reserves from the east flank of the Granite Point field. Also attached is our Company draft No. 364377 dated October 20, 1987 for $100.00 to cover the filing fee. The proposed directional program, surface plat, drilling program, drilling time curve, and drilling fluid program along with sketches of the BOP equipment and diverter system are also attached. This is the first well to be drilled in the northeast quarter of Section 7. There are no affected operators. Drilling operations are scheduled to commence on November 1, 1987. Please contact Kurt Unger in our Anchorage office at 562-2147, extension 211 if you have any questions concerning this application. Very truly yours, District Manage~ Attachments STATE OF ALASKA , ALASKA O,- AND GAS CONSERVATION CC .... vllSSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill [] Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenF11 Service [] Developement Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Amoco Production Company 105 feet Middle Kenai 3. Address 6. Property Designation P.O. Box 100779, Anchoraqe, Alaska 99510 ADL 18742 Granite Point Field 4. Location of well at surface Leg 2, Slot 8 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) Platform Anna 787' FNL, 605 FEL, Sec 12 TION GP 18742 Blanket At top of productive interval R12W S.M. 8. Well nu ,tuber Number C5 Top 10,005' TVD, 550' FNL, 3250' FWL Sec ; 37 Surety - 599481 At total depth TION, R11W, S.M. 9. Approximate spud date Amount 11 ~(~:T~I~W6_.8~' .FNL, 3777' FWL, Sec 7 ' .M ' November 1, 1987 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 65 Top GP 18743 #36 12,350' MD 4730 feet Horizontal 1850 feet 5060 11,905' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 600 feet Maximum hole angle '~8 0 Maximum surface 2405 psig At total depth (TVD) 5744 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 26 20 133 X-52 V~.~c~- ~nn n 0 600 600 To Surface 17½ 13 3/8 61/68 K55/NI~O BTC 3500 0 0 3500 3445 To Surface 12¼ 9 5/8 53.5 N80 BTC 10300 0 0 1030'0 9432 500 sx 8~ 7 35 S95 BTC 2250 10100 9259 12350 1130.5 To cover entire length 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate OC~r' ;t . Production , Liner Alaska 0il & Gas Cons. COBB Perforation depth: measured Ar~ch0rage true vertical 20. Attachments Filing fee [] Property plat~ BOP Sketch ~ DiverterSketch ~ Drilling program FA Drilling fluid program [] Time vs depth plot E~: Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the forego~g is tr, u~and correct to the best of my knowledge Signed ~~,~~,/~,~¢~~ Title District Manager Date 10/21/8' Commission Use Only Permit Number [ APInumber IApprovaldate I See cover letter "" ~-~ ¢~ ~ 10/26/87 for other requirements Conditions of approval Samples required [] Yes EYl~Io Mud Icg required ~ Yes [E~No Hydrogen sulfide measures [] Yes [~-~1o Directional survey required E3~-Yes [] No Required working pressure for BORE ©2M; ~ 3M; .[] 5M; [] 1OM; [] 15M Other: :~~~ ~~ by order of Approved by Commissioner the commission Date/~ ¢ Zg Form 10-401 Rev. 12-1-85 Submit in triplicate Granite Point 18742 No. 37 General Drilling Program 1. Nipple up 30" riser. Clean out 30" piling. 2. Drill 17~'' . .~ hole to 600' Open hole to 26". 3. Run and cement 20" conductor casing to surface. 4. Nipple up 20" riser and 10" diverter system. Function test all components. Perform formation leak off test below 20" casing. 5. Drill 17½" hole to approximately 3500'. 6. Run and cement 13 3/8" surface casing to surface. 7. Nipple down diverter system. Nipple up BOP's and test to 3,000 psi. Perform formation leak-off test below 13 3/8" casing. 8. Drill 1~-~''~4 hole to approximately 10,300' to top set the C2 zone. 9. Run open hole logs. 10. Run 9 5/8" casing and cement with 500 sx. 11. Drill out 9 5/8" casing. Perform formation leak-off test. Drill 8-~" hole to total depth (approximately 12,350') 12. Run open hole logs. 13. Run 7" liner 10,100~- 12,350rand cement over entire length. 14. Perforate zones of interest. 15. Run hydraulic BHA and dual strings of 3½" tubing. 16. Set back-pressure valves, nipple down BOP's, nipple up tree. Test tree to 5,000 psi. Pull back-pressure valves. 17. Place well on production. NOTE: A. B. Mud loggers will be used from spud - TD. Casing design factors of 1.125, 1.0, and 1.8 will be used for collapse, burst and tensile strengths respectively. Granite Point 18742 No. 37 Mud Program Interval' SFC - 3,500 Feet (26" & 17½" Hole Sections) Mud Type' EPA Mud Type No. 5 - Spud Mud. Mud Description' Prehydrated Gel - Seawater W e i g h t P___~V Y__~P F__~L 9.0 10 10-20 NC Interval' 3,500 TD (1~-~'' " - ~4 and 8½ Hole Sections) Mud Type' EPA Mud Type No. 2 - Lignosulforate mud. Mud Description' Dual Polymer - Freshwater HTHP We i gm t P__~v Y__~P FL 9.0' 10 10-15 15 *Mud weight will be increased as required to control formation pressures. RECEIVED OCT ~' ?~,~7 oil 8, Gas cons. Commiss Anchorage Basis le e e Granite Point 18742 No. 37 Anticipated Formation Pressures GP 18742 No. 36 11.9 ppg EMW kick in C4 zone at 9,842' MD (9,441' TVD). 02/26/86. High Pressure Waterflood water. Calculated Maximum Formation Pressure: 9441 feet x .052 x 11.7 = 5744 psi Maximum Surface Pressure If 20% of the wellbore is evacuated with 8.5 ppg seawater in the well, the maximum surface pressure is: Psmax : 5,744 psi - (9441 - (.20 x 9441)) x .052 x 8.5 ppg. Psmax = 2,405 psi Maximum Anticipated Mud Weight: The maximum anticipated mud weight is 11.7 ppg. SUBJECT Amoco Production Compr~'~V ENGINEERING CHART Sheet No. File Of A ppn Date i/ i ' I lo ~o OC-I' , ~ Oil & Gas Co~s. Oommi~$1O~ ~¢h0rage Form 371 t MOBIL, G~rAtV/TE PT. "! i / / RI2W / / / / , - / / / / / RIIW FtLEH~E: Al, T1 TRADITIONAL UNITS 1987-10-21 .J:58 RADIUS OF CURVATURE METHOD VERTICAL SECTION OR CLOSURE DIRECTION IS 86.50 DEGREES MEIS. SURVEY DEP~H NORTH [)EPTH iNCL. I]IR. (TVD) - SOUT}! 300.00 1.00 N 0.00E 299.98 2 62 400.00 l.S0 N 0.00E 399.96 4 80 500.00 2.00 N 0.00E 499.9i 7 85 690.00 2.50 ~ 0.00E 599.84 Il 78 700.00 3.00 N20.00E 699.72 16 48 800.00 4.S0 N40.00E 799.50 22 11 900.00 S.50 N60 00E 899.12 2? 69 t000.00 6.50 NS0 O0E 998.57 31 25 t100.00 7.50 NS0 O0E 1097.82 33 36 t200.00 8.S0 NS0 00E 1196 85 35 ?8 1300.00 9.50 NS0 00E 1295 62 38 49 1400.00 !0.50 NS0 00E 1394 10 41 51 2000 00 11 50 NS0 00E 1983 06 2500 00 12 50 NS0.00E 2472 13 3000 00 13 50 N80.00E 2959 31 0.00 0.00 0.00 0.00 0.83 4.08 10.72 20.50 32 50 46 2O 61 61 78 71 EAST VERT. CLOSURE DOG -WEST SECTION Di2T. DIR. LEG 0.16 3 lq 0E 0 3 0.29 5 N OE 0 5 0.48 8 N OE 0 5 0.72 12 N OE 0 5 I . 83 t7 ,U 3E 1 t 5.42 22 N10E 2 0 12.40 30 N21E 2.0 22.37 37 N33E 2 3 34.47 47 N44E 1 0 48 30 58 N52E 1 0 63 85 73 N58E 1 0 8i 10 89 N62E 1 0 201 N72E 0 2 304 N75E 0 2 417 N76E 0 2 535 N77E 0. ! 658 N78E 0.1 683 N78E 0 0 709 N78E 0 5 ! o 734 hTuE 0 0 760 N78E 0 0 786 N78E 0 0 813 N78E 1 0 61 39 19i 45 i94 85 79 44 293 83 298 13 98 97 404 59 409 88 3500 00 !4 0O N80.00E 3444 98 119 6! 52i 63 527 96 4-000 00 14 50 NS0.00E 3929 60 140 98 642 84 650 25 4100 00 i4 50 NS0.00E 4026.41. 145 33 667 50 675 12 4~00,. 00 ~5~ 00 NSO.00E 4123.11 !49 -~c,., 692 57 700 42 4300 00 !S 00 NS0.00E 4219.70 154 24 718.06 726 13 4400 nO ~5 0~ NS0 20E 4316.29 158 69 743 55 rS! oc 4500.00 15.00 NS0.40E 4412.88 163.05 769.07 777 59 4600.00 !6.00 N80,60E 4509.24 167.47 795.42 804 16 ¢70©,, 00 .~7 00 NS0.80E ~605. .lP. ~72~ .05 o°~3.45z 832 42 ~41_ N78E ~ 0 4800 00 18 00 Ngl.00E 4700 49 176 81 85].14 862 34 871 N78E 1 0 4900 00 19 00 NS1.20E 4795 32 t8I 72 884.49 893 93 903 N78E 1 0 5000 00 19 50 NS1.40E 4889 72 186 71 9i7 08 926 72 936 N?SE 0 5 5100 00 20 00 Ngl.60E 4983 84 191 70 950 50 960 43 970 N79E 0 5 5200 00 20 50 NS1.80E 5077 65 196 70 984 75 994 92 1004 N79E 0 5 5300 00 21 00 N82.00E 5171 16 201 69 1019 82 1030 23 1040 N79E 0 5 5400 00 2] 50 N82.20E 5264 36 206 67 1055 72 1066 37 1076 N79E 0 5 5500 00 22 00 N82.40E 5357 24 211 64 1092 45 t103 33 1113 N79E 0 5 5600 00 22 50 Ng2.60E 5449 79 216.58 t129 99 1141 10 1151 N79E 0 5 5700 O0 23 O0 N82.80E 5542 O1 221.49 1168 34 I179 69 1189 N79E 0 5 5800.00 23 50 N82.00E 5633.89 226.71 1207 47 1219 06 1229 N79E 0 6 5900.00 24.00 N82.80E 5725.42 232.04 t247.39 1259 23 1269 N79E 0 6 6000.00 24.50 N83.00E 5816.59 237.12 1288.15 1300 22 1310 NSOE 0 5 6100.00 25.00 N83.ZOE 5907.41 242.15 1329.71 1342.01 1352 NSOE 0 5 6200 O0 25.50 N83.40E 5997.85 247.12 t372.07 1384.60 1394 NSOE 0 5 6300 00 26 00 N83.60E 6087.91 252.04 1415.24 1427.99 1438 NSOE 0 5 6400 00 26 50 N83.80E 6177.60 256.89 1459.20 1472.16 1482 NSOE 0 5 6500 00 27 00 N84.00E 6266.89 261.68 1503.96 1517.13 1527 NSOE 0.5 6600.00 27 50 N84.20E 6355.79 266.38 1549 50 1562.87 1572 NSOE 0.5 6700 00 28 00 N84.40E 6444.29 271.01 1595 83 1609.40 1619 NSOE 0.5 6800 O0 28 50 N84.60E 6532.37 275.54 1642 95 1656 70 1666 NSOE 0.5 6900.00 29 00 N84.80E 6620.05 279.99 1690 84 1704 78 1714 NS1E 0.5 7000.00 29.50 N85.00E 6707.29 284.33 1739 51 1753 62 1763 NS1E 0.5 7]00.00 30.00 N85.20E 6794.11 288.57 17~8 99 1803 23 1~12 NS1E 0.5 7200.00 30.50 N85.40E 6880.49 292.70 I839 15 1853 59 I862 NS1E 0.5 7300.00 3].00 N85.60E 6966.43 296.71 1890 12 1904 71 1913 NS1E 0.5 7~.nfi O0 3!.50 NSS.80E 7051.92 300.60 1941.86 1956 58 1965 NS1E 0.5 7000.00 29.~'-'~' N85.00E 6707 .... 29 284 33 1739 51 1 ....~.62 1763 NS1E 0 7100.00 30 ~ N85.20E 6794.11 288.57 1788.95 lbvJ.23 1812 NS1E 0.5 7200.00 30 50 N85.40E 6880.49 292.70 1839.15 1853.59 1862 NS1E 0.5 7300.00 31 00 N85.60E 6966.43 296.71 1890.12 1904.71 1913 NS1E 0 7400.00 31 50 N85.80E 7051 92 300 60 1941.86 1956 58 1965 N81E 0 5 7500.00 32 00 ff86.00E 7136 95 304 36 1994.34 2009 20 2017 NS1E 0 5 7600.00 32 50 NSG.2OE 7221 52 307 99 2047.58 2062 56 2071 NB1E 0 5 7700 O0 33.00 N86.40E 7305 62 311 48 2101.56 2116 66 2125 N82E 0 5 7800 00 33.50 NSG.GOE 7389 25 314 83 2156.29 2171 49 2179 N82E 0 5 7900 00 34.00 NSG.BOE 7472 39 318 02 2211.75 2227 04 2235 N82E 0 5 8000 00 34.50 N87.00E 75~>J.O5 321 07 2267.95 2283 32 2291 NS?E 0 5 8100 O0 35.00 N87.20E 7637 21 323 95 2324.88 2340 32 2347 N82E 0 5 $200 00 35.50 N87.40E 7718 87 326 67 2382.53 2398.03 2405 N82E 0 5 8300 O0 36.00 N87 60E 7800 03 329.22 2440.90 2456 44 2463 N82E 0 5 8400.00 36.50 N87 80E 7880 67 331 59 2499.98 2515 56 2522 N82E 0 5 8500.00 37.00 N88 O0E 7960 79 333 78 2559.77 2575 37 2581 N83E 0 5 8600.00 37.50 N88 20E 8040 39 335 79 2620 27 2635 88 2642 NB3E 0 S 8700.00 38.00 N88 40E 8119 46 337 60 2681 46 2697 07 2703 N83E 0 S 8800.00 38.00 }488 60E 8198 26 339 22 2743 01 2758 60 2764 N83E 0 i 8900.00 38.00 N88 80E 8277 06 340 61 2804 56 2820 12 2825 N83E 0 1 9000 O0 38.00 N89 OOE 8355 86 341 79 2866 i1 288t 63 2886 N83E 0 1 9100 O0 38.00 N89 20E 8434.66 342 76 2927 67 2943 13 2948 N83E 0 1 9200 00 37 25 N89 40E 8513 86 343 51 2988.71 3004 11 3008 N83E 0 8 9300 00 36 50 N89 60E 8593 85 344 03 3048 72 3064.03 3068 N84E 0 8 9400 O0 35 75 N89 80E 8674 62 344 34 3107 67 3122.90 3127 N84E 0 8 9500 O0 35 00 N90 OOE 8756 1G 344 44 3t65 56 3180.69 3184 N84E 0.8 9600.00 34 50 S89 80E 8838 32 344.34 3222 64 .3237.66 3241 N84E 0 5 9700.00 33 75 S89 60E 8921 09 344 05 3278 74 3293.63 3297 N84E 0 8 9800.00 33 00 589 00E 9004 60 343 37 3333 75 3348.49 335! NS4E 0 8 9900.00 32 ~5 S88 00E 9088 82 341 96 3387 64 3402 20 3405 N84E 0 9 I0000 00 31 SO S87 OOE 9!73 74 339 66 34.40 40 3454 72 3457 N84E 0 ~0!00 O0 ~n ~c S86 OOE 925q 34 336 50 3491 99 3506 02 3508 N84E 0 30200 O0 20 00 S85 OOE 9345.61 332 53 3542 40 3556 09 3558 NSSE 0 9 10300 00 29 25 584 00E 9432.54 327 80 3591 60 3604 92 3607 NSSE 0 9 10400 O0 28 50 S83.00E 9520.10 322.33 3639 58 3652 47 3654 NSSE 0 9 10500 O0 =,~? 75 S$2.00E 9608.29 316..~$ 3686 32 36~8. 74 3700 NSSE 0 9 1Of, O0 00 ..,?~ 00 58t.00E 9697.09 309 ~o~o ~731~ 79 3743 72 3745 NgSE 10700 O0 26 25 580 O0E 9786.49 301 98 3775 99 3787 38 3788 NSSE 0 ,'o . .. ~9~ 2 !u~,00 00 26 ~5 S79 00E 9876 ~7 ~ . 9 3819 48 3830 30 3831 NB6E 0 4 10aO0.00 2~ 2~ ~,8 00~ q965 86 285 10 3862 82 3873 0~ 3873 N86E 0 4 11000.00 26 25 S77 O0E 10055.54 2~,~ _~3 .~90G O0 ..~15 53 3916 N86v- 0 4 11100.00 26.25 STG OOE 10145.22 265 2! 3949 O1 3957 83 3958 N86E 0 11200.00 25.50 575 OOf 10235.20 254 28 3991 26 3999 33 3999 N8GE 0 9 11300.00 24 75 S74.OOE 10325 73 242 93 4032 17 4039 48 4039 N87E 0 9 11400.00 24 00 573.00E 10416 82 23t 21 4071 74 4078 26 4078 N87E 0 9 11500.00 23 25 572.00E 10508 43 2t9 16 4109 96 4115 67 4116 N87E 0 8 11600.00 22 50 $71.00E 10600 57 206 83 4146 82 4151 70 4152 N87E 0 8 11700.00 21 75 S70.00£ 10693 20 194.25 4182.32 4186 37 4187 N87E 0.8 11800 00 21 00 S69.00E 10786 32 181 49 4216 45 4219 66 4220 N88E 0 8 11900 00 20 25 $68.00E 10879 91 168 58 4249 23 4251 59 4253 NUBE 0 12000 00 19 S0 S67.00E 10973 95 155 57 4280 63 4282.14 '4283 N88E 0 8 12100 00 18.75 $65.00E 11068 42 142 24 43t0 56 4311 20 4313 N88E 1 0 12200 O0 18 75 S64.00E 11163 tl 128 41 4339 57 4339 31 4341 N88E 0 3 12300 OO 18 75 S63.OOE 11257 80 114 06 4368 34 4367 1S 4370 NB9E 0 3 12400.00 18 75 SG2.00E 11352.50 99 22 4396.84 4394 70 4398 NB9E 0 3 .... !25~0.0b ..... 18 75 H61.00E '1i447.19 83.88 4425.09 442t 95 4426 N89E 0 3 12600.00 18 75 ~60.00~ 1154].88 68.05 4453.06 4448 91 4454 N89E 0.3 12700.00 18 75 559.00E 11636.57 51.74 4480.76 4475 55 4481 N89E 0.3 ' 12800.00 18 75 558.00E 11731.26 34.95 4508.16 4501 89 4508 Ng0E 0.3 224 A 0 2,, 9 8 1227 9 ~ 7 7 8 ' 207 54E 6 5 t, 215 ~" 219 ~l O9 ,'?29 1207 ANNA 10 9 232 '"~ 239 11 -lO 217 muc 1 PL:~.AN -'[()P~ VIEW FIL. E '=: ALT1 UNITS :::: F'T 0 5000 400C, 3000 .................................................................................................. 2:00 1000 't ....................................................................................................................................... .-100C ................................................................................................................................................ 0 1000 2000 3000 4000 o003 WEST EAST --2000 't -1300 6000 c~ (¢ ~o /,¢.7~/.z /~C, ~ 7 100C I FI LE = ALT1 200C .......................................................................................... IVertical Section ....................... [8S~50 300C ................................................................................................................................................... 400C'--! ......... $00C 600C 700C ] .................. 5.00C ~OOC 1COOC 1!00C: 12000 0 1000 2000 3000 4000 5000 6000 7000 8000 PI ..... AN -T()P ..... VIEW -.60C 0 © 650 - ............................................................................................. x( ..................... , · / / ./ ,/' --70 C ......................................................................... ~- -/ ...................................... -75C .... -85C ......................................................................................................................... -900- -700 -650 600 -550 -..., JO -450 -Z. O0 WEST EAST Legend TRUE VERTICAL DEPTH 0.00 50 00 !00 O0 150 00 200 00 NO.I(ALT1 NORTH EAST -SOUTH -WEST -787.00 -605.00 -786.56 -605 O0 786 '~ - .J.o -605 00 -785.69 -605 O0 -785.25 -605 00 250 00 -284 82 -605 00 300 O0 -784 38 -605 0O 350 00 -783 29 --605 00 400 00 -782 20 -605 O0 450 00 -780 67 -605 00 SO0 O0 -779 14 -605 O0 550 O0 -777 18 -605 00 600 00 -775 2i -605 00 650 O0 --772 86 -604 58 700 00 -770 50 -604 !6 750 00 -767 68 -602 53 800 00 -764 86 -600.88 850 00 -762 06 -597 55 qo0 00 "59 28 c94 ! . - : -... I000 O0 -755 72 -584 33 i050 00 -754 66 -578 28 1100.09 -753 59 -572 20 ].lSO 00 -75.2 36 -565 28 !200 O0 -751 14 -558.30 1250 00 -749 76 -550.50 1300 0'~. -748 37 -.~,~c~2.62_ i350 00 -746 84 1400 00 -745 29 -525 i6 ,4.~0 O0 -743 60 515 59 1500 00 -741 92 -506 02 1550.00 1600.00 1650.00 1700.00 1~0 1800.00 1850.00 -740 23 -496 44 -738 54 -486 87 -736 85 -477 30 -735 16 -467 73 -73~ 48 -458 -731 79 -448 59 -730 10 -439 02 1900.00 -728 41 -429 45 1950.00 -726 73 -419 o,g' 2000.00 -724 98 -410 O0 TO(POSTG39C) FROM NO. 1 FT DIR. 8 06 1',183E 8 48 N84E 9 33 N86E 9 76 N87E t0 19 NgTE 10 62 N88E ll 06 11 6] S84E t2 52 SSOE 13 16 STGE 13 G6 S70~ 14 02 S6SE ~3 86 SSGE 14 0i S48E !4 i0 S34E 14.66 S24E t5 29 S 9E !5 63 S 2W 18 38 S22~ 18 77 S32W 20 13 S52W 21 19 S61W 22 94 STOW 24 97 578W 28 06 sgsw ~ O 30 94 34 97 N82W 38 8S N76W 42 93 47 17 N66W 51 42 N60~ 56 t2 NSS~ [ 19 N49W 66.88 N44~ 73.16 N39~ 80.09 N34~ 87.50 N30~ 95.65 N26W TO(POST32RD) FROM NO.1 FT DIR. 4.47 NG3E 4.09 NTOE 3.76 N77E 3.27 N88E 2.95 S77E 2.77 So~E 2.92 S38E 4..03 S1GE 5.48 S SE 7 61S3W 9 83 S 7W 12 24 S 9W 14 67 SllW 17 38 S13W 20 11 S15W 24 21 S20W 28 45 523W 34 31S30W 40 49 SZSW 47 !8 S4IW 54 28 S46W 62 08 SS1W 70 28 S54W 79 73 SS8W 89 44 S60W 100 31 S62W 111 35 S64W 123 37 S66W 135 56 S67W 148 S8 S68W 16i 67 S69W 174 95 S70W 188 30 S71W 202 13 £72W 215 99 S72W 230 09 S73W 244 22 S?3W 258.43 S?4W 272.65 S75~ 28G.57 S?5W 300.78 S76~ '. ~ · · TO(POSTCP1S) FROM NO.I FT DIR. 4 12 Si4W 4 62 S14W 5 12 S14W S 75 S15W 6 47 S16W 7 18 S!SW 7 70 8 62 S36W 9 60 S41W 10 74 S44W 12 O0 S49W 13 58 S50W 15 14 SS1W 17 41 S52W i9 68 SS3W 23 20 SS4W 26 72 S55W 30 00 SS6W 33 27 S57W ~ 05 S56W 36 81SS6W 36 7G S55W 3G 71 555W 36 42 S52W 36 23 SSOW 36 73 S47W 37 46 S43W 39 27 S39W 41 39 536W 44 81 S33W 48 1S S30W S0 58 S26W 52 54 S23W 52 28 S19W S1 82 S15W 50 52 5!IW 49.42 S 6W 48.47 S 1W 47.87 S 4E 47.63 S10E 47.65 S1SE T~ADITIONAL UNITS I987-10-21 08:26 TRUE NO.I(ALT1 ) VERTICAL NORTH EAST DEPTH -SOUTH -WEST 0.00 -787 O0 -605 00 2000.00 -724 98 -410 O0 2100.00 -721 29 -389 07 2200.00 -?t7 60 -368 14 2300 00 -7!3 9i -34? 20 2400 00 -7t0 22 -326 27 2500 O0 -706 44 -304.83 2600 00 2700 00 2800 00 2900 O0 3000 00 3100 00 -702 43 -282.10 -698 42 -259.36 -694 41 -236.63 -690.41 -213.89 -686 30 -190 60 -682 05 -!66 50 3200 00 -6?7 80 -142 40 3300 00 -673 55 -118 31 3400 00 -669 30 -94 21 3500.00 -664 96 -69 61 3600.00 -660 55 -44 60 3700.00 -656 14 -19 59 3800.00 -65t 73 3900.00 -647 32 4000.00 -642 86 4100 00 -638.31 4200 00 -633 67 4300 00 -629 06 4400 00 -624 53 4500 00 -619 96 4600 0O -615 ]9 5.4.3 30 44 55 77 81 58 107 86 134 25 160 66 t87 89 216 95 4?00 O0 -610 2i 247 99 4800.00 -605.03 281 tl 4900.00 -599.75 315.73 S000.00 -594.44 351 40 5100.00 -589.11 388 13 5200.00 5300.00 5400 00 5500 O0 5600 00 -583.77 425 93 -S78.42 464 81 -573 08 504 79 -567 ?S 545 87 -562 21 588 04 5700 00 -556 44 631 30 5800 00 -550 81 675 73 5900 00 -545 26 721 32 6000.00 -539 76 768 11 6100.00 -534 31 816 16 6200.00 -528 91 865 43 6300.00 -523.57 915 92 6400.00 -518 31 967 64 6500.00 -513 Il lOZO 63 6600.00 -508 03 1074 89 6700.00 -503 03 1130.44 6800.00 -498 1S 1187.37 6900.00 -493 39 1245.72 7000.00 -488 77 1305.44 RADIUS OF CURVATURE METHOD ¢',,,¢' TO(POSTG39C) FROM NO.! FT 8 06 N83E 95 65 N26W 113 !8 N21W 131 70 N18W 149 27 NI. SW 163 04 N13W !74 61NllW 186 26 N!0W 198 3? N 9W 211.09 N 9W 224.41N 8W 237.85 N 7W 251.29 N 6W 264.85 N 5W 278 49 N 5W 292 29 N 4W 303 25 N 3W 313 80 N 2W 324 00 N 2W 332 19 N 1W 340 46 N OE 349 69 N 1E 359 !9 N 2E 369.56 N 4E 381.15 N .,CE 391.35 N ?E 400.82 N 8E ,05 05 N 9E 413 43 NIOE 418 S1 Nile 423 71N12E 428 71N12E 434 14 N12E 439 87 N13E 445.84 N13E 452.00 N13E 458.72 N13E 464.89 N12E 469.82 N12E 4?4.70 NllE 479.51N10E 482.28 N 9E 485.02 N gE 486 27 N 6E 487 26 N 3E 488 22 N 1E 489 15 N 3W 492.09 N 6W 497 t] NllW 505 38 NISW 517 26 N20W 532 92 N24W TO(POSTCPI$) FROM NO.1 FT 4 12 S!4W 47 65 SISE 48 01 S23E 48 75 532E 50 51 S41E 53 38 S49E 56 82 SS6E 60 06 S61E 64 06 S65E 68 64 S69E 73 82 S73E 79 79 576E 86 04 S76E 92 44 S?6E 98 79 575E 105 16 57r~ i11.43 574E 117 46 S73E 123 91 S72E ]30 40 S71E 136 9! ST1E 142 88 $70E 148 34 568E 152.91 S67E 157 S0 S65E 162 21 S63E 166 1.2 S62E 168 38 559E i69 25 556E 169 12 S53E 168 65 S49E 168 2] S44E 168 04 S39E 168 39 S34E 169 62 S28E 171 92 523E 175.62 S17E 181.22 S10E 189 22 S 4E 199 42 S 2W 212 44 S 9W 228 21S1SW 246 87 S20W 267 87 S24W 291 78 $28W 318 64 S32W 349.68 536W 385.28 S39W 426.69 S43W 475.77 S47W 527.61 S50W 58!.83 SS3W TO(GP36 ) FROM NO. 1 FT DIR. 11.66 S59E !43.80 S 8E !56.09 S12E 170 21S15E 185 '/7 319E 201 91 $2tE z~u 03 S23E 233 78 524E 248 11 525E 259 17 S26E 267 72 S27E 275 65 S28E 283 62 S30E 291 99 S31E 301 77 232E 3t3 i2 S33E 324 82 534E 337 11 235E 350 59 537E 365 66 S38E 383 53 539E 403 80 S41E 424 32 S42E 443 88 S43E 462 81 S44E 481 24 S4SE 498 71 S46E 514 iZ 547E 527 02 S4?E 537 60 S47E 546.18 S47E 552 86 S47E SS7 70 546E 560 85 S46E 562 52 S45E S62 56 S44E S60 81 S43E S57 86 S42E 554 51 S41E 552 49 S39E 553 75 S37E 55? 34 S35E 561 40 S32E 565 32 S29E 568.93 SZ6E 572 SS S23E 576 42 SZOE 580 94 S16E 586 55 S12E 594 16 S 8E 604 57 S SE 618 15 S 1E ,,%, .; · . o , LEG. LAT, 7Z9' 636' WEST - 11 12 · I LEG. ¢40. 2 LEG. NO. 3 LaT. C~m?~8' )6.96" L&T. x = 266.850 X = ¢~0~ ~( C0¢ KRO~ ~.E. COq. 7~0' SO~r.~ 8 8~4' SOUT~ ~ CERTIFICATE OF SURVEYOR .j LEG. LAT. LONG. i$1 X · 266,74~ FRO~ ~E. CO~. fZ4' ~O~TH I hereby ccrli/y lho~ t om properly reglslered and licensed 1o preclice tend surveying in lh¢ Slole of ,61osko and fhof this plol repreSenlS o location survey made by me or under my suoerv~sion ¢nd lhO1 oll dimensions and olher delails ore correcl. Dole Surveyor NOTE 12 7 The loCal,on of plalform legs was accomplished by u:/tng lriongulol~on Slolions Oud, Tfiflify, end Tyonek Offsef. FINAL PLAT OF I TYOS[K PL. ATFOR~ "A' j son'v£~6o Ko~ ..... PAN AMERICAN PETROLEUM CORP. P.O 80X 779 ANCHORA6E, ALASKA SUeVEYEO OY ff M, LINOSEY & ASSOC. LANO SURVEYORS 8 C1Vl~ ENG(NEERS .... ~. ¢. C. il SUBJECT Amoco Production Company ENGINEERING CHART Sheet File Of Appn i ' I j j : ...... '10 Lille ........ o v~ E~ ¢/~/2./S ~ t i ' ! ! I i I' i! i ! : i j . ,'. I ; I ' ! ? ~ I ! · ( ! , I : i i i i ! 30.25' \ / PLATFORM ANNA DRILLING STACK 0 ~ __PITCHER NIPPLE--16"ID W/ 10" FLOWLINE ANNULAR BOP "NL SHAFFER" --1,.3 5/8" 5000 PSI BX--160 ASSY WT. 13,650 LBS. DBL GATE BOP "NL SHAFFER" --13 5/8" 5000 PSI BX--160 ASSY WT. 16,500 LBS. __MUD CROSS-- 15 5/8" BORE W/ 4-" 5000 PSI VALVES & CK ___SGL GATE BOP "NL SHAFFER" 13 5//8" 5000 PSI BX--160 ASSY WT 9100 LBS. RISER 18"0D 13 5/8 5000 FLG W/ GREYLOK CLAMP RING (AX) "CIW" P//N 4-1700--13 LOWER RISER 11" ID , .W/ 10" 5000 PSI FLG r~cember 18, 19~1 A~oco Production Company P.O. Box 779 Anchorage, Alaska 99510 Application for Permit to Drill, G~nite P?i_nt 18742, No. 37, ~ec. 31, TII~I, RllW, S.M., Platform B~"~c-~ ....................................... Dear ~r. p'connell: In reference to your conversation this date with James E. Trimble of this office, the subject application is returned to you. It is our understanding that there are no present plans to drill this weI 1. ALASKA OIL AItlD GAS ~,OttS£RVATIOtV (',OMMISSlO# October 6, 1980 JAY S. HAMMOND, GOVERNOR 3001 PORCUPIN~¢ DRI V£-ANCHQRA GE, ALASKA 99501 A D M I N I S T R A T I V E A P.P R O V A L NO. 76.14 Re: The ap_~!ication' of Amoco Production Company to drill the ,G'~'~i:~-e~'~'~~'~J."8'7"4~'~.~3""'7?,-well as part of the pressure m~~~o:ect approved by Conservation Order No. 76. Mr. L. A. Darsow District Superintendent Amoco Production'Company P. O. Box 779 Anchorage, Alaska 99510 Dear Mr. Darsow: The application was received on October 3, 1980 and stated that the referenced well would be located in a more favorable loca- tion to improve ultimate recovery from the east flank of the Granite Point reservoir. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the referenced well pursuant to Rule 7 of Conservation Order No. 76. Yours very truly, Harry W. Kugler/ Commissioner BY THE ORDER OF THE COMMISSION 6~'P g Z7 (2 ~ 8) (8) (14 uz=u 22) ' (z3~ 28) .... (29 r. nm~ 3i) 7 2. Is well no be locaued in a ~i=~nad pool ............................. ~__ ........ 3. Is ~ !ocazad p~p. er dis~e ¢~-cm prcp.~ ~Ltu~ .................. ~ 4. is ~ locarad p .~ ~ ~um~ca ~ other wells .................... ZR-- 5. is suffi~z umdmdicaued a~ea~e av~!~nie i~ this pool ............ ~ 6. Is ~ ~o be deviated and .is ~mJ_!bore plat ina!uJad ................ _~ 7. is operator the only a~aa~.ad par%~ ................................. _~_ 8. C~ p¢~: be ~.u~o~ed before ~ ~een-day ~% ...................... , 9. Does .cpe_~uor hav~ a bend in force .................................. ~ 10. Is a conse_~za~ order naa_dad ....................................... ~ !!. Is admini~~ ~mppr. ova!-naedad ................................... ~ 12. Is the lease ~er amo~=ua ......................... .... ...... ~ Does dna well have a unique n=~na and number .............. , . .. 14. is csn~e-~r s~-iu~ provided ........................................ 4~ 15. Will surfac~ casinE proracU ~sh ~,-a.ce::' zones ....................... ,,~.,c' ' 16. is en~ cz:~_ul: used ~o cir~]~ta o~ cgndnd~r and ~ca ......... ~ 17. ~ll c~ ~a ~ ~~ ~d ~E~Ea ~ p~~~ s~~ ... ~ 18. W~ c~U ~ ~1~ ~ ~~~ ~~ ..................... ~ , 19. ~]] ~1! ~~ ~ a~~a s~a~ ~ ~~se, ~i~ ~ ~~.. ~ 20. ~ ~ ~ ~ be ~~ o~ ~ ~ ~~ ~!]5~ ............ - ~ ~. ~ old ~ore ~~: ~ca~e ~~d ~ 10-403 ............ 24. IS the d~:~!~nE fluid pro~ scl~r~/_c and ]{~u of ~e~. u adaquaua ~ 26. ~ ~~ ~~= ~~ ~~- T~u ~ 3OO~ p~ .. ~ 27. ~ ~ ~ ~~otd c~iy w/~I ~-53 ~ 84) .................. ~. ~ ~~~ of~S ~ ~b~ ................................. 29. Ar~ data p'=esmzzed on l:X:rr_'en~¥1 ove_~~ zorma? ................. /' /k;/~ 31. If a~.o~2shmr~ loc. ,. are surce7 ~r~ of seabed csndi~ prase~/~ · 32 AdRi~ _~l ::-e~,ri-~e:~ . ~ iii iii i Geolo~: r~v: 01/28/87 6.011 ,,, 0 FI= e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . FMS Composite Sepia's 187-109 1-4 Are in special storage due to . overSIze. . Please ask the Liberian to retrieve them for you in the storage upstairs.