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166-052
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,015 feet See schenatic feet true vertical 10,075 feet N/A feet Effective Depth measured 5,025 feet 7,811 feet true vertical 4,639 feet 7,093 feet Perforation depth Measured depth 4,153 - 4,404 feet True Vertical depth 3,853 - 4,078 feet 4-1/2" L-80 7,809 (MD) 7,091 (TVD) Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80 7,927 (MD) 7,196 (TVD) 7,811 (MD) 397 (MD) Packers and SSSV (type, measured and true vertical depth) Model D Pkr 7,093 (TVD) TRSSSV 397 (TVD) 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 Pt 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: Other: N2 Ops 69 324-681 Sr Pet Eng: 8,610psi 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. Eric Dickerman Eric.Dickerman@hilcorp.com 907 564-4061Operations Manager N/A 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 N/A 270 Size 588 0720 0 2600 13-3/8" 8,460psi 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 166-052 50-733-20437-00-00 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: ADL0017587 Granite Pt / Granite Pt Gas Granite Pt St 17587 03-87 Plugs Junk measured Length measured TVD Production Liner 8,178 3,074 Casing Structural 7,416 7" 8,178 10,999 10,059 589 2,092 589Conductor Surface Intermediate 20" 3,090psi 3,060psi 2,730psi 5,750psi 2,092 1,998 Burst Collapse 1,500psi 1,130psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:19 pm, Jul 17, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.07.17 13:58:56 - 08'00' Dan Marlowe (1267) DSR-7/21/25 Gas CDW 07/18/2025. AOGCC will now revoke DIO 19 and 19.01 as requested by Hilcorp under Docket DIO-25-002. RBDMS JSB 072525 _____________________________________________________________________________________ Revised By: EPD 07/17/25 SCHEMATIC Bruce Platform Well: Granite Pt St 17587 3 (Br 3-87) Completed: 12/29/24 PTD: 166-052 API: 50-733-20437-00-00 PBTD = 5,025’ / TD = 11,015’ HOLE ANGLE thru Interval =qq C-1 8 6 7 2 3 4 9 20” 4-1/2” TOC @ 3,016’, CBL 1/4/25. Fill Tag @ 9,067 MD 11/13/2024 5 C-2 C-3,4 C-7 C-5 C-8 C-9 13-3/8" 9-5/8" 7" 1 A-1 A-0 9-5/8” TOC @ 3,550’ CBL 12/26/24. A-7 A-9 LB-2 LB-1 RKB to TBG Head = 42.80’ Tree connection: ?? CASING DETAIL Size Wt Grade Conn ID Top Btm 20 133 K-55 18.73 Surf 589’ 13-3/8” 54.5 J-55 8 rd, ST&C 12.515 Surf 2,092’ 9-5/8” 43.5 S-95 ERW ST&C 8.755 Surf 52’ 40 N-80 Buttress 8.835 52’ 4,676’ 40 S-95 ERW ST&C 8.835 4,676’ 6,696’ 43.5 S-95 ERW ST&C 8.755 6,696’ 8,178’ 7” 32 N-80 Butt. 6.094 7,925’ 8,014’ 29 S-95 ST&C 6.184 8,014’ 8,760’ 32 N-80 Butt. 6.094 8,760’ 10,999’ TUBING DETAIL 4-1/2” 12.75 L-80 8 rnd EUE 3.958 Surface 7,809’ 2-7/8” 6.4 L-80 IBT 2.441 7,810’ 7,927’ JEWELRY DETAIL No Depth (MD) Depth (TVD) OD ID Item 1 397’ 397’ 6.750” 3.813” TRSSSV – Giant Oil Tools – 5k-450-Blank 3.813” X Profile 2 1,995’ 1,911’ 5.570” 3.970” Chemical Injection Sub (2800psi Pop Pressure( 0psi tbg) 6300 psi POP pressure (3500 psi tbg) 3 5,025’ 4,639’ - - CIBP (06/15/25) 4 5,225’ 4,815’ - - CIBP (06/14/25) 5 7,807’ 7,089’ 5.250” 4-1/2” Float Collar w/ wiper plug landed 6 7,810’ 7,092’ 5.050” 2.441” 4-1/2” x 2-7/8” crossover 7 7,811’ 7,093’ 8.125” 4.250” 9-5/8” Baker Mod. D Permanent packer, ID = 4.75” (behind 2-7/8” float shoe) 8 7,929’ 7,197’ 3.700 2-7/8” Float Shoe 9 8,990’ 8,146’ - - Expandable Plug w/ 28’ of cement on top (12/16/24)ToC 8,962’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status LB-2 4,153’ 4,170’ 3,853’ 3,868’ 17’ 06/17/25 Open LB-1 4,211’ 4,225’ 3,905’ 3,917’ 14’ 06/17/25 Open A-0 4,277’ 4,291’ 3,964’ 3,976’ 14’ 06/16/25 Open A-0 4,299’ 4,309’ 3,983’ 3,992’ 10’ 06/16/25 Open A-1 4,384’ 4,404’ 4,060’ 4,078’ 20’ 06/16/25 Open Isolated Perf Details on Pg 2 Notes: 06/18/25: Tagged 3,500’ CEMENT DETAILS 13-3/8”17-1/2” hole: Cemented with 1200sxs.Assumed ToC to surface. 9-5/8” 12-1/4” Hole: Cemented with 1000sxs (215bbls) of (15.5ppg) class G cement with full returns. Assuming yield of 1.21 cuft/sxs, volumetric ToC should be at 4325’ MD. 1/13/67 CBL shows fully cemented up to 4200’ (stopped logging there) 4-1/2”Cemented with 280 bbls 15.3 ppg Class G with full returns. Bumped plug with 1800 psi (ToC 4-1/2” x 9-5/8” ~3,016’) 3,793’RA Tag 4,610’RA Tag 5,202’RA Tag _____________________________________________________________________________________ Revised By: JLL 06/25/25 SCHEMATIC Bruce Platform Well: Granite Pt St 17587 3 (Br 3-87) Completed: 12/29/24 PTD: 166-052 API: 50-733-20437-00-00 ISOLATED -- PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status A-7 5,040’ 5,046’ 4,652’ 3,757’ 6’ 06/14/25 Isolated (06/15/25) A-9 5,232’ 5,252’ 4,821’ 4,838’ 20’ 06/13/25 Isolated (06/14/25) C-1 9,015' 9,035' 8,169' 8,187' 20 7/18/2008 Isolated (12/16/24) 9,030' 9,050' 8,183' 8,201' 30 10/3/1999 Isolated (12/16/24) C-2 9,240' 9,310' 8,375' 8,439' 70 6/30/1972 Isolated (12/16/24) C-2X 9,240' 9260' 8,375' 8,393' 20’ 10/3/1999 Isolated (12/16/24) C-2 9,380' 9,400' 8,502' 8,520' 20 6/30/1972 Isolated (12/16/24) C-2X 9,390' 9,400' 8,511' 8,520' 10 10/3/1999 Isolated (12/16/24) C-3/4 9,480' 9,495' 8,592' 9,606' 15 6/30/1972 Isolated (12/16/24) C-5 9,580' 9,650' 8,682' 8,746' 70 6/30/1972 Isolated (12/16/24) C-7 10,045' 10,095' 9,119' 9,167' 50 6/30/1972 Isolated (12/16/24) 10,120' 10,130' 9,192' 9,202' 10 6/30/1972 Isolated (12/16/24) 10,150' 10,200' 9,221' 9,270' 50 6/30/1972 Isolated (12/16/24) 10,215' 10,270' 9,285' 9,339' 55 6/30/1972 Isolated (12/16/24) 10,290' 10,310' 9,359' 9,378' 20 6/30/1972 Isolated (12/16/24) C-8 10,432' 10,462' 9,499' 9,528' 30 6/30/1972 Isolated (12/16/24) 10,478' 10,578' 9,544' 9,643' 100 6/30/1972 Isolated (12/16/24) C-9 10,628' 10,715' 9,692' 9,778' 87 6/30/1972 Isolated (12/16/24) Well Name:GPF BR 03-87 API #:50733204370000 Field:Granite Point Field Permit #:166052 Sundry #:324-681 12/16/2024 12/17/2024 12/18/2024 12/19/2024 12/20/2024 12/21/2024 12/22/2024 Well Operations Summary PJSM & permit. R/U back on well. RIH w/ 2-1/2" Dump bailer. Could not pass 7602' MD. POOH. RIH w/ 2.70" gauge ring & spangs. No issue at 7602' MD. Tag TOC at 8985' MD. POOH. Reran 2-1/2" Dump bailer. Still could not pass 7602' MD. POOH. Made 3 runs w/ 2" x 30' dump bailer @ 3.9 gallons per run. TOC is now 8978' MD on top of expandable plug set at 8990' MD. Plan forward: 6 more runs w/ 2" Dump bailer to achieve 25'cement on top of plug. PJSM & PTW. Make 4 runs w/2'' OD x 30' bailer. Each bailer containing 3.9gal of cement. Made 6 bailer runs total (4 runs today) w/ a total of 23.4 gal of cement dumped on top of the expandable plug set at 8990' MD. TOC is now 8968' MD. Travel to platform. PJSM & permit. MIRU AK Eline. PT to 3000psi. Re-head. Prep plug. Set expandable plug in 7" casing at 8990'. RIH w/ 30' x 2" dump bailer. Dumped 3.5 gallons of shot pellets in plug-basket. RIH w/ 30' x 2" dump bailer. Dumped 3.9 gallons of cement on shot pellets. Secure equipment. SDFN. Plan forward: Allow 8-12 hour cure time for first cement dump. Continue dump bailer runs to achieve 25' TOC on top of plug. PJSM and permit. Dump bailer job temporarily postponed to be able to set plug on IRU 44-36. Secure equipment and well. Travel to Beluga. Plan forward: Continue dump bailer runs after IRU work. Continue with Eline dump bailing cmt. Made 2 runs dumping total of 7.8 gallons, Est TOC at 8962 ft., E-line RIH with 3 ft. tbg punch loaded with 7 gr. "0" deg phasing 4 SPF, tagged up at 8934 ft logged punch on depth, punch holes at 7,790' to 7,793 ft. rig down E-line, spotting 404 support equipment on deck. lay out and make up hoses on deck, plumb in 400 bbl tank to mix tank. Filling 400 bbls tank with FIW Continue to reverse circulate 600 bbl down IA taking returns from tbg. Monitor well, tbg still not balanced. Reverse circulate 75 bbls down IA taking returns from tbg, total of 675 bbls pumped shut down pump, tbg still not balanced. Pump 80 bbls of 8.8 ppg NaCl down tbg at 1.8 bpm. Final pressure at 50 psi and 115 psi on IA at the pipe line connection. Shut down pump ,total of 755 bbls pumped. T/IA- 0/115 psi- bleed down IA to "0", one bbl of clean fluid returned, well static. Set BPV nipple down tree. Clean hanger connection, make up blanking sub ,N/up 13-5/8 5m BOPE Daily Operations: Continue to rig up 404 circulating hose, modify tank suction lines, plumb mix tank lines. Complete boat transfers w/equipment. Mix 650 bbls of drill water to 8.6 ppg. Transfer to 400 bbl upright tank. pump 165 bbls to rig pit. Check T/ IA: 0/ 300 psi. Bleed off IA pressure and monitor. Break circulation down Tbg and Up IA- circulate 10 bbls. Swap over to reverse circulating and establish a rate of 1.8bpm at 50 psi. 40bbls pumped at time of report. Page 1 of 5 12/23/2024 12/24/2024 12/25/2024 12/26/2024 12/27/2024 12/28/2024 12/29/2024 12/30/2024 Deck management, preparations and equipment maintenance. Backload recovered completion equipment and offload 4-1/2'' completion equipment. Tier, tally and remove protectors from 4-1/2'' pipe. Prepare completion & shoetrack. MU 2-7/8'' x 119ft shoetrack c/w float shoe and float collar. PU and RIH w/ 4-1/2'' 12.75# L-80 EUE 8rd completion from surface to 1800' at time of report. Install 1 ea. 6.375'' floating centralizer on each jt. AOGCC Approval from B. McLellan for change in completion due to failed CMIT and a longer cemented shoe track, 12/26/24, 16:32.L/D 3.5'' tbg hgr and landing jt. POOH to surface and LD 257jts of 3-1/2'' N-80 Butt completion tbg. RU Eline unit and RIH w/ 8.25'' GR/JB tool string, tag packer at 7811'MD. MU and PU 9-5/8'' CBL tool string. Log free pipe near surface for calibration. RIH to 7935', Log up at 50fpm to 3500'. Lost communication with tool at 3500'. POOH and LD tool string. Cont. setup for MIT, Dress out Rig floor, fill surface line. Attempt CMIT as per Sundry to 2100 psi. Pressure up to 2300 psi on T& IA. 0 / 5 / 10 / 15 minute pressures: 2300 / 2150 / 2050 / 1950. Non passing CMIT. Contact OE for path forward and discussions with AOGCC. Wait on decisions and communications with AOGCC. PU on tbg hanger, pull seal assy out w/78k lbs. RU circulating equipment and forward circ 430bbls of 8.6 ppg NaCl. Monitor well. Continue to nipple up 13-5/8 BOPE, raise and scope derrick, Install floor, hand rails and access stairs to floor, P/up and make up test joint, fluid pack BOPE, fill test joint, had leak at the 11" 5m well head to riser flange, torque same, close annular, filling test joint the 11" 5m well head to riser flange leaking, lay down test joint, draining stack ,Break bolts on well head flange. PU BOPE from WH flange. Inspect ring grooves. Remove R54 gasket and install RX54 gasket. Set BOPE down and re-torque up flanged connection. Install 3-1/2'' TJ into blanking sub. Connection test BOPE to 250/3000 psi- good. Shell test BOPE. Complete BOPE testing as per AOGCC and Hilcorp expectations, 250/3000 psi for 5/5 min. Remove blanking sub and BPV. Swap over to 3-1/2'' landing jt. Prepare for CMIT. Continue to RIH w/4-1/2'' 12.75# L-80 EUE 8rd completion from 1800 to tag depth of 7817'MD, float shoe depth at 7936' MD. Prepare to space out completion string and land tbg hanger. Continue spaceout, POOH L/D 2 joints, p/u spaceout pups & M/U same, p/u hanger & landing joint, make up penetrations through hanger w/chem inj line & SSSV line. Land hanger, placing float shoe @7929', up wt 92k, dn wt 74k, R/U CMT head M/U CMT head & circ lines, fill pipe, PJSM for cmt job, PT lines 250/3200psi good, pump 280 bbls 15.3 cmt, drop plug pump 8.6 PPG brine displacement bump plug w/119 bbls (caculated) pressure up t/2300psi FCP=1800psi, hold pressure, good, bleed back check floats good. RD Cmt unit. Start rig down of 404. Scope down and lay down mast. Rig out floor. B/L CMT unit. Cont. Rig down aux Eq. N/D BOPE, N/U tree, test void 5k good, test tree 250/5000, good, pull TWC. secure well. RDMO 404 rig package Page 2 of 5 1/3/2025 1/4/2025 1/5/2025 1/6/2025 1/7/2025 4/9/2025 4/10/2025 4/11/2025 Wait on weather to fly out Slickline crew. Wait on weather to fly out Slickline crew Fly out SL crew. PTW/PJSM. Rig up Slickline on 03-87. PT PCE. RIH w/ 3.83" Nogo Centralizer. Tag TRSSSV at 397' KB. Pooh. RIH w/ 3.83" Nogo Centralizer, stem & flapper checker. Tag TRSSSV at same depth. Control line pressured up to 4900psi. Pick up and pulling a bind against the flapper. Sit back down. Cycle control line pressure multiple times. Still pulling a bind. Hand spang and shear pins to get up through the flapper. Pooh. Pins sheared on one side. RIH w/ 3.83" Nogo centralizer & 4-1/2" brush. Tag TRSSSV at same depth. Work brush across TRSSSV. See no control line pressure changes. Pooh. Re-run 3.83" Nogo Centralizer, stem & flapper checker. Tag at same nogo depth. Still pulling a bind against the flapper. Dump and re-apply control line pressure to 4900psi. No change. Hand spang and shear pins to get up through flapper. Pooh with pins sheared. Notify OE. Rig down SL. Will need to get a TRSSSV exercise tool from Giant Oil Tools. PJSM. Permit. PT PCE. SD in TRSV at 368' wlm with 4-1/2" braided line brush and 3.867" centralizer. Brush TRSV for 30 min. Exercise TRSV at 368' wlm, jar down to open flapper holding control line pressure. Pull bind and dump control line pressure. No indication of flapper closing. RIH with flapper checker to TRSV, all tattle tale pins intact, confirmed flapper open. RIH with flapper checker to TRSV, confirm open. RIH with 5' of stem to 450' below TRSV, PUH through flapper multiple times without issues. Travel from Steelhead to Bruce Platform. Permit with Ops. Stage AK Eline Unit. Prep to run CBL. RIH w/ 1.69" CBL Tools. Tag PBTD at 7760. Correlate to RA Tag at 5199'md. TOC in 4-1/2" x 9-5/8" Casing at ~ 3016'. Pooh. Pulled heavy at 650' (TRSSSV at 399' with 4500psi applied on control line). Able to freely RIH but keep tagging up at 650'. Attempt to pressure up opposite side control line labeled "CIM" incase they were labled wrong. Still unable to pull up past 650'. Cycle TRSSSV pressure. Still unable to pull past 650'. After multiple attempts to pull thru, the eline cable popped free. Pooh with only cable weight. Eline cable pulled ooh with 280' still on the counter. Appears the Eline cable parted on the TRSSSV leaving ~ 250' of 1/4" Eline cable + CBL Toolstring (30.83' oal). Rig down Eline equipment & prep to send to Tyonek. Call out SL crew & fishing tools. RIH with 3 prong wire grab, 4-1/2" wire finder, 4-1/2" bait sub on GR. Found eline at 7484' wlm. PUH to 7468' removing slack, then begin jarring on fish. GR sheared. RBIH with GR, latch bait sub at 7484' wlm, begin jarring on fish. GR sheared. Page 3 of 5 4/12/2025 4/13/2025 5/15/2025 5/16/2025 5/17/2025 5/18/2025 6/10/2025 6/11/2025 CTU 9 N2 Blowdown. T/I/O 1330/0/80 psi. PU Injector and MU tools, Stab on well and fluid pack reel. PT lubricator, Inner reel valve, inner and outer flowcross valves 250/3500 psi to complete BOP test requirements. No failures. Witness waived by Jim Regg. RIH w/ 2.20" OD CTC, stinger, and reverse-out nozzle. Tag @ 7775' CTM. PU to 7760' and come-online w/ N2 @ 640 scfm. Reverse out 45 bbls brine until dry N2 returns w/ 92,000 scf N2. SI Choke and POH. Final T/I/O 2148/0/80 psi. RD to MOBE to Dolly RDMO. CTU 9 N2 Blowdown. MOBE to platform. Offload boat, spot equipment and rig up. Shell Test and Test BOPE 250/3500 psi per Sundry. No failures. Witness waived by Jim Regg. SDFN. RIH with GS, latch bait sub at 7,484' wlm, begin jarring, POOH with fish. At surface, strip out 280' of eline and recover CBL toolstring. Drift at 3.60' gauge ring to 7,730' wlm. Drift 30' x 2.75" dummy guns to 7,728' wlm. RDMO. PTW/PJSM w/ Fox CTU 9 and Ops. MIRU on BR 03-87. PTW/PJSM w/ Fox and Ops Unable to get N2 pump or back up N2 pump working. RDMO from well. Send Eqiupment to shore for maintenance. 38 bbl remaining in the well to lift out. PTW/PJSM w/ Fox and Ops MIT-IA to 1500 psi Charted. Pass. Make up 2" CTC, 2.18"x5" Weight bar and 2.25" JSN Test BOP as per AOGCC sundry 250/3500 psi. Witness waived by Jim Regg. RIH Jet across SSSV from 300'-400'. Made 5 passes across SSSV. RIH reverse out Ňuid from the well. Recovered 100 BBL. N2 pump broke down. POOH. SDFN Page 4 of 5 6/13/2025 6/14/2025 6/15/2025 6/16/2025 6/17/2025 6/18/2025 PJSM/PTW. RIH w/ GPT. Tag at 4981'. Log up. Fluid level @ 4811'. Bleed WHP from 1270 to 60 psi. No water influx and minimal production. Pressure up to 1100 psi w/ N2 and RIH w/ Gun #7. Perforate LB1 4211 - 4225'. WHP increased to 1146 psi. Gun covered/filled w/ mud. RIH w/ GPT. Bled WHP from 1140 to 940 psi. Fluid level moved up to 4582'. RIH w/ Gun #8 17'. WHP 940 psi. Perforate LB2 4153 - 4170'. WHP increased to 957 psi. Gun covered/filled w/ mud. Bull plug dry. RIH w/ GPT. Well SI. Tag @ 4982'. FL @ 4534'. Bled WHP from 958 psi to 700 psi. Dynamic GPT pass. FL 4355' . Bled WHP to 275 psi and make static pass. No FL observed. Continue bleeding. Methane to surface @ 210 psi. Make dynamic pass @ 75 psi . Tag @ 4982'. No FL observed. Shut in well @ 34 psi and POH. Lay down and SDFN. PJSM/PTW. RIH w/ GPT. Note anomaly in Weight, Temp, and Pressure @ 3240'. Cont RIH. Pressure sensor appears plugged. Tag bridge @ 3300' and fell thru. Set down @ 3500'. Tool dropping slowly. 500 Lbs over to pull free. POH. Unable to identify definitve FL. Decision made to cancel further perforations. Rig down. End Job. Asset team evaluated project, the well did not produce from the target intervals and will remain shut in, foregoing the final MIT-IA performed within 30 days of stabilized production. AOGCC Approval M. Rixse to perforate 5/15/25, 10:27. AK E-Line Perforate. MOBE crew and N2 Equipment to platform. PJSM/PTW. MIRU. PT 250/3500 psi. RIH w/ gun #1 20' x 2-3/4" Geo Razor 6 spf, 60* Phsg. Bled WHP to 1512 psi. Perforate A9 5232 - 5252'. POH. Gun dry. RIH w/ GPT. Tag @ 7778' WLM. Fluid level @ 7760. WHP 1500 psi. Bleed N2 to tank to 3 psi WHP. Fluid level remained @ 7755'. SI well and POH. Monitor build-up rate. SDFN PTW/PJSM. SITP 20 psi. RU AK E-Line. RIH w/ 3.75" gauge ring on spangs and tag @ 4,121'. RIH w/ 3.54" gauge ring and drift to 5,283' (no tag). RIH w/ CIBP and set @ 5,225'. PT N2 pump and hardline to 4000 psi. Pressure up well to 1500 psi. RIH w/ 2' x 2 3/4" 6SPF 60 deg guns and perf A7 (5,040' - 5,046'). RIH w/ GPT and saw no fluid level, tagged CIBP @ 5,225'. PU above perfs and bleed N2 checking periodically for water influx and LEL's. Saw no water influx or LEL's but tagged ~100' high after bleeding to 300 psi on tubing. POOH, secure well, and SDFN. PTW/PJSM. SITP 340 psi. RU AK E-Line. RIH w/ CIBP, set @ 5,025' and confirm set w/ tag. RIH w/ 20' x 2 3/4" 6SPF 60deg guns and pressure up well to 1350 psi w/ N2. Perforate A1 (4,384' - 4,404'). RIH w/ GPT and did not see fluid level, tagged CIBP @ 5,025'. PU above perfs and bleed well to zero while checking periodically for water/fill influx and LEL's. Saw LEL's @ 160 psi and final tag was 5,000' (25' high) w/ no water. Leave well shut in, POOH, and secure well for night. PTW/PJSM. SITP 0 psi. RU AK E-Line. RIH w/ 10' x 2 3/4" 6SPF 60deg guns, tag @ 5,000' and pressure up well to 1300 psi w/ N2. Perforate A0 (4,299' - 4,309'). RIH w/ GPT and did not see fluid level, tagged fill @ 4,988'. PU above perfs and bleed well to 425 psi while checking periodically for water/fill influx and LEL's. Saw no LEL's and final tag was 4,982' with fluid level @ 4,930'. POOH w/ GPT and RIH w/ 16' x 2 3/4" 6SPF 60deg guns, pressure up well to 1300 psi w/ N2 and re-perf A1 (4,384' - 4,400'). Peforate A0 4277 - 4291'. POH and SDFN. Page 5 of 5 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: 7/15/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250715 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF BCU 14B 50133205390200 222057 6/20/2025 AK E-LINE Perf BR 03-87 50733204370000 166052 6/15/2025 AK E-LINE Perf BRU 211-35 50283201890000 223050 6/2/2025 AK E-LINE Perf BRU 213-26 50283201920000 223069 6/23/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/4/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/22/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/12/2025 AK E-LINE PPROF BRU 241-23 50283201910000 223061 6/10/2025 AK E-LINE Cement/Perf BRU 241-23 50283201910000 223061 6/19/2025 AK E-LINE CIBP BRU 241-23 50283201910000 223061 6/21/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 6/4/2025 AK E-LINE PlugPerf KBU 43-07Y 50133206250000 214019 6/17/2025 AK E-LINE Perf KU 41-08 50133207170000 224005 6/24/2025 AK E-LINE Plug Perf LIS L5-26 50029220790000 190110 6/21/2025 AK E-LINE Patch MRU M-25 50733203910000 187086 6/17/2025 AK E-LINE CIBP PBU 15-14A 50029206820100 204222 6/3/2025 BAKER SPN PBU 18-15C 50029217550300 211172 6/12/2025 AK E-LINE CBL/Perf PBU F-38B 50029220930300 225029 6/12/2025 BAKER MRPM SRU 241-33B 50133206960000 221053 5/25/2025 AK E-LINE CIBP Please include current contact information if different from above. T40659 T40660 T40661 T40662 T40663 T40664 T40664 T40664 T40665 T40665 T40665 T40665 T40666 T40667 T40668 T40669 T40670 T40671 T40672 T40673 BR 03-87 50733204370000 166052 6/15/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.16 10:52:24 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Casey Morse Cc:Juanita Lovett; Eric Dickerman; Dan Marlowe Subject:20250515 1024 APPROVAL to reduce perf interval Granite Pt St 17587 03 (Bruce 03-87) 324-681 PTD 166-052 Date:Thursday, May 15, 2025 10:27:28 AM Casey, Hilcorp is approved to perforate as described below. Thank you for the notice. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Thursday, May 15, 2025 9:49 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Eric Dickerman <Eric.Dickerman@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: Granite Pt St 17587 03 (Bruce 03-87) 324-681 PTD 166-052 Mel, Sundry 324-681 for the Bruce 03-87 well (PTD 166-052) has conditions stating “Submit [9-5/8” casing] CBL to AOGCC prior to perforating” and “AOGCC approval of Cement Evaluation Log required” in the procedure section regarding the cement for the new 4-1/2” completion. Attached is the email I had previously sent to Bryan with the 9-5/8” casing CBL. Also attached is the CBL from the 4-1/2” completion. These logs were also provided to AOGCC with submittal T39963 and T39965. Based on the performance from our recent gas tests on an offset well at the Anna platform, we are electing to bypass the “E-line Perf procedure (deep sands)” for now and plan to move forward with the perforations of the shallow sands only ±3,940’ - ±5,325’ MD (±3,662’ - ±4,900’ TVD). Coil is rigging up today to start the N2 blowdown and obtain the MIT-IA. Eline should be heading out mid-next week for the perforations. Please let me know if we are good to proceed with the perfs. Thank you, Casey Morse Operations Engineer Cook Inlet Offshore Hilcorp Alaska, LLC (907) 777-8322 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: 2/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250220 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 18RD 50133205840100 222033 1/27/2025 AK E-LINE Patch BRU 223-24 50283201830000 221072 1/26/2025 AK E-LINE Perf CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf KU WD-01 50133203450000 181107 10/15/2024 YELLOWJACKET PERF MPI 1-29 50029216690000 186181 1/29/2025 AK E-LINE Perf MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch MRU A-13 50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf NCIU A-21 50883201990000 224086 1/15/2025 AK E-LINE Plug, Perf NK-41A 50029227780100 197158 1/6/2025 HALLIBURTON Coilflag PAVE 3-1 50029238060000 224140 1/4/2025 YELLOWJACKET CBL PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T40127 T40128 T40129 T40130 T40131 T40132 T40133 T40134 T40135 T40136 T40137 T40138 T40139 T40140 T40141 T40142 T40143 T40144 T40145 T40146 T40147 GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.20 14:09:18 -09'00' 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: 1/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240116 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 09A 50133204450100 224113 10/26/2024 YELLOWJACKET SCBL BCU 12A 50133205300100 214070 8/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 233-23T 50283202000000 224088 12/28/2024 AK E-LINE PPROF BRU 233-27 50283100260000 163002 12/31/2024 AK E-LINE PPROF BRU 243-34 50283201240000 208079 12/27/2024 AK E-LINE PPROF GP 03-87 50733204370000 166052 12/25/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/16/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/21/2024 AK E-LINE Perf GP BR-03-87 50733204370000 166052 1/3/2025 AK E-LINE CBL IRU 44-36 50283200890000 193022 1/3/2024 AK E-LINE Depth Determination/Plug IRU 44-36 50283200890000 193022 12/26/2024 AK E-LINE DepthDetermination KU 31-07X 50133204950000 200148 12/3/2024 AK E-LINE Perf MPU B-21 50029215350000 186023 1/4/2025 AK E-LINE PlugSettingRecord MPU H-08B 50029228080200 201047 12/28/2024 AK E-LINE Welltech MRU G-01RD 50733200370100 191139 12/12/2024 AK E-LINE IPROF MRU G-01RD 50733200370100 191139 12/18/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/3/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/19/2024 AK E-LINE Perf PBU 01-37 50029236330000 219073 11/23/2024 HALLIBURTON PPROF PBU 06-05 50029202980000 178020 12/21/2024 HALLIBURTON RBT PBU 06-19B 50029207910200 224095 12/11/2024 HALLIBURTON RBT PBU 11-38A 50029227230100 198216 11/27/2024 HALLIBURTON TEMP PBU 14-31A 50029209890100 224090 11/11/2024 HALLIBURTON RBT PBU L-103 50029231010000 202139 11/25/2024 HALLIBURTON IPROF PBU M-207 50029238070000 224141 12/25/2024 HALLIBURTON RBT PBU P2-55 50029222830000 192082 12/5/2024 HALLIBURTON PPROF PBU S-15 50029211130000 184071 11/18/2024 HALLIBURTON RBT TBU M-25 50733203910000 187086 12/13/2024 AK E-LINE Perf T39958 T39959 T39960 T39961 T39962 T39963 T39964 T39964 T39965 T39966 T39966 T39967 T39968 T39969 T39970 T39970 T39971 T39971 T39972 T39973 T39974 T39975 T39976 T39977 T39978 T39979 T39980 T39981 GP BR-03-87 50733204370000 166052 1/3/2025 AK E-LINE CBL GP 03-87 50733204370000 166052 12/25/2024 AK E-LINE CBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.16 13:56:40 -09'00' 1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Thursday, December 26, 2024 4:32 PM To:Dan Marlowe; Casey Morse Cc:Juanita Lovett Subject:RE: [EXTERNAL] Re: Granite Pt St 17587 03-87 PTD# 166-052 Attachments:Br 03-87 Schematic 2024-12-26 proposed REV D.pdf Dan, Casey, I missed that on the original diagram. This plan makes sense. Hilcorp has approval to proceed with the plan as described below and as shown in the diagram. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Thursday, December 26, 2024 3:50 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Casey Morse <Casey.Morse@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] Re: Granite Pt St 17587 03-87 PTD# 166-052 Jumping in here since I helped work out the design with our wellsite lead See attached schematic Schematic shows the cartoon of what we intend but we can work toward a tally when we get completion on site. This schematic in fact shows exactly what you mention for the exact reasons you mention. The cementing dart and plug will both be 4-1/2 and we will keep a 4-1/2” float collar (item #4) up above the crossover so that part of the system will work as designed. Then we will cross over (item #5) below the float collar, run a few sticks or the 2-7/8 and then the float shoe (item #7). We will space it out so that the existing packer body will be mid joint on a 2-7/8” so we have plenty of flow through for the cement. Thanks 2 Dan From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, December 26, 2024 3:39 PM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] Re: Granite Pt St 17587 03-87 PTD# 166-052 Casey, Can you send me a proposed tubing tally that details the proposed shoe track? If you drop a dart that seats in 2-7/8”, it’s going to allow bypass as you pump it down through 4-1/2” and then end up contaminating cement and a wet shoe. You’d be better off having the float collar up above the 4-1/2” x 2-7/8” x/o. You could place the float in the 2-7/8” as shown in your diagram, then have a few joints of 2-7/8 pipe run through the packer, then one joint of 4-1/2” pipe above the packer, then 4-1/2” float collar at 7770’ and still have room to perf at 7760’. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Thursday, December 26, 2024 2:08 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] Re: Granite Pt St 17587 03-87 PTD# 166-052 Bryan, thank you for your response last night. Since our email exchange, we were able to unseat the hanger, and it appears that the seals and tubing tail freely disengaged from the packer. This creates another option to get a longer cemented shoe track without covering up prospective gas pay. I attached a proposed schematic for a new completion design that would get >75’ cement isolation in the tubing and casing and leave open the B-2 sand to test for gas pay. Our analysis for the probability of success of the B-2 sand does not justify additional expenses associated with milling up the packer, and setting a 75’ shoe track above the packer would require us to bypass this zone. We are on track to run the CBL tonight, so we will know more of our forward plans based on those results. Regardless, it would be great to know if we should begin to secure parts for the attached completion CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 3 design, so we can get those in position and keep the operation moving forward if the CBL shows good results. Does the attached design sufficiently address the conditions of approval you outlined below? Thank you, Casey Morse From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, December 25, 2024 8:24 PM To: Casey Morse <Casey.Morse@hilcorp.com> Subject: Re: [EXTERNAL] Re: Granite Pt St 17587 03-87 PTD# 166-052 Casey, you’ll need 75’ or more in the float shoe. If you don’t have the space for that , plan to mill up the packer and place plug as deep as possible with 75 ft+ of cement in the shoe. Your plan is approved with this condition. Regards Bryan Regards. Sent from my iPhone On Dec 25, 2024, at 8:14 PM, Casey Morse <Casey.Morse@hilcorp.com> wrote: Sundry attached. From: Casey Morse Sent: Wednesday, December 25, 2024 4:41 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] Re: Granite Pt St 17587 03-87 PTD# 166-052 Bryan, I just looked through the tubing tally again. The top of the seal assembly is at 7824’. The deepest set of perfs we were hoping to target is 7722-7752’. All the perforations will be dependent on the quality of cement we see in the CBL, and we’d love to get the CBL and some additional logs to tighten up the depths before committing to the length of the shoe track. Are you ok with us pulling the tubing, running the CBL, and then we can discuss the completion design from there? Thanks, Casey From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Wednesday, December 25, 2024 12:56 PM CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 4 To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] Re: Granite Pt St 17587 03-87 PTD# 166-052 We have potential gas zones identified down to ~7760’, so we were hoping to keep that shoe track as short as possible to reduce the amount of pay we bypass. Casey From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, December 25, 2024 12:43 PM To: Casey Morse <Casey.Morse@hilcorp.com> Subject: [EXTERNAL] Re: Granite Pt St 17587 03-87 PTD# 166-052 Casey, can you add some length to the shoe track so it’s more than 10’ of cement? Can you make it 80’ long with two joints between float and landing collar? Sent from my iPhone On Dec 25, 2024, at 12:19 PM, Casey Morse <Casey.Morse@hilcorp.com> wrote: Bryan, We got our BOP rigged up and tested on the Bruce 03-87 and then failed our CMIT against the basket plug set below the tubing tail as part of Sundry 324-681. The pressure bled down linearly from 2250 to 2000 psi over 15 minutes, so it appears to be a steady slow leak. The likely cause is a failed barrier at the basket plug we set on 12/16. That was a 7” expandable plug set at 8990’ with 10 x 3.9-gal bailer runs dropped on top. The theoretical cement top above that plug should be 8962’. We tagged at 8934’ on 12/20. We did obtain a successful CMIT with a packoff set in the tubing tail on December 3. Below is a snapshot of the service report from 12/3. I’m confident that our leak is below the packer. It appears we have reduced the flowpath to the perfs, but we did not fully seal it off with the expandable plug and dump bailer. Could we please change the procedure forward and set a 9-5/8” CIBP above the packer (approx. 7750’) after we remove the tubing? Following that, we would obtain a MIT against the casing and 9-5/8” CIBP. The new completion design would tag the CIBP, space out, and land the tubing as deep in the well as possible with a 10’ pup between the float shoe and float collar, so we will have >10’ of cemented pipe on bottom as part of the completion. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 5 Please let me know if we can proceed as described, or if you need any additional information on this. Thank you for looking over this on Christmas Day. I hope you are enjoying your Christmas otherwise! Thanks, Casey Morse <image001.png> Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. <BR 03-87 AOGCC 10-403 324-681 PTD 166-052 Approved 12-18-24.pdf> The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this 6 email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. _____________________________________________________________________________________ Revised By: DEM 2024-12-26 PROPOSED Bruce Platform Well: Granite Pt St 17587 3 (Br 3-87) Completed: 7/21/08 PTD: 166-052 API: 50-733-20437-00-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 20 133 K-55 18.73 Surf 589’ 13-3/8”54.5 J-55 8 rd, ST&C 12.515 Surf 2,092’ 9-5/8” 43.5 S-95 ERW ST&C 8.755 Surf 52’ 40 N-80 Buttress 8.835 52’4,676’ 40 S-95 ERW ST&C 8.835 4,676’6,696’ 43.5 S-95 ERW ST&C 8.755 6,696’8,178’ 7” 32 N-80 Butt.6.094 7,925’8,014’ 29 S-95 ST&C 6.184 8,014’8,760’ 32 N-80 Butt.6.094 8,760’10,999’ TUBING DETAIL 4-1/2”12.75 L-80 8 rnd EUE Surface ±7,800’ 2-7/8”8 rnd EUE ±7,800’±7,900’ JEWELRY DETAIL No Depth (MD) Depth (TVD) OD ID Item 1 ±350’±350’6.750”3.813”TRSSSV 2 ±2,000’5.570”3.970”Chemical Injection Valve 3 ±5,780’CIBP 4 ±7,770’4-1/2” Float Collar 5 ±7,800’4-1/2” x 2-7/8” crossover 6 7,810’7,092'8.125”4.250”Packer, Permanent, Baker Mod. D (DPM) 7 ±7,900’3.750”2-7/8” Float Shoe 8 8,990’±8,147’Expandable Plug w/ 28’ of cement on top PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status Upper Gas ±3,940’±5,325’±3,662’±4,900 ±1,385 Future Future Lower Gas ±5,801’±7,760’±5,300’±7,048’±1,959’Future Future C-1 9,015'9,035'8,169'8,187'20 7/18/2008 Isolated 9,030'9,050'8,183'8,201'30 10/3/1999 Isolated C-2 9,240'9,310'8,375'8,439'70 6/30/1972 Isolated C-2X 9,240'9260'8,375'8,393'20’10/3/1999 Isolated C-2 9,380'9,400'8,502'8,520'20 6/30/1972 Isolated C-2X 9,390'9,400'8,511'8,520'10 10/3/1999 Isolated C-3/4 9,480'9,495'8,592'9,606'15 6/30/1972 Isolated C-5 9,580'9,650'8,682'8,746'70 6/30/1972 Isolated C-7 10,045'10,095'9,119'9,167'50 6/30/1972 Isolated 10,120'10,130'9,192'9,202'10 6/30/1972 Isolated 10,150'10,200'9,221'9,270'50 6/30/1972 Isolated 10,215'10,270'9,285'9,339'55 6/30/1972 Isolated 10,290'10,310'9,359'9,378'20 6/30/1972 Isolated C-8 10,432'10,462'9,499'9,528'30 6/30/1972 Isolated 10,478'10,578'9,544'9,643'100 6/30/1972 Isolated C-9 10,628'10,715'9,692'9,778'87 6/30/1972 Isolated Notes:1/20/17 - C/O fill to 9,650’ CEMENT DETAILS 13-3/8”17-1/2” hole: Cemented with 1200sxs.Assumed ToC to surface. 9-5/8” 12-1/4” Hole: Cemented with 1000sxs (215bbls) of (15.5ppg) class G cement with full returns. Assuming yield of 1.21 cuft/sxs, volumetric ToC should be at 4325’ MD. 1/13/67 CBL shows fully cemented up to 4200’ (stopped logging there) 1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Friday, December 13, 2024 2:04 PM To:Ryan Rupert Cc:Casey Morse; Aaron Douget; Dan Marlowe; Juanita Lovett; Darcy Dunbar - (C); Howard Hooter - (C); Roby, David S (OGC); Davies, Stephen F (OGC); Dewhurst, Andrew D (OGC) Subject:RE: Granite Pt St 17587 03-87 (Permit 166-052, Sundry 324-681) Ryan, Hilcorp has verbal approval to complete the scope of work listed below as part of sundry 324-681. Wait for further approval before completing the remaining scope in the sundry. Condition of approval, provide 48 hrs notice for AOGCC opportunity to witness tag of TOC and CMIT TxIA to 2100 psi. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Friday, December 13, 2024 1:31 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Casey Morse <Casey.Morse@hilcorp.com>; Aaron Douget <adouget@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Darcy Dunbar - (C) <Darcy.Dunbar@hilcorp.com>; Howard Hooter - (C) <Howard.Hooter@hilcorp.com> Subject: Granite Pt St 17587 03-87 (Permit 166-052, Sundry 324-681) Bryan- Per our conversation, Hilcorp seeks verbal approval to proceed with the pre-RWO scope as written in the sundry submittal (copied below). Please advise. Thank you. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907-777-8300 Fax: 907-777-8580 June 3, 2022 Mr. Chris Wallace, Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 2021 Annual Disposal Report for Granite Point State 17587 03-87 (DIO 19) Dear Mr. Wallace: In accordance with DIO 19 rule 5, attached is a plot, and associated data, of tubing and casing pressures, and injection rates for well Granite Point St 17587 03-87 (Br 3-87, PTD # 166-052) for the year 2021. No fluid was injected into Granite Point State 17587 03-87 in 2021. It is currently shut in due to TxIA communication. Should you have questions, please contact Meredyth Richards at 777-8430 or Josh Allely at 777-8505. Sincerely, Meredyth Richards Reservoir Engineer Date Tubing IA OA OOA 12/31/2021 305 300 90 0 12/30/2021 305 300 90 0 12/29/2021 305 300 90 0 12/28/2021 305 300 90 0 12/27/2021 300 300 90 0 12/26/2021 300 300 90 0 12/25/2021 300 300 90 0 12/24/2021 300 300 90 0 12/23/2021 300 300 90 0 12/22/2021 300 300 90 0 12/21/2021 300 300 90 0 12/20/2021 300 300 90 0 12/19/2021 300 300 90 0 12/18/2021 300 300 90 0 12/17/2021 300 300 90 0 12/16/2021 300 300 90 0 12/15/2021 300 300 90 0 12/14/2021 300 300 90 0 12/13/2021 305 300 90 0 12/12/2021 305 300 90 0 12/11/2021 305 300 90 0 12/10/2021 305 300 90 0 12/9/2021 305 300 90 0 12/8/2021 305 300 90 0 12/7/2021 305 300 90 0 12/6/2021 305 300 90 0 12/5/2021 305 300 90 0 12/4/2021 315 300 90 0 Date Range: 01/01/2021 - 12/31/2021 Well: BR 03-87 Desc: Shut-In Permit to drill: 1660520 Admin Approval: DIO #19 API: 50-733-20437-00-00 12/3/2021 305 300 90 0 12/2/2021 305 300 90 0 12/1/2021 305 300 90 0 11/30/2021 300 300 90 0 11/29/2021 300 300 90 0 11/28/2021 300 300 90 0 11/27/2021 300 300 90 0 11/26/2021 300 300 90 0 11/25/2021 300 300 90 0 11/24/2021 300 300 90 0 11/23/2021 300 300 90 0 11/22/2021 300 300 90 0 11/21/2021 300 300 90 0 11/20/2021 300 300 90 0 11/19/2021 300 300 90 0 11/18/2021 300 300 90 0 11/17/2021 300 300 90 0 11/16/2021 300 300 90 0 11/15/2021 300 300 90 0 11/14/2021 300 300 90 0 11/13/2021 300 300 90 0 11/12/2021 300 300 91 0 11/11/2021 300 300 90 0 11/10/2021 300 300 91 0 11/9/2021 300 300 90 0 11/8/2021 300 295 90 0 11/7/2021 300 295 90 0 11/6/2021 300 295 90 0 11/5/2021 300 290 90 0 11/4/2021 300 295 90 0 11/3/2021 300 300 90 0 11/2/2021 300 300 90 0 11/1/2021 300 300 90 0 10/31/2021 300 300 90 0 10/30/2021 300 300 90 0 10/29/2021 300 300 90 0 10/28/2021 300 300 90 0 10/27/2021 300 300 90 0 10/26/2021 300 300 90 0 10/25/2021 300 300 90 0 10/24/2021 300 300 91 0 10/23/2021 300 300 90 0 10/22/2021 300 300 91 0 10/21/2021 300 300 91 0 10/20/2021 300 300 90 0 10/19/2021 300 300 90 0 10/18/2021 305 300 90 0 10/17/2021 305 300 90 0 10/16/2021 305 300 90 0 10/15/2021 305 300 90 0 10/14/2021 305 300 90 0 10/13/2021 305 300 90 0 10/12/2021 305 300 90 0 10/11/2021 305 300 90 0 10/10/2021 305 300 90 0 10/9/2021 305 300 90 0 10/8/2021 305 300 90 0 10/7/2021 305 300 90 0 10/6/2021 300 300 90 0 10/5/2021 300 300 90 0 10/4/2021 300 300 90 0 10/3/2021 300 300 90 0 10/2/2021 300 300 90 0 10/1/2021 300 300 90 0 9/30/2021 300 300 90 0 9/29/2021 300 300 90 0 9/28/2021 300 300 90 0 9/27/2021 300 300 90 0 9/26/2021 300 300 90 0 9/25/2021 300 300 91 0 9/24/2021 300 300 90 0 9/23/2021 300 300 90 0 9/22/2021 300 300 91 0 9/21/2021 300 300 90 0 9/20/2021 300 300 90 0 9/19/2021 300 300 90 0 9/18/2021 300 300 90 0 9/17/2021 300 300 90 0 9/16/2021 300 300 90 0 9/15/2021 300 300 90 0 9/14/2021 300 300 90 0 9/13/2021 300 300 90 0 9/12/2021 300 300 90 0 9/11/2021 300 300 90 0 9/10/2021 300 300 90 0 9/9/2021 300 300 90 0 9/8/2021 300 300 90 0 9/7/2021 300 300 90 0 9/6/2021 300 300 90 0 9/5/2021 300 300 90 0 9/4/2021 300 300 90 0 9/3/2021 300 300 90 0 9/2/2021 300 300 90 0 9/1/2021 300 300 90 0 8/31/2021 300 300 92 0 8/30/2021 300 300 90 0 8/29/2021 300 300 90 0 8/28/2021 300 300 90 0 8/27/2021 300 300 90 0 8/26/2021 300 300 90 0 8/25/2021 300 300 90 0 8/24/2021 300 300 90 0 8/23/2021 300 300 90 0 8/22/2021 300 300 90 0 8/21/2021 300 300 90 0 8/20/2021 300 300 90 0 8/19/2021 300 300 90 0 8/18/2021 300 300 90 0 8/17/2021 300 300 90 0 8/16/2021 300 300 90 0 8/15/2021 300 300 90 0 8/14/2021 300 300 90 0 8/13/2021 300 300 90 0 8/12/2021 300 300 90 0 8/11/2021 300 300 90 0 8/10/2021 300 300 90 0 8/9/2021 300 300 90 0 8/8/2021 300 300 90 0 8/7/2021 300 300 90 0 8/6/2021 300 300 90 0 8/5/2021 300 300 90 0 8/4/2021 300 300 90 0 8/3/2021 300 300 90 0 8/2/2021 300 300 90 0 8/1/2021 300 300 90 0 7/31/2021 300 300 90 0 7/30/2021 300 300 90 0 7/29/2021 300 300 90 0 7/28/2021 300 300 90 0 7/27/2021 300 300 90 0 7/26/2021 300 290 90 0 7/25/2021 300 290 90 0 7/24/2021 300 290 90 0 7/23/2021 300 290 90 0 7/22/2021 300 290 90 0 7/21/2021 300 290 90 0 7/20/2021 300 290 90 0 7/19/2021 300 290 90 0 7/18/2021 300 300 90 0 7/17/2021 300 290 90 0 7/16/2021 300 300 90 0 7/15/2021 300 300 90 0 7/14/2021 300 295 90 0 7/13/2021 300 300 90 0 7/12/2021 300 300 90 0 7/11/2021 300 300 92 0 7/10/2021 300 300 93 0 7/9/2021 300 300 90 0 7/8/2021 310 300 90 0 7/7/2021 310 300 90 0 7/6/2021 310 300 90 0 7/5/2021 310 300 90 0 7/4/2021 305 300 90 0 7/3/2021 305 300 90 0 7/2/2021 310 300 90 0 7/1/2021 305 300 90 0 6/30/2021 305 300 90 0 6/29/2021 305 300 90 0 6/28/2021 310 300 90 0 6/27/2021 305 300 90 0 6/26/2021 305 300 90 0 6/25/2021 310 300 90 0 6/24/2021 305 300 90 0 6/23/2021 310 300 90 0 6/22/2021 305 300 90 0 6/21/2021 315 300 90 0 6/20/2021 315 300 90 0 6/19/2021 315 300 90 0 6/18/2021 315 300 90 0 6/17/2021 315 300 90 0 6/16/2021 315 300 90 0 6/15/2021 315 300 90 0 6/14/2021 315 300 90 0 6/13/2021 315 300 90 0 6/12/2021 315 300 90 0 6/11/2021 315 300 90 0 6/10/2021 315 300 90 0 6/9/2021 315 300 90 0 6/8/2021 315 300 90 0 6/7/2021 315 300 90 0 6/6/2021 310 300 90 0 6/5/2021 315 300 90 0 6/4/2021 315 300 90 0 6/3/2021 320 300 90 0 6/2/2021 315 300 90 0 6/1/2021 320 300 90 0 5/31/2021 320 300 90 0 5/30/2021 320 300 90 0 5/29/2021 320 300 90 0 5/28/2021 320 300 90 0 5/27/2021 320 300 90 0 5/26/2021 320 300 90 0 5/25/2021 320 300 90 0 5/24/2021 320 300 90 0 5/23/2021 320 300 92 0 5/22/2021 325 300 90 0 5/21/2021 325 300 90 0 5/20/2021 325 300 90 0 5/19/2021 325 300 90 0 5/18/2021 325 300 90 0 5/17/2021 325 300 90 0 5/16/2021 325 300 90 0 5/15/2021 325 300 90 0 5/14/2021 325 300 90 0 5/13/2021 325 300 90 0 5/12/2021 325 300 90 0 5/11/2021 325 300 90 0 5/10/2021 325 300 90 0 5/9/2021 325 300 90 0 5/8/2021 325 300 90 0 5/7/2021 320 300 90 0 5/6/2021 310 300 90 0 5/5/2021 320 300 90 0 5/4/2021 315 300 90 0 5/3/2021 325 300 90 0 5/2/2021 320 300 90 0 5/1/2021 325 300 90 0 4/30/2021 325 300 90 0 4/29/2021 325 300 90 0 4/28/2021 305 300 90 0 4/27/2021 305 300 90 0 4/26/2021 305 300 90 0 4/25/2021 305 300 90 0 4/24/2021 305 300 90 0 4/23/2021 305 300 90 0 4/22/2021 305 300 90 0 4/21/2021 305 300 90 0 4/20/2021 305 300 90 0 4/19/2021 305 300 90 0 4/18/2021 305 300 90 0 4/17/2021 305 300 90 0 4/16/2021 305 300 90 0 4/15/2021 325 300 90 0 4/14/2021 325 300 90 0 4/13/2021 325 300 90 0 4/12/2021 325 300 90 0 4/11/2021 325 298 90 0 4/10/2021 325 300 90 0 4/9/2021 310 300 90 0 4/8/2021 310 300 90 0 4/7/2021 310 300 90 0 4/6/2021 310 300 90 0 4/5/2021 310 300 90 0 4/4/2021 310 300 90 0 4/3/2021 310 300 90 0 4/2/2021 310 300 90 0 4/1/2021 310 300 90 0 3/31/2021 310 300 90 0 3/30/2021 310 300 90 0 3/29/2021 305 300 90 0 3/28/2021 320 300 90 0 3/27/2021 320 300 90 0 3/26/2021 320 300 90 0 3/25/2021 320 300 90 0 3/24/2021 320 300 90 0 3/23/2021 320 300 90 0 3/22/2021 320 300 90 0 3/21/2021 320 300 90 0 3/20/2021 320 300 90 0 3/19/2021 320 300 90 0 3/18/2021 320 300 90 0 3/17/2021 320 300 90 0 3/16/2021 320 300 90 0 3/15/2021 320 300 90 0 3/14/2021 320 300 90 0 3/13/2021 325 300 90 0 3/12/2021 325 300 90 0 3/11/2021 325 300 90 0 3/10/2021 325 300 90 0 3/9/2021 315 300 90 0 3/8/2021 320 300 90 0 3/7/2021 320 300 90 0 3/6/2021 325 300 90 0 3/5/2021 325 300 90 0 3/4/2021 325 300 90 0 3/3/2021 325 300 90 0 3/2/2021 325 300 90 0 3/1/2021 325 300 90 0 2/28/2021 325 300 90 0 2/27/2021 325 300 90 0 2/26/2021 325 300 90 0 2/25/2021 325 300 90 0 2/24/2021 325 300 90 0 2/23/2021 325 300 90 0 2/22/2021 325 300 90 0 2/21/2021 325 300 90 0 2/20/2021 325 300 90 0 2/19/2021 325 300 90 0 2/18/2021 325 300 90 0 2/17/2021 325 300 90 0 2/16/2021 325 300 90 0 2/15/2021 325 300 90 0 2/14/2021 325 300 90 0 2/13/2021 325 300 90 0 2/12/2021 325 300 90 0 2/11/2021 325 300 90 0 2/10/2021 325 300 90 0 2/9/2021 325 300 90 0 2/8/2021 325 300 90 0 2/7/2021 325 300 90 0 2/6/2021 325 300 90 0 2/5/2021 325 300 90 0 2/4/2021 325 300 90 0 2/3/2021 325 305 90 0 2/2/2021 325 310 90 0 2/1/2021 325 300 90 0 1/31/2021 325 300 90 0 1/30/2021 325 300 90 0 1/29/2021 325 300 90 0 1/28/2021 325 300 90 0 1/27/2021 325 300 90 0 1/26/2021 325 300 90 0 1/25/2021 325 300 90 0 1/24/2021 325 301 90 0 1/23/2021 325 300 90 0 1/22/2021 325 300 90 0 1/21/2021 325 300 90 0 1/20/2021 325 300 90 0 1/19/2021 325 300 90 0 1/18/2021 325 300 90 0 1/17/2021 325 300 90 0 1/16/2021 325 300 90 0 1/15/2021 325 300 90 0 1/14/2021 325 300 90 0 1/13/2021 325 300 90 0 1/12/2021 325 300 90 0 1/11/2021 325 300 90 0 1/10/2021 325 300 90 0 1/9/2021 325 300 90 0 1/8/2021 325 300 90 0 1/7/2021 325 300 90 0 1/6/2021 325 300 90 0 1/5/2021 325 300 90 0 1/4/2021 325 300 90 0 1/3/2021 325 300 90 0 1/2/2021 325 300 90 0 1/1/2021 325 300 90 0 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 Cut Tubing Other: Complete 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): 11,015 N/A Casing Collapse Structural Conductor 1,500psi Surface 1,130psi Intermediate Production 3,090psi Liner 8,610psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng CO 76B 12/18/2024 10,999'3,074' 3-1/2" 10,059' Model D Packer & N/A 7,810 (MD) 7,092 (TVD) & N/A 8,178' Perforation Depth MD (ft): 9,015 - 10,715 8,178' 7" 8,169 - 9,778 7,416'9-5/8" 20" 13-3/8" 589' 2,092' MD 3,060psi 2,730psi 588' 1,998' 589' 2,092' Length Size Proposed Pools: N-80 TVD Burst 7,870 5,750psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017587 166-052 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20437-00-00 Hilcorp Alaska, LLC Granite Pt St 17587 03-87 AOGCC USE ONLY 8,460psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Granite Point Middle Kenai Oil Undefined WDSP Granite Pt Gas 10,075 9,067 8,217 2,797psi N/A 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 2:02 pm, Dec 04, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.12.04 08:42:02 - 09'00' Dan Marlowe (1267) 324-681 DSR-12/16/24 10-404 SFD 12/6/2024 Workover rig BOP test to 3000 psi. Annular test to 2500 psi CT Unit BOP test to 3500 psi. Place 25' of cement on top of plug set ~5300' TVD. X Submit 4-1/2" & 9-5/8" CBL logs to AOGCC and obtain approval prior to perforating. Provide 48 hrs notice for AOGCC to witness MITIA to 1500 psi within 30 days after regular production begins. Perforate New Pool Yes for pre-RWO scope 12/13/24 Bryan McLellan BJM 12/17/24 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.18 10:01:35 -09'00'12/18/24 RBDMS JSB 121824 Recomplete for Gas HWO Well: Granite Point State 17587 3 (Bruce 03-87) Well Name:Granite Point State 17587 3 (Bruce 03-87) API Number:50-733-20437-00-00 Current Status:Offline Class II Disposal Injector (TxIA anncom) Leg:Leg #1 (North corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:166-052 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Worst Expected BHP:3,617 psi @ 8,207’ TVD (8.48ppg) Static BHP collected 12/1/24 Max. Potential Surface Pressure: 2797 psi Using 0.1 psi/ft Brief Well Summary Buce well 03-87 is a long term shut in injector. After showing signs of TxIA in 2017, the well was not easily fixable, so the company pivoted to a different well for Bruce injection needs. The well has sat idle since 2018. The well appears to have good/high cement behind the intermediate casing across potential gas sands. Bruce 03-87 is a good candidate to recomplete uphole and target gas production from the Granite Point Gas Pool. The goal of this project is to abandon the existing oil completion, and recomplete for uphole gas production Pertinent wellbore information: x Max inclination: 35 degrees x 1984: Most recent RWO. Current 3-1/2” tubing run x 2017: CT cleanout o Washed from 9067’ to 9406’ MD o Acidized above interval o Motor/mill from 9216’ – 9650’ MD o Perform 2nd acid job x Dec-2017: TxIA communication o Annulus pressures indicate TxIA communication o SL diagnostics find tubing hole o Patch run from 7,717 – 7,729’ SLMD o MIT-IA to 1850psi PASS x Feb-2018: Signs of TxIA again o Tubing hole found right on top of existing patch o SL extended patch from 7703’ – 7729’ MD now o MIT-T to 2000psi PASSED (plug at 7703’ MD) o MIT-IA to 1600psi PASSED x 2/14/18: o Well continues to pass MIT-IA’s, but TxIA pressures continue to show communication o Possible one way leak o Stopped repair effort, and pivoted to easier well for disposal Recomplete for Gas HWO Well: Granite Point State 17587 3 (Bruce 03-87) x 11/13/24 o MIT-IA failed (tubing pressures up) o Chip scale form 1800’ to top patch at 7709’ MD o MIT-T’s pass above 5500’ MD (fail below) o Pull patch assembly pre-RWO o Drift to 9067' MD with 2.74" gauge ring x 12/3/24 o Set TT plug at 7850’ SLMD. Attempt CMIT-TxIA FAIL o Pull (lots of scale) and reset TTP plug below packer.CMIT-TxIA to 2450psi PASS Pools in Bruce 03-87: x Top Granite Point Gas Pool: 3,409’ MD (3,185’ TVD) x Top Granite Point Middle Kenai Oil Pool: 8,990’ MD (8,147’ TVD) Pressures: x Open Granite Point Middle Kenai Oil Pool perfs (C-sands) o Past injection has left the open perfs close to normally pressured o 12/1/24 Static BHP showed 3617psi at 9057’ MD / 8207’ TVD (8.48ppg) o MPSP for pre-rig and RWO = 3617 – 820 = 2797psi x Proposed Granite Point Gas pool sands o Deepest proposed perf at 7,760’ MD / 7,048’ TVD o Ended the hole section in 1967 with an 11.1ppg mud o 11.1 ppg * 0.052 * 7,048 ft TVD = 4068 psi o 0.1 psi/ft * 7,048 ft TVD = 704 psi o MPSP from Gas Sands = 4068 – 704 = 3,364psi x Minimum offset LOT/FIT at or above these TVD’s: 14.3ppg at 3307’ TVD (Br 06-87) x The proposed deep gas perfs in Bruce 03-87 are from 5,300’ - 7,048’ TVD o 11.1 ppg * 0.052 * 7048 ft TVD = 4068 psi o 0.1 psi/ft * (7048 ft TVD – 5300 ft TVD) = 175 psi o 4068 psi – 175 psi = 3893 psi (at 5300’ ft TVD) o 3893 psi / 0.052 / 5300’ TVD =14.13ppg x The proposed shallow gas perfs in Bruce 03-87 are from 3,662’ - 4,900’ TVD o 11.1 ppg * 0.052 * 4900 ft TVD = 2828 psi o 0.1 psi/ft * (4900 ft TVD – 3662 ft TVD) = 124 psi o 2828 psi – 124 psi = 2704 psi (at 3662’ ft TVD) o 2704 psi / 0.052 / 3.662’ TVD = 14.2ppg 9-5/8” Cement (1967): x 12-1/4” hole x Openhole caliper averages >14” x Well cemented with 1000 sxs x Non-existent records on cement weight / yield x Only cement property notes are on SLB log from 1/13/67 indicating 15.5ppg cement x Assuming 15.5# cement, ToC could range from 4300’ MD (12.25” hole) to 6200’ MD (openhole caliper) x If cement was actually lighter, yield would be higher, and ToC could be as high as 1000’ MD x 1/13/67 CBL shows cement up to 4200’ MD (stopped logging there)1/13/67 CBL shows cement up to 4200’ MD (stopped logging there) Only cement property notes are on SLB log from 1/13/67 indicating 15.5ppg cement Recomplete for Gas HWO Well: Granite Point State 17587 3 (Bruce 03-87) Pre-RWO Procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 3000psi high 3. RIH and set expandable plug to abandon the Granite Point Middle Kenai Oil Pool a)Target set depth at ±8,990’ MD / ±8,147’ TVD (right at top pool) b) Given top fill at 9067’ MD / 8217’ TVD, only 35’ MD / 32’ TVD open perfs exposed today c) After set, lightly tag plug to confirm its set 4. RIH and dump bail 25’ cement on top of plug 5. RDMO EL 6. CMIT-TxIA to 2100psi a) 8147’ TVD * 0.25 = 2037psi b) Provide 48hrs notification to state for MIT witness RWO Procedure: 1. MIRU Hilcorp rig #404 2. Circulate / Bullhead kill well: a. Work over fluid will be 8.6ppg brine b. Ensure any wellbore fluids are fully displaced with KWF via circulation and bullheading c. WBV = 641 bbls i. Tubing above packer: 68 bbls ii. IA above packer: 500bbls iii. Casing + Liner below packer to 9650’ MD (top cleanout from 2017): 73 bbls 3. Set BPV / TWC, ND tree, NU BOP a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low / 3,000psi High / 2,500psi Annular c. BOP’s will be closed as needed to circulate the well d. Test to cover existing 3-1/2” tubing, plus new 4-1/2” tubing 4. Pull TWC / BPV 5. RIH and cut just above packer at ±7,800’ MD (7,083’ TVD) 6. POOH with 3-1/2” tubing 7. RU EL and obtain CBL of 9-5/8” casing 8. MU 4-1/2” completion a. SSSV at ±350’ MD b.Target bottom of completion at ±7,790’ MD / 7,074’ TVD (immediately above existing packer) c. Planning ~10’ shoe track, so new PBTD becomes ±7,780’ MD / 7,066’ TVD 9. RIH and land completion 10. Circulate 273bbls cement into 4-1/2” x 9-5/8” annulus a. Target ToC at ±2,900’ MD (2,727’ TVD) b.This brings ToC ±500’ MD above the top Granite Point Gas Pool at 3,409’ MD (3,185’ TVD) c. Adjust 4-1/2” x 9-5/8” ToC to within ±500’ MD of newly logged ToC behind 9-5/8” casing 11. ND BOP, NU tree and test 12. RDMO Cement evaluation log required. SFD Provide 48 hrs for AOGCC witness of CMIT-TxIA to 2100 psi. -bjm obtain CBL of 9-5/8” casing Submit CBL to AOGCC prior to perforating. -bjm Recomplete for Gas HWO Well: Granite Point State 17587 3 (Bruce 03-87) Post-Rig Procedure 1. Obtain CBL. Submit results to AOGCC 2. MIT-IA to 1500psi (charted) 3.MIRU Fox Energy offshore Coiled Tubing and pressure control equipment 4.PT lubricator to 250psi low / 3000psi high 5.RIH and blow well dry with nitrogen a.Reverse circulate water out of wellbore (no perforations, passing MIT’s) b. Estimated volume to recover = 118bbls 6.Once dry, trap N2 pressure on wellbore per OE 7.RDMO CT E-Line Perf procedure (deep sands) 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 3500psi high 3. Ensure CBL approval from AOGCC before perforating 4. RIH and perforate Deep Gas Sands from ±5,801’ - ±7,760’ MD (±5,300’ - ±7,048’ TVD) per RE/Geo 5. RDMO EL Will perf / monitor deep sand performance before moving uphole. If deep sands are to produce for more than 30 days, perform MIT-IA per below. E-Line Perf procedure (Shallow sands) 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 3500psi high 3. RIH and set CIBP within 50’ MD of top perf a. Deep perfs will be isolated via CIBP before any shallow perfs are shot b. If pressures and production dictate that deeper sands may remain open with upper sands, AOGCC approval will be needed before shooting upper sands with deep sands still open 4. RIH and perforate Shallow Gas Sands from ±3,940’ - ±5,325’ MD (±3,662’ - ±4,900’ TVD) per RE/Geo 5. RDMO EL 6. MIT-IA to 1500psi (charted) a. Once perforating is complete, perform MIT-IA within 30 days of stabilized production b. Will confirm cement packer / isolation from perfs to IA AOGCC approval will be needed before shooting upper sands with deep sands still open Provide 48 hrs notice for AOGCC opportunity to witness. -bjm Deep perfs will be isolated via CIBP before any shallow perfs are shot AOGCC approval of Cement Evaluation Log required. SFD Dump bail 25 ft of cement on top of plug. -bjm Provide 48 hrs notice for AOGCC witness. -bjm Ensure CBL approval from AOGCC before perforating Recomplete for Gas HWO Well: Granite Point State 17587 3 (Bruce 03-87) CONTINGENCY plug: (if any zone makes unwanted solids or water) 7. RU nitrogen to tubing and PT lines to 3500psi (or higher if needed) 8. Pressure up on tubing and displace water back into formation 9. MIRU E-line and pressure control equipment 10. PT lubricator to 250psi low / 3500psi high 11. Set 4-1/2” isolation plug or patch per OE 12. RDMO Nitrogen and EL CONTINGENCY CT Cleanout: (if any zone brings in excessive fill and needs to be cleaned out) 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 3500psi high 3. MU FCO BHA 4. RIH and cleanout to PBTD or as deep as practical a. Working fluid will be water (8.33ppg or greater) b. Take returns to surface up the CT x tubing annulus c. Add foam and nitrogen as necessary to carry solids to surface d. Can use GL to assist with hole cleaning 5. Once cleanout is completed, blow well down with nitrogen 6. RDMO CT Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Drawing (Hilcorp) 6. Fluid/Flow Diagrams (Hilcorp #404) 7. Fox CT BOP Diagram 8. Offshore Nitrogen procedure 9. RWO Sundry Change Form _____________________________________________________________________________________ Revised By: TDF 12/3/2024 SCHEMATIC Bruce Platform Well: Granite Pt St 17587 3 (Br 3-87) Completed: 7/21/08 PTD: 166-052 API: 50-733-20437-00-00 PBTD = 10,989’ TD = 11,015’ HOLE ANGLE thru Interval =qq C-1 3 1 20” Fill Tag @ 9,067 MD 11/13/2024 2 C-2 C-3,4 C-7 C-5 C-8 C-9 13-3/8" 9-5/8" 7" RKB to TBG Head = 42.80’ Tree connection: ?? CASING DETAIL Size Wt Grade Conn ID Top Btm 20 133 K-55 18.73 Surf 589’ 13-3/8” 54.5 J-55 8 rd, ST&C 12.515 Surf 2,092’ 9-5/8” 43.5 S-95 ERW ST&C 8.755 Surf 52’ 40 N-80 Buttress 8.835 52’ 4,676’ 40 S-95 ERW ST&C 8.835 4,676’ 6,696’ 43.5 S-95 ERW ST&C 8.755 6,696’ 8,178’ 7” 32 N-80 Butt. 6.094 7,925’ 8,014’ 29 S-95 ST&C 6.184 8,014’ 8,760’ 32 N-80 Butt. 6.094 8,760’ 10,999’ TUBING DETAIL 3-1/2” 9.2 N-80 ABC 2.992 42.8’ 7,870’ JEWELRY DETAIL No Depth (MD) Depth (TVD) OD ID Item 1 42.80’ 42.8' CIW Tubing Hanger, BPVP ? 2 7,810’ 7,092' - Packer, Permanent, Baker Mod. D (DPM) 7,824’ 7,105' 3.000 Locator, Baker 190-47 7,825’ 7,105' 3.000 Seal Assembly, Baker, 190-47 3 7,870’ 7,145' - Mule Shoe PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status C-1 9,015' 9,035' 8,169' 8,187' 20 7/18/2008 Open 9,030' 9,050' 8,183' 8,201' 30 10/3/1999 Open C-2 9,240' 9,310' 8,375' 8,439' 70 6/30/1972 Open C-2X 9,240' 9260' 8,375' 8,393' 20’ 10/3/1999 Open C-2 9,380' 9,400' 8,502' 8,520' 20 6/30/1972 Open C-2X 9,390' 9,400' 8,511' 8,520' 10 10/3/1999 Open C-3/4 9,480' 9,495' 8,592' 9,606' 15 6/30/1972 Open C-5 9,580' 9,650' 8,682' 8,746' 70 6/30/1972 Open C-7 10,045' 10,095' 9,119' 9,167' 50 6/30/1972 Open 10,120' 10,130' 9,192' 9,202' 10 6/30/1972 Open 10,150' 10,200' 9,221' 9,270' 50 6/30/1972 Open 10,215' 10,270' 9,285' 9,339' 55 6/30/1972 Open 10,290' 10,310'9,359' 9,378' 20 6/30/1972 Open C-8 10,432' 10,462'9,499' 9,528' 30 6/30/1972 Open 10,478' 10,578'9,544' 9,643' 100 6/30/1972 Open C-9 10,628' 10,715'9,692' 9,778' 87 6/30/1972 Open Notes: 1/20/17 - C/O fill to 9,650’ CEMENT DETAILS 13-3/8”17-1/2” hole: Cemented with 1200sxs.Assumed ToC to surface. 9-5/8” 12-1/4” Hole: Cemented with 1000sxs (215bbls) of (15.5ppg) class G cement with full returns. Assuming yield of 1.21 cuft/sxs, volumetric ToC should be at 4325’ MD. 1/13/67 CBL shows fully cemented up to 4200’ (stopped logging there) _____________________________________________________________________________________ Revised By: TDF 12/3/2024 PROPOSED Bruce Platform Well: Granite Pt St 17587 3 (Br 3-87) Completed: 7/21/08 PTD: 166-052 API: 50-733-20437-00-00 PBTD = 7,780’/ 7,083’ TVD TD = 11,015’ HOLE ANGLE thru Interval =qq C-1 4 5 20” TOC @ ± 2,900’ Fill Tag @ 9,067 MD 11/13/2024 3 C-2 C-3,4 C-7 C-5 C-8 C-9 13-3/8" 9-5/8" 7" 1 2 RKB to TBG Head = 42.80’ Tree connection: ?? CASING DETAIL Size Wt Grade Conn ID Top Btm 20 133 K-55 18.73 Surf 589’ 13-3/8” 54.5 J-55 8 rd, ST&C 12.515 Surf 2,092’ 9-5/8” 43.5 S-95 ERW ST&C 8.755 Surf 52’ 40 N-80 Buttress 8.835 52’ 4,676’ 40 S-95 ERW ST&C 8.835 4,676’ 6,696’ 43.5 S-95 ERW ST&C 8.755 6,696’ 8,178’ 7” 32 N-80 Butt. 6.094 7,925’ 8,014’ 29 S-95 ST&C 6.184 8,014’ 8,760’ 32 N-80 Butt. 6.094 8,760’ 10,999’ TUBING DETAIL 4-1/2” - - - - Surface ±7,790’ 3-1/2” 9.2 N-80 ABC 2.992 ±7,800’7,870’ JEWELRY DETAIL No Depth (MD) Depth (TVD) OD ID Item 1 ±350’ ±350’ TRSSSV 2 ±5,780’ CIBP 3 7,810’ 7,092' - Packer, Permanent, Baker Mod. D (DPM) 7,824’ 7,105' 3.000 Locator, Baker 190-47 7,825’ 7,105' 3.000 Seal Assembly, Baker, 190-47 4 7,870’ 7,145' - Mule Shoe 5 ±8,990’ ±8,147’ Expandable Plug w/ 25” of cement on top PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status Upper Gas ±3,940’ ±5,325’ ±3,662’ ±4,900 ±1,385 Future Future Lower Gas ±5,801’ ±7,760’ ±5,300’ ±7,048’ ±1,959’ Future Future C-1 9,015' 9,035' 8,169' 8,187' 20 7/18/2008 Isolated 9,030' 9,050' 8,183' 8,201' 30 10/3/1999 Isolated C-2 9,240' 9,310' 8,375' 8,439' 70 6/30/1972 Isolated C-2X 9,240' 9260' 8,375' 8,393' 20’ 10/3/1999 Isolated C-2 9,380' 9,400' 8,502' 8,520' 20 6/30/1972 Isolated C-2X 9,390' 9,400' 8,511' 8,520' 10 10/3/1999 Isolated C-3/4 9,480' 9,495' 8,592' 9,606' 15 6/30/1972 Isolated C-5 9,580' 9,650' 8,682' 8,746' 70 6/30/1972 Isolated C-7 10,045' 10,095' 9,119' 9,167' 50 6/30/1972 Isolated 10,120' 10,130' 9,192' 9,202' 10 6/30/1972 Isolated 10,150' 10,200' 9,221' 9,270' 50 6/30/1972 Isolated 10,215' 10,270' 9,285' 9,339' 55 6/30/1972 Isolated 10,290' 10,310' 9,359' 9,378' 20 6/30/1972 Isolated C-8 10,432' 10,462' 9,499' 9,528' 30 6/30/1972 Isolated 10,478' 10,578' 9,544' 9,643' 100 6/30/1972 Isolated C-9 10,628' 10,715' 9,692' 9,778' 87 6/30/1972 Isolated Notes:1/20/17 - C/O fill to 9,650’ CEMENT DETAILS 13-3/8”17-1/2” hole: Cemented with 1200sxs.Assumed ToC to surface. 9-5/8” 12-1/4” Hole: Cemented with 1000sxs (215bbls) of (15.5ppg) class G cement with full returns. Assuming yield of 1.21 cuft/sxs, volumetric ToC should be at 4325’ MD. 1/13/67 CBL shows fully cemented up to 4200’ (stopped logging there) Bruce Platform BR-17587-03 12/06/2017 Bruce Platform BR 3-87 Proposed 11/22/2024 BR 3-87 20 X 13 3/8 X 9 5/8 X 4 1/2 Tubing hanger, CIW-DCB-FBB-CCL, 11 X 4 ½ EUE lift X 4 ½ EUE susp, w/ 4'’ type H BPV profile, 6 ¼ EN neck Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M EFO, X-bottom prep Casing spool, OCT-22-BP, 21 ¼ 2M X 13 5/8 3M, w/ 2- 2 1/16 5M EFO, OO bottom prep Casing head, OCT-22, 21 ¼ 2M X SOW, w/ 2- 2 1/16 2M EFO 20'’ 13 3/8'’ 9 5/8'’ X2 control lines 4 ½’’ 404 BOP stack 10/09/2024 2.26' Riser 13 5/8 5M FE X 13 5/8 5M FE Spacer spool 13 5/8 5M FE X 11 5M Variable rams 2 7/8-5 4.54' 4.67' Choke and Kill valves 2 1/16 5M CIW-U 13 5/8-5000 Mud Cross 4 1/16 5M EFO Blind Rams 4.30'Hydril GK 13 5/8-5000 DSA 4 X 2DSA 4 X 2 HILCORP ALASKA, LLC KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary 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. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Granite Pt St 17587 03-87 (PTD 166-052)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Ryan Rupert To:Davies, Stephen F (OGC) Cc:McLellan, Bryan J (OGC); Dewhurst, Andrew D (OGC); Juanita Lovett; Ryan Rupert Subject:RE: [EXTERNAL] Granite Pt St 17587 03-87 (Permit 166-052, Sundry 324-681) - Request Date:Thursday, December 5, 2024 8:10:07 PM Attachments:Br_06-87_LOT(11-14-89).pdf Br_14-42_LOT(7-19-79).pdf Steve- I did some decent digging in the area, as I couldn’t find any FIT/LOT data on Br 03-87. I have all the drilling reports, and none of them mention conducting one. That seems common across most wells of that vintage on Bruce. Not sure if that means they weren’t done, or just not mentioned. I did find the below data Br 06-87 LOT at 14.3ppg attached (3307’ TVD) Br 14-42 LOT at 17.4ppg attached (3112’ TVD) Subject well Br 03-87: no LOT/FIT found for surface casing at 3185’ TVD Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Thursday, December 5, 2024 10:30 AM To: Ryan Rupert <ryan.rupert@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] Granite Pt St 17587 03-87 (Permit 166-052, Sundry 324-681) - Request Ryan, I’m reviewing Hilcorp’s Sundry Application to plug existing perforations and perforate new intervals in the Granite Pt St 17587 03-87. The LOT/FIT data presented in this application is from nearby well Br 06-87. I checked and AOGCC does do not have any record of that LOT/FIT in our files. Could Hilcorp please provide a copy for our records? Any other LOT/FIT information that Hilcorp could provide for Br 03-87, Br 06-87, and other wells near Br 03-87 would be greatly appreciated. Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Hilcorp Alaska, LLC July 1, 2020 Mr. Chris Wallace, Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, Alaska 99501 Dear Mr. Wallace: 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907-777-8322 Fax: 907-777-8580 RECEIVED JUL 0 6 2020 AOGCC In compliance of DIO 19 rule 5, attached is a plot, and associated data, of tubing / casing pressures and injection rates for well Granite Point St 17587-03 (Br 3-87 , PTD # 166- 052) for the year 2019. Last Mechanical Integrity test: 1/13/2018 Next MIT due: January 2022 No volumes were injected into Granite Point St 17587-03 in 2019. Should you have questions, please contact Matthew Hunter 777-8428 or Holly Tipton at 777-8330. Sincerely, Matthew Hunter Reservoir Engineer Attachment 1 — Br 3-87 Injection rates and pressures F. CQ M 4 C7 u m LL CL U c�l 0 r 1i 0 w 0 0 ,-4 0 Ln .17 0 m 0 0 cv I NE rn .-i 0 tV r'vl r+ Ch r -i v 0 e 0 rn r+ 0 ry rn 0 a cw p Oo Q 4 .�-i C? C=O rV CD Ch Y -w 0 ko F= 0 Ln in 0 cn 1-40 a en 0 r•� 0 rn CN rU CN C3 rn 0 c� co CD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a p p 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 rn rn rn rn rn rn rn rn rn rn rn rn m rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn o p N \ O O O O O O O O O O O O O O O O O O O O O O O O O O O O c -I ci ri ri ri ri ri -1 -1 c -I r -I ri ri -1 -1 -1 ri .--i c -I ri r -I ri ri ri -1 r1 -1 -1 m m m m m M m M M M M M M M M M m M M M M m m M m M M M M \ N c -I rnC3)a O O 4tO -1 rlj O O O O O O O O O O O O O O O O O O O O O O O O O O O O O p p \ m m Ill Vl m m to Ill m to Ln m Ill m Ln to m Ln m Ill Ln Ill Ill Ln m m m Ln O M M M M M M M M m M M M M M M M M M m M M M M M M M M M 0 ^ °n m o j c\i 0.7 1 � ' � � N O 7 � mO M r -I ;:A ;:I r -I ;Li ;:4 r -i c -I ;:4 ;:4 r -I a -I ;:4 ri r -I r -I r -I r -I ri ;:4 ri ; l Ol Ol Ol Ol Ol Ql O n w 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 rH -1 r -I r -I r -I - +-' a i M N N N N N N N N N N N N N N N N N N N N N N O O O O O O 00 + O \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ N N N N N N 4J 4J ri M O M m N w N I- N (.0 N Ill N Ch N M N N N ri N O N m -I w -I I, W -I Ln -I Ith M N r -I -I O -i \ \ \ \ \ \ -zl- N L r r -i r r rH ri r-1 r c M W I- W U) � 4J �0- M M N N N N N N N N N N N (N N N N N N N N N N N N N N N N N C) d a a 0 0 rH -1 H r -I -I rH rH -I -i r -I r -I -- -- ri -i r -I -i -- r -I e -i c-1 -1 r -I r -I -I -I rH ri O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O Ln O O O O O O O O O O O O O O in O O O O O O O O O O O O O O O m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O In In In In m m m in in m m In Ln m m m In in in m in In In in In In Ln in In In In In In In In In in In In m M m M M m m m M M M M M M M m M m M m M m m M M M m M M M M m m M M M m m m Q1 Ol Gl r1 r -I c -I r -I c --I r -i c -I ;-I r -I ;-i ri ri r -I a1 ;Lj ri ;LI i --I r1 r1 r -I Ql O1 Ol Ol al Ol Ql 61 Dl c -I r -I ri i --I r -I r -I O O O N N N N N N N N N N N N N N N N N N N N N O O O O O O O O O N N N N N N N N N \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ N N N N N N N N N \ \ \ \ \ \ \ \ \ O Ol 00 I- l0 in M N r -i O M 00 I- l0 to M N rA O \ \ \ \ \ \ \ \ \ r -i O Cr) 00 I- l0 M N -i m N N N N N N N N N N .--I e-1 r -I r- -1 -1 -1 r1 r1 -1 Ol 00 I\ l0 In -zt M N -I M M N N N N \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ N N N r -i r -i r i rr-I r1 r -i r -I r -I r -I r -i r -i r1 -i�--I r -i -1 rl ri 1-1 r ri r r -I r -ii i rrr r r -I O O O O 0 0 r -i c -I ci 1 i r1 rrrH r1 i i r -i i c -I r -i c -I rrrrrc1 r -i r1 r -i r� r1 r1 r -i c -i rri r -i r1 c-1 c -1i ri rc-I c -I ri ri r1 r -i r -i O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O m m O 0 0 0 0 0 0 0 0 0 0 0 m O 0 0 0 m m m m m m m r -I .1 ri r -i ri ri r -I r -i r -I ri r -I O N O O -1 .—I r -I r -i rH r -I r i r -i r1 r i ri r l ri r -I ri r -I r -I 1-1 -i .—I -i -i r -i —i m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m M m O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O m m m m m m m m m m m-zt Kt m m m m m m m m m m m m m m m m m m m m m m m m m m M M M M M M m M M M m m M M M M M M M M M M M M M M M M M M M M M M M M M M M r -I ;:i ri r -I ;:I ri ;:i r•1 c--1 c -i r -I ri ri ri r -I ;:I m 0 0 0 0 m m m m m m m m m m m m m m m m m m O O O O O O O O O O O O O O O O r1 r i r -I r i r r i r r i r -I r i ri r i ri r -I r i ri c i r -I r -i r r -i c1 N N N N N N N N N N N N N N N N O O O O O O O O O O O O O O O O O O O O O O O \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ N N N N N N N N N N N N N N N N N N N N N N N M M N .1 O Ol 00 Il l0 m -zt M N —4 O \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ N N N N N N r -I ri -i i—I r1 r -i rI ri —i —i Ol 00 I� l0 m M N r -I O Ol 00 I- l0 m 't M N r -I O Ol 00 Il \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ M N N N N N N N N N N r -I c -i r -i O O O O O O O O O O O O O O O O O O O O O O O O O \ \ \ \ \ \ \ \ \ \ \ \ \ \ r -i c1 ri ri ri ri r -I ri a1 .1 i1 c -i e q —1 rH —1 —1 r -I ri rH ri r -i r -I ri ri Ol O1 O1 O1 O1 Ol Ol O1 0) Ol Ol Ol Ol Ol O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 rn m rn rn rn m rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn rn m rn rn m Ln Ln Ln Ln o 0 0 0 0 0 0 0 0 0 0 0 o Ln o 0 0 0 0 o m o o m Ln Ln Ln Ln m o 0 0 0 0 -- -i ci ci ri N N N N N N N N N r -I r -I r -I r -i r -I N ri N N N N N N N ri ri rl rH ri -4 N N N N N m m m m M M M m m m m M m M m m m m m m M M M m m M m m M M m m m M M m M M M O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O Ln m m Ln Ln m m m Ln Ln Ln Ln Ill Ln Ln Ln m m m m m m Ln Ln Ln m Ln Ln Ln Ln Ln Ln Ln m Ln Ln Lf) Ln Ln m M M m m m M M M M M M m M M M m m M M m M m m m m M m M m M M M M M M M M m r-1 r -I -- ri r-1 r -I r -I m m m m m m m m m r -I r -I r -i r -I -i r -I -1 -1 ri r -I -1 -1 -1 r -I r -i rH r-1 i- c-1 rH r -i r -i M 0 0 0 0 0 0 0 r-1 r-1 r-1 r-1 r-1 r-1 r -I r-1 rH 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 r-1 N N N N N N N O O O O O O O O O N N N N N N N N N N N N N N N N N N N N N N O \ \ \ \ \ \ \ N N N N N N N N N \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ N LD Ln M N r -I O \ \ \ \ \ \ \ \ \ r -I O Ol 00 Il, LO Ln dt m N ri O Ql 00 I- l0 Ln M N -i O -- -1 ri r-1 c -I r -I Ql 00 I, lD Ln M N r -i M M N N N N N N N N N N r-1 rH r -I r-1 r-1 r -I r -i r -i r-1 r -I Ol \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ Cr) Ql Ql Ql Ql 6l Ql Ol Ol Ol Ol Ql Ol Ol Q1 Ol 00 00 00 00 00 00 00 00 00 00 00 W 00 00 00 00 00 00 00 00 00 00 W O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m O O O O O Ln O Ln O O Ln O 0 0 0 0 0 1n In O 0 0 Ln O 1n In Ln Ln In Ln Ln Ln Ln Ln In Ln O Ln Ln N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N M m m M M M M m M M M m M M M M M M M m M M M M M M M m m m m M M M M m M M M O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O Ln Ln Ln Ln m Ln m m m m m Ln m m m m m m Ln m m m m Ln m Ln m Ln Ln Ln Ln m m m m Ln Ln m LO M M m M M m M M M m m M M M M m m M m M M M m M M M m m M M m m M m m m m m M m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m r1 ri r1 r1 r -i r1 i-+ r1 rH c -i c -i rH rH ri c-+ 1-1 r1 r1 r1 r1 r1 r1 m m m m m m m m m r1 r1 r1 r -I r -I r1 ri %-1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 c-� ri ri r1 r1 r1 r1 ri r -I QCCOC (DOC N N N N N N N N N N N N N N N N N N N N N N OOCOOOOOC N N N N N N N N \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ N N N N N N N (,j N \ \ \ \ \ \ \ \ r-1 O m 00 1- LD Ln M N r1 O m 00 I- lD Lf) M N -4 O \ \ \ \ \ \ \ \ \ 00 1- l0 Ln It M N r1 M M N N N N N N N N N N rH r -I c --I r1 r -I r -I r-1 H r1 r1 m 00 I, lD Ln -t:- M N r1 \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ 00 CO 00 00 00 00 00 00 I- n n n n !- n r� n n n r� n r- r- n n n N n t\ r- t\ r- n n r- n t\ t\ t\ 0 0 0 0 0 0 0 0 0 0 0 0 0 Cl 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o O o 0 0 o O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 rn rn rn rn rn m rn rn rn rn rn rn rn rn rn rn rn rn rn rn m rn m rn rn rn rn rn rn rn rn m rn rn rn rn rn rn rn Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln In Ln In In Ln Ln Ln Ln Ln Ln Ln Ln N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N m m M M m M m m m m M m m M m M m M M m M M M M M M M M m M M M M m m m M M M 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 Ln 0 0 0 0 0 Lo Lo tp 3 3 Ln Ln m m Ln m m Ln Co Co Lo Co Co Lo Lo m m m m m m m Lo LD (o Lo (D Lo M m m m Ln Ln M m m m m m m cn m m m M M m M rn m M M m cn M M rn m cn m M M m M m m ro m m M cn m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m 1-1 ri r -I ri r -I ri ri c -i ri ri r -I c -i c -i c -i r-1 r -I r -i ri ri ri ri m m m m m m m m m r-1 ri ri r -I ri ri ri e-1 ri o O O O o O O O o o O O o 0 0 o O O o o O ri ri ri ri ri ci r-1 ri ri 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N N N N O O O O O O O O O N N N N N N N N N \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ N N N N N N N N N \ \ \ \ \ \ \ \ \ O (1) 00 I- W V) M N ri O O1 00 rl W Ln I:t M N r -I O \ \ \ \ \ \ \ \ \ r'I O 0) 00 I, W In m M N N N N N N N N N N r -I ri r -I -i r -I ri -1 ri ri c --I 01 00 I" w Lf) M N r -I M M N N N N N N N \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ 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m m m m m m m m m m m m m m m m m m m m m m m m m .-i r i c1 r -I ri ri ri ri ri ri ri ri ri ri ri T -i m m m m m m m m m O O O O O O O 0 O O O O 0 0 0 0 r -I ri ri ri c --I r -I . i ri ri N N N N N N N N N N N N N N N N O O O O O O O O O \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ N N N N (J N N N N u) I:* m N r O m W I, l0 u) I:J- m N ri O \ \ \ \ \ \ \ \ \ N N N N N N ri ri r -I ri ri ri ri c1 e1 ri M 00 L, W u) m N r-1 \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ r -I ri r -i r -I ri ri c -I r -I ri ri ri ri c -I r -I c -i ri ri ri ri ri c -I c -I r -I c -I c-1 RECEIVED STATE OF ALASKA ALTA OIL AND GAS CONSERVATION COMAION � f 1 REPORT OF SUNDRY WELL OPERATIONS 2018 __1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ .ADCwn a Performed: Suspend a Perforate a Other Stimulate a Alter Casing El Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Install Tubing Patch 0 2.Operator 4.Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska,LLC Development a Exploratory a 166-052 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic a Service 0 6.API Number: Anchorage,AK 99503 50-733-20437-00-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL0017587 Granite Pt St 17587 3 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pools and Undefined WDSP 11.Present Well Condition Summary: Total Depth measured 11,015 feet Plugs measured N/A feet true vertical 10,075 feet Junk measured N/A feet Effective Depth measured 9,650 feet Packer measured 7,810 feet true vertical 8,746 feet true vertical 7,092 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 589' 20" 589' 588' 3,060 psi 1,500 psi Surface 2,092' 13-3/8" 2,092' 1,998' 2,730 psi 1,130 psi Intermediate Production 8,178' 9-5/8" 8,178' 7,416' 5,750 psi 3,090 psi Liner 3,074' 7" 10,999' 10,059' 8,460 psi 8,610 psi Perforation depth Measured depth 9,015-10,715 feet True Vertical depth 8,169-9,778 feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/N-80 7,870(MD) 7,145(TVD) 7,810(MD) Packers and SSSV(type,measured and true vertical depth) Baker Model D Pkr 7,092(TVD) SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: ' ; MEV a '_ , N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 724 388 Subsequent to operation: 0 0 4 402 425 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory a Development❑ Service ll Stratigraphic a Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil a Gas a WDSPLQ Printed and Electronic Fracture Stimulation Data a GSTOR ❑ WINJ a WAG a GINJ a SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-038 Authorized Name: Stan W.Golis Contact Name: Michael Quick Authorized Title: Operations Manager Contact Email: mquick@hilcorp.com Authorized Signature: T (---%. (7-?-4.-::o Date: Z f zq-) I t e) Contact Phone: (907)777-8442 3'?--r Form 10-404 Revised 4/2017 r J QWRBD i,.,,. 2C18 Submit Original Only • • SCHEMATIC Bruce Platform Granite Point Field Well: Br 17587 3 Hilcorp Alaska,LLC Completed: 7/21/08 RKB to TBG Head=42.80' CASING AND TUBING DETAIL Tree connection:?? SIZE WT GRADE CONN ID TOP BTM. 1 I i 2 . 1 20 133 K-55 18.73 Surf 589' 13-3/8" 54.5 J-55 8 rd,ST&C 12.515 Surf 2,092' L 9-5/8" 43.5 S-95 ERW ST&C 8.755 Surf 52' 4 - 40 N-80 Buttress 8.835 52' 4,676' 5 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 7" 32 N-80 Butt. 6.094 7,925' 8,014' L ., 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' Tubing: i3-1/2" 9.2 N-80 ABC 2.992 42.8' 7,870' 1 JEWELRY DETAIL NO. Depth OD ID Item r 1 42.80' CIW Tubing Hanger, BPVP? `' 2 43.80' - ? Crossover,3-1/2"EUE 8rd Pin x 3-1/2"Buttress Pin 3 44.30' - 2.992 Pup, 3-1/2", ABC Tubing 4 48.30' - 2.992 Pup,3-1/2", ABC Patch 7,703- 5 58.30' - 2.992 Pup, 3-1/2", ABC 7 7,729 6 7,810' Packer, Permanent, Baker Mod. D(DPM) = 6 7 7,824' 4.875 3.000 Locator, Baker 190-47 8 8 7,825' 4.734 3.000 Seal Assembly, Baker, 190-47 9 9 7,839' - 2.992 1 joint,3-1/2",9.2#, N-80,ABC 10 7,870' - - Mule Shoe 10 Z Notes: 1/20/17-C/O fill to 9,650' Z PERFORATION DATA Cl Zone Top Btm Amt Accum Last Tie in Log SPF Perf Date C2 C 1 9,015' 9,035' 20 12 7/18/2008 CCUGR 7-17-08 C-3,4 9,030' 9,050' 30 4 10/3/1999 1999 C-2 9,240' 9,310' 70 4&8 6/30/1972 Et C-5 C-2X 9,240' 9260' 20' 4 10/3/1999 1999 ',:;-.:7;;;.``.... .°;.:•:',' .",'-'- C-2 9,380' 9,400' 20 4&8 6/30/1972 -,.,.- :',-;;:;,:i.-:-.:.;:.......-.:.-:::- C-7 C-7 C-2X 9,390' 9,400' 10 4 10/3/1999 1999 { i ` C 8 C-3/4 9,480' 9,495' 15 4 6/30/1972 C-5 9,580' 9,650' 70 4&8 6/30/1972 ,.,.{4*"* :t`-4 C-7 10,045' 10,095' 50 4&8 6/30/1972 .47.'.'l,.*:;,,:''...:":-.'.:',..,--: �.. t ,•'' .� .,i . 10,120' 10,130' 10 4 6/30/1972 'I's' f1,* 10,150' 10,200' 50 4&8 6/30/1972 - ':::-.‘1,4,n,!..1.•: 10,215' 10,270' 55 4&8 6/30/1972 a c:5-- ''',t `4=:;' 10,290' 10,310' 20 4&8 6/30/1972 C-8 10,432' 10,462' 30 4&8 6/30/1972 PBTD=10,989' TD=11,015' 10,478' 10,578' 100 4&8 6/30/1972 HOLE ANGLE thru Interval= ° C-9 10,628' 10,715' 87 4&8 6/30/1972 Updated: 02/28/18 by: JLL • • 111 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 17587 3 Slickline 50-733-20437-00 166-052 2/3/18 2/5/18 Daily Operations: 02/03/18-Saturday ARRIVE ON PLATFORM JSA/TGSM RIG UP. P/T LUB 3000PS1 (GOOD). RIH W/2.84 G-RING TO 34KB W/T 340KB SEE SCALE, POOH. RIH W/2.74 G-RING TO 7720KB TAG PATCH, POOH. RIH W/D&D HOLE FINDER TO 7720KB TAG PATCH, SET, TEST FAIL. SEE TBG AND CSG COMMUNICATING, PULL UP TO 7717 KB RE-TEST, SEE SAME. PULL UP TO 7000KB TEST GOOD @ 1000PSI AND 1500PSI POOH. RIH W/PONY TAIL TO 7000KB WILE BLEEDING CSG OFF. START INJECTING DOWN TBG. RIH TO 7720KB @ 30FPM SEE SLIGHT BOBBLE @ 7058KB BUT NOT DEFINITIVE, POOH. OOH, LAY DOWN FOR NIGHT HAVING TARP RISER TO STOP IT FROM FREEZING. 02/04/18-Sunday JSA/TGSM. CHECK TS, RIG UP RISER'S NIGHT CAP, FROZE, THOW OUT. RIH W/D&D HOLE FINDER ON 2 1/2 JDC TO 7712KB W/T SET PRESSURE UP TUB TO 1000PSI THEN 1500PSI HOLDS, POOH. OOH RE-DRESS D&D AND JDC LAY DOWN LUB AND USE METH TO MELT ICE. RIH W/D&D HOLE FINDER ON 2 1/2 JDC TO 7722KB SET ON TOP OF PATCH TEST, SEE TBG AND CSG COMUNICATION, PULL TO 7721KB RE-TEST, SAME, PULL UP TO 7715KB TEST 1000PSI AND 1500PSI GOOD - POOH. RIH W/3" GS TO 7722KB W/T LATCH A-STOP JAR FREE POOH W/A-STOP. RIH W/3" GS TO 7723KB W/T LATCH PATCH HIT 4 OJ LICKS UP TO 1200LB POOH W/PATCH. OOH W/PATCH RE DRESS ADD STINGER. RIH W/PATCH ON 3" GS TO 7726KB W/T SET PATCH, POOH. RIH W/PATCH ON 3" GS TO 7704KB W/T SET 2ND PATCH, POOH. RIH W/3" A-STOP ON GS TO 7703KB W/T SET A-STOP, POOH. PATCH SET FROM 7703'to 7729'. 02/05/18- Monday OOH W/GS, PATCH SET. LAY DOWN FOR NIGHT.JSA/TGSM. START UP JET HEATER TO DE-ICE RISER. INJECT TILL TUBING REACHES 2000PS1 CSG HOLDING 350PS1.TEST BACK SIDE, HOLD 1600PSI ON CSG TBG 400PSI FOR 1:00 HOLDS (GOOD TEST). RIG DOWN. �clicycie Pd-S,� )?S'�t gra Regg, James B (DOA) /6,to©SzD From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Thursday, February 8, 2018 1:52 PM To: Regg,James B (DOA); DOA AOGCC Prudhoe; Brooks Phoebe L(DOA);Wallace, Chris D (DOA) Subject: MIT Bruce platform 02-07-18 Attachments: MIT Bruce 02-07-18.xlsx Gentlepeople, Here is the official report for the successful MIT on the Granite Point State 17587#3 (AKA Bruce 3-87) well performed and witnessing waived on 2/7/18. As the longer patch installation successfully repaired the downhole mechanical integrity for this well, we will be using the 2/7/18 date as the anniversary date for future MITs on this batch disposal well. Thank you Larry 1 . • 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaoCcBalaska.00v AOGCC.Insoectors(Dalaska.00v phoebe.brookst6alaska.00v chris.wallace(Oalaska.00v OPERATOR: Hilcorp Alaska,LLC 0 � ;1 g �f FIELD/UNIT/PAD: Granite Point Field/NGPU/Bruce Platform (J� DATE: 02/07/18 OPERATOR REP: Stuart Allison AOGCC REP: Witness waived Well Bruce 3-87 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1660520, Type lnj N ' Tubing 400 450 450 450 450 450 Type Test P Packer TVD 7091 - BBL Pump 2.0 ' IA 520 1850 • 1850 ' 1850' 1850+ 1850 ' Interval I Test psi 1773 - BBL Return 2.0 ' OA 90 92 92 92 92 92 Result P Notes: Pump time started at 12:45,took 2 hours to get to 1850#. Monitored for 1 hour.After bleed down Tubing @ 3808,IA @ 500#,OA©85#. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In] TubingType Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min'. 60 Min. PTD Type In] Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval • Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test • Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In] Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: • TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT Bruce 02-07-10 % Or 74.4,,yw\ I//j, s THE STATE Alaska Oil and Gas ���►:_�i����, of T LAS Conservation Coissi®n __- A _ _= 333 West Seventh Avenue 191,r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OFMain: 907.279.1433 ALAS"• Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager e a ! �!" + Hilcorp Alaska, LLC ��� �� 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field,Middle Kenai Oil Pool and Undefined WDSP Pool, Granite Pt St 17587 3 Permit to Drill Number: 166-052 Sundry Number: 318-038 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French • Chair DATED this(Jday of February, 2018. RBDMS (Av — 1 2Z18 III - RECEIVED STATE OF ALASKA JAN 3 0 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: Install Tubing Patch Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑ 166-052 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service E. 6.API Number: Anchorage,AK 99503 50-733-20437-00-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A . Will planned perforations require a spacing exception? Yes 0 No Q / Granite Pt St 17587 3 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017587 • Granite Point Field/Middle Kenai!Oil Pools and Undefined WDSP • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,015 • 10,075 • 9,650 • 8,746' 405 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 589' 20" 589' 588' 3,060 psi 1,500 psi Surface 2,092' 13-3/8" 2,092' 1,998' 2,730 psi 1,130 psi Intermediate Production 8,178' 9-5/8" 8,178' 7,416' 5,750 psi 3,090 psi Liner 3,074' 7" 10,999' 10,059' 8,460 psi 8,610 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,015-10,715 8,169-9,778 3-1/2" 9.2#/N-80 7,870 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Model D Packer&N/A ' 7,810(MD)7,092(TVD)&N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑. 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/2/2018 OIL ❑ WINJ ❑ Wiz.p... 2 ' Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG El Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan Golis Contact Name: Michael Quick Authorized Title: Operations Manager Contact Email: mouick a hilCorp.com / Contact Phone: (907)777-8442 Authorized Signature: if Date: t 1 • o I Ql COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �13 -Of Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ R2D!11S Il/ F119 - 1 2018 Spacing Exception Required? Yes ❑ No IA* Subsequent Form Required: j1)2q-- APPROVED BY ' le—) Approved by: v COMMISSIONER THE COMMISSION Date: Z Z 3 S bi3 Form and Form 10-403 Revised 4/2017 Approved applica i I o he date of approval. Attachments in Duplicate • • Well Work Prognosis Well: Br 03-87 Hilcorp Alaska,LL(. Date: 1/30/2018 Well Name: Granite Point St 17587#03 API Number: 50- 733-20437-00 Current Status: Waste Disposal/Injection Leg: Leg#1 (North) Estimated Start Date: February 2, 2018 Rig: N/A (wireline) Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 166-052 First Call Engineer: Michael Quick (907) 777-8442 (0) (907) 317-2969 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904(M) Current Bottom Hole Pressure: 4,368 psi @ 8,700'TVD 0.431 psi/ft(8.29 ppg)based on 07/14/2008 Static survey Maximum Expected BHP: 4,368 psi @ 8,700'TVD 0.431 psi/ft(8.29 ppg)based on 07/14/2008 Static survey Max Potential Surface Pressure(MPSP):2,705 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Current Shut in Tubing Pressure: 405 psig Brief Well Summary Well Bruce 03-87 is a waste disposal/injector completed in the Granite Point Field/Middle Kenai Oil Pool/Undefined WDSP. The well showed possible tubing by IA communication on 11/20/2017, and a tubing patch was installed from 7717' to 7729'. The well passed an MIT to 1850 psi on 1/13/2018 that was witnessed by an AOGCC inspector. The disposal operation on this well is cyclical, as the platform does not produce enough water to warrant daily operation. The well showed possible tubing by IA communication on 1/29/2018, and was shut in on the same day.''The AOGCC was notified of this possible communication via email on 1/30/2018. Diagnostics will be completed on the well to determine if the patch is leaking, or if there is an additional hole that needs to be covered. If an additional hole is discovered, it will be covered by either extending the existing patch or adding an additional tubing patch. This is the only disposal well on the Bruce platform, and due to the winter freeze up we can no longer ship the waste to shore via the pipeline. We are requesting expedited approval of this sundry to prevent the shut down of production on the platform.( Procedure: 1. MIRU Slick-line, PT lubricator to 3,000 psi. 2. Run holefinder&/or other diagnostic tools to determine where the leak is. 3. Repair leak by: y , a. Replacing existing patch b. Extending the length of existing patch +/-10' c. Install an additional tubing patch 4. RD slick-line 5. Conduct pressure test on 9-5/8" casing to 1500 psi for 30 minutes 6. MIT 9-5/8" casing to 1780 psi for 30 minutes on a chart recorder(Notify AOGCC inspectors 48 hours in advance of MIT for witness) ii: NOTE: MIT will be done with well static, as this well is used for small batch disposal operations. ry 7. Turn well over to operations, resume injection after AOGCC approval is received. • Well Work Prognosis Well: Br 03-87 Hileorp 9laska,Llf Date: 1/30/2018 Attachments: 1. Well Schematic-Current 2. Well Schematic- Proposed • • Bruce Platform SCHEMATIC Granite Point Field Well: Br 17587 3 Completed: 7/21/08 HiIcorp Alaska,LLC RKB to TBG Head=42.80' CASING AND TUBING DETAIL Tree connection:?? SIZE WT GRADE CONN ID TOP BTM. 1 i 2 I 20 133 K-55 18.73 Surf 589' 13-3/8" 54.5 J-55 8 rd,ST&C 12.515 Surf 2,092' 3 9-5/8" 43.5 S-95 ERW ST&C 8.755 Surf 52' 40 N-80 Buttress 8.835 52' 4,676' 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 7" 32 N-80 Butt. 6.094 7,925' 8,014' L 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' Tubing: 3-1/2" 9.2 N-80 ABC 2.992 42.8' 7,870' JEWELRY DETAIL NO. Depth OD ID Item 1 42.80' CIW Tubing Hanger, BPVP? 2 43.80' - ? Crossover,3-1/2"EUE 8rd Pin x 3-1/2"Buttress Pin 3 44.30' - 2.992 Pup, 3-1/2", ABC Tubing 4 48.30' - 2.992 Pup,3-1/2", ABC Patch 7,717- 5 58.30' - 2.992 Pup,3-1/2", ABC 77,729 � 6 7,810' - - Packer, Permanent, Baker Mod. D(DPM) m isem 6 7 7,824' 4.875 3.000 Locator, Baker 190-47 8 8 7,825' 4.734 3.000 Seal Assembly, Baker, 190-47 9 9 7,839' - 2.992 1 joint, 3-1/2",9.2#, N-80,ABC 10 7,870' - - Mule Shoe 10 Z Notes: 1/20/17-C/O fill to 9,650' L PERFORATION DATA Cl Zone Top Btm Amt Accum Last Tie in Log SPF Perf Date C2 C-1 9,015' 9,035' 20 12 7/18/2008 CCL/GR 7-17-08 C-3,4 9,030' 9,050' 30 4 10/3/1999 1999 C-2 9,240' 9,310' 70 4&8 6/30/1972 C-5 C-2X 9,240' 9260' 20' 4 10/3/1999 1999 ,,.,, , , „ ,e,, C-2 9,380' 9,400' 20 4&8 6/30/1972 .1 ': : C-7 C-2X 9,390' 9,400' 10 4 10/3/1999 1999 f� x�a ,oF.;i�•��;' C 8 C-3/4 9,480' 9,495' 15 4 6/30/1972 , "°t,._,# +:);:;:,' °� C-5 9,580' 9,650' 70 4&8 6/30/1972 � T * 12 . ..,"'„.-., C-7 10,045' 10,095' 50 4&8 6/30/1972 1a ' �` C 9 10,120' 10,130' 10 4 6/30/1972 .o-.-e...,-, " "+�"'.' 10,150' 10,200' 50 4&8 6/30/1972 w'+a.:r ,.� � 3� ��� �- 10,215' 10,270' 55 4&8 6/30/1972 10,290' 10,310' 20 4&8 6/30/1972 C-8 10,432' 10,462' 30 4&8 6/30/1972 PBTD=10,989' TD=11,015' HOLE ANGLE thru Interval= 10,478' 10,578' 100 4&8 6/30/1972 C-9 10,628' 10,715' 87 4&8 6/30/1972 Updated: 01/09/18 by:JLL • • Bruce Platform PROPOSED Granite Point Field Well: Br 17587 3 Completed: 7/21/08 Hilcorp Alaska,LLC RKB to TBG Head=42.80' CASING AND TUBING DETAIL Tree connection:?? SIZE WT GRADE CONN ID TOP BTM. 12 20 133 K-55 18.73 Surf 589' 3 13-3/8" 54.5 J-55 8 rd,ST&C 12.515 Surf 2,092' 9-5/8" 43.5 S-95 ERW ST&C 8.755 Surf 52' L 4 , 40 N-80 Buttress 8.835 52' 4,676' 5 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 7" 32 N-80 Butt. 6.094 7,925' 8,014' Z 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' Tubing: 3-1/2" 9.2 N-80 ABC 2.992 42.8' 7,870' JEWELRY DETAIL NO. Depth OD ID Item 1 42.80' CIW Tubing Hanger, BPVP? 2 43.80' - ? Crossover, 3-1/2"EUE 8rd Pin x 3-1/2"Buttress Pin 3 44.30' - 2.992 Pup,3-1/2", ABC Tubing 4 48.30' - 2.992 Pup,3-1/2", ABC 1 Patch ±7,710 5 58.30' 2.992 Pup,3-1/2", ABC 7 ±7,731 6 7,810' Packer, Permanent, Baker Mod. D(DPM) 6 7 7,824' 4.875 3.000 Locator, Baker 190-47 8 8 7,825' 4.734 3.000 Seal Assembly, Baker, 190-47 9 9 7,839' - 2.992 1 joint, 3-1/2", 9.2#, N-80,ABC 10 7,870' - - Mule Shoe Z 10 Z Notes: 1/20/17-C/0 fill to 9,650' L PERFORATION DATA Cl Zone Top Btm Amt Accum Last Tie in Log SPF Peri Date C2 C_1 9,015' 9,035' 20 12 7/18/2008 CCL/GR 7-17-08 C-3,4 9,030' 9,050' 30 4 10/3/1999 1999 C-2 9,240' 9,310' 70 4&8 6/30/1972 C-5 C-2X 9,240' 9260' 20' 4 10/3/1999 1999 x , x C-2 9,380' 9,400' 20 4&8 6/30/1972 m ;^ C-7 C-2X 9,390' 9,400' 10 4 10/3/1999 1999 zf ' r'µ< fi C-8 C-3/4 9,480' 9,495' 15 4 6/30/1972 ,„.....•t:”--.1'...'-",'-'-',4". `\^• C-5 9,580' 9,650' 70 4&8 6/30/1972 ; ��.. %k-,-+'"�t 1`',= • • Schwartz, Guy L (DOA) From: Michael Quick <mquick@hilcorp.com> Sent Tuesday,January 30,2018 3:20 PM To: Wallace, Chris D (DOA);Schwartz, Guy L(DOA) Cc: Larry Greenstein;Juanita Lovett Subject: Sundry for Granite Point ST 17587 3 (Bruce 03-87) PTD 166-052 Attachments: 10-403 Granite Pt St 17587 3 - 2018-01-30 Submitted.pdf Guy— I will be delivering a sundry to repair the Granite Point ST 17587 3 well (PTD 166-052)this afternoon. I have attached a scan of the submittal. We will be repairing or extending the tubing patch that was installed under sundry 317-583 that was approved 12/15/17. We are requesting expedited approval of this, if possible, as this is the only disposal well on the Bruce Platform and our option to send waste to shore via the pipeline is not valid during the winter freeze. We would like to mobilize to repair this well on 2/2. Thank you for the consideration of this request. Mike From: Michael Quick Sent:Tuesday,January 30,2018 7:38 AM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc:'Schwartz,Guy L(DOA)'<guy.schwartz@alaska.gov>; Larry Greenstein<Igreenstein@hilcorp.com>;Juanita Lovett <jlovett@hilcorp.com> Subject:Granite Point ST 17587 3 (Bruce 03-87) PTD 166-052 Chris— It appears that we have possible tubing by IA communication on the Bruce disposal well,Granite Point ST 17587 3 . The well was shut in yesterday afternoon, 1/29/18. We are formulating a plan forward and will communicate once we have our plan ready. Call with any questions. Thanks, Mike Michael Quick Hilcorp Alaska, LLC Operations Engineer Office 907-777-8442 Cell 907-317-2969 Email mquick a(�hilcorp.com 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,January 17,2018 Jim Regg P.I.Supervisor `1 q: (I111,0 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 03-87 FROM: Guy Cook GRANITE PT ST 17587 03-87 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name GRANITE PT ST 17587 03-87 , API Well Number 50-733-20437-00-00 Inspector Name: Guy Cook Permit Number: 166-052-0 Inspection Date: 1/13/2018 Insp Num: mitGDC180114172102 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 03-87 - Type Inj N 'TVD 7092 Tubing 340 340 • 340 • 340 PTD i 1660520 Type Test SPT Test psi 1773 IA 716 1851 1850 - 1849 - BBL Pumped: r 1.8 . IBBL Returned: _ 9 L8 • OA 89 95 - 95 95 - Interval INITAL PIF P ✓ Notes: Initial MIT-IA due to patch installed into the tubing. Well was pressurized with a small air powered diaphram pump drawing water out of two 55 gallon barrels. After testing the well was bled back into the barrels to approximately 685 psi. • Wednesday,January 17,2018 Page 1 of 1 STATE OF ALASKA JAN 0 9 2018 AL OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend 0 Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Wet 0 Other:Install Tubing Patch El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑ Exploratory 0 166-052 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20437-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017587 Granite Pt St 17587 3 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pools and Undefined WDSP 11.Present Well Condition Summary: Total Depth measured 11,015 feet Plugs measured N/A feet true vertical 10,075 feet Junk measured N/A feet Effective Depth measured 9,650 feet Packer measured 7,810 feet true vertical 8,746 feet true vertical 7,092 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 589' 20" 589' 588' 3,060 psi 1,500 psi Surface 2,092' 13-3/8" 2,092' 1,998' 2,730 psi 1,130 psi Intermediate Production 8,178' 9-5/8" 8,178' 7,416' 5,750 psi 3,090 psi Liner 3,074' 7" 10,999' 10,059' 8,460 psi 8,610 psi Perforation depth Measured depth 9,015-10,715 feet True Vertical depth 8,169-9,778 feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/N-80 7,870(MD) 7,145(TVD) 7,810(MD) Packers and SSSV(type,measured and true vertical depth) Baker Model D Pkr 7,092(TVD) SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A ®pt JAN '2 2.01)3 Treatment descriptions including volumes used and final pressure: SE N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 100 400 Subsequent to operation: 0 0 0 513 403 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory El Development❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas ❑ WDSPLD Printed and Electronic Fracture Stimulation Data ❑ GSTOR El WINJ El WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-583 Authorized Name: Stan W.Golis Contact Name: Michael Quick Authorized Title: Operations56°"` Manager Contact Email: mquick@hilcorp.com Authorized Signature: Date: 1 / 1 i ($ Contact Phone: (907)777-8442 Form 10A04 Revised 4/2017 ��jr / 1 z vRDDMS (/J.^.'! 1 1 7r19Submit Original Only • • Bruce Platform SCHEMATIC Granite Point Field Well: Br 17587 3 Completed: 7/21/08 Hilcorp Alaska,LLC RKB to TBG Head=42.80' CASING AND TUBING DETAIL Tree connection: ?? SIZE WT GRADE CONN ID TOP BTM. 1 2 I 20 133 K-55 18.73 Surf 589' 3 13-3/8" 54.5 J-55 8 rd,ST&C 12.515 Surf 2,092' L 4 .\ 9-5/8" 43.5 S-95 ERW ST&C 8.755 Surf 52' 40 N-80 Buttress 8.835 52' 4,676' 5 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 7" 32 N-80 Butt. 6.094 7,925' 8,014' L \ 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' Tubing: 3-1/2" 9.2 N-80 ABC 2.992 42.8' 7,870' JEWELRY DETAIL NO. Depth OD ID Item 1 42.80' CIW Tubing Hanger, BPVP? 2 43.80' ? Crossover, 3-1/2"EUE 8rd Pin x 3-1/2"Buttress Pin r- 3 44.30' - 2.992 Pup,3-1/2", ABC Tubing 4 48.30' - 2.992 Pup,3-1/2", ABC Patch 7,717- 5 58.30' - 2.992 Pup,3-1/2", ABC 7 7,729 6 7,810' Packer, Permanent, Baker Mod. D(DPM) 6 7 7,824' 4.875 3.000 Locator, Baker 190-47 8 '■ 8 7,825' 4.734 3.000 Seal Assembly, Baker, 190-47 9 9 7,839' - 2.992 1 joint,3-1/2",9.2#, N-80,ABC 10 7,870' - - Mule Shoe 10 IX Notes: 1/20/17-C/O fill to 9,650' Z PERFORATION DATA Cl Zone Top Btm Amt Accum Last Tie in Log SPF Perf Date C2 C-1 9,015' 9,035' 20 12 7/18/2008 CCL/GR 7-17-08 C-3,4 9,030' 9,050' 30 4 10/3/1999 1999 C-2 9,240' 9,310' 70 4&8 6/30/1972 C-5 C-2X 9,240' 9260' 20' 4 10/3/1999 1999 r x: 3. ` x; C-2 9,380' 9,400' 20 4&8 6/30/1972 a :.‘: ,rY C-7 C-2X 9,390' 9,400' 10 4 10/3/1999 1999 .f-4,41,-,k7:47:-C-7,'4:1' C-3/4 9,480' 9,495' 15 4 6/30/1972 ^ '*1C8 : ^.,. C-5 9,580' 9,650' 70 4&8 6/30/1972 " .` ',r #t5`' C-7 10,045' 10,095' 50 4&8 6/30/1972 -. ..i , k'`- 10,120' 10,130' 10 4 6/30/1972 `r .1-; iyY 10,150' 10,200' 50 4&8 6/30/1972. e:. F \ 10,21510,27055 4&8 6/30/1972 10,290' 10,310' 20 4&8 6/30/1972 C-8 10,432' 10,462' 30 4&8 6/30/1972 PBTD=10,989' TD=11,015' HOLE ANGLE thru Interval= 10,478' 10,578' 100 4&8 6/30/1972 C-9 10,628' 10,715' 87 4&8 6/30/1972 Updated: 01/09/18 by: JLL • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 17587 3 Slickline 50-733-20437-00 166-052 1/3/18 1/5/18 Daily Operations: 01/03/18-Wednesday FLY OUT TO BRUCE PLATFORM CHECK IN AND FILL OUT JSA AND WORK PERMIT. FINISHED RIGGING UP, STAB ON WELLHEAD AND PRESSURE TEST TO 2500PSI,TEST GOOD. FINISHED FOR NIGHT, SECURE WELL AND SDFN. 01/04/18-Thursday FILL OUT JSA AND WORK PERMIT. ATTEND MORNING SAFETY MEETING. RIH WITH CABLE BRUSH MAKE SEVERAL PASSES FROM 7800 TO SURFACE WHILE INJECTION PUMP RUNNING. RIH W/AD2 STOP AND 3"GS SET @ 7729KB POOH. RIH WITH PACKOFF AND PATCH PIPE SET @ 7719KB POOH. RIH W/AA STOP SET @ 7717KB POOH. OOH LAY DOWN LUBRICATOR, SECURE WELL, CLEAN UP TOOLS AND SDFN. 01/05/18 - Friday FILL OUT WORK PERMIT AND JSA. ATTEND MORNING SAFETY MEETING. ASSIST WITH LOW PRESSURE INTEGRITY TEST. CONTINUE RIGGING DOWN. WAIT ON TEST.TEST GOOD. FINISH RIGGING DOWN. FLY TO OSK. 01/06/18-Saturday 01/07/18-Sunday 01/08/18 - Monday 01/09/18-Tuesday • II Bruce Injection Well 3-87 In-House PT TIME TUBING PSI 9 5/8" PSI 13 3/8" PSI Pretest 370 150 86 Initial 360 1500 92 10:50 360 1500 92 10:55 360 1500 92 11:00 360 1500 92 11:05 350 1500 92 11:15 350 1500 92 11:30 350 1500 92 11:45 350 1500 92 12:00 350 1500 92 NOTES: IA held solid at 1500 PSI for duration of test. 1600 1400 1200 1000 800 TUBING 600 IA 400 OA 200 0 h� .\ate O h O h O O Q`¢'• ��' y0* ti0* y'V ' O tiNy tit•s 1NR 1�0 ! • Schwartz, Guy L (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Friday,January 12, 2018 2:13 PM To: Schwartz, Guy L(DOA);Wallace, Chris D(DOA) Cc: Michael Quick Subject: FW: BR 17587 3 Disposal well (PTD 166-052) Post patch pressure test Attachments: Br 3-87 Post Patch PT 1-6-18.pdf You got it Mike. Hi Guy The field sent me a table of the low pressure(1500 psi) pressure test on the patch that the procedure and 10-403 required. The initial, witnessed MIT to full pressure (1773 psi) is being done today, I believe, and I'll be sending in the official report of that as soon after that as I can. I've attached the pressure test table of pressures that was collected on January 6th. Sorry that wasn't included in the 10- 404 submittal. Looked pretty tight to me. Larry From: Michael Quick Sent: Friday,January 12, 2018 2:01 PM To:Larry Greenstein<Igreenstein@hilcorp.com> Cc:Juanita Lovett<jlovett@hilcorp.com> Subject: FW: BR 17587 3 Disposal well. (PTD 166-052) Larry— Please see below. Mike From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday,January 12, 2018 1:51 PM To: Michael Quick<mquick@hilcorp.com> Cc:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Subject: BR 17587 3 Disposal well. (PTD 166-052) Mike, Looking at 10-404 report for this well. The procedure calls for testing the casing to 1500 psi and follow-up MIT-IA after stable injection: The daily reports provided only covers setting the patch and mentions a low pressure test the following day. Was this to 1500 psi and just not written down and charted? Has witnessed MIT-IA been done?? Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 1 Or Tip • • yw � I�j,7SA THE STATE Alaska Oil and Gas ti 1, of j Conservation Commission s t — 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wh Main: 907.279.1433 ®p,ALAS5'� Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager SCANNED JAN 2 9 'M 18 Hilcorp Alaska, LLC 3 800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pools and Defined WDSP, Granite Pt. St. 17587 3 Permit to Drill Number: 166-052 Sundry Number: 317-583 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French 4\ Chair DATED this 11 day of December, 2017. REc:sL G i ZCjii • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 12 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AO G C C 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well El Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill El Perforate New Pool El Re-enter Susp Well ❑ Alter Casing El Other: Install Tubing Patch 0' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC . Exploratory ❑ Development ❑ 166-052 3.Address: 6.API Number. 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ Anchorage,AK 99503 50-733-20437-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No El Granite Pt St 17587 3 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017587 . Granite Point Field/Middle Kenai!Oil Pools and Undefined WDSP, 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 11,015 ' , 10,075 9,650 8,746 • 405 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 589' 20" 589' 588' 3,060 psi 1,500 psi Surface 2,092' 13-3/8" 2,092' 1,998' 2,730 psi 1,130 psi Intermediate Production 8,178' 9-5/8" 8,178' 7,416' 5,750 psi 3,090 psi Liner 3,074' 7" 10,999' 10,059' 8,460 psi 8,610 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,015-10,715 • 8,169-9,778 3-1/2" 9.2#/N-80 7,870 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker Model D Packer&N/A 7,810(MD)7,092(ND)&N/A 12.Attachments: Proposal Summary El Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development El Service El 14.Estimated Date for 15.Well Status after proposed work: 12/26/2017 Commencing Operations: OIL ❑ WINJ ❑ WDSPL El ' Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR El SPLUG ❑ Commission Representative: GINJ El Op Shutdown El Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan Golis Contact Name: Michael Quick Authorized Title: Operations Manager Contact Email: mquick( hilcorp.Com Contact Phone: (907)777-8442 Authorized Signature: fe Date: 1 Z f 4-2' ( 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 51^/ -y!' f/� `, n Plug Integrity ❑ BOP Test ClMechanical Integrity Test I' Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ A -,- L r I Spacing Exception Required? Yes ❑ No c/ Subsequent Form Required: /�j1 4(0Ll �t'`"` `° -+ i ./ LtH 1�. APPROVED BY Z I I t; Approved by: t —f COMMISSIONER THE COMMISSION Date: {�1 '?1/2..0iAIr)17- , /2/6,(//7, '7 ORIGINAL /z_,q-,7 � / Submit Form and `I Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • • Well Work Prognosis Well: Br 03-87 Hileorp Alaska,LIADate: 12/11/17 Well Name: Granite Point St 17587#03 API Number: 50-733-20437-00 Current Status: Waste Disposal/Injection Leg: Leg#1 (North) Estimated Start Date: December 26, 2017 Rig: N/A (wireline) Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 166-052 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Michael Quick (907) 777-8442 (0) (907) 317-2969 (M) Current Bottom Hole Pressure: 4,368 psi @ 8,700'TVD 0.431 psi/ft(8.29 ppg)based on 07/14/2008 Static survey Maximum Expected BHP: 4,368 psi @ 8,700'TVD 0.431 psi/ft(8.29 ppg)based on 07/14/2008 Static survey Max Potential Surface Pressure(MPSP):2,705 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Current Shut in Tubing Pressure: 405 psig Brief Well Summary Well Bruce 03-87 is a waste disposal/Injector completed in the Granite Point Field/Middle Kenai Oil Pool/Undefined WDSP. The well showed possible tubing by IA communication on 11/20/2017, and was shut in on the same day. The AOGCC was notified of this possible communication via email on 11/21/2017. Diagnostics completed on the well show a small hole in the tubing at 7,722'. This procedure will install a tubing patch to restore tubing integrity. Procedure: 1. MIRU Slick-line, PT lubricator to 3,000 psi. 2. RIH with slick-line and set stops and patch over hole at ±7,722. 3. RD slick-line 4. Conduct in-house MIT on 9-5/8" casing to 1500 psi for 30 minutes 5. MIT 9-5/8" casing to 1500 psi for 30 minutes on a chart recorder(Notify AOGCC inspectors 48 hours in advance of MIT for witness) 6. Turn well over to operations, resume injection after AOGCC approval is received. Attachments: 1. Well Schematic-Current 2. Well Schematic- Proposed • • Ini Bruce Platform SCHEMATIC Granite Point Field Well: Br 17587 3 Completed: 7/21/08 Hilcarp Alaska,LLC RKB to TBG Head=42.80' CASING AND TUBING DETAIL Tree connection:?? SIZE WT GRADE CONN ID TOP BTM. 1 2 I 20 133 K-55 18.73 Surf 589' 13-3/8" 54.5 J-55 8 rd,ST&C 12.515 Surf 2,092' 3 L , 9-5/8" 43.5 S-95 ERW ST&C 8.755 Surf 52' 40 N-80 Buttress 8.835 52' 4,676' 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 7" 32 N-80 Butt. 6.094 7,925' 8,014' Z ..\ 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' Tubing: 3-1/2" 9.2 N-80 ABC 2.992 42.8' 7,870' JEWELRY DETAIL NO. Depth OD ID Item 1 42.80' CIW Tubing Hanger, BPVP? 2 43.80' - ? Crossover,3-1/2"EUE 8rd Pin x 3-1/2"Buttress Pin 1� , e9 3 44.30' - 2.992 Pup,3-1/2", ABC k2 wj ' 4 48.30' - 2.992 Pup,3-1/2", ABC 6 5 58.30' - 2.992 Pup, 3-1/2", ABC \ 6 7,824' 4.875 3.000 Locator, Baker 190-47 sm _ 10 7 7,825' 4.734 3.000 Seal Assembly, Baker, 190-47 7 8 7,839' - 2.992 1 joint,3-1/2",9.2#, N-80,ABC 8 9 7,870' - - Mule Shoe 10 7,810' - - Packer, Permanent, Baker Mod. D(DPM) X 9Z Notes: 1/20/17-C/O fill to 9,650' L PERFORATION DATA Cl Zone Top Btm Amt Accum Last Tie in Log SPF Perf Date C2 C-1 9,015' 9,035' 20 12 7/18/2008 CCL/GR 7-17-08 C-3,4 9,030' 9,050' 30 4 10/3/1999 1999 C-2 9,240' 9,310' 70 4&8 6/30/1972 C-5 C-2X 9,240' 9260' 20' 4 10/3/1999 1999 C-2 9,380' 9,400' 20 4&8 6/30/1972 C-7 C-2X 9,390' 9,400' 10 4 10/3/1999 1999 ;$, C-3/4 9,480' 9,495' 15 4 6/30/1972 a +rt C-8 . +' > C-5 9,580' 9,650' 70 4&8 6/30/1972 e rw. ", . C-7 10,045' 10,095' 50 4&8 6/30/1972 10,120' 10,130' 10 4 6/30/1972 C-9 ,. • ^a,rti . "�,,+ 10,150 10,200 50 4&8 6/30/1972 a' .i,t �`-' 10,215' 10,270' 55 4&8 6/30/1972 / j r \l 10,290' 10,310' 20 4&8 6/30/1972 C-8 10,432' 10,462' 30 4&8 6/30/1972 PBTD=10,989' TD=11,015' HOLE ANGLE thru Interval= 10,478' 10,578' 100 4&8 6/30/1972 C-9 10,628' 10,715' 87 4&8 6/30/1972 Updated: 02/17/17 by:JLL • • 13 Bruce Platform PROPOSED Granite Point Field Well: Br 17587 3 Completed: 7/21/08 Hilcorp Alaska,LLC RKB to TBG Head=42.80' CASING AND TUBING DETAIL Tree connection: ?? SIZE WT GRADE CONN ID TOP BTM. 1 I 2 I 20 133 K-55 18.73 Surf 589' 13-3/8" 54.5 J-55 8 rd,ST&C 12.515 Surf 2,092' 3 9-5/8" 43.5 S-95 ERW ST&C 8.755 Surf 52' L 4 - 40 N-80 Buttress 8.835 52' 4,676' 5 ; 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 7" 32 N-80 Butt. 6.094 7,925' 8,014' Z 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' Tubing: 3-1/2" 9.2 N-80 ABC 2.992 42.8' 7,870' JEWELRY DETAIL NO. Depth OD ID Item 1 42.80' CIW Tubing Hanger, BPVP? 2 43.80' - ? Crossover,3-1/2"EUE 8rd Pin x 3-1/2"Buttress Pin 3 44.30' - 2.992 Pup,3-1/2", ABC 4 48.30' - 2.992 Pup,3-1/2", ABC Tubing Patch 5 58.30' - 2.992 Pup,3-1/2", ABC 6 ±7,722 6 7,824' 4.875 3.000 Locator, Baker 190-47 m : VW' 10 7 7,825' 4.734 3.000 Seal Assembly, Baker, 190-47 78 7,839' - 2.992 1 joint,3-1/2", 9.2#, N-80,ABC 8 9 7,870' - - Mule Shoe 10 7,810' - - Packer, Permanent, Baker Mod. D(DPM) Z 9X Notes: 1/20/17-C/O fill to 9,650' L PERFORATION DATA Cl Zone Top Btm Amt Accum Last Tie in Log SPF Perf Date C2 C 1 9,015' 9,035' 20 12 7/18/2008 CCL/GR 7-17-08 C-3,4 9,030' 9,050' 30 4 10/3/1999 1999 C-2 9,240' 9,310' 70 4&8 6/30/1972 C-5 C-2X 9,240' 9260' 20' 4 10/3/1999 1999 `:*e C-2 9,380' 9,400' 20 4&8 6/30/1972 Asa _ C-7 C-2X 9,390' 9,400' 10 4 10/3/1999 1999 €4 i`te-' t.r• C-3/4 9,480' 9,495' 15 4 6/30/1972 ' �kr�.. C-8 ,4"-'t- F + C-5 9,580' 9,650' 70 4&8 6/30/1972 � i , C-7 10,045' 10,095' 50 4&8 6/30/1972 ! '. 10,120' 10,130' 10 4 6/30/1972 ,-•3} Vk+".j C 9 '1. 14, 10,150' 10,200' 50 4&8 6/30/1972 ;tom as . ,'¢', g 10,215' 10,270' 55 4&8 6/30/1972 10,290' 10,310' 20 4&8 6/30/1972 0-8 10,432' 10,462' 30 4&8 6/30/1972 PBTD=10,989' TD=11,015' HOLE ANGLE thru Interval= 10,478' 10,578' 100 4&8 6/30/1972 C-9 10,628' 10,715' 87 4&8 6/30/1972 Updated: 02/17/17 by:JLL • • Wallace, Chris D (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Tuesday, November 21, 2017 9:24 AM To: Wallace, Chris D (DOA) Cc: Larry Greenstein Subject: BR 03-87 PTD 166-052 (GRANITE PT ST 17587 03-87) Good morning Chris, We shut in Bruce 03-87 yesterday morning due to possible tubing x IA communication. Larry and I will submit a path forward to conduct diagnostics as soon as possible thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Email DMarlowe(aThilcorp.com Hilcorp A Company Built on Energy SCANNED 1 Hilcorp Alaska, LLC ° 3800 Centerpoint Drive Suite 1400 (: t 7 Anchorage,AK 99503 Phone: 907-777-8322 AOGT Fax: 907-777-8580 March 27, 2017 Ms. Cathy P. Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 c App ., uzoi, Dear Ms. Foerster: In compliance of DIO 19 rule 5, attached is a plot, and associated data, of tubing/casing pressures and injection rates for well Granite Point St 17587-03 (Br 3-87 , PTD # 166- 052) for the year 2016. Last Mechanical Integrity test: 12/6/2013 Next MIT due: Every 4 years For the year 2016, a total of 1667 barrels of water were disposed of in the subject well. No anomalous injection pressures occurred during this period, with pressures remaining below 3000psi, indicating that fluids remained confined to the intended injection zone. Sincerely, /fr- •id Edw.#41 Reservoir Engineer Attachment 1 —Br 3-87 Injection rates and pressures • 0 C. C. CI. 1.0 VI In ca •p-i ...-1 irq r..I I 0 I I - t4 I .. , 1.0 ,....1 ' 0 "F 01 . .1 0 C C. 1.0 in al 0 t_ 1:=1 .--. LA I._ In a) C 03 ....., to :-.-- 6 , In I1.....1 : ' RII N ',, , in 0 03 in c) 0 . ....... I-1 ' kiti -I ga •C < 0 0 - I 1 ' 7 ref 0 = s. CI3 ...ci 1.1. M. I- L,D , u3 1 CD ,... ,........b................._211111111M1001...0........... mainimi..=..... iiiiiiiic.......... I , ILII ........... . ...... - r4 r--- 1 1 1 1 1 I ur-i 0 0 0 0 C. C. C. 0 C. C. C. 0 0 0 In C. 1/1 0 in rl 01 r...1 C.4 1--I • c 7-10 U v 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a N co 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M M m m m M N N N lD l0 N N m m m m m N N N l0 LD LO LD lD LD LD N N N N N N N N N N N N N N N N N N N N N N N N N N N N N 0 O N O O O O O O O O O O O O O O O O O O O O O O O O O O O O N Ln Lf) Ln Lf) Ln Ln Ln Ln Ln Ln Ln Ln LI) Ln Lf) Ln Ln Ln Ln Ln Ln Lf) Ln to Ln Lf) Ln Ln tD t0 CD LO LD lD LD LI) LD LC) LD LD l0 LD LC) lD LD LD LD LD lD LD LD LD LD lD LD lD O O) 0Ln O r1 0 oN OO O 0 O Ln Ln in Ln Ln Ln to Ln Ln Ln Ln O O 0 0 Lf) Ln Ln Ln Ln Ln to Ln Ln Ln O 0 0 0 0 N N N N N N N N N N Ln Ln in Ln N N N N N N N N N N LOD p r•-. ct dt d d d d �t cY d' dr di- d �t N CO "••••.. - 'i - [V 0 + >z m iT-1r-I r I rra-I a-I L- %-1i r-1 rri LD LD LD Q 0 - N C N N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ri r-+ ri r-I d' +- Q c-I c-I N N N N N N N N N N N N N N fV N CV N N N N N 0 0 0 0 CO Ln ++ c 0 pc 0 O \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ N N N N c-1 0 01 00 N LD Ln M N r-I O 0) CO N l0 Ln Ct M N r-I 0 \ \ *"••••.. 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Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 650 425 Subsequent to operation: 0 0 131 342 1684 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory❑ Development❑ Service El Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-582 - Contact Dan Marlowe(907)283-1329 Email dmarlowe(a�hilcorp.com Printed Name Stan W.Golis / 1 Title Operations Manager Signature C Phone (907)777-8356 Date z/Z.2-C) /z"i 1 2•ZL•/7 Form 10-404 Revised 5/2015 �" NEONS LU FEB j 2 ybmit Original Only • • • • Bruce Platform SCHEMATIC Granite Point Field Well: Br 17587 3 Hilcorp Alaska,LLC Completed: 7/21/08 RKB to TBG Head=42.80' CASING AND TUBING DETAIL Tree connection: ?? SIZE WT GRADE CONN ID TOP BTM. 1 2 I 20 133 K-55 18.73 Surf 589' 3 13-3/8" 54.5 J-55 8 rd, ST&C 12.515 Surf 2,092' 9-5/8" 43.5 S-95 ERW ST&C 8.755 Surf 52' L 4 , 40 N-80 Buttress 8.835 52' 4,676' 5 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 7" 32 N-80 Butt. 6.094 7,925' 8,014' L 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' Tubing: 3-1/2" 9.2 N-80 ABC 2.992 42.8' 7,870' JEWELRY DETAIL NO. Depth OD ID Item 1 42.80' CIW Tubing Hanger, BPVP? 2 43.80' - ? Crossover, 3-1/2"EUE 8rd Pin x 3-1/2"Buttress Pin 3 44.30' - 2.992 Pup,3-1/2", ABC 4 48.30' - 2.992 Pup, 3-1/2", ABC 6 5 58.30' - 2.992 Pup,3-1/2", ABC \ 6 7,824' 4.875 3.000 Locator, Baker 190-47 1>-- 1 OM 10 7 7,825' 4.734 3.000 Seal Assembly, Baker, 190-47 7 8 7,839' - 2.992 1 joint, 3-1/2", 9.2#, N-80,ABC 8 9 7,870' - - Mule Shoe 10 7,810' - - Packer, Permanent, Baker Mod. D(DPM) 9 Z Notes: 1/20/17-C/O fill to 9,650' L PERFORATION DATA Cl Zone Top Btm Amt Accum Last Tie in Log SPF Perf Date C2 C 1 9,015' 9,035' 20 12 7/18/2008 CCL/GR 7-17-08 C-3,4 9,030' 9,050' 30 4 10/3/1999 1999 C-2 9,240' 9,310' 70 4&8 6/30/1972 C-5 C-2X 9,240' 9260' 20' 4 10/3/1999 1999 C-2 9,380' 9,400' 20 4&8 6/30/1972 C-7 C-2X 9,390' 9,400' 10 4 10/3/1999 1999 C-3/4 9,480' 9,495' 15 4 6/30/1972 - ;,re C-8 x C-5 9,580' 9,650' 70 4&8 6/30/1972 C-7 10,045' 10,095' 50 4&8 6/30/1972 C 9 10,120' 10,130' 10 4 6/30/1972 10,150' 10,200' 50 4&8 6/30/1972 10,215' 10,270' 55 4&8 6/30/1972 / \ 10,290' 10,310' 20 4&8 6/30/1972 C-8 10,432' 10,462' 30 4&8 6/30/1972 PBTD=10,989' TD=11,015' 10,478' 10,578' 100 4&8 6/30/1972 HOLE ANGLE thru Interval= ° C-9 10,628' 10,715' 87 4&8 6/30/1972 Updated: 02/17/17 by: JLL s • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 17587 3 CTU 50-733-20437-00 166-052 1/15/17 1/20/17 Daily Operations: 01/15/17 -Sunday Mobe crew to platform (weather hold for short time at heliport). Orientate crew. PJSM. Spot real, ops cab, choke& pump. Check well, static&shut in. M/u xo spool, riser& BOPE. M/u high pressure & suction lines. M/u control lines f/pump & accumulator. Prep &start equip. Function test BOPE. Install test bar. Flood lines& BOPE with test fluid. Shell test t/4500 good. Test BOPE as per Hilcorp &AOGCC requirements. AOGCC witness waived by Jim Regg @ 8:56 am on 1-13-17. Test all to 250 low/4500 high. Finish install gooseneck to injector&stab pipe. Blow down surface lines. Secure • well & equip. for night. Rest crew. 01/16/17- Monday We finished resting crew. Fired up equip. Installed riser to injector, installed coil connector&test flange. Pull tested t/ 10k good. Filled circulating tank, attempted to fill coil w/fluid but pressured up. Bled off pressure, blew down surface lines, covered coil reel & r/u heat to it. Mix 19 bbls 9.5 Brine while thawing coil reel. Break circulation w/10 bbls brine, remove test flange, stab injector onto BOP. Launch pig in coil & blow down w/ N2. Blow down surface lines. Remove injector f/BOP, install night cap. Cut connector from coil retrieve pig. Install new coil connector, pull test t/10k, good. Cover reel &apply heat for night. Rest crew. 01/17/17-Tuesday PJSM, prep & start equip. Pull night cap. Found ice at cap, decided prep & blow through surface lines till verified clear. Function test BOPE, all good. M/U BHA= 1.69 od ctc, DHCV, stinger, 1.5" nozzle = 9.225'. Stab injector on well & p/t, good. Flood coil & break circulation at surface, good. RIH circulating t/8800', cont in hole t/tag @ 9026'. Pick up break circ @ 1.1 bpm, 3000 psi. Rih tag at 9026' work string attempt to make hole, no go. POOH t/surface. Secure well, blow down lubricator& stack. Launch pig& blow down coil w/N2. Break off lubricator, remove nozzle, no recovery of pig. Check reel verify launch,verified. Remove fluid from BOPE & riser. Setup weatherproofing around stack, cover reel & heat both for night. Mix 19 bbls Brine for freeze protect. Rest crew. 01/18/17-Wednesday PJSM. Start eq., blow through surface lines, clear plugs as needed. Mix 16 bbls 9. brine for freeze protect. Flood surface lines &coil w/brine. Recover pig c/o coil connector. Pull test t/10k. M/u MHA p/t t/3500 good. M/u BHA= CTC, MHA, 1 11/16" mud motor, 2.75" mill = 12.48'.Stab lubricator& p/t 250/4500 good.Surface test MTR good. RIH t/tag @9067'. C/o to 9406', circ @ .8BPM, 1800 psi, diff pressure 60 with max spike t/300, POOH t/7900'. Shut in & attempt to est. inj rate, pumping @ .8 BMM, t/3500psi no go. Attempt @ .4BPM, pressure up t/3500, shut do monitor. Pressure dropped 550 psi in 5 min, drop ball to open circ. sub, ball seated &sheared open @ 2400psi. PJSM f/pumping acid. Mix additives. Rih t/9140' when acid hit eot, POOH t/7800', spotting 45 bbls 10% hydrochloric acid on btm. Shut in t/bullhead, pump @ .6bpm, t/3500 psi. Shut down monitor, pressure dropped 400psi in 4 min. POOH. R/u while pulling t/pump 140 bbls w/o fluids to production. OOH, secure well. Pump brine through surface lines for freeze protect. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 17587 3 CTU 50-733-20437-00 166-052 1/15/17 1/20/17 Daily Operations: 01/19/17-Thursday Blow down lubricator, I/d BHA. R/u N2, launch pig, blow down coil, blow down surface lines. Break off lubricator, recover pig. Finish winterize. Rest crew. PJSM,get eq. running& make sure surface lines are clear. P/U injector, m/u lubricator, m/u coil connector, pull test t/10k good.Troubleshoot& change out charge pump for brine. Flood surface lines&coil w/brine. P/t coil connector& MHA t/3500psi good. M/u BHA= 1 1/2" coil connector, xo, MHA, 1 -11/16 motor, 2.75" mill. Stab lubricator, p/t good, surface test mtr good.Tih t/9000', rih dry tag @ 9216'. C/o t/9500', circ. .8bpm, 1450psi, 75-100 differential.Turned returns to production at bottoms up. 01/20/17- Friday Cont. c/o F/9500', t/9650' circ. .8bpm, 1450psi, 75-100 differential, taking returns to production. POOH t/7900', shut in to inject, pump @.7BPM, pressure up t/3500 psi. Shut down & monitor, pressure dropped 830 psi in 5 min. Drop ball t/open circ. sub. ball seated & sheared open @ 2000psi. Line up on 10% Hydrochloric acid. Rih t/9100' pump 47bbls spotting while POOH t/8000'. Cont. POOH t/surface, secure well. R/u N2 & blow down reel & surface lines, break off lubricator, I/d BHA. Found coil connector cracked, finish winterizing for night.Turn well over to production. • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday,January 27,2017 1:52 PM To: Juanita Lovett Cc: Dan Marlowe;samantha.carlisle@alaska.gov Subject: RE:Withdraw Sundry#316-071/PTD: 166-052 -Granite Pt St 17587 3 Juanita, The AOGCC will withdraw sundry 316-071 for well GPS 17587 3 as requested. Guy Schwartz Sr. Petroleum Engineer SCANNED N 0 5201:7 AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Juanita Lovett[mailto:jlovett@hilcorp.com] Sent: Friday,January 27,2017 10:12 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc: Dan Marlowe<dmarlowe@hilcorp.com> Subject:Withdraw Sundry#316-071/PTD: 166-052-Granite Pt St 17587 3 Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Scope of work was to pump an acid soak down injection tubing and across perforations to clean up any scale deposition. Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska,LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: ilovett@hilcorp.com 1 RBDMS L - F:13 1 0 2017 • • of TFJ („<"\l///,/ � THE STATE Alaska Oil and Gas h of 1fL SKA 11 Conservation Commission �..� 333 West Seventh Avenue ':1:474.1-970111* Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER Main: 907.279.1433 (4'ALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager Hilcorp Alaska, LLC SCANNED MAR IL 52017, 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil and Undefined WDSP Pool, Granite Pt St 17587 3 Permit to Drill Number: 166-052 Sundry Number: 316-582 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4C) °. Daniel T. Seamount, Jr. Commissioner DATED this / day of November, 2016. RBDMS (,‘.. NOV 2 8 2016 • • EIV STATE OF ALASKA REN0Cv0 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate E(Acid) • Pull Tubing ❑ Change Approved Program El Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: CTCO 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drip Number. Hilcorp Alaska,LLC • Exploratory ❑ Development p 166-052 1 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service El , 6.API Number. Anchorage,AK 99503 50-733-20437-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 J Granite Pt St 17587 3 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017587 ' Granite Point Field/Middle Kenai Oil Pool&Undefined WDSP ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 11,015 ' 10,075 * 9,037 L 8,189 2,705 psi N/A 9,037'OH)/ Casing Length Size MD TVD Burst Collapse Structural Conductor 589' 20" 589' 588' 3,060 psi 1,500 psi Surface 2,092' 13-3/8" 2,092' 1,998' 2,730 psi 1,130 psi Intermediate Production 8,178' 9-5/8" 8,178' 7,416' 5,750 psi 3,090 psi Liner 3,074' 7" 10,999' 10,059' 8,460 psi 8,610 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,015-10,715 . 8,169-9,778 3-1/2" 9.2#/N-80 7,870 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker Model D Perm Packer&N/A ' 7,810'(MD)7,092'(ND)&N/A 12.Attachments: Proposal Summary 2 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigrapf❑ Development❑ Service 0 • 14.Estimated Date for 15.Well Status after proposed work: 11/28/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL El• Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe©hilcorp.com Printed Name G-�j Stan W.Golis Title Operations Manager Signature c/k*"'" t"' Cirldj. Phone (907)777-8356 Date 1 (I ' (4 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test Vr +Mecchhanical Integrity Test CI Location Clearance Other: y its-co jo5• '$ °6 /e!.. f ( c2j l ` is % % I% LIII. Post Initial Injection MIT Req'd? Yes ❑ No ❑ r C Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /0—y G`/ RB®ISIS8 l- NOVOV 22U IU dP, / /// Approved b •'` APPROVED BY / (// COMMISSIONER THE COMMISSION Date: !/7 . n1 b4 111 iAL � ���ll /R +' 6Submit Form and Form 10-403 Revised 11/2015 1p ra li a ioor 1 months from the date of approval. Attachments in Duplicate • • Well Work Prognosis Well: Br 03-87 Hilcorp Alaska,LLC Date:11/08/16 Well Name: Granite Point St 17587#03 API Number: 50-733-20437-00 Current Status: Waste Disposal/Injection Leg: Leg#1 (North) Estimated Start Date: November 28, 2016 Rig: Coil Tubing Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 166-052 First Call Engineer: Dan Marlowe (907)283-1329 (0) (907)398-9904(M) Second Call Engineer: Stan Golis (907)777-8356(0) Current Bottom Hole Pressure: 4,368 psi @ 8,700'TVD 0.431 psi/ft(8.29 ppg)based on 07/14/2008 Static survey Maximum Expected BHP: 4,368 psi @ 8,700'TVD 0.431 psi/ft(8.29 ppg)based on 07/14/2008 Static survey Max Potential Surface Pressure(MPSP):2,705 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Brief Well Summary Well Bruce 03-87 is a waste disposal/injector completed in the Granite Point Field/Middle Kenai Oil Pool/Undefined WDSP. Recent wireline work has indicated scale formation in the well bore and perforation tunnels.This procedure will clean-out fill covering the perforations and acidize the perfs Procedure: 1. MIRU 1.5" Coil Tubing. 2. NU BOP and test to 250psi low/4,500psi High. (Note: Notify AOGCC 48 hours in advance of test) 3. RIH cleaning out fill to± 10,720.Circulate bottoms up. Fluids will be produced Water.All returns will be through gas buster to open top rig tanks(non-enclosed)or to production header. 4. Spot±4,500 gallons (107 bbls) of±10% Hydrochloric Acid across perforations 5. POOH with coil to liner top circulate 2x bottoms up to purge coil. 6. Soak for>_4 hours. 7. Displace into formation with ±80 bbls produced water 8. POOH and rig down coil 9. Turn well over to operations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Coil Tubing BOP Drawing 4. Flow Diagrams 5. RWO Sundry Revision Change Form •• III Bruce Platform SCHEMATIC Granite Point Field Well: Br 17587 3 Completed: 7/21/08 llileorp Alaska,ITC RKB to TBG Head=42.80' CASING AND TUBING DETAIL Tree connection: ?? SIZE WT GRADE CONN ID TOP BTM. 1 2 I 20 133 K-55 18.73 Surf 589' 13-3/8" 54.5 J-55 8 rd, ST&C 12.515 Surf 2,092' 3 9-5/8" 43.5 S-95 ERW ST&C 8.755 Surf 52' L 4 .\ 40 N-80 Buttress 8.835 52' 4,676' 5 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 7" 32 N-80 Butt. 6.094 7,925' 8,014' L. ., 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' Tubing: 3-1/2" 9.2 N-80 ABC 2.992 42.8' 7,870' j JEWELRY DETAIL NO. Depth OD ID Item 1 42.80' CIW Tubing Hanger, BPVP? 2 43.80' - ? Crossover, 3-1/2"EUE 8rd Pin x 3-1/2"Buttress Pin 3 44.30' - 2.992 Pup,3-1/2", ABC 6 4 48.30' - 2.992 Pup,3-1/2", ABC 5 58.30' - 2.992 Pup,3-1/2", ABC 1>-<1 F><1 10 6 7,824' 4.875 3.000 Locator, Baker 190-47 7 7 7,825' 4.734 3.000 Seal Assembly, Baker, 190-47 8 8 7,839' - 2.992 1 joint, 3-1/2",9.2#, N-80,ABC 9 7,870' - - Mule Shoe 9 10 7,810' - - Packer, Permanent, Baker Mod. D(DPM) 1 // A A Fill Tagged w/ GR 7/18/08 9,037' ` PERFORATION DATA Cl Zone Top Btm Amt Accum Last Tie in Log -A' SPF Perf Date C2 C 1 9,015' 9,035' 20 12 7/18/2008 CCL/GR 7-17-08 C-3,4 9,030' 9,050' 30 4 10/3/1999 1999 C-2 9,240' 9,310' 70 4&8 6/30/1972 . C-5 C-2X 9,240' 9260' 20' 4 10/3/1999 1999 C-2 9,380' 9,400' 20 4&8 6/30/1972 - ' C-7 C-2X 9,390' 9,400' 10 4 10/3/1999 1999 C-8 C-3/4 9,480' 9,495' 15 4 6/30/1972 C-5 9,580' 9,650' 70 4&8 6/30/1972 C-7 10,045' 10,095' 50 4&8 6/30/1972 C-9 10,120' 10,130' 10 4 6/30/1972 10,150' 10,200' 50 4&8 6/30/1972 10,215' 10,270' 55 4&8 6/30/1972 10,290' 10,310' 20 4&8 6/30/1972 C-8 10,432' 10,462' 30 4&8 6/30/1972 PBTD=10,989' TD=11,015' HOLE ANGLE thru Interval= 10,478' 10,578' 100 4&8 6/30/1972 C-9 10,628' 10,715' 87 4&8 6/30/1972 Updated: 1/25/16 by: JLL 0 ill Bruce Platform PROPOSED Granite Point Field Well: Br 17587 3 Completed: 7/21/08 Hilcorp Alaska.LLC RKB to TBG Head=42.80' CASING AND TUBING DETAIL Tree connection:?? SIZE WT GRADE CONN ID TOP BTM. 12 20 133 K-55 18.73 Surf 589' 13-3/8" 54.5 J-55 8 rd, ST&C 12.515 Surf 2,092' 3 9-5/8" 43.5 S-95 ERW ST&C 8.755 Surf 52' L 4 \ 40 N-80 Buttress 8.835 52' 4,676' 5 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 7" 32 N-80 Butt. 6.094 7,925' 8,014' Z 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' Tubing: 3-1/2" 9.2 N-80 ABC 2.992 42.8' 7,870' sg JEWELRY DETAIL NO. Depth OD ID Item 1 42.80' CIW Tubing Hanger, BPVP? 2 43.80' - ? Crossover,3-1/2"EUE 8rd Pin x 3-1/2"Buttress Pin 3 44.30' - 2.992 Pup,3-1/2", ABC 6 4 48.30' - 2.992 Pup,3-1/2", ABC --15 58.30' - 2.992 Pup,3-1/2", ABC 10 6 7,824' 4.875 3.000 Locator, Baker 190-47 7 7 7,825' 4.734 3.000 Seal Assembly, Baker, 190-47 8 8 7,839' - 2.992 1 joint,3-1/2",9.2#, N-80,ABC 9 7,870' - - Mule Shoe 10 7,810' - - Packer, Permanent, Baker Mod. D(DPM) z 9 z Z Fill Tagged w/ GR 7/18/08 9,037' PERFORATION DATA Cl Zone Top Btm Amt Accum Last Tie in Log SPF Perf Date C2 C-1 9,015' 9,035' 20 12 7/18/2008 CCL/GR 7-17-08 C-3,4 9,030' 9,050' 30 4 10/3/1999 1999 C-2 9,240' 9,310' 70 4&8 6/30/1972 C-5 C-2X 9,240' 9260' 20' 4 10/3/1999 1999 C-2 9,380' 9,400' 20 4&8 6/30/1972 C-7 C-2X 9,390' 9,400' 10 4 10/3/1999 1999 N.C-8 C-3/4 9,480' 9,495' 15 4 6/30/1972 C-5 9,580' 9,650' 70 4&8 6/30/1972 C-7 10,045' 10,095' 50 4&8 6/30/1972 C 9 10,120' 10,130' 10 4 6/30/1972 10,150' 10,200' 50 4&8 6/30/1972 10,215' 10,270' 55 4&8 6/30/1972 / \ 10,290' 10,310' 20 4&8 6/30/1972 C-8 10,432' 10,462' 30 4&8 6/30/1972 PBTD=10,989' TD=11,015' HOLE ANGLE thru Interval= 10,478' 10,578' 100 4&8 6/30/1972 C-9 10,628' 10,715' 87 4&8 6/30/1972 Updated: 11/09/16 by: JLL • • . in Bruce Platform Br 03-87 Coiled Tubing BOP Hilrn.rp Alaska,1.1.c 11/08/2016 Lubricator to injection head o (pi Ifni) - I_ M 1 ( I l� _ _ 41/161O , g= Blind/Shear Blind/Shear __- _j c —1 C: Blind/Shear Blind/Shear -J e °O: c_ -- Slip Slip ;0 c_ __ Pipe Pipe __ =1 Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M u 2 1/16 10M 2 1/16 10M 71 Valve,swab,CIW-FL,/cti) • 3 1/16 10M FE,HWO ,,; , r 0 0® Valve,wing,CIW-FL, ,� , 3 1/16 10M FE,HWO AP 1 eft II Valve,master,CIW-FL ® iill 3 1/16 10M FE,HW �i . IV e'c 4 11./1$ / 0 • I = wN N ITL — —B— —" .—.—.— c .3 .3 N . ooNfV V) c60 Y Ki —t:‘, CN I — G $ N -O O .0 , J+ N ._ m 3 0 o y �I o 0 c 3 0 N N N > > f0 t$ co 27 U ) .- .5 a)C L U -0 BF_ - _I a O a Q.. co Q c a) 2 c • I - 11 I I x a) 33 0 ` {Ii Z Io a)0- ) ; cn I _!_...._- Q kilik-‘7.7ri 2- iduf . .. 7- . a iII' - 1 a I� 01114, el! . C — _■ w a i E o -�! . ki.-1 1 LU � 1i% CD AtC • }I CU eat CI 600 iJ C E12 __. " -0 ccJ N F- U W `'" �m � I I t L.4 III ~� _ II ir1.,..1®1. 0, P ii i 1 t 1I, Q, -- am 0 CO CD d 0. j1 I I 1,.1 n n n n ` Ma IIS if 1�\ t87 ; ►•� I �il� !km j i [ �.M ��Fly —''',�}I I�Illlf )I(�a)] '�'i 1' V V V V 1.5_ CD la y 0 13- o 0 O NCY o LL 1--•y J ‘- m LLy yx0 C6 10 Q c.0 E Nm <O CD NNti 0:C O 0 O V= iU •� �x v� In-J • • a) w0 / > � 2 Q — ® R& i , 7E 0o ° / / 2 a = w « E ® § 3 ) = § I CSE » < » - k / 2 u) 0 e - k = . Ec \/ a o U / $ %« � -0 ■ ■ 2 ® Tr ,_ti) c a) � $ % t . o O Co � W @ co k 15 B in / 2 w (22 ko itk a a) U. ' �k ■ k as e g« C » e - co _ ..aco 0 \ -DO ') k L. V. E % ° o 0 • O k \ / a _ _0 / 0) a \ 0 c 77 co C . -a = / 2 a) = g u)2 ¢ ƒ■ § � /— a ■ co ..r.4 tri « 03 k 0. o % � E O v) qQ § q 2k & as % « o x m G m 0 § (Co .§ e 0 2 Q % £ 2 it E Ell «; © / . . : & 0 -a E0 To->. \ o oo_ V Cl) CO 2 • • VOFTJi • ...i,',���I yy��s� THE STATE Alaska Oil and Gas ;-s 1,-..---:=7:4* fAL o TASKA Conservation Commission c 5� -_; ' 333 West Seventh Avenue c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis ° c 3T1 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil &Undefined WDSP Pools, Granite Pt St 17587 3 Permit to Drill Number: 166-052 Sundry Number: 316-071 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, aliet Cathy . Foerster Chair DATED this �l day of February, 2016. RBDMS LL FEB 1 9 2016 • 4 RECEIVED STATE OF ALASKA FEB 0 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION t) S z,a7,itt APPLICATION FOR SUNDRY APPROVALS AOGut 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate 0 (Aid ' Pull Tubing ❑ Change Approved Program❑ Plug for Redrill Eli Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC , Exploratory ❑ Development ❑ 166-052 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic LI Service 0 . 6.API Number: Anchorage,AK 99503 50-733-20437-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No E✓ Granite Pt St 17587 3 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0017587 Granite Point Field/Middle Kenai Oil Pool&Undefined WDSP 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,015 • 10,075 . • 9,037 8,189 2,000 psi N/A 9,037'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 589' 20" 589' 588' 3,060 psi 1,500 psi Surface 2,092' 13-3/8" 2,092' 1,998' 2,730 psi 1,130 psi Intermediate Production 8,178' 9-5/8" 8,178' 7,416' 5,750 psi 3,090 psi Liner 3,074' 7" 10,999' 10,059' 8,460 psi 8,610 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,015-10,715 - 8,169-9,778 3-1/2" 9.2#/N-80 7,870 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Model D Perm Packer&N/A • 7,810'(MD)7,092'(TVD)&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic II 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigrapt❑ Development❑ Service [ - 14. Estimated Date for 15.Well Status after proposed work: 2/16/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL 0 • Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Trudi Hallett(907)777-8323 Email thallett(a�hilcorp.com Printed Name Stan W.Golis �Q1.,- Title Operations Manager Signature 6Oti , Phone (907)777-8356 Date '1 (Z' ( "f COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .., ;Di10 -01I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No V Subsequent Form Required: / b— '0 a i RBDMS L L. FEB 1 9 2016 APPROVED BY Approved by:A,,/ .3",, COMMISSIONER THE COMMISSION Date: I'M illibG AL ,,,,,_ z___,,, ,, 134/ �� Subin Form ane Form 10-403 Revised 11/2015 Approved application is t s rom the date of approval. /� „ achments in Duplicate • a Well Work Prognosis Well: Br 03-87 Hilcorp Alaska,►►c Date: 02/02/16 Well Name: Granite Point St 17587#03 API Number: 50- 733-20437-00 Current Status: Waste Disposal/Injection Leg: NA Estimated Start Date: February 16,2016 Rig: NA Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 166-052 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 4368 psi @ 8700' TVD (9,600' MD) (Static well head pressure 1/25/16 of 540 psi, assume fluid to surface and gradient 0.44 psi/ft) Maximum Expected BHP: 6368 psi @ 8700'TVD (9,600' MD) Max Potential Surface Pressure (MPSP): 2,000 psi treatment pump pressure limit Brief Well Summary Well Bruce 03-87 is a waste disposal/injector completed in the Granite Point Field/Middle Kenai Oil Pool/Undefined WDSP. Recent wireline work has indicated scale formation in the well bore and perforation tunnels. Hilcorp plans to pump an acid soak down the injection tubing and across the perforations to clean up any scale deposition. Procedure 1. MIRU pumping equipment. 2. Pressure test surface lines to ±2,000 psi (treatment pump relief valve limit). 3. Mix chemicals and pump in the following sequence: a. Pump produced water down tubing. b. Pump ±24 bbl xylene pre-flush @ .5 bpm. c. Pump ±4,500 gallons (107 bbls) of±10% Hydrochloric Acid @ .5 to .75 bpm until empty. *Pump in ±20 bbl batches following with produced water flush each time. d. Chase with water at same rate to displace tbg volume (±68 bbls). A0( t J 4. Shut down pump and let acid soak for >_4 hours. is L �, 5. Pump water to push chemical into formation (±80 bbls) 6. RD Pumping equipment. 7. Return well to injection. Attachments: 1. As-built Schematic 2. Pumping Unit Diagram . • a Bruce Platform SCHEMATIC Granite Point Field Well: Br 17587 3 Completed: 7/21/08 Hilcorp Alaska.LI,C RKB to TBG Head=42.80' CASING AND TUBING DETAIL Tree connection:?? SIZE WT GRADE CONN ID TOP BTM. 12 20 133 K-55 18.73 Surf 589' 13-3/8" 54.5 J-55 8 rd,ST&C 12.515 Surf 2,092' 3 9-5/8" 43.5 S-95 ERW ST&C 8.755 Surf 52' Z 4 , 40 N-80 Buttress 8.835 52' 4,676' 5 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 7" 32 N-80 Butt. 6.094 7,925' 8,014' L 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' Tubing: 3-1/2" 9.2 N-80 ABC 2.992 42.8' 7,870' JEWELRY DETAIL NO. Depth OD ID Item 1 42.80' CIW Tubing Hanger, BPVP? 2 43.80' - ? Crossover,3-1/2"EUE 8rd Pin x 3-1/2"Buttress Pin 3 44.30' - 2.992 Pup,3-1/2", ABC 6 4 48.30' - 2.992 Pup,3-1/2", ABC --1 5 58.30' - 2.992 Pup,3-1/2", ABC I810 6 7,824' 4.875 3.000 Locator, Baker 190-47 7 i 7 7,825' 4.734 3.000 Seal Assembly, Baker, 190-47 8 7,839' - 2.992 1 joint, 3-1/2", 9.2#, N-80,ABC 9 7,870' - - Mule Shoe Z 10 7,810' - - Packer, Permanent, Baker Mod. D(DPM) Z 9 Z Fill Tagged w/ GR 7/18/08 9,037' PERFORATION DATA Cl Zone Top Btm Amt Accum Last Tie in Log SPF Perf Date C2 C-1 9,015' 9,035' 20 12 7/18/2008 CCL/GR 7-17-08 C-3,4 9,030' 9,050' 30 4 10/3/1999 1999 C-2 9,240' 9,310' 70 4&8 6/30/1972 C-5 C-2X 9,240' 9260' 20' 4 10/3/1999 1999 C-2 9,380' 9,400' 20 4&8 6/30/1972 C-7 C-2X 9,390' 9,400' 10 4 10/3/1999 1999 C-3/4 9,480' 9,495' 15 4 6/30/1972 C-8 C-5 9,580' 9,650' 70 4&8 6/30/1972 C-7 10,045' 10,095' 50 4&8 6/30/1972 C 9 10,120' 10,130' 10 4 6/30/1972 92 10,150' 10,200' 50 4&8 6/30/1972 10,215' 10,270' 55 4&8 6/30/1972 / N 10,290' 10,310' 20 4&8 6/30/1972 C-8 10,432' 10,462' 30 4&8 6/30/1972 PBTD=10,989' TD=11,015' HOLE ANGLE thru Interval= 10,478' 10,578' 100 4&8 6/30/1972 C-9 10,628' 10,715' 87 4&8 6/30/1972 Updated: 1/25/16 by: JLL 4110 O• 2O E z� §� 4 \ z } 2kW ( §0 | | | | i || |. 1; 9 A . ! . � / 4 0 RECEIVED Jur_ 13 2015 AOGCC Reid Edwards Reservoir Engineer—Cook Inlet Offshore Asset Hilcorp Alaska, LLC 3800 Centerpoint Drive - Suite 100 Anchorage, AK 99503 July 10, 2015 SCANNED ASG 0 3 2015 Chris Wallace Alaska Oil and Gas Conservation Commission 333 W 7th Ave #100 Anchorage, AK 99501 Re: 2014 Annual Report for Disposal Injection Order No. 19 I Dear Chris, Attached is a plot, and associated data, of tubing/casing pressures and injection rates for well Granite Point St 17587-03 (Br-87-3 , PTD# 166-052) for the year 2014. The subject well was returned to injection 11/21/2013 after being SI since December 2008 in order to dispose of Class II fluids which include produced waters and deck drainage. An MIT of the tubing by 9 5/8"casing annulus was performed 10/24/2013 and passed. Permission was then granted by the state to return the well to injection with a follow up MIT. A second MIT, witness waived by the AOGCC, was performed and passed 12/6/2013 after the well had stabilized. The MIT results were sent via email to the AOGCC on 12/10/2013. Injection rates and pressures have been continued to be monitored through 2014 and remain stable with no indications of tubing/annulus communication. The injection pressure has been increasing throughout the year indicating an increase in reservoir pressure or degradation of the perforations. For the year 2014, 48,469 barrels of water were disposed of in the subject well. Please call with any questions or concerns. / Si •rely, "'P../ 'eid Ed a 1 'ese sir s . • -er—Cook Inlet Offshore Asset 9 i 77-8421 • Chris Wallace July 10, 2014 Page 2 N 01 0 VI 0 0 0 00 00 O l___ _ _1_-._ N 0 j A 0 N N -! 0 A fi (1 l co4----1 _ A 1 �� I N O c A i e I a ! a o _I A I I ' D I CO n I A v • _ O ni W :'..1: 40 DAI A N _O alAF. o N I O a 1 1 o I N _� O * • A I N 1 A 1 N .I -i_ O O pO V~i O 0 O co O Chris Wallace July 10, 2014 Page 3 Well: BR 03-87 Desc: Injection Permit to drill: 1660520 Admin Approval: DIO#19 API: 50-733-20437-00-00 Date Range:01/01/2014- 12/31/2014 Water Date Tubing IA OA OOA Injection 12/31/2014 1025 250 40 0 138 12/30/2014 1100 250 40 0 136 12/29/2014 1200 250 40 0 133 12/28/2014 1100 200 40 0 205 12/27/2014 1230 290 40 0 99 12/26/2014 1250 200 42 0 130 12/25/2014 1200 200 42 0 169 12/24/2014 1000 275 42 0 159 12/23/2014 1050 300 42 0 80 12/22/2014 1050 250 42 0 156 12/21/2014 1000 250 42 0 129 12/20/2014 1000 250 42 0 130 12/19/2014 1050 250 42 0 130 12/18/2014 1050 250 42 0 137 12/17/2014 1050 250 42 0 139 12/16/2014 900 250 42 0 161 12/15/2014 900 250 42 0 152 12/14/2014 1050 275 42 0 117 12/13/2014 1000 275 42 0 114 12/12/2014 1000 275 42 0 144 12/11/2014 1000 275 42 0 129 12/10/2014 1000 250 42 0 133 12/9/2014 1550 275 42 0 109 12/8/2014 950 275 40 0 132 12/7/2014 1000 275 40 0 126 12/6/2014 900 275 40 0 98 12/5/2014 950 275 40 0 130 12/4/2014 1100 275 40 0 124 12/3/2014 1000 275 40 0 151 12/2/2014 950 275 40 0 153 Chris Wallace July 10, 2014 Page 4 12/1/2014 950 275 40 0 122 11/30/2014 850 250 40 0 128 11/29/2014 800 250 40 0 127 11/28/2014 850 275 42 0 113 11/27/2014 900 275 42 0 130 11/26/2014 800 290 42 0 110 11/25/2014 1050 260 42 0 137 11/24/2014 1100 275 42 0 122 11/23/2014 900 275 42 0 126 11/22/2014 1050 275 42 0 110 11/21/2014 1000 275 42 0 138 11/20/2014 1050 275 42 0 110 11/19/2014 1050 275 42 0 122 11/18/2014 850 275 42 0 112 11/17/2014 1250 275 42 0 127 11/16/2014 900 225 40 0 135 11/15/2014 1000 250 42 0 132 11/14/2014 950 250 42 0 134 11/13/2014 800 250 42 0 133 11/12/2014 1050 250 40 0 122 11/11/2014 875 225 40 0 138 11/10/2014 850 275 40 0 131 11/9/2014 800 275 40 0 110 11/8/2014 900 275 40 0 119 11/7/2014 800 275 40 0 134 11/6/2014 850 275 40 0 136 11/5/2014 1000 275 40 0 114 11/4/2014 943 225 40 0 124 11/3/2014 957 250 42 0 131 11/2/2014 960 250 42 0 118 11/1/2014 968 250 42 0 113 10/31/2014 925 250 42 0 111 10/30/2014 981 250 42 0 116 10/29/2014 876 250 42 0 129 10/28/2014 976 250 42 0 121 10/27/2014 777 250 42 0 143 10/26/2014 1143 250 42 0 102 10/25/2014 916 250 42 0 151 10/24/2014 913 250 42 0 107 Chris Wallace July 10, 2014 Page 5 10/23/2014 907 250 42 0 114 10/22/2014 950 250 42 0 107 10/21/2014 850 250 42 0 142 10/20/2014 800 250 42 0 159 10/19/2014 825 275 42 0 86 10/18/2014 1025 275 42 0 125 10/17/2014 850 250 42 0 157 10/16/2014 900 300 42 0 94 10/15/2014 850 300 42 0 121 10/14/2014 900 275 42 0 139 10/13/2014 950 300 42 0 90 10/12/2014 950 300 42 0 159 10/11/2014 900 300 42 0 268 10/10/2014 900 300 42 0 163 10/9/2014 800 300 42 0 82 10/8/2014 970 300 42 0 122 10/7/2014 800 300 42 0 125 10/6/2014 800 300 42 0 116 10/5/2014 500 325 42 0 115 10/4/2014 925 320 42 0 98 10/3/2014 950 300 44 0 107 10/2/2014 950 340 44 0 119 10/1/2014 925 300 44 0 102 9/30/2014 945 300 44 0 116 9/29/2014 941 300 44 0 107 9/28/2014 952 300 44 0 105 9/27/2014 948 300 44 0 108 9/26/2014 1085 300 44 0 111 9/25/2014 990 300 44 0 121 9/24/2014 950 300 44 0 149 9/23/2014 900 275 44 0 114 9/22/2014 600 275 44 0 107 9/21/2014 950 250 44 0 126 9/20/2014 1400 210 44 0 189 9/19/2014 1000 125 44 0 342 9/18/2014 1000 225 44 0 198 9/17/2014 950 250 44 0 161 9/16/2014 1027 225 44 0 296 9/15/2014 929 275 44 0 186 • Chris Wallace July 10, 2014 Page 6 9/14/2014 924 275 44 0 136 9/13/2014 924 275 44 0 112 9/12/2014 923 275 44 0 152 9/11/2014 1047 275 44 0 121 9/10/2014 1072 275 44 0 165 9/9/2014 1033 275 44 0 163 9/8/2014 1044 275 44 0 118 9/7/2014 1065 275 44 0 141 9/6/2014 1090 275 44 0 116 9/5/2014 1120 275 44 0 226 9/4/2014 1026 275 44 0 178 9/3/2014 1098 275 44 0 105 9/2/2014 1004 275 44 0 157 9/1/2014 1003 275 44 0 103 8/31/2014 1073 275 44 0 128 8/30/2014 1058 275 44 0 150 8/29/2014 1017 275 44 0 161 8/28/2014 1062 275 44 0 232 8/27/2014 895 275 44 0 131 8/26/2014 800 275 44 0 103 8/25/2014 1300 275 44 0 167 8/24/2014 600 250 46 0 227 8/23/2014 1350 300 44 0 114 8/22/2014 550 300 46 0 155 8/21/2014 800 325 44 0 136 8/20/2014 850 325 44 0 130 8/19/2014 500 300 46 0 123 8/18/2014 500 300 44 0 129 8/17/2014 500 300 44 0 151 8/16/2014 500 300 44 0 140 8/15/2014 550 300 44 0 153 8/14/2014 500 300 44 0 141 8/13/2014 550 300 44 0 160 8/12/2014 550 300 44 0 132 8/11/2014 500 300 44 0 150 8/10/2014 1000 280 44 0 127 8/9/2014 1000 280 44 0 134 8/8/2014 700 300 44 0 120 8/7/2014 550 300 44 0 139 Chris Wallace July 10, 2014 Page 7 8/6/2014 900 325 44 0 109 8/5/2014 1008 300 44 0 154 8/4/2014 948 300 44 0 199 8/3/2014 941 300 44 0 104 8/2/2014 829 200 44 0 107 8/1/2014 869 200 44 0 84 7/31/2014 888 200 44 0 118 7/30/2014 909 200 44 0 110 7/29/2014 1100 200 44 0 150 7/28/2014 800 200 44 0 188 7/27/2014 900 300 44 0 151 7/26/2014 1300 250 44 0 148 7/25/2014 700 200 44 0 304 7/24/2014 550 275 44 0 125 7/23/2014 800 300 44 0 133 7/22/2014 700 250 44 0 135 7/21/2014 1100 275 44 0 171 7/20/2014 650 250 44 0 182 7/19/2014 450 400 44 0 44 7/18/2014 800 400 44 0 41 7/17/2014 750 300 44 0 150 7/16/2014 950 400 44 0 105 7/15/2014 770 300 44 0 116 7/14/2014 870 300 44 0 150 7/13/2014 993 300 44 0 123 7/12/2014 1021 200 44 0 132 7/11/2014 1002 300 44 0 241 7/10/2014 941 300 44 0 277 7/9/2014 959 300 44 0 151 7/8/2014 770 300 44 0 253 7/7/2014 1000 300 44 0 64 7/6/2014 996 300 44 0 73 7/5/2014 1012 300 44 0 135 7/4/2014 1023 300 44 0 126 7/3/2014 1025 300 44 0 148 7/2/2014 1042 300 44 0 139 7/1/2014 950 300 44 0 135 6/30/2014 600 300 44 0 137 6/29/2014 1000 300 44 0 140 Chris Wallace July 10, 2014 Page 8 6/28/2014 650 325 44 0 138 6/27/2014 1350 250 44 0 175 6/26/2014 850 160 44 0 351 6/25/2014 650 300 44 0 168 6/24/2014 800 300 44 0 175 6/23/2014 700 340 40 0 179 6/22/2014 800 340 40 0 179 6/21/2014 800 340 40 0 272 6/20/2014 700 340 40 0 231 6/19/2014 800 340 40 0 71 6/18/2014 700 340 40 0 71 6/17/2014 700 340 40 0 82 6/16/2014 700 340 40 0 102 6/15/2014 800 380 40 0 64 6/14/2014 500 340 40 0 99 6/13/2014 500 340 40 0 100 6/12/2014 500 350 40 0 97 6/11/2014 500 350 40 0 84 6/10/2014 750 325 40 0 133 6/9/2014 800 225 40 0 114 6/8/2014 800 225 40 0 169 6/7/2014 850 225 40 0 125 6/6/2014 800 225 40 0 146 6/5/2014 800 225 40 0 141 6/4/2014 960 225 40 0 138 6/3/2014 800 225 40 0 137 6/2/2014 925 225 40 0 179 6/1/2014 800 250 40 0 185 5/31/2014 850 300 41 0 168 5/30/2014 800 275 41 0 209 5/29/2014 500 300 41 0 166 5/28/2014 800 300 41 0 140 5/27/2014 900 300 41 0 163 5/26/2014 650 250 40 0 185 5/25/2014 800 340 41 0 93 5/24/2014 800 300 40 0 133 5/23/2014 800 300 40 0 151 5/22/2014 850 300 40 0 150 5/21/2014 850 300 40 0 207 Chris Wallace July 10, 2014 Page 9 5/20/2014 740 300 40 0 159 5/19/2014 742 300 40 0 88 5/18/2014 710 300 40 0 85 5/17/2014 686 300 40 0 80 5/16/2014 688 300 40 0 67 5/15/2014 760 300 40 0 73 5/14/2014 745 300 40 0 85 5/13/2014 890 300 40 0 105 _ 5/12/2014 901 300 40 0 160 5/11/2014 906 300 40 0 145 5/10/2014 872 300 40 0 137 5/9/2014 919 300 40 0 138 5/8/2014 946 300 40 0 130 5/7/2014 875 300 40 0 262 5/6/2014 740 300 40 0 159 5/5/2014 850 300 40 0 120 5/4/2014 850 250 40 0 173 5/3/2014 850 250 40 0 180 5/2/2014 800 200 40 0 171 5/1/2014 800 300 40 0 132 4/30/2014 850 250 40 0 139 4/29/2014 550 225 38 0 201 4/28/2014 500 250 38 0 176 4/27/2014 450 250 38 0 165 4/26/2014 800 275 38 0 144 4/25/2014 800 250 38 0 165 4/24/2014 600 200 38 0 167 4/23/2014 600 200 36 0 194 4/22/2014 500 200 36 0 198 4/21/2014 700 200 36 0 199 4/20/2014 700 225 36 0 196 4/19/2014 600 225 36 0 145 4/18/2014 475 275 35 0 120 4/17/2014 500 275 35 0 116 4/16/2014 650 275 34 0 115 4/15/2014 838 275 34 0 114 4/14/2014 838 125 34 0 120 4/13/2014 838 125 34 0 163 4/12/2014 838 125 34 0 95 Chris Wallace July 10, 2014 Page 10 4/11/2014 838 125 34 0 93 4/10/2014 838 125 34 0 115 4/9/2014 838 125 34 0 105 4/8/2014 838 125 34 0 160 4/7/2014 631 125 34 0 256 4/6/2014 626 250 34 0 149 4/5/2014 655 250 34 0 105 4/4/2014 646 150 34 0 198 4/3/2014 641 75 36 0 321 4/2/2014 721 150 36 0 240 4/1/2014 711 175 36 0 219 3/31/2014 641 150 36 0 295 3/30/2014 546 225 34 0 272 3/29/2014 568 350 34 0 119 3/28/2014 649 325 34 0 113 3/27/2014 567 325 34 0 121 3/26/2014 567 325 34 0 122 3/25/2014 562 300 34 0 137 3/24/2014 598 305 36 0 113 3/23/2014 631 305 36 0 90 3/22/2014 561 305 36 0 149 3/21/2014 630 305 36 0 148 3/20/2014 519 380 36 0 134 3/19/2014 92 420 36 0 106 3/18/2014 161 375 32 0 0 3/17/2014 561 375 32 0 167 3/16/2014 549 300 34 0 131 3/15/2014 563 350 34 0 98 ' 3/14/2014 566 300 34 0 121 3/13/2014 566 325 34 0 124 3/12/2014 593 300 34 0 120 3/11/2014 570 350 34 0 121 3/10/2014 547 350 34 0 125 3/9/2014 546 99 3/8/2014 546 340 34 0 103 3/7/2014 548 350 34 0 100 3/6/2014 564 350 34 0 100 3/5/2014 560 350 34 0 100 3/4/2014 559 350 32 0 126 Chris Wallace July 10, 2014 Page 11 3/3/2014 555 350 34 0 111 3/2/2014 545 335 34 0 101 3/1/2014 531 375 34 0 106 2/28/2014 529 350 34 0 82 2/27/2014 532 375 34 0 104 2/26/2014 531 360 32 0 98 2/25/2014 350 350 34 0 110 2/24/2014 350 350 32 0 104 2/23/2014 350 375 32 0 83 2/22/2014 350 350 32 0 95 2/21/2014 400 370 32 0 97 2/20/2014 450 375 32 0 62 2/19/2014 425 275 32 0 124 2/18/2014 650 275 32 0 100 2/17/2014 650 375 36 0 111 2/16/2014 650 375 36 0 96 2/15/2014 650 375 36 0 105 2/14/2014 650 375 36 0 80 2/13/2014 650 375 36 0 68 2/12/2014 650 375 36 0 68 2/11/2014 650 375 36 0 98 2/10/2014 594 375 36 0 94 2/9/2014 570 350 32 0 101 2/8/2014 561 350 34 0 132 2/7/2014 556 400 36 0 94 2/6/2014 607 400 34 0 71 2/5/2014 625 350 32 0 66 2/4/2014 527 400 34 0 86 2/3/2014 537 350 34 0 88 2/2/2014 544 375 34 0 95 2/1/2014 548 400 34 0 85 1/31/2014 552 375 34 0 105 1/30/2014 547 350 36 0 104 1/29/2014 575 375 34 0 76 1/28/2014 546 350 34 0 119 1/27/2014 544 350 32 0 105 1/26/2014 593 350 32 0 98 1/25/2014 595 350 32 0 94 1/24/2014 566 350 32 0 146 ' Chris Wallace July 10, 2014 Page 12 1/23/2014 542 350 32 0 153 1/22/2014 514 400 32 0 115 1/21/2014 523 400 32 0 70 1/20/2014 518 400 32 0 89 1/19/2014 500 400 32 0 68 1/18/2014 369 330 32 0 104 1/17/2014 570 400 32 0 100 1/16/2014 575 400 32 0 99 1/15/2014 350 400 32 0 106 1/14/2014 350 400 32 0 109 1/13/2014 400 440 32 0 56 1/12/2014 500 350 32 0 109 1/11/2014 400 425 34 0 70 1/10/2014 500 375 32 0 81 1/9/2014 350 400 32 0 100 1/8/2014 400 400 32 0 52 1/7/2014 400 300 32 0 99 1/6/2014 400 350 32 0 78 1/5/2014 400 350 32 0 111 1/4/2014 400 350 32 0 109 1/3/2014 400 350 32 0 79 1/2/2014 400 350 32 0 152 1/1/2014 400 350 32 0 127 Imag(.~.._~iect Well History File Cover r XHVZE This page identifies those items that were not scanned during the initial production Scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ ~2 ~-(~ ~, well History File Identifier Organizing RESCAN [] Color items: [] ~e items: ~ Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of vadous kinds [] Other BY: BEVERL~ VINCENT SHERYL MARIA WINDY Project Proofing BY: BEVER[~~ VINCENT SHERYL MARIA WINDY Scanning Preparation ~ x 30 = BY: BEVERL~'~INCENT SHERYL MARia WINDY + _~-'~ = TOTAl- PAGES Production Scanning Stage 1 BY: Stage 2 BY: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL A'i-I'ENTION IS REQUIRED ON AN INDiViDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) PAGE COUNT MATCHES NUMBER IN SCANNING PREPAI~TiON: ~ YES NO ~ROBIN VINCENT SHERYL MARIA WINDY DATE:~~ I(lO~ /S/ ~%. I~iN STAGE t, PAGE(S)DISCREPAN,~W~RE FOUND: yes - NO BEVERLY ROBIN VINCENT SHERYL MARIA ~ DATE~ ~( ~~ ~~' IIIIIIlilll II ReScanned (i~dividual page [speciM etze,f~] sc~mh~g completed) RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /S/ Quality'Checked 12/10/02Rev3NOTScanned.wpd RECEIVED JUL 2 9 2014 AOGCC Reid Edwards Reservoir Engineer — Cook Inlet Offshore Asset Hilcorp Alaska, LLC 3800 Centerpoint Drive - Suite 100 Anchorage, AK 99503 July 24, 2014 Chris Wallace Alaska Oil and Gas Conservation Commission 333 W 7u' Ave #100 Anchorage, AK 99501 SCANNED Re: 2013 Annual Report for Disposal Injection Order No. 19 Dear Chris, Attached is a plot, and associated data, of tubing / casing pressures and injection rates for well Granite Point St 17587-03 (Br -87-3 , PTD # 166-052) for the year 2013. The subject well was returned to injection 11/21/2013 after being SI since December 2008 in order to dispose of Class II fluids which include produced waters and deck drainage. An MIT of the tubing by 9 5/8" casing annulus was performed 10/24/2013 and passed. Permission was then granted by the state to return the well to injection with a follow up MIT. A second MIT, witness waived by the AOGCC, was performed and passed 12/6/2013 after the well had stabilized. The MIT results were sent via email to the AOGCC on 12/10/2013. Injection rates and pressures have been continued to be monitored through 2014 and remain stable with no indications of tubing / annulus communication. The stable rates and pressures also indicate that there is no degradation of injectivity from disposal operations since returning the well to injection. For the year 2013, 4,303 barrels of water were disposed of in the subject well. Please call with any questions or concerns. 907-777-8421 t Offshore Asset Chris Wallace July 24, 2014 Page 2 U p Chris Wallace July 24, 2014 Page 3 Well: BR 03-87 Desc: Injection Permit to drill: 1660520 Admin Approval: DIO #19 API: 50-733-20437-00-00 Date Range: 01/01/2013 - 01/01/2014 Date Tubing 95/8 13 3/8 20 Water In ection 1/1/2014 400 350 32 0 127 12/31/2013 400 350 32 0 96 12/30/2013 400 350 32 0 89 12/29/2013 500 325 32 0 118 12/28/2013 450 350 32 0 95 12/27/2013 550 380 32 0 85 12/26/2013 500 300 32 0 160 12/25/2013 400 350 32 0 118 12/24/2013 543 350 32 0 96 12/23/2013 543 350 34 0 122 12/22/2013 543 350 34 0 102 12/21/2013 543 350 34 0 92 12/20/2013 543 350 34 0 96 12/19/2013 543 350 34 0 97 12/18/2013 543 350 34 0 69 12/17/2013 568 350 34 0 92 12/16/2013 536 375 34 0 113 12/15/2013 564 350 34 0 115 12/14/2013 556 400 34 0 114 12/13/2013 751 400 32 0 99 12/12/2013 571 400 36 0 114 12/11/2013 535 400 36 0 91 12/10/2013 561 400 36 0 105 12/9/2013 441 450 36 0 101 12/8/2013 538 450 36 0 43 12/7/2013 633 425 36 0 98 12/6/2013 604 400 36 0 113 12/5/2013 590 350 32 0 93 12/4/2013 623 320 32 0 97 Chris Wallace July 24, 2014 Page 4 12/3/2013 637 400 34 0 120 12/2/2013 595 400 34 0 121 12/1/2013 602 450 34 0 109 11/30/2013 626 400 34 0 98 11/29/2013 593 154 11/28/2013 620 81 11/27/2013 631 450 34 0 94 11/26/2013 699 350 34 0 85 11/25/2013 705 350 34 0 172 11/24/2013 711 400 32 0 159 11/23/2013 640 450 36 0 102 11/22/2013 665 600 36 0 88 11/21/2013 300 1000 36 0 97 11/20/2013 300 1250 36 0 0 11/19/2013 300 1250 36 0 0 11/18/2013 300 1250 36 0 0 11/17/2013 300 1250 36 0 0 11/16/2013 300 1250 36 0 0 11/15/2013 300 1250 36 0 0 11/14/2013 300 1250 36 0 0 11/13/2013 300 1250 36 0 0 11/12/2013 300 1250 36 0 0 11/11/2013 300 1200 36 0 0 11/10/2013 300 1200 36 0 0 11/9/2013 300 1200 36 0 0 11/8/2013 300 1200 36 0 0 11/7/2013 300 1200 36 0 0 11/6/2013 300 1200 36 0 0 11/5/2013 300 1200 36 0 0 11/4/2013 300 1200 36 0 0 11/3/2013 300 1300 36 0 0 11/2/2013 300 1250 38 0 0 11/1/2013 300 1150 36 0 0 10/31/2013 300 1150 38 0 0 10/30/2013 300 1150 36 0 0 10/29/2013 300 1150 36 0 0 10/28/2013 300 1100 36 0 0 10/27/2013 300 0 10/26/2013 300 1100 38 0 0 Chris Wallace July 24, 2014 Page 5 10/25/2013 300 1100 38 0 0 10/24/2013 300 1825 38 0 0 10/23/2013 300 1300 36 0 0 10/22/2013 300 1300 36 0 0 10/21/2013 245 1300 36 0 0 10/20/2013 225 1300 36 0 0 10/19/2013 450 1500 36 0 0 10/18/2013 300 1500 36 0 0 10/17/2013 300 550 36 0 0 10/16/2013 300 550 36 0 0 10/15/2013 300 550 36 0 0 10/14/2013 300 555 36 0 0 10/13/2013 300 550 36 0 0 10/12/2013 300 550 36 0 0 10/11/2013 300 550 36 0 0 10/10/2013 300 550 36 0 0 10/9/2013 300 550 36 0 0 10/8/2013 300 550 36 0 0 10/7/2013 300 550 34 0 0 10/6/2013 300 525 36 0 0 10/5/2013 300 525 36 0 0 10/4/2013 300 525 36 0 0 10/3/2013 300 525 36 0 0 10/2/2013 300 525 36 0 0 10/1/2013 300 525 36 0 0 9/30/2013 300 525 36 0 0 9/29/2013 300 525 36 0 0 9/28/2013 300 525 36 0 0 9/27/2013 300 525 36 0 0 9/26/2013 300 525 36 0 0 9/25/2013 300 525 36 0 0 9/24/2013 300 525 36 0 0 9/23/2013 300 525 36 0 0 9/22/2013 300 525 36 0 0 9/21/2013 300 525 36 0 0 9/20/2013 300 525 36 0 0 9/19/2013 300 525 36 0 0 9/18/2013 300 525 36 0 0 9/17/2013 300 525 36 0 0 Chris Wallace July 24, 2014 Page 6 9/16/2013 300 525 36 0 0 9/15/2013 300 525 36 0 0 9/14/2013 300 525 36 0 0 9/13/2013 300 525 36 0 0 9/12/2013 300 525 36 0 0 9/11/2013 300 525 36 0 0 9/10/2013 300 525 36 0 0 9/9/2013 300 525 36 0 0 9/8/2013 300 525 36 0 0 9/7/2013 300 525 36 0 0 9/6/2013 300 525 36 0 0 9/5/2013 300 525 36 0 0 9/4/2013 300 525 36 0 0 9/3/2013 300 525 36 0 0 9/2/2013 300 550 36 0 0 9/1/2013 300 550 36 0 0 8/31/2013 300 550 36 0 0 8/30/2013 300 550 36 0 0 8/29/2013 300 550 36 0 0 8/28/2013 300 550 36 0 0 8/27/2013 300 550 36 0 0 8/26/2013 300 550 36 0 0 8/25/2013 300 550 36 0 0 8/24/2013 300 550 36 0 0 8/23/2013 300 550 36 0 0 8/22/2013 300 550 36 0 0 8/21/2013 300 550 36 0 0 8/20/2013 300 550 36 0 0 8/19/2013 300 550 36 0 0 8/18/2013 300 550 36 0 0 8/17/2013 300 550 36 0 0 8/16/2013 300 550 36 0 0 8/15/2013 300 550 36 0 0 8/14/2013 300 550 36 0 0 8/13/2013 300 550 36 0 0 8/12/2013 300 525 36 0 0 8/11/2013 300 525 36 0 0 8/10/2013 300 525 36 0 0 8/9/2013 300 525 36 0 0 Chris Wallace July 24, 2014 Page 7 8/8/2013 300 525 36 0 0 8/7/2013 300 525 36 0 0 8/6/2013 300 525 36 0 0 8/5/2013 300 525 36 0 0 8/4/2013 300 525 36 0 0 8/3/2013 300 525 36 0 0 8/2/2013 300 525 36 0 0 8/1/2013 300 525 36 0 0 7/31/2013 300 525 36 0 0 7/30/2013 300 525 36 0 0 7/29/2013 300 525 36 0 0 7/28/2013 300 525 36 0 0 7/27/2013 300 525 36 0 0 7/26/2013 300 525 36 0 0 7/25/2013 300 525 36 0 0 7/24/2013 300 525 36 0 0 7/23/2013 300 525 36 0 0 7/22/2013 300 525 34 0 0 7/21/2013 300 525 34 0 0 7/20/2013 300 525 34 0 0 7/19/2013 300 525 34 0 0 7/18/2013 300 525 34 0 0 7/17/2013 300 525 34 0 0 7/16/2013 300 525 34 0 0 7/15/2013 300 525 34 0 0 7/14/2013 300 525 34 0 0 7/13/2013 300 525 34 0 0 7/12/2013 300 525 34 0 0 7/11/2013 300 525 34 0 0 7/10/2013 300 525 34 0 0 7/9/2013 300 525 34 0 0 7/8/2013 300 525 34 0 0 7/7/2013 300 525 34 0 0 7/6/2013 300 525 34 0 0 7/5/2013 300 525 32 0 0 7/4/2013 300 525 32 0 0 7/3/2013 300 525 32 0 0 7/2/2013 300 525 32 0 0 7/1/2013 300 525 32 0 0 Chris Wallace July 24, 2014 Page 8 6/30/2013 300 525 32 0 0 6/29/2013 300 525 32 0 0 6/28/2013 300 525 32 0 0 6/27/2013 300 525 32 0 0 6/26/2013 300 525 32 0 0 6/25/2013 300 525 32 0 0 6/24/2013 300 525 32 0 0 6/23/2013 300 525 32 0 0 6/22/2013 300 525 32 0 0 6/21/2013 300 525 34 0 0 6/20/2013 300 525 34 0 0 6/19/2013 300 525 34 0 0 6/18/2013 300 525 32 0 0 6/17/2013 300 525 32 0 0 6/16/2013 300 525 32 0 0 6/15/2013 300 525 32 0 0 6/14/2013 300 525 32 0 0 6/13/2013 300 525 32 0 0 6/12/2013 300 525 32 0 0 6/11/2013 300 525 32 0 0 6/10/2013 300 525 32 0 0 6/9/2013 300 525 32 0 0 6/8/2013 300 525 32 0 0 6/7/2013 300 525 32 0 0 6/6/2013 300 525 32 0 0 6/5/2013 300 525 32 0 0 6/4/2013 300 525 32 0 0 6/3/2013 300 525 32 0 0 6/2/2013 300 525 32 0 0 6/1/2013 300 525 32 0 0 5/31/2013 300 525 32 0 0 5/30/2013 300 525 32 0 0 5/29/2013 300 525 32 0 0 5/28/2013 300 525 32 0 0 5/27/2013 300 525 30 0 0 5/26/2013 300 525 30 0 0 5/25/2013 300 525 30 0 0 5/24/2013 300 525 30 0 0 5/23/2013 300 525 30 0 0 Chris Wallace July 24, 2014 Page 9 5/22/2013 300 525 30 0 0 5/21/2013 300 525 30 0 0 5/20/2013 300 525 30 0 0 5/19/2013 300 525 30 0 0 5/18/2013 300 525 30 0 0 5/17/2013 300 525 30 0 0 5/16/2013 300 525 30 0 0 5/15/2013 300 525 32 0 0 5/14/2013 300 525 32 0 0 5/13/2013 300 550 30 0 0 5/12/2013 300 550 30 0 0 5/11/2013 300 550 30 0 0 5/10/2013 300 550 30 0 0 5/9/2013 300 550 30 0 0 5/8/2013 300 550 30 0 0 5/7/2013 300 550 30 0 0 5/6/2013 300 550 30 0 0 5/5/2013 300 550 30 0 0 5/4/2013 300 550 30 0 0 5/3/2013 300 550 30 0 0 5/2/2013 300 550 30 0 0 5/1/2013 300 550 30 0 0 4/30/2013 300 550 30 0 0 4/29/2013 300 550 30 0 0 4/28/2013 300 550 30 0 0 4/27/2013 300 550 30 0 0 4/26/2013 300 550 30 0 0 4/25/2013 300 550 30 0 0 4/24/2013 300 550 30 0 0 4/23/2013 300 550 30 0 0 4/22/2013 300 525 30 0 0 4/21/2013 300 525 30 0 0 4/20/2013 300 525 30 0 0 4/19/2013 300 525 30 0 0 4/18/2013 1 300 525 30 0 0 4/17/2013 300 525 30 0 0 4/16/2013 300 525 30 0 0 4/15/2013 300 525 30 0 0 4/14/2013 300 525 30 0 0 Chris Wallace July 24, 2014 Page 10 4/13/2013 300 525 30 0 0 4/12/2013 300 525 30 0 0 4/11/2013 300 525 30 0 0 4/10/2013 300 525 30 0 0 4/9/2013 300 525 30 0 0 4/8/2013 300 525 30 0 0 4/7/2013 300 525 30 0 0 4/6/2013 300 525 30 0 0 4/5/2013 300 525 28 0 0 4/4/2013 300 525 28 0 0 4/3/2013 300 525 28 0 0 4/2/2013 300 525 28 0 0 4/1/2013 300 525 28 0 0 3/31/2013 300 525 28 0 0 3/30/2013 300 525 28 0 0 3/29/2013 300 525 28 0 0 3/28/2013 300 525 28 0 0 3/27/2013 300 525 28 0 0 3/26/2013 300 525 28 0 0 3/25/2013 300 525 28 0 0 3/24/2013 300 525 28 0 0 3/23/2013 300 525 28 0 0 3/22/2013 300 525 28 0 0 3/21/2013 300 525 28 0 0 3/20/2013 300 525 28 0 0 3/19/2013 300 525 28 0 0 3/18/2013 300 0 3/17/2013 300 0 3/16/2013 300 0 3/15/2013 300 0 3/14/2013 300 0 3/13/2013 300 0 3/12/2013 300 0 3/11/2013 300 525 28 0 0 3/10/2013 300 525 28 0 0 3/9/2013 300 525 28 0 0 3/8/2013 300 525 28 0 0 3/7/2013 300 525 28 0 0 3/6/2013 300 525 28 0 0 Chris Wallace July 24, 2014 Page 11 3/5/2013 300 525 28 0 0 3/4/2013 300 525 28 0 0 3/3/2013 300 525 28 0 0 3/2/2013 300 525 28 0 0 3/1/2013 300 525 28 0 0 2/28/2013 300 525 28 0 0 2/27/2013 300 525 28 0 0 2/26/2013 300 525 28 0 0 2/25/2013 300 525 28 0 0 2/24/2013 300 525 28 0 0 2/23/2013 300 525 28 0 0 2/22/2013 300 525 28 0 0 2/21/2013 300 525 28 0 0 2/20/2013 300 525 28 0 0 2/19/2013 300 525 28 0 0 2/18/2013 300 525 28 0 0 2/17/2013 300 525 28 0 0 2/16/2013 300 525 28 0 0 2/15/2013 300 525 28 0 0 2/14/2013 300 525 28 0 0 2/13/2013 300 525 28 0 0 2/12/2013 300 525 28 0 0 2/11/2013 300 525 28 0 0 2/10/2013 300 525 28 0 0 2/9/2013 300 525 28 0 0 2/8/2013 300 525 28 0 0 2/7/2013 300 525 28 0 0 2/6/2013 300 525 28 0 0 2/5/2013 300 525 28 0 0 2/4/2013 300 0 2/3/2013 300 525 28 0 0 2/2/2013 300 525 28 0 0 2/1/2013 300 0 1/31/2013 300 0 1/30/2013 300 0 1/29/2013 300 525 28 0 0 1/28/2013 300 525 28 0 0 1/27/2013 300 525 28 0 0 1/26/2013 300 525 28 0 0 Chris Wallace July 24, 2014 Page 12 1/25/2013 300 525 28 0 0 1/24/2013 300 525 28 0 0 1/23/2013 300 525 28 0 0 1/22/2013 300 525 28 0 0 1/21/2013 300 0 1/20/2013 300 0 1/19/2013 300 0 1/18/2013 300 525 28 0 0 1/17/2013 300 525 28 0 0 1/16/2013 300 525 28 0 0 1/15/2013 300 525 28 0 0 1/14/2013 300 525 28 0 0 1/13/2013 300 525 28 0 0 1/12/2013 300 525 28 0 0 1/11/2013 300 525 28 0 0 1/10/2013 300 525 28 0 0 1/9/2013 300 525 28 0 0 1/8/2013 300 525 28 0 0 1/7/2013 300 525 28 0 0 1/6/2013 300 525 28 0 0 1/5/2013 300 525 28 0 0 1/4/2013 300 525 28 0 0 1/3/2013 300 525 28 0 0 1/2/2013 300 525 28 0 0 1/1/2013 300 550 28 0 0 6r--Udt, P & Sloe 175b7-'' 7S- /4"oSZrJ Regg, James B (DOA) ' From. Larry Greenstein [Igreenstein@hilcorp.com] Sent: Tuesday, December 10, 2013 1:25 PM To: Wallace, Chris D (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: Glen Payment; Tim Cowan; Stuart Allison; Chester Holt Subject: MIT Granite Pt St 17587 #3 (Br 3-87) 12-06-13 (PTD# 1660520) Attachments: Br 3-87 MIT Chart 12-6-13.pdf; MIT Bruce 12-6-13.xls Gentlepeople, Here is the official report of the successful MIT on the Bruce 3-87 well PTD# 1660520 performed on 12-6-13. The AOGCC witnessing was waived. The well was injecting while the MIT was being performed, but as a batch disposal well, the tubing pressure had not stabilized. The casing pressure did not track the increase in the tubing pressure and remained solid at 1850 psi for a successful MITIA. Larry `�- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regg(cDalaska.gov: AOGCC.Inspectorsa-alaska.gov: phoebe. brooks(cbalaska.gov chhs.wallaceftalaska.gov OPERATOR: Hilcorp Alaska, LLC FIELD / UNIT / PAD: Granite Point Field / NGPU / Bruce Platform(�Gl DATE: 11 OPERATOR REP: AOGCC REP: 12/06/13 Stuart Allison TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Form 10-426 (Revised 11/2012) MIT Bruce 12-6-13.xis INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance 0 = Other (describe in notes) Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Br 3-87 1 Type In'. W TVD 1 7,091' Tubing 535 540 550 558 567 580 1 Interval 0 P.T.D. 1 1660520 1 Typetestl P Test psi 1773 Casing 450 1850 1850 1850 1850 1850 P/F P Notes: MIT performed after restart of disposal operations ✓ AOGCC witnessing waived OA 37 37 37 37 37 37 Well I Type In'. I TVD I Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well I Type In'. TVD I Tubing Interval P.T.D.1 I Type test I Test psil Casing P/F Notes: OA Well I T pe In'. I TVD I Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well I Type In'. I TVD Tubing Interval P.T.D. I Type test I Test psi I Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Form 10-426 (Revised 11/2012) MIT Bruce 12-6-13.xis INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance 0 = Other (describe in notes) 5 r�■.••� 6 AM — J O.00O / ' _ 000 / - 060 53 01, 45 too / -sopfF,50 EL O 040 L) -� / ORAPW OONTROLs .mac` \\ \ 1 tioN , � L L% S o, L '�.�AA 1 Ww for, / CHART N0. MP-5000 - I A- 0 MFTFG 3- g� O O OEA cli I O O G+ I O O O � A O O A i O O0 CA 0 1. o 1300 Aw F t cv u?_ O / 00 t i c REMARKS / 00 0002 °��, r /. 00�` \ \�.��,, ,• 001'..,._^�'" p i i i OV 00 sp 5� Wd N 9 el • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday, August 22, 2012 1:14 PM To: 'Reid Edwards' Cc: Larry Greenstein Subject: RE: Bruce -3 -87 2011 Annual report for Disposal Injection Order No. 19 PTD 1660520 Reid, For this well, with zero injection, the email below is satisfactory. I will file the report, and I look forward to seeing this well utilized in the future. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission SCANNED MAY 0 3 2013 333 West 7 Avenue Anchorage, AK 99501 (907) 793 -1250 (phone) (907) 276 -7542 (fax) chris.wallacePalaska.gov From: Reid Edwards [ mailto:reedwards(ahilcoro.com] Sent: Wednesday, August 22, 2012 10:02 AM To: Wallace, Chris D (DOA) Cc: Larry Greenstein Subject: Bruce -3 -87 2011 Annual report for Disposal Injection Order No. 19 Chris, Attached is a graph and a table detailing the shut -in condition of the disposal well Granite Point State 17587 #3 (Bruce -3- 87) for the year 2011. There were no fluids injected in Br -3 -87 in 2011. The last injection into the well was in December of 2008. Upon deciding that the well wouldn't be used again for quite some time, the imposed pressure on the casing has been bled down and held steady. Please let me know if this notice will suffice for official notification or if a formal document will be required. Thanks Reid Edwards — Reservoir Engineer Hilcorp Alaska LLC Office: 907 - 777 -8421 Cell: 907 -250 -5081 1 ',Pressure & Rate vs Time - Well Br 1758' 600 - ......9 5/8" ' 500 13 3/8" ' -- — Tubing 400 — T m 300 a 200 — 100 0 -I • - --- ,.-_- ....-- _, --- - _.. - "-' O 71--z _ _ _ O o o a m N N n 0 co Z M O t�'1 co co N N N N N N N O 0 n n n O n n 0 O- .-- "'� •� " Report Date 13 3/8" 20" TIO R e (' 01/01/12 26 0 12/31/11 26 0 300 Data Sheet 12/30/11 26 0 300 12/29/11 28 0 300 12/28/11 28 0 300 O p tt13 Br 17587 03 12/27/11 28 0 300 �� VIP ‘N( l� L 12/26/11 26 0 300 12/25/11 26 0 300 12/24/11 26 0 300 12/23/11 26 0 300 12/22/11 26 0 300 Permit # 1660520 12/21/11 26 0 300 12/20/11 26 0 300 12/19/11 26 0 300 Sundry # 399 -062 12/18/11 25 0 300 12/17/11 26 0 300 12/16/11 25 0 300 API # 50- 733 - 20437 -00 12/15/11 25 0 300 12/14/11 25 0 300 12/13/11 25 0 300 12/31/2010 to 01/01/2012 12/12/11 25 0 300 12/11/11 25 0 300 12/10/11 25 0 300 12/09/11 25 0 300 12/08/11 25 0 300 12/07/11 25 0 300 12/06/11 25 0 300 12/05/11 25 0 300 12/04/11 25 0 300 12/03/11 25 0 300 12/02/11 25 0 300 12/01/11 25 0 300 11/30/11 25 0 300 11/29/11 25 0 300 11/28/11 26 0 300 11/27/11 26 0 300 8/22/20121:1, • • - • - -ports 7e.xls 11 Dolan Br 3 -87 2011 Pressure Data (3).x!s Br 17587 03 r . • Chevron Steve Lambert Chevron North America %1110 Sr. Advising Pet. Engineer Exploration and Production 3800 Centerpoint Drive %.1 V ' Anchorage, AK 99503 -' Tel 907 263 7658 Fax 907 263 7847 ION `lid Email salambert @chevron.com Al*a S �,rl,� C � r Antheraga 1 (0 - June 7, 2011 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7` Ave., Suite 100 Anchorage, Alaska 99501 '7 Q Re: 2010 Annual Report for Disposal Injection Order No. 19 Gentleman: Attached please find a graph and a table detailing the shut -in condition of the disposal well Granite Point State 17587 #3 (AKA Br 3 -87 - PTD #1660520) for the year 2010. There were no fluids injected into the Br 3 -87 well in 2010. The last injection into this well was in December of 2008. Upon deciding that the well wouldn't be used again for quite some time, the imposed pressure on the casing was bled down and held steady the rest of the year. Please call with any questions or concerns. Sincerely, r / 1 Steve ambe Senior Advising Petroleum Engineer MidContinent /Alaska Chevron North America Exploration and Production www.chevron.com br 3 -87 Pressure Observations 600 - - 1 -1 500 - ' -1 —Hours Tubing ■•■■9 5/8" 1 • ■13 3/8" 400 — - - - - -- - - - _ — Rate ` - 1 v d 300 1 cc a - 0 200 —_... — ___ --- - 0 0 • 100 _ — -- — -- — - 0 0 R 0 10/14/09 01/22/10 05/02/10 08/10/10 Time 11 /18 /10 02/26/11 06/06/11 09/14/11 Printed on 6/2/2011 at 4:23 PM br 3 -87 Pressure Data 201106 01.xis br 3 -87 Pressure Observations 7000 1200 6000 -- 1000 s — i i n& 5000 '° 8 — �i 800 4000 - - - -- . - ----- — - - - - 3 N 600 a z 3000 -- 400 2000 • 1000 — — - 200 200 i _ 1 _ 1 1 1 . 1 1 . o X _ 0 06/01/08 12/18/08 07/06/09 01/2010 08/10/10 02/26/11 09/14/11 Printed on 6/2/2011 at 4:34 PM br 3 -87 Pressure Data 201106 01.xls Date 9 5/8" 13 3/8" 20" Tubing )nj Vol Date 5/8" 13 3/8" 20" Tubing ; inj vol TIO Report 12/31/10 500 25 0 300 07/01/10 500 24 0 • 0 - _ -. 12/30/10 500 25 0 300 06/30/10 500 20 0 . Data Sheet 12/29/10 500 25 0 300 06/29/10 500 22 0 _ 1 12/28/10 500 24 0 300 > 06/28/10 00 24 0 12/27/10 500 24 0 300 06/27/10 00 24 0 , Br 17587 03 12/26/10 500 24 0 300 i 06/26/10 0 24 0 i , 12/25/10 500 24 0 300 06/25/10 00 24 0 12/24/10' 500 24 i 0 300 06/24/10 500 24 0 INJECTION 12/23/10' 500 24 0 300 06/23/10 500 24 0 12/22/10 500 24 ? 0 300 06/22/10 00 24 0 12/21/101 500 24 .' 0 300 06/21/10 00 24 0 Permit # 1660520 12/20/10: 500 24 0 300: 06/20/10 500 24 0 12/19/10 500 24 0 300 ,_ ,. 06/19/10 500 24 0 12/18/10 500 24 0 31 06/18/10 0 24 0 Sundry # 399 -062 12/17/10 500 24 0 3i ► 4 06/17/10 500 24 0 12/16/10 500 24 0 300 06/16/10 500 24 0 12/15/10 ' 500 24 0 300, 06/15/10 500 24 0 API # 50- 733 - 20437 -00 12/14/101 500 24 0 300 06/14/10 500 24 0 12/13/101 500 24 0 300 06/13/10 500 24 0 12/12/101 500 24 0 300 06/12/10 500 24 0 12/31/2009 to 12/31/2010 • 12/11/101 500 24 I 0 300 06/11/10 ' 500 24 0 12/10/101 500 24 0 300 06/10/10 500 24 0 12/09/10 500 24 0 300 06/09/10 500 24 0 12/08/10 500 24 0 300 06/08/10 500 24 0 • 12/07/101 500 24 0 300 06/07/10 500 25 0 12/06/10 500 24 0 300 06/06/10 500 25 0 12/05/10 500 24 0 300'. 06/05/10 500 25 0 12/04/10 500 24 0 3001 06/04/10 500 25 0 12/03/104, 500 24 0 300: 06/03/10 500 25 0 12/02/101 500 24 0 300 06/02/10 500 25 0 . 12/01/10 500 24 0 300' 06/01/10 ' 500 25 0 11/30/10 500 24 0 300 05/31/10 500 25 0 11/29/10 500 24 0 300 05/30/10 500 22 0 11/28/10 , 500 24 0 300, 05/29/10 500 22 0 11/27/10 500 24 0 300 � 05/28/10 500 22 0 11/26/10 500 24 0 300 05/27/10 500 22 0 11/25/10 500 24 0 300' 05/26/10 500 22 0 11/24/10 500 24 0 300' 05/25/10 500 22 0 11/23/10 500 25 0 300; 05/24/10 ; 500 22 0 11/22/10 500 25 0 300 05/23/10 500 22 0 11/21/10 500 25 0 300, 05/22/10 500 22 0 11/20/10 500 25 0 3001 05/21/10 500 22 0 • 11/19/10'- 500 25 0 300! 05/20/10 500 22 0 11/18/10 ` 500 25 0 3001 05/19/10 500 22 0 11/17/10 500 25 0 300; 05/18/10 500 22 0 11/16/10 ' 500 25 0 300 05/17/10 500 22 0 11/15/10 500 25 0 300: 05/16/10 500 22 11/14/10 500 25 0 300' 05/15/10 500 22 0 300 11/13/10 500 25 0 300' 05/14/10 500 22 0 300 11/12/10 500 25 0 300 05/13/10 500 22 0 300 11/11/10 500 24 0 300 05/12/10 500 22 0 300 11/10/10 500 24 0 300 05/11/10 500 22 0 300 11/09/10 500 24 0 300 05/10/10 500 22 0 300 11/08/10 500 24 0 300 05/09/10 500 22 0 3001 11/07/10 500 24 0 300. 05/08/10 500 22 0 3001 11/06/10 500 24 0 300 05/07/10 500 22 0 3001 11/05/10 500 24 0 300 05/06/10 500 22 0 3001 11/04/10 500 24 0 300 05/05/10 500 22 0 300! 11/03/10 500 24 0 300 05/04/10 500 22 0 300 11/02/10 500 24 0 300 05/03/10 500 22 0 300! 11/01/10 500 24 0 300 05/02/10 500 22 0 300 `i 10/31/10 500 24 0 300 05/01/10 500 22 0 300 10/30/10 500 24 0 300 04/30/10 500 22 0 300 10/29/10 500 24 0 300 04/29/10 500 22 0 30 10/28/10 500 24 0 300 04/28/10 500 22 0 10/27/10 500 24 0 300 04/27/10 500 22 0 10/26/10 500 25 0 300 04/26/10 500 22 0 304 10/25/10 500 25 0 300 04/25/10 500 22 0 30( 10/24/10 500 25 0 300 04/24/10 500 22 0 30¢ 10/23/10 500 25 0 300 04/23/10 500 22 0 3 10/22/10 500 25 0 300 04/22/10 385 22 2 10/21/10 500 25 0 300 04/21/10 375 21 2 10/20/10 500 25 0 300 04/20/10 375 21 27 10/19/10 500 25 0 300 04/19/10 380 21 33 10/18/10 500 25 0 300 04/18/10 375 21 10/17/10 500 24 0 300 04/17/10 360 21 1 10/16/10 500 24 0 300 04/16/10 360 21 10/15/10 500 24 0 300 04/15/10 360 21 10/14/10 500 75 0 300 04/14/10 390 21 10/13/10 500 75 0 300 04/13/10 500 22 10/12/10 500 25 0 300 04/12/10 500 20 0 10/11/10 500 25 0 30Q 04/11/10 500 20 0 10/10/10 500 25 0 300 04/10/10 500 20 0 10/09/10 500 25 0 300 04/09/10 500 20 0 3 1 • 0/08/10 500 25 0 300 04/08/10 500 20 0 10/07/10 500 25 0 300 04/07/10 500 20 0 10/06/10 500 25 0 300 04/06/10 500 20 0 3 10/05/10 500 25 0 300 04/05/10 500 22 0 3 10/04/10 500 25 0 300 04/04/10 500 22 0 3 10/03/10 500 25 0 300 0 04/03/10 500 22 0 30 10/02/10 500 25 0 300 0 04/02/10 500 22 0 3 10/01/10 500 25 0 300 04/01/10 500 22 0 3 o 09/30/10 500 25 0 300 0 03/31/10 500 22 0 30Q 09/29/10 500 25 0 300 03/30/10 500 22 0 30Q 09/28/10 500 25 0 300 0 03/29/10 500 20 0 3 09/27/10 500 26 0 300 03/28/10 500 20 0 3 09/26/10 500 26 0 300 03/27/10 500 20 0 3 09/25/10 500 26 0 300 03/26/10 500 20 0 09/24/10 500 26 0 300 03/25/10 500 20 0 3 09/23/10 500 26 0 300 03/24/10 500 20 0 3 0 09/22/10 500 26 0 300 03/23/10 500 20 0 30Q 09/21/10 500 26 0 300 03/22/10 500 22 0 300 09/20/10 500 24 0 300 03/21/10 500 22 0 300 09/19/10 500 24 0 300 03/20/10 500 22 0 30 09/18/10 500 24 0 300 03/19/10 500 20 0 306 09/17/10 500 25 0 300 03/18/10 500 22 0 300 • 09/16/10 500 25 0 300 03/17/10 500 22 0 300 09/15/10 500 25 0 300 03/16/10 500 22 0 30q 09/14/10 500 25 0 300 03/15/10 500 22 0 30 09/13/10 500 24 0 300 03/14/10 500 22 0 300 09/12/10 500 24 0 300 03/13/10 500 22 0 300 09/11/10 500 24 0 300 03/12/10 500 22 0 300 09/10/10 500 24 0 300 03/11/10 500 20 4 300 09/09/10 500 24 0 300 03/10/10 500 20 4 30Q 09/08/10 500 24 0 300 03/09/10 500 20 4 300 09/07/10 500 24 0 306 03/08/10 500 20 4 30Q 09/06/10 500 24 0 300 03/07/10 500 20 4 300 09/05/10 500 24 0 300 03/06/10 500 20 4 300 09/04/10 500 24 0 300 03/05/10 500 20 4 30Q 09/03/10 500 24 0 300 03/04/10 500 20 4 300 09/02/10 500 24 0 300 03/03/10 500 20 4 300 0 09/01/10 500 24 0 300 03/02/10 500 20 0 300 c 08/31/10 500 24 0 300 03/01/10 500 20 0 300 08/30/10 500 24 0 300 02/28/10 500 20 08/29/10 500 24 0 300 02/27/10 500 20 08/28/10 500 24 0 300 02/26/10 500 20 08/27/10 500 24 0 300 02/25/10 500 20 08/26/10 500 24 0 300 02/24/10 500 20 08/25/10 500 24 0 300 02/23/10 500 20 08/24/10 500 24 0 300 02/22/10 500 20 08/23/10 500 24 0 300 02/21/10 500 20 08/22/10 500 24 0 300 02/20/10 500 20 08/21/10 500 24 0 300 02/19/10 500 20 08/20/10 500 24 0 300 02/18/10 500 20 08/19/10 500 24 0 300 02/17/10 500 20 08/18/10 500 24 0 300 02/16/10 500 20 08/17/10 500 24 0 300 02/15/10 500 20 08/16/10 500 26 300 02/14/10 500 20 08/15/10 500 24 0 300 02/13/10 500 20 08/14/10 500 24 0 300 02/12/10 500 20 08/13/10 500 24 0 300 02/11/10 500 20 08/12/10 500 24 0 300 02/10/10 500 20 08/11/10 500 24 0 30Q -� 02/09/10 500 20 08/10/10 500 24 0 300 02/08/10 375 20 08/09/10 500 24 0 300 02/07/10 375 20 • 08/08/10 500 24 0 300 02/06/10 375 20 08/07/10 500 24 0 300 02/05/10 370 20 08/06/10 500 24 0 300 02/04/10 375 20 08/05/10 500 24 0 300 02/03/10 360 20 08/04/10 500 24 0 300 02/02/10 375 20 08/03/10 500 24 0 300 02/01/10 500 20 08/02/10 500 24 0 300 01/31/10 500 20 08/01/10 500 24 0 300 r 01/30/10 500 20 07/31/10 500 24 300 01/29/10 500 20 07/30/10 500 24 0 300 01/28/10 500 20 07/29/10 500 24 0 300 . 01/27/10 500 20 07/28/10 500 26 0 300 01/26/10 500 20 07/27/10 500 24 0 300 01/25/10 360 20 07/26/10 500 24 0 300 01/24/10 360 20 07/25/10 500 24 0 300 01/23/10 360 20 07/24/10 500 24 0 300 01/22/10 360 20 _ 07/23/10 500 24 0 300 01/21/10 360 20 07/22/10 500 24 0 300 01/20/10 360 20 07/21/10 500 22 0 300 01/19/10 360 20 07/20/10 500 20 0 300 01/18/10 300 20 07/19/10 500 20 0 300 01/17/10 300 20 07/18/10 500 20 0 300 01/16/10 300 20 • 07/17/10 500 20 0 300 01/15/10 300 20 07/16/10 500 20 0 300 01/14/10 300 20 07/15/10 500 20 0 300 01/13/10 300 20 07/14/10 500 20 0 300 01/12/10 300 20 07/13/10 500 20 0 300 01/11/10 300 20 07/12/10 500 20 0 300 01/10/10 500 20 07/11/10 500 22 0 30d 01/09/10 500 20 07/10/10 500 22 0 300 01/08/10 500 20 07/09/10 500 22 0 300 01/07/10 500 20 07/08/10 500 24 0 300 01/06/10 500 20 0 07/07/10 500 22 0 300 01/05/10 500 20 0 07/06/10 500 22 0 360 01/04/10 500 20 0 1. 07/05/10 500 24 0 3 0d 01 /03/10 500 20 0 + . 07/04/10 500 25 0 300 01/02/10 500 20 0 07/03/10 500 24 300 01/01/10 500 20 0 ,++ 0 07/02/10 500 24 0 300 • • Chevron Steve Lambert Chevron North America 4101 Sr. Advising Pet. Engineer Exploration and Production P.O. Box 196247 %O. Anchorage, AK 99519-6247 Tel 907 263 7658 Fax 907 263 7847 Email salambert@chevron.com IRFA. V 544ANNED PO-) -lg. tTh December 15, 2010 2(11° DEC ar Mr. Tom Maunder Alaska Oil and Gas Conservation Commission Iiia ' o Opt 8t 11 atm 9 333 W. 7 Ave., Suite 100 Anchorage, Alaska 99501 Re: 2009 Annual Report for Disposal Injection Order No. 19 Gentleman: Attached please fmd a graph and a table detailing the shut -in condition of the disposal well Granite Point State 17587 #3 (AKA Br 3 -87 - PTD #1660520) for the year 2009. �,"� (v � There were no fluids injected into the Br 3 -87 well in 2009. The last injection into this well was in December of 2008. Upon deciding that the well wouldn't be used again for quite some time, the imposed pressure on the casing • was bled down and held steady the rest of the year. Please call with any questions or concerns. Sincer s %'--( (' Steve L bert Senior Advising Petroleum Engineer MidContinent /Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Drive Anchorage, AK 99503 Tel 907 263 7658 Fax 907 263 7847 salambert@chevron.com MidContinent /Alaska Chevron North America Exploration and Production www.chevron.com Plot PreIle & Volume vs Time - Well Br 17587 0241) 200 I i : 180 I 1 2000 ' -- 160 • _ 140 —9 5/8" 13 3/8" 1500 20 -- - - -- - -- - - - - -- 120 — Tubing ib —Br 3 -87 vol i of 100,1 m a 1000 -..— 80 it 60 I 1 500 -1 Men ' 1111.111M � I " 40 /I I !ti. 20 0 rn rn rn co rn rn rn rn rn o ,. O) 0 0 0 0 0 0 0 0 0 0 0 0 0 p 10 8 1 N N N N N N c7 co CD ? 0 r m 0 o - c+ 0 n A 0 0 c� 0 0 Date 5/8" 13 3/8" 20" Tubing gl we TIO Report 01/01/10 p 500 20 0 300 0 12/31/09 500 20 0 300 Data Sheet 12/30/09 500 20 0 300 12/29/09 `500 20 0 300 12/28/09 " 500 20 0 300 Br 17587 03 12/27/09 . 500 20 0 300 12/26/09 '1500 20 0 300 12/25/09 500 20 0 300 INJECTION 12/24/09 500 20 0 300 12/23/09 360 20 0 300 12/22/09 360 20 0 300 Permit # 1660520 12/21/09 500 20 0 300 12/20/09 500 20 0 300 12/19/09 4360 20 0 300 Sundry # 399 -062 12/18/09 360 20 0 300 12/17/09 360 20 0 300 12/16/09 ' 360 20 0 300 API # 50- 733 - 20437 -00 12/15/09 -'360 20 0 300 12/14/09 385 18 300 12/13/09 375 20 300 12/31/2008 to 01/01/2010 12/12/09 ' 350 22 300 12/11/09 350 300 12/10/09 360 22 300 12/09/09 350 22 300 Q 12/08/09 . - 500 20 0 300 d 12/07/09 500 20 0 300 0? 12/06/09 ` 500 20 0 300 0 12/05/09 ' 500 20 0 300 12/04/09 500 20 0 300 0 12/03/09 500 20 0 300 12/02/09 500 20 0 300 12/01/09 • 500 20 0 300 11/30/09 500 22 0 300 11/29/09 . 500 20 0 300 11/28/09 500 22 0 300 11/27/09 ` 500 21 0 300 11/26/09 r 500 22 0 300 11/25/09 ' 500 22 0 300 11/24/09 "Y 500 22 0 300 11/23/09 ,. 500 20 0 300 11/22/09 . 500 20 0 300 11/21/09 500 20 0 300 11/20/09 500 20 0 300 11/19/09 500 20 0 300 11/18/09 p 20 0 • 11/17/09 ! 20 0 11/16/09 20 0 00 11/15/09 22 0 300 11/14/09 22 0 300 11/13/09 40 22 0 300 11/12/09 ' 10 22 0 300 11/11/09 z 22 0 300 11/10/09 22 0 300 11/09/09 20 0 350 11/08/09 20 0 350 11/07/09 20 0 350 11/06/09 20 0 350 11/05/09 - , 20 0 350 11/04/09 20 0 350 11/03/09 20 0 300 11/02/09 20 300 11/01/09 20 300 10/31/09 20 300 10/30/09 50 20 300 10/29/09 "50 20 0 - ` 300 10/28/09 •4- 50 20 4 300 10/27/09 50 20 300 10/26/09 "350 21 0 300 10/25/09 350 20 0 300 10/24/09 °' ; 350 20 0 300 10/23/09 350 20 0 300 10/22/09 350 20 0 300 10/21/09 - 350 22 0 300 10/20/09 50 22 0 300 10/19/09 .00 22 0 300 10/18/09 •00 24 0 300 10/17/09 500 24 0 300 10/16/09 500 22 0 300 10/15/09 '; 21 24 350 10/14/09 00 20 0 350 10/13/09 10/14/09 . 00 20 20 0 350 10/12/09 '.00 20 0 350 10/11 /09 00 22 0 300 10/10/09 " 500 22 0 300 10/09/09 500 20 0 350 10/08/09 '`s 00 20 0 300 10/07/09 500 20 0 300 10/06/09 500 20 0 300 10/05/09 - :;: 350 20 300 10/04/09 '350 20 300 10/03/09 150 20 300 10/02/09 50 20 300 10/01/09 = , 350 21 300 09/30/09 ° 350 20 300 09/29/09 "350 20 300 09/28/09 300 20 0 300 09/27/09 '?135 20 0 300 09/26/09 1350 20 0 300 09/25/09 .' 350 20 0 300 09/24/09 350 20 0 300 09/23/09 t., 350 20 0 300 09/22/09 '350 22 0 300 09/21/09 350 21 310 09/20/09 500 20 0 300 o 09/19/09 : 500 20 0 300 a 09/18/09 500 20 0 300 09/17/09 ' 500 20 0 300 0 09/16/09 500 20 0 300 o 09/15/09 ] 500 20 0 300 0 09/14/09 ' 500 20 0 300 0 09/13/09 500 20 0 300 09/12/09 ' - 500 20 0 300 a 09/11/09 ` 500 20 0 300 0 09/10/09 ' ' 500 20 0 300 09/09/09 500 20 0 300 09/08/09 .. 350 20 0 300 09/07/09 350 20 300 09/06/09 350 20 300 09/05/09 350 20 300 09/04/09 350 20 300 09/03/09 .' 350 20 300 09/02/09 350 20 300 09/01/09.` 350 20 350 08/31/09 3. 300 20 0 350 08/30/09 350 20 0 300 08/29/09 ` 350 20 0 300 08/28/09 : 350 21 0 300 08/27/09 _" 350 20 0 300 08/26/09 s 250 20 0 300 08/25/09 ' 500 20 0 300 08/24/09 350 21 • 08/23/09 350 21 08/22/09 350 21 000 08/21/09 350 21 300 08/20/09 300 20 300 08/19/09 500 20 310 08/18/09 500 21 '. 310 08/17/09 500 20 0 300 08/16/09 >:.00 20 0 300 08/15/09 ' f 20 0 300 08/14/09 20 0 350 08/13/09 20 0 350 08/12/09 ..00 20 0 400 08/11/09 -.00 20 0 300 08/10/09 "50 20 300 08/09/09 i 360 20 300 08/08/09 360 20 300 08/07/09 00 20 300 08/06/09 400 20 300 08/05/09 ' "k 50 20 300 08/04/09 50 20 300 08/03/09 50 20 0 300 08/02/09 400 20 0 300 08/01/09 350 20 0 300 07/31/09 00 20 0 300 07/30/09 '350 20 0 300 07/29/09 50 20 0 300 07/28/09 500 20 0 300 07/27/09 ' 500 20 0 300 07/26/09 '500 20 0 300 07/25/09 500 20 0 300 07/24/09 500 20 0 300 07/23/09 450 20 0 300 07/22/09 '500 20 0 300 07/21/09 `.' 00 28 0 300 07/20/09 ' '500 28 0 300 07/19/09 500 28 0 300 07/18/09 500 28 0 300. 07/17/09 '' 1200 28 0 300 07/16/09 ; 2150 28 0 300 07/15/09 2150 28 0 300 07/14/09 4 2150 28 0 300 07/13/09 ' 2150 28 0 300 07/12/09 2150 28 0 300 07/11/09 ' 2150 25 0 300 07/10/09 % 2150 28 0 300 07/09/09 2150 28 0 300 07/08/09 2150 28 0 300 07/07/09 2200 28 0 300 07/06/09 -' 2200 28 0 300 07/05/09 ': 2200 26 0 300 07/04/09 '? 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A hard copy is being sent by mail. The engineer (Ted Kramer) who caught up with the reports last year, left in April this year and it fell through the cracks. We didn't use the well in 2009 and not so far in 2010 either. There are no pressure problems associated with this well and no performance issues either as it was not in use in 2009. Hope this isn't too much of a problem to get your files caught up. Let me know if we need to do anything else for this well. I've built a reminder on my e -mail to get this done next year on time. Larry 1 Br 3 -87 (PTD # 1660520) Imposed nnulus Pressure and Wellhead Injection Pressure Fi... Page 1 of 2 • • Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Monday, September 08, 2008 1:21 PM To: Maunder, Thomas E (DOA) Subject: FW: Br 3 -87 (PTD # 1660520) Imposed Annulus Pressure and Wellhead Injection Pressure Findings Attachments: Br 3 -87 pressure limit calc summary; Br 3 -87 historic TIO 8- 8- 08.xls; Br 3 -87 recent TIO 8 -8- 08.xls fyi Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Greenstein, Larry P [ mailto :Greensteinlp @chevron.com] Sent: Thursday, August 14, 2008 7:48 AM To: Regg, James B (DOA) Cc: KRAMER, TED E; Schulte, Raymond [Petrotechnical]; Cole, David A Subject: Br 3 -87 (PTD # 1660520) Imposed Annulus Pressure and Wellhead Injection Pressure Findings Hi Jim, This is the note we talked about documenting the usage of the Bruce 3 -87 well during the injection test last November and the latest of the Grind & Inject batches last month. Attached you'll find the drilling department's methodology and calcs to determine reasonable pressure limits for the Br 3 -87 well. This and the historical usage of the well were used in the decision to maintain an imposed pressure on the annulus for well integrity /safety concerns. «Br 3 -87 pressure limit calc summary» During the injectivity test last November, —3000# was used as back -up pressure on the annulus and for the more recent batches —2000# has been the imposed annulus pressure. Both have proven effective at minimizing the dP for the many different slurry weights of the batches that have been injected into this well. Also attached is the TIO plot for the disposal usage for this well. Some of the oldest data is incomplete, but the newer data covers similar disposal operations and shows a gradual increase in the tubing pressure required to dispose of the fluids. «Br 3 -87 historic TIO 8- 8- 08.xls» A closer inspection of the last series of batch injections shows this same pattern in the second plot. «Br 3 -87 recent TIO 8- 8- 08.xls» 12/17/2010 Br 3 -87 (PTD # 1660520) Impose1nnulus Pressure and Wellhead Injectio1ressure Fi... Page 2 of 2 Based on historical and recently confirmed pressures, it seems that DIO #19, Finding #15 is in need of revision. As part of the original DIO, Unocal estimated that the average injection pressure would be around 2500# and the max pressure would be around 3000 #. It appears these numbers would be more accurate if they were in a 5000# average with a maximum of 6000# range. With your concurrence, how would you recommend these revisions take place ?? Is this a DIO #19A type request, or a DIO # 19.001 admin approval type request or does this e -mail with your concurrence suffice as notification of these changes ?? Please call or e-mail me with our options and the proper way to achieve these changes. Thanks Jim. Larry 263 -7661 12/17/2010 Br 3 -87 pressure limit calc summa, • Page 1 of 2 Maunder, Thomas E (DOA) From: Schulte, Raymond [Petrotechnical] [RSchulte @chevron.com] Sent: Tuesday, August 05, 2008 10:52 AM To: Greenstein, Larry P Subject: Br 3 -87 pressure limit calc summary From: Newell, Jack R [FEP] Sent: Tuesday, August 05, 2008 9:48 AM To: Schulte, Raymond [Petrotechnical] Subject: BR17587: Summary Outline Ray, Have attached a simple summary on how values were achieved. Summary "BR17587 3: "PTD: 166 -052" • The Bruce platform well 17587 Br -3 is operating under Area Injection Order Number 11 dated September 29, 1986. 1 The tubing/ casing parameters are below: Values per regulatory requirements. • Limiting regulatory pressure allowance is the section of 9 -5/8" Casing f/ 7810' MD t/ 7903' MD. Pressure differential is based on 70% Triaxial/ hoop stress of 70% or 5259 A -PSI across the 9 -5/8" tubular. 1 Pore pressure is per AOGCC gradient of .465 psi /ft. 2 Pressure differential is based on a AOGCC gradient of .465 psi /ft. • MIT annular test to comply w/ AOGGC requirements: • Develop a differential of .25 psi /ft at 7092' TVD depth of packer or 1500 psi which ever is greater • PA = .25'7092 = 1773 PSI 1 P_Formation = .465 * 7092' = 3297 PSI 2 P_Hydrostatic for 1773 PSI A = 3297 PSI + 1773 PSI = 5070 PSI 3 P_Hydrostatic_Casing x Tubing_ Annular 8.4 PPG Fluid = 3097 PSI 4 P_Annular for AOGCC MIT = 5070 PSI — 3097 PSI = 1973 PSI Test Pressure 5 P_Annular_2000 PSI = 5097 PSI @ 7092' TVD 6 P_Annular 2162 PSI = 5259 PSI @ 7092' TVD maximum for 70% Pipe Stress with no pore pressure 12/17/2010 Br 3 -87 pressure limit calc summa Page 2 of 2 • backup. • Pressures per Area Injection Order allowed on 9 -5/8 ", 43 #, S95 casing section below packer above 7" liner hanger is limiting section. • P_External = .465 * 7174' TVD: 3336 PSI 1 PD MIT = .25 * 7174' TVD: 1793 PSI 2 P_Hydrostatic for 1793 PSI MIT = 3336 PSI + 1793 PSI = 5129 PSI to achieve 1793 PSI A 3 P_Hydrostatic_Fluid = (8.4PPG)(.052)(7174' TVD) = 3133 PSI 4 P_Surface = 5129 PSI — 3133 PSI = 1996 PSI 5 P_Hydrostatic_Max_@ 7174' TVD = 5259 PSI + 3336 PSI = 8595 PSI 6 P MASP_Tubing = 8595 PSI — 3133 PSI = 5461 PSI • Tubing Pressures • Tubing pressures are below mechanical limits when the MASP is within the pressure limits of the 9 -5/8" casing section below the packer and above the liner hanger. 1 Liner has simplex hanger - No Seals Jack R Newell • • 12/17/2010 • • Plot Pressure & Rate vs Time - Well Br 17587 03 7000 -- 1200 — 7" —9 5/8" 13 3/8" 6000 20" 1000 SURF - Tubing — Vol P 5000 - 800 4000 r r 1 w w u) 60g 5 E 0. I. 3000 — I - 400 2000 '111 - 200 1000 - — — — i ll 0 1 - --0 6> O o v o 0 0 0 Date 13 3/8" 20" TIO Report 08/07/08 22 0 08/06/08 24 0 Data Sheet 08/05/08 24 0 08/04/08 20 0 08/03/08 20 0 Br 17587 03 08/02/08 20 0 08/01/08 20 0 07/31/08 20 0 INJECTION 07/30/08 20 0 07/29/08 20 0 07/28/08 20 0 Permit # 1660520 07/27/08 20 0 07/26/08 20 0 07/25/08 20 0 Sundry # 399 -062 07/24/08 20 0 07/23/08 20 0 07/22/08 20 0 API # 50- 733 - 20437 -00 07/21/08 20 0 07/20/08 20 0 07/19/08 20 0 04/19/1999 to 08/08/2008 07/18/08 20 0 07/17/08 20 0 07/16/08 20 0 07/15/08 20 0 07/14/08 20 0 07/13/08 20 0 07/12/08 20 0 07/11/08 20 0 07/10/08 20 0 07/09/08 20 0 07/08/08 20 0 07/07/08 20 0 07/06/08 20 07/05/08 20 0 07/04/08 20 0 07/03/08 20 0 12/17/2010 11:35 AM - TIO Reports 7e.xls J J Dolan Br 3 -87 historic TIO 8- 8- 08.xls Br 17587 03 • 0 Plot Pressure & Rate vs Time - Well Br 17587 03 7000- 1200 o 9 5/8" ' 13 3/8" 20" 6000 — — Tubing 1000 — Vol ' 1 5000 - 800 4000 , - - ' a) vi 6O m w C d 4 Cr. 3000 ^-- ■,....I ' 400 2000 - I ~ 200 1000 i -ate Tr 0 co co co co co CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO m CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 fh 0 Q) N N CO N (n CO — V r O FO (0 0) V N- O M co 0) N U) CO .- V N- O co t0 0) N U) co <•) t0 0) N (0 co •- CO N-- 0 CO CO 0) N U) CO •- • r 0 N U() O N N N 0 0 0 •- •- N N N N O O O.- •- •- N N N 0 0 0 •- z .- .- N N N CO O O O z z z N N 01 CO O O O •- z 7 N N f2 N O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 88888888 0 0 0 0 0 0 Date 13 3/8" 20' TIO Report 08/07/08 22 0 , 08/06/08 24 0 Data Sheet 08/05/08 24 0 08/04/08 20 0 08/03/08 20 0 Br 17587 03 08/02/08 20 0 08/01/08 20 0 07/31/08 20 0 INJECTION 07/30/08 20 0 07/29/08 20 0 07/28/08 20 0 Permit # 1660520 07/27/08 20 0 07/26/08 20 0 07/25/08 20 0 Sundry # 399 -062 07/24/08 20 0 07/23/08 20 0 07/22/08 20 0 API # 50- 733 - 20437 -00 07/21/08 20 0 07/20/08 20 0 07/19/08 20 0 02/10/2008 to 08/08/2008 07/18/08 20 0 07/17/08 20 0 07/16/08 20 0 07/15/08 20 0 07/14/08 20 0 07/13/08 20 0 07/12/08 20 0 07/11/08 20 0 07/10/08 20 0 07/09/08 20 0 07/08/08 20 0 07/07/08 20 0 07/06/08 20 07/05/08 20 0 07/04/08 20 0 07/03/08 20 0 12/17/2010 11:35 AM - TIO Reports 7e.xls J J Dolan Br 3 -87 recent TIO 8- 8- 08.xls Br 17587 03 • thevron Ted Kramer ~ Petroleum Engineeer ~ ... .. `-.. >/x .~,q,~r:-. ,, yh F_tJli~ ~'cr•>~G:~d~f6s~ bi~Jk„ i ~'° June 23, 2009 Mr. Tom Maunder Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 W. 7ih Ave., Ste. 100 Anchorage, Alaska 99501 • Chevron North America Exploration and Production P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7690 Fax 907 263 7847 Email ted.kramer@chevron.com a'~ ~~~"~~~~ s { ~,. u ~ ~ ~~ ,• (,~{.jf7 ~«~(~+~R r . . «~ Y~~ ~ ~~ ~~~°~~ ~~ ~rt~ ~}~~~~rssi~~ Re: 2008 Annual Report for Disposal Injection Order Number 19. Gentlemen, ,~i(o 4~ Attached please find a graph and a table detailing the volume injected into Granite Point State 17587 #3 well in 2008. The total amount of fluid injected into Granite Point State 17587 #3 well in 2008 amounted to 20,400 bbls. of fluid - pre-flush, slurry, and post flush. The highest tubing injection pressure seen was 6,050 and occurred on 5/10/08. The last injection of 2008 occurred on December 6, 2008. The tubing pressure reached 5,328 psi. during this injection. Chevron plans to continue utilizing this well for the disposal injection of drill cuttings and other class two fluids as the need arises in 2009. Please call with any questions or concerns. Sincerely, ~ir`"~ ~' ~a s..~ -~ v-~--~ a- Ted E. Kramer Petroleum Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7960 Cell 907-382-0059 Fax 907 263 7847 ted. kramer@chevron.com MidContinent/Alaska Chevron North America Exploration and Production www.chevron.com ~ • ' Pl ressure & Rate vs Time - Well Br 1758 7 ~ooo ~ooo ~9 5/8" 13 3/8" 900 6000 _.. s. 20~~ ~Tubing ~Vol Inj S00 5000 700 600 4000 ~ N ~ 50~ ~ ~ a 3000 400 2000 300 200 1000 100 0 - 0 ao m m m m ao co ao w m m ao m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 s o o ~ a ~ s o o ° a s Date 9 5/8" 13 3/8" 20" Tubing Vol I 01/01/09 2150 21 350 12/31/08 2150 21 350 12/30/OS 2150 21 300 12/29/08 2200 21 0 350 ~ 12/28/08 2200 21 0 400 12/27/08 2200 21 0 400 12/26/OS 2200 21 0 400 12/25/OS 2200 21 0 400 12/24/08 2200 20 0 400 12/23/08 2150 20 0 400 12/22/08 2175 20 4 350 - 12/21/08 2200 20 0 350 12/20/08 2150 20 0 350 12/19/OS 2150 20 0 350 12/18/08 2150 20 0 350 12/77/08 2150 20 0 350 12/16/08 2150 20 0 350 12/15/08 2200 20 0 400 12/14/OS 2200 20 0 400 12/13/OS 2200 20 0 400 12/12/08 2150 20 0 400 12/11/08 2050 20 450 12/10/08 2050 20 450 12/09/OS 2150 20 0 400 12/OS/08 2150 20 400 12/07/08 2150 20 600 12/06/08 2150 20 5328 7 12/OS/08 2150 20 400 12/04/08 2150 19 450 12/03/OS 2150 20 600 12/02/OS 2050 20 5511 7 12/01 /08 2200 25 300 11/30/08 2200 25 300 11/29/08 2050 25 300 11/28/08 2050 25 300 11/27/08 2090 25 350 11/26/08 2100 25 350 11/25/08 2150 75 350 11/24/08 2150 25 0 350 11/23/08 2150 25 0 350 11/22/08 2150 25 0 350 67~~b~$123 AI~~~ Reo orts 7~e5xls 0 350 J J Dolan TIO Report Data Sheet Br 17587 03 INJECTION Permit # 1660520 Sundry # 399-062 API # 50-733-20437-00 01 /01 /2008 to 01 /01 /2009 Br 3-87 TIO Report 2009 01 01.x1s Br 17587 03 11 /20/08 2150 11/19/08 2150 11/18/OS 2150 11/17/OS 2200 11/16/OS 2100 11/15/OS 2200 11/14/08 2200 11/13/08 2200 11/12/08 2150 11/11/OS 2150 11/70/08 2150 11/09/08 2150 11/08/08 2150 11/07/OS 2150 11/06/OS 2150 11/OS/08 2150 11/04/08 2125 11/03/08 2100 11/02/08 2100 11/01/08 2500 10/31/08 2000 10/30/08 2050 10/29/08 2150 10/28/OS 2050 10/27/08 2150 10/26/OS 2150 10/25/OS 2150 10/24/OS 2150 10/23/OS 2150 10/22/08 2200 10/21/OS 2200 10/20/08 2100 10/19/08 2100 10/18/08 2100 10/17/08 2050 10/16/08 2050 10/15/08 2050 10/14/08 2150 10/13/08 2150 10/12/08 2150 10/11/08 2150 10/10/08 1850 10/09/08 2150 10/08/08 2150 10/07/08 2150 10/06/08 2150 10/05/08 2150 10/04/08 2175 10/03/08 2150 10/02/OS 2150 10/01/OS 2150 09/30/08 2200 09/29/08 2000 09/28/08 2100 09/27/08 2150 09/26/OS 2100 09/25/08 2200 09/24/OS 2200 09/23/OS 2200 09/22/08 2250 09/21/08 2160 09/20/08 2100 09/19/08 2150 09/18/08 2150 09/17/08 2150 09/16/08 2000 09/15/08 2050 09/14/08 2200 09/13/08 2700 09/12/08 2200 09/11/OS 2200 09/10/08 2200 09/09/08 2200 09/08/08 2200 09/07/08 2280 09/06/08 2110 09/OS/OS 2100 09/04/08 211~ 09/03/08 214 09/02/OS 211 09/01/OS 220~ 08/31/08 2200 OS/30/08 2175 ~2~~~ 1 ~23 AIu~F~~~ 30 30 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 400i 400' 400' 400' 4001 400'' 350' 400'', 400 350'', 400. 400i 400~ 400, 400I 500'! 5571 '! 400~ 400i 400'. 400 400 400 400, 400'; 400f 400i 400! 400~ 400 400' 500 500' 500! 500I 600' 600' 1050'. 5548 650'. 800' 10001 5708'. 500'. 500'' 600' 700' 1000 5700 400 500 500 500 500 500 800 5832 700 0 1200 2250 1900 4000 5800 400 400 600 600 1800 2000 2000 3900 400 400 555 500 555 550 600 700' 900 0 778 0 0 965 0 0 911 0 0 909 0 0 0 0 0 0 0 780 0 0 • J J Dolan Br 3-87 TIO Repor1 2009 01 01.x1s Br 17587 03 08/28I08 220~ 08/27/08 2150 08/26/08 2150 OS/25/OS 2050 OS/24/OS 2100 08/23/08 2250 08/22/08 2150 OS/21/08 2150 08/20/08 2150 08/19/08 2110 08/18/OS 2200 08/17/OS 2200 OS/16/OS 2150 OS/15/OS 2200 OS/14/08 2200 08/13/08 2100 OSl12/08 2050 08/11/08 2150 OS/10/OS 2150 08/09/08 2150 OS/08/OS 2150 OS/07/OS 2150 OS/06/08 2100 08/OS/08 2200 08/04/08 2050 08/03/08 2050 08/02/08 2050 OS/01/08 2050 07/31 /08 2100 07/30/OS 2150 07/29/OS 2700 07/28/OS 2100 07/27/08 2100 07/26/08 2100 07/25/08 2100 07/24/08 2100 07/23/OS 2100 07/22/OS 2100 07/21/OS 2050 07/20/08 2050 07/19/08 2050 07/18/08 2050 07/17/08 2050 07/16/08 2050 07/15/OS 2050 07/14/OS 2025 07/13/OS 2025 07/12/08 2025 07/11/08 2025 07/10/08 2000 07/09/08 2000 07/OS/08 2000 07/07/08 2000 07/06/08 2000 07/O5/08 2000 07/04/08 2000 07/03/08 2000 07/02/08 2000 07/01/OS 2000 06/30/OS 2000 06/29/08 2000 06/28/08 2000 06/27/OS 2000 06/26/OS 2000 06/25/08 2000 06/24/08 2000 06/23/08 2000 06/22/08 2000 06/21/08 2000 06/20/OS 2000 osi~sios 2aoo O6/18/08 2000 O6/17/08 2000 06/16/08 2000 06/15/08 2000 06/14/OS 2000 06/13/08 2050 06/12/08 2000 06/11/08 2050 06/10/08 2200 06/09/OS 2200 06/OS/08 2100 06/07/08 2200 ~~~123 AWF2~R 30 30 30 35 27 25 26 26 30 30 30 30 30 30 30 22 22 22 24 22 24 24 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 24 0 1200 ~699 0 934 • 0 650 0 0 800 0 1300 0 0 5817 629 0 500 0 0 500 600 660 800 0 1050 0 0 5720 740 0 750 0 0 1000 0 1500 0 5754 925 0 500 0 0 500 0 500 0 600 0 700 0 1000 0 0 5945 867 0 400 0 0 400 0 500 0 500 0 600 0 1000 0 0 5940 844' 0 300 0 0 300 0' 0 300 0' 0 300 0, 0 375 01 0 500 0'. 0 400 0: 0 300 0 300 0 300 0 300 01 0 300 0 300 ~ 0 300 0 350 0 350 0 350 ~ 0 350 ' 0 350 ~ 0 350 i 0 350 0 350 ~ 350 ~ 0 350 ~ 0 350 ~ 0 400 0 400 ; 0 485 700 ~ 500 350 4 350 350 1 350 ~ 350 i 400 S 400 400 ~ 400 } aao ;E 400 0 450 { 0 400 0 500 0 600 ~~ 0 700 0 1100 0 0 5649 504 0 400 4 0 400 i 0 400 S 0 400 ~ 0 400 ~' J J Dola~ Br 3-87 TIO Report 2009 Ot OLxls Br 17587 03 06/05/OS 2200 20 0 400 06/04/08 2200 20 0 ~ 400 • O6/03/08 2200 20 0 400 06/02/OS 2200 20 400 06/01/OS 2200 20 400 05/31 /08 2200 20 400 OS/30/OS 2200 20 400 OS/29/OS 2200 20 450 OS/28/08 2200 20 450 OS/27/08 2200 20 450 05/26/O8 2200 20 450 05/25/O8 2200 20 450 05/24/O8 2200 20 450 05/23/08 2200 20 500 OS/22/08 2200 20 500 05/21/08 2170 20 550 05/20/08 2170 20 600 OS/19/08 2100 20 0 700 05/18/08 2100 20 0 900 OS/17/08 2150 20 0 1400 0 05/16/08 2150 20 0 4000 313 OS/15/08 3150 20 0 500 0 O5/14/08 3100 20 0 500 05/13/08 3150 20 0 600 05/12/08 3200 20 0 900 0 OS/11/08 3100 20 0 6000 494 O5/10/08 3050 20 0 6050 472 OS/09/08 3150 20 0 500 0 OS/08/08 3150 20 0 500 O5/07/08 3250 20 0 500 OS/06/08 3250 20 0 600 OS/05/08 3250 20 800 0 OS/04/08 3250 20 5700 401 05/03/08 3250 22 5950 808 05/02/08 3250 22 400 0 05/01 /08 3250 22 450 0 04/30/08 3250 0 500 0 04/29/08 3250 22 500 0 04/28/OS 3250 22 500 0 04/27/08 3250 22 600 0 04/26/08 3250 22 700 0 04/25/08 3250 22 5650 402 04/24/OS 3150 25 5900 618 04/23/08 3250 25 400 0 04/22/08 3250 25 1100 0 04/21/OS 3175 24 0 5900 585 04/20/OS 3150 25 0 400 0 04/19/08 3200 24 0 400 04/18/O8 3100 25 0 500 04/17/OS 3150 22 0 600 0 04/16/OS 3200 22 0 5850 580 04/15/08 3210 25 0 5550 500 04/14/08 3200 25 400 0 04/13/08 3200 25 0 400 04/12/08 3200 25 0 400 04/11/08 3200 23 0 500 04/10/08 3300 0 400 04/09/08 3300 25 0 500 04/08/08 3300 24 0 650 0 04/07/08 3200 24 0 5850 517 04/06/08 3200 24 0 500 0 04/O5/OS 3200 25 0 5600 363 04/04/OS 3200 24 0 400 0 04/03/OS 3200 24 0 400 0 04/02/08 3200 24 0 500 0 04/01/OS 3150 90 0 5700 577 03/31/OS 3150 0 0 350 0 03/30/08 3150 0 0 350 0 03/29/08 3200 0 0 400 0 03/28/08 3200 0 0 5500 448 03/27l08 2960 0 0 300 0 03/26/08 2960 0 0 300 0 03/25/08 2950 20 310 03/24/08 2975 0 0 300 03/23/08 2975 0 0 300 03/22/~8 2950 0 0 300 03/21 /08 2950 0 0 300 03/20/OS 3000 0 0 300 03/19/OS 3000 0 0 300 03/1S/OS 3000 0 0 300 03/17lOS 3000 0 0 300 03/16/OS 03/15/08 3000 3000 0 0 0 0 300 300 ~t~~$1 23 A( u$~~ Repor ts 7~xls 0 300 ~ J Dolan Br 3-87 TIO Report 2009 01 01.x1s Br 17587 03 ~ 03/13/08 3050 0 0 300 03/12/08 03/11 /08 03/10/08 03/08/08 03/07/08 03/06/08 03/OS/08 03/04/08 03/03/08 03/02/08 03/01 /08 02/29/08 02/28/08 02/27/08 02/26/08 02/25/08 02/24/08 02/23/08 02/22/OS 02/21 /08 02/20/08 02/19/08 02/18/08 02/17/08 02/16/OS 02/15/08 02/14/08 02/13/OS 02/12/08 02/11/08 02/10/OS 02/09/OS 02/08/OS 02/07/OS 02/06/08 02/OS/OS 02/04/O8 02/03/08 02/02/OS 02/01 /08 01 /31 /OS 01l30/08 01/29/08 01 /28/08 01 /27/08 01/26/08 01 /25/08 01 /24/08 01 /23/08 01 /22/08 01 /21 /08 01 /20/08 01/19/08 01 /18/08 01/17/08 ° 01/16/08 01/15/08 01/1 01/1 01/1 01/1 0 ~ 6/2/2009 11:23 AM - TIO Reports 7e.xls J J Dolan Br 3-87 TIO Report 2009 Ot 01.x1s Br 17587 03 3050;: 305U'' a`~ 300a 900.` 900? 900;' 90Q~ 900' 90Qr 90Q''~ 9254 925. 920r 950I 915 915i 915i 915°; 915'{ 91 S+ 915 915: 915a 91~ 91~ 915~:' 91~ 915; 915~ 91~ 915: 915' 915~ 915 915~ 91 S? 915~ 915;' 915 95Qi 95~ 925: 925~ 925, 925' 925: 92~' 925,' 925i 925' 925 925" 92S 925~ 925' 9251 s2o; 910' 920' 910". 910i 915'' 910' 900 93U 920` 920 900 920: 915: 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 300 0 300 0 300 0 5400 0 0 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 250 0 250 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 0 300 250 300 300 250 250 305 0 300 260 250 300 300 250 0 300 300 ~~'tfw''Vf Ot'1 ~anCISCO Castro Chevron North erica Exploration and Production ~ Technical Assistant 909 W. 9th Avenue ~ ~~''~' '°-~-4.,~; ',.~r- Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE September 17, 2008 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 WEi1 LGG TYPE SCALE 60G DATE INTERVkL LOGGED RUIY # &LiNE CD NOTES - !_.G,S, PDS, DLIS RESERVOIR SATURATION TOO SIGMA TBU K-12RD2 MODE GRlCCL 5" 11-Au -08 7200-11456 1 1 1 PDS, LAS PSP PRESSURE GRANITE PT TEMPERATURE ST 17587 3 LOG GR-CL 5" 17-Jul-08 200-9036 1 1 PDS, LAS v~C /(oCo-~c~ ~1~ ~~~~~ ~~I' ~. ~LL~ 20~& Please acknowledge receipt by signing and returning one copy of'thi~-~nsm~t, a ~r'FAX to 907 263 7828. ~~~,.~__ Received By: Date: ~. m ~ `Ll~tj 3 S-FATE OF ALASKA '~ AL~ OIL AND GAS CONSERVATION COMM ION .-, ~' ~. REPORT OF SUNDRY WELL OPERATIONqNS JUL ~ ~ ~~~~; 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ` ~"``' ° ' ^~'^' ~ ~ Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver ^ Time Extension ^ " Change Approved Program ^ Operat. Shutdown^ Perforate Q - Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. WeII Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory^ 166-052 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service Q 6. API Number: 50-733-20437-00- 7. KB Elevation (ft): 9. Well Name and Number: 42.8' Granite PT ST 17587 3 (BR17587 03) 8. Property Designation: 10. Field/Pool(s): ADL0017587 (Bruce Platform) ~ Granite PT Field /Middle Kenai Oil ' 11. Present Well Condition Summary: - Total Depth measured 11,015 " feet Plugs (measured) N/A true vertical 10,075. feet Junk (measured) 9,037' (fill) Effective Depth measured 9,037 feet true vertical 8,189 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 589' 20" 589' 588' 3060 psi 1500 psi Surface 2,092' 13-3/8" 2,092' 1,998' 2730 psi 1130 psi Intermediate 8,178' 9-5/8" 8,178' 7,416' 5750 psi 3090 psi Production 3,074' 7" 10,999' 10,059' 8460 psi 8610 psi Liner Perforation depth: Measured depth: See Attached Schematic ~~~~~~~; QU ~ ~ ~f 2~~8 True Vertical depth: See Attached Schematic Tubing: (size, grade, and measured depth) 3-1/2" N-80 9.2# 7,870' Packers and SSSV (type and measured depth) Baker Mod D Perm Packer @ 7,810' and N/A 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 0 0 Subsequent to operation: 0 0 0 1940 250 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^ Service ^Q Daity Report of Weil Operations X 16. Well Status after work: Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL Q 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. Exem~t:~*-~ 308- Y /~/ ~lf!"~ Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager .r- - Signature L... Phone 263-7600 Date 7/21/2008 Form 10-404 Revised 04/2006 S ~F~~ ,BUG ~ ~ 2008 Submit Original Only' -' l ~p RIGI[~AL Bruce Platform Well No. 3 GP 17587 RKB to TBG Head = 42.80' SIZE WT CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 20 133 K-55 18.73 Surf 589' 13-3/8" 54.5 J-55 8 rd, STBC 12.515 Surf 2,092' 9-5/8" 43.5 S-95 ERW ST&C 8.755 Surf 52' 40 N-80 Buttress 8.835 52' 4,676' 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 7" 32 N-80 Butt. 6.094 7,925' 8,014' 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' Tubing: 3-1/2" 9.2 N-80 ABC 2.992 42.8' 7,870' NO. De th OD JEWELRY DETAIL ID Item 1 42.80' CIW Tubing Hanger, BPVP ? 2 43.80' - ? Crossover, 3-1/2" EUE 8rd Pin x 3-1/2" Buttress Pin 3 44.30' - 2.992 Pup, 3-1/2", ABC 4 48.30' - 2.992 Pup, 3-1/2", ABC 5 58.30' - 2.992 Pup, 3-1/2", ABC 6 7,824' 4.875 3.000 Locator, Baker 190-47 7 7,825' 4.734 3.000 Seal Assembly, Baker, 190-47 8 7,839' - 2.992 1 joint, 3-1/2" , 9.2#, N-80, ABC 9 7,870' - - Mule Shoe 10 7,810' - - Packer, Permanent, Baker Mod. D (DPM) Fill Tagged w/ GR 7/18/08 9,037' Zone Top PERFORATION DATA Btm Amt Accum Last SPF Perf Date Tie in Log C-1 9.015' 9,035' 20 12 7/18/2008 CCUGR 7-17-08 9,030' 9,050' 30 4 10/3/1999 1999 C-2 9,240' 9,310' 70 4 & 8 6/30/1972 C-2X 9,240' 9260' 20' 4 10/3/1999 1999 C-2 9,380' 9,400' 20 4 & 8 6/30/1972 C-2X 9,390' 9,400' 10 4 10/3/1999 1999 C-3/4 9,480' 9,495' 15 4 6/30/1972 C-5 9,580' 9,650' 70 4 & 8 6/30/1972 C-7 10,045' 10,095' 50 4 & 8 6/30/1972 10,120' 10,130' 10 4 6!30/1972 10,150' 10,200' 50 4 & 8 6/30/1972 10,215' 10,270' S5 4 & 8 6/30/1972 10,290' 10,310' 20 4 & 8 6/30/1972 C-8 10,432' 10,462' 30 4 & 8 6/30/1972 10,478' 10,578' 100 4 & 8 6/30/1972 C-9 10,628' 10,715' 87 4 & 8 6/30/1972 WBD_Bruce_GP_17587-31 Updated 7-21-08.doc DATE: 7/21/2008 CVK PBTD = 10,989' TD = 11,015' HOLE ANGLE thru Interval = ° chevron Chevron -Alaska Daily Operations Summary Wa(I Name BR 03-87 Field Name GRANITE POINT API/UWt 507332043700 Lease/Serial CHEVNO ADL017587 QU1725 License No./Prope... 1660520 Orig KB Elev (flKB) 115.0 Water Depth (ft) - - - --- - Jobs _ __ Job Cat Type AFE No. QC Eng Well Service Perforating UWDAK-J7138-D... 'Daily Operations _ _ ~ 6/11/2008 00:00 - 6/12/2008 00:00 Operations Summary Prep well 7/13/2008 00:00 - 7/14/2008 00:00 Operations Summary Rig up Slickline and Run 2.8" GR, 2.5"x20' Dummy Gun to 7582' slm. 7/14/2008 00:00 - 7/15/2008 00:00 Operations Summary Ran gauge ring to 9049.6'. Ran 2"dummy gun to 9049.5'. Ran temp/press survey to 9029'. 7/17/2008 00:00 - 7/18/2008 00:00 Operations Summary Ran CCL/GR/Press-Temp tools and tag fill at 9037'. Logged out of hole with temp/press tool. 7/18/2008 00:00 - 7/19/2008 00:00 Operations Summary Perforated from 9035' to 9015' with 2", big hole, 6 spf, 90 deg phase HC, followed by 2", deep penetrator, 6 spf, 90 deg phase HC. ~~~~~ ~~ ~~~~~a CO1~T5ER~TIO CO~SSIO~l~T T;mothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~O' ~~ ~ 6~ Re: Granite Point Field, Granite Pt Undefined Disposal Pool, Granite PT ST 17587 3 Sundry Number: 308-244 ~~~~ JUL ~ ~ 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 this ` ~ day of July, 2008 Encl. STATE OF ALASKA ~. ~~t. ~ O ALA OIL AND GAS CONSERVATION COM~SION ~*~ APPLICATION FOR SUNDRY APPROVALS I~r JUG ~ ~ ~ ~'r ~ ~~ 20 AAC 25.280 er..~.,.., r.:~ „ ~. 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate ~ ai ve •t •° ' {Stheir . ~~ Alter casing^ Repair well ^ Plu Perforations ^ Stimulate ^ Time Exten~cyii~] = , g Change approved program^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 166-052 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20437-00 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 ~ Granite PT ST 17587 3 BR17587 03 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~~rs , ~~~Q~~~~W ~ ~~tKu ~`vy i ADL0017587 Bruce Platform 42.8' . . ; ~ Granite PT Field / Mi~'d i Oil 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11,015' 10.075' 9,067' 8,216' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 589' 20" 589' 588' 3060 psi 1500 psi Surface 2,092' 13-3/8" 2,092' 1,998' 2730 psi 1130 psi Intermediate 8,178' 9-5/8" 8,178' 7,416' 5750 psi 3090 psi Production 3,074' 7" 10,999' 10,059' 8460 psi 8610 psi Liner N/A N/A N/A N/A N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" N-80 7,870' Packers and SSSV Type: Packers and SSSV MD (ft): Baker Mod D Permanent Packer and N/A 7,810' and N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 7/15/2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL Q Commission Representative: ' 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature "~"° hone 276-7600 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~'G ~ _ ~~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~ • Subsequent Form Required: ~~ APPROVED BY Approved by: ~ COMMISSIONER THE COMMISSION Date: ~ ~~ t v Form 10-403 Revised 06/20 ~ ~~ JU(,: ~ ~ 2008 ORIGINq~ ~r ~l 7./c7.o$ Submit in , te~~/P/~` Bruce Platform Well No. 3 GP 17587 RKB to TBG Head = 42.80' WBD Bruce GP 17587-31.doc CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20 133 K-55 18.73 Surf 589' 13-3/8" 54.5 J-55 8 rd, STBC 12.515 Surf 2,092' 9-518" 43.5 S-95 ERW ST&C 8.755 Surf 52' 40 N-80 Buttress 8.835 52' 4,676' 40 S-95 ERW ST8~C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 7" 32 N-80 Butt. 6.094 7,925' 8,014' 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' Tubing: 3-1 /2" 9.2 N-80 ABC 2.992 42.8' 7,870' JEWELRY DETAIL NO. De th OD ID Item 1 42.80' CIW Tubing Hanger, BPVP ? 2 43.80' - ? Crossover, 3-1/2" EUE 8rd Pin x 3-1/2" Buttress Pin 3 44.30' - 2.992 Pup, 3-1/2", ABC 4 48.30' - 2.992 Pup, 3-1/2", ABC 5 58.30' - 2.992 Pup, 3-1/2", ABC 6 7,824' 4.875 3.000 Locator, Baker 190-47 7 7,825' 4.734 3.000 Seal Assembly, Baker, 190-47 8 7,839' - 2.992 1 joint, 3-1/2" , 9.2#, N-80, ABC 9 7,870' - - Mule Shoe 10 7,810' - - Packer, Permanent, Baker Mod. D (DPM) Fill Tagged w/ GR 6-11-08 9,067' RKB (SLM) Zone Top PERFORATION DATA Btm Amt Accum Last SPF Perf Date Present Condition C-1 9030' 9050' 30 4 10/3/1999 1999 C-2 9,240' 9,310' 70 4 i£ 8 6/30/1972 C-2X 9240' 9260' 20' 4 10/3/1999 1999 C-2 9,380' 9,400' 20 4 & 8 6/30/1972 C-2X 9,390' 9,400' 10 4 10/3/1999 1999 C-3/4 9,480' 9,495' 15 4 6/30/1972 C-5 9,580' 9,650' 70 4 & 8 6/30/1972 C-7 10,045' 10,095' 50 4 & 8 6!30/1972 10,120' 10,130' 10 4 6/30/1972 10,150' 10,200' 50 4 i£ 8 6/30/1972 10,215' 10,270' 55 4 8~ 8 6/30/1972 10,290' 10,310' 20 4 & 8 6/30/1972 C-8 10,432' 10,462' 30 4 8~ 8 6/30/1972 10,478' 10,578' 100 4 & 8 6/30/1972 C-9 10,628' 10,715' 87 4 8 8 6/30/1972 DATE:6-16-2008 JRN PBTD = 10,989' TD = 11,015' HOLE ANGLE thru Interval = ° Bruce Platform Well No. 3 GP 17587 RKB to TBG Head = 42.80' WBD_Bruce_GP_17587-31_Proposed.doc CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20 133 K-55 18.73 Surf 589' 13-3/8" 54.5 J-55 8 rd, ST&C 12.515 Surf 2,092' 9-5/8" 43.5 S-95 ERW ST&C 8.755 Surf 52' 40 N-80 Buttress 8.835 52' 4,676' 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 7" 32 N-80 Butt. 6.094 7,925' 8,014' 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' Tubing: 3-1/2" 9.2 N-80 ABC 2.992 42.8' 7,870' JEWELRY DETAIL NO. De th OD ID Item 1 42.80' CIW Tubing Hanger, BPVP ? 2 43.80' - ? Crossover, 3-1/2" EUE 8rd Pin x 3-1/2" Buttress Pin 3 44.30' - 2.992 Pup, 3-1/2", ABC 4 48.30' - 2.992 Pup, 3-1/2", ABC 5 58.30' - 2.992 Pup, 3-1l2", ABC 6 7,824' 4.875 3.000 Locator, Baker 190-47 7 7,825' 4.734 3.000 Seal Assembly, Baker, 190-47 8 7,839' - 2.992 1 joint, 3-1/2" , 9.2#, N-80, ABC 9 7,870' - - Mule Shoe 10 7,810' - - Packer, Permanent, Baker Mod. D (DPM) Fill Tagged w/ GR 6-11-08 9,067 RKB (SLM) Zone Top PERFORATION DATA Btm Amt Accum Last SPF Perf Date Present Condition C-1 9020' 9085' 30 4 Proposed Proposed C-1 9030' 9050' 30 4 10/3/1999 1999 C-2 9,240' 9,310' 70 4 & 8 6/30/1972 C-2X 9240' 9260' 20' 4 10/3/1999 1999 C-2 9,380' 9,400' 20 4 & 8 6/30/1972 C-2X 9,390' 9,400' 10 4 10/3/1999 1999 C-3/4 9,480' 9,495' 15 4 6/30/1972 C-5 9,580' 9,650' 70 4 & 8 6/30/1972 C-7 10,045' 10,095' 50 4 & 8 6/30/1972 10,120' 10,130' 10 4 6/30/1972 10,150' 10,200' 50 4 & 8 6/30/1972 10,215' 10,270' 55 4 & 8 6/30/1972 10,290' 10,310' 20 4 & 8 6/30/1972 C-8 10,432' 10,462' 30 4 & 8 6/30/1972 10,478' 10,578' 100 4 & 8 6/30/1972 C-9 10,628' 10,715' 87 4 & 8 6/30/1972 DATE:6-16-2008 JRN PBTD = 10,989' TD = 11,015' HOLE ANGLE thru Interval = ° Chevron ~ • Granite Point Field Bruce Platform Well # 3-87 (GP 17587) 7/7/08 OBJECTIVE: • Add perfs and re-perf the C 1 sand. PROCEDURE SUMMARY: • Rig up slickline and pressure test to 250 psi low and 2500 psi high. • RIH with gauge rings starting with 2.80" to determine perf gun size and tag fill. • RIH with dummy guns and tag fill. • RIH and add/re-perforate C1 sand from 9020' (+/-) to 9085' (+/-) RKB. • Rig down slickline and secure well ~-~~~ `~rw ~ v~. Br 3-87 REVISED BY: BCA 7/7/08 DI019 STATE OF ALASKA Page 1 of 5 OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Re: The APPLICATION OF Union Oil Company of California ("Unocal") for disposal of Class 11 oil field wastes by underground injection in the Granite Point State 17587 #3 well. Anchorage, Alaska 99501-3192 Disposal Injection ) Order No. 19 Granite Point State ) 17587 #3 well ) Granite Point Field July 6, 1999 ~v~L ~ G~ -~ ~ 0~c~ ~ev~ ~~~~ ~~ \ ~ P ~~k ~ t~~~~ ~ ~~~ ~~~~ IT APPEARING THAT: 1. By correspondence dated February 10, 1999, Unocal requested authorization from the ~1l l Alaska Oil and Gas Conservation Commission ("Commission"} to dispose of Class II oil field waste fluids by underground injection into the Granite Point State 17587 #3 well, located on the Bruce Platform in the Granite Point Field. 2. Unocal submitted additional information supporting the application on February 17, 1999. 3. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on February 19, 1999. 4. The Commission did not receive any protest or a request for a public hearing. FIND{NGS: 1. Unocal is the operator of the Granite Point Field. There are no other operators within aone- quarter mile radius of the proposed disposal injection well. 2. The portion of freshwater aquifers beneath Cook Inlet described by aone-quarter mile area beyond and tying directly below the Granite Point Field are exempt aquifers under 40 CFR 147.102(b)(2)(i) and 20 AAC 25.440(c}. 3. Unocal proposes to conduct disposal operations into the Lower Tyonek Formation between 9,240 feet and 10,715 feet measured depth ("MD") in the Granite Point State 17587 #3 well. At this depth, there are no other wells within one-quarter mile radius of the Granite Point State 17587 #3 well. 4. The Granite Point State 17587 #3 well is perforated between 9,240 feet and 10,715 feet MD http://www.state.ak.us/locaUakpages/ADMIN/ogc/orders/dio/diol9.htm 7/11/2008 DI019 Page 2 of 5 • in the C-2, C-2X, C-3, C-5, and C-7 sandstone horizons of the Granite Point Middle Kenai Oil Pool. 5. The Granite Point. State 17587 #3 well was drilled to the northern portion of the Granite Point Field, an area with relatively low recovery factors due to the generally poor reservoir characteristics of the Lower Tyonek Formation at this location. 6. The Granite Point State 17587 #3 well has been shut-in since February of 1987 because of uneconomic performance. 7. The proposed disposal zone in the Granite Point State 17587 #3 welt is overlain by more than 5,000 feet of Upper Tyonek Formation. 8. The Upper Tyonek Formation is dominated by impermeable lithotoges, consisting primarily of interbedded siltstone, mudstone, and coal. Some lenticular sandstones are present, but they are volumetrically unimportant. 9. Evaluation of cased hole logs and cement records indicates the Granite Point State 17587 #3 well is cemented adequately to isolate the proposed disposal interval. 10.The well is completed with 20 inch conductor set at 589 feet MD, 133/s inch surface casing set at 2,092 feet MD and cemented to surface, a long string of 9~/s inch production casing set at 8,178 feet MD and cemented back into the surface casing, and a 7 inch liner from 7,925 feet to 10,999 feet MD. 11.The well is equipped with 3%Z inch tubing string to 7,869 feet MD and 8.6 inch packer set at 7,$24 feet MD. 12.The Granite Point State 17587 #3 well was completed initially as an oil producer. It produced from March 1967 until June 1972; cumulative oi[ production was 1.3 million barrels. It was converted to an injection well in July 1972; cumulative water injection was 4.25 million barrels through January 1987. The well has not been used since that date. 13.The waste stream wilt consist of produced water, drilling, completion and workover fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms; and other Class it fluids generated from drilling, production, workover and completion operations. Constituent volumes will vary depending on drilling, workover, stimulation and maintenance activity. 14.Unocal estimates that the maximum daily volume to be injected will not exceed 3,000 barrels per day. 15.Unocal estimates the average injection pressure will be about 2,500 psi, with a maximum daily injection pressure of 3,000 psi, at an injection rate ofi three barrels per minute. 16.Unocal expects to maintain infectivity by occasionally stimulating the disposal interval. Stimulation activity will entail pumping solid free fluid to disperse solids, chemically treating the well, and elevating pressure to breakdown the disposal interval. 17.Fracture propagation within the disposal interval is an integral part of the process of placing http://www.state.ak.us/IocaUakpageslADMIN/ogc/orders/dio/dio 19.htm 7/11 /2008 DI019 Page 3 of 5 • waste fluids into the disposal interval. Fractures will be created as the disposal zone begins to plug. Fractures (or disaggregation of the clogged pores and rock matrix) provide pathways to transport waste fluids to undamaged storage volume within the disposal zone. 18.Unocal will conduct periodic surveillance of disposal operations through temperature surveys, pressure transient tests, step rate tests, thermal decay time logs, disposal rate and pressure monitoring, mechanical integrity tests and tagging effective depth to determine fill buildup. 19.Reservoir surveillance techniques will also be used for tracking near wellbore fluid movement, estimating dimensions of disposal fracture or disposal storage volume and detecting changes in disposal zone characteristics. 20.Evaluation of operation performance and reservoir surveillance will aid in preventing fracturing of the confining zones. CONCLUSIONS: 1. The requirements of 20 AAC 25.252(c) have been met. 2. All underground sources of drinking water in the Granite Point field have been exempted for Class II injection activities. 3. Waste fluids authorized for disposal under this order in the Granite Point State 17587 #3 well will consist exclusively of Class II waste generated from drilling, completion, workover and production operations. 4. Permeable strata, which reasonably can be expected to contain the total volume of disposal fluids anticipated for this project, are present in the Lower Tyonek Formation. 5. Waste fluids wiN be contained within appropriate receiving intervals by confining lithologies in the Upper Tyonek Formation, cement isolation of the wellbore and operating conditions. 6. Disposal injection of Class II wastes into the Granite Point Middle Kenai Oil Pool in the Granite Point State 17587 #3 well will not cause waste because the well no longer has utility as a production well or as an injection well for enhanced oil recovery. 7. Disposal injection operations in the Granite Point State 17587 #3 well will be conducted at rates and pressures below those required to fracture the confining zones. 8. Periodic fracturing and stimulation will be required to place solids into the disposal interval. Fracture growth can be contained within the disposal interval by controlling the rate and volume of injection. 9. Surveillance of disposal material movement, monitoring of operating parameters and demonstration of mechanical integrity every four years will ensure the waste fluids are contained within the disposal interval. Changes in baseline data may be an indication that fluid is escaping beyond the designated confining zone. 10.The mechanical integrity of the tubing, packer and production casing in the Granite Point http://www.state.ak.us/IocaUakpages/ADMIN/ogc/orders/dio/dio 19.htm 7111 /2008 DI019 Page 4 of 5 • State 17587 #3 well must be demonstrated in accordance with 20 AAC 25.412 prior to commencing injection operations. 11.Disposal injection operations in the Granite Point State 17587 #3 well will not cause waste, jeopardize correlative rights, or impair ultimate recovery. NOW, THEREFORE, IT IS ORDERED THAT: Rule 1 Authorized Infection Strata for Disposal. Class II oil field fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for disposal into the Lower Tyonek Formation from 9,240 to 1©,715 feet MD in the Granite Roiint State 17587#3 well Rule 2 Authorized Fluids This authorization is limited only to Class II fluids. The Commission must be notified immediately if any non-Class II fluids are injected into the well. Rule 3 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission that ensures the tubing- casing annulus is pressure tested prior to initiating disposal and at least once every four years thereafter. The casing must be tested at a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the true vertical depth of the packer, whichever is greater, but may not be subjected to a hoop stress greater than 70% of the minimum yield strength of the casing. The test pressure must show stabilizing pressure and may not decline more than 10% within thirty minutes. The Commission must be notified at least twenty-four (24) hours in advance to enable a representative to witness pressure tests. Rule 4 We11 Integrity Failure Whenever disposal rates and/or operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action and obtain Commission approval to continue injection. Rule 5 Surveillance Operating parameters including disposal rate, disposal pressure, annulus pressures and volume of fluids and solids pumped must be monitored and reported according to requirements of 20 AAC 25.432. An annual report evaluating the performance of the disposal operation must be submitted by July 1 of each year. Rule 6 Administrative Action Upon request, the Commission may administratively revise and reissue this order or any of its rules upan proper showing that the change is based on sound engineering practices, wilt not allow waste fluids to escape from the disposal zone, and will not cause waste. http://www.state.ak.us/local/akpages/ADMIN/ogc/orders/dio/diol9,htm 7/11/2008 DI019 • DONE at Anchorage, Alaska and dated July 6, 1999. Robert N. Christenson, P.E., Chairman Camille Oechsli, Commissioner Di posal_Order__Index Page 5 of 5 http://www.state.ak.us/local/akpages/ADMIN/ogc/orders/dio/dio 19.htm 7/11 /2008 A Administrative Approval DIO 19.01 • Re: The application from Unocal Inc. to perforate additional interval in GP State 17587 No. 3 for disposal of Class II fluids. August 12, 1999 C.A. Ruff Unocal North American Oil and Gas Division P.O. Box 196427 Anchorage, Alaska 99519-6247 Dear Mr. Ruff: We have received your application to add perforations above the defined disposal interval pursuant to DIO 19. The interval requested represents the "Cl" sand within the Lower Tyonek Formation between 9015 feet and 9240 feet measured depth in the Granite Point State 17587 #3 well. 'The Commission has reviewed your application to expand the defined disposal interval up to 9015 feet measured depth. Initial development of the well as a producer and then as an injector utilized perforated intervals up to 9240 feet measured depth. The initial disposal intervals only considered developed sands and did not address non-developed sands. The additional interval does not come within a quarter mile of any other wells in the area. Cement isolation appears to be adequate for containment of disposal fluids and the operator has demonstrated mechanical integrity of the well. Additional perforations will not affect the amount of impermeable lithologies in the Upper Tyonek Formation, which serve as barriers to disposal fluid migration. The Alaska Oil and Gas Conservation Commission has reviewed the evidence available and finds that adding perforations to the GP 17587 #3 well will not affect containment of disposal fluids. The additional perforations will allow flexibility in conducting waste disposal operation, will not jeopardize correlative rights nor cause waste. Therefore, the Commission approves the addition of perfaratiais to the GP I7587 #3 well and expansion of the disposal zone up 9015 fit rneasur«3 dom. Sincerely, Robert N. Christenson, P.E. David W. Johnston Chairman Commissioner BY ORDER OF THE COA~iNIISSION MEMORANDUM / /~ TO: Jim Regg w<.~~~ !1 ~ ~~~~ P.I. Supervisor l f FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Comm. DATE: Friday, September 14, 2007 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 3 GRANITE PT ST 17587 3 Src: Inspector NON-CONFIDENTIAL Reviewed By: ..; ~..; : ~ G ~.s P.I. Suprv~r•5 - !I ~ ~~c' Comm Well Name: GRANITE PT ST 17587 3 API Well Number 50-733-20437-00-00 Inspector Name• Lou Grimaldi Insp Num• mitLG070907093424 Permit Number 166-052-o Inspection Date• 9/6/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WClI ~ 3 iType Ind, N 1 T~ ~ 709 j ~ 800 ~ ]900 ~ 1900 ~ ]900 P.T. ~ 166os2o ~TypeTest ~ SPT Test psi i 1900 ~ OA a ~I o j o ~ o Interval 4YRTST P~ P ..% Tubing 350 ~, 400 j 400 ~I 400 I NOteS' Dennis Powell very accomodating with travel • to/from platform. Good test, well had 800 psi on IA when I arrived. Bled back to check fluid level which was at surface. Test went well. ~~~~ Gov ~ ~ Zoo? Friday, September 14, 2007 Page 1 of 1 RE: MIT Bruce 04-08-06 - - e e Tom you are correct. We only plan to inject into the wells for 6 to 8 hours. Just long enough that we can confirm the rate and pressure at which the wells will take water. From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, April!?, 20063:09 PM To: Greenstein, Larry P Cc: James Regg; Lambert, Steve A; Rodriguez, Tim E. Subject: Re: MIT _Bruce_04-08-06 Larry, et al: The MITs you provided look acceptable. I have examined the files and did not find anything that should prevent you from doing the injectivity testing. From the "letter and 404" Steve submitted, it appears that the testing will only involved a few hours of injection. Is that the case? Call or message with any questions. Tom Maunder, PE AOGCC ·~c !.. ~,,~ ;¡,,~¡; if ì ~'-J{,-,;1)T!;ì \:,f'.;;.,; (":. " .'..Yo. {) Greenstein, Larry P wrote, On 4/17/20069:16 AM: ~ \ <0<0 - OS" ð' Here is the MIT report for the Bruce wells 3-87, 5RD-86, 6-42 and 12RD-42. We will be checking the injectivity performance on 5RD as our primary candidate, but wanted some back-up wells just in case. Bruce 3-87 is the intermittent disposal well on the platform. Please let us know if we may begin our injectivity testing based on these preliminary MIT results. Thank you. Larry «MIT _Bruce_ 2006.xls» 1 of 1 4/18/20062:59 PM e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us greensteinlp@chevron.com; trodriguez@chevron.com OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: Unocal Alaska Granite Point Field / Bruce Platform 04/14/06 Ken Sides/Dennis Powell Pre-Injectivity Tests Packer Depth Pretest Initial 15 Min. 30 Min, ~ Weill Sr 3-87 I Type Inj, I N TVD I 7,091' Tubing 400 410 410 410 I ntervall 4 P.T.D.1166-0521 Typetest I P Test psi I 1773 Casing 990 1,775 1,775 1,775 P/FI P , Notes: OA 0 0 0 0 Weill Sr 5RD-86I Type Inj, N TVD I 7,760' Tubing 30 30 30 30 Intervall I P,T.D. 179-0051 Type test I P Test psil 1940 Casino 640 1,950 1,950 1,950 P/FI P Notes: OA 135 140 140 140 Weill Sr 6-42 I Type Ini.1 N TVD I 8,149' Tubing 0 0 0 0 Interval I I P,T.D.1167-019! Type test I P Test psil 2037 Casing 505 2,040 2,040 2,040 P/F P Notes: OA 195 335 335 335 Well! Br 12RD-42I Type Ini.1 N TVD I 8,594' Tubing 310 310 310 310 Interval! I PT.D, 178-0591 Typetestl P Test psil 2149 Casing 1,500 2,200 2,200 2,200 P/F P Notes: Top of 7" liner 8282' OA 310 310 310 310 TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4= Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form BFL 9/1105 MIT_Bruce_ 2006.xls APR-IO-2003 THU 02:50 PM ---... " ----..." ) FAX NO. ) P, 02/09 ..,,'"""~ ,i tJfv---/ 1 UNOCALe Dwight E. Johnson Fiald Superintandent Unocal Alaska Tel 907.263.7654 Fax 907.263.7847 Cell 907.252.1462 e-mail johnsond@unocal,çQm ._-,....-~.- .......-~...,... VIA FACSIMILE AND FIRST CLASS MAIL FacsimUe: 907.276.7542 April 7 2003 ~ED OC1 ~ 1 1\)05 Mr. Winton Aubert Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue #100 Anchorage Alaska 99501-3539 " "'--'~C:>~~\4~-\~'\- \'\~fl t\.~ \b~-as~ J Re: NO COMMUNICATION BETWEEN BRUCE WELL # 3..87 AND Well # 8-42 <....~~~~,'\ \ Dear Mr. Aubert: '-=>,,~\\-<LV ~ ~ \-- \ ~ 'l ~ ð~ ~ \<o~'"()~<o Unocal Alaska is pleased to inform you that we have reviewed the pressure data for the 2002 injection into the Bruce Platform Well # 3...87 Class II Disposal Wen and the corresponding readings on the Bruce Platform Well # 8-42 annuli, as wall as analytical data on the material recovered from the Bruce Platform Well # 8-42 9 518" x 13 318 "annulus, and concluded that there is no communication between Well # 3-87 and Well # 8-42. On Friday. March 21 2003 I contacted you to let you know that Unocal Alaska was looking into the composition of and cause for some material that was bled from the 9 5/8't x 13 3/8" annulus of our Bruce Platform Well # 8-42. The Operator said that the fluid smelled like diesel and seemed like the type of material that had been injected down the Bruce Platform Well # 3-87 Class II Disposal WelL He thought that Wen # 8-42 had been drilled with water based mud and that there was no logical source of diesel in that annulus. However. it turns out that a significant amount of diesel was added to the water based mud system with which Well 8~42 was originally drilled, and the original chrome lignosulfonate 6 ..... 7 ok diesel system would be expected to be inside the 9 5/8" x 13 3/8'1 annulus. ,,) ~,.,..., ~-\"I: .~ ~\~~ ~ ~~ \ :\\-.t~ ~~~\\""'I ~'> K) ~\1t<"s.';:'~ s.~~1 \"<:.~<,"'- c \'.. "'<is' \-k'" =..\.)~? 0-...... 'i t--.\L~'J -\0 ~~~~ '\~~ C>.1NNù \,,<>.. a\,~~~",,0;::O \ "'~ \a-:'~~ G"> ~"\JO-. \ ~~ . SC\,,~ \\'v"-.}'\ÒC\ ~Q..":> ~\~ ~K \~~ <:')"~~'-J\~~ f ~~ ~\~~\ ~~c. \\ ~ \.) r--oco... \ \Cè.O~ ~a t" ~~ c-~ \- \:~<::... \e -' r *,"", t'\. ~ J.. ~ CA~"Ö \'\ ~ '\ S \J-o.) a,\.L \ ~ ~d ~ ~\.x -Ç\~ ~c~ Û- ~ ro--\\~ SO ~ Union 011 CDmpany of callfomia I UnQÇ~1 ~aakA gOg West ath Avenue, AnCl'1orsge, Alaska 99501 htt$)://WWW.unOCSI.com ~<C>\-M':\~" ~~CJi~ ':J IO/~,,()\ \)..)1 ~c..., ~Q\\\'->()'" "-\,-\\'''s_~je 2>\.J (è. \-0 '\ ''- .\-((. '-\i'-4...( ~ ~ ~- <S(è\\..)', CLQ . II" , I " ~ Ll(\\ ,) ) UNOCALe Dwight E. Johnson Field Superintendent Unocal Alaska Tel 907.263.7654 Fax 907.263.7847 Cell 907.252.1462 e-mail johnsond@unocal.com VIA FACSIMILE AND FIRST CLASS MAIL Facsimile: 907.276.7542 April 7, 2003 Mr. Winton Aubert Petroleum Engin~er Alaska Oil and Gas Conservation Commission 333 W. ih Avenue #100 Anchorage, Alaska 99501-3539 RECEIVED APR 1 8 2003 A'aska Oi' & Gas Cons. Commission Anchorage Re: NO COMMUNICATION BETWEEN BRUCE WELL # 3-87 AND Well # 8-42 Dear Mr. Aubert: Unocal Alaska is pleased to inform you that we have reviewed the pressure data for the 2002 injection into the Bruce Platform Well # 3-87 Class II Disposal Well and the corresponding readings on the Bruce Platform Well # 8-42 annuli, as well as analytical data on the material recovered from the Bruce Platform Well # 8-42 9 5/8" x 13 3/8 "annulus, and concluded that there is no communication between Well # 3-87 and Well # 8-42. On Friday, March 21,2003 I contaçted you to let you know that Unocal Alaska was looking into the composition of and cause for sÒ,me material that was bled from the 9 5/8" x 13 3/8" annulus of our Bruce Platform Well # 8-42. , t.".. The Operator said that the fluid smelled like diesel and seemed like the type of material that had been injected down the Bruce Platform Well # 3-87 Class II Disposal Well. He thought that Well # 8-42 had been drilled with water based mud and that there was no logical source of diesel in that annulus. However, it turns out that a significant amount of diesel was added to the water based mud system with which Well 8-42 was originally drilled, and the original chrome lignosulfonate 6 - 7 % diesel system would be expected to be inside the 9 5/8" x 13 3/8" annulus. Union Oil Company of California I Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http://www.unocal.com ) Mr. Winton Aubert April 7, 2003 Page 2 Below appears a brief history of the drilling and cementing of Bruce Well # 8-42: Bruce Well # 8-42 was drilled and completed as follows: Spud date 9-5/8" casing set date (TD) Drilling rig release date Workover rig completion dates 7/22/67 9/9167 9/10/67 9/13/67 - 9/17/67 The Baroid drilling mud used was described as a Q-Broxin/BenExlCC-16 water base mud. Q-Broxin is a chrome-based lignosulfonate, BenEx is a bentonite extender, and CC-16 is a causticized lignite. 13-3/8" was set at 2059'. Diesel (probably whatever type fueled the rig) was added beginning at about 4600' and was added daily to make up about 6% - 7°k of mud volume to TD. 9-5/8" was set at 10086'. Cemented with 1300 sacks class G cement. No CBL has been run on the well. A rough calculation, assuming gauge 12-1/4" hole and 1.1 ft3 yield on the cement would then result in an estimated TOC at 5520'. Chemical Testing and Engineering Environmental Services Laboratory (SGS) performed analytical testing of the sample recovered from the Well # 8-42 annulus. The laboratory results appear as Attachment 1, uSGS Laboratory Results". The Gas Chromatography/Mass Spectrophotometer High Resolution Fingerprint demonstrates that the pattern is consistent with a weathered #1 diesel and some trace amounts of residual hydrocarbons such as crude oil. Steve Ede of SGS asserts that this fingerprint is significantly different from (lighter than) either the Diesel #1/#2 blend used in small amounts to suspend the Flo-Vis during the Bruce Well # 3- 87 injection or the Diesel #4 (MAPCO 200) used as a drilling fluid base oil for the cuttings that were slurried and injected in Bruce Well # 3-87. In addition, chromium was detected at 206 ppm using an Optical method (215 ppm ICP, verbal from SGS 4/7/03) in the sample recovered from Well # 8-42. This chromium level, when compared to Aluminum and other elements, was significantly elevated from the amount that would naturally occur in dirt according to Mr. Ede. Since the time when Well # 8-42 was originally drilled Unocal has gone to chrome-free mud systems for its drilling activities. Therefore, the appearance of the elevated chrome levels in the fluids appears to be a definitive marker linking the fluid recovered from the Well# 8-42 annulus with the original mud in the annulus when the well was cemented. Union Oil Company of California / Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http://www.unocal.com ) Mr. Winton Aubert April 7, 2003 Page 3 The pressures in the Well # 8-42 annuli were monitored during the injection events in Well # 3- 97. Mr. Chris Myers with Unocal reviewed the pressure date on those annuli compared with the injection events into Well # 3-97. The pressures in the annuli did not show any responses to the Well # 3-97 injection events. Since the fluid recovered from Well # 8-42 is from the original drilling and cementing of the well and there are no pressure responses in Well # 8-42 from Well # 3-97 injection events Unocal Alaska concludes that there is no communication between the two wells. Thank you very much for your consideration of these matters. If you have any questions about the analytical data please contact Laura Hammond at (907) 263-7898. My number is (907) 263- 7654. Best regards, ~~~ Dwight Johnson cc: Mr. Tom Maunder, AOGCC Union Oil Company of California / Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http://www.unocal.com .,) Attachment 1 SGS Laboratory Results 4-·2-03; 3:24P.M; ;907 5615301 #2/ 5 ) ) 200 W. Potter Drive Anchorage, AK 995 J 8-1605 Tel: (907) 562-2343 Fax: (907) 56 J -530 1 Web: http://www.sgsenvironmental.com Laura Han11110nd Unocal-Oìl & Gas Division P.O. Box 8129 Nikiski, AK 99635 Work Order: Client: Report Date: 1031567 Bruce 842 9 5/8 x 13 3/8 Unocal-Oil & Gas Division March 28, 2003 ~nclosed are the analytical results associated with the above workorder. i\s required by the state of Alaska and theUSEP A, a fonnal Quality Assurance/Quality Control Program ismaíntained by ~GS. A copy of our Quality Control Manual that outlines this program is available at your request. ~xcept as specifically noted, all statements and data in this report are in confonnance to the provisions set forth in our Quality t\.ssurance Program P{an. . Jyou have any questions regarding this report or if we can be of any other assistance, please call your SGS Project Manager at :907) 562-2343. " [he following descriptors may be found on your report which will serve to furthe~ qualify the data. GT D LT Practical Quantitation Limit (reporting limit). . Indicates the analyte was analyzed for but not detected. Indicates an estimated value that falls below PQL, but is greater than the MOL. Indicates an estimated value that falls below PQL, but is greater than the MOL. Indicates the analyte is found in the blank associated with the sample. The analyte has exceeded allowable limits. Greater Than Secondary Dilution Less Than Surrogate out of range PQL U F J B * ~ SGS Member of the SGS Group (Societe Generale de Surveillance) 4- 2-03; 3:24PM; ;907 5615301 # 3/ 5 ') ) 1031567001 Unocal-0il & Gas Division, Bruce .842 9 5/8 x 13 3/8 Hydrocarbon from Bruce 842 Water (Surface, Eff., Ground) AU DateslTimes are Alaska Standard Time Printed Date/Time 03/28/2003 14:0~6 Collected Dateffime 03/25/2003 10:25 Received Date/Time 03/25/2003 10:40 Technical Director Stephen C. Ede Release<lBy ~. M S Ref.# mtName )jectName/# mt Sample ID trix lple Remarks: )RO .; The pattern is consistent with a weathered #1 Diesel and some trace amounts of residual hydrocarbons such as crude oil. lmeter Results PQL Units Method Allowable Limits Prep Date Analysis Date Init tals Department Chromium 206 0.900 mg/L SW84660lOB 03/27/03 03/27/03 MTG nivolatile Organic Fuels Department Diesel Range Organics 1 '1400 300 mg/L AKI02 03/26/03 03/26/03 DS :rogates 5a Androstane <surr> 111 % AKI02 50-150 03/26/03 03/26/03 DS :. 0.2 ~~J'~_ 1.5 1.4 1.3 1.2 .. I···· I"" :'0.0 :'0.4 : 1.0 ,i :. 0.6 II> ~ 0.6 :'1.2 =-1.4 f r 1.6 . ~ ---------- Analyst: OS Analyst: OS Area Amount IC ' Units 8554 I 10.691 TH 2924 34.601 HH 7816012 113586.578 768042 12191.660 7824566 113710.898 77Q966 12238.075 aPR-10-2003 THU 02:50 PM NO, P. 02/09 UNOCAL Dwigitt E, Johnson Field Superintendent Unocal Alaska Tel 907.263.7654 Fax 907.263.7847 Cell 907.252.1462 e-mail johnsond~unocai,~m VIA FACSIMILE AND FIRST Ct. ASS MAIL Facsimile: 907.276.7542 April 7, 2003 Mr. Winton Aubert Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue #100 Anchorage, Alaska 99501-3539 Re: NO COMMUNICATION BETWEEN BRUCE WELL # 3-87 AND Well # 8-42 Dear Mr. Aubert: Unocal Alaska is pleased to inform you that we have reviewed the pressure data for the 2002 injection into the Bruce Platform Well # 3-87 Class !! Disposal Well and the corresponding readings on the Bruce Platform Well # 8-42 annuli, as well as analytical data on the material recovered from the Bruce Platform Well # 8-42 9 518" x 13 3/8 "annulus, and concluded that there is no communication between Well # 3-87 and Well # 8-42. On Fdday, March 2t, 2003 1 contacted you to let you know that Unocal Alaska was looking into the composition of and cause for some material that was bled from the 9 5/8" x 13 3/8" annulus of our Bruce Platform Well # 8-42. The Operator said that the fluid smelled like diesel and seemed like the type of material that had been injected down the Bruce Platform Well # 3-87 Class II Disposal Well. He thought that Well # 8-42 had been drilled with water based mud and that there was no logical source of diesel in that annulus. However, it turns out that a significant amount of diesel was added to the water based mud system with which Well 8-42 was originally drilled, and the original chrome lignosulfonate 6 - 7 % diesel system would be expected to be inside the 9 5/8" x 13 3~8" annulus. Union OII Company of California ! Unocal Aiasl<a 909 West 9th Avenue, AnCllorage, Alasl<a 99501 htt~://www.unOC~l.com 0-2003 THU 02:50 PM Ffl× NO, P, 03/09 Mr, Winton Aubert April 7, 2003 Page 2 Below appears a bdef history of the drilling and cementing of Bruce Well # 8-42: Bruce Well # 8-42 was drilled and completed as follows; Spud date 9-{S/8" casing set date (TD) Drilling rig release date -- Workover rig completion dates -- 7122167 919167 9110167 9113167 - 9/17~67 The Baroid drilling mud used was described as a Q-Broxin/BenEx/CC-16 water base mud. Q.Broxin is a chrome-based lignosulfonate, BenEx is a bentonite extender, and CC-16 is a causticized lignite. t 3-318" was set at 2059'. Diesel (probably whatever type fueled the rig) was added beginning at about 4600' and was added daily to make up about 6% - 7% of mud volume to TD. 9-5/8" was set at t0086'. Cemented with 1300 sacks class G cement- No CBL has been run on the well. A rough calculation, assuming gauge 12-il4" hole and 1.1 ft3 yield on the cement would then result in an estimated TOC at {;520'. Chemical Testing and Engineering Environmental Services Laboratory (SGS) performed analytical testing of the sample recovered from the Well # 8-42 annulus. The laboratory results appear as Attachment 1, "SGS Laboratory Results". The Gas Chromatography/Mass Spectrophotometer High Resolution Fingerprint demonstrates that the pattern is consistent with a weathered #1 diesel and some trace amounts of residual hydrocarbons such as crude oil. Steve Ede of SGS asserts that this fingerprint is significantly different from (lighter than) either the Diesel #1/#2 blend used in small amounts to suspend the FIo-Vis during the Bruce Well # 3- 87 injection or the Diesel #4 (MAPCO 200) used as a drilling fluid base oil for the cuttings that were slurried and injected in Bruce Well # 3-87. In addition, chromium was detected at 206 ppm using an Optical method (215 ppm ICP, verbal from SGS 4/7/03) in the sample recovered from Well # 8-42. This chromium level, when compared to Aluminum and other elements, was significantly elevated from the amount that would naturally occur in dirt according to Mr. Ede. Since the time when Well # 8-42 was originally drilled Unocal has gone to chrome-free mud systems for its drilling activities. Therefore, the appearance of the elevated chrome levels in the fluids appears to be a definitive marker linking the fluid recovered from the Well# 8-42 annulus with the original mud in the annulus when the well was cemented. Union Oil Company of California I Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska gg501 http:l/www.unoc, al.com ~PR-lO-2003 THU 02:50 PH F~qX NO, P, 04/09 Mr. Winton Aubert April 7, 2003 Page 3 The pressures in the Well # 8-42 annuli were monitored during the injection events in Well # 3- 97. Mr, Chris Myers with Unocal reviewed the pressure date on those annuli compared with the injection events into Well # 3-97. The pressures in the annuli did not show any responses to the Well # 3-97 injection events, Since the fluid recovered from Well # 8-42 is from the original drilling and cementing of the well and there are no pressure responses in Well # 8-42 from Well # 3-97 injection events Unocal Alaska concludes that there is no communication between the two wells. Thank you very much for your consideration of these matters. If you have any questions about the analytical data please contact Laura Hammond at (907) 263-7898. My number is (907) 263- 7654. Best regards, Dwight Johnson cc: Mr. Tom Maunder, AOGCC Union Oil Company of California I Unocal Ala~"l(a 909 WeSt 9th Avenue, Anchocage, Alaska 98801 http:l/www.unoc~l.corn APR-10-2003 THU 02:50 PM FAX NO, P, 05/09 Attachment 1 SGS Laboratory Results aPR-10-2003 THU 02:51 Laura 'Hammond · Unocal-Oil & Gas Division P~O. Box 8129 Nikiski, AK 99635 PM NO, P! 200 W, Potter Drive Anchorage, AK 99518-1605 Tel: (907) 562-2343 Fax: (.907) 561-:5301 Web: http://www.sgscttvironm~tal,com 06/09 Work Order: · . Client: Report Date: .. I031567 Bmoc $42 9 5/8 x 13 3/8 Unocal-Oil & Gas Division March 28, 2003 · . Enclosed are the anaiytic.al results associated with tho above worko~der. As required by the state of Alaska and the USEPA, a formal Quality Aasurance/Quality Control Program is maintained by SGS. A copy of our Quality Control Manual that outlines this program is available at yom' request.. Except as specifically .noted, ail statements and data in this report are in conformance tO the provisions set forth in our Quality Assurance Pmg~am Plan, .. If you"have any queslions regarding this report or if we can be of any other assistance, please call your SGS Project Manager at (907) 562-2343. The i~ollowing descriptors may be found on your report which will serve to furth,r qualify the data. PQL U F 'B * D LT Practical Quantitation Limit (reporting limit). Indicates the analyte was analyzed for but not detected. Indicates an estimated value that falls below PQL, but is greater than the MDL Indicates an estimated value that falls belo.w PQL, but is greater than the MDL. Indicates the analyte is found in the blank associated with the sample. The an. alyte has exceeded allocvable limits, Greater Th an Secondary Dilution Less Than Surrogate out of range .. ( sGs · · Member of thc SOS Group (Soeiete Generaie de Surveillanci) · . APR-10-2003 THU 02:B1 PM · ; Ref.# :Bt ~ame ,jeer Name~/# ;nt Sample I'D . . '1031567001 Unocal-Oil & Gas Division. Bnice 842 ia 5/8 x 13 3/8 Hydrocarbon fi.om Bruce 842 Water (Surface, Eft., Ground) NO, P, ,Ail Dar .es/T!mes are Alaska Standard Time. · Printed Date/Time 03/2812003.14:0.6' Collectcd DatedTime 03/25/2003 10:25 Received Date/Yime 03/25/2003 10:40 Technical Director Stephen C. Ede Released By' ' ~ ~ 07/09 ~plv Remarks: )RO - Thc pattem is consistent with a weathered #1 Diesel and some Ixace araounts ofrcsidual hydrocarbons such as crude oil. Allowable Pr~p Analysis imeter Result~ .-' PQL Uni~ Metl~(I Limit~ Date Da~ Init ~als Department chromium . 206 .. · -~ivol~tile O=gan±c Fuel~ Department Die~el Range'Organics ! '1400 rrOg&~es Sa Androstan¢ <sun'> 111 · · · 0.900 mg/L 8W846 60101~ 03/27/03 03/27~03 300 mg/L AKI02 03126/03 03126103 % AKI02 50-15 0 03/26/03 03126/03 MTG Ds Ds O ' · " '" CT&E EnVironmental Services, Inc. ..' '- ' 'Sample Name: 1031567001'10A :. Date,q'~me: 03126/2003'3:37:42 PM .. 'Ana~st: DS Method: D:~,Public\SA'~M'L~I'HOD~,SAF03'~303C-met .. Dilution: 10 ~',~ ' ".. ".. S~mple File: -D:~ubI[ctSA'~DATA~.O32603\S~F031. 30326_016.DAT .... m ...... DRO~RO ~5 i .. '.'...-' ' .~.;~ · ,~Z~ I-T_ " ' ,. .. - - -~'~' .... i i - i '1 t i r - .'* ~ ....- -..: '.-'..: .... · ... . -0,0.... o,'~ o.z. '. ~3 · · 0.4... ' '0.5 · .0.6 o.z". · 0.$ · 0.9 t.o .1.1 · 1.2 1..3 · .1.4- · I · .-. · ;'. -' ,- i-' .. : ' · ' - '- . " 'M~u~s ' '* - .' .. '.-,.. .." · ' '.- ' .. '-:" ',.:, ' .. Page 3' of 3 . :.. -. .. i ...,:,.. , , ,. :.':' ..... ..' . · . . · . -o . CT&E Environmental'services, Inc. SamPle Name: ~'03~567001'10 A Method: DSPublic(SA~M ETHOD\SAFOG .i 303C~et Samp!e FUe: 'D:~Public'xSA~ATA\032603\SAF03130326_.D16.DAT .... · . F~rcmt F..ID Results" · · Name. " R.T. ' ' .... " Date/Time: 03/26/2003 3:37:42 PM ." Dilution: 10 - Amount IC. An a[.y.~ DS · . . · . . 5 alpha And:osta~e' - · DRO '" " · RKO. mo ~b suaa. .~0 AND SU~' . . . 0.9.34 L]08 . · . : 8554 ..... 2924 · 7816012. · ' 768042 71124566 77O.966 .'}'ag.., 2 of 3 11'0.691 : . 34.601 ii3ss6.$'~s 12191,660 .113710.898 12238.075 Tit [Fwd: Bruce 17587 #3' Disposal Injection Orde,~"-9] PTD #166-052 Subject: [Fwd: Bruce 17587 #3: Disposal Injection Order #19] P1D #166-052 Date: Thu, 08 Jun 2000 13:26:31 -0800 From: Blair Wondzell <blair_wondzell@admin.state.ak. us> Internal Organization: State of Alaska, Dept of Admin, Oil & Gas To: Tom Maunder <tom_maunder@admin.state.ak. us>, "Christopher A. Ruff" <ruffc@unocal.com> Tom, Please look into this and take whatever action is necessary so that an extension of the disposal zone can be given on short notice. Thanks, Blair Chris, Tom is now responsible for all UlC activities (except fnancial) effective 6/5/00. I will provide help when needed and relief when he is not available. All UIC correspondence should be directed to Tom. I know that you will provide him the same consideration and cooperation that you've shown me. Thanks, Blair Subject: Bruce 17587 #3: Disposal Injection Order #19 Date: Tue, 6 Jun 2000 09:37:36 -0700 From: "Ruff, Christopher A" <ruffc@unocal.com> To: "Wondzell, Blair E-Vendor" <Blair_Wondzell@admin.state.ak. us> CC: "Geeslin, James W (Tray)" <geeslinj@Orion. Unocal.com>, "Frankforter, Matthew" <frankm@Orion. Unocal.com>, "Cole, David A" <dcole@Orion. Unocal.com> Blair, Disposal operations on the Bruce Platform are running smoothly ever since we added the C-1 Sand (9015-9185) which was approved on 8/12/999, Administrative Approval DIO 19.01. In order to insure a continuous operation I would like to get approval to expand the defined disposal interval up to 8125' IVD. This way if we run into injectivity problems in the future, advance in order to keep us from having a crew on standby waiting for approval in the future. This will include the next sand above the current disposal interval. MD 'E/D 8720 - 8749 7902 - 7929 8504 - 8522 7706 - 7723 8125 - 8155 7380 - 7396 Formation Undesignated Tyonek Undesignated Tyonek Undesignated Tyonek Information about the new interval... 1) 785' tvd above our current injection interval 2) Cement isolation appears to be adequate for containment of disposal fluids 3) Mechanical integrity of the well has been proven 4) Does not come within a quarter mile of any other wells in the area 5) The additional perforations will not affect the containment of the disposal fluids by the impermeable lithologies in the Upper Tyonek formation. 6~8~00 1:38 PM [Fwd: Bruce 17587 #3' Disposal Injeclion orde,-~'~9] PTD #166-052 '"~'- 6) The additional perforations will not jeopardize correlative rights nor cause waste. Please let me know the best way to proceed with this request. Chris ..... Original Message ..... From: Ruff, Christopher A Sent'. Wednesday, August 11, 1999 8:16 AM To: Wondzell, Blair E Cc: Cronk, Jon A; Tyler, Steve L. -Contract; Williamson, Dan R; Johnson, Dwight E; Myers, Chris S; Cole, David A; Dorman, Allen Subject: Bruce 17587 #3: Disposal Injection Order #19 Blair, Disposal Injection Order No. 19 Rule 1 specifies the top of the disposal interval to be 9240 feet MD which is the top of the Tyonek C-2 interval. Over the past month we have been injecting into the ~ell and fill has covered our perfs up to 9485 feel We would like to add perfs to the C-1 interval which is currently not perforated and is a non-productive zone in the field. The proposed interval is from 9015 to 9185 feet MD. Do I need to file anything other than a 10-4037 Proposed Perforations C1 9015-9185 Current Perforations C2 9240-9310 Top of interval specified in Rule 1 of the injection order is 9240. C2 9380-9400 C3/4 9480-9495 Top of fill currently at 9485 (fill is cuttings slurry which was being injected) C-5 9580-9650 C-7 10045-10095 10120-10130 10150-10200 10215-10270 10290-10310 C-8 10432-10462 10478-10578 Top of fill at 10485 before di~osal began c-9 10628-10715 ,~ ,,~ ,) 6~8/00 1:38 PM Bruce 17587'~3 · Disposal Injection Order # 19 Subject: Bruce 17587 #3: Disposal Injection Order #19 Date: Tue, 6 Jun 2000 09:37:36 -0700 From: "Ruff, Christopher A" <ruffc~unocal.com> -- ~ <~'~ ~ To: "Wondzell, Blair E-Vendor" <Blair_Wondzell~admin. state.ak.us> CC: "Geeslin, James W (Tray)" <geeslinj~Orion. Unocal.com>, "Frankforter, Matthew" <frankm~Orion. Unocal.com>, "Cole, David A" <dcole~Orion. Unocal.com> Blair, Disposal operations on the Bruce Platform are running smoothly ever since we added the C-1 Sand (9015-9185) which was approved on 8/12/999, Administrative Approval DIO 19.01. In order to insure a continuous operation I would like to get approval to expand the defined disposal interval up to 8125' MD. This way if we run into injectivity problems in the future, advance in order to keep us from having a crew on standby waiting for approval in the future. This will include the next sand above the current disposal interval. MD 8720 - 8749 8504 - 8522 8125 - 8155 7902 - 7929 7706 - 7723 7380 -7396 Formation Undesignated Tyonek Undesignated Tyonek Undesignated Tyonek Information about the new interval... 1) 785' tvd above our current injection interval 2) Cement isolation appears to be adequate for containment of disposal fluids 3) Mechanical integrity of the well has been proven 4) Does not come within a quarter mile of any other wells in the area 5) The additional perforations will not affect the containment of the disposal fluids by the impermeable lithologies in the Upper Tyonek formation. 6) The additional perforations will not jeopardize correlative rights nor cause waste. Please let me know the best way to proceed with this request. Chris ..... Original Message ..... From: Ruff, Christopher A Sent: Wednesday, August 11, 1999 8:16 AM To: Wondzell, Blair E Cc:' Cronk, Jon A; Tyler, Steve L. -Contract; Williamson, Dan R; Johnson, Dwight E; Myers, Chris S; Cole, David A; Dorman, Allen Subject: Bruce 17587 #3 : Disposal Injection Order #19 Blair, Disposal Injection Order No. 19 Rule 1 specifies the top of the disposal interval to be 9240 feet MD which is the top of the Tyonek C-2 interval. Over the past month we have been injecting into the well and fill has covered our perfs up to 9485 feet. We would like to add perfs to the C-1 interval which is currently not perforated and is a non-productive zone in the field. The proposed interval is from 9015 to 9185 feet MD. Do I need to file anything other than a 10-4037 6/8/00 1:13 PM Bruce 1758,~/#3 'Disposal Injection Order #19 Proposed Perforations Cl 9015-9185 Current Perforations C2 9240-9310 order is 9240. C2 9380-9400 C3/4 9480-9495 Top of fill currently at 9485 (fill is cuttings slurry which was being injected) > C-5 9580-9650 > C-7 10045-10095 > 10120-10130 > 10150-10200 > 10215-10270 > 10290-10310 > C-8 10432-10462 > 10478-10578 > c-9 10628-10715 Top of interval specified in Rule 1 of the injection Top of fill at 10485 before disposal began 6/8/00 1:13 PM SU BJ ECT BASED ON ENGINEER BP EXPLORATION ENGINEERING DATA BUDGETIAFE NO. SHEET NO.~ DEPT. APP'VL DATE FILE NO. OF__ AK 2337-1 (3/94) TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Administrative Approval DIO 19.01 Re: The application from Unocal Inc. to perforate additional interval in GP State 17587 No. 3 for disposal of Class II fluids. August 12. 1999 C.A. Ruff Unocal North American Oil and Gas Division P.O. Box 196427 Anchorage, Alaska 99519-6247 Dear Mr. Ruff: We have received your application to add perforations above the defined disposal interval pursuant to DIO 19. The interval r~quested represents the "C 1" sand ~qthin the Lower Tvonek Formation between 9015 feet and 9240 feet measured depth in the Granite Point State 17587//3 well. The Commission has revie~ved vour application to expand the defined disposal interval up to 9015 feet measured depth. Initial develol~ment of the well as a producer and then as an injector utilized perforated inten, als up to 9240 feet measured depth. The initial disposal intervals only considered developed sands and did not address non-developed sands. The additional interval does not come within a quarter mile of any other wells in the area. Cement isolation appears to be adequate for containment of disposal fluids and th~ operator has demonstrated mechanical integrity of the well. Additional perforations will not affect the amount of impermeable lithologies in the Upper Tyonek Formation. which serve as barriers to disposal fluid migration. The Alaska Oil and Gas Conservation Commission has reviewed the evidence available and finds that adding perforations to the GP 17587 #3 well will not affect containmem of disposal fluids. The additional perforations will allow flexibility in conducting waste disposal operation, will not jeopardize correlative rights nor cause waste. Therefore. the Commission approves the addition of perforations to the GP 17587 #3 well and expansion of the disposal zone up 9015 feet measured depth. ~Sincer ~ / // ~ Robert N. Christenson. P.E. Chairman 'Commissioner BY ORDER OF THE COMMISSION STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: The APPLICATION OF Union Oil ) Company of Califomia ("Unocal") for ) disposal of Class II oil field wastes by ) underground injection in the Granite ) Point State 17587 #3 well. ) Disposal Injection Order No. 19 Granite Point State 17587 #3 well Granite Point Field July 6, 1999 IT APPEARING THAT: By correspondence dated February 10, 1999, Unocal requested authorization from the Alaska Oil and Gas Conservation Commission ("Commission") to dispose of Class II oil field waste fluids by underground injection into the Granite Point State 17587 #3 well, located on the Bruce Platform in the Granite Point Field. . Unocal submitted additional information supporting the application on February 17, 1999. . The Commission published notice of opportunity for public hearing in the Anchorage Daily News on February 19, 1999. 4. The Commission did not receive any protest or a request for a public hearing. FINDINGS: . Unocal is the operator of the Granite Point Field. There are no other operators within a one-quarter mile radius of the proposed disposal injection well. . The portion of freshwater aquifers beneath Cook Inlet described by a one-quarter mile area beyond and lying directly below the Granite Point Field are exempt aquifers under 40 CFR 147.102(b)(2)(i) and 20 AAC 25.440(c). o Unocal proposes to conduct disposal operations into the Lower Tyonek Formation between 9,240 feet and 10,715 feet measured depth ("MD") in the Granite Point State 17587 #3 well. At this depth, there are no other wells within one-quarter mile radius of the Granite Point State 17587 #3 well. . The Granite Point State 17587 #3 well is perforated between 9,240 feet and 10,715 feet MD in the C-2, C-2X, C-3, C-5, and C-7 sandstone horizons of the Granite Point Middle Kenai Oil Pool. k ) Disposal Injection Ord~o. 19 July 6, 1999 Page 2 o The Granite Point State 17587//3 well was drilled to the northern.portion of the Granite Point Field, an area with relatively low recovery factors due to the generally poor reservoir characteristics of the Lower Tyonek Formation at this location. o The Granite Point State 17587 #3 well has been shut-in since February of 1987 because of uneconomic performance. . The proposed disposal zone in the Granite Point State 17587/t3 well is overlain by more than 5,000 feet of Upper Tyonek Formation. ge The Upper Tyonek Formation is dominated by impermeable lithologies, consisting primarily of interbedded siltstone, mudstone, and coal. Some lenticular sandstones are present, but 'they are volumetrically unimportant. 9, Evaluation of cased hole logs and cement records indicates the Granite Point State 17587/13 well is cemented adequately to isolate the proposed disposal interval. 10. The well is completed with 20 inch conductor set at 589 feet MD, 133/8 inch surface casing set at 2,092 feet MD and cemented to surface, a long string of 95/8 inch production casing set at 8,178 feet MD and cemented back into the surface casing, and a 7 inch liner from 7,925 feet to 10,999 feet MD. 11. The well is equipped with 3 ½ inch tubing string to 7,869 feet MD and 8.6 inch packer set at 7,824 feet MD. 12. The Granite Point State 17587 #3 well was completed initially as an oil producer. It produced from March 1967 until June 1972; cumulative oil production was 1.3 million barrels. It was converted to an injection well in July 1972; cumulative water injection was 4.25 million bah'els through January 1987. The well has not been used since that date. 13. The waste stream will consist of produced water, drilling, completion and workover fluids, rig wash, drilling mud slurries, NORM scale, tank bottoms; and other Class II fluids generated from drilling, production, workover and completion operations. Constituent volumes will vary depending on drilling, workover, stimulation and maintenance activity. 14. Unocal estimates that the maximum daily volume to be injected will not exceed 3,000 barrels per day. 15. Unocal estimates the average injection pressure will be about 2,500 psi, with a maximum daily injection pressure of 3,000 psi, at an injection rate of three barrels per minute. 16. Unocal expects .to maintain injectivity by occasionally stimulating the disposal interval. Stimulation activity will entail pumping solid free fluid to disperse solids, chemically treating the well, and elevating pressure to breakdown the disposal interval. Disposal Injection Orde'~er N° 19 July 6, 1999 Page 3 17. Fracture propagation within the disposal interval is an integral part of the process of placing waste fluids into the disposal interval. Fractures will be created as the disposal zone begins to plug. Fractures (or disaggregation of the clogged pores and rock matrix) provide pathways to transport waste fluids to undamaged storage volume within the disposal zone. 18. Unocal will conduct periodic surveillance of disposal operations through temperature surveys, pressure transient tests, step rate tests, thermal decay time logs, disposal rate and pressure monitoring, mechanical integrity tests and tagging effective depth to determine fill buildup. 19. Reservoir surveillance techniques will also be used for tracking near wellbore fluid movement, estimating dimensions of disposal fracture or disposal storage volume and detecting changes in disposal zone characteristics. 20. Evaluation of operation performance and reservoir surveillance will aid in preventing fracturing of the confining zones. CONCLUSIONS: 1. The requirements of 20 AAC 25.252(c) have been met. . All underground sources of drinking water in the Granite Point field have been exempted for Class II injection activities. o Waste fluids authorized for disposal under this order in the Granite Point State 17587 #3 well will consist exclusively of Class II waste generated from drilling, completion, workover and production operations. . Permeable strata, which reasonably can be expected to contain the total volume of disposal fluids anticipated for this project, are present in the Lower Tyonek Formation. o Waste fluids will be contained within appropriate receiving intervals by confining lithologies in the Upper Tyonek Formation, cement isolation of the wellbore and operating conditions. o Disposal injection of Class II wastes into the Granite Point Middle Kenai Oil Pool in the Granite Point State 17587 #3 well will not cause waste because the well no longer has utility as a production well or as an injection well for enhanced oil recovery. 7, Disposal injection operations in the Granite Point State 17587 #3 well will be conducted at rates and pressures below those required to fracture the confining zones. Disposal Injection Ordei~o. 19 July 6, 1999 Page 4 ge Periodic fracturing and stimulation will be required to place solids' into the disposal interval. Fracture growth can be contained within the disposal interval by controlling the rate and volume of injection. , Surveillance of disposal material movement, monitoring of operating parameters and demonstration of mechanical integrity every four years will ensure the waste fluids are contained within the disposal interval. Changes in baseline data may be an indication that fluid is escaping beyond the designated confining zone. 10. The mechanical integrity of the tubing, packer and production casing in the Granite Point State 17587 #3 well must be demonstrated in accordance with 20 AAC 25.412 prior to commencing injection operations. 11. Disposal injection operations in the Granite Point State 17587 #3 well will not cause waste, jeopardize correlative rights, or impair ultimate recovery. NOW, THEREFORE, IT IS ORDERED THAT: Rule 1 Authorized Injection Strata for Disposal. Class II oil field fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for disposal into the Lower Tyonek Formation from 9,240 feet to 10,715 feet MD in the Granite Point State 17587 #3 well. Rule 2 Authorized Fluids This authorization is limited only to Class II fluids. The Commission must be notified immediately if any non-Cl..ass II fluids are injected into the well. Rule 3 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission that ensures the tubing-casing annulus is pressure tested prior to initiating disposal and at least once every four years thereafter. The casing must be tested at a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the true vertical depth of the packer, whichever is greater, but may not be subjected to a hoop stress greater than 70% of the minimum yield strength of the casing. The test pressure must show stabilizing pressure and may not decline more than 10% within thirty minutes. The Commission must be notified at least twenty-four (24) hours in advance to enable a representative to witness pressure tests. Rule 4 Well Integrity Failure Whenever disposal rates and/or operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action and obtain Commission approval to continue injection. Disposal Injection Order~No. 19 July 6, 1999 Page 5 Rule 5 Surveillance Operating parameters including disposal rate, disposal pressure, annulus pressures and volume of fluids and solids pumped must be monitored and reported according to requirements of 20 AAC 25.432. An annual report evaluating the performance of the disposal operation must be submitted by July 1 of each year. Rule 6 Administrative Action Upon request, the Commission may administratively revise and reissue this order or any of its .rules upon proper showing that the change is based on sound engineering practices, will not allow waste fluids to escape from the disposal zone, and will not cause waste. DONE at Anchorage, Alaska and dated July 6, 1999. Camille Oechsh, Commissioner AS 31.05.080 provides that within. 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for reheating. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon reheating, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for reheating is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day at,er the application for rehearing was filed). :, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pulltubing: Alter casing: Repair well: Other: X Injection Test 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of Califomia (UNOCAL) Development: 115' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: X Granite Point Field 4. Location of well at surface 8. Well number 2,050" FSL. 2,019" FWL, Sec. 31, TllN, R11W, SM Granite Pt. St. 17587 No. 3 At top of productive interval 9. Permit number/approval number 66-52 At effective depth 10. APl number 50- 733-20437-00 At total depth 11. Field/Pool Granite Point Field, N/A 12. Present well condition summary Total depth: measured 11,015' feet Plugs (measured) true vertical 10,080' feet Effective depth: measured 10,969' feet Junk (measured) true vertical 10,034' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 589' 20" 185 sx 589' 589' Surface 2,092' 13-3/8" 1,200 sx 2,092' 2,004' Intermediate Production 8,178' 9-5/8" 1,000 sx 8,178' 7,415' Liner 10,999' 7" 800 sx 8,014' - 10,999' ' 7,273'-10,064' Scab Liner Perf°ration depth:Abandoned: truemeasured:vertical See AttachedOR IN. L Abandoned: Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 to 7,870' MD EIVED Packers and SSSV (type and measured depth) Baker Mod. D @ 7,810' MD ELM 13. Stimulation or cement squeeze summary UU~ N/A Intervals treated (measured) , :.:..-;..~ u;t ~, u~a doa$, 6omBj_s_$ion N/A^nch0rag0 Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 0 0 0 0 0 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: Suspended: Service: X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed:~'~~ ~~, Dan Williamson Title: Drilling Manager Date: Form 10-40zl Rev 06/15/88 SUBMIT IN DUPLICATE Operations Summary Granite Point St. 17587, Bruce Well 3 DAY 1 (4/12/99) MOB TO PLATFORM. OFFLOAD, SPOT RIG UP DOWELL CEMENT PUMP. DAY 2 (4/13/99) PERFORM INJECTIVITY TEST WITH 266 BBLS 3% KCL WATER. MAX PUMP RATE 5.5 BPM @ 3,643 PSI. FINAL PUMP RATE AT 4.9 BPM @ 3,890 PSI. SHUT DOWN FOR NIGHT. DAY 3 (4/14/99) RU GRINDING UNIT. DAY 4 (4/15/99) PROCESS OIL BASED MUD CUTTINGS TO BUILD INJECTION TEST SLURRY. DAY 5 (4/16/99) CONT. PROCESS AND BUILD SLURRY. DAY 6 (4/17/99) PERFORM INJECTION NO. 2. INJECT 60 BBLS SLURRY (10 PPG, 45 ViS. 10% SOLIDS) 4 BPM @ 4,000 PSI. CHASE WITH 200 BBLS 3% KCL WATER MAX RATE OF 4.3 BPM @ 4,000 PSI. CONTINUE BUILDING INJECTION SLURRY FOR INJECTION NO. 3. DAY 7 (4/18/99) CONTINUE BUILDING INJECTION SLURRY. COMMENCE INJECTION TEST NO. 3. WITH 204 BBLS. (+10.2 PPG, 40 VIS. 19% SOLIDS). MAX PUMP RATE DURING MUD INJECTION 4 BPM @ 2,900 PSI. STABILIZED RATE OF 3 BPM @ MAX. 2,981 PSI. PUMP 257 BBLS 3% KCL FLUSH. MAX. PRESSURE OF 4,020 AT 3.5 BPM. FINAL PRESSURE DURING FLUSH 3,880 PSI @ 3.5 BPM. DAY 8 (4/19/99) RIG DOWN EQUIPMENT DE-MOB TO BEACH. 'UNOCAL RKB to TBG Head -- 42.80' Tree connection: ?? 10 C2 C2 C-3,4 C-5 C-7 C-8 PBTD = 10,989' TD = 11,015' HOLE ANGLE thru Interval = o B-3 Draw II.doc Bruce Well No. 3 GP 17587 Completed 5/30/84 SIZE WT CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 20 13-3/8" 9-5/8" ,, Tubing: 3-1/2" Surf 589' 54.5 J-55 8 rd, ST&C 12.515 Surf 2,092' 43.5 S-95 ERW ST&C 8.755 Surf 52' 40 N-80 Buttress 8.835 52' 4,676' 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 32 N-80 Butt. 6.094 7,903' 8,014' 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6.094 8,760' 10,999' 9.2 N-80 ABC 2.992 42.8' 7,870' NO. JEWELRY DETAIL Depth OD ID 1 42.80' 2 43.80' 3 44.30' 4 48.30' 5 58.30' 6 7,824' 7 7,825' 8 7,839' 9 7,870' 4.875 4.734 - ? 2.992 2.992 2.992 3.000 3.000 2.992 . - Item CIW Tubing Hanger, BPVP ? Crossover, 3-1/2" EUE 8rd Pin x 3-1/2" Buttress Pi Pup, 3-1/2", ABC Pup, 3-1/2", ABC Pup, 3-1/2", ABC Locator, Baker 190-47 Seal Assembly, Baker, 190-47 1 joint, 3-1/2", 9.2#, N-80, ABC Mule Shoe 10 7,810' - Packer, Permanent, Baker Mod. D (DPM) Fill Tagged w/ GR 2.80 Gagae Ring Run 10,478' SLM 2/18/99 7,929' SLM Excessive PU W eights Zone Top PERFORATION DATA Accum Last Btm Amt SPF Perf Date Present Condition C-2 9,240' C-2 9,380' C-3/4 9,480' C-5 9,580' C-7 10,045' 10,120' 10,150' 10,215' 10,290' C-8 10,432' 10,478' C-9 10,628' 9,310' 70 4 & 8 6/30/72 9,400' 20 4 & 8 6/30/72 9,495' 15 4 6/30/72 9,650' 70 4 & 8 6/30/72 10,095' 50 4 & 8 6/30/72 10,130' 10 4 6/30/72 10,200' 50 4 & 8 6/30/72 10,270' 55 4 & 8 6/30/72 10,310' 20 4 & 8 6/30/72 10,462' 30 4 & 8 6/30/72 10,578' 100 4 & 8 6/30/72 10,715' 87 4 & 8 6/30/72 DATE: 2/5/99 TCB STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operatioll shutdown: Re-enter suspended well: Aller casing: Repair Well: Plugging: '13me extension: Stimulate-=~= Change approved pro~ram: Pull I~'-"~lng: Varia%e: Perforate: Olfler: "~onvert to Disposal 2.'Name of Operator ............ 5. Type of well: 8. Datum elevation'['DF or ~J~i " Union Oil Company of California (UNOO_A...~) ........... Development; --.-- 115' RKB above MSL feet 3. Address Exploratory; '~'. Ur~it a Property name $tratlgraphi~: P,O. I~x 196247 Anchorage, AK 99519 Sewice'. ~ Granite Point Field 4. L~)~alJon o~ well at sur~ ....... Bru~e Platform, Leg # 1, Slot # 8. ' .......... 8. Well number 2,050" FSL. 2,019" FWL, See. 31, TI1N, RllW, SM Granite Pt, St, 17687 No. At top of productive interva~ 9, Permit number 66-52 At effective depth 10'. APl number ....... 50- 733-2O437-OO At to~ depth i t. Fald/Pool ..... ............... Gr~..!~ Point Fletd, N/A 12. Present well condition summary Total depth: measured 11,015' feet Plug~ (mea~uced) true verU~l I0,080' feet Effective depth: measured 10,969' feet Junk (measured) ~ue vaticai 10,034' feet Casing Length Size Cemented Measured depth True verUcal depth Structural Conductor 589' 20' 185 sx 589' 589' Surface 2,092' 13-3/8' 1,200 sx 2,092' 2,004' Intermediat~ Production 8,178' 9-6/8" 1 ,OeO sx 8,178' 7,41 Liner 10,999' 7" 800 sx 8.014' - 10,999' 7,273'. 10,064' Perforation depth: measured See Attached .ORIGINAL. Tubing (size, grade, and measured deplh) 3-1/2', 9.3#, N-80 to 7,870' MD Packers and SSSV (type and measured cleplh) Baker Mod. D ~ 7,810' MD ELM i3: Atta~ements D%oription '~ummanj of proPosal: ................. De'~ied op~-afi-ons program: BOP sketch: .......... ~,;~;~,~ ........ 14. Estimated date for commen~t on' 15. Status of well classification a~; ,,, , 16, tf'~-oposa~ Well verbally app~<~;- - Oil: Gas: Suspended: APR 1 3 1999 Na'ne of approver ,~'[h~'/*~_ 9 Date approved ....... .S,~,rv...~: Injector (Conversion to Disposal,) __ 17. I here~rtlfy l~at the~to~e~l~hg le ~rae all(j correct to the beet of my knowledge. ,~. ,,. '-- St~,,. ed~)~J~/~~. . lliamson T~e: Drilling Uana~e, FOR COMMISSION USE ONLY ~C°nd~s °f appr°vai: iq°§fY c°rn~/ssi°n s° 'ePmsentetive may witnesSpiug ,ntegri~__BOP ,, ................. MechanicaJ Integrity Test ~ Subsequent form required 10-/~O~'l~.,, t3~'''''''tP~d~.,¢d~O ~z~OO~3~ - - ORIGINAL A~3pr.¥_ed by order of th.e.c~mmis?ioner Ro~i't N. Christenson ..---~'"-Commlssloner~ / Form 10-403 Rev 06/1~/88 SUBMIT IN TRIPLICATE !AIdL~:'1~ 666L '~L'JdV Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7660 UNOCAL April 13, 1999 Alaska Oil and Gas Conservation Commission 300t Porcupine Drive Anchorage, AK 99501 Attn: Blair Wondzell Subject: Bruce Platform, Well No. 3-17587 APl No. 50-733-20437-00 Attachment to 10-403 Dear Blair, The intent is to inject water into the existing perforations in order to develop an Injection profile. After analyzing pressures and rates obtained from that injection test, if deemed acceptable, weighted slurry will be built to 10.5ppg and injected followed by a 200 bbl water flush. Then a second weighted injection volume of 200 bbls. will be built and injected. The purpose of this test is to ensure that the well is capable of service es a disposal well and to allow for the sizing of a surface pump for injection, If you have any questions or comments please call Tim Brandenburg at 263-7657, Unocal Alaska Business Unit Bruce Platform We!lNo. 3 - 17587 UNOCAL(S) III I III !No. Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) · I MIRU 12.0 12 0.5 ..... 2 p~essutetestt° 8,000psi' '[~_o~e.. ,k ;cr,.. t,'~ ..... 4:6 ...... l~i'0.? 3 Fi'il"rUbi~g w~th water. 0.5 17 O.7 '" 4 iPump 200 bbls water, perform step, rate test to 5,500psi. Analize data. 4.0 21 ...... 0.9 5 RU Inlet G~dhg Package 48.0 69 2.9 ' "6' 'Build 60 bbls w.e..ighted fluict (10.$ppg) Drill Cuttings as weighting agent. 24.0 93 .... 3.9 ._7Inject 60 b~ls at 5,400 psi or 3 bbls/min. . ..... 6 99 4.1 8 Pump 200 bbl water flush at 5,500 psi. or 3 bbls/min. 3 102 4.2 9 Build 200 bbls wighted fluid (lO.Sppg) Drill Cuttings as weighting agont. 24.0 126 5.2 10 Inject 200 bbls at 5,400ps.!:. ' ....... 6 132 5.5 11 Pump 200 bbI water flush at 5,500. psi. or 3 bbls/min. 3 135 5.6 12i Clean Equipment 24.0 159 6.6 13j fig Down, baek.!oad_ ... ' ....... 18 177 .. 7.4 .. Bruce 3 IT AFE Est II.xls Page 1 of 1 4/13/99 ~./~, '~ ~.~,q'ON 'd~JO::) 7V:)ONI1 ~V88'8 666L '~L'~dV Unocal Corporation P.O. Box196247 Anchomge, Alaska 99519 907-263-7660 UNOCAL ) April 12, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn; Blair Wondzell Subject: Bruce Platform, Well No. 3-17587 APl No. 50-733-20437-00 Dear Blair, Enclosed is a form 10-403 for the re-classification of Bruce No. 3 -17587 from an injection well to a disposal well. This is being submitted prior to an injection test to be performed on the well in advance of the approval of the area injection order currently before the Commission. If you have any questions or comments please call Tim Brandenburg at 263-7657, Sincerely, APR 1 1999 Anchorage q/z ' a nP, P,q'oN ' d~O0 ]VOONfl HdLE;:I~ 666L ' ~3 [' J dV Bruce 3-17587 Perforations Zone Top MD Btm MD Top TVD Btm TVD C-2 9,240' 9,310' 8,376' 8,439' C-2 9,380' 9,400' 8,503' 8,520' C-3/4 9,480' 9,495' 8,591' 8,605' C-5 9,580' 9,650' 8,682' 8,746' C-7 10,045' 10,095' 9,122.' 9,171' 10,120' 10,130' 9,197' 9,206' I 0,150' 10,200' 9,224' 9,274' 10,2.15' 10,270' 9,289' 9,353' 10,290' ' 10,310' 9,363' 9,382' C-8 10,432' 10,462' 9,503' 9,532' 10,478' 10,578' 9,548' 9,647' C-9 10,628' 10,715' 9,696' 9,783' Amt 7O 20 15 7O 5O 10 5O 55 2O 3O 100 87 Accum SPF 4&8 4 4&8 4&8 4 4&8 4&8 4&8 4&8 4&8 4&8 'd~JO3 ]VOONn !999 ~dL$'l~ 666l '~L'JNV ) - ( UNOCAL ) RKB to TBG Head; 42,80' Tree connection: ?? ~0 C2 C-3,4 C-5 C-7 (2:-8 'C-9 PELTO = t0,989' TD = 11,015' HOLE AN(~LE thru Interval -- o B-3 ])mw II. doc Well No. 3 GP 17587 Completed 5/30/84 I , II SIZE WT CASING AND TUBING DETAIL GRADE CONN ID TO~P BTM. 20 13-3/8" 9-5/8" Surf 589' 54.5 $~55 8 rd, ST&C 12.515 Surf 2,092' 43.5 S-95 ERW ST&C 8.755 Surf 52' 40 N-80 Buttress 8.835 52' 4,676' 40 S-95 ERW ST&C 8.835 4,676' 6,696' 43.5 S-95 ERW ST&C 8.755 6,696' 8,178' 32 N-80 Butt. 6.094 7,903' 8,014' 29 S-95 ST&C 6.184 8,014' 8,760' 32 N-80 Butt. 6,094 8,760' 10,999' Tubing: 3-1/2" 9.2 N-80 ABC 2.992 42.8' 7,870' NO. Depth OD JEWELRY DETAIL ID Item I 42.80' 2 43.80' 3 44.30' - 4 48.30' - 5 58.30' - 6. 7,824' 4.875 7 7,825' 4.734 8 7,839' - 9 7,870' - ? 2,992 2.992 2.992 3.000 3.000 2.992 CIW Tubing Hanger, BPVP ? Crossover, 3-1/2" EUE 8rd Pin x 3-1/2" Buttress Pul?, 3-1/2", ABC Pup, 3-1/2", ABC Pup, 3-1/2", ABC Locater, Baker 190-47 Seal Assembly, Baker, 190-47 I joint, 3-1/2", 9.2#, N-80, ABC Mule Shoe 10 7,810' - - Packer, Permanent, Baker Mod. D (DPM) Fill Tagged w/ GR 2.80 Gagae Ring Run Zone Top 10,478' SLM 2/18199 7,929' SLM Excessive PU W eights PERFORATION DATA Accum Last Btm Amt SPF Pert Date Pressnt Condition C-2 9,240' 0,3t 0' C-2 9,380' 9~400' 0-3/4 9,480' 9,495' C-5 9,580' 9,650' C-7 10,045' 10,095' 10,120' 10,130' 10,150' 10,200' 10,215' 10,270' 10,290' 10,310' C-8 10,432' 10,462' 1'0,478' 10,578' C-9 10,628' 10,715' 70 4 & 8 6130/72 20 4 & 8 6/30/72 15 4 6130/72 70 4 & 8 6/30/'1'2 50 4 & O 0/30/72 10 4 6/30/72 50 4 & 8 6130172 55 4'& 8 6/30172 20 4 & 8 6/30~72 30 4 & 8 6/30/72 100 4 & 8 6/30172 i~ '~ ::! ~ .... i"';~ 1 ;5 1999 TCB · ~ '~,,z, ~) '-~,'2'~ ' ~tNC),q -IV,~(~Nn[ici/~, :il aaa t ' Z l' ] dy ALASKA OIL AND GAS CONSERVATION COMMISSION P ~- PI~ODOC~ $ '- SALT WATI~ ~ bi = ~LIt ~ON GLYCOL 8ALT WAYIm Mawr ,31, 1999 9'02AM UNOCAL CORP, No,blb4 .) Unocal Corporation P.O, ~o× Anchorage, Alaska 99519 90?-263-7660 UNOCAL March 29, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Blair Wondzell Subject: Bruce Platform, Well No. 3-17587 APl No.~9 ~w~ ~nn~ nn Dear Blair, Unocal seeks approval to perform an injectivity test on Bruce Well No. 3-17587. While it is acknowledged that the Commissions has not yet approved the permit to convert.the well to full time service as a disposal well, Unocal needs to c~nduct this work in order to properly size surface equipment (i.e. injection pump) and to place that equipment on order, Attached is a brief outline of the plan for the injection test, comments please call Tim Brandenburg at 263-7657. If you have any questions or ~/7 'A nTl¢'ON 'HNOD ]VOONn ~d60'g Unocal Alaska Business Unit Bruce Platform Well No. 3-17587 UNOCAL(S) No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) I MIRU 12.0 12 0.5 .... 2 Pressure test. 1.0 13 0.5 3 Fill Tubing with water. 0.5 14 0.6 ..... 4_~Pmp 200 bbls water. 0.5 14 0.6 ...... 5 Pump 200 bbls base fluid (9 ppg). 2.0 16 0.7 6~Pump 150 bbls water flush. 1.5 18 0.7 ,, , 7 ~imp 50 bbls mixed with 15% solids (10.5 ppg). 1 19 0.8 ...... 8 Pum.p 150 bbls water flush. 1.5 20 0.8 9 Rig Down, back load. 12 32 1.3 lilllil Il [ Bruce 3 IT AFE Est. xls Page I of 1 ~/e ,~ nTle,O[l ,4 nn ]vnnNn Anchorage 3~29~99 Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL ) Alaska December 19, 1995 Mr. Blair Wondzell State of Alaska Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 MIT of Bruce Platform's Shut-in Water Injection Wells Dear Mr. Wondzell, Attached please find the results of the Mechanical Integrity Tests for the shut-in waterflood wells on Unocal's Cook Inlet Platform Bruce. The waterflood on Bruce Platform is out of service at this time with all waterflood injection wells shut-in. As we discussed on the phone Dec. 14th, only shut-in tubing, production casing, and intermediate casing pressures would be reported for shut-in wells providing the reservoir energy was too low to contaminate upper, fresh water zones. Well Date Tbg Press Prod Csg Press Int Csg Press psig psig t(tofq~ psi8 ,, Bruce 3-17587 12/14/95 0 125 /oo 0 Bruce 5-17586 12/14/95 300 850 c9 20 Bruce 6-18742 12/14/95 0 1550 .co 0 Bruce 10-18742 - 12/14/95 0 110 ~o 10 Bruce 12-18742 12/14/95 770 775 q:~ 0 Bruce 14-18742 12/14/95 750 1400 ~o 0 ~_~._,~__ Bruce 31-18742 - 12/14/95 700 20 600 O 5 Please note that well 10-18742 was ~luggedin 9/88 and well 31-18742 was plugg~ in 10/88. Thank you, Marie L. McConnell Production Engineer cc: Clay Chivers Platform Bruce Well Files Enclosure RECEiV' -L) DEC 2 1 1995 Alaslm ~,. ~., ,~..~ ,,OHS. ~nmission ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192. PHONE: (907) 279-1433 TELECOPY: (907) 276-7543 November 3, 1992 Janet Bounds Unocal P O Box 190247 Anchorage, AK 99519-0247 Dear Ms Bounds: As we discussed on the phone October 28, AOGCC will be reassigning APl numbers for the wells listed below. In order to accommodate the revision of Unocal's records, we will not announce these changes to the public until the first week of December, or until you advise me that all the necessary changes are made. Give me a call if you would like to discuss this matter further. Well Name Permit # Old APl Number New APl Number Granite Pt St 17587 #3 66-52 ' 50-883-10031 50-733-20437 Granite Pt St 17587 ~ 89-30 50-883-10032 50-733-20438-90 Granite Pt St 17587 f/~ 89-103 50-883-10034 50-733-20439 Granite Pt St 18742 ft8 67-36 50-883-20008 50-733-20440 Granite Pt St 17586 ~4 67-54 50-883-20009 50-733-20441 Granite Pt St 18742 #34 79-17 50-883-20009-01 50-733-20441-01 Granite Pt St 17586 ~f41 91-45 50-883-20009-02 50-733-20441-02 Granite Pt St 18742 #14 79-33 50-883-20010 50-733-20442 Granite Pt St 18742 #20 68-16 50-883-20012 50-733-20443 Granite Pt St 18742 #20RD 91-20 50-883-20012-01 50-733-20443-01 Granite Pt St 17587 #5 68-24 50-883-20013 50-733-20444 Pretty Creek Unit #2 79-9 50-283-20022 50-283-20022-90 Nicolai Creek Unit #4 91-100 50-283-20033 50-283-20033-90 Lewis River D-1 89-72 50-283-20068 50-283-20068-90 Trading Bay Unit G-18DPN 83-135 50-733-20160 50-733-20160-90 Yours truly, Robed P Crandall Sr Petr Geologist /jo Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 W. G. Smith District Manager June 11, 1984 File. TJZ-O37-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Subsequent Noti ce Granite Point 17587 Well No. 3 Platform Bruce, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, subsequent to repairing a communication leak in Granite Point 17587 Well No. 3. The tubing string was pulled and one joint of tubing was found that was split..The packer was milled out and retrieved and fill was cleaned out to 10,533 feet, at which point collapsed casing was encountered. A new packer was run, the split joint of tubing was replaced, and the tubing string was rerun. The well was returned to injection and is currently injecting approximately 1,300 BWPD at 5,000 psi. Please direct any questions concerning the project to Mike Schwein in our Anchorage office. Very truly yours, W. G. Smith Di strict Manager Attachment MTS/dds RECEIVED J U N ! 219t]4 Alaska 0il & Gas Cons. Oommis$ioD Anchorage STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION (~OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHERWiSe.' 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator Amoco Production Company 3. Address P. O. Box 100779, Anchorage, Alaska 99510 4. Location of Well Leg 1, Slot 8, Granite Point Platform Bruce 2,050' FSL, 2,019' FWL, Sec. 31, T11N, R11W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 107' KB, MSL 12. I 6 . Lease Designation and Serial No. ADL 17587 7. Permit No. 66-52 8. APl Number 50- 883-10031 9. Unit or Lease Name Granite Point 17587 10. Well Number 3 11. Field and Pool Granite Point Field Middle Kenai Sands Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made ~ Other [] Pull Tubing [] Other [] Pulling Tubing J~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). le 3. 4. 5. 6. 7. Circulated and killed well. Set back-pressure valve, nippled down tree, nippled up BOP's and tested to 2,500 psi. Pulled back-pressure valve. Pulled tubing and seal assembly. Milled out and retrieved the packer set at 7,848 feet and cleaned out fill to 10,533 feet. Ran new packer, seal assembly, and tubing. Packer set at 7,810 feet and muleshoe set at 7,871 feet. Set back-pressure 'valve, nippled down BOP's, nippled up tree and tested to 5,600 psi. Pulled back-pressure valve. Returned the well to injection. RE(~IVED JUN 1 21984 Alaska Oil & Gas Cons. CommJ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use ~-~"~"-~ Title District Manager Date06/11/84 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date ssion Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager May 1, 1984 Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-27 2-8471 File' WGS-126-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent Granite Point 17587 Well No. 3 Pla~tform Bruce, Cook Inlet, Alaska , Attached in triplicate for your ap.proval is a State of Alaska Form 10-403 Sundry Notices and Reports on Wells, to notify you of our intent to repair a communication leak in Granite Point 17587 Well No. 3. The well is currently shut-in due to tubing/annulus communication. We plan to begin this work as soon as possible. Any questions concerning this project may be directed to Mike Schwein in our Anchorage office. Very truly yours, W. G. Smith District Manager Attachment MT S / dmh RECEIVED MAY 0 !gt]4 Alaska Oil & C-,~; Cons, Commission Anchorage ---, STATE OF ALASKA --', ALASK/-, _~IL AND GAS CONSERVATION C..MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED W'ELL · · 2. Name of Operator Amoco Production Company 3. Address P. 0. Box 100779, Anchorage, Alaska 99510 4. Location of Well Leg 1, Slot 8, Granite Point Platform Bruce OTHER [] 7. Permit No. 66-52 8. APl Number 50- 883-1003] "9. Unit or Lease Name 6'rap!te Po~_nt 17587 2,050' FSL, 2,019' FWL, Sec. 31, T11N, R11W, S.M. 10. Well Number 3 11. Field and Pool Granite Point Field 5. Elevation in feet (indicate KB, DF, etc.) ~nT, KB M<::L I 6. Lease Designation and Serial No. Mi ddl e Kenai Sands A~! 1 Check Appropriate Box l~'l~di~t~l~ature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well · Change Plans [] Repairs Made Pull Tubing ~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment I-1 I-I Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1. Rig up wireline and test lubricator to -2,500 psi. Perforate tubing at 7,810 feet. 2. Circulate and kill well. 3. Set back-pressure valves,, nipple down tree, nipple up BOP's and test to 2,500 . psi. Pull back-pressure valves. 4. Pull tubing and .seal assembly. 5. Mill out and retrieve the packer set at 7~848 feet and clean out fill. 6. Run new packer, seal assembly, and tubing. 7. Set back-pressure valves, nipple down BOP's, nipple up.tree and test.to 5,600 psi. Pull back-pressure valves. 8. Return the well to injection. 14. I hereby certify that the foregoJ~g is true and~4:orrect to the best of my knowledge. ~- RECEIVED MAY 0 3 1984 Alaska Oil & Gas Cons. Commission The space below for Commission use Title Bistrict Manager Da,e 5/0!/84 Conditions of Approval, if any: Approved by BY LiJtiHI[ t. $1ITI COMMISSIONER Approved Copy By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions~' H3 Trtphcate and "Subsequent Reports" in Dupl,cate SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 July 31, 1980 Amoco Production C~k3ny P.O. Box 7'79 Anchorage, Alaska 99510 AttentiOn: Randi Rosenburg. Gentlemen: Enclosed are 2_BIprintsof the Amoco Production Oompany Company Field. Granite :Point Engineered Production Log Well County PLEASE REPLY T ...... ,o: ~..~.~ 500 c ra e, .as. j ~ STAT TEC__ Grainte Point 17587 Well #3 (6/17/8%~: Kenai State. Alaska ' Additional prints are being sent to: 2 BL nrints Am:~r Production ~y 1010 Security Life Building Denver, Colorado 80202 Attention:--Division Production Mgr 1 BL nrints Getty bil Company Three Park Central,Suite 700 Arapahoe Street Denver, Colorado 80202 Attention: Walter J. Newman 1 BL nrints Atlantic Richfield Company P.O. Box 360 Anchorage, Alaska 99510 Attention: -T. Wellman 1 BL prints Alaska Oil & Gas Conservation Cc~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Hovle Hamilton 1 BLnrints Chevix)n U.S.A., Inc. P.O. Box 7-839 Anchorage,-Alaska 99502 Attention: C.F. Kirkvold __prints 1 BLDrints Phillips Petroleum Company 7800 Dorado place Englewood, Colorado 80111 Attention: J.P. Denny prints Returned to The film is .... (Anchorage We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER OFFSHORE SERVICES DISTRICT MANAGER $O5--! $65-A RETXlN THIS SECTION FOR YOUR RECORDS G.P.S. 18742 //12 R.D. G.P.S. 18742 //14 G.P.S. 18742 //31 G.P.S. 18742 //6 RE --.-~-~:..~-~~-- ................. ..... -~ P..~ $....1. $7.~.~....#.~.o ............ ~ . G.P.S. 17586 //5.R.D. PRINTS .............. N ~ J ............. SEPIA ............. ~ ~'~' ~'~'~'1~'"'~"~' ~)'~ ~)'~' iiii~.'~iiii PRINTS .............. NE® ...... t~.. .... SEPIA iiiiiiiiiiiiiiiiii i iiil iiiiiiiill............ PRINTS NEC= ............... SEPIA ............................................................ PRINTS ..............NE® ............... SEPIA ABOVE RECEIVED FROM: j.~f~. [-'.C-.[i..I--V ~ b DRESSER ATLAS :'i', 'i 8 1.q~O '- 25K8 ~l. e. , ', ..... " SIGN .. .................. ~t,.p, ~ n,.-.~r [.~n. J 9-,;, ........ ~1 Co~~ --i'-co~-~F,, ._ I - . CONFER: - L. A. Darsow District Superintendent June 6, 1980 Fi le' LAD-572-WF Mr. Hoyle H. Hamilton, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 Sundry Noti ce Granite Point 18742 Well No. 3' · 'Platform' Anna, 'CoOk'Inlet, 'Alaska Enclosed in triplicate is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, indicating our intention for reperforati.ng Granite Point 18742 Well No. 3. AnalYsis of a February 1979 pressure build-up test of Granite Point 18742 Well No. 3 indicates a pressure loss of 589 psi due to skin. Additionally, oil production has declined from 698 BOPD in June 1976 to 318 BOPD in February 1980. Yours very truly, L. A. Darsow District Superintendent RECEIVED Attachments ~ka 0il & G:~s , .......... ~msion Anchurage MPW/kl t Form ! 0-403 REV. 1-10~73 Subml t "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. Ow~LLL[~]WELLGAS D OTHER 2. NAME OF OPERATOR Amoco Production Company/ 3. ADDRESS OF OPERATOR ' P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface Leg. 1, Slot 6, a.P. Platform Anna 729' FNL, 636' FEL, Sec. 12, TION, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 105' KB MSL 14. Check Appropriate Box To Indicate Nature of Notice, Rel 5. APl NUMERICAL CODE 50-733-10065 6. LEASE DESIGNATION AND SERIAL NO. ADL 18742 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Granite Point 18742 9. WELL NO. 3 10. FIELD AND POOL, OR WILDCAT Granite Point Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) TD 871' FNL, 1658' FEL, Sec. 12, TION, R12W, S.M. 12. PERMIT NO. 3ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF.' WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) ~ (NOTE, Report results of mul~ le completion on Well Completion or Recompletion. )port and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Reperforate the Middle Kenai Sands C-4, C-5 and C-7 zones to remove damage and recover lost producing rates. Depths to be perforated are' C-4:8150-8220' C-5: 8250-8290' 8315-8330' 8355-8380' 8390- 8420' 8430-8460' C-7: 8700-8735' 8820-8835' 8840- 8850' 8895-8920' 8960-8970' 16. I hereby certify that the foregoing is true and correct Di stri ct Superintendent TITLE , TITLE ~OMMISSIONEI~ BY .ORDER ~ '.THE COMMISSION See Instructions On Reverse Side DATE DATE June 6, 1980 Appt~ed ~o;0~ Returned Form 10-403 REV. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL L-.J OTHER Water Injection Z NAME OF OPERATOR .Amoco Production Company 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL 10. Atsurface Leg 1, Slot 8, Granite Point Platform Bruce, 2050' FSL, 2019' FWL, Section 31, 11. TllN, RllW, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 107.3' RDB 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-283-10031 6. LEASE DESIGNATION AND SERIAL NO. ADL 17587 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Granite Point State 17587 9. WELL NO. 3 FIELD AND POOL, OR WILDCAT Granite Point SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 30, TllN, RllW, S.M. 12. PERMIT NO. 66-52 =ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. This is to advise that. operator is cancelling its plans to acidize the subject well with 2500 gallons of 12-3 mud acid as proposed by our Notice of Intent dated December 22, 1976. RECEIVED JAN 1 4 1977 4Dlvlsi0n of 011 and Gas ConsePation Anohorage 16. I hereby certify that the foreg~oing is true and correct TITLE Area Superintendent DATE. January 13, 1977 (This space for State office use) APPROVED BY . CONDITIONS OF APPROVAL, IF ANY.' TITLE DATE See Instructions On Reverse Side January 13, 1977 File: LAD-047-WF Amoco Production Compan' P. O. Box 779 Anchorage, Alaska 995 Mr.~Hoyle Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Acid Treatment Granite Point 17587 Well No. 3 This is to advise that we haVe cancelled plans to acidize the subject well as previously proposed by our Notice of Intent dated December 22, 1976, File: GJR-958-WF. Yours very truly, L. A. Darsow Area Superintendent Attachment RECEIVED JAN t o~ Oil and Anchora~ G. J. Ross Area Superintendent December 22, 1976 File: GJR-958-WF Mr. Hoyle Ha~ilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 ll:,i' -,.. /., ~ t ..... i I t :-,:(""' .... t ' I Dear Sir: Re: Acid Treatment Granite Point 17587 Well No. 3 Attached for your review and approval is our Form 10-403 to acidize the subject well. Yours' very truly, George o. ~oss Area Superintendent Attachment DiVISiON OF OIL AND GAS ANC:NO~A~ F~rm 10-403 REV. 1-10-73 s" in -~rlplicate ~,ubrnlt "1 ntel~.ti~°n~.~,rtS,, in Duplicate ~. ,,Sut~sequen[ r,~.~ 50-283-10031 ..... ~R~AL NO. ?. IF INDIAN, ALL.u---- 1. WELL~--~ AmocO Production Company ---------------- ~ AT O R '' -'-a 99510~ .~ 3~EUO AND WOOL' OR W~OC~ 4. Atsurface Leg l, Slo_t~, ..~eL 2019' FWL, ~'-' / -,-, TllN, RL1W, S.M. __. ' Bruce, 205u to , I Sec. ju, -,- Data SUBsEQuENT REpoRT OF: 14 TICE OF iNTENTION TO WATER sHUT-OFF ~ ' REPAIRING WELL · : ALTERING CASING NO ~ r~,~l_ R ALTER CASING F~ RAcTURE TREATMENT_ ABANDONMENT* _ WATER SHUT-OFF ~,~uLTIPLE coMPLETE F ~o TING OR ACiDIZIN L..---I ~ S,.--O ~ TEST RE TREAT ~ DON'* other) ' . ~cIDIZE ~ ~ r,,ANGE pLANS ~- (NOTE:. ~e_p~of~t;;~;~stlmated date ~ ..... I I ..... [ Co~' ~~ent dates, ~'~ REPAIR WELL (Other) pLETED oPERATIONS {Clearl~ state ~! ~'~'.~ ..... ~. DESCRIBE pRoPOSED OR COM starting any proposed work, 2500 gallons 12-3 mud ' idize sub~ect ~ell ~[t~ Operator plans to ac ~, ~,,A~n hloric ac~d. The ac~fl is to 5e ;[500 ~allOn$ ~° ~ --;ulling the ~e11. The ~ell is ac~d and ~ithout pumped thrOUgh tubing interval 9240-10,715' · perforated in the Middle Kenai Sand 0EC 2 © DIVISION OF O1[ AND GAS ue and correct Area te office u cO.D'~ ~" ' ~e instructions On Reve-e S,de Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 August 17, 1972 File: JCS-462-WF Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Re: Sundry Notice and MonthlY Report of Operations Granite Point 17587 Well No. 3 The required copies of both State of Alaska Forms P-3 and P-4 are transmitted herewith covering recent water injection conversion operations on Granite Point 17587 We 11, 1972, File: JCS-385-538/WF, advised you of the date and time when injections began into thiS well. Yours very truly, John C. Schillereff Supervisor in Charge Attachments DIVISION OF OIL AND GAS ~ ~o. v~ STATE ALASKA ~'. 3-1-70 OIL AND GAS CONSERVATION CONV~AITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS o,L~,~ ~] o,s~,.~ [] o?~--, Water Iniection NAME OF OPERATOR SUBMIT IN DUPLICAT~ AP1 NU~IER1CAL CODE 50-283-10031 6 LEASE DE$IGNA?ION AXD SEBIAL ADL-17587 '~ IF INDIA]~, AI.,OTIE~: OR TRIBE NAME 8. L.~IT FAR~I OR LEASE NAME Amoco Production Company 3. AD~)~ESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 99510 Surface: Leg 1, Slot 8, Granite Point Platform Bruce, Sec. 31, TllN, RllW, S.M. Granite Point State 17587 9 WELL NO 3 10 F~.I_-~ AND POOL. OR WILDCAT Granite Point om, mc-rzv~ Sec. 30, TllN, RllW, S.M. 12. PERMIT NO. 66-52 '13, REPORT TOTAL DEPTH AT END OF MONTH, CHA. NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUM]~ USED. PERFORATIONS. TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE A~D A.NY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS Summary. of Operations for July 1972 July 1- 2 July ~3 July 4 - 10 set packer at 7850' on wireline. Laid down drillpipe and ran 3-1/2" tubing. Tested each tubing joint to 7000 psi with Gator Hawk. Spaced out and pressure tested annulus to 2500 Psi. Filled annulus with inhibited saltwater solution and landed tubing, Nippled down BOP and installed wellhead and injec- tion lines. Started injections at 1:00 p.m. on July 3, 1972. Tested injectivity. Injection rate on July 10, 1972 was 3206 BWPD at 3400 psi. Final Report. DIVISION OF OIL AND GAS 14. I he~b~ ~fY ~t th~mZ ~ ~e~ ~ ~ ~ ~~ =~ Supervisor in Charge ,, ~ Au~us~ 17, 1972 NOTE--RePort on this form is required for .ea~ calendar ~tht regardless of the status of operations, end must ~ filed in duplicate with the oil and gas conservation commiffee bythe 15~'of the suec~ding mnffi, ~le~ otherwise directed. ,~pprov~ Retu~ ~ ~ ,, [ ~1 ., Form REV. 9-30-6 9 Smbrntt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATIO, N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this £orrn /or proposals to drill or to deepen use "APP]~ICATION 'FoR ~EIZL~iT-LJ' 'for such 'pl:o~osal$~) OILwELL ~--~ OASW~LL [~ OT"ER Water Injection 2. NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. 0. Box 779, g~rtchoral~e~ Alaska 4. LOCATION OF WELL At surface 99510 Leg 1, Slot 8, Granite Point Platform Bruce, Sec. 31, TllN, RllW, S.M. 13, ELEVATIONS (Show whether DF, aT, GR, etc. RDB 107' above MSL 14. 5. AP1 N~C~J, CODE 50-283-10031 6. LEA~E DI/ISIGNATION A. ND SERIAL NO. ADL-17587 7. IF INDIA-N, ALLOTTEE OR TRIBE NAME 8. UNIT, Fa OR LEASE NAME Granite Point State 17587 9. V~ELL NO. 3 10. FIELD A~D POOL, OR WILDCAT Granite Point 11. SEC., T., R., M., (MOTTOM HOL~ OBJECTIVE) Sec. 30~ TllN~ RllW, S.M. 12. PEP,_NLIT NO. 66-52 Check Appropriate Box To I,nd~cate Niat'ure of NOtice, Rei~ort, or Other D~ta NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT j [ MULTIPLE COMPI,ETE SHOOT OR ACIDIZE AaANDONs REPAIR WELL CHANGE PLANS j j ~Oth~) ! .! REPAIRING WELL SHooTING OR ACIDIZING i ABANDONMEI~T* convert to water in~ection (NOTE: Report results of multiple ~ompletton on Well Completion or Recompletion Report and Log form.) !5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and glv~ pertinent dates, including: estimated date of starting any proposed work. Ran bottom hole pressure survey on June 26, 1972. Shut the well in on the same day. Killed well and pulled artificial 'lift equipment and laid down tubing. Ran 9-5/8" casing scraper to 7900'. Ran bit and casing scraper for 7" casing to 10,800'. Ran retrievable packer on drillpipe and set at 7875' and tested annulus to 2500 psig. Pulled drillpipe and packer and ran correla- tion log. Perforated 9240-9310' , 9380-9400' , 9480-9495' , 9580-9650', 10,045- 10,095', 10,120-10,130', 10,150-10,200', 10,215-10,270', 10,290-10,310', 10,432-10,462', 10,478-10,578', and 10,628-10,715' at 2 JSPF with casing guns. Ran Baker Model D packer on wireline and set at 7850'. Ran 3-1/2" tubing and pressure tested to 7000 psi with Gator Hawk. Pressure tested annulus to 2500 psi then filled with inhibited saltwater. Landed the tubing, nippled down BOP, and installed wellhead and injection lines. Pressure tested well- head to 5000 psi. Started injections at 1:00 p m~~ ~.~2 ~ted injectivity and completed operations on July 10~ . j l~ n July 10, 1972 was 3206 BWPD at 3400 psi. DIVISION OF OIL AND GAS 16. I hereby cey that the foregoing is true and correct TITLE Supervisor in Charge DATE August 17, 1972 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: DATE See Instrudions On Reverse Side ApproVal Copy Ret.med Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 August 4, 1972 File: JCS-447-533.4 Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Procupine Drive Anchorage, Alaska 99504 Dear Sir: Re: Reservoir Pressure Report Granite Point 18742 Well No. 16 and 17587 Well No. 3 Transmitted herewith are bottom hole pressure data for thesubject wells as shoWn on the' Reservoir PresSure RepOrt, Form P-12. This data was obtained immediately prior to converting these wells to water injection service.' Yours very truly, Supervisor in charge .¸ Att achment OlVlSiON OF OiL ,,.%"',:"0 GA'; Form P--12 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE RESERVOIR PRESSURE REPORT *See Instructions on Reverse Side )pePator Amoco Production Compa~y Address . P. O: Box 779, Anchorage, Alaska 99510 . ~'ield . . County < I Date Granite point ' I' Kenai BoroUgh 8-4-72 ?roducing Formation t Oil Gradie'nf:. Water Gradient Initial c°mpleti°n* 1S'pecial~ [General s~rvey*' :' ' Datum'Plane--8780 ' MSL 1Gas Gravity ' ' ' Bomb 'Test Data .. sonic Instruh~en{ Test Data '~ ~ ' ' ~ ' . ~ Wt. of Wt. of Pressure 2 ~ c Shut-In Prod. Test ~ .~ ©~ . Date ~ Tubing Test' B.H. Observed (Bbls. perDay) Liquid Liquid Liquid Gas Casing at Lease ~ a Tested ~ ~ Pressure Depth ~ Temp. Pressure Level Gradient Column Cohmn Pressure Datum ~ r2 ~ ... Oil Water ' 128~ 18742· 16~, 0 6-11-72 24 1014 8900' 1238 '~ . ::- (-7601 , , 17587 3 0 6-25-72. 24 0 9818' 1710~ 1710 · "' MD .~ (-8780 .. : MSL) , · . Note: Bottom HolLe h'ess~re measuremeni:s run ])rior t:~ comerting l:hese ~ells ~:o wat~r injection servi~:e. · Designate type of report by "X". ! SupervisOr - CESTmIC~TE: X, ithe undersigned, state that I am th, ..1...n......b_-..~...a..r.j~.~..... of the ...a~O.~.o....~..~.o.~[lJ.~.~ion Company (company), and that I am authorized by said company~ to make this report'; and that this report was prepared under my supervision and direction and that t. he facts stated therein are true, correct and complete to the best of my knowledge. ~i.~~~. ~. MINER PUBLISHING CO. Form No. P--4 REV. STATE oF '-AI~KA SUBMIT IN ~rOlmLICAT~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WILL WgLL OTH[R gater ln~ection 2. NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPEI~ATOR 99510 V. 0. Box 779, Anchora~e~ Alaska '4. LOCATi'~N OF W~-~ Surface: LaS 1, Slot 8, Granite Point Platfor~ Bruce, Sec. 31, TllN, RllW, S.M. t- AP1 N~IE~CA/. CODE 50-283-10031 6 LEASE DESIGNATION AND SEHIAL NO. ADL-17587 IF INDIA]~. ALOTTEE OR TRIBE NAME 8. L,~IT FAB2A OR LEASE NAME Granite Point State 17587 9 WELL N0 3 10 FIELD A.MD POOL, OR WILDCAT Granite Point . sec., r., ~.. ~,. ¢i~o~ .o= o~ Sec. 30, TllN, RllW, S.M. 12, PER.MIT NO 66-52 13. RE~ORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLU1VfES USED. PERFOHATIONS. TESTS AND RESULTS FISHING JOB~ JUT~K I/~ HOLE AND SIDE-TRACKED HOLE A~D A2qY OTHER SIGNIFICANT CI~LA/~GE~ IN HOLE CONDITIONS. Summ~ of Operations for June 1972 June 26 - 28 June 29 June 30 TO ll,0lS, I~D 10,969. Kill vail with filtered salt water. Pull and lay down tubing and Kobe bottom hole assembly. Run bit and casing scraper and clean out to 7900' in 9-5/8" casing. Run bit amd casing scraper and clean out ~o 10,800' in 7" liner, Run retrievable packer and set at ~875'. Pressure test annulus to 2500 psi. Run ~amm Ray correlation lo$. Perforate 9240 - 9310', 9380 - 9400', 9480 - 9495', 9580 - 9650', 10,045 - 10,095', 10,120 - 10,130' , 10,150 - 10,200' , 10,21~ - 10,270' 10,290 - 10,310' , 10,432 - 10,462', 10,478 - 10,578', and 10,628 - 10,71~' at 2 JSFF., JUL 1 7 197 DIVISION OF OIL AND GAS 14. I hereby certify correct Supervisor in Charge July 14, 1972 smmm ~ ~..qCT-TTT.T,EP, F__.FF 'rrrx.~ m i · iii ii i Ul, , i i NOTE--Report off this form is required for .each calendar month~ regardless of the status of operations, and must bo flied in duplicate with the oil and gas coniervQt(on committee by the ISth of the succeeding month, uflle~8 otherwise directed. For. m P--7 ~ ..... .-: ' ' S%TBMIT IN PUP! !¢i~ ':* STATE OF ALASKA ',see other struet ions on jl ii i WELL cOMPLETION OR RECOMPL~ION REPORT AND LOG* _, None Assigned .......... ~:,?~i 6. LEASE DES[GN&TION AND SERL4J.~ NO. ~ la. TYPE OF WELL: b. TYPE OF COMPLETION: NEW [~ WORK~ %VELL OVER WELL WELL , -~DR¥ Other EN BACK I~ESYR. Other ~. NAME OF OPERATOR Pan American Petroleum Gorporat~on 3. ADDRESS OF OPERATOR · P. 0. Box 779:- Anchorage~ .Alaska 99501 ~-. LOCATION OF WELL 7(Repo,'~ locati6n clearly, and'in accordance with any State requirements)* At ,ti.ace_ . RECEIVED At top pi0d. interval reported below ' ~. '.- -- ' NOV 15 1968 At total de'pth DIVISION OF OIL AND OA~ 17587 ALLO~ OR TRIBE NA1VIE 8. UNIT,FAR/VI OR LEASE NAME Granite Point State 17587 9. 'WELL NO. .. FLELD A~D POOL; OR WILDCAT Granite Point 1L SEC., T., R., M., (BO~I'OM HOLE : OBJECTIVE) Section 30; TllN, RllW 12, PER~IT NO. 18, TOTAL DEPTH, NLD & TVD [19: PLUG, B~CK MD & TVD[20. IF 1V/ULT]~PLE COM~L., ] 21. 22. PRODUCING II~V~(s) ~OF ~S C~MpLETi0N ~--~D'P ~OTTOM AND NAME, : /- . '. . , . (MD TV'D)* 24. TY-~E ELailCTI~C 'AND-OTHER LOGS: RUIq': : '- RT, OR, .~C)* [17. F_J.,EV. CASIN'GHEAD INTERYALS "DRILLED BY ']" ' CABLE TOOLS '23. WAS DIRECTIONAL SURVEY MADE i CASI/~G SIZE - CASING RECORD (RePort all :strings set in will) - WEIGHT, LB/FT. DEPTH HOLE SIZE 26. LINER RECO~ · D) SACKS-CEMENT* 28. PER~FORATIONS OPF~ TO PRODAYCTIOI~ (inte~al, size andnumber) _ 27. TUBING RECOI~D SCREEN (MD) SIZE l.' DEPTH SET (MD,) [ PACKER SET (1VID) 3~ & 2-7[8" 10,72~, [ , , 29. ACID, SHOT, Fi'<A~CTU'HE, CEa?LENT SQUt~[gZE, ETC. A~iOUNT-A.N-D I-LIND O.FAVIATE~AL US,ED" ' i u 30. PEODUCTION . DATE FIRST Pi~ODUCTION 'f PI~ODUCTION METHOD (Flowfl~.g, ga~ lift, pump~g--size and type of p~p) [V/ELL ~TAWS (~oduci~ or 10-16-68 :~ '[~ Pumping I ~'~"") Producing DATm OF TZST, lHO~S TES~ '[~tOXE SIZE [PROD'N FOR OI~BBL. ' ~CF. WA~B~. [GAS-O~ ~O .. ! : [ l~s'r ~O'D r~ow, ~sma I~S~a r~ss~ ic~~~ o~ssu. '. 2~c~. . lorn as~w~r-~ (c~.) ~ · DISPOSITION OF GAS (~old, used for fuel, vented, etc.) TEST WITNESSED BY Used ~fior fuel and flared 32.LIST OF ATTACHMENTS . Chronological ~orkover H~story I hereb7 eert~7 that the foregolng~ttaehed Information ~ complete and correct a~ determined from alUavaflable records ii i ~ ~ i i i1~ · (See Instructions and Spaces lot Additional Data on Reverse Side) i CEMr. NTING RECORD i AJVfOLT~ PULLED D~t I/N-TERVAL (1VED) 'I INSTRUCTIONS ~ _ .General: This form is designed for submitting a complete and correct well completion report and lpg on all types of lands and leases in Alaska. : :' Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth ~meas~Jre- ~ ment.s given in other spaces on this form and in any attachments. Items ]0, and ]]:: If this well is completed for separafe production from.~more than one interval zone - .(multlple completion), so state in item 20, and in item 22 show the prcducing interval;' or~ interv, aJ§, '~top(s),~bottom(s) and name (s) (if any) for only the interval reported~ in item 30. Submit a .separate report ~ (page) on this form, adequately identified, for each adctitional interval to be seperately pioduced, show- · ~ing the ad~litional data pertinent to such interval. ~.ltem]6: "Sacks Cement": Attached supplemental rec6rds'for this well shoukJ show the details of any m61- 'tiple stage cementing and the location of the cementing tool. ~. Item 28: Submit a separate completion report on this form for 'each interVal to be separately produced. ... (See ,instruction for items 20~and 22 above), ~ .,_ ~4. SUMMARY OF 9"O~VIATION TESTS INCLUDING INTERVAL TESTED. PRESSURE DATA A.ND'~OVE~ES"OF OIL, GAS, 35. GEOLOGI'~ WATER AND MUD NAME i MEAS.: DEPTI{ . . ,,, , , 36. CO~ DATA. Aqq'ACII BRIEF D~CRIPI~'ONS OF LITIIOLOGY. POROSITY, FRACAS. APP~NT DIPS AND DETEC'PEI) SI~OWS OF OIL. G~ OR WA~. . , , .. , ,... , . , . , GRANITE POINT STATE 17587 NO. 3 Chronological Workover History lO/16 10/10- 15 PBTD 10,969'. Converted to a pumping oil well. Pulled and reran tubing. Installed pump and pump tested. Form No. P--4 REV. 9.~-.~7 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF :DRILLING AND WOR'KOVER' OPERATIONS ~ API NtnVm~UCAL ~ODE None Assigned 6. LEASE DESIG~1ATION A,~'D SEi~IAL NO. ADL- 17587 1. 7. IF IND1A]~', ALOTTEE O~ TRIBE NAME 0IL ~ GAS ~-~ WELL WELL OTHER 2. NAME OF OPERATOR Pan American Petroleum Covp 3. ADDRESS OF OPEI%ATOR P. 0. Box 779 .- Anchora~e~ Alaska 99501 4. LOCATION OF WELL Leg 1, Slot 8, G. P. Platform B; 2050' FSL, 2019' FWL, Sec. 31, TllN, RllW, S.M. 8. U'NIT,FAHM OR LEASE NAME Granite Point State 17587 9. WELL NO. 10. FIELD A-ND POOL. OR WILDCAT . Gr~nlta PQint I1. SEC., T., R., M.. CROP'rOM HOLE oaJ~-rnr~ sec..30, TllN, RllW, S.M. 12. PEP./VIIT NO. 66-52 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUIVIES USED, PERFOP,.ATIONS, TESTS A/XFI) RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE-TR~CKED HOLE AJNrD A.NY OTHER SIGNIFICA2qT CI-IAN'~ES IN HOL~ CO1VDITIONS. 10/16 PBTD 10,969'. Converted to a pumping oil well. 10/10- 15 Pulled and reran tubing. Installed pump and pump tested. RECEIVED NOV 1 5 DiViSION OF OIL AND OAS 14. I hereby certify that the SmN~D ~ , Asst. Area Admin. SU?Vr. DAT~ November 11~ 1968 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, anO must ~ filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 lfl~l · AND orr,=~ Anchora8e L~A~- N.M.~ ADL'17587 L~ ~ ~,~ ~ granite Point SCare 17587 MONTHLY R~PORT OF OPeRATiONS State ..... A_!$_8_.k~__ ......................... Borough _._~_~_.__l__ ........... ~ ................ Field ........ _ _~__r. _ _a..~...i.~ ?.. _P_ .0. _i. _l}..t_ ..................................... Th, e l'ollow~ng is a ¢orreot report of operations and prod~et~or~ (~nelz~dir~ drgllgr~g an, d prodgoin~ wells) for the month o[ ...... Jtlly ............................. 1,9__6_?_, ............................................................................ .4 ~ er~ t' s address .......... ~_,___O ,__IIOIL~_~ ~ .............................. Co mpa r~ y __l~tn__,i~mlrl_~al_l~.golttm..tl~rl~.,_ .................................... _ittohor~:~_~ak8 ...................... Si~r~ed Original Signed By: .................. l'i--K2 Y,1tEBI~_· - · ': ................... Phor, e .......................... ~l-_lt~ll ........................................ ~ler~,'s title _ __ &r_(& _ l, ip~~~i~ ............. SEC. AND Dtlrs CU. F~. oF GAS GALLONS OF BARRELS Or REMARKS ~ OF ~ r~Wp. RANGE WELL BARRE~ O~ O~ ORA~TY GASOLINE WA~ER (If (If &ffiins, de~th; If shut down, oa~; NO. Pao~c~ (~'tho~) ~ECOVERED ~O~O~ 80 8~a$e) date ~d rmult of ~t for ........... oon~t of ~) lO ~ 1~ 11~ 3 31 ~,~5 41 47,903 -0- 478 I NOTE.--There were ....... .6.~.~3.3,~ ......................... runs or sales of oil; ........... ['lO ............................... M cu. ft. of gas sold; .............. NO ......................................... runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding rr~nllll, janlpssl o~tl}errwi~ directed. LI~ IV[~ LJ AUB 1 0.1967 DIVISION OF MINES & MINERAL~ Form P-~7 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION SUBMIT IN DUP[/ _. 2' Effective: July 1, 1964 (See other t~; structions on reverse side) WELL COMPLETION OR RECOMPLETJON 'REPO.RT AND LOG * BACK ItESV'R. ,-~ · Other EN la. TYPE OF WELL: b. TYPE OF COMPLETION: NEW [--~ WORK[--] WELL OVER NAME OF OPERATOR ADDRESS OF opERATOR Pan American Petroleum Corpor~'~i~ 15. D~ATE SPUDDED 16. DATE T.D. REACHED 17. DATE COMPL. 11-11- 66 2- 7- 67 3 -17- 67 I 10-25-66 18. ELEVATIONS (DF, R~R, RT, GR, ETc.)* RKB 107.3' above MSL 5. LEASE DESIGNATION AND SER][AL' NO. ADL- 17587 6. IF INDIAN, ALLOTTEE OR TRIBE' 7. UNIT AOREEMENT NAME $. FARM OR' LEASE NAME NAME Granite point State 17587 9. WELL NO. ,: 3 10; FIELD AND POOL, OR WILDCAT Granite .Point · 11. SEC.,~T., R., M,, OR: BLOCK AND S~RVEY OR. AREA ' BHL: Sec. 30, TllN, RllW, 12. BOROUGH [:'l 13. sTATE ... Kenai i Alaska P. O. Box 779 - AnChorage., Alaska 99501 4. L~OCATION OF WELL (Report location clearly and in accordance with any Etate requirements)* ~tsar~aceSlot 8, Leg 1, Granite Point P~laiform B: 2050' FSL, ~ 201q~ FW.L_ S~c. 31, T11N, RllW%'~ S M At top prod. tn~ervai rdpor~euo~low ' .'.. ' 242' FSL, 667' FWL, Sec..30, T~IN, ~'RllW, S.M. At total depth · 647' FSL, 729' FWL, Sec. I 14. PER~IT'N0: DATE ISSUED 19. ELEV.. CASiNGHEAD 77.I" aboVe MSL 20. ?OTAL DEPTH, MB & TVD 21. PLUG, EA~V~--.-T.D., MB & TVD ] 22. IF' MULTIPLE COMPL., 23. INTERVALS ROTAR~ TOOLS CABLE TOOLS -'~'- [ HOW MANY* DRILLED BY 11,015' 10 969' ' I I ~' , ~ 0 - TD 24. PRODUCING INTERVAL(S), OF THIS COMPLET-iON TOP, BOTTOM, NAME (MD .AND TVD)s l"2~. WAS DIRECTIONAL ' ~ SURVEY MADE 9240 - 10 715' top of pay C Unit Mi:dd~e Kenai Member, Kenai ' ' ' · -, Yes '- formation at 8503' :: 26. ~YPE ELECTRIC AND OTHER LOGS RUN >":' ~ Acoustic ! 27. WAS WE~L CORED DIL, Sonic, Dipmeter, Gamma Ray, ~.ement.. Bond log, Signal log I ~ No 28. CASING SIZE 2.0'~ 13-3/8" 9-5/8" WEIGHT, LB./FT. CASING RECORD (RePor~ll strings set in well) ' DEPTH SET (MD) HQLE ! SIZE [. CEMENTING RECORD ' zogz, : iT- /z'' 16oo sx+33~0 Diacel D & ~5 8178' t2-~'/4" ]1000 sx + 1~o CFR2 AMOUNT PULLED .' sx w/4% ;;~C~C12 CaClZ ,: 29, LINER RECORD ~) 30. TUBING RECORD SIZE TOP (MD) BOTTOM (MD) SCREEN (~D) 7II 7295' 10,999' 31. PERFORATION RECORD (Interval, size and number) See Chronological Well History-. .___32' ACID, SHOT DEPTH iNTERVAL (MD) None SIZE / DEPTH SaT (MD) ] PACKER SET (MD) '[ Z-7/'8' 8905-10693', FRACTURE, CEMENT SQUEEZE, ET0. AMOUNT AND KIND OF MATERIAL USEb NOne 33.* PRODUCTION DATE FIRST PRODUCTION PRODUCTION METHOD (.Flowing, gas lift, pumping--size an5 type o! pump) I WELL STATUS (Producing or . ] shut.in) 2 - 19- 67 Flowing Produc Lng FLOW. TUBING PRESS. CASING PRESSURE CALCULATED OIL-BBL. GAS MCF. WATER--BBL. ] OIL GRAVITY-APl (CORR.) 24-HOUR RATE [ [ 350 1620 ~ ~ 2800 896 42 40.1 34. DISPOSITION. OF OAS .( ~old, useti for yuel,, vented, etc..) Vented TEST WITNESSED BY 35. LISTOF ATTACHMENTS DIL, Directional Data, Chronological Well History-, Perforation Record. 36. I hereby certify that the foregoing and attached information is complete and correct as determined from all avail~,e ~e~c~rds,~ SIGNED TITLE Area Superintendent DATE 4/~1/67 i~U/ *(See Instructions and S~ces ~or Additional Data on Reverse Side) DIVISION Of MINES & MINER~ ~CHO~GE ~ INSTRUCTIONS General: This form is designed for sabm'itt~ng a ~mple~ and ~rr~t well completion' repo~ 8nd log on aB ~s 0f landa and lea~ ~ ether a ~er~ agene7 o~ both, pumuang ~ applicable ~eral ~d/or 8~te laws-'~d re.la.ohs. An~'ne~ssar7 s~ial instme~on~ con.ming ghe me of th~ form and ~e nmber of eopi~ t0 be submi~t~, partieul~17 with ~gard ~ l~al, 8rea, or re~onal pro~nr~ and praet~e~, oithe~ ~e shown belo~ or will be ~sa~ bT, or ma7 be ob~ined from, the local ~ederal .... and/or Sm~ offi~. S~. i~trhctions .on i~ ~ and 24, and ~, ~low. regard~g separate re~r~ for ~para~ ~mpletions. ~ If not ~ prior to the ~e this summary ~ ~ submitS; ~pi~ of all currently availabl0 lo~ (d~lem, g~lo~sts, staple and core analysis, all tion :and pr~sure tests,' ~nd directorial Survey~ shoed be at~ehed hereto, to the exten~ r~uir~ by applicable ~eral and/or 8~te laws and relations. All attachments ' should be li~ted on this form, s~ item 35; ~ ' I~ 4: ILthere 8re no ap~ieable S~' r~uiremen~, lo~tions on ~eral or 'indian land shoffid ~ deseri~ ~ 8eeord~ with ~eral r~uirem~n~. Consult local 8~te orF~eraloffi~ for ap~ifie instructions. ' ~r - ~ I~ 18: In~iea~ which elevstion ~ us~ aa ~eren~ (where not o~e~l~ shom~} fo~ depth measuremen~ giv0n in o~e~ apaees on this fo~m and ~ an7 attachment.' I~ ll a~$ ~4: If this we~ is eomple~ fo~ soparat~ pr~uetion from more ~an o~ interval zono (multipleeomp[etion), so state in i~m' ~g, and in l~m g~ show the Produ~g inte~al, or intervals, top(s), bottom(s) and nme(s) (~ anT) for on17 the inteffval re~ ~ l~m ~. 8ubmi~ a ~parate repo~ (pa~) on t~ fo~ ad~uatel7 identified, for each additional inte~al to be sepam~lT, p~u~,' ~how~g the additional da~ pertmeng to such ~terval. ' ·. ' I~ ~: "~ ~em~t": At~eh~ supplemen~l re~rds for this well shoffid show the de.tis 0f' ~7 mffitiple s~ge ~menting and tho location of the eementin~ ~ol. ~ ~$: Submit a ~parate completion re~ on ~ fo~m for oaeh i~ter.al to 'b~. ~para~17 prdd~e~.' (8~ instruction fo~ items 22 and 2~ .... . - : ~ - r _. ..- . ..............~· . .... . '~- 57. SUMMARY OF POROUS ZONES: -. ~ . . ....... . . ~ ' -' -. .! sHOW-~LL IMPORTANT Z0~ES OF POROSITY AND CONTENTs THEREOF; COaEO IN~ERV~A~S; iND ALL DRILL-STEM TESTS, INCLUDI~IG 3~. ._ -GEOLOGIC MARKERS .. DE~H INTERVAL TESTED~ 'CUSHION USED, TIME' TOOL OPEN; FLOWING AND SHUT-IN 'PRESSURES, AND RECOVERIES " : FORMATION TOp ~ BOTTOM : ' ' - DESCRIPTION, CONTENTS~ ETC. .' '-' -' . -~ TOP . .:_ · ' ,. ~ ...... ~ NAME -. ., '-- ' --. MEAS. DEPTH TRUE VERT..DEPT~ .... - . " : :' . ~ ..~i -- MGS.Sand F-MG Qtz. sand .- .with ~ongl°m'erate -: "~ ... ' . ',. ,. ,-.,': .... .... . -. . · .~- , zone : pebbles, '"light gray, Ca~bonace'°uS, '~ : ~ ..Bei a. . 4325 : . ~ -.? ''~ : ~-. slightly calcareous.. ,~-~ MGS.San'd ~ ,'-.:~ ~,."-, c-. ' ~ .... ~"i~ '~ ':~: ........ .::_: " . , Member ....... ~';'~ ~'6942 ' ~6317~' ~-.; .. . ? ..'~ .- ;: - C, ~ :' · : ' ' .-: . ~': , , ~: · .,: . .~. .- ~ " _. ".. .... . . ' -, - ~[_ '' -. ' ~ -- ( · ~ : :,- [ ' .... ~r, '_ .. ~ '-~, ~ .... ., .. .. .. · . '~ ...... ~ . . . _ - : . , .... · ..· [' ~ ~ '~ . : ., -- . . ·- ..... . -. '~ · .. . : . .... , .., . · - .~ -' ,., . . . ..: .-, .~. . ~ . ? ', :.' .... ( '~ . . :, ~: --' , ,. .- .". - DM-12 Date ,~ 3-.20...-.69 -~ State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Petroleum Branch INDIVIDUAL WELL RECORD (31) 30 , T · liN R. Permit No. S Meridian 66-52 ,,~,, Issued _ 10- 25-_~.~ ..... G.P.Platfom , Slot 6. L~ 1 Operator_. ?an American Pet. Corp, Location (Surface) 2050' FSL &.20.1~i~'FWL'. Se~, 31__ Lease NOe ADL 17587 175~c ........ or Owner __Gra_n.~!t~..P.°int state . (Bottom) 660' FSL ~ 660' FWL. See, 30. Well No. 3 Spud Date~__~ll~,_!l-66 _ Drilling ceased Suspended Abandoned Completed (F-GL-P~_ _2-20-67 ...... IP 2....__565 ~ B/D, Area Granite Point ............ Gray Total Depth _ 11;015' . . KB 80' above MLLW Elevation ,40.1_API Cut 1_~% Gas ....... 8_2_1.___ _~ M~F/D, Casing: Size Depth 20;' 589 ' 13-3/8" 2092' 9-5/8" 8178'. Bean 116_ /64 CP. '1620 psi, Tm ~,3.~_0 ~ ~_psi Sx Sm~t Perf: 10,715'-10,680' Plugs~ 11,000-10,969 710 10,673-.10,628; 10,578-10,5~8} __~ 10~553-10,478:10~462-10,4323 10,311-10,291/10,270-10,24%; 1000 10 , 240-10 , 215) 10,200-10,1503 10,095' 10,045 ~ 9,650-9,580; 800 9,400-9,380; 9,310-9,290; GEOLOGIC FORMATIONS Surface Lowest Tested. 9,280-40'. Name PRODUCTIVE HORIZONS Depth._~ ....... Contents Year WELL STATUS May June July Aug Sept Oct Nov Dec Remarks: 11-11-66 11-14-66 11-25-66 12-15-66 12-23-66 1 -04-67 1-11 67 1 -25-67 2-07-67 2-O9-67 2-15-67 2-16-67 2-20-67 3-1 to 12-67 3-17-67 Chronological Well History .,~ ..,. ..,. >~¢ , >~¢ -,- >l-' * * ¥ Granite Point State 17587 #3 APR PlV!,SlON OF MIh, l~:b ~ MINEP,,A~ ANCHOP. AG~ Spud. Set 20". casing at 589' with 710 sacks. Drilled 12-1/4" hole to 2110', reamed to 17-1/2", logged and set 13-3/8" casing at 2092' with 1200 sacks. Drilled 12-1/4" hole to 6648'. Completed fishing job for stuck drill pipe. Con- tinued drilling 12-1/4" hole to 7488'. Completed fishing job for stuck drill pipe. Drilled 12-1/4" hole to 8186'. Logged and set 9-5/8" casing at 8178' with 1000 sacks. Drilled 8-5/8" hole to 9691' and logged. Drilled 8-5/8" hole to 11,015' and logged. Ran 7" liner 7295-10, 999'. Cemented with 800 sacks. Perforated 10680-715', 10628-673', 105482578', 10478-553', 10432-462', 10291-311', and 10240- 270' with 4 jspf. Perforated 10215-240', 10150- 200', 10045-095', 9580-9650', 9380-9400', 9290- 9310', and 9240-280' with 4 spf with casing guns. Ran :tubing. Drilling rig released. Well shut in for pipeline repairs. Completed as flowing oil well. TD 11,015', D Unit, Middle Kenai Member, B[enai formation. PBTD 10,969'. Top of pay C Unit, Middle Kenai Member, Kenai formation at 8503'. IPF 2800 BCPD on 116/64- inch choke with TPF 350 psi, corrected gravity 40.1°, GOR 315, and BS&W 1.6 percent, capacity allowable. Granite l~oint Field DeveZopment Oil Well. Bottom hole location SW/SW Section 30, TllN, RllW, SM, Kenai Borough, Alaska. Final Report. APR 2 IV[9 ~-,196'1 {:.:.':'/. ,; ,,' .)Q ,- ! · ! ~'orm No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 LAN° orr,c~' Anchorage L~ =" "~'~ ~ Granite Point State 17587 ~' LE$$EE'$ MONTHLY REPORT OF OPERaTIOnS State .......... ~J.~s_ka ................. Borough .............. _m____e__n._.a__~ ................ Field ........ _G____r.a..n.i._t..e____P..~o._~.n_.t._ .................................... The followin~ is a correct report of operations arid prod~etion (ineludin~ drillir~ and prod~ein~ wells)/'or the month of ........... _F__e_.b_?__u__a_.?__~_: ........... 19__6__7__ ............................................................................. ./l ~ e r~ t ' s address ................. .~._ _ _O_ _: _ _ _B_ 9_x_ _ _7. 7_ ~ ...................... Company _ ?_ _ _a_ n. _ _ ~ _ _ _ _ _ _: _ _ _ . . _ _ . _ _ __._A.... . _m_ ~. .r_ i. _c _~. _n. . _ ?. _e. _t_r_ p~l. _e_ . .u. _ .m. . . _ .~. .o_ _ .......................................... __A__ n_~~_lao_r_age,. A_la s ka' Si~ned ...... _~__~~~_ ......... P l~ o ~ e .............. 2 72 - 84.71 ~l ~ e n t ' s title ...... _ .A_ _ ~ _e_ _a. . _ [S_u_ _P_ _e. ~_i. .n. .t. _e_ .n. . .d_ .e. SEC. AND BARRELS OF OIL ORAVITY (~ASOLINE WATER (If (If drilling, del}th; if shut down, oause; ~ OF ~ TwP. RANOE WELL Days CU. FT. OF GAS GALLONS Or BAERELS OF REMARKS NO. Pao~ocn~, (In thousands) RECOVERED none, so state) d~te and result o! te~t eo~t~t of ~'~) .... _ ' 30 ,f SW llN llW 3 0 0 0 0 0 0 None ]~BT1- 10969' ~.nd s]mt in for t,ipeli:xe repairs 2/28/~7. Drill,~d 8-5/8" h>le to ll, 015'{and .'et 7" liner 10,~.~99-7295', 2/9/67. PBD 10)69'. Perf. 1~ 680-10715', }0628-10673', 1(548-.0578', 104'78-10552, 10432-10462', 1~ 291-.1031{[', 10240-10270', alii with 4 jspf. P, ff. 10215-10240' 10150-10200', 1~045-100')5' 9580- 9650', 93 50-9400', 9290- 9310', 9>~40-928¢' all with 4 j~pf. Flow tested i /18 - 2/?.( /67. Rig relearned 2/20/67 anti,yell shut in fl)r pipelil~e r{;pair.'. { ........ BHL Se SW NOTE.--There were ..........................N..._o. ................. runs or sales of oil; .............. .N...0. ........................... M cu. ft. of gas sold; ................. .N..o. .................................. runs or sales of gasoline during the month. ( Write /'no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding mont~ ~unl?s otherwise directed, i~ ;~'~.. ' ~.~ ~,~,,, ~I~.- To: Mr. T. R. Marshal,~"~$r, $1iate Div. of Mir: ..... & Minerals, Anchorage Date: 3-9-67 Pan Americans Granite Point State 17587 No, 3 tilgh :Le:-:ol,.:.?¢.o?." ,. &,... ........ Dtpmater Tacwc,_~ ~.0'<~ [ ~ '~k""~~-~ '" ' ~ ,. · !r~d,ic t ton- Z, iecrr j. ca 1 1,;t~:erlog-Ca~ma Ray Log ]',l!cro'~ ,',:~/f;a 19 per Log Micro!at.ar log/Cai ~par Log Nud Log Neutron LOg Pr,.~'ximL t y-Nicrolog/Caliper Log Neutron Yoro.~£ty Log Ne,~.tron Poroaity-Gam~ ~y Log T~'~: ~;'rat ute Log Others: Blue OIVISI©N ~.~i. M!I".¢L!$ a ANCHORAGE B.;Celpt Acknowledged bL_~~~ ..-~~ .Da'L:~~/~. ~~ Please return one signed co~y ~9.~..~he letterhead'addres~ "~ / - ' (~. P. State !7587 ~3 Pan Amor X~ ~Lean ~orpo~&t~on s Operator P~ Ane~ican Pecrol~un 1). ~o Box 779 E~:~o~t is the Suu~, l~ocXce (~03) perrainin~ ro con- procedure ot~ ~13e re£erenced ~ell. Forth P--3 STA F ALASKA SUBMIT IN TRIp: ~TE. (Other instructions ~ re- OIL AND GAS CONSERVATION COMMISSION verse aide) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or 'to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) Ef£ecttve: July 1, 1964 §. LEASE DESIONATION AND SERIAL NO. ADL- 17587 (~. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME OIL [] GAS [] WELL WELL OTHER 2. NAME OF OPERATOR 8. ADDRESI~ OF OPERATOR B~ 779. [ l~eh~a~e.. Ala~ 99501 ' 4. LOC~ION OF WE~L (Repo~]~lon clearly and In ~ordance with any State requirements.' See also space 17 below;) At su~oce Slog 8, ~g 1, G~anite Potng ~fo~ BI 20~0~ FSL, 2019~ ~L, Sec. 31, Tl~, R!IW, 14. PEnMIT ~0. 16. 8. FARM OR LEASE NAME 9. WE~L N0. 10. FIELD AND FOOL~ OR WILDCAT 11. SEC., T., R., M., OB BLE. AND SURVEY OR' AREA BHL: See. 30, TllN 12. BoRouGH .. "J 1 Ala8~ Check Appropriate Box T° Indicate .Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE. COMPLETE ABANDONs CHANGE PLANS SUBSEQUENT REPOB~ OF`: WATER SHUT-OFF ~ REPAIRING WELL . FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple :completion on Well (Other) c~lel:ton pl~e~lurm . completion or Recompletion ReportandLog'torm. DESCRIBE PROPOSED OB CO~PLETED OPERATXONS (Clearly state all Pertinent details, and give pertinent dates, ineludin~ ~timated date of s~rting any proposed wor~ If well is di~etion~y drill~ ~lve sub~ laotians and measured and true vertical depths for ull markers and zonem perti- nent ~ this work.) * ~ [oll~in~ in~e~als, seX-ceded from veil lOgs, viii be perforated and' Ce.z~ed: '9013- ~ approxi~ely 153* FSL & 739' ~L, Sec. 30, TllN, ~11~'. S.~. 92~0- 9312 " 242' FSL & 705' ~L, Sec. 30, 958~ - 9650 " 385' FSL & 667' ~L, Sec. 30, TIlN, RII~, Also selected in~e~als Ir~ 9650- 11~0 (Unlog~ed as o[ *This is l~e upPe~st interval to be test:ed. Perm£ss!on is soushc ~o ~esl~ and possibly complete ~his well less than ~:he c~ lease lines of ADL - 17~$7 and ADL - 18742, bo~h of which are held by Pan ~rican, Iratli~Lps, Sblly, and Sinclair, certify that ~hj~.oregoin~ ~bi true and correct ~' ~. A~A~.LL TITLE Area Su~erintenden~ DATE 2-6,-67 ' (This space for Fed.~lgal ,or St4te 9tiles use) / THOMAS R. MARSHALL, JP~ APPROVED B ..... CONDITIONS OF APPROVAL, ~ A~: Conservation Committee ~t. c~lec~ p~~ of ~e c~ee ~o l~gt~ ~**See Iflmucflons on ~eyene Side (~o~a~ File DATE Form. No. P--4 ~t STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 ~r~,o~ Anchorage N-M~. ADL 17587 ...~,. ~.~G. P. 17587 Well No. 3 LESSEE'S MONTHLY REPORT OF OPERATIONS T]~e followin~ is a correoi repori of operations and prod~ciion (i~cl~din~ drillin~ and producinff wells) for ~e mont~ of .... ]_~_~_~_X ....................... ~9~_~__, ............................................................................ ~ent's address ___~,___~,___~_Q~__~Q_ .................................. Company ~a.~__~_m~_ri.~_~D__~_rO~_~m..-~9-rP. AnchOrage, Alaska ........... ~iff~ed ~~" ~ .............................................................................................. ~2 ........................ wo~e ................... 3_~=_~ .............................................. ~,, ~ u~te .~_r¢_~__~_~!~_~_~_~_ ............. aEC. AND ~4or ~4 BHL Sec. 30 SW of SW TWP. TD 1-4 Dit Dr: 913 31'. ~ 6? JTD ne tq r. led~8- 5, BARI~ELS OF OIL 0 ~g on 1- 31- Recovere .67 Set 9- le until en Cu. FT. OF GAS (In' thousands) ,1 fish. casing at nonth. (}ALLONS OF (]ASOLINE RECOVERED 1- L1-67 Ra Il78' wit BARREI2 OF W&~,~R (If none, so state) None REMARKS (If drilling, dopth; if shut dowu, oaUse; date ~nd reoult of teet for ~aooltne oontent of fas) m DIL, ~onic and ~ 1000 s: cmt. NOTE.--There were ............ ..N.0.. ............................. runs or sales of oil; . No ............. M cu. ft. of gas sold; ............................ ..N..? ......................... runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE--Report on this form is required for each calendar month, regardless of the status °f I~Peff'atj'°n~ atnh~ ]~nw~e[~o[ ~l[~ ']] be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding mo~n,~ur~esr .~ directed. FEB 8.1967 DIVISION OF MINES & MINERAL,S ANCHORAGE Form No. P 4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1964 ~j'~,~' ' ~o ,-,.-,=. Anchorage ~f~'~,'~.~ ~ ~ ADL 17587 '/'~ ~.~' ~ .~,~ ~.~G. P. State 17587 Well No. 3 LE$SEE'S MONTHLY REPORT OF OPERATIONS State .... _A_ _ l_ ~_ _s_ _k_ _a_ . .............. ] ......... Borough ....... _ K_ _ _e_n_ _a.i_ ........................ Field .............. _D_ _ .e. y_ _e.1- -°. _ P-m. . _ .e- .n- - .t- ................................... Tl~e followir~g is a eorreo~, repor~ of operatior~s arid. prod~etior~ (ir~el~dir~ drillir~ and prod~eir~ wells) for ~ke mor~tk of December , 19__6__6__ ............................................... .............................. ./l~er~ i' s address .... ~ .... _0_ .... _B___o__x___7___7__9_ ................................. Corr,pa~l] _p__.a=n___A.__m_.e_ri_c~a_n___.P__e_tr.o.l_c.um._G_ar~~/.~. ~/ p, ;/~-o~; .................... -~- -7--~--T- -8- -4- --7-1- ................................... ~ .......... .~er~ffs gfgIe A r e ~_~_-u-t~e rinte nde nt Cu. F~. o~ OAs /tE0. AND ' BA~REIIi OF Orr. ~ or ~4 (In' thousands) SW 1/4 SW 1/4 Sec. 30 0 0 .g. 1-1-67 led to 664 the AC 'ator panel lax .11 collars tilled to 7488' an¢ 50 of diesel ~ rs. 12-2 (~ALLONS OF GASOLINE RECOVERED ~' TD an 12 -15- Succes drill pi nd 135 g BARREI21 OF WA~g- (If nollo~ 80 8~tO) stuck 66. Spoti sful recc )e stuck ,.llons o REMARKS (If drilling, d~th: if ahu~ down, oauae; date ~ad reeult of t~t for ~sollae oontent of i~as) None ,rill pipe at :ed 41 bbls ,very of when AC scot-free ~NCHORAGE NoTE.~There were ........... .N...°.. .............................. runs or sales of oil'_ ......... .N...©. ................................ M cu. ft. of gas sold' ............................ .N...O_ ......................... runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.~Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1964 ~i{~_y~. LAND BFFIEE Anchorage .~^s~ N"Ms~ ADL 17587 ~ ~.~ ~ ~.,~ ~*~G. P. State 17587 Well'No. 3 LE$SEE'S MONTHLY REPORT OF OPERATIONS State ................. --A-!--a---s---k--~ ........... BoroUgh ............... _K_..e_.n..~_i__ ................ Field ............. _ _D. _e..y__e__l_ _o_.p__ _. _ro_.e__ .n..t ............................... Tl~e f°llowin~ is a oorreot report of operations and production (i~cl~din~ drillin~ and prod~ci~ wells) for tke mor~tA of ....... __N___o_y_~.__m___b___e._r_~_ ............. 19__6__6__, _ ........................................................................... Anchorage, Alaska. ~,~ne~d--~ .... /-'~~. ........................ ................................... _z_:ZZ__-___S__4__7.1_ .............................. z f ' ........... CU. FT. OF (]AS GALLONS OF SEC. AND BARBEI~ OF Orr. GASOLINE ~ O~ ~ (In' thousands) RECOVERED sw 1/4 SW 1/4 Sec. 30 0 0 · 12-1-66. spudded 1 "G" plus per sack · 11-14-6 /ed to TD in 2. 0 ~ng. 11- 2. 2. - class "G" 53 lbs. Di Z% 25-66. ~-11-66. Diacel Zll0', 1 66. Set ~cel "n' BAREEIJ} OF WA~EE (If nona, so ~tate) REMARKS (If drilling, depth; if ~hu~ down, oau~e; dat~ and result of test for gasoline content Of &'Gl) None Set Z0" D" and -ZZ-66. .3-3/8" and 2% :asing at 589' 25 sx class Ran DIL and :asing at ZaC1z and NOTE.--There were ........... .N..-°-. .............................. runs or sales of oil' . ............ ~.Q ........................... M cu. ft. of gas sold; .No runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE. Report on this £orm is required £or each calendar month, regardless of the status of operations, and ,nku~t be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month,i~;ual'e~S o~he~r~]~ directed. P. O. Box 779 Anchorage, Alaska 99501 Date November 11, 1966 Re: Spud new well Granite Point State 17587 #3 Director, Division of Lands State of Alaska Department of Natural Resources 344 6th Avenue Anchorage, Alaska Dear Sir: This is to notify you that the subject well was spudded on State Lease ADL- 17587 at 1Z00 hours on 11/11/66 . The surface location , , of this well is at NE/4 SV¢/4', Sec. 31 , T- 11 ., R- 11 -W, S.M. ~-] We plan no directional work on this well, so the bottom hole location will be the same as the surface location. ~ We plan to drill this well directionally to a bottom hole location of SVf/4 SV¢/4 Sec 30 T- 11 -N, R- 11 -W, S.M. V~ry truly YOURS, F. K. Krebill Area Superintendent RECEIVED N0¥ 2 1966 DIVISION OF MINES & MINERALS' ANCHORAGE ? FORM 4?0 2-~57 PANAMERICAN PETROLEUM CORPOP. ATION P. O. BoX 779 Anchorage, Alaska 99501 November 4, 1966 Mr. Thomas R Marshall, Jr. Division cYf Mines & Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: File: ]?KI~-1668-WF Re: Surface Location, Granite Point State 17587 #3 Due to a change in plans, the surface location of the subject well on Pan American's Granite Point Platform B has been changed from Slot No. 8, Leg No' 1, as shown on our Application for Permit to Drill dated October 19, 1966, to Slot No. 6, Leg No. 1. Please change your records to show that the surface location will be Slot No. 6, Leg No. 1. Yours very truly, F. K. Krebill A rea Supe rintendent REC. F.. IV[D 10¥ 8 1966 OF MINES & MIN~RAL~ ANCHORAGE 3001 Porcupin~ Drive Anchoralge, Alaaka 99504 October 26, ~966 779 ATT~TIO~: Mr. Fo Area ~.~ar Sir: Granite Point Stage 175¢!i] #3 Pan aneric~n Petroleum Corporation, Operator Enclosed is gh~ approved permit to drill th~ captioned ,mil. Cement level outside 9 5/8" ca~Lu~ shall reach at least 200 feet above uppermost o£I or gas sand encountered. truly yours, Ti _~e~__s R. ~larshall, Jr. Petro lema Supervisor ~a/cJh FORM SA-I B 100M 9/65 MEMORANDUM TO: r- Div. of lttnes and llinerals FROM:Tho~It i{. ~srshall, Jr. Pe tro leu~ Supervisor State of Alaska DATE : SUBJECT: October 26, 1966 Ft lin§ Fee Enclosed t~ check 50. 15621 ior $50.00 and approved perait to drill /roa Pan aerican Pe~roleu~ Corporation £or Granite Point State 17587 /clh Form, P 1 ' STATE OF ALASKA (Other Instrnetions on .... reverse side) OIL AND 'GAs CONSERVATION COMMISSION-: ....... SUBMIT IN TI~. JATE* APPLICATION FOR PERMIT TO'DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK · . ' - ~-" . ~ ' ~-~ DRIL~L ~ ' DEEPEN I=l b. TYPE OF'WELL : OIL ~ OAS D SINGLE ~ MULTIPLE ~-~ WELL . WELL OTHER ZONE - ZONE . · 2. NAME OF. OPERATOR .- - _ Pan A~erican Petroleum Co~orat£on · 8. ADDRESS OFOPERATOR'" . . ~.- . _ .... . Box 779 Anchorage, Alaska7 99501 4. LOCATION.OF WELL~ (Reportiocation clearly and in aCCordance with any State requirements.* ) At surface SlOt NCc. 8, L~g NO, 1,. Pan.Americ.an .GraD/re Pt. Plat.'B' 2050'. FSL. 2019' 'F~L,'-~c. 31S TI1N, 1LilW, $.I~' At proposer prou. zone 660' FSL, 660~ FWLt Sec. 30~ Ti.IN~ t~IW, 14. DISTANCE IN MILES'~ID DIRECTION FROM NEAREST TOWN OR POST OFFICE* 9 miles S~ of ~onek Effective: July 1, 1964 LEASE DESIGNATION AND SERIAL NO. ADL- 17587 6..~F INDIAN, ALLOTTEE OR TRIBE NAME 7.~ UNIT. AGREEMENT NAME- 8. FARM OR .LEASE 'NAME GP State 17587. ~0. FIELD'AN~ POOL, OR WILDCAT Granite Point 11. SEC., T., R., M., OR ELK. AND SURVEY OR AREA BttL: Sec. 30, TllN, _._ RllW,.. S,M. 12. B. OROUGH SHI 13. STATE Kenai [ A~a sma ID. DISTANCE FROM PROPOSED* 16. NO. OF ACRES IN LEASE 17. NO. OF ACRES ASSIGNED LOCATION TO NEAREST TO THIS PaOPERT, OR LEASE LINE, FT. 660' l~fL 2592 160 (Also to nearest drlg. unit line~ if any) t8. DISTANCE ~ROM PROPOSED LOCATION* 4~75' 1/~ O~ X9. ~O~OS~ ~ 20. ~0~ :O~ CAdiZ TO NEAREST WELLi DRILLING, COMPLETED, o~ ~m~D ~. o~ ,ms ~. ~'~onek 17587 ~ 13, ~0' 21. E~vxrm~s (Show whe~er DF, RT, GE, e~.) 22J a~PaOX, va~E woa~ wmb s~a~* Est. 80~ above ~LW -- to be co~i~ed ~en rigged up La~e Nov~ber, 1966 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIOHT PER FOOT SETTING DEPTH QUANTITY OF CEMEN= 26" 20" 13-3/8" 9-5/8~ 79. 6 lb 600 54.5 lb 2~00 40 & 43.5 10000 8-'~/8" 7" 26 lb 9800- 13000 Circulate %o surface Circulate to surface , Minimum of 500' above shoe~ add{floreal cement may be used depending upon electric log interpretation. Complete fillup from shoe to hanger Reason for deviation: to reach target BHL from permanent platform. There are no affected operators. BOP specs attached. Intervals of interest to be perforated and msv be stimulated. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program, if any. 24. I hereby t.e~ifx ~hat the Foregoinf~.is True and C~rect. (This space for Federa~or State office use) .. Area Superintendent DATE Oct. 19, 1966 APPROVED BY ~ , CONDITIONS OF APPROVAL, II~ ANY: APPROVAL DATE THOMAS R. MARSHALL, JR. Executive Secre~ary TITLE - · - /~,~cs~a Oil & Gas Conservation Corem. irreg. *See Instructions On Reverie Side 36 3~ - ' ~--'~ '~=. FROM S.W. :COR. 2050'.. NORTH S 2[019' EAST .f I '" !C'AL~ ~- ,6bO LEG NO, 2 LEG NO. 3 LAT. 60°59'~6:32'' LAT. 60°59'55-gP. LONG. lB1° I?' 51.48" LONG. 151 ° 1'7' 52-99 y = 2,559,~:6 Y = 2~559~517 X. = 269;664 X = FROM S.W. COR:' .FROM ~.W, COR. 1989'' NORTH ~ 1.9~' NORTH ~055' EAST 1979'.EAST LEG NO 4 LAT. 60o59'56-52" LONG. 151° 17'53.61" Y = 2,559,378 X = :>69,560 FROM S.W. COR. 2009' NORTH& t948' EAST 30 TIIN 3~ TION 6 CERTIFICATE OF SURVEYOR '~ 'hereby certify that I om properly registered and licensed to practice land surveying ~n the State of Atasko and . that- this plat rep~:esents o locat~on survey made by me or under my supervision and that alt :dimensions and other deta~ts are correct . 32 SURVEYED BY' F M LINDSEY 8~ ASSOC- LAND SURVEYORS & CIVIL ENGINEERS 3201 ARCTIC BLVD. ANCHORAGE. ALASKA NOTE DIYI$1OtN Of MINIL~' & MINI The Iocat ~on of plat.form t_egs was accomplJ shed t~ triangulation stot.~ons Dud, Trinity, and Tyonek Offset. :,Ail coord'inc~tes are Alaska State Plane Zone 4. PAN AMERICAN PETROLEUM caRP ~iBO>( 779 ANCHORAGE, ALASKA 7 July 1966, Amended Inlet to show, correct, distance SW eec. ~or. to leg 2 1992 'to 1989. I ~INAL PUAT OF , , E"i V [' ~U~'V£Y ED FOR ..... Ri~{~IV[D OCT 1 ~ 19~ t.}I¥1~tON Ol= ~.IINl~ & %y . OCT · pnds ~o e~'F~ ~o~ iIileX uo aa 07 ~ooo AliaN · . ' ,~ ' ~ ~ .. ~ ~ · ~ t ~, . ~ , ! . ~' ' ' ;0 ~'qTd ''~ (( ., .... , , ~.alnno a,~s ~..iua~ __>~~ % uaa:..inaI eauds .... ~'~ / nZ 130 au. ii dn IIlg-~ 4 1 "~', l'[ ' ~, ~Z _ __<_ )
