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Home My WebLink About160-0451. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Rod Job, Pull Pump 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 10,828 feet N/A feet true vertical 10,824 feet 10,423 feet Effective Depth measured 10,631 feet N/A feet true vertical 10,628 feet N/A feet Perforation depth Measured depth See schematic feet True Vertical depth See schematic feet 3-1/2" 9.84# / L-80 211' (MD) 211' (TVD) Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / P-110; L-80 10,416' (MD) 10,413' (TVD) Packers and SSSV (type, measured and true vertical depth)N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Hemlock Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 5,760 psi 2,730 psi 7,440 psi 3,014'3,013' Burst Collapse 1,130 psi Production Liner 10,828' Casing Structural 10,824'10,828' 3,014' 28'Conductor Surface Intermediate 22" 13-3/8" 28' measured TVD 6-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 160-045 50-133-10118-00-00 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 3. Address: Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA 028996 Swanson River Field / Hemlock Oil Soldotna Creek unit (SCU) 32-08 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16 Gas-Mcf MD N/A 90 Size 28' 115 1900 0 00 196 323-055 Sr Pet Eng: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. Noel Nocas, Operations Manager N/A Jake Flora, Operations Engineer jake.flora@hilcorp.com 907-777-8442 p k ft t Fra O s 6. A G L PG , p 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 9:03 am, Jan 08, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.01.05 16:10:17 - 09'00' Noel Nocas (4361) RBDMS JSB 011124 DSR-1/26/24 Page 1/5 Well Name: SRF SCU 032-08 Report Printed: 1/5/2024www.peloton.com Well Operations Summary Jobs Actual Start Date:8/16/2023 End Date: Report Number 1 Report Start Date 8/15/2023 Report End Date 8/16/2023 Operation Report Number 2 Report Start Date 8/21/2023 Report End Date 8/22/2023 Operation Held PTW and PJSM, discuss plan forward \n\nCheck well Tbg/IA static. Set containment, spot in base beam, pit and pump. Filled pit with producted water R/u circulating eq. to IA. Bullhead 175bbls catch pressure, bleed to 0psi and monitored IA to pit static. Carrier arrived from KGF, spotted rig, installed rod basket. Raised and while scoping up derrick wench line #2 (off driller side) cable thimble hung-up inside the cable sheave. Scoped and L/d derrick. Removed sheave and freed cable. Inspected the cable swedge and found minor damage. Called rig mech to replace swedge. Raised and scoped Derrick, secured guy lines. R/u rod tongs and staged pulling eq. Ran air hoses to rod basket and functioned. M/u pony rod pup to polish rod. \n\nSDFN Report Number 3 Report Start Date 8/22/2023 Report End Date 8/23/2023 Operation PTW and PJSM with crew. \n\nCheck well, SITP=0psi, IA=vac Picked up on polish rod, backed the stuffing box. P/u to 35k seen travel that pump possible come of seat. L/d 6' and 2-4' pony rods. Picked up with over pull to 45k, Worked rod trying to pull free. Landed stuffing box, R/u circ eq. pressured up on tbg to 1000psi. Held worked rods pressure held at 1000psi. Surged tbg trying to break bridge down hole- no luck. Pumped 40bbls of hot water down IA. L/d Stuffing box and polish rod and made up 6' pony rod, Continued working rods made 16' then no movement. Discuss with OE approved to pull max (50K). Informed all personnel stay clear of rig floor. Worked rod pulling up to 50k. Made 5' then no movement. Cont work rod to 50k and rod string parted string weight @ 13k. Inspect derrick all good. Perp to pull rods, built containment to store. POOH L/d 77 1" Rods, 128 7/8" Rods and 4 3/4" and 1 with body part 23' down. Inspected rods 1" and 7/8" no visible issues, found stress cracks in the 3/4". Sent pictures to OE. \n\nSecured well and SDFN Report Number 4 Report Start Date 8/23/2023 Report End Date 8/24/2023 Operation PTW and PJSM, discuss plan forward with crew. \n\nCheck well pressure, Tbg/IA=0/0 Set BPV, N/u the tree. Inspected hanger no visual rod cutting. Installed test plug. P/u floor and pin back in derrick, N/u 7" BOP stack. Set koomey unit, choke house and bang board. Ran electrical. Lay out accumulator control lines and hooked up to stack. Function tested, R/u work floor, handrails and stairs. Still waiting for weavers to haul out choke/kill lines. Lay out and hooked up ck/kill line. Hooked up gas detection and RigSense, Built 2-7/8" and 3-1/2" Test Joints. Finished building containment. Finished sealing in containment. Rig died, found lose wire in harness. Repaired wire all good. Took on 20bbls of fresh water for testing R/u testing eq. Flood stack. Shell tested BOP's with 2-7/8" Test joint 250-2500psi. Good test. Report Number 5 Report Start Date 8/24/2023 Report End Date 8/25/2023 Operation PTW and PJSM, discuss plan forward with crew. Tested BOP's as per Sundry approval: Annular 250-2500psi, Rams 250-2500psi, Valves 250-2500psi. Tested gas detection and preformed accumulator drawdown test. Test good. Tested with 2 7/8" and 3 1/2" Test Jt. AOGCC witness waived by Jim Regg on Wed 8/23/2023 11:33 AM. L/d Testing eq. Pulled BPV well static. M/u landing jt with FOSV. MIRU YJ E-line unit. M/u 1-11/16" x 2' tbg puncher. Stab on landing jt with PCE. RIH tag TOF @ 5,378'. Log collars at 5,371'. Punched holes at 5,375'-77'. Tbg went on vac. Wait for tbg to equalize and POOH. L/d tools and RDMO EL. Fill pits with produced water. R/u circulating eq. Lined up to pump down tbg with IA open to pit. Pumped 86bbls and catch returns of crude with gas breaking out and hovering across pits. SD job after 114bbls pumped. Weather condition damp with no wind not favorable to take returns to rig pit. Discussed plan with crew decided to r/u flowback tank at a safe distance from any ignition source. Lay containment, R/u 400bbls defuser tank to take returns from the IA. Circulating 39bbls returns oil and gas. Weather condition unfavorable to vent on pad. S/d pump. Contacted ops, hooked up IA to flowline and circulated well to 3-9 tank setting. Circulated 189bbls of produced water at 3bpm/200psi, with returns at 8.5ppg S/d pump, calculated hole losses while circulating ~30bph. \n\nSecured well SDFN Report Number 6 Report Start Date 8/25/2023 Report End Date 8/26/2023 Operation PTW and PJSM, discussed plan forward with crews. Check well pressure, Tbg/IA on vac. R/u floor and handling eq. made 10' pup on landing jt and FOSV. Pumped 20bbls down IA monitored well static. API: 50-133-10118-00-00 Field: Swanson River Sundry #: 323-055 State: ALASKA Rig/Service:Permit to Drill (PTD) #:160-045 Page 2/5 Well Name: SRF SCU 032-08 Report Printed: 1/5/2024www.peloton.com Well Operations Summary Operation P/u on landing jt to 66k, made 1/2' turn to the left and J out of suspension hanger, no tension in tbg, (previous completion was landed with 18k in tension). Slacked off and encounter 2' of drag before tbg anchor caught entire string weight. P/u to neutral weight 62k. Made 8 turns to the right and released tbg anchor. P/u and latched back into the tbg hanger. R/u circ eq. Bullhead 32bbls down tbg at 3bpm/60psi. Swapped over to IA and bullhead 53bbls pressure increased to 1000psi. SD pump monitored well for 15mins and pressure bleed back to formation. Open IA and tbg on vac. BOLDS, had 1 lock down pin seized up and would not back out. Called out Hilcorp wellhead to repair pin and BOLDS With IA open pulled hanger off seat at 63k and pulled to rig floor, BOLD hanger and landing jt. Inspected hanger and found rod cut inside profile threads. POOH L/d 2 jts of 3-1/2" poly core tubing and racked back 2 stands. C/o handling eq, POOH standing back 2-7/8" EUE completion tbg. f/10,237' t/8,900'. Pumped double pipe displacement every 15 jt out thru IA valve. Rig engine died and would not restart, suspect overheating, troubleshot and checked temp all good. Wiggled wires and was able to restart engine but cant shift out of 1st gear. Secured well and SDFN. Call mechanic to troubleshot issue tonight. Report Number 7 Report Start Date 8/26/2023 Report End Date 8/27/2023 Operation PTW and PJSM, discussed plan forward with crew. SITP=10psi and IA=50psi. Bleed gas off tbg and IA to 0psi, R/u circ eq. Pumped 30bbls of 8.5ppg produced water down tbg and 30bbls down IA. S/d pump Tbg/IA on vac. Monitored well for 15mins Tbg/IA static. R/d circ eq. POOH standing back tbg f/8602 t/8275', rig engine shut down, troubleshot and couldn't get engine to stay running. Secured well. Called out rig mechanic. Wait on mechanic to arrive. Mechanics arrived started carrier engine, began POOH while mechanic monitor the engine. POOH f/8275 t/5600'. continuous pumping .4bpm down IA with continuous hole fill with POOH Well started U-tubing out the tbg, shut off hole fill pump and stab valve. Chech well pressure IA on vac and Tbg static. Spilled approximal 1/4bbl of oil in containment and 1/4 cup off containment. Reported spill to Hilcorp HSE. Cleaned up spill and scrubbed down containment and rig floor. R/u circ eq. Lined up pumped down tbg returns from IA valve to flowback tank. Circulated STS returns good 8.5ppg. SD IA and Tbg on vac. Continued POOH standing back tbg f/5600' t/5371' Found parted rod string. Stripped space out pups jts and BOP's over rod string. P/u on rod string to neutral wt. 8.5k. Observed the pump stroke and then pulled string to 25k over and started moving the tbg string. Slacked off and R/u the rod tongs. S/o 4k down and turned string to the left and backed off rods. P/u and string wt at ~2k. Began POOH and L/d 7 3/4" rods and rig engine died. Clamped rod string and closed rod bops. Stripped over TIW valve and secured well. SDFN. Mechanic onsite to troubleshot. Report Number 8 Report Start Date 8/27/2023 Report End Date 8/28/2023 Operation PTW and PJSM, discussed plan forward with crew. Check well pressures IA and Tbg static. Mechanic on site working to resolve issue with Carrier Motor. Crew clean and scrubbed rig. Mechanic was able to start up rig, POOH L/d began L/d 3/4" rods and rig motor shut down again. Crew continued housekeeping while mechanic troubleshoot, found faulty breaker and repaired. Rig running again POOH L/d total of 70 3/4" rods, (1750'). M/u TIW with xo to Otis. R/u YJ E-line, M/u CCL, wt bar and 1-9/16" x 2' tbg punched, 2.5" CCL to top shot. Stab on well and RIH tag 1750'. Log collars, punched hole at 1746'-48'. Tbg on vac. POOH L/d E-line R/u circ eq. Pumped 70bbls to flush tbg. R/d circ eq. R/u tongs and prep to POH. Crew preformed kick drill, responds time 56sec. POOH standing back tbg f/5371' t/7120' and found rod string. C/o handing eq. M/u space out pups and rod BOP's, P/u on rod string to 8k and seen pump stroke. Tried jarring free with pump stroke no luck. Put left hand torque in rod string worked down backed off rods. String wt 3k. POOH L/d 3/4" rods and 5 sinker bars, there is 5 (125') of sinker bars and left in the hole on top of the pump. Secured well and SDFN. Report Number 9 Report Start Date 8/28/2023 Report End Date 8/29/2023 Operation PTW and PJSM, discussed daily activities with crew, Well pressures SITP 0psi, IA 0psi M/u TIW with xo t/Otis. R/u YJ E-line, M/u CCL, wt bar and 1-9/16" x 2' tbg punched, 2.5" CCL to top shot. Stab on well and RIH tag 2998'. Log collars, punched hole at 2946'-48'. Tbg on vac. POOH L/d E-line R/u Circ eq. Pumped 30bbls down tbg. Monitor well Tbg on vac. IA static. R/d circ eq. R/u handling eq. prep floor and pull tubing POOH standing back 3000' of 2-7/8 EUE Tbg and found top of the sinker bars Backed off and L/d 5 sinker bars and the pull rod out of tbg. L/d 5 tbg joint and the Tbg anchor, Found 2' of scale on top off the pump. Built containment to L/d the the pump, seat nipple and tbg joint together. Perforated sub was scaled off. Pressure washed and cleanout slots. B/o bottom of the seating nipple and L/d the nipple, pump and 2-7/8" tbg joint together. Will tear down tomorrow and inspect. Pulled 4-1/2" mud joints from well, removed bull plug and emptied jts into 55gal drum. Sand and scale. Secured well and SDFN. Report Number 10 Report Start Date 8/29/2023 Report End Date 8/30/2023 Operation PTSM, Check well static, Breakdown & cleanout mud joints, had bottom joint full & perf joint slots were packed off, M/U mud joints, perf joint, & new seat nipple. C/O handling tools, housekeeping, & prepping backload while waiting on P110 pipe arrival. API: 50-133-10118-00-00 Field: Swanson River Sundry #: 323-055 State: ALASKA Rig/Service: Page 3/5 Well Name: SRF SCU 032-08 Report Printed: 1/5/2024www.peloton.com Well Operations Summary Operation Unload truck w/ tubing, & new 3/4" rods, backload truck, tally pipe. RIH w/4 1/2" mud joints, seating nipple, 1 Jt 2 7/8" P110 EUE 6.5# tubing, anchor, & 7 joints 2 7/8" P110 tubing t/296' M/U hanger, make dry run land out Good, pull hanger l/d same. Cont RIH w/2 7/8" 6.5# L-80 EUE 8 rd tubing from derrick t/1366'. secure well, SDFN Report Number 11 Report Start Date 8/30/2023 Report End Date 8/31/2023 Operation PTSM, Check well, tubing & IA =0, level rig. Cont. RIH w/2 7/8" 6.5# l-80 EUE 8rd completion f/1366' t/10181', L/D 2 stands 3 1/2" tubing from derrick. P/U Jts 2 7/8" 6.5 # P110 tubing, RIh t/tag @ 10408', P/U l/d joint, up wt 56k, dn wt 53k M/U hanger, & land, RILD pins, P/U "J out of hanger, RIH t/10398', rotate tubing 10 turns to left setting tubing anchor, wk out tq, set down 20k, verify set, P/U "J" back into hanger with 18k tension in string. R/U circ lines, drop standing valve, R/U & fill tubing, pressure up to test @ 1000psi, w/no luck, losing 250 psi in 2 min, make 4 attempts with same results. R/U W/L RIH & latch standing valve, P/U & let equalize, POOH recover standing valve. L/D W/L secure well SDFN Report Number 12 Report Start Date 8/31/2023 Report End Date 9/1/2023 Operation PTSM, check well pressures, IA-0 Tubing-0 Drop standing valve, change up circulating line configuration, Fill tubing, attempt to test t/1000psi, had same leak as previous test's. RIH with wireline, latch standing valve @10346' wlm in seat nipple, P/U to let flush through seat, re-set. P/T t/1000psi, with no change in outcome. P/U & let equalize, POOH L/D standing valve. RIH w/ D&D hole finder t/set at 10328' wlm, in joint above seal nipple, fill tubing & test t/ 1000psi with no luck. Move up to to set in joint above tubing anchor @ 10305' wlm, had issue with pickoff, POOH & repair & redr RIH w/ D&D hole finder,set in joint above tubing anchor 10297' wlm, fill 10 bbls& test, with same results. Release plug & pull up to 8330'wlm, set plug, fill & test. no joy, release & pull up hole t/6318'wlm set plug, fill & test w/no luck, release & pull up hole t/4335'wlm set & test t/1000psi good. POOH set & test @2320' good. POOH lost hole finder @ 834', OOH no tool, RIH recovered hole finder, POOH l/d w/l & secured well for night Report Number 13 Report Start Date 9/1/2023 Report End Date 9/2/2023 Operation PTSM, check Tubing & IA-0, fill well while re-dressing D&D hole finder. W/L RIH w/ D&D hole finder t/10,330', set same, fill & test failed, POOH, set & test @ 6348', 5860', 5390' and all fail, set @ 5015' tested t/ 1000psi good. POOH R/D w/l, Pull landing joint, set BPV, M/U test joint. Fill Surface Eq. with test water. Test BOPE as per Hilcorp & AOGCC requirements, Witness was waived By inspector Jim Regg, tested w/ 2 7/8" TJ, 250/2500, had 1 FP on Choke HCR, serviced & re-tested good. R/D test Eq. pull blanking sub & BPV. M/U landing joint. P/U "J" out of hanger, up wt 76k, RIH 44" rotate string release tubing anchor. P/U "J" back into hanger, up wt 58k BOLD pins, pull hanger to floor, L/D same. cont. POOH stand back 2 7/8" completion t/9267' Secure well, SDFN Report Number 14 Report Start Date 9/2/2023 Report End Date 9/3/2023 Operation PTSM, check well, IA & tubing 0, Cont. POOH standing back 2 7/8" completion, f/9267' t/5430', L/D singles from 5430 - 5242', found bad connection, loose on bottom of collar, Pulled & l/d t/5085' Dropped standing valve w/ball & rod, filled tubing & test t/1000psi good, Lost belt tensioner on HPU, C/O handling Eq, tally pipe, while waiting on backup to arrive. C/O HPU, & test good RIH p/u 11 singles to 5437', continue RIH w/ stands t/7397', R/U fill pipe & test t/1000psi not getting good test, open let air bleed out, re-fill with hose, re-test with same results. Secure well, SDFN Report Number 15 Report Start Date 9/3/2023 Report End Date 9/4/2023 Operation PTSM, check well GOOD Fill & attempt to test tubing while W/L r/u, no luck testing RIH latch ball & rod on standng valve assy, equalize & POOH f/7327'wlm RIH w/ D&D hole finder t/ 7327', set, fill tubing & test good. POOH, l/d wireline. API: 50-133-10118-00-00 Field: Swanson River Sundry #: 323-055 State: ALASKA Rig/Service: Page 4/5 Well Name: SRF SCU 032-08 Report Printed: 1/5/2024www.peloton.com Well Operations Summary Operation Cont. TIH w/ 2 7/8" 6.5# eue 8rd completion t/10385' M/U hanger, & land, RILD pins, P/U "J out of hanger, RIH t/10404', rotate tubing 8 turns to left setting tubing anchor, wk out tq, set down 20k, verify set, P/U "J" back into hanger with 18k tension in string. C/O landing Joint, R/U w/l, RIH w/D&D hole finder t/10333' wlm, Set, Fill & test t/ 1200psi good Release plug, sheared off POOH,, RIH latch D&D plug wk free POOH R/D wireline. R/D circulating lines, Pull landing joint, Install BPV, clear wk area for staging rods in AM, secure well, SDFN Report Number 16 Report Start Date 9/4/2023 Report End Date 9/5/2023 Operation PTSM, Check well good Clear & r/d floor, n/d BOPE, Inspect wellhead. install adaptor & master vavle, test void t/5k good, level master valve. install flow cross, rod BOPE & wk table, stage rods, r/u handling eq. P/U pump assy, stroke pump & test good, install dip tube, RIH, P/U guides & sinker bar's, Checking tq with tq. cards. Prep & p/u 3/4" rods, dial in rod tongs for correct torque, make adjustments to HPU to make consistent. Continue p/u 3/4" rods RIH.t/2642', install polish rod & stuffing box secure well for night. Report Number 17 Report Start Date 9/5/2023 Report End Date 9/6/2023 Operation PTSM, check well good, Pull polish rod & stuffing box, install wk table & stripper, Cont. RIH p/u 3/4" rods f/2642' t/5167' (194 rods) RIH w/ 3 stands 3/4" rods, l/d same C/O handling eq. for 7/8" rods, dial tq in to accommodate same. Cont. RIH w/ 7/8" rods t/8342' 127 rods C/O handling Eq. adjust tongs for 1" rod tq. run RIH P/U 1" rods, t/10334' tag, P/U & space out w/ 20' of 1" full guided rod pups, strip off wk table & install polish rod & stuffing box, secure well for night. Report Number 18 Report Start Date 9/6/2023 Report End Date 9/7/2023 Operation PTSM, check well good Check rod stroke & plumb with the rig, Check space out, add 2' pup. stroke pump & PT t/1050psi good, clamp polish rod, cut rig loose. Cont. breaking down rig eq. move to Paxton 7, prep & scope down mast, lay over same, prep for loadout, load up aux rig eq. & rig, mobe to Paxton pad. Report Number 19 Report Start Date 9/20/2023 Report End Date 9/21/2023 Operation Report Number 20 Report Start Date 12/8/2023 Report End Date 12/9/2023 Operation PJSM and approved PTW. Removed snow around wellhead. Contiued transporting 401 rig package from Beaver Creek. Built containment. Spot base bean and carrier. Hooked up blow down lines from tbg/csg to the Johnson tank. Spot co man trailer, bang board and gen. Set in fuel tank. Set and r/u pit and pump. R/u circ eq. IA=60psi, SITP 150psi. ran hoses from IA to johnson tank. Bled off IA all gas. R/u to pump down IA. Filled pits with hot water. Pumed 128bbls down IA pressure up 400psi, S/d monitored IA bleed to 0psi then on Vac. Crew change head PJSM. Contiued installing winterization. Raised and scoped up derrick. Level rig, secure guy lines.R/u blowdown line to Tbg. Report Number 21 Report Start Date 12/9/2023 Report End Date 12/10/2023 Operation Bled off tbg pressure to johnson tank. install work floor, R/u handling eq. Bout stuffing box and L/d polish rod, up wt 13k. POOH with 1" and 7/8" rodsrting and visualy inspecting for damage. Found the first 3/4" rod parted 22.5' down right above a guide. M/u 2-5/16" OS loaded w/3/4" grapple, 4' stab bar. RIH picking up 7/8" and 1" rod string. Tag fish at 5203'. Beat down on fish to slide the 3/4" rod guide down and latched fish. Pickup 22k on rod string and unseated pump, tbg on vac. Pumped 53bbls of hot PW down tbg. POOH L/d 7/8' and 1" rods 103 out at reort time. Report Number 22 Report Start Date 12/10/2023 Report End Date 12/11/2023 Operation Contiued L/d 1" and 7/8" rods. Recovered OS, L/d total of 48 3/4" rod and began hang back in basket. L/d 10 sinker bars and rod pump. Stroke pump and inspect. found pump having issues stroking and L/d pump. P/u new insert rod pump, RIH p/u 12 sinker bars, 3/4" rods=146, 7/8 rods= 144. Start P/u 1" rods at report time. Report Number 23 Report Start Date 12/11/2023 Report End Date 12/12/2023 Operation Cont RIH p/u 1' rods = 110. Tag seat nipple and space out rod string with 2', 4' and 8' pony rods. P/u polish rod and m/u stuffing box. API: 50-133-10118-00-00 Field: Swanson River Sundry #: 323-055 State: ALASKA Rig/Service: Page 5/5 Well Name: SRF SCU 032-08 Report Printed: 1/5/2024www.peloton.com Well Operations Summary Operation Fluid packed Tbg with 16bbls, Stroked pump and pressure up to 1000psi-good test. opened retruns to johnson tank, pumped BU (35bbls) with rig all good. Scoped and L/d derrick, R/d eq. and moved to KGF. API: 50-133-10118-00-00 Field: Swanson River Sundry #: 323-055 State: ALASKA Rig/Service: Updated by DMA 01-05-24 Well: SCU 32-08 PTD 160-045 API: 50-133-10118-00-00 SCHEMATIC RKB: 143’/ GL: 128’ AMSL New KB – THF: 15.00’ TD = 10,828’ PBTD = 10,631’ PBTD ±10,631’ DV @ 1,308’ DV @ 7,996’ Bad Casing @ 10,634’ 1 2 3 4 5 6 CASING DETAIL Size WT Grade Conn ID Top Btm 22” - - - - Surface 28’ 13-3/8” 54.5 J-55 8RD 12.615” Surface 1,308’ 54.5 J-55 8RD 12.615” 1,310’ 3.014’ 6-5/8” 28 P-110 8RD 5.791” Surface 115’ 24 N-80 BTC 5.921” 115’ 6,477’ 24 P-110 8RD 5.921” 6,477’ 7,996’ 24 P-110 8RD 5.921” 7,998’ 10,037’ 28 P-110 8RD 5.791” 10,037’ 10,828’ TUBING DETAIL Size WT Grade Conn ID Top Btm When new 3-1/2” Poly-Lined 9.84 L-80 TPL 4040 2.347” Surface 211’ 3/18/22 2-7/8” 6.5 P-110 8RD 2.441” 211’ 2,206’ 3/18/22 2-7/8” 6.5 L-80 8RD 2.441” 2,206’ 10,416’ 12/7/12 JEWELRY DETAIL (3/18/22) # Depth ID When new Description 1 19’2.441”3/18/22 Tubing Hanger J-Latch Tension hanger 2 2,937’2.441”2001 Marker Sub for IA FL shots 3 10,282’2.441”12/5/12 Tubing Anchor (Weatherford BA) 4 10,348’2.225”Seating Nipple 5 10,349’-Perforated Joint (66’) 6 10,415’-Bull Plug / end of assembly ROD DETAIL (12/11/23) Depth Length When new Description -46’12/11/23 Polish Rod 57’14’12/11/23 1”EL Pony Rods (8’, 4’, 2’) 71’2750’12/11/23 1” EL Sucker rods w/ 4 per XL guides (110ea) 1,996’3600’12/11/23 7/8” EL Sucker rods w/ 4 XL guides per rod (144) 5,196’3650’12/11/23 3/4” EL Sucker rods w/ 4 XL guides per rod (146) 10,046’175’12/11/23 1.5in Sinker Bars (7) and stabilizer bars (4) 120’12/11/23 Stabilizer/Sinker Bars 10,338’40’12/11/23 Rod Pump, insert 10,353’ 15’ Dip Tube:Bottom 1’ is perforated at 10,363’ MD. 10+’ from Perf joint to dip tube inlet PERFORATION DETAIL ON NEXT PAGE MAX HOLE ANGLE = 3° @ 7,004’ FISH DETAIL ON NEXT PAGE TBG Anchor fish @ 10,423’ (12/4/12) Prime Mover: Weatherford Rotaflex 1100-500-306” (set in 2001) SL tagged sand ~40’ below seating nipple at 10,388’ MD (3/18/22) Updated by DMA 01-05-24 Well: SCU 32-08 PTD 160-045 API: 50-133-10118-00-00 SCHEMATIC FISH DETAIL # Depth Length ID OD Description F I S H 10,423’ 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) 4.09’ 2.375 4.25 Chemical Injection Sub 39 3.438 4.4 Screen Assembly 0.008” 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug (Bottom f Fish) PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376’ 10,396’ 10,373' 10,393' 20’ Perforated October 2011 2/20/1961 WSO 10,496’ 10,497’ 10,493' 10,494' 1’ Squeezed 10-12-1985 10/16/1985 H1 10,516’ 10,518’ 10,513' 10,515' 2’ Re-perf 08-18-01 10/1/2011 H1 10,518’ 10,533’ 10,515' 10,530' 15 Re-perforated October 2011 10/16/1985 H1 10,518’ 10,520’ 10,515' 10,517' 2’ Re-perf 08-18-01 / 10-02-2004 2/21/1961 H1 10,520’ 10,529 10,517' 10,526' 9’ Re-perf 10-16-1985 / 06-10-1995 / 08-18-2001 / 10-02-2004 2/21/1961 H1 10,529’ 10,530’ 10,526' 10,527' 1’ Re-perf 10-16-1985 10/16/1985 H1 10,530’ 10,532’ 10,527' 10,529' 2 8/18/2001 H2 10,543’ 10,545’ 10,540' 10,542' 2’ 10/16/1985 H2 10,545’ 10,546’ 10,542' 10,543' 1’ Re-perf 08-18-01 10/1/2011 H2 10,545’ 10,566’ 10,542' 10,563' 21’ Re-perforated October 2011 6/10/1995 H2 10,546’ 10,550’ 10,543' 10,547' 4’ Re-perf 10-16-1985 / 08-18-2001 / 10-02-2004 2/21/1961 H2 10,550’ 10,560’ 10,547' 10,557' 10’ Re-perf 10-16-1985 / 06-10-1995 / 08-18-2001 / 10-02-2004 2/21/1961 H2 10,560’ 10,569’ 10,557' 10,566' 9’ Re-perf 10-16-1985 / 06-10-1995 / 08-18-2001 2/21/1961 H2 10,569’ 10,572’ 10,566' 10,569' 3’ Re-perf 10-16-1985 2/21/1961 H2 10,572’ 10,575’ 10,569' 10,572' 3’ Sqzd 10-16-1985 2/21/1961 H3 10,580’ 10,584’ 10,577' 10,581' 4’ Sqzd 10-16-1985 10/16/1985 H3 10,585’ 10,592’ 10,582' 10,589' 7’ 2/21/1961 H3 10,592’ 10,600’ 10,589' 10,597' 8’ Re-perf 10-16-1985 2/21/1961 H3 10,600’ 10,603’ 10,597' 10,600' 3’ Sqzd 10-16-1985 2/21/1961 H3 10,608’ 10,616’ 10,605' 10,613' 8’ Sqzd 10-16-1985 2/21/1961 H3 10,622’ 10,631’ 10,619' 10,628' 9’ Sqzd 10-16-1985 2/21/1961 H4/5 10,622’ 10,678’ 10,619' 10,674' 56’ Sqzd 10-16-1985 2/20/1961 WSO 10,681’ 10,682’ 10,677' 10,678' 1’ Sqzd 10-16-1985 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Jacob Flora To:Donna Ambruz Subject:FW: [EXTERNAL] RE: SCU 32-08 RWO (Pump Change) (PTD: 160-045) (Sundry: 322-055) Stuck pump, request to NU BOP & pull tubing Date:Wednesday, August 23, 2023 8:11:39 AM From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, August 23, 2023 8:09 AM To: Jacob Flora <Jake.Flora@hilcorp.com> Subject: RE: [EXTERNAL] RE: SCU 32-08 RWO (Pump Change) (PTD: 160-045) (Sundry: 322-055) Stuck pump, request to NU BOP & pull tubing Jake, Hilcorp has authorization to proceed with your plan below, with the following condition of approval: After shooting holes in tubing, bullhead crude oil from tubing with KWF, then bullhead the annulus with KWF to flush all hydrocarbons from the entire wellbore before pulling tubing. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Tuesday, August 22, 2023 6:49 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Re: [EXTERNAL] RE: SCU 32-08 RWO (Pump Change) (PTD: 160-045) (Sundry: 322-055) Stuck pump, request to NU BOP & pull tubing Bryan, I will send BOP diagram in am. I know it’s the same 7” stack w 2-7/8 to 3-1/2 VBRs that we have been using. 323-055 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Good questions, please see responses below: With the pump stuck in the seat nipple, the tubing is full of fluid- We plan to tubing punch as needed to not pull wet tubing. We could attempt to circulate thru the punches, however the well keeps a static level of around 6000’ from surface and it would likely all go into the formation. We did bullhead the IA with water and it went on a vac. After pulling tubing to the top of the rods and exposing the first rod coupling we will place the tubing in the slips, pick up on the rod elevators, pull tension on the rods and work left hand torque into the rod string until it backs off, hopefully deep. Then pull the free rods from the tubing, and then pull tubing to the next rod back off point. This “stripping” process is repeated until all rods and tubing are removed from the well. This afternoon we pulled the parted rods from the well and now know that it parted on the 5th 3/4” rod in the body, at about 5300’ MD. Let me know if you have any further questions. We appreciate your response, I know your engineering staff is in training this week. Jake On Aug 22, 2023, at 5:58 PM, McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> wrote: Please submit BOP diagram. In step 4, what action do you plan to “repeat until pump is recovered”? Could you describe what you are planning to do after getting to the top of the rods? Should you punch holes in the tubing above rods so you can circulate if needed and get rid of oil from the tubing? Do you have circulation? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 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. <image002.jpg> From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Tuesday, August 22, 2023 11:56 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: SCU 32-08 RWO (Pump Change) (PTD: 160-045) (Sundry: 322-055) Stuck pump, request to NU BOP & pull tubing Hello Bryan, We have 401 on this well now and are unable to pull the rod pump. It appears to be stuck at the seat nipple or just above. We are suspecting debris from the previous workover has fallen downhole and wedged near the top of the pump. Our option to continue the workover is now to backoff and strip tubing/rods from the well. Hilcorp requests permission to perform the below steps: 1. Put left hand torque in the rod string, back off and pull the rods to the backoff point. We will work the torque down and hopefully get a deep backoff near the pump. 2. NU & test BOPs to 2500 psi 3. Pull tubing to the rods 4. Repeat until the pump is recovered 5. Re-run tubing/completion 6. Run new rod pump, test 7. RDMO <image003.png> 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 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Rod Job, Pull Pump 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,828'10,423' (fish) Casing Collapse Structural Conductor Surface 1,130 psi Intermediate Production 5,760 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng N/A N/A 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: AOGCC USE ONLY Jake Flora, Operations Engineer jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 February 7, 2023 Tubing Grade: 9.84* / L-80 Tubing MD (ft): 211Perforation Depth TVD (ft):Tubing Size: 3-1/2" 6.5# / P110 - L-80 2,206' - 10,416'See Schematic See Schematic 2-7/8" N/A N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028996 160-045 50-133-10118-00-00 Swanson River Hemlock Oil Same CO 123B Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Soldotna Creek Unit (SCU) 32-08 Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 10,824'10,631'10,628'~1,475psi N/A MD 2,730 psi 28' 3,013' 28' 3,014' Perforation Depth MD (ft): 10,828'6-5/8" 22" 13-3/8" 28' 3,014' 7,440 psi10,824'10,828' m n P s 66 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 2:41 pm, Jan 27, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.01.27 13:37:10 -09'00' Noel Nocas (4361) 10-404 DSR-1/30/23BJM 2/1/23 SFD 2/1/2023GCW 02/02/23JLC 2/2/2023 Brett W. Huber. Sr.Digitally signed by Brett W. Huber. Sr. Date: 2023.02.02 12:23:56 -09'00' RBDMS JSB 020323 SCU 32-8 Rod Swap Well Name: SCU 32-8 API Number: 50-133-10118-00-00 Current Status: Rod Pump Oil Producer Permit to Drill Number: 160-045 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375(C) Second Call Engineer: Chad Helgeson (907) 777-8405 (907) 229-4824 (C) Max. Expected BHP: ~2,535 psi @ 10,600’ TVD Memory gauge at 10,300’ TVD built up to 2235psi after 14 days SI on 12/13/16. Extrapolated to 2400psi. Used 0.45psi/ft from there to bottom-perf. Max. Potential Surface Pressure ~1475 psi Based on 0.1 psi/ft to surface Well Summary SCU 32-8 is a Hemlock oil producer. It’s had a rod pump completion since 2001. The well has required periodic RWO’s to repair parted rods, pump issues, and occasionally tubing issues with all new rods installed in 2019. A 2022 workover found a rod part between the polish rod and the first pony rod. The damaged coupling was replaced without pulling the pump and after moving the rig off the well failed to pump fluid with a high stack- out tag seen on the stroke. The objective of this sundry is to pull and replace the pump which is believed to be the culprit. This sundry does NOT cover any tubing / BOP work. If problems are found beyond rods/pump, the plan would be to RDMO rig 401 and troubleshoot from there. The downhole reservoir configuration hasn’t been changed in this well since 2011, and no productivity enhancements nor changes have occurred. Wellbore History o 2022 RWO September Replaced polish rod and two pony rods (did not pull pump), failed to o 2022 RWO March Replaced upper 2200’ of tubing Caliper indicated lower section of tubing in good condition Installed 3-1/2” Poly-lined tubing in top 200’ o 2019 RWO: Installed all new rods o 12/12/12: Well passed its most recent AOGCC NFT o 2012 RWO attempted to mill / retrieve fish from below 10,400, but was ultimately unsuccessful, and left fish downhole. No reservoir changes occurred o 10/1/11: last reservoir modification: G-zone perfs added x Safety system: o Well operates without a traditional SSV system per AOGCC (see attached) o Well is equipped with functionally equivalent components per attached letter from 9/24/13 SCU 32-8 Rod Swap Replace Rods and/or Pump Procedure: 1. Ensure Rotoflex surface pump unit is uncoupled, skidded back, and the motor is LOTO 2. MIRU Hilcorp rig #401 3. Bleed down any residual tubing and IA pressure 4. Pump 260 bbls produced water down IA, this will place the annulus on a vacuum 5. Fluid pack tubing with produced water. If unable to fluid pack, pump tubing volume of 55bbls. 6. Verify no flow before ND packoff/stuffing box (BOP not required for rod pulling / running) 7. Latch rods, unseat pump 8. Pump down the tubing to clean rods 9. POOH racking back rods to pump 10. LD pump and inspect 11. RU slickline, tag TD with bailer, investigate for scale and solids inside mud anchor 12. PU new pump, run pump and rods 13. Space out rods, land pump 14. Install polish rod, packoff and stuffing box 15. PT tubing to 1000psi, stroke pump with rig 16. RDMO Rig #401 17. Roll up Rotoflex pumping unit, recouple, and remove LOTO 18. Return well to production with same surface safety systems as previously installed Note: If rod string is to be left across the wellhead, either the well must be manwatched, OR the polish rod stabbed back on to the rod string and the packoff/stuffing box reinstalled. Attachments: 1. Current wellhead drawing (no changes) 2. Current Schematic (no changes) 3. NFT (3/18/2013) 4. SVS letter (9/24/13) 5. Aerial 660’ map 6. RWO sundry change form By Anne Prysunka at 8:14 am, Oct 17, 2022 6ZDQVRQ5LYHU 6&8&XUUHQW &DVLQJ KHDG 6KDIIHU .' 0 ; 62: Z ¶/32 ¶ FDVLQJ KXQJ RI ZLWK .' VOLSV DQG SDFNRII DVV\ 7XELQJ KHDG 6KDIIHU 7/ 0 ; 0 Z 0662 ¶7\SH VHFRQGDU\ VHDO LQ KHDG &RPSOHWLRQ VSRRO 6HDERDUG6 0)(;0 )( QR RXWOHWV RQ KHDG $GDSWHU 6HDERDUG 0 ; 0 Z ¶33VHDOSRFNHWò FRQWURO OLQH H[LW 9DOYH :.00 0 )( +:2 $$ 4W\ 9DOYH :.00 ¶/32 +:2 $$ 9DOYH PDVWHU :.0/ 0 )( +:2 $$ WULP &URVV VWGG 0 ; 0 &RPSDQLRQ IODQJH 0 ;(8( 9DOYH ZLQJ &,:)/ 0 +:2 $$ WULP 7XELQJ KDQJHU 6HDERDUG 7HQVLRQ W\SH ; (8( UG OLIW DQG (8( VXVS Z ¶W\SH+ %39 SURILOH ¶FRQWURO OLQH H[LW OHIW WR UHOHDVH ULJKW WR FDWFK 6ZDQVRQ 5LYHU 6&8 ; ; Updated by DMA 03-31-22 Well: SCU 32-08 PTD 160-045 API: 50-133-10118-00-00SCHEMATIC RKB: 143’/ GL: 128’ AMSL New KB – THF: 15.00’ TD = 10,828’ PBTD = 10,631’ PBTD ±10,631’ DV @ 1,308’ DV @ 7,996’ Bad Casing @ 10,634’ 1 2 3 4 5/6 7 CASING DETAIL Size WT Grade Conn ID Top Btm 22” - - - -Surface 28’ 13-3/8” 54.5 J-55 8RD 12.615”Surface 1,308’ 54.5 J-55 8RD 12.615”1,310’3.014’ 6-5/8” 28 P-110 8RD 5.791”Surface 115’ 24 N-80 BTC 5.921” 115’6,477’ 24 P-110 8RD 5.921”6,477’7,996’ 24 P-110 8RD 5.921”7,998’10,037’ 28 P-110 8RD 5.791”10,037’10,828’ TUBING DETAIL Size WT Grade Conn ID Top Btm When new 3-1/2” Poly-Lined 9.84 L-80 TPL 4040 2.347”Surface 211’ 3/18/22 2-7/8” 6.5 P-110 8RD 2.441” 211’2,206’3/18/22 2-7/8” 6.5 L-80 8RD 2.441”2,206’10,416’12/7/12 JEWELRY DETAIL (3/18/22) #Depth ID When new Description 1 19’2.441”3/18/22 Tubing Hanger J-Latch Tension hanger 2 2,937’2.441”2001 Marker Sub for IA FL shots 3 10,282’2.441”12/5/12 Tubing Anchor (Weatherford BA) 4 10,348’2.225”Seating Nipple 5 10,349’-Perforated Joint (6’) 6 10,355’-4-1/2” Tubing IBT (60’) 7 10,416’-Bull Plug / end of assembly ROD DETAIL (3/19/22) Depth Length When new Description -40’Polish Rod (reused for March-2022 RWO) 55’16’3/19/22 1” x 8’ EL Pony Rods with no guides (2) 71’175’10/28/19 1” EL Sucker rods w/ no guides (7) 246’1,750’10/28/19 1” EL Sucker rods w/ 4 guides per rod (70) 1,996’3,200’10/28/19 7/8” EL Sucker rods w/ 4 XL guides per rod (128) 5,196’4,850’10/28/19 3/4” EL Sucker rods w/ 4 XL guides per rod (194) 10,046’85’Sinker Bars (10) and stabilizer bars (4) 10,306’42’3/19/22 Rod Pump 10,348’15’Dip Tube: Bottom 1’ is perforated at 10,363’ MD. 10+’ from Perf joint to dip tube inlet PERFORATION DETAIL ON NEXT PAGE MAX HOLE ANGLE = 3° @ 7,004’ FISH DETAIL ON NEXT PAGE Top of fish @ 10,423’ Prime Mover: Weatherford Rotoflex SL tagged sand ~40’ below seating nipple at 10,388’ MD (3/18/22) Updated by DMA 03-31-22 Well: SCU 32-08 PTD 160-045 API: 50-133-10118-00-00 SCHEMATIC FISH DETAIL # Depth Length ID OD Description F I S H 10,423’ 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) 4.09’ 2.375 4.25 Chemical Injection Sub 39 3.438 4.4 Screen Assembly 0.008” 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug (Bottom f Fish) PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376’ 10,396’ 10,373' 10,393' 20’ Perforated October 2011 2/20/1961 WSO 10,496’ 10,497’ 10,493' 10,494' 1’ Squeezed 10-12-1985 10/16/1985 H1 10,516’ 10,518’ 10,513' 10,515' 2’ Re-perf 08-18-01 10/1/2011 H1 10,518’ 10,533’ 10,515' 10,530' 15 Re-perforated October 2011 10/16/1985 H1 10,518’ 10,520’ 10,515' 10,517' 2’ Re-perf 08-18-01 / 10-02-2004 2/21/1961 H1 10,520’ 10,529 10,517' 10,526' 9’ Re-perf 10-16-1985 / 06-10-1995 / 08-18-2001 / 10-02-2004 2/21/1961 H1 10,529’ 10,530’ 10,526' 10,527' 1’ Re-perf 10-16-1985 10/16/1985 H1 10,530’ 10,532’ 10,527' 10,529' 2 8/18/2001 H2 10,543’ 10,545’ 10,540' 10,542' 2’ 10/16/1985 H2 10,545’ 10,546’ 10,542' 10,543' 1’ Re-perf 08-18-01 10/1/2011 H2 10,545’ 10,566’ 10,542' 10,563' 21’ Re-perforated October 2011 6/10/1995 H2 10,546’ 10,550’ 10,543' 10,547' 4’ Re-perf 10-16-1985 / 08-18-2001 / 10-02-2004 2/21/1961 H2 10,550’ 10,560’ 10,547' 10,557' 10’ Re-perf 10-16-1985 / 06-10-1995 / 08-18-2001 / 10-02-2004 2/21/1961 H2 10,560’ 10,569’ 10,557' 10,566' 9’ Re-perf 10-16-1985 / 06-10-1995 / 08-18-2001 2/21/1961 H2 10,569’ 10,572’ 10,566' 10,569' 3’ Re-perf 10-16-1985 2/21/1961 H2 10,572’ 10,575’ 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Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Rod Pump Repair Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic and printed data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,828 feet N/A feet true vertical 10,824 feet 10,423 (fish) feet Effective Depth measured 10,631 feet N/A feet true vertical 10,628 feet N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation depth Measured depth True Vertical depth 3-1/2" 9.84* / L80 211' MD 211' TVD Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / P110 - L-80 2,206' - 10,416' MD 2,206' - 10,413' TVD Packers and SSSV (type, measured and true vertical depth)N/A; N/A N/A; N/A N/A; N/A N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title:Contact Phone: N/A 3. Address: Soldotna Creek unit (SCU) 32-08 measuredPlugs Junk measured N/A See attached schematic See attached schematic measured true vertical Packer Oil-Bbl Gas-Mcf STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 160-045 50-133-10118-00-00 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA 028996 Swanson River Field / Hemlock Oil Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 186 150 0 Water-Bbl 0 186 Ryan Rupert, Operations Engineer 322-090 117 0 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 43 0 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ryan.rupert@hilcorp.com 907-777-8503Dan Marlowe, Operations Manager, 907-283-1329 t Fra O 6. A PG , R Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 2:54 pm, Mar 31, 2022 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.03.31 14:44:07 -08'00' Dan Marlowe (1267) DSR-3/31/22 RBDMS SJC 041222 Rig Start Date End Date 3/8/22 3/21/22 Held PJSM. Inspected Derrick, observed the drill line rubbing against the pulley system that was added for the 401 man rider. L/d 25 1" Rods stands from basket with the tugger line. Prep carrier, Scoped and Lay down Derrick. Broke down rod stands on the ground. Moved equipment around with winch truck, moved out 401 and loaded on trailer. Sent Rig to D&D to make repairs awaiting approve drawling form Inspections. Housekeeping around Pad. Well secure SDFN, No night watch required while rig is being repaired. 03/11/2022- Friday Rig being repaired at D&D shop. 03/12/2022 - Saturday Continued working on rig repairs at D&D yard, Inspected and prepared rig to haul back to location in the AM. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 32-08 50-133-10118-00-00 160-045 03/09/2022 - Wednesday Held PJSM, discussed sundry and working with Rod's. Warmed equipment, TP=0psi, SICP=0psi, Attempted to fill tbg with Vac truck but unsuccessful, Set in dragon heater, pit, pump and choke manifold. R/u circ eq, Pumped 61bbls of 150deg PW down tbg @ 2bpm/100psi, SD pump well ck tbg static, R/d circ eq. P/u Rod handling eq, B/o Stuffing box and pulled rod pump off-seat, PU rod sting wt @ 24k, L/d 2-8' pony rods, pony rod coupling underneath the polish rod was severely wore from rubbing the Tbg hanger, M/u stuffing box and polish rod and secured well. R/u circ eq, with IA opened pumped 150deg PW down tbg and caught returns up IA 8.4 PW, Appears tbg leak is at surface, SI Tbg and pumped 2bbls down IA and pressured up to 400psi, monitored leakoff @ 100psi/min. Ck well for flow, static. B/o Stuffing Box and L/d the Polish Rod, R/u work floor and tools. POOH w/rod string completion f/10,357't/8,391', hanging back rod string in rod basket. Derrick man heard a noise coming from the Derrick Crown. Stop work to inspect crown, found drill line rubbing against support beam and possible sheave damage. M/u Polish Rod and Stuffing Box to secure well, SDFN. Night Rig watch on tower. Mechanic will be out in the AM to Troubleshot issue. 03/10/2022 - Thursday 03/08/2022 - Tuesday Held PJSM with Crew and discussed daily activities. Split up crew and finished cleanup and assist with flowline on SRU 21- 34. Graded pad to prepare for rig acceptance. Offloaded Trailers and arranged eq on Pad. Lay out containment for Rig and Eq. Set in and spotted Rig Beam, Spotted 401, Installed Rod Basket in Derrick, Serviced rig, Raised and Scoped Derrick, secured guy lines. P/u and Inspected Rod handling tool, Hooked up Tbg/IA to Bleed Trailer, SITP=150psi/SICP=150psi, Bled off gas head, SDFN, Night Rig Watch on Tower. Rig Start Date End Date 3/8/22 3/21/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 32-08 50-133-10118-00-00 160-045 PJSM and discussed daily activities. Warmed up equipment and walk arounds. SI Tbg/IA=0psi, Set BPV, N/d Tree and inspected lift threads, M/u blanking sub, prep wellhead and N/u 7 1/16" triple stack BOP's. Torqued stack, M/u Kill/Ck lines and control lines, function tested BOP's. R/u work floor, handrails and stairs, installed winterization around rig and equipment, built 2-7/8" and 3-1/2" test joints. M/u test 2-7/8" Test Jt and eq. Flood stack and circulated air out, Shell tested BOP's had leak off, Started troubleshooting, chased leak path to the Tbg hanger, B/o blanking sub and dressed and retightened, dumped 1 sack of bar on top the hanger, pressured up and repeated several times until pressure flat lined. Tested BOPE per sundry as following: Annular 250-2500psi, Rams 250-2,500psi, Valves 250-2500psi. Used 2-7/8 and 3- 1/2" Test Joint. Preformed Koomey drawdown and tested gas detection, all good. Charts and closure times noted in well file folder. Witness waived by Jim Regg via email on 03/14/22 @ 11:19pm. Blew lines dry, R/d Testing eq, secured well. SDFN. 03/13/2022 - Sunday Held PJSM, Discussed daily activities. Hauled carrier from D&D to locations, Moved Generator, bang board and fuel tank, squared up base beam with rotaflex unit. Off loaded carrier and spotted same, raised and scoped out derrick, secured guy lines, R/u work floor and rod handling tools. Well check, Tbg/IA on slight vac, L/d Polish rod and stuffing box, M/u stripper head, POOH hung back 5 triples of 7/8" and lost air supply to foot control in rod basket. Troubleshot found found 1 side of the 3-way plugged off. Continue POOH w/ hung back 128 7/8" rods and 71 3/4" rods. Motorman noticed the right angle drive was overheating, SD rig checked the temp at 408 degs, Contacted mechanic. Let right angle drive cool down. R/d rod stripper head, M/u polish rod and stuffing box, secured well. Mechanic's on site and replace right angle drive. 03/14/2022 - Monday PJSM, and discussed daily activities. Warmed rig, Inspected repair work made to the right angle drive. POOH hanging back 3/4" rods, L/d sinker bars, stabilizer bars and rod pump, broke 1' dip tube. Note: No wear on box's or guides, pump stroke was smooth, sign of wear or washing on the pump mandrel. Some of the the on the dip tubs. Cleaned rig floor, spotted Vac truck and hook up pump line to the Tbg and pumped 20bbls of 150 deg water. Monitored tbg on vac. MIRU SL, Tested lubricator to 1,500psi-good test, RIH w/2.38" GR to 10,300'slm, POOH-no issues, M/u full tbg drift wire scratcher, RIH worked scratcher several time f/ surface t/ 2,000' while flushing tbg with 150deg water, POOH L/d scratcher, observed no paraffin wax buildup on scratcher. Discussed with caliper service hand and decided tbg was clean to run the caliper log. M/u Caliper Log Tool, RIH t/10,300' @ 150fpm, POOH 50fpm logging f/10,300, t/surface, @ 2,000' slowly gravity feed 150deg PW @.5bpm down Tbg, Note SL weight increase while feeding fluid, L/d tools and lubricator, note some paraffin build on top of caliper tool. RDMO SL, secured well. Download and sent caliper reading in for processing. 03/15/2022 - Tuesday Rig Start Date End Date 3/8/22 3/21/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 32-08 50-133-10118-00-00 160-045 03/16/2022 - Wednesday Held PJSM, Warmed equipment and walk arounds. Shut-in Tbg/IA 0psi, Pulled BPV, R/u circulating eq. lines to IA, Began pumping down IA to formation @ 2bpm, caught pressure after 120bbls away. Lined up taking return form to tbg to the gas buster, cont rev circulating @ 3.5bpm/750psi. Pumped 341bbls, SD pump, monitored well static. MIRU EL, assembly 1- 11/16" RCT, hung WL sheave and brought tools to rig floor, attempted to RIH and set down 2' below the Tbg, worked tools no progress, reconfigured tools, shorten landing jt and made several attempts no progress. M/u 2.30" tapered LIB and Tap down on tbg restriction, metal maker on side of LIB. Arranged Floor, marked landing jt to orientate suspension hanger, P/u on elevators to string wt @ 58k, anchor appears to be released, Rotated pipe 1/4" turn and J-out of hanger, attempted to RIH w/WL tools and tagged in same spot 2' below hanger. RDMO AK EL. Slacked off 4' on completion string and started taking weight on tbg anchor, P/u to 58k and J-back into hanger, Anchor appears to sliding, held PJSM BOLDS, cleared rig floor, Pulled Hanger off seat @ 56k, P/u 3' string weight increased to 70k pulling into Anchor, S/o and landed hanger. RILDS. Secured well and SD equipment. 03/17/2022 - Thursday PJSM, warmed and checked eq. R/u pollard SL, M/u 1.90" swage, RIH tagged 2' below hanger, Beat down w/ spang jar and worked through tbg obstruction, M/u 2.30" LIB RIH set down @ 2' tab on LIB POOH metal marks on one side of LIB. M/u (Dummy RCT Tool) 1.90 swage w/1-3/4" wt bars and spang jar, total tool length 38', RIH to 300' no issues, POOH, M/u 2.225" swage RIH tagged 2', worked swage w/jars and work through tight spot. R/d SL and stand by on Pad. M/u 2- 7/8" Landing jt with pump-in sub and M/u Kelly hose, MIRU AK EL, M/u 1-11/16" RCT assembly, RIH and cut tbg @ 306'. Pumped 2bbls down tbg to cool down cutter. POOH, L/D Tools all good, RDMO AK EL. BOLDS, M/u 2 7/8" handling tools, Pulled Hanger off seat to rig floor, PUW 9k. Tbg was severely rod cut from bottom off the hanger 6' down on the 1st joint, L/d Hanger and jt #1 together, POOH L/d 9jts and 6'cut joint. Tally 10jt of 2-7/8" P110 8rd tbg, M/u 4 11/16" Overshot w/cut lip guide dressed to catch 2-7/8". RIH tagged TOF 308', latched fish P/u to 58k, turned pipe 8 rounds to the right and released anchor string weight @ 49k. POOH Racking back 5 stands of 2-7/8" P110. L/d fishing BHA and cut Jt. POOH L/d 60 more joints of 2-7/8" L-80. Total of 70 joints L/d (2215'). PUW 40k, Set the Tbg anchor pulled 10k over and set in slips, leave tbg in tension over night to test anchor. Rig Start Date End Date 3/8/22 3/21/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 32-08 50-133-10118-00-00 160-045 03/18/2022- Friday PJSM, warmed eq. Check well Shut-in Tbg/IA static. R/u Pollard S/L, RIH w/2" Drive down bailer, locate and worked thru rod pump seating nipple, tagged 42' down inside 4-1/2" mud joints, worked bailer. POOH, recover cup size of packed formation sand, made 2 more bailer runs not making hole. Discussed with OE, with 42' of rat hole inside mud joints was good to run completion. R/D SL. Dropped cup type standing valve, M/u TIW and kelly hose, filled tbg with 25bbls of PW, pressured up on tbg to 1,500psi and held for 30mins-good test, Bleed off pressure. Cleared rig floor, P/u handing tools to run 2-7/8" completion tubing, RIH w/61jts of 2-7/8" P110 EUE 8rd Tbg, Make-up Tq 2300ft/lbs. R/d 2-7/8" handling tools, P/u 3-1/2" handling tools, RIH w/6jts of 3-1/2" TPL 4040 Tubing, Torqued to Manufacture Make-up 2350ft/lbs. P/U Tbg hanger and Landing Jt, Landed completion with 48k dn on Hanger, RILDS, J out of hanger S/o 42" turned pipe 8 times to left with wrenches held torque while making several pickup and set down until working all slack worked out of the Tbg Anchor. Set down string weight to verify anchor will catch tbg string, Picked up to 66k and J back in hanger leaving string 18k in tension. EOT @ 10,415'md. M/u Kelly hose, filled Tbg w/13bbls, pressured up to 1,500psi, held and charted for 30mins-good test. Bleed off pressure and blew circ lines dry. R/u SL, RIH w/2"JDC latched standing valve 10,344'SLM, equalized and jarred free, POOH L/d Standing valve, RDMO S/L. 03/19/2022 - Saturday Held PJSM, warmed eq. Check well Tbg/IA 0psi. Set BPV, Cleaned and cleared floor, Removed handrails and winterization, RD work floor, disconnected control lines, Broke down Ck/Kill lines. ND Bop's/NU the tree, pack-off and tested hanger void 500psi-5000psi 15min test good. R/u work floor, M/u riser, rod stripper head and work plate, brought rod handling tools to floor. P/u Weatherford 1-3/4" RHBC pump, bucket tested pump good, M/u 1.66" Dip Tube on bottom of pump (15'x1.66" w/1' of perforations on bottom of tube), RIH w/Weatherford EL rod completion as per tally, making up connection with Weatherford EL grade torque card. 194 3/4" Rods, 128 7/8" rods, 20 1" Rods. Kicked out and replaced two 3/4" Rods due to bad pin ends. M/u Polish rod and stuffing box, secured well SDFN. Resume running rod completion in the AM. Rig Start Date End Date 3/8/22 3/21/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 32-08 50-133-10118-00-00 160-045 Held PJSM warmed up eq, SITP/IA 0psi. L/d the stuffing box and polish rod, continue RIH w/1" rods, tag and landed pump in the seating nipple, PUW and SOW 21k, M/u 2 8' pony rods, stuffing box and polish rod, spaced out pump out 38" off bottom, filled tubing and pressured up to 1000psi testing the Tbg and stuffing box, held for 5mins good test. Bleed off pressure. See rod tally in well folder for running order. Stroked pumped with the rig and would not pump up past 150psi, started trouble shooting. Appears to be issues with the traveling valve. B/o the stuffing box and pulled 5k over on rod string and unseated pump, well on vac, pumped 40 bbls of PW down tbg to flush out possible trash. Seated pump and lightly tagged bottom several time trying to knockout any trash in the valve, fluid packed tbg, M/u stuffing box stroked pump with same issue. Continued troubleshooting, found that the pump will only bring up fluid while tagging bottom on every stroke, started making 35' long strokes and started pumping up without having to tag bottom, hooked circ line and continued stroking pump for 1hr. to the rig pit with no issues. Secured well SDFN. Will resume testing the pump in the AM before RD 401. 03/21/2022 - Monday Held PJSM, warmed eq. Continued testing rod pump with no issues. SI well, and hung off and clamped Rod string. Scoped and Lay over Derrick, prep rig and equipment for rig move. Hauled equipment and rig to 41-08, picked up containment and cleaned up pad. End of well work, turned well over to ops. 03/20/2022 - Sunday Updated by DMA 03-31-22 Well: SCU 32-08 PTD 160-045 API: 50-133-10118-00-00SCHEMATIC RKB: 143’/ GL: 128’ AMSL New KB – THF: 15.00’ TD = 10,828’ PBTD = 10,631’ PBTD ±10,631’ DV @ 1,308’ DV @ 7,996’ Bad Casing @ 10,634’ 1 2 3 4 5/6 7 CASING DETAIL Size WT Grade Conn ID Top Btm 22” - - - -Surface 28’ 13-3/8” 54.5 J-55 8RD 12.615”Surface 1,308’ 54.5 J-55 8RD 12.615”1,310’3.014’ 6-5/8” 28 P-110 8RD 5.791”Surface 115’ 24 N-80 BTC 5.921” 115’6,477’ 24 P-110 8RD 5.921”6,477’7,996’ 24 P-110 8RD 5.921”7,998’10,037’ 28 P-110 8RD 5.791”10,037’10,828’ TUBING DETAIL Size WT Grade Conn ID Top Btm When new 3-1/2” Poly-Lined 9.84 L-80 TPL 4040 2.347”Surface 211’ 3/18/22 2-7/8” 6.5 P-110 8RD 2.441” 211’2,206’3/18/22 2-7/8” 6.5 L-80 8RD 2.441”2,206’10,416’12/7/12 JEWELRY DETAIL (3/18/22) #Depth ID When new Description 1 19’2.441”3/18/22 Tubing Hanger J-Latch Tension hanger 2 2,937’2.441”2001 Marker Sub for IA FL shots 3 10,282’2.441”12/5/12 Tubing Anchor (Weatherford BA) 4 10,348’2.225”Seating Nipple 5 10,349’-Perforated Joint (6’) 6 10,355’-4-1/2” Tubing IBT (60’) 7 10,416’-Bull Plug / end of assembly ROD DETAIL (3/19/22) Depth Length When new Description -40’Polish Rod (reused for March-2022 RWO) 55’16’3/19/22 1” x 8’ EL Pony Rods with no guides (2) 71’175’10/28/19 1” EL Sucker rods w/ no guides (7) 246’1,750’10/28/19 1” EL Sucker rods w/ 4 guides per rod (70) 1,996’3,200’10/28/19 7/8” EL Sucker rods w/ 4 XL guides per rod (128) 5,196’4,850’10/28/19 3/4” EL Sucker rods w/ 4 XL guides per rod (194) 10,046’85’Sinker Bars (10) and stabilizer bars (4) 10,306’42’3/19/22 Rod Pump 10,348’15’Dip Tube: Bottom 1’ is perforated at 10,363’ MD. 10+’ from Perf joint to dip tube inlet PERFORATION DETAIL ON NEXT PAGE MAX HOLE ANGLE = 3° @ 7,004’ FISH DETAIL ON NEXT PAGE Top of fish @ 10,423’ Prime Mover: Weatherford Rotoflex SL tagged sand ~40’ below seating nipple at 10,388’ MD (3/18/22) Updated by DMA 03-31-22 Well: SCU 32-08 PTD 160-045 API: 50-133-10118-00-00 SCHEMATIC FISH DETAIL # Depth Length ID OD Description F I S H 10,423’ 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) 4.09’ 2.375 4.25 Chemical Injection Sub 39 3.438 4.4 Screen Assembly 0.008” 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug (Bottom f Fish) PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376’ 10,396’ 10,373' 10,393' 20’ Perforated October 2011 2/20/1961 WSO 10,496’ 10,497’ 10,493' 10,494' 1’ Squeezed 10-12-1985 10/16/1985 H1 10,516’ 10,518’ 10,513' 10,515' 2’ Re-perf 08-18-01 10/1/2011 H1 10,518’ 10,533’ 10,515' 10,530' 15 Re-perforated October 2011 10/16/1985 H1 10,518’ 10,520’ 10,515' 10,517' 2’ Re-perf 08-18-01 / 10-02-2004 2/21/1961 H1 10,520’ 10,529 10,517' 10,526' 9’ Re-perf 10-16-1985 / 06-10-1995 / 08-18-2001 / 10-02-2004 2/21/1961 H1 10,529’ 10,530’ 10,526' 10,527' 1’ Re-perf 10-16-1985 10/16/1985 H1 10,530’ 10,532’ 10,527' 10,529' 2 8/18/2001 H2 10,543’ 10,545’ 10,540' 10,542' 2’ 10/16/1985 H2 10,545’ 10,546’ 10,542' 10,543' 1’ Re-perf 08-18-01 10/1/2011 H2 10,545’ 10,566’ 10,542' 10,563' 21’ Re-perforated October 2011 6/10/1995 H2 10,546’ 10,550’ 10,543' 10,547' 4’ Re-perf 10-16-1985 / 08-18-2001 / 10-02-2004 2/21/1961 H2 10,550’ 10,560’ 10,547' 10,557' 10’ Re-perf 10-16-1985 / 06-10-1995 / 08-18-2001 / 10-02-2004 2/21/1961 H2 10,560’ 10,569’ 10,557' 10,566' 9’ Re-perf 10-16-1985 / 06-10-1995 / 08-18-2001 2/21/1961 H2 10,569’ 10,572’ 10,566' 10,569' 3’ Re-perf 10-16-1985 2/21/1961 H2 10,572’ 10,575’ 10,569' 10,572' 3’ Sqzd 10-16-1985 2/21/1961 H3 10,580’ 10,584’ 10,577' 10,581' 4’ Sqzd 10-16-1985 10/16/1985 H3 10,585’ 10,592’ 10,582' 10,589' 7’ 2/21/1961 H3 10,592’ 10,600’ 10,589' 10,597' 8’ Re-perf 10-16-1985 2/21/1961 H3 10,600’ 10,603’ 10,597' 10,600' 3’ Sqzd 10-16-1985 2/21/1961 H3 10,608’ 10,616’ 10,605' 10,613' 8’ Sqzd 10-16-1985 2/21/1961 H3 10,622’ 10,631’ 10,619' 10,628' 9’ Sqzd 10-16-1985 2/21/1961 H4/5 10,622’ 10,678’ 10,619' 10,674' 56’ Sqzd 10-16-1985 2/20/1961 WSO 10,681’ 10,682’ 10,677' 10,678' 1’ Sqzd 10-16-1985 6(& 1:Swanson River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his Map +LOFRUS$ODVND//&+LOFRUS$ODVND//&Changes to Approved Rig Work Over Sundry Procedure6XEMHFW &KDQJHVWR$SSURYHG6XQGU\3URFHGXUHIRU:HOO6&837'6XQGU\;;;;;;$Q\PRGLILFDWLRQVWRDQDSSURYHGVXQGU\ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ&KDQJHVWRDQDSSURYHGVXQGU\ZLOOEHFRPPXQLFDWHGWRWKH$2*&&E\WKHULJZRUNRYHU5:2³ILUVWFDOO´HQJLQHHU$2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6HF3DJH'DWH3URFHGXUH&KDQJH1HZ5HTXLUHG"<1+$.3UHSDUHG%\,QLWLDOV+$.$SSURYHG%\,QLWLDOV$2*&&:ULWWHQ$SSURYDO5HFHLYHG3HUVRQDQG'DWH$SSURYDO $VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH 3UHSDUHG )LUVW&DOO2SHUDWLRQV(QJLQHHU 'DWH Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 4/20/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 32-08 (PTD 160-045) RCT 3/17/2022 Please include current contact information if different from above. PTD:160-045 T36584 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.11 11:46:55 -08'00' 5HJJ-DPHV%2*& )URP:DGH+XGJHQV&ZKXGJHQV#KLOFRUSFRP! 6HQW6DWXUGD\0DUFK30 7R5HJJ-DPHV%2*& 6XEMHFW5(>(;7(51$/@5(+$.6&8%23(7HVW5HSRUW $WWDFKPHQWV+$.[OV[+$.[OV[ ƚƚĂĐŚĞĚĂƌĞƚŚĞĐŽƌƌĞĐƚĞĚƌĞƉŽƌƚƐƐŚŽǁŝŶŐƚŚĞsĂůǀĞƐŝǌĞƐ͘ dŚĂŶŬzŽƵ͕ tĂĚĞ,ƵĚŐĞŶƐ t^D͕ZŝŐϰϬϭ ,ŝůĐŽƌƉůĂƐŬĂ ͗ϵϬϯͲϯϯϭͲϲϳϭϭ K͗ϵϬϳͲϮϯϴͲϮϱϴϬ ǁŚƵĚŐĞŶƐΛŚŝůĐŽƌƉ͘ĐŽŵ &ƌŽŵ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗^ĂƚƵƌĚĂǇ͕DĂƌĐŚϭϵ͕ϮϬϮϮϱ͗ϯϭWD dŽ͗tĂĚĞ,ƵĚŐĞŶƐͲ;ͿфǁŚƵĚŐĞŶƐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗΀ydZE>΁Z͗,<ϰϬϭ^hϯϮͲϬϴKWdĞƐƚZĞƉŽƌƚϯͬϭϱͬϮϮ sĂůǀĞƐŝǌĞƐŵŝƐƐŝŶŐŽŶϯͬϰĂŶĚϯͬϭϱƌĞƉŽƌƚƐ͘ :ŝŵZĞŐŐ ^ƵƉĞƌǀŝƐŽƌ͕/ŶƐƉĞĐƚŝŽŶƐ K' ϯϯϯt͘ϳƚŚǀĞ͕^ƵŝƚĞϭϬϬ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ϵϬϳͲϳϵϯͲϭϮϯϲ &ƌŽŵ͗tĂĚĞ,ƵĚŐĞŶƐͲ;ͿфǁŚƵĚŐĞŶƐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕DĂƌĐŚϭϳ͕ϮϬϮϮϵ͗ϯϴD dŽ͗KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗:ƵĂŶŝƚĂ>ŽǀĞƚƚфũůŽǀĞƚƚΛŚŝůĐŽƌƉ͘ĐŽŵх͖ΖKKĨĨƐŚŽƌĞΖфŽĨĨƐŚŽƌĞΛĂůůĂŵĞƌŝĐĂŶŽŝůĨŝĞůĚ͘ĐŽŵх͖ŽŶŶĂŵďƌƵǌ фĚĂŵďƌƵǌΛŚŝůĐŽƌƉ͘ĐŽŵх͖ZǇĂŶZƵƉĞƌƚфZǇĂŶ͘ZƵƉĞƌƚΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗,<ϰϬϭ^hϯϮͲϬϴKWdĞƐƚZĞƉŽƌƚϯͬϭϱͬϮϮ WůĞĂƐĞƐĞĞĂƚƚĂĐŚĞĚKWdĞƐƚZĞƉŽƌƚĨŽƌ^hϯϮͲϬϴ͘ dŚĂŶŬzŽƵ͕ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH 6&8 37' -5HJJ 37' tĂĚĞ,ƵĚŐĞŶƐ t^D͕ZŝŐϰϬϭ ,ŝůĐŽƌƉůĂƐŬĂ ͗ϵϬϯͲϯϯϭͲϲϳϭϭ K͗ϵϬϳͲϮϯϴͲϮϱϴϬ ǁŚƵĚŐĞŶƐΛŚŝůĐŽƌƉ͘ĐŽŵ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:401 DATE: 3/15/22 Rig Rep.: Rig Phone: 907-283-2580 Operator: Op. Phone:907-283-2580 Rep.: E-Mail Well Name: PTD #11600450 Sundry #322-090 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250-2500 Annular:250-2500 Valves:250-2500 MASP:1475 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.NA Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 7-1/16" 5M P Pit Level Indicators PP #1 Rams 1 2-3/8"x2-7/8" Flex P Flow Indicator NA NA #2 Rams 1 3-1/2" Ram P Meth Gas Detector PP #3 Rams 1 Blind P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2-1/16" 5M P Inside Reel valves 0NA HCR Valves 1 2-1/16" 5M P Kill Line Valves 3 2-1/16" 5M P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)2500 P Quantity Test Result 200 psi Attained (sec)13 P No. Valves 8P Full Pressure Attained (sec)32 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): 6 x 2200 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:4.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3-14-22/5:08pm Waived By Test Start Date/Time:3/15/2022 19:00 (date) (time)Witness Test Finish Date/Time:3/15/2022 23:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Test was preformed with 2-7/8" and 3-1/2" Test Jts. Chris Hannevold Hilcorp Wade Hudgens SCU 32-08 Test Pressure (psi): whudgens@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0315_BOP_Hilcorp401_SCU_32-08 9 9 9 9 9 9 9 9 -5HJJ 3/15/22 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 3/16/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 32-08 (PTD 160-045) Caliper 3/14/2022 Please include current contact information if different from above. 160-045 T36420 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.16 12:32:00 -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:McLellan, Bryan J (OGC) To:Ryan Rupert Cc:Donna Ambruz; Wade Hudgens - (C); Joe Kaiser; Dan Marlowe Subject:RE: SCU 32-8 RWO (PTD#160-045) Date:Tuesday, March 15, 2022 3:45:00 PM Ryan, You have approval to proceed with your plan to cut the tubing and fish it out in 2 segments, and to perform the tubing cut without wireline lubricator, as long as the hydrocarbons have been flushed from the well and tested BOP stack is on the well. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Tuesday, March 15, 2022 1:36 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Wade Hudgens - (C) <whudgens@hilcorp.com>; Joe Kaiser <jkaiser@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: SCU 32-8 RWO (PTD#160-045) Bryan- Per our conversation, we’d like to RU EL tomorrow morning and make a tubing cut in the 2-7/8” and remove the tubing in 2 segments. We will have KWF on each side, and all hydrocarbons flushed from the well per the sundry. We will also have tested BOP’s on the well before EL is rigged up. Given this, Hilcorp was not planning on rigging up a lubricator with EL for the tubing cut. Please confirm if this is acceptable. Thanks, Ryan Rupert Kenai 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. 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Ă͘WƌŽǀŝĚĞϮϰŚƌŶŽƚŝĐĞƚŽK';ŶŽƚŝĨŝĐĂƚŝŽŶƚŽ>DŝƐEKdƌĞƋƵŝƌĞĚͿ ď͘WdƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚͬϮϱϬϬƉƐŝĂŶŶƵůĂƌ Đ͘dĞƐƚsZ͛ƐŽŶϮͲϳͬϴ͟ƚĞƐƚũŽŝŶƚ͕ĂŶĚϯͲϭͬϮ͟ƚĞƐƚũŽŝŶƚ;ŝĨƉůĂŶŶŝŶŐƚŽŚĂŶĚůĞͿ ϭϳ͘hŶƐĞĂƚƚƵďŝŶŐŚĂŶŐĞƌĂŶĚĚŽǁŶŚŽůĞĂŶĐŚŽƌ͕ĂŶĚƌĞƚƌŝĞǀĞϮͲϳͬϴ͟ĐŽŵƉůĞƚŝŽŶ ϭϴ͘DĂŬĞƵƉŶĞǁůŽǁĞƌĐŽŵƉůĞƚŝŽŶĂŶĚƚƵďŝŶŐĂŶĐŚŽƌŽŶϮͲϳͬϴ͟ƚƵďŝŶŐ ϭϵ͘Z/,ĂŶĚůĂŶĚϮͲϳͬϴ͟ĐŽŵƉůĞƚŝŽŶǁŝƚŚƚƵďŝŶŐĂŶĐŚŽƌĂƚцϭϬ͕ϯϴϬ͛D ϮϬ͘EKW͛Ɛ͕EhƚƌĞĞĂŶĚƚĞƐƚ Ϯϭ͘EhZŽĚƐƚƌŝƉƉĞƌ ^hϯϮͲϴ ZŽĚƉƵŵƉǁĞůůZtK ZƵŶƌŽĚƐͬƉƵŵƉ͗ ϮϮ͘WhƉƵŵƉĂŶĚĚŝƉƚƵďĞĂƐƐĞŵďůǇ Ϯϯ͘Z/,ŽŶƚĂƉĞƌĞĚƌŽĚƐƚƌŝŶŐ Ϯϰ͘^ƉĂĐĞŽƵƚƌŽĚƐ͕ůĂŶĚƉƵŵƉĂŶĚŝŶƐƚĂůůƉŽůŝƐŚƌŽĚ Ϯϱ͘WdƚƵďŝŶŐƚŽϭϬϬϬƉƐŝ Ϯϲ͘EZŽĚƐƚƌŝƉƉĞƌ͕ĂŶĚŝŶƐƚĂůůƐƵƌĨĂĐĞĞƋƵŝƉŵĞŶƚ Ϯϳ͘ZDKZŝŐηϰϬϭ Ϯϴ͘ZŽůůƵƉZŽƚŽĨůĞǆƐƵƌĨĂĐĞƉƵŵƉŝŶŐƵŶŝƚ͕ƌĞĐŽƵƉůĞ͕ĂŶĚƌĞŵŽǀĞ>KdK Ϯϵ͘ZĞƚƵƌŶǁĞůůƚŽƉƌŽĚƵĐƚŝŽŶǁŝƚŚƐĂŵĞƐƵƌĨĂĐĞƐĂĨĞƚǇƐǇƐƚĞŵƐĂƐƉƌĞǀŝŽƵƐůǇŝŶƐƚĂůůĞĚ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ƵƌƌĞŶƚ^ĐŚĞŵĂƚŝĐ Ϯ͘WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ƵƌƌĞŶƚǁĞůůŚĞĂĚĚƌĂǁŝŶŐ;ŶŽĐŚĂŶŐĞƐͿ ϰ͘E&d;ϭϮͬϭϮͬϮϬϭϮͿ ϱ͘^s^ůĞƚƚĞƌ ϲ͘ZŝŐϰϬϭKW^ĐŚĞŵĂƚŝĐ;ϳͲϭͬϭϲ͟dƌŝƉůĞϱŬͿ ϳ͘ĞƌŝĂůϲϲϬ͛ŵĂƉ ϴ͘ZtKƐƵŶĚƌǇĐŚĂŶŐĞĨŽƌŵ hƉĚĂƚĞĚďǇZZ ϬϮͲϭϴͲϮϮ tĞůů͗^hϯϮͲϬϴ WdϭϲϬͲϬϰϱ W/͗ϱϬͲϭϯϯͲϭϬϭϭϴͲϬϬͲϬϬ^,Dd/ Z<͗ϭϰϯ͛ͬ'>͗ϭϮϴ͛D^> EĞǁ<ʹ d,&͗ϭϱ͘ϬϬ͛ dсϭϬ͕ϴϮϴ͛WdсϭϬ͕ϲϯϭ͛ WdцϭϬ͕ϲϯϭ͛ sΛ ϭ͕ϯϬϴ͛ sΛ ϳ͕ϵϵϲ͛ ĂĚ ĂƐŝŶŐΛ ϭϬ͕ϲϯϰ͛ ϭ Ϯ ϯ ϰ ϱ ϲ ϳ ^/E'd/> ^ŝǌĞ td 'ƌĂĚĞ ŽŶŶ /dŽƉ ƚŵ ϮϮ͟ Ͳ Ͳ Ͳ Ͳ ^ƵƌĨĂĐĞ Ϯϴ͛ ϭϯͲϯͬϴ͟ ϱϰ͘ϱ :Ͳϱϱ ϴZϭϮ͘ϲϭϱ͟^ƵƌĨĂĐĞ ϭ͕ϯϬϴ͛ sŽůůĂƌ ϭϮ͘ϲϭϱ͟ϭ͕ϯϬϴ͛ϭ͕ϯϭϬ͛ ϱϰ͘ϱ :Ͳϱϱ ϴZϭϮ͘ϲϭϱ͟ϭ͕ϯϭϬ͛ϯ͘Ϭϭϰ͛ ϲͲϱͬϴ͟ Ϯϴ WͲϭϭϬ ϴZ ϱ͘ϳϵϭ͟^ƵƌĨĂĐĞ ϭϭϱ͛ Ϯϰ EͲϴϬ d ϱ͘ϵϮϭ͟ ϭϭϱ͛ϲ͕ϰϳϳ͛ Ϯϰ WͲϭϭϬ ϴZ ϱ͘ϵϮϭ͟ϲ͕ϰϳϳ͛ϳ͕ϵϵϲ͛ sŽůůĂƌ ϱ͘ϵϮϭ͟ϳ͕ϵϵϲ͛ϳ͕ϵϵϴ͛ Ϯϰ WͲϭϭϬ ϴZ ϱ͘ϵϮϭ͟ϳ͕ϵϵϴ͛ϭϬ͕Ϭϯϳ͛ Ϯϴ WͲϭϭϬ ϴZ ϱ͘ϳϵϭ͟ϭϬ͕Ϭϯϳ͛ϭϬ͕ϴϮϴ͛ dh/E'd/> ϮͲϳͬϴ͟ ϲ͘ϱ >ͲϴϬ ϴZ Ϯ͘ϰϰϭ͟^ƵƌĨĂĐĞ ϭϬ͕ϯϱϵ͛ :t>Zzd/> η ĞƉƚŚ >ĞŶŐƚŚ /KĞƐĐƌŝƉƚŝŽŶ ϭ ϭϱ͛ ϲϮ͛Ϯ͘ϵϵϭ͟ϳ͟dƵďŝŶŐ,ĂŶŐĞƌ:Ͳ>ĂƚĐŚ͕ǁͬϮũŽŝŶƚƐŽĨϯͲϭͬϮ͟ ƚƵďŝŶŐďĞůŽǁŚĂŶŐĞƌ͘ Ϯ Ϯ͕ϵϴϵ͛Ϯ͘ϰϰϭ͟ϱ͟DĂƌŬĞƌ^Ƶď ϯ ϭϬ͕Ϯϵϰ͛Ϯ͘ϯϮ͛Ϯ͘ϰϰϭ͟ϲ͘ϲϮϱ͟dƵďŝŶŐŶĐŚŽƌ ;ŝŶƐƚĂůůĞĚŶĞǁϭϮͬϱͬϭϮͿ ϰ ϭϬ͕ϯϴϰ͛Ϭ͘ϲϱ͛Ϯ͘ϮϱϬ͟^ĞĂƚŝŶŐEŝƉƉůĞ ϱ ϭϬ͕ϯϱϵ͛ϱ͘ϲϱ͛ϰ͘ϯϳϱ͟ϰ͘ϱ͟WĞƌĨŽƌĂƚĞĚ:ŽŝŶƚ ϲ ϭϬ͕ϯϲϱ͛ϲϭ͛ϰ͘ϯϳϱ͟ϰ͘ϱ͟ϰͲϭͬϮ͟dƵďŝŶŐ/d ϳ ϭϬ͕ϰϮϲ͛Ϭ͘ϰϰ͛ϰ͘ϯϳϱ͟ϰ͘ϱ͟ƵůůWůƵŐ ZKd/> ϬϭͬϯϭͬϮϬ η ĞƉƚŚ >ĞŶŐƚŚ KĞƐĐƌŝƉƚŝŽŶ Ͳϭϲ͛ ϰϬ͛ ϭͲϭͬϮ͟WŽůŝƐŚ ZŽĚ͕Ϯϰ͛ŝŶǁĞůů ϯϵ͛ ϭϲ͛ ϭ͟ϭ͟ǆϴ͛ >WŽŶǇZŽĚƐ;ϮͿ ϱϱ͛ ϭ͕ϵϱϬ͚ϭ͟ϭ͟ǆϮϱ͛>^ƵĐŬĞƌƌŽĚƐǁͬϰ y>ŐƵŝĚĞƐ ƉĞƌƌŽĚ;ϳϴͿ Ϯ͕ϬϬϱ͛ϯ͕ϮϬϬ͛͘ϴϳϱ͟ϳͬϴ͟ǆϮϱ͛>^ƵĐŬĞƌƌŽĚƐǁͬϰ y>ŐƵŝĚĞƐ ƉĞƌƌŽĚ;ϭϮϴͿ ϱ͕ϮϬϱ͛ϰ͕ϴϱϬ͛͘ϳϱ͟в͟ǆϮϱ͛>^ƵĐŬĞƌƌŽĚƐǁͬϰy>ŐƵŝĚĞƐƉĞƌƌŽĚ;ϭϵϰͿ ϭϬ͕Ϭϱϱ͛ϵϴϳ͛ ϭͲϭͬϮ͟^ŝŶŬĞƌĂƌƐ;ϭϬͿ ĂŶĚƐƚĂďŝůŝǌĞƌďĂƌƐ;ϰͿ ϭϬ͕ϯϭϱ͛ϰϮ͛ϭ͘ϳϱ͛tĞĂƚŚĞƌĨŽƌĚϮϱͲϭϳϱͲϯϴͲϰͲϬͲϬZ,ZŽĚWƵŵƉηϳϯϮϬ DĂǆ^ƚƌŽŬĞϯϵϭ͟ʹ ϴϬZŝŶŐW/ŶƐƚĂůůĞĚϭϬͬϮϴͬϭϵ ϭϬ͕ϯϱϳ͛ϭ͛ϭ͘ϲϲϬ͟^ĂŶĚ^ĐƌĞĞŶ WZ&KZd/KEd/>KEEydW' Dy,K>E'>сϯΣΛϳ͕ϬϬϰ͛ &/^,d/>KEEydW' dŽƉŽĨĨŝƐŚ ΛϭϬ͕ϰϮϯ͛ 1HZ7XELQJ5DQ 1HZURGVUDQ 1HZSXPSUDQ hƉĚĂƚĞĚďǇZZϬϮͲϭϴͲϮϮ tĞůů͗^hϯϮͲϬϴ WdϭϲϬͲϬϰϱ W/͗ϱϬͲϭϯϯͲϭϬϭϭϴͲϬϬͲϬϬ ^,Dd/ &/^,d/> ηĞƉƚŚ>ĞŶŐƚŚ/KĞƐĐƌŝƉƚŝŽŶ & / ^ , ϭϬ͕ϰϮϯ͛ϭ͘ϭ Ϯ͘Ϯϱ ϯ͘ϲϴϴƵƉƚǇƉĞƐĞĂƚŝŶŐŶŝƉƉůĞ;dŽƉŽĨ&ŝƐŚͿ ϰ͘Ϭϵ͛Ϯ͘ϯϳϱ ϰ͘ϮϱŚĞŵŝĐĂů/ŶũĞĐƚŝŽŶ^Ƶď ϯϵ ϯ͘ϰϯϴ ϰ͘ϰ^ĐƌĞĞŶƐƐĞŵďůǇϬ͘ϬϬϴ͟ ϵϳ͘ϭϴϮϯ͘ϵϱϴ ϰ͘ϱůĂŶŬƉŝƉĞ ϭϬ͕ϱϭϵϬ͘ϳϱ Ϭ ϱ͘ϭϴϴƵůůWůƵŐ;ŽƚƚŽŵĨ&ŝƐŚͿ WZ&KZd/KEd/> ĂƚĞŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿŵƚŽŵŵĞŶƚƐ ϭϬͬϭͬϮϬϭϭ'ͲϭϭϬ͕ϯϳϲ͛ϭϬ͕ϯϵϲ͛ϭϬ͕ϯϳϯΖϭϬ͕ϯϵϯΖϮϬ͛WĞƌĨŽƌĂƚĞĚKĐƚŽďĞƌϮϬϭϭ ϮͬϮϬͬϭϵϲϭt^KϭϬ͕ϰϵϲ͛ϭϬ͕ϰϵϳ͛ϭϬ͕ϰϵϯΖϭϬ͕ϰϵϰΖϭ͛^ƋƵĞĞǌĞĚϭϬͲϭϮͲϭϵϴϱ ϭϬͬϭϲͬϭϵϴϱ,ϭϭϬ͕ϱϭϲ͛ϭϬ͕ϱϭϴ͛ϭϬ͕ϱϭϯΖϭϬ͕ϱϭϱΖϮ͛ZĞͲƉĞƌĨϬϴͲϭϴͲϬϭ ϭϬͬϭͬϮϬϭϭ,ϭϭϬ͕ϱϭϴ͛ϭϬ͕ϱϯϯ͛ϭϬ͕ϱϭϱΖϭϬ͕ϱϯϬΖϭϱZĞͲƉĞƌĨŽƌĂƚĞĚKĐƚŽďĞƌϮϬϭϭ ϭϬͬϭϲͬϭϵϴϱ,ϭϭϬ͕ϱϭϴ͛ϭϬ͕ϱϮϬ͛ϭϬ͕ϱϭϱΖϭϬ͕ϱϭϳΖϮ͛ZĞͲƉĞƌĨϬϴͲϭϴͲϬϭͬϭϬͲϬϮͲϮϬϬϰ ϮͬϮϭͬϭϵϲϭ,ϭϭϬ͕ϱϮϬ͛ϭϬ͕ϱϮϵϭϬ͕ϱϭϳΖϭϬ͕ϱϮϲΖϵ͛ZĞͲƉĞƌĨϭϬͲϭϲͲϭϵϴϱͬϬϲͲϭϬͲϭϵϵϱͬϬϴͲϭϴͲϮϬϬϭ ͬϭϬͲϬϮͲϮϬϬϰ ϮͬϮϭͬϭϵϲϭ,ϭϭϬ͕ϱϮϵ͛ϭϬ͕ϱϯϬ͛ϭϬ͕ϱϮϲΖϭϬ͕ϱϮϳΖϭ͛ZĞͲƉĞƌĨϭϬͲϭϲͲϭϵϴϱ ϭϬͬϭϲͬϭϵϴϱ,ϭϭϬ͕ϱϯϬ͛ϭϬ͕ϱϯϮ͛ϭϬ͕ϱϮϳΖϭϬ͕ϱϮϵΖϮ ϴͬϭϴͬϮϬϬϭ,ϮϭϬ͕ϱϰϯ͛ϭϬ͕ϱϰϱ͛ϭϬ͕ϱϰϬΖϭϬ͕ϱϰϮΖϮ͛ ϭϬͬϭϲͬϭϵϴϱ,ϮϭϬ͕ϱϰϱ͛ϭϬ͕ϱϰϲ͛ϭϬ͕ϱϰϮΖϭϬ͕ϱϰϯΖϭ͛ZĞͲƉĞƌĨϬϴͲϭϴͲϬϭ ϭϬͬϭͬϮϬϭϭ,ϮϭϬ͕ϱϰϱ͛ϭϬ͕ϱϲϲ͛ϭϬ͕ϱϰϮΖϭϬ͕ϱϲϯΖϮϭ͛ZĞͲƉĞƌĨŽƌĂƚĞĚKĐƚŽďĞƌϮϬϭϭ ϲͬϭϬͬϭϵϵϱ,ϮϭϬ͕ϱϰϲ͛ϭϬ͕ϱϱϬ͛ϭϬ͕ϱϰϯΖϭϬ͕ϱϰϳΖϰ͛ZĞͲƉĞƌĨϭϬͲϭϲͲϭϵϴϱͬϬϴͲϭϴͲϮϬϬϭͬϭϬͲϬϮͲϮϬϬϰ ϮͬϮϭͬϭϵϲϭ,ϮϭϬ͕ϱϱϬ͛ϭϬ͕ϱϲϬ͛ϭϬ͕ϱϰϳΖϭϬ͕ϱϱϳΖϭϬ͛ZĞͲƉĞƌĨϭϬͲϭϲͲϭϵϴϱͬϬϲͲϭϬͲϭϵϵϱͬϬϴͲϭϴͲϮϬϬϭ ͬϭϬͲϬϮͲϮϬϬϰ ϮͬϮϭͬϭϵϲϭ,ϮϭϬ͕ϱϲϬ͛ϭϬ͕ϱϲϵ͛ϭϬ͕ϱϱϳΖϭϬ͕ϱϲϲΖϵ͛ZĞͲƉĞƌĨϭϬͲϭϲͲϭϵϴϱͬϬϲͲϭϬͲϭϵϵϱͬϬϴͲϭϴͲϮϬϬϭ ϮͬϮϭͬϭϵϲϭ,ϮϭϬ͕ϱϲϵ͛ϭϬ͕ϱϳϮ͛ϭϬ͕ϱϲϲΖϭϬ͕ϱϲϵΖϯ͛ZĞͲƉĞƌĨϭϬͲϭϲͲϭϵϴϱ ϮͬϮϭͬϭϵϲϭ,ϮϭϬ͕ϱϳϮ͛ϭϬ͕ϱϳϱ͛ϭϬ͕ϱϲϵΖϭϬ͕ϱϳϮΖϯ͛^ƋǌĚϭϬͲϭϲͲϭϵϴϱ ϮͬϮϭͬϭϵϲϭ,ϯϭϬ͕ϱϴϬ͛ϭϬ͕ϱϴϰ͛ϭϬ͕ϱϳϳΖϭϬ͕ϱϴϭΖϰ͛^ƋǌĚϭϬͲϭϲͲϭϵϴϱ ϭϬͬϭϲͬϭϵϴϱ,ϯϭϬ͕ϱϴϱ͛ϭϬ͕ϱϵϮ͛ϭϬ͕ϱϴϮΖϭϬ͕ϱϴϵΖϳ͛ ϮͬϮϭͬϭϵϲϭ,ϯϭϬ͕ϱϵϮ͛ϭϬ͕ϲϬϬ͛ϭϬ͕ϱϴϵΖϭϬ͕ϱϵϳΖϴ͛ZĞͲƉĞƌĨϭϬͲϭϲͲϭϵϴϱ ϮͬϮϭͬϭϵϲϭ,ϯϭϬ͕ϲϬϬ͛ϭϬ͕ϲϬϯ͛ϭϬ͕ϱϵϳΖϭϬ͕ϲϬϬΖϯ͛^ƋǌĚϭϬͲϭϲͲϭϵϴϱ ϮͬϮϭͬϭϵϲϭ,ϯϭϬ͕ϲϬϴ͛ϭϬ͕ϲϭϲ͛ϭϬ͕ϲϬϱΖϭϬ͕ϲϭϯΖϴ͛^ƋǌĚϭϬͲϭϲͲϭϵϴϱ ϮͬϮϭͬϭϵϲϭ,ϯϭϬ͕ϲϮϮ͛ϭϬ͕ϲϯϭ͛ϭϬ͕ϲϭϵΖϭϬ͕ϲϮϴΖϵ͛^ƋǌĚϭϬͲϭϲͲϭϵϴϱ ϮͬϮϭͬϭϵϲϭ,ϰͬϱϭϬ͕ϲϮϮ͛ϭϬ͕ϲϳϴ͛ϭϬ͕ϲϭϵΖϭϬ͕ϲϳϰΖϱϲ͛^ƋǌĚϭϬͲϭϲͲϭϵϴϱ ϮͬϮϬͬϭϵϲϭt^KϭϬ͕ϲϴϭ͛ϭϬ͕ϲϴϮ͛ϭϬ͕ϲϳϳΖϭϬ͕ϲϳϴΖϭ͛^ƋǌĚϭϬͲϭϲͲϭϵϴϱ hƉĚĂƚĞĚďǇD ϬϮͲϮϰͲϮϮ tĞůů͗^hϯϮͲϬϴ WdϭϲϬͲϬϰϱ W/͗ϱϬͲϭϯϯͲϭϬϭϭϴͲϬϬͲϬϬWZKWK^ ^,Dd/ Z<͗ϭϰϯ͛ͬ'>͗ϭϮϴ͛D^> EĞǁ<ʹ d,&͗ϭϱ͘ϬϬ͛ dсϭϬ͕ϴϮϴ͛WdсϭϬ͕ϲϯϭ͛ WdцϭϬ͕ϲϯϭ͛ sΛ ϭ͕ϯϬϴ͛ sΛ ϳ͕ϵϵϲ͛ ĂĚ ĂƐŝŶŐΛ ϭϬ͕ϲϯϰ͛ ϭ Ϯ ϯ ϰ ϱ ϲ ϳ ^/E'd/> ^ŝǌĞ td 'ƌĂĚĞ ŽŶŶ /dŽƉ ƚŵ ϮϮ͟ Ͳ Ͳ Ͳ Ͳ ^ƵƌĨĂĐĞ Ϯϴ͛ ϭϯͲϯͬϴ͟ ϱϰ͘ϱ :Ͳϱϱ ϴZϭϮ͘ϲϭϱ͟^ƵƌĨĂĐĞ ϭ͕ϯϬϴ͛ sŽůůĂƌ ϭϮ͘ϲϭϱ͟ϭ͕ϯϬϴ͛ϭ͕ϯϭϬ͛ ϱϰ͘ϱ :Ͳϱϱ ϴZϭϮ͘ϲϭϱ͟ϭ͕ϯϭϬ͛ϯ͘Ϭϭϰ͛ ϲͲϱͬϴ͟ Ϯϴ WͲϭϭϬ ϴZ ϱ͘ϳϵϭ͟^ƵƌĨĂĐĞ ϭϭϱ͛ Ϯϰ EͲϴϬ d ϱ͘ϵϮϭ͟ ϭϭϱ͛ϲ͕ϰϳϳ͛ Ϯϰ WͲϭϭϬ ϴZ ϱ͘ϵϮϭ͟ϲ͕ϰϳϳ͛ϳ͕ϵϵϲ͛ sŽůůĂƌ ϱ͘ϵϮϭ͟ϳ͕ϵϵϲ͛ϳ͕ϵϵϴ͛ Ϯϰ WͲϭϭϬ ϴZ ϱ͘ϵϮϭ͟ϳ͕ϵϵϴ͛ϭϬ͕Ϭϯϳ͛ Ϯϴ WͲϭϭϬ ϴZ ϱ͘ϳϵϭ͟ϭϬ͕Ϭϯϳ͛ϭϬ͕ϴϮϴ͛ dh/E'd/> ϮͲϳͬϴ͟ ϲ͘ϱ >ͲϴϬ ϴZ Ϯ͘ϰϰϭ͟^ƵƌĨĂĐĞ ϭϬ͕ϯϱϵ͛ :t>Zzd/> η ĞƉƚŚ >ĞŶŐƚŚ /KĞƐĐƌŝƉƚŝŽŶ ϭ ϭϱ͛ ϲϮ͛Ϯ͘ϵϵϭ͟ϳ͟dƵďŝŶŐ,ĂŶŐĞƌ:Ͳ>ĂƚĐŚ͕ǁͬϮũŽŝŶƚƐŽĨϯͲϭͬϮ͟ ƚƵďŝŶŐďĞůŽǁŚĂŶŐĞƌ͘ Ϯ Ϯ͕ϵϴϵ͛Ϯ͘ϰϰϭ͟ϱ͟DĂƌŬĞƌ^Ƶď ϯ цϭϬ͕ϯϴϬ͛Ϯ͘ϯϮ͛Ϯ͘ϰϰϭ͟ϲ͘ϲϮϱ͟dƵďŝŶŐŶĐŚŽƌ ϰ d^ĞĂƚŝŶŐEŝƉƉůĞ ϱ dWĞƌĨŽƌĂƚĞĚ:ŽŝŶƚ ϲ dϰͲϭͬϮ͟dƵďŝŶŐ/d ϳ dƵůůWůƵŐ ZKd/> η ĞƉƚŚ >ĞŶŐƚŚ KĞƐĐƌŝƉƚŝŽŶ dWŽůŝƐŚZŽĚ͕Ϯϰ͛ŝŶǁĞůů dϭ͟ǆϴ͛>WŽŶǇZŽĚƐ;ϮͿ dϭ͟ǆϮϱ͛>^ƵĐŬĞƌƌŽĚƐǁͬϰy>ŐƵŝĚĞƐƉĞƌƌŽĚ dϳͬϴ͟ǆϮϱ͛>^ƵĐŬĞƌƌŽĚƐǁͬϰy>ŐƵŝĚĞƐƉĞƌƌŽĚ dв͟ǆϮϱ͛>^ƵĐŬĞƌƌŽĚƐǁͬϰy>ŐƵŝĚĞƐƉĞƌƌŽĚ d^ŝŶŬĞƌĂƌƐ;ϭϬͿĂŶĚƐƚĂďŝůŝǌĞƌďĂƌƐ;ϰͿ dZŽĚ WƵŵƉ d^ĂŶĚ^ĐƌĞĞŶ WZ&KZd/KEd/>KEEydW' Dy,K>E'>сϯΣΛϳ͕ϬϬϰ͛ &/^,d/>KEEydW' dŽƉŽĨĨŝƐŚ ΛϭϬ͕ϰϮϯ͛ 1HZ7XELQJ5DQ 1HZURGVUDQ 1HZSXPSUDQ hƉĚĂƚĞĚďǇDϬϮͲϮϰͲϮϮ tĞůů͗^hϯϮͲϬϴ WdϭϲϬͲϬϰϱ W/͗ϱϬͲϭϯϯͲϭϬϭϭϴͲϬϬͲϬϬ WZKWK^^,Dd/ &/^,d/> ηĞƉƚŚ>ĞŶŐƚŚ/KĞƐĐƌŝƉƚŝŽŶ & / ^ , ϭϬ͕ϰϮϯ͛ϭ͘ϭ Ϯ͘Ϯϱ ϯ͘ϲϴϴƵƉƚǇƉĞƐĞĂƚŝŶŐŶŝƉƉůĞ;dŽƉŽĨ&ŝƐŚͿ ϰ͘Ϭϵ͛Ϯ͘ϯϳϱ ϰ͘ϮϱŚĞŵŝĐĂů/ŶũĞĐƚŝŽŶ^Ƶď ϯϵ ϯ͘ϰϯϴ ϰ͘ϰ^ĐƌĞĞŶƐƐĞŵďůǇϬ͘ϬϬϴ͟ ϵϳ͘ϭϴϮϯ͘ϵϱϴ ϰ͘ϱůĂŶŬƉŝƉĞ ϭϬ͕ϱϭϵϬ͘ϳϱ Ϭ ϱ͘ϭϴϴƵůůWůƵŐ;ŽƚƚŽŵĨ&ŝƐŚͿ WZ&KZd/KEd/> ĂƚĞŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿŵƚŽŵŵĞŶƚƐ ϭϬͬϭͬϮϬϭϭ'ͲϭϭϬ͕ϯϳϲ͛ϭϬ͕ϯϵϲ͛ϭϬ͕ϯϳϯΖϭϬ͕ϯϵϯΖϮϬ͛WĞƌĨŽƌĂƚĞĚKĐƚŽďĞƌϮϬϭϭ 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Operations Abandon LJ Plug Perforations LJ Fracture Stimulate Li Pull Tubing Ll tdownLJ Performed: Suspend ElPerforate ElOther Stimulate ❑ ®�tI Alter Casing 1:1Ch%%if r ee rogram ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well El Re-enter Susp Well ❑ Other: Pull Rods & Pump Repair Q 2. Operator 4. Well Class Before Work: Hilcorp Alaska, LLC 5. Permit to Drill Number: Name: Development Q Exploratory ❑ 160-045 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6. API Number: AK 99503 50-133-10118-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA 028996 Soldotna Creek unit (SCU) 32-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 10,828 feet Plugs measured N/A feet true vertical 10,824 feet Junk measured 10,423 (fish) feet Effective Depth measured 10,631 feet Packer measured N/A feet true vertical 10,628 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation depth Measured depth See attached schematic True Vertical depth See attached schematic Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / L-80 10,359' MD 10,356' TVD Packers and SSSV (type, measured and true vertical depth) N/A; N/A N/A; N/A N/A; N/A N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 125 180 Subsequent to operation: 87 11 107 10 320 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 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 ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-533 Authorized Name: Taylor Wellman 777-8449 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkrameKoihilcoro com Authorized Signature: DateContact Phone: 777-8420 Form 10-404 Revised 4/2017 � �wz,. /, RBDMS K-/ MAR 0 4 2020 Submit Original Only *!� Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 32-08 Rig 401 50-133-10118-00 1 160-045 1/26/20 1 1/31/20 Daily Operations: 01/26/2020 -Sunday PJSM and PTW Truck equipment. Unload light plants and heaters off trucks. Rig up heater on the carrier to get it to start. Lay out felt and pit liner. Spot equipment. Spot base bean and carrier on pit liner. Spot dragon heater, tool connex, pusher shack, change shack, generator, bang board, and fuel tank. Rig up electrical connections. Install skirting around carrier and heat the carrier. SDFN. Night watch on tour to monitor heaters and rig. 01/29/2020- Wednesday PTSM, fire up eq & stage tools Cont. POOH t/ parted string pulled 2-8' 1" pony rods 79- 25' 1" EL sucker rods 7-25', 7/8" EL sucker rods, one 9.87', 7/8" parted sucker rod, = 2,222'^', clean break Clean & clear floor, M/U fishing BHA, xo coupling, 2-5/16" overshot assy w/ 7/8" grapple = 1.33' RIH t/2,222', tag TOF, up/dn wt 12k. Set do 2k, P/U 1k OP, set down 3k, pull t/26k, string movement, cont. Pull t/ 36k, work 2x pulling pump free, weight 26k. Clean & clear floor, r/u t/ pull, investigate drive line vibration. R/U hot oil truck pump 80 bbls produced down tubing t/ clean, @ 1.6-2bpm 250 psi POOH w/fish I/d broken rod w/overshot, cont. POOH racking back 56 stands. Secure well, night watch, monitor well rig & keep lights on. 01/30/2020 - Thursday Cont. POOH f/4,050' racking rod stands, L/D sink rods t/ pump assy. Surface test pump good, replace cups, function test good. TIH w/sink bars checking every connection, Troubleshoot & repair rod tongs Cont. RIH w/ pump asst' t/3,590', breaking every connection, cleaning inspecting & making up t/spec. Secure well, night watch rig & monitor well. 01/31/2020 - Friday PTSM Cont. RIH w/ pump assy.F/3,590', t/ 8,390", breaking every connection, cleaning inspecting & making up t/spec. Cont. RIH w/ pump assy, t/10,280', breaking every connection, cleaning inspecting & making up t/spec. remove stuffing box from old rod & install on new polish rod, flush tubing w/40 bbls PW, RIH seat pump & tag up plunger, space out, pull secondary BOP & stripper head, install stuffing box & polish rod, fill tubing & function test pump good, pressure up t/ 500 psi hold 10 min good. Ran PUMP w/screen, 10 25' sinker bars, 3 stab bars, 194 25'3/4" rods 128 25'7/8" rods, 78 25' 1" rods, 2- 8' 1" Pony Rods. 140' polish rod Secure well, night watch rig & monitor well. B Casi 10, Swanson River Field WellSCHEMATIC API:5-1SCU 3-011PTD00-045 API : 50-133-10118-00-00 lalcon, Aloe4e. LLC RKB: 143'/ GL: 128' AMSL New KB -THF: 15.00' CASING DETAIL Size WfGra Length Conn ID Top Btm 22" - 2.991" 7" Surface 28' 1" EL Pony Rods (8') 54. 5" 8RD 12.615" Surface 1,308' 13-3/8" DV Collar 12.615" 1,308' 1,310' 0.65' 54.5 J-55 8RD 12.615" 1,310' 3.014' 4.375" 28 P-110 8RD 5.791" Surface 115' 4.5" 24 N-80 BTC 5.921" 115' 6,477' 6-5/8" 24 P-110 8RD 5.921" 6,477' 7,996' DV Collar 5.921" 7,996' 7,998' 24 P-110 8RD 5.921" 7,998' 10,037' 28 P-110 8RD 5.791" 10,037' 10,828' TUBING DETAIL 2-7/8" 6.5 L-80 8RD 2.441" Surface 10,359' New Tubiag Ran 4/11/13 (replace 3 top jts 11/23/13) JEWELRY DETAIL # Depth Length ID OD Description 1 15' 62' 2.991" 7" Tubing Hangerl-Latch, w/ 2 joints of 3-1/2" tubing below hanger. 2 2,989' 1" EL Pony Rods (8') 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor 4 10,384' 0.65' 2.250" 3.5" Seating Nipple 5 10,390' 5.65' 4.375" 4.5" Perforated Joint 6 42' 61' 4.375" 4.5" 2-7/8" Tubing 6.4# BT 7 10,434' 0.44' 4.375" 4.5" Bull Plug ROD DETAIL 01/31/20 # Depth Length OD Description A -16' 40' 1-1/2" Polish Rod, 24' in well B 39' 16' 1" 1" EL Pony Rods (8') C 55' 1,950' 1" 1" x 25' EI -Sucker rods w/ 4 XL guides per rod (78) 2,005' 3,200' .875" 7/8"x25'EL Sucker rods w/ 4 XL guides per rod (128) 5,205' 4,850' .75" '/." x 25' EL Sucker rods w/ 4 XL guides per rod (194) C 10,044' 175' 1-1/2" 1-1/2" Sinker Bars (7) D 10,315' 42' 1.75' Weatherford 25-175-38-4-0-0 RHBC Rod Pump #7320 Max Stroke 391" — 80 Ring PA Installed 10/28/19 E 10,357' 1' 1.660" Sand Screen New Rods Ran 1028/19 (All rods/pump replaced/Re-ran Polish Rod) 'RATION DETAIL ON NEXT PAGE FISH DETAIL ON NEXT PAGE LE = 3° @ 7,004' Updated by DMA 02-06-20 Swanson River Field SCHEMATIC Well: SCU 50-133-10118-00-00 045 Qflmrn Alk.. LLC PERFORATION DETAII Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 H3 10,516' 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 H3 10,518' 10,533' 10,515' 10,530' 15 Re -perforated October 2011 10/16/1985 H3 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-01/10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 91 Re-perf 10-16-1985/06-10-1995/08-18-2001 / 10-02-2004 2/21/1961 H3 10,529' 10,530' 10,526' 10,527' 1' Re-perf 10-16-1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,50 10,563' 21' Re -perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re -pert 10-16-1985 / 08-18-2001 / 10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547 10,557' 10' Re-perf 10-16-1985/06-10-1995/08-18-2001 / 10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re -per' 10-16-1985/06-10-1995/08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re-perf 10-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10-16-1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re-perf 10-16-1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' 5gzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 1016-1985 2/21/1961 144/5 10,622' 10,678' 10,619' 10,674' S6' Sqzd 30-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) F I 4.09' 2.375 4.25 Chemical Injection Sub 5 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug (Bottom f Fish) Updated by DMA 02-06-20 11 STANDARD WELL PROCEDURE IfiIrori,.%laAaAlA. NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard 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 Transport. 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/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 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 Transport. 12/08/2015 FINALvl Page 1 of 1 s up Annulus) COILED TUBING UNIT N2 JETTING FLOW SCHEMATIC THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 32-08 Permit to Drill Number: 160-045 Sundry Number: 319-533 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www, a o g c c. a l a s k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, JPrice Chair DATED this _ ay of November, 2019. IBDMS -'j NOV 2 7 2019 RECEIVE® NOV 2 0 Ogg �-5 "�u/ AOGCC'� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n AAC 91;9Rn 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate © Repair Well ❑✓ Operations shutdown ❑ Suspend D Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Program❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Pull Rods &Pump Repair❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ 160-045 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-10118-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C0123B Will planned perforations require a spacing exception? Yes I] No ❑. Soldotna Creek Unit (SCU) 32-08 y 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA 028996 Swanson River Field / Hemlock Oil 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): 10,828' 10,824' 10,631' 10,628'—1,037psi N/A 10,631(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28, Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5# / L-80 10,359' Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A N/A N/A 12. Attachments: Proposal Summary r Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Strati ra hic g p ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 10, 2020 OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: 01NJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: So York 777-8345 Contact Name: Ted Kramer Authorized Title: Oper ins Manager Contact Email: tkra�com - '� .� Contact Phone: 777-8420 Authorized Signature: r p� Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1/\ el." 7 J\ ,519-533 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance Q Other: i1rZ, -- o �5Z .13DP ! L.S f-- -ABDMS tom' Nov 2 7 2019 Post Initial Injection MIT Req'd? Yes © No ❑ Spacing Exception Required? Yes ❑ No f�( Subsequent Form Required:(' APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /9 n I (1 I A Submit Form and #1(2evis Izb17 Approved applications f r�`y/n1p 1 f/rp�r a date of approval 7/�� achments in Duplicate N liil ora Alaska. Lb Well Prognosis Well: SCU 32-08 Date: 11/19/2019 Well Name: SCU 32-08 API Number: 50-133-10118-00-00 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: January 10, 2020 Rig: Rig 401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-045 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0065 (M) Second Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (M) AFE Number: Current Bottom Hole Pressure: — 1,500 psi @ 10,300` TVD (Fluid Level Calculations) Maximum Expected BHP: — 1,500 psi @ 10,300' TVD Max. Potential Surface Pressure: —1,037 psi (0.1 psi/ft gas gradient to surface) Brief Well Summary Soldotna Creek Unit 32-08 is a rod pump well with a Weatherford Roto -flex Unit. The rods were replaced in October 2019. The well ran 12 days and parted a rod. The purpose of this work/sundry is to pulls the rods to the part and see why the string parted after such a short runtime. The broken rod will be replaced and the well placed back on production. Notes Regarding Wellbore Condition Well is currently not producing on rod pump. Fish @ 10,423' — Fish consists of a screen, injection sub and a SN. Pre - Sundry Work • Disconnect Rotoflex Pumping Unit and push back out of way • Blow -down any pressure on the well and shoot fluid level (echometer) on casing. Workover Rig Procedure: 1. MIRU Rig#401. 2. Pump casing volume of produced water down annulus and bleed off any pressure. 3. Nipple up rod stripper head. 4. LD polish rod and pull EL rods standing back same. Note: Visually Inspect rods while pulling lookine for pits and cracks. 5. Fish broken rod and replace. 6. Run rods back in well and test pump action with the rig. a. Note: If pump action is bad, pull pump and replace, run back in well. 7. Hang off rod string. 8. ND Rod Stripper head and Tree. 9. RD 401. Turn well over to production. Contingency Plan- If unsuccessful fishing rod 10. ND wellhead, NU BOPE. �t� U Ilil..m Alaska, LL, Well Prognosis Well: SCU 32-08 Date: 11/19/2019 1. Test BOPE to 250 psi Low/Z 00 psi High, annular to 250 psi Low/ Snn psi High (hold each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Not AOGCC 24 hrs in advance of BOP test. b. Notification to ELM is not required. c. Perform Test. d. Test VOR rams on 2-7/8" testjoint. e. Email completed 10-424 form to all AOGCC addresses listed on the form within 5 days of BOPE test. 12. L/D BOP test equipment. 13. Ensure well is dead. 14. Pull tubing hanger free, unseat tubing anchor and POOH w/ tubing to rod part. Note: It is possible the tubing near the surface is worn. Check the top 4joints and if wear is found near surface, replace with new 2-7/8" tubing. 15. Rack back tubing string (2-7/8" 8RD) a. Inspect tubing for holes/worn joints. 16. Strip out rods and pump. kbj A„,: 17. Continue out of well to TAC. LD same. Continue pulling out of hole with tubing. 18. LD any bad joints and replace 2 joints above and below each bad joint. 19. RIH back in well with tubing and TAC. 20. Set tubing anchor one joint higher than the previous set depth. 21. Set TWC, ND BOPE, NU Tree and test to 3,000 psi, Pull TWC. 22. NU Rod Stripper. 23. Bucket test pump for pump action. If Pump is questionable, replace with new rod pump. 24. PU existing dip tube, and rod pump, replace and RIH with rods, sinker bars, 3/4", 7/8" and 1", space out the rods, install polish rod. 25. Fill tubing with PW, ND rod stripper. 26. Test wellhead and tubing to 1,000 psi, by stroking pump with rig or test pump. 27. RD Rig #401. 28. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 29. Return to production with same surface safety system as previously installed. 30. Replace IA x OA pressure gauge if removed (6-5/8" x 13-3/8"). Attachments: 1. Actual Schematic (Proposed Schematic will be the same as the Actual) 2. BOPE 3. Blank RWO Procedure Change Form Ca. Swanson River Field SCU IDL.o o ,Iv6�, r.� SCHEMATIC PI: 50-133-10118-00-00 045 RKB: 143'/ GL: 128' AMSL New KB—THF: 15.00' CASING DETAIL TD=10,828' PBTD=10,631' TUBING DETAIL 2-7/8" 6.5 L-80 8RD 2.441" Surface 10,359' New Tubing Ran 4/11/13 (replace 3 top jts 11/23/13) JEWELRY DETAIL # Depth Grade Conn ID Top Btm n 62' 2.991" 7" - Surface 28' 1" EL Pony Rods (8') 2.441" 1-55 8RD 12.615" Surface 1,308' 13-3/8" DV Collar 12.615" 1,308' 1,310' 0.65' 54.5 J-55 8RD 12.615" 1,310' 3.014' 4.375" 28 P-110 8RD 5.791" Surface 115' 4.5" 24 N-80 BTC 5.921" 115' 6,477' 6 -5/8 - 24 P-110 8RD 5.921" 6,477' 7,996' DV Collar 5.921" 7,996' 7,998' 24 P-110 8RD 5.921" 7,998' 10,037' 28 P-110 8RD 5.791" 10,037' 10,828' TUBING DETAIL 2-7/8" 6.5 L-80 8RD 2.441" Surface 10,359' New Tubing Ran 4/11/13 (replace 3 top jts 11/23/13) JEWELRY DETAIL # Depth Length ID OD Description 1 15' 62' 2.991" 7" Tubing Hanged -Latch, w/2joints of 3-1/2" tubing below hanger. 2 2,989' 1" EL Pony Rods (8') 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor 4 10,384' 0.65' 2.250" 3.5" Seating Nipple 5 10,390' 5.65' 4.375" 4.5" Perforated Joint 6 42' 61' 4.375" 4.5" 2-7/8" Tubing 6.4# IBT 7 10,434' 0.44' 1 4.375" 1 4.5" 1 Bull Plug ROD DETAII # Depth Length OD Description A 7' 40' 1-1/2" Polish Rod, 24' in well B 47' 16' 1" 1" EL Pony Rods (8') C 63' 1,975' 1" 1"x25'EL Sucker rods w/ 4 XL guides per rod (79) 2,038' 3,200' .875" 7/8" x 25' EL Sucker rods w/ 4 XL guides per rod (128) 5,2384' 4,850' .75" Y.." x 25' EL Sucker rods w/ 4 XL guides per rod (194) C 10,088' 175' 1-1/2" 1-1/2" Sinker Bars (8) D 10,348' 42' 1.75' Weatherford 25-175-38-4-0-0 RHBC Rod Pump#7320 Max Stroke 391"-80 Ring PA Installed 10/28/19 E 10,390' 1' 1.660" Sand Screen New Rods. 10/28/19 (All rods/pump replaced/Re-ran Polish Rod) (RATION DETAIL ON NEXT PAGE FISH DETAIL ON NEXT PAGE LE = 3° @ 7,004' Updated by DMA 11-06-19 Swanson River Field SCHEMATIC Well: SCU 50-133-10118-00-00 T0045 ll lcorn AMA.. LL( PERFORATION DETAII. Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,37fi' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 30-12-1985 10/16/1985 Hl 10,516' 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re -perforated October 2011 10/16/1985 Hl 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-01/10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 91 Re-perf 10-16-1985 / 06-10-1995 / 08-18-2001 /30-02-2004 2/21/1961 H3 10,529' 10,530' 10,526' 10,527' 1' Re-perf 10-16-1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re -perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re-perf 10-16-1985 / 08-18-2001 / 10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re-perf 10-16-1985 / 06-10-1995 / 08-18-2001 /10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re-perf 10-16-1985/06-10-1995/08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re-perf 10-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10-16-1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re-perf 10-16-1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 1-14/5 10,622' 10,678' 10,619' 10,674' S6' Sqzd 10-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) F I 4.09' 2.375 4.25 Chemical Injection Sub S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug (Bottom f Fish) Updated by DMA 11-06-19 \ i I I 2-1/16'5M MANUAL GATE VALVE 2-1/16"5M HCR 7-1/16" 5M ISA SPHERICAL ANNULAR 7-1/16" SM TRIPPLE RAM IE BOP (BLINDS INSTALLED IN BOTTOM BORE) "5M DRILLING SPOOL W/2-1/16" =TS STACK BOP, 71116'-5K ILLLowjk 1.1 U a U cd 14 En 03 Q U o A m .G 0 N d m U_ c U c N E L E OI O y C E - o 3 �- TE _0 c N N d-0.0 >� 0 m O 3 co co N C (0 N o N D) N C N R OIL c U Co N L w U 0 caa oi> m o a C' o CL R p C CL O R 3 aU @U �O O cQ E a`) a) U 0.& C _0 C N a) 3 � �E2 c. wo a� > 0 a a) CL > R o c Y co o 3 N 6% C `- O N (0 Y w T OU EU c O S =dmN > R Lim U R U c > O OffO I VX a as av N > W R =0 - CL c a d N YRaR 2 M y= L C a M � 'O a L Z „ QY Z d rn c R L U V 7 m U O a` d A m rn R a U d 0 w R 0 Y R •i. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS KL:ut:lVttj NOV 15 2019 1. Operations Abandon LJ Plug Perforations U Fracture Stimulate Ll Pull Tubing L4i Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: Pull Rods & Pump Repair ❑� 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 160-045 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-10118-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA 028996 Soldotna Creek unit (SCU) 32-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 10,828 feet Plugs measured N/A feet true vertical 10,824 feet Junk measured 10,423 (fish) feet Effective Depth measured 10,631 feet Packer measured N/A feet true vertical 10,628 feet true vertical NIA feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation depth Measured depth See attached schematic True Vertical depth See attached schematic Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / L-80 10,359' MD 10,356' TVD Packers and SSSV (type, measured and true vertical depth) N/A; N/A NIA; N/A N/A; NIA N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 90 25 Subsequent to operation: 0 71 69 90 250 14. Attachments (required per 20 AAc 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-444 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Manager Authorized Title: Operations Manager Contact Email: tkramer(rDhilcom.com Authorized Signature: %' AA,-_- /�r /yam ) }/' 1— 777-8420 pate: / /may Contact Phone: Form 10-404 Revised 4/2017 'u'! �l/�/b �1i-1g,rq Y IL/ ( �BDMS�T^,1(,d y NOV 18 2019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 32-08 Rig 401 50-133-10118-00 160-045 10/21/19 10/28/19 Daily Operations: 10/21/2019- Monday Truck all equipment to from SCU 24313-04, lay down rig containment, set base beam, position rig and scope up to 1/2 mast. R/U generator, heaters, bang board, and spot connex. Shoot a fluid level down the annulus at S,OOOFt. Tubing had 250psi on it. Staged blow down trailer and bled well down for 2hrs, well is still bleeding intermittently. Secure well for the night, install rig containment berms and SDFN. 10/22/2019-Tuesday PJSM and permit to work. Fire up rig, heaters generator. Tubing had 40psi on it after sitting over night, bled down to zero. Scope up derrick, secure guy lines, R/U rod basket and controls. R/U hot oil truck and pump 1.6 BBLs to fill the tubing. Pressure test tubing to 2,OOOpsi, TEST GOOD. Pump additional 60 BBLs of produced water down the annulus. R/U rig floor, handrails and rod handling equipment. R/D stuffing box on pump jack. R/U sucker rod BOP. Pull and lay down polished rod. POOH with sucker rods racking back. Pulled 2,OOOFt - 1" rods, 3,200Ft-7/8" rods, and 925Ft of 3/4" rods. Found broken rod at-6,125Ft. The upward facing pin is sheared off inside of the coupling on a 3/4" rod. Fishing OD will be 1.50". Secure well, secure racked back sucker rods, and SDFN 10/23/2019 - Wednesday PJSM, ensure Opsi on the well, fire up rig M/U series 10 overshot with 1.5" grapple on rod string and RIH with stands out of the derrick to 6145Ft. P/U weight 15k. Work and attempt to latch fish. Consulted Yellow Jacket on procedures. Couldn't latch fish, decision made to POOH and see what the overshot looked like. Repaired broken rod transfer cable. POOH from 6,145Ft racking rods back in the derrick. Series 10 1.5" overshot didn't have any markings on it from where it hit a fish. Consulted town and decided to RIH with SL tomorrow. Secure well and SDFN. 10/24/2019 - Thursday PJSM and R/U Pollard slickline with 2.24" OD LIB. RIH with 2.24" LIB and tag fisb-aI-fi,2QIEt-J?QC-FL LIB shows impression of parted sucker rod mirroring the piece we pulled out of the well. RIH w/ 1.5" ID series 10 overshot on 2-7/8" G-bait sub w/ 2-7/8" GS to 6,201Ft, set overshot, shear off GS. POOH. R/D Pollard slickline and R/U to RIH with GS on the end of rods. RIH with rods out of the derrick to 6,102Ft and latch fish. Up wt before latch was 15k, after latch entire rod string traveled at 25k stroking the pump. After pump stroke began over pull to unseat pump. Pulled to 28k and 1" rods parted 400Ft from surface. POOH racking back rods and found a pin had pulled the threads out of a coupling. M/U 2" ID Series 10 overshot on the end of the rods and RIH to 400Ft. Work and latch fish. Pull 22k and overshot released from fish. Worked overshot with no luck and POOH. Found the overshot internal spring completely pulled out of the overshot and was missing. M/U second 2" ID Series 10 overshot on the end of the rods and RIH to 400Ft. Work and latch fish. Pull 25k and overshot released from fish. Worked overshot with no luck and POOH. Found the overshot internal spring completely pulled out of the overshot and was missing. RIH with 1" rod coupling on rods and made it up to the upward facing pin on the fish. Able to get 6k overpull before the threads let loose. Tried 3x and POOH. M/U 1.875" Series 10 overshot on the end of the rods and RIH to 400Ft. Worked and tried to latch fish, couldn't latch. POOH. Consult town and fishing tool company. Decision made to secure well and SDFN. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 32-08 Rig 401 50-133-10118-00 160-045 10/21/19 10/28/19 Daily Operations: 10/25/2019 - Friday PJSM, fire up rig and heaters, ensure Opsi is on the well. M/U O'Bannon short catch overshot for with 1.25" ID and RIH on rods to 400Ft. Latch upward facing pin on the 1" rod, work and set grapple. Work weight up to 30k, weight broke back to 28K, climbed to 32K and broke back to 28k. Well went on a slight vacuum. POOH racking back rods in the derrick to 400FT. Break out and lay down fishing grapple and damaged rod. POOH racking back rods in derrick to 6,200Ft, lay down 1.5" ID series 10 overshot, GS bait sub, and parted rod. Continue out of hole racking back rods. Repair rod transfer air cylinder and sheave. RIH with rods from derrick from surface to 10,074Ft in preparation to lay down singles. Secure well and SDFN. 10/26/2019 -Saturday PJSM. Fire up rig, heaters and light plants. Verify 0 psi on the well. R/U hot oil truck and vac truck. Pump 140BBL at 1.5BPM of 190F produced water down the tubing to clean the rods and tubing. R/D hot oil truck and vac truck. POOH from 10074Ft laying down single rods. Lay down 191ea 3/4" rods, 128ea 7/8" rods, 75ea 1" rods. R/U Pollard slickline and RIH with 2.25" magnet to pump seat nipple at 10382Ft. POOH and had 6ea small pieces of series 10 2"OD spiral grapple 0.5" long. RIH with 2.4" OD wire brush to clean pump seat nipple, brushed pump seat nipple at 103841Ft and tagged bull plug at 10419Ft. POOH. RIH with 2.25" OD magnet to 10,382Ft tagged pump seat nipple. POOH, no pieces of grapple were on the magnet. R/D slickline, secure well and SDFN. 10/27/2019 -Sunday PJSM, service rig,fire up rig, heaters and light plants. Verify 0 psi on well. P/U Weatherford RHCB 38Ft X 1.75" rod pump and test with 5 gallons of fresh water. Pump operates per design. RIH with 10 1.5" weight bars and 4 stabilizer rods to 303Ft, rod lubing and checking torque on each connection. New vee -packing on pump was hanging up in the tubing. Added 5 gallons of diesel to tubing to lubricate. Pump didn't hang up after diesel was added. P/U singles and RIH w/ 194ea NEW 3/4" EL L/C guided rods with 4ea King Cobra 2.25" OD rod guides to 5,153FT. New couplings every connection, checking torque every 10 rods. P/U singles and RIH w/ 128ea NEW 7/8" EL L/C guided rods with 4ea King Cobra 2.25" OD rod guides to 8,353Ft. New couplings every connection, checking torque every 7 rods. P/U singles and RIH w/ 64ea NEW 1" EL L/C guided rods with 4ea King Cobra 2.25OD rod guides to 9,953Ft. New couplings every connection, checking torque every rod. Secure well and SDFN. 10/28/2019 - Monday PJSM, verify well has Opsi, fire up rig, heaters, light plants. P/U singles and RIH w/ 15ea NEW 1" EL L/C guided rods with 4 ea King Cobra 2.25OD rod guides to 10,384Ft. New couplings every connection, checking torque every rod. Seat pump and space out with (2) 8ft 1" EL L/C guided pony rods with lea King Cobra 2.25" OD rod guides. M/U polished rod and stuffing box. Pump left 36" off of bottom stroke and polished rod is 7Ft above stuffing box. Begin rig down waiting on vac truck and tripex pump to pressure test tubing. Full tubing with produced water using the vac truck —25BBL to fill tubing. R/U triplex pump and pressure test tubing to 1,OOOpsi. TEST GOOD. Scope down and lay over derrick, load trucks, R/D heaters, light plants, generator, and bang -board. Organize rods and couplings, remove pit liner and clean location. Load rig on low boy trailer and truck all equipment to SU 32-09. SDFN. Ca. ff ❑ilcorn AJ.4.. LLC RKB: 143'/ GL: 128' AMSL New KB—THF: 15.00' TD=10,828' PBTD=10,631' SCHEMATIC CASING DETAIL Swanson River Field Well: SCU 32-08 / PTD 160-045 API: 50-133-10118-00-00 Size WT Grade Conn ID Top I Bt, 22" - - - - Surface 28' 1" EL Pony Rods (8') 54.5 J-55 I 8RD 12.615" Surface 1,308' 13-3/8" DV Collar 12.615" 1,308' 1,310' 0.65' 54.5 J-55 .BIRD 12.615" 1,310' 3.014' 4.375" 28 P-110 8RD 5.791" Surface 115' 4.5" 24 N-80 BTC 5.921" 115' 6,477' 6-5/8" 24 P-110 8RD 5.921" 6,477' 7,996' DV Collar 5.921" 7,996' 7,998' 24 P-110 8RD 5.921" 7,998' 10,037' 28 P-110 BIRD 5.791" 10,037' 10,828' TUBING DETAIL 2-7/8" 6.5 L-80 8RD 2.441" Surface 10,359' New Tubing Ran 4/11/13 (replace 3 topjts 1123/13) JEWELRY DETAIL # Depth Length ID OD Description 1 15' 62' 2.991" 71, Tubing Hanger J -Latch, w/2joints of 3-1/2" tubing below hanger. 2 2,989' 1" EL Pony Rods (8') 2.441" 5" Marker Sub 3 10,294' 2.32' 2441" 6.625" Tubing Anchor 4 10,384' 0.65' 2.250" 3.5" Seating Nipple 5 10,390' 5.65' 4.375" 4.5" Perforated Joint 6 42' 61' 4.375" 4.5" 2-7/8" Tubing 6.4# IBT 7 10,434' 0.44' 4.375" 4.5" 1 Bull Plug ROD DETAIL # Depth Length OD Description A 7' 40' 1-1/2" Polish Rod, 24' in well B 47' 16' 1" 1" EL Pony Rods (8') C 63' 1,975' 1" 1"x25'EL Sucker rods w/ 4 XL guides per rod (79) 2,038' 3,200' .875" 7/8" x 25' EL Sucker rods w/ 4 XL guides per rod (128) 5,2384' 4,850' .75" W x 25' EL Sucker rods w/ 4 XL guides per rod (194) C 10,088' 175' 1-1/2" 1-1/2' Sinker Bars (8) D 10,348' 42' 1.75' Weatherford 25-175-38-4-0-0 RHBC Rod Pump #7320 Max Stroke 391" —80 Ring PA Installed 10/28/19 E 10,390' 1' 1.660" Sand Screen New Rods Ran 1028/19 (All rods/pump replaced/Re-ran Polish Rod) RATION DETAIL ON NEXT PAGE FISH DETAIL ON NEXT PAGE -E = 3" @ 7,004' Updated by DMA 11-06-19 Swanson River Field SCHEMATIC Pe1150-133-0118ppp0 045 11i1esra Alaska. LLC PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 Hl 10,516' 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re -perforated October 2011 10/16/1985 Hl 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-01/10-02-2004 2/21/1961 Hl 10,520' 10,529 10,517 10,526' 91 Re-perf 10-16-1985/06-10-1995/08-18-2001 / 10-02-2004 2/21/1961 Hl 10,529' 10,530' 10,526' 10,527' 1' Re-perf 10-16-1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re -perforated October 2011 6/10/1995 112 10,546' 10,550' 10,543' 10,547' 4' Re -pert 10-16-1985/08-18-2001/10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re-perf 10-16-1985/06-10-1995/08-18-2001 / 10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re-perf 10-16-1985/06-10-1995/08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re-perf 10-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 30-16-1985 2/21/1961 13 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re-perf 10-16-1985 2/21/1961 13 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 30-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10-36-1985 FISH DETAII Updated by DMA 11-06-19 th Length ID OD Description 23' t,F 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) 4.09' 2.375 4.25 Chemical Injection Sub S 39 3.438 4,4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug (Bottom f Fish) Updated by DMA 11-06-19 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 32-08 Permit to Drill Number: 160-045 Sundry Number: 319-444 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner K2 DATED this 2 day of October, 2019. RBDM51L OC i 0 3 2010 STATE OF ALASKA r )� y, ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS f 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well (] - Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑r . Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Pull Rods & Pump Repair❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 160-045 ' 3. Address: 3800 Cente oint Dr, Suite 1400 rP 6. API Number: Anchorage Alaska 99503 50-133-10118-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C01238 Will planned perforations require a spacing exception? Yes ❑ No 0 Soldotna Creek Unit (SCU) 32-08 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA 028996 Swanson River Field / Hemlock Oil 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): 10,828' 10,824' 10,631' 10,628'-1,037psi WA 10,631' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation Depth MD (ft): Perforation Depth TVDTubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5# / L-80 10,359' Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): NIA N/A WA 12. Attachments: Proposal Summary Wellbore schematic El 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: October 12, 2019 OIL ❑✓ • WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: iLramer@tfilcorp.com / Contact Phone: 777-8420 � � _ ? Authorized Signature f Date: � b � q 0 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test (( Mechanical Integrity Test ❑ Location Clearance ❑ Other: A a5 -0o Ps,: z3 r. s Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: /O _ qo9 �+ APPROVED BY Approved by6j��* COMMISSIONER THE COMMISSION Date: ` G A /Q �j/fit /�+� S b It and Form 10ao3,R sed a/zo1� II Approved applicati� idl 1` � seri the da ofap�dlrlblYlJ ` AU�n�,t n cte P"�•�� 1 ��111 L //V n Hil.m Alaska. W Well Prognosis Well: SCU 32-08 Date:9/25/2019 Well Name: SCU 32-08 API Number: 50-133-10118-00 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: February 27th, 2019 Rig: Rig 401 ✓ Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-045 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0065 (M) Second Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (M) AFE Number: Current Bottom Hole Pressure: — 1,500 psi @ 10,300' TVD (Fluid Level Calculations) Maximum Expected BHP: — 1,500 psi @ 10,300' TVD Max. Potential Surface Pressure: —1,037 psi (0.1 psi/ft gas gradient to surface) r7 "f % GSa- Brief Well Summary Z o Soldotna Creek Unit 32-08 is a rod pump well with a Weatherford Roto -flex Unit. The rods were last replaced in October 2014. In March 2019, the well was last pulled to replace the rod pump. The purpose of this work/sundry is to pulls the rods and repair/replace the pump and broken rod. �esF ccsJ� After pulling the rods, we will perform a fill check with Slickline. If the pump cannot be recovered fishing with rods, then the tubing may have to be pulled to recover the pump. This Sundry is written to pull the tubing. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump. • Surface equipment (Roto -flex unit) disconnected and rolled back. Ready for WO rig • Fish @ 10,423' — Fish consists of a screen, injection sub and a SN. Pre - Sundry Work • Disconnect Rotoflex Pumping Unit and push back out of way • Blow -down any pressure on the well and shoot fluid level (echometer) on casing. Workover Rig Procedure: 1. MIRU Rig #401. 2. Pump casing volume of produced water down annulus and bleed pressure. 3. Nipple up rod stripper head. 4. LD polish rod and pull EL rods standing back same. Note: Visually Inspect rods while pulling looking for pits and cracks. If Rods are in poor condition, contact Operations Engineer. 5. LD pump and dip tube. a. Inspect and bucket test pump. 6. Drop standing valve to test tubing. Test tubing to 2,000 psi. a. If tubing does not test, plan to pull the tubing. Go to step # 9. 7. RU Slickline and pull standing valve. 8. PU Blind box on SL and RIH and tag for fill. Bull plug @ 10,434'. POOH. RD SL. 1�_ IV K Hato Alask . LU Well Prognosis Well: SCU 32-08 Date: 9/25/2019 a. If tubing test good, re -run pump and rods, according to step 21 and continue from there. Otherwise, go to Step #9. 9. Set BPV. ND Rod Stripper head and Tree. a. If BPV does not seat or hold in hanger (possible cut threads) and lifting threads are intact, use blanking sub and test BOPE. Contingency if BPV or blanking sub do not work (perform rolling BOP test as follows): (Note: Well will not flow.) b. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. c. With stack out of the test path, test choke manifold per standard procedure % d. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) e. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. f. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) g. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 10. NU BOPE. 11. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each �,U ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. <v) a. Notify AOGCC 24 hrs in advance of BOP test. x b. Notification to BLM is not required. c. Perform Test. d. Test VBR rams on 2-7/8" test joint. e. Email completed 10-424 form to all AOGCC addresses listed on the form within 5 days of BOPE test. 12. L/D BOP test equipment. 13. Pump PW down tubing and casing to ensure well is dead. 1f1; Pull tubing hanger free, unseat tubing anchor and POOH w/ tubing. ksN Note: It is possible the tubing near the surface is worn. Check the top 4 joints and if wear is found near surface, replace with new 2-7/8" tubing. i 15. Rack back tubing string (2-7/8" 8RD) a. Inspect tubing for holes/worn joints. 16. LD bad joints and replace 2 joints above and below each bad joint. 17. RIH with tubing. 18. Set tubing anchor one joint higher than the previous set depth and land / set new tubing hanger. 19. Set TWC, ND BOPE, NU Tree and test to 3,000 psi, Pull TWC. 20. NU Rod Stripper. 21. PU existing dip tube, and new rod pump, replace and RIH with new rods as necessary in the string (sinker bars, 3/4", 7/8" and 1), space out the rods, install polish rod. 22. Fill tubing with PW, ND rod stripper. H Lll.n, Alaska. LL Well Prognosis Well: SCU 32-08 Date:9/25/2019 23. Test wellhead and tubing to 1,000 psi, by stroking pump with rig or test pump. 24. RD Rig #401. 25. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 26. Return to production with same surface safety system as previously installed. 27. Replace IA x OA pressure gauge if removed (6-5/8" x 13-3/8"). Attachments: 1. Actual Schematic (Proposed Schematic will be the same as the Actual) 2. BOPE 3. Blank RWO Procedure Change Form n IN—..Une4a. LLC. RKB: 143'/ GL: 128' AMSL New KB—THF: 15.00' TD = 10,828' PBTD = 10,631' Swanson River Field SCHEMATIC API: 50-133-10118-00 160-045 CASING DETAIL Size WF Grade Conn ID Top Btm 22" - - - - Surface 28' 1" EL Pony Rads (4', 6', 8') 54.5 1-55 8RD 12.615" Surface 1,308' 13-3/8" 6.625" DV Collar 4 12.615" 1,308' 1,310' 3.5" 54.5 J-55 8RD 12.615" 1,310' 3.014' Perforated Joint 28 P-110 8RD 5.791" Surface 115' 7 24 N-80 BTC 5.921" 115' 6,477' 1-1/4" Memory Gauge 24 P-110 8RD 5.921" 6,477' 7,996' 6-5/8" DV Collar 5.921" 7,996' 7,998' 24 P-110 8RD 5.921" 7,998' 10,037' 28 P-110 8RD 5.791" 10,037' 10,828' TUBING DETAIL 2-7/8" 6.5 L-80 I 8RD 1 2.441" 1 Surface 10,359' New Tubing Ran 4/11/13 (replace 3 top jts 1123/13) N Depth Length ID OD Description 1 15' 62' 2.991" 7" Tubing Hanger J -Latch, w/2joints of 3-1/2" tubing below hanger. 2 2,989' 1" EL Pony Rads (4', 6', 8') 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor 4 10,384' 0.65' 2.250" 3.5" Seating Nipple 5 10,390' 5.65' 4.375" 4.5" Perforated Joint 6 38.57' 61' 4.375" 4.5" 2-7/8"Tubing 6.4#IBT 7 1 16,434' 1 0.44' 4.375" 4.5" 1 Buil Plug ROD DETAIL # Depth Length OD Description A 36' 40' 1-1/2" Polish Rod, 24' in well B 76' 18' 1" 1" EL Pony Rads (4', 6', 8') C 94' 2,000' 1" 1"x25'EL Sucker rods w/ 4 XL guides per rod (80) 2,094' 3,200' .875" 7/8" x 25' EL Sucker rods w/ 4 XL guides per rod (128) 5,294' 4,850' .75" Y"x25'EL Sucker rods w/ 4 XL guides per rod (194) C 10,144' 200' 1-1/2" 1-1/2" Sinker Bars (8) D 10,344' 38.57' 1.75' 215" x 175" RHBC Rod Pump part #2283168-80 Ring PA Installed 12-15-16 (03/04/19) E 10,386' 4' 1.660" Perforated Diptube F 10,390' 2.5' 1.250" 1-1/4" Memory Gauge New Rods Ran 10/02/14 (All rods/pump replaced/Re-ran Polish Rod) )RATION DETAIL ON NEXT PAGE FISH DETAIL ON NEXT PAGE LE = 3- @ 7,004' vnhole Revised: 10/02/14 Updated by DMA 03-15-19 K Swanson River Field SCHEMATIC Well: I II:50-133-10118-00 160-045 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re -perforated October 2011 10/16/1985 HS 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-01/ 30-02-2004 2/21/1961 Hl 10,520' 10,529 10,517' 10,526' 9' Re-perf 10-16-1985/06-10-1995/08-18-2001 / 10-02-2004 2/21/1961 H1 10,529' 10,530' 10,526' 10,527' 1' Re-perf 10-16-1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re -perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re-perf 10-16-1985 /08-18-2001/10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re -pert 10-16-1985 /06-10-1995 /08-18-2001 / 10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re -pert 10-16-1985 /06-10-1995 /08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re-perf 10-16-1985 2/21/1961 112 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10-16-1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 113 10,592' 10,600' 10,589' 10,597' 8' Re-perf 10-16-1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 114/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) F I 4.09' 2.375 4.25 Chemical Injection Sub 5 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug (Bottom f Fish) Downhole Revised: 10/02/14 Updated by DMA 03-15-19 8 1 7 16 5 4 1 3 1 2 11 BILL OF MATERIAL ITEM ON PART NUMBER DESCRIPTION 1 1 SA705-00013 NNULAR BOP ASSEMBLY, STUDDED TOP X FLG BTM, [SAX ABOP 7 1/165000 MWP PR1 (65.3) 2 1 70-0705-0W29 ASSEMBLY, RBOP 7 1/16-5000 MWP, PR1, STUDDED BOTTOM ITRBOP X TOP WITH 3 21/16-5K MWP STUDDED OUTLET D D 1 1 (30.9) O C O �^ 0 ®OG'J49@mm' 0 0� TOP BORE-2.3/8' PIPE RAMS �� 0 ®OGvm@I'�QQQ� O o �- MID RAMSSORE-2-7/8'PIPE 29.6 (29.8) 1 BOTTOM BORE--C80 RAMS O®O IGiTGPC�iG3'. Q BD O n B B 2-1/16" 5M MANUAL GATE VALVE 2-1/16" 5M HCR MIBNC M�AMXoµ 111E UNLESS OTHERWISE SPECIFIED EYECI ECN DEBCRIKON WTE BY DESCRIPTION EDxFAFx155 1XEBClEPNDE%CWBIY£PXOF4XTV NAME pgTE ^^^� SNOT BCNEMISORPtMN TOLEPANCE N9DNE Ix INCxEB.,„X_.,NR uwRANBEoxXLIxc MNsrstPAooLE A M WIEfAAIEDEWIPMENIPNDExMA _T TDE USE olsaosEo.cR ccWEo STACK BOP, 71/16"-5K YELLOWJACKET p A P+M EEp01ECRVAiIO ex x—s.o8 FFB KS 91812)19 PEPMq FGUIPMBR.MISCDCNNEHIIBLWIW E%C6PTWXEN MOMNEo. _ BRFPXSMMPEM 5 O15NWNIIM 015 CMNEFRMII ONMWIMYM Vx—t'�8 OILPIFLC 9E0.VICEB W_TTOTGREEMEM__E Exmzm a+oTLB. gEWINDMC MLK—E .ED INAY 81&2019 .I TOIMFgMTm EOIMEMEM.UVCN CEMwq NI.N @ SpNMyEIESS PART NO. TEWIFlgll RESERVESTXE RIBxTTocxwSE — ' REV µC1 PdECi'WMD'. EINISNX1nMs MATERIAL: SEE BOM -- &PFMAMk6WImwrNonce PW 31-001147 8 7 6 5 4 3 2 1 Y d a O F\ Ulf 1� LE d y r L o d m U_ L U C � E L E -- E m 0.9 C E C = m CL TE C 0 3 O N '0.0 0)'a o `o. nv m o c (0.9 o am N m CD= C U f0 N U 0 o a Q C- a) m O C CL= Cu 3 �U cu L) -00 °' O c Q N E U o rn N � N 3 v Z' a a N Q RL(D n 0 Co 0 C Y @O 0 3 N 0 0 CU Y w T oU EO c c N y d � R Y U ❑ cu U Rcu c C9o00 ay a-- N N R CL c Q NN R S d m r c CL M Cl. Ma d�> Z d rn c m L U L 7 a d O a` ed+ ❑ m rn m a V m ❑ 2 'O m Q 2 IL Y m ❑ LL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RE 0 E � VBE) MAR 1 F 2rl9 1. Operations Abandon Ll Plug Perforations LJ Fracture Stimulate Li Pull Tubing LJ Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ .rforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Other: Pull Rods & Pump Repair ❑✓ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 160-045 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-10118-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA 028996 Soldotna Creek unit (SCU) 32-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 10,828 feet Plugs measured N/A feet true vertical 10,824 feet Junk measured 10,631 (fill) feet Effective Depth measured 10,631 feet Packer measured N/A feet true vertical 10,628 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation depth Measured depth See attached schematic True Vertical depth See attached schematic Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / L-80 10,359' MD 10,356' TVD Packers and SSSV (type, measured and true vertical depth) N/A; N/A N/A; N/A N/A; N/A N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 0 0 110 1 250 Subsequent to operation: 1 34 25 110 150 1 415 14. Attachments (required per 20 nnc 25.070, 25.071, & 25,283) 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 L✓j Gas LJ WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-080 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email:tkramerroDhilcom .com Authorized Signature: 1 @ r1 Date: 1 11 I �W)dA 4%1 Contact Phone: 777-8420 Form 10-404 Revised 4/2017 3BDMS./ MAR 191019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number start Date End Date SCU 32-08 Rig 401 1 50-133-10118-00 1 160-045 2/26/19 1 3/5/19 Daily Operations: 02/26/2019-Tuesday AAO crew at farm yard finishing 401 rig. Load out to location. Crews arrive at Swanson River field. Hold safety meeting and orientation at the HOA facility. Lay pit liner and spot in 401 carrier. Steer drag link broke on carrier. Unable to articulate front end. Call mechanics. Mechanics fixed 401 drag link. Continue to RU in the am. 02/27/2019- Wednesday PTW. Safety meeting. Continue rigging up 401. Crews went from 6 part line to 4 part line. Position rig on well. Stand mast. Move in dragon heater and fuel tank.Troubleshoot transmission. Rig up Rod handling gear. 02/28/2019 -Thursday Permit to work. Hold safety meeting. 401 carrier won't start. Jump start rig. Install berm around rig. Lay down traction grating around common walkways around rig. Raise drill console and drillers platform. Not able to find lower platform at farm yard. Hook up airlines to rod basket and rod transfer cylinder. Unload weaver trailer with new rods from Weatherford. 401 carrier keeps dying. Test Crown-0-matic. The crown-o-matic no go tab sheared off brake shaft. Call out rig mechanic and welder. Organize parts connex and pusher shack while awaiting repairs. Mechanic on location. Assist with alternator swap and charge batteries. Welder on location. Add to PTW . Obtain Hot work permit. Assist welder in reattaching stop plate on brake linkage (fix crown-o-matic). Location secure. 03/01/2019 - Friday Permit to work. Hold safety meeting with AAO crew. Perform oil checks. Fire rig and equipment. Fuel equipment. Hold tailgate meeting on proper rod handling techniques. Remove Rod head and pack off box from tree. Lay down with polished rod. install rod wiper box on tree. Lay down 4', 6', 8' pup joints. Rod transfer cable to short and wrong saddle clamps. Wait on parts. New cable on location and correct wire rope clamps. Start pulling rods standing back triplex in rod basket. Inspect rod box and collars as removed. Rods look to be in good shape. Pull all sinker/weight bars. Found rod part at top of pump. 1.5" sub that connects to the polished bore of the reciprocating pump rod of .875" OD. Top of fish 10,306.5' MD. Pull pump off trailer. Measure and take pictures for reference. Fish neck is 1-5/8". Dress series 10 overshot with 1-5/8" grapple. Install TIW valve on tree. Well secure for the night. Rig mechanics on location to change out all air lines and fittings in rod box. All crews off location. 03/02/2019-Saturday Permit to work. Hold JSA. Fuel rig. Service equipment. Grease Crown, draworks, blocks, and power tongs. Bleed well down. Modify long catch Series 10 overshot. Make up weight bars. Install overshot. TIH with rods. Tag top of fish at 10,306.5'. Work rod assembly. Latched up to fish. 23k normal weight. Pulled to 30k slowly and weight broke back to 23k. Attempt to slack off to latch overshot. Couldn't get overshot to latch. Trip OOH. No fish recovered. Inspect overshot grapple. Teeth were folded. Possibly why we weren't able to re-latch. Well secure. SDFN. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 32-08 1119401 50-133-10118-00 1 160-045 2/26/19 1 3/5/19 Daily Operations: 03/03/2019-Sunday Permit to work. Hold safety meeting with AAO crew. Rig maintenance. Bleed off well. 20 psi. Pick weight bar. Make up series 10 overshot with 1.625" Grapple insert. RIH with rods and overshot. Tag fish at 10,306.5'. Work overshot for .5 hrs. Up weight and slack off weight 22.5K. Over pulled to Max 33k and dragged 30k. Pump unseated. POOH with rods nd pump. Lay down BHA (Rod pump). Secure well. Fuel equipment. Change out tugger line. 03/04/2019 - Monday Permit to work. Safety meeting. Check fluids. Rig maintenance. Load 70 bbls in Vac truck. Bring hot oil truck to location. Pump 65 bbls of lease water at 175*F down tubing to clean tubing walls and clear tubing of any sand/debris. PU new 2.25" OD x 39.4' rod pump. Extend pump piston. Use Emry cloth to clean polished piston. Small amounts of surface rust. Perform bucket test to ensure pump is pulling fluid. Install dip tube. RIH with previous rod assembly. 2.25" OD x 39.4' rod pump, 8x 1.5 " weight bars, 194 x3/4" EL rods, 128x 7/8" rods, 80x 1" rods. Space out rods. Pu rod stretch. Pump 30" off bottom. Install clamp. Pump 18 bbls of crude oil into tubing to fill. Stroke pump and watch flow. Close valve and pressure up tubing with rod pump to 600 psi. Secure well. Clean up location. Rig down vac truck and hot oil truck. Mobe to P&S yard. SDFN. 03/05/2019-Tuesday PTW. Safety meeting. Rig down HAK 401. Trailer to farm yard. Pump methanol down flow line. 100 gallons. Communication at tank setting. Rlg up flow lines. Slide rotoflex forward and hook up polished rod. Well online pumping. Ca Swanson River Field Well: 50 1 3� 0 18 00160-045 SCHEMATIC Hilar, Al.". LLC RKB: 143'/ GL: 128' AMSL New KB—THF: 15.00' TD =10,828' PBTD =10,631' USING DETAIL Size WT Grade Conn ID Top Btnn 22" - - - - Surface 28' 18' 54.5 1-55 8RD 12.615" Surface 1,308' 13-3/8" DV Collar 12.615" 1,308' 1,310' 0.65' 54.5 J-55 8RD 12.615" 1,310' 3.014' 4.375" 4.5" 28 P-110 8RD 5.791" Surface 115' 2-7/8" Tubing 6.4# IBT 24 N-80 B7C 5.921" 115' 6,477' E 24 P-110 8RD 5.921" 6,477' 7,998 6-5/8" DV Collar 5.921" 7,996' 7,998' 24 P-110 8RD 5.921" 7,998' 10,037' 28 P-110 8RD 5.791" 10,037' 10,828' TUBING DETAIL 2-7/8" 6.5 L-80 I 8RD 1 2.441" Surface 10,359' New Tubing Ran 4/11/13 (replace 3 top jts 1123/13) # Depth Length ID OD Description 1 15' 62' 2.991" 7" Tubing Hanger J -Latch, w/ 2 joints of 3-1/2" tubing below hanger. 2 2,989' 18' 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor 4 10,384' 0.65' 2.250" 3.5" Seating Nipple 5 10,390' 5.65' 4.375" 4.5" Perforated Joint 6 10,144' 61' 4.375" 4.5" 2-7/8" Tubing 6.4# IBT 7 10,434' 0.44' 4.375" 4.5" Bull Plug ROD DETAIL # Depth Length OD Description A 36' 40' 1-1/2" Polish Rod, 24' in well B 76' 18' 1" 1" EL Pony Rods (4', 6', 8') C 94' 2,000' 1" 1" x 25' EL Sucker rods w/ 4 XL guides per rod (80) 2,094' 3,200' .875" 7/8" x 25' EL Sucker rods w/ 4 XL guides per rod (128) 5,294' 4,850' .75" 'h" x 25' EL Sucker rods w/ 4 XL guides per rod (194) C 10,144' 200' 1-1/2" 1-1/2" Sinker Bars (8) D 10,344' 38.57' 1.75' 2.25" x 175" RHBC Rod Pump part #2283168-80 Ring PA Installed 12-15-16 (03/04/19) E 10,386' 4' 1.660" Perforated Diptube F 10,390' 2.5' 1.250" 1-1/4" Memory Gauge New Rods Ran 10/02/14 (All rods/pump replaeed/Re-ran Polish Rod) )RATION DETAIL ON NEXT PAGE FISH DETAIL ON NEXT PAGE LE = 3° @ 7,004' ✓nhole Revised: 10/02/14 Updated by DMA 03-15-19 Swanson River Field SCHEMATIC Well: 50-133-10118-00160-045 Nilcorn Al&Ak LLC PERFORATION DETAII Date Zone Top(MD) Btm(MD)KAD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396'3' F I 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497'3' 39 10,494' 1' Squeezed 10-12-1985 10/16/1985 H1 10,516' 10,518'3' 10,515' 2' Re -pert 08-18-01 10/1/2011 H3 10,518' 10,533'5' 10,530' 15 Re -perforated October 2011 10/16/1985 Hl 10,518' 10,520'5' 10,517' 2' Re -pert 08-18-01/10-02-2004 2/21/1961 H3 10,520' 10,5297' 10,526' 91 Re-perf 10-16-1985/06-30-1995/08-18-2001 / 10-02-2004 2/21/1961 Hl 10,529' 10,530'' 10,527' 1' Re-perf 10-16-1985 10/16/1985 Hl 10,530' 10,532'' 10,529' 28/18/2001 H2 10,543' 10,545'' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re -perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re-perf 10-16-1985/08-18-2001/10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re-perf 10-16-1985/06-30-1995/08-18-2001 /10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re-perf 10-16-1985/06-30-1995/08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re-perf 10-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 30-16-1985 2/21/1961 H3 10,580' 10,584' 4' Sqzd 10-16-1985 10/16/1985 H3. 10,585' 10,592' 89' 7' 2/21/1961 H3 10,592' 10,600' U10,57710,581,81' 97' 8' Re-perf 10-16-1985 2/21/1961 H3 10,600' 10,603' 0' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 3' 8'Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 0,619 10,628' 9' Sqzd 10-16-1985 2/21/1961 1-14/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10-16-1985 FISH DETAIL # Depth Length Description 10,423' 1.1 Cup type seating nipple (Top of Fish) F I 4.09' :M3.9584.5 Chemical Injection Sub S 39 Screen Assembly 0.008- H 97.182 Blank pipe 10,519 0.75 Bull Plug (Bottom f Fish) Downhole Revised: 10/02/14 Updated by DMA 03-15-19 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 32-08 Permit to Drill Number: 160-045 Sundry Number: 319-080 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this Z4 day of February, 2019. .161019 EtBDM� D'� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 90 AAc 95 9Rn .E IV D FEB 2 1 20 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 10 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 10 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Aker Casing ❑ Other: Pull Rods & Pump Repair ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 160-045 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-10118-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C0123B ❑ D Soldotna Creek Unit (SCU) 32-08 ' Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA 028996 Swanson River Field / Hemlock Oil ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 10,828' 10,824' 10,631' 10,628'—1,037psi N/A 10,631' (fill) Casing Length Size MD ND Burst Collapse Structural Conductor 28' 22^ 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-718" 6.5# / L-80 10,359' Packers and SSSV Type: N/A Packers and SSSV MD (ft) and ND (ft): N/A N/A N/A 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: February 27, 2019 OIL ❑Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: 91 -fps i — 7 Date: 9 ,.a 2— IQ Commission Representative: S � kv GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoirp is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-6345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerCothilcoro corn Contact Phone: 777-8420 1 Authorized Signature: Date: —)—IF L, 101 COMMISSION USE ONLY Conditions of approval: No ify Commission so that a representative may witness Sundry Number: U U V Plug Integrity ❑ BOP Test Mechanical Integrity Test El Location Clearance El Other: 2 SAO % 5 �• 8 / 6 (f j 5'r �s -� La,% r /ti !ij r ..c��•C-SIC, Post Initial Injection MIT Req'd? Yes No�Q19 Spacing Exception Required? Yes ❑ No ,� Subsequent Form Required: / © Rg��VIS``Fill / // 7.r APPROVED BY /Z6//7 Approved by: COMMISSIONER THE COMMISSION Date:G `/ rm` / IL — �ZSubmit Form and 6Drm`10-403 Revised 4/2017 Approved application i a d o 1 monts rom the date of approval/Attachments in plicate X79 y� /� H Hi1wrY Alaska, LG Well Prognosis Well: SCU 32-08 Date: 2/21/2019 Well Name: SCU 32-08 API Number: 50-133-10118-00 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: February 27t", 2019 Rig: Moncla 401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-045 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0065 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Bottom Hole Pressure: - 1,500 psi @ 10,300' TVD (Fluid Level Calculations) Maximum Expected BHP: - 1,500 psi @ 10,300' TVD Max. Potential Surface Pressure: -1,037 psi (0.1 psi/ft gas gradient to surface) Brief Well Summary Soldotna Creek Unit 32-08 is a rod pump well with a Weatherford Roto -flex Unit. The rods were last replaced in October 2014. In December 2016, the Well was last pulled to repair a tubing leak. The purpose of this work/sundry is to pulls the rods and repair/replace the pump and broken rod. We will then pressure test the tubing to insure it is in good condition. If the tubing passes the pressure test, then the rods and new pump will be re -ran and the well placed back on production. If the tubing fails the pressure test, BOPE equipment will be rigged up and the tubing will be pulled to locate and repair a tubing leak. w Notes Regarding Wellbore Condition kwo `te f • Well is currently not producing on rod pump. r �. • Surface equipment (Roto -flex unit) disconnected and rolled back. Ready fo WO rig • On 8/1/16 a fluid level measurement was collected with an Echometer at 8,160' with well flowing and 60 psi on the casing. Workover Rig Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing. 2. MIRU Rig#401. 3. Pump casing volume of produced water down annulus and bleed pressure. 4. Nipple up rod stripper head. 5. LD polish rod and pull EL rods standing back same. Note: Visually Inspect rods while pulling looking for pits and cracks. If Rods are in poor condition, contact Operations Engineer. �( 6. LD pump and dip tube. ,fJ a. Inspect and bucket test pump. 7. Drop standing valve to test tubing. Test tubing to 2,000 psi. a. If tubing test good, re -run pump and rods, according to step 21 and continue from there. Otherwise, go to 7b. b. If tubing does not test, plan to pull th tubing. 8. RU Slickline and pull standing valve. 9. Set BPV. NO Rod Stripper head and Tree. I Well Prognosis Well: SCU 32-08 nileorp Alaska, LG Date: 2/21/2019 a. If BPV does not seat or hold in hanger (possible cut threads) and lifting threads are intact, use blanking sub and test BOPE. Contingency if BPV or blanking sub do not work (perform rolling BOP test as follows): b. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. c. With stack out of the test path, test choke manifold per standard procedure d. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) e. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the ((� well. Record the pumping rate and pressure. Once the BOP ram and annular tests are completed, test the remainder of the system y following the normal test procedure (floor valves, gas detection, etc.) g. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 10. NU BOPE. 11. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each pra t for 5 -min). Record accumulator pre -charge pressures and chart tests. (3D\ v////// a. Notify AOGCC 24 hrs in advance of BOP test. b. Notification to BLM is not required. c. Perform Test. d. Test VBR rams on 2-7/8" testjoint. e. Email completed 10-424 form to all AOGCC addresses listed on the form within 5 days of BOPE test. 12. L/D BOP test equipment. 13. Pump PW down tubing and casing to ensure well is dead. 14. Pull tubing hanger free, unseat tubing anchor and POOH w/ tubing. Note: It is possible the tubing near the surface is worn. Check the top 4 joints and if wear is found near surface, replace with new 2-7/8" tubing. 15. Rack back tubing string (2-7/8" 8RD) a. Inspect tubing for holes/worn joints. 16. LD bad joints and replace 2 joints above and below each bad joint. 17. RIH with tubing. 18. Set tubing anchor one joint higher than the previous set depth and land / set new tubing hanger. 19. Set TWC, ND BOPE, NU Tree and test to 3,000 psi, Pull TWC. 20. NU Rod Stripper. 21. PU existing dip tube, and new 1-3/4" rod pump, replace and RIH with new rods as necessary in the string (sinker bars, 3/4", 7/8" and 1), space out the rods, install polish rod. 22. Fill tubing with PW, ND rod stripper. 23. Test wellhead and tubing to 1,000 psi, by stroking pump with rig or test pump. 24. RD Rig #401. 25. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 26. Return to production with same surface safety system as previously installed. 27. Replace IA x OA pressure gauge if removed (6-5/8" x 13-3/8"). Attachments: 1. Actual Schematic (Proposed Schematic will be the same as the Actual) 2. BOPE 3. Blank RWO Procedure Change Form Well Prognosis Well: SCU 32-08 Date: 2/21/2019 Swanson River Field SCHEMATIC Well: SCU 50-133-10118-00 160-045 Ink. Alaelu. LLC RKB: 143'/ GL: 128' AMSL New KB—THF: 15.00' TD=10,828' PBTD=10,631' CASING DETAIL Size WT Grade Conn ID Top Btm 22" - - - - Surface 28' 1" EL Pony Rods (4', 6', 8') 54.5 1-55 8RD 12.615" Surface 1,308' 13-3/8" DV Collar 12.615" 1,308' 1,3101 0.65' 54.5 1-55 8RD 12.615" 1,310' 3.014' 4.375" 28 P-110 8RD 5.791" Surface 115' 4.5" 24 N-80 BTC 5.921" 115' 6,477' Bull Plug 24 P-110 8RD 5.921" 6,477 7,996' 6-5/8" DV Collar 5.921" 7,996 7,998' 24 P-110 8RD 5.921" 7,998' 10,037' 28 P-110 8RD 5.791" 10,037' 10,828' TUBING DETAIL 2-7/8" 1 6.5 L-80 I 8RD 1 2.441" Surface 10,359' New Tubing Ran 4/11/13 (replace 3 top jts 11/23/13) # Depth Length ID OD Description 1 15' 62' 2.991" 7„ Tubing Hanger J -Latch, w/ 2 joints of 3-1/2" tubing below hanger. 2 2,989' 1" EL Pony Rods (4', 6', 8') 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor 4 10,384' 0.65' 2.250" 3.5" Seating Nipple 5 10,3901 5.65' 4.375" 4.5" Perforated Joint 6 42' 61' 4.375" 4.5" 2-7/8" Tubing 6.4# 1 B 7 10,434' 0.44' 1 4.375" 4.5" Bull Plug ROD DETAIL # I Depth I Length OD Description A 36' 40' 1-1/2" Polish Rod, 24' in well B 76' 18' 1" 1" EL Pony Rods (4', 6', 8') C 94' 2,000' 1" 1" x 25' EL Sucker rods w/ 4 XL guides per rod (80) 2,094' 3,2001 .875" 7/8" x 25' EL Sucker rods w/ 4 XL guides per rod (128) 5,294' 4,850' .75" V" x 25' EL Sucker rods w/ 4 XL guides per rod (194) C 10,144' 200' 1-1/2" 1-1/2" Sinker Bars (8) D 10,344' 42' 1.75' 1-3/4" x 42' Insert Pump, RHBC Pump w/ PA Ring 80 PA Ring, Sand Seal, 2-1/2" x 1-3/4" x 36" x 36-1/2" x 37" RHBC E 10,386' 4' 1.660" Perforated Diptube F 10,390' 2.5' 1.250" 1-1/4"Memory Gauge New Rods Ran 10/02/14 (All rods/pump replaced/Re-ran Polish Rod) )RATION DETAIL ON NEXT PAGE FISH DETAIL ON NEXT PAGE SLE = 3- @ 7,004' vnhole Revised: 10/02/14 Updated by DMA O1-09-17 Swanson River Field PI: 50-133- 18 016°-°45 SCHEMATIC32-08 Hilrnrn M.A.. LLC PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 H3 10,516' 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 H3 10,518' 10,533' 10,515' 10,530' 15 Re -perforated October 2011 10/16/1985 Hl 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-03/3002-2004 2/21/1961 H3 10,520' 10,529 10,517' 10,526' 9' Re-perf 10-16-1985/06-10-1995/08-18-2001 /30-02-2004 2/21/1961 Hl 10,529' 10,530' 10,526' 10,527' 1' Re-perf 1016-1985 10/16/1985 H3 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re -perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re-perf 1016-1985 / 08-18-2001 / 10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re-perf 10-16-1985/06-30-1995/08-18-2001 / 10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re-perf 10-16-1985/06-10-1995/0818-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re-perf 10-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 1016-1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re-perf 10-16-1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1951 H3 10,608' 10,616 10,605' 10,613' 8' Sqzd 1016-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 30-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) F I 4.09' 2.375 4.25 Chemical Injection Sub S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug (Bottom f Fish) Downhole Revised: 10/02/14 Updated by DMA 01-09-17 HILCORP ALASKA 7-1/16" 5M BOPE 7-1/16" SM HYDRIL GK ANNULAR 32" TALL, FLANGE TO FLANGE 7-1/16" SM LWS DBL GATE BOP DRESSED W/VARIABLE RAMS IN TOP DRESSED W/BLIND RAMS IN BOTTOM FLANGE TO FLANGE 7-1/16" 5M DRILLING SPOOL W/2-1/16" 5M OUTLETS 18" TALL, FLANGE TO FLANGE —77" TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: - 3.30 gallon open chamber volume - 3.86 gallon close chamber volume GATE STYLE BOP SPECS: -1.45 gallons to close per gate - 1.18 gallons to open per gate 5.45:1 closing ratio 1.93:1 opening ratio UHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SCU 32-08 (PTD 160-045) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC 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 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, February 22, 2019 12:28 PM To: 'Ted Kramer' Cc: Donna Ambruz, Davies, Stephen F (DOA) (steve.davies@alaska.gov) Subject: RE: SCU 32-08 AOGCC 10-403 Submitted 02-21-19 Ted, Verbal approval granted for steps 1-7 on the sundry. This includes pulling rods only .. if BOPE are needed to pull tubing the final sundry approval is needed. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal low. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv.schwartz@olaska.aovl. From: Ted Kramer <tkramer@hilcorp.com> Sent: Friday, February 22, 2019 11:38 AM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: FW: SCU 32-08 AOGCC 10-403 Submitted 02-21-19 Guy, Hilcorp Requests verbal approval to move the Rig 401 to SCU 32-08 and to perform the Rod repair portion of the attached Sundry Request. This request is made so that Hilcorp can complete a Category 3 & 4 inspection on the Rig 401 and then repair a rod part. Hilcorp in support of this request offers that the rod repair will not require the well head to be removed so well control can be maintained during this operation. If the pump is stuck and cannot be removed (requiring the tubing to be pulled), and rigging up BOPE equipment is required, Hilcorp agrees to stop and wait for the approved sundry. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Ted Kramer Sent: Thursday, February 21, 2019 10:57 AM To: Schwartz, Guy L (DOA) (guy schwartz alaska.Kov) «uy schwa rtz@alaska.eov> Subject: FW: SCU 32-08 AOGCC 10-403 Submitted 02-21-19 Guy, Attached is a Sundry to Repair a rod part SCU 32-08 which we are sending over today. I am writing and attaching a copy because we are asking that this Sundry be expedited for the following reason: Hilcorp has been working through a category 3 and 4 rig inspections on the 401 workover rig. The work on the rig is nearing completion and we are bringing in an inspector next week to sign off on the inspections for this rig. We have been notified that in order to obtain the sign off, the rig needs to be erected on a well so that the blocks can be ran up and down. Hilcorp believes that this well is the best candidate to fulfill that need and here is why:. The purpose of the work on this well is to repair a parted rod string. The Sundry is written to pull tubing in case for some reason we cannot pull the pump. But, the plan is to rig the 401 up on the well, complete the inspection by running the blocks up and down and then pulling the rod string to see what is going on in this well. If the pump can be pulled, we will replace the pump and the parted rod and run the rods back and hang off. The well will then be returned to production. A pretty simple work over but we would like to have the Sundry in place so that we can rig up and complete the inspection. For efficiency reasons, we would then like to repair the well. I would have had this in sooner but have been out of the office. Any help expediting this Sundry would be appreciated. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC - 0 907-777-8420 C 985-867-0665 From: Donna Ambruz Sent: Thursday, February 21, 2019 10:32 AM To: Ted Kramer <tkramerPhilcorp.com> Subject: SCU 32-08 AOGCC 10-403 Submitted 02-21-19 FYI Thank you Operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct 907.777.8510 -Fax dambruz@hilcoro.com STATE OF ALASKA ALAALlikA OIL AND GAS CONSERVATION COMMISION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing U Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Rod Pump/Tubing Repair ❑., 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑., Exploratory ❑ 160-045 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-10118-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA 028996 Soldotna Creek unit(SCU)32-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 10,828 feet Plugs measured N/A 'I'''' r w i 4 r;:.i + 1 .1 t' true vertical 10,824 feet Junk measured 10,631 (fill) feet JAN I 1. ?Ot7 Effective Depth measured 10,631 feet Packer measured N/A feet true vertical 10,628 feet true vertical N/A feet /4; `O I,.+;( Y 1 Casing Length Size MD TVD _.,,first :; Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner sato° tit tri:„3 Perforation depth Measured depth See attached schematic True Vertical depth See attached schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 10,359'MD 10,356'ND Packers and SSSV(type,measured and true vertical depth) N/A;N/A N/A;N/A N/A;N/A N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 180 180 Subsequent to operation: 54 9 91 75 150 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations LI Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil la Gas • WDSPL 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: 316-609 Contact Joe Kaiser-777-8393 Email jkaiserc hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature Yr .7Phone 907-777-8405 Date 1-I 0-V7 Form 10-404 Revised 5/2015 5L "`-7-/7 RBDnns L 'Jr,,l 2 5 2017 Submit Original Only • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 32-08 Moncla 401 50-133-10118-00 160-045 12/12/16 12/16/16 Daily Operations: 12/12/2016- Monday Mobe Moncla 401 from KGF. PJSM, off loaded rig equipment, laid containment, spot beam and rig. 12/13/2016-Tuesday Held PJSM, discussed daily activities and warmed-up equipment. Raised derrick and RU floor, spotting equipment. Pit, pump, manifolds, Koomey unit, diesel tank and gen unit. Sealed in 3 sides on the the 75' x 100' containment. Cont winterization for associated rig equipment. SITP 150psi SICP 150psi. Hooked-up Kelly hose f/csg t/gas buster. Bled off csg/tbg pressure to gas buster. Pumped 60 bbls down csg monitored well on vac. PU rod handling tools. Unseated pmp and BO/LD the stuffing box and polished rod. Pumped 40 bbls of 150deg water down tbg to clean rods. MU rod stripper head and TOH w/rod string hanging back rods in basket. BO/LD rod pump. Rods and pump is in good condition.Secured well and SDFN. Night watch on tower. 12/14/2016-Wednesday Held PJSM, discussed daily activities. Cleaned and cleared rig floor and RD same. Set a BPV. ND production tree and_NU 7. 1/16" BOP. Stack mud cross w/2-1/6" 5M, manual kill/ck valve and 2-1/16" 5M, HCR kill/ck valve, double gate blinds on bottom and 2-3/8" to 3-1/2"VBR's on top and 7-1/161" 5M Shaffer preventer. Connected kill/choke lines f/stack t/ manifolds. MU control lines 1/ Koomey t/stack. Winterized same. RU floor, windwalls and stairwell. Installed skirting around rig floor. PU/MU Foster tongs and 2-7/8" shoulder type elevators. MU 2-7/8" test jt with blanking sub. Flooded BOP equipment and circulated air out of the system. Performed shell test 250-2,500psi, Good Test.Tested BOPE per AOGCC regs as follows: gas detection, pressure tested annular 250-2,500psi, Rams 250-2,500psi, valves 250-2,500psi. Performed Koomey drawdown test. No failures recorded. AOGCC witnessed waived by Jim Regg on 12/12/16 at 14:00hrs. LD test jt and pulled the TWC. PU/MU 2-7/8" landing jt. PU on tbg string to 72K and turned pipe 1/4" to right and jayed out of hanger. SO 4" to string weight @ 56K.Turned pipe to the right and released tbg anchor. Pull up hole and jayed back into hanger. Dropped test plug, PU/MU TIW and Kelly hose, pumped 50bbls down tbg. Secured well, SDFN. Night watch on tower. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 32-08 Moncla 401 50-133-10118-00 160-045 12/12/16 12/16/16 Daily Operations: 12/15/2016-Thursday Held PJSM, discussed daily activities. MU Kelly hose and started pump. Pumped 50bbls down tbg, monitored csg on vac. BOLDS. BO/LD Kelly hose. Cleaned rig floor and pulled hanger and first slick joint under hanger was rod cut about 6' below hanger. LD hang_er and first 3j . MU Kelly hose and tested tbg to 2,000psi. good test. BO/LD Kelly hose. PU/MU 3 jts of new 2-7/8" 6.4# EUE L-80 8rd and TIH w/same. Established parameters 56K up/55K dn, PU/MU tbg hanger and landing jt. Landed completion with 56K on hanger. RILDS PU to 55K and jayed out of hanger, SO 42" and turned pipe to the left 8 times and set the tbg anchor.Set string weight down on anchor to ensure set. PU on tbg to 73K and jayed back into hanger. Leaving completion hung off with 18K in tension. BO/LD landing Jt. Set BPV. RD windwalls, stairwell and rig floor. Disconnected Koomey lines and kill/ck lines. ND BOP stack and NU production tree. PT to 5,000psi, good test. Pulled BPV. Removed winterization and RD associated equipment. MIRU SL. RIH w/2"JDC to 10,386' and latched test plug. Picked up and equalized well.Jarred free and TOH. LD test plug. RDMO SL. Loading rig equipment to haul to Moncla's yard. RU floor and rod handling tools.TIH w/new RHBC 1-3/4" 80 ring pump, stablizer bar, 8-1-1/2" sinker bars, 194 3/4" rods, 128 7/8" rods, 80 1" rods,4', 6', 8' pony rod, stuffing box and polish rod. Cont loading rig equipment. Seated pump. Spaced Pump out 40' off bottom and landed with rod clamps leaving 152" of polish rod above the Rotaflex slab. MIRU vac truck pump 30 bbls to fill tbg string. RDMO vac truck. Stroked rod pump with rig and pressured up on tbg to 750psi, good test. Bled off pressure. Secured well and SDFN. Night watch on tower. 12/16/2016- Friday Held PJSM. RDMO Moncla 401 and associated equipment. Mobilized rig and equipment to Moncla's yard. Cleaned and cleared location.Turned well over to production.TLTR is 230bbls of produced water. H . Swanson River Field • Well:SCU 32 08/PTD 160-045 SCHEMATIC • API: 50-133-10118-00 Hilcoro Alaska,LLC RKB:143'/GL:128'AMSL New KB—THF:15.00' CASING DETAIL A 1 Size WT Grade Conn ID Top Btm IIL 22" Surface 28' 54.5 J-55 8RD 12.615" Surface 1,308' DV @ ' , B II 13-3/8" DV Collar 12.615" 1,308' 1,310' 1,308' 54.5 J-55 8RD 12.615" 1,310' 3.014' 28 P-110 8RD 5.791" Surface 115' 24 N-80 BTC 5.921" 115' 6,477' II 24 P-110 8RD 5.921" 6,477' 7,996' 2 6-5/8" DV Collar 5.921" 7,996' 7,998' 24 P-110 8RD 5.921" 7,998' 10,037' I,- 28 P-110 8RD 5.791" 10,037' 10,828' TUBING DETAIL 2-7/8" 6.5 L-80 8RD 2.441" Surface 10,359' II New Tubing Ran 4/11/13 DV @ (replace 3 top its 11/23/13) 7,996' II ; # Depth Length ID OD Description II1 15' 62' 2.991" 7" Tubing Hanger J-Latch,w/2 joints of 3-1/2" tubing below hanger. 1 2 2,989' 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor C 4 10,384' 0.65' 2.250" 3.5" Seating Nipple II 5 10,390' 5.65' 4.375" 4.5" Perforated Joint 3 6 61' 4.375" 4.5" 2-7/8"Tubing 6.4#IBT 7 10,434' 0.44' 4.375" 4.5" Bull Plug D ROD DETAIL E 4 # Depth Length OD Description 5 A 36' 40' 1-1/2" Polish Rod,24'in well F , . B 76' 18' 1" 1"EL Pony Rods(4',6',8') 6 — C 94' 2,000' 1" 1"x 25'EL Sucker rods w/ 4 XL guides per rod(80) 7 2,094' 3,200' .875" 7/8"x 25'EL Sucker rods w/ 4 XL guides per rod(128) Top of fish 5,294' 4,850' .75" %"x 25'EL Sucker rods w/ 4 XL guides per rod(194) @ 10,423' C 10,144' 200' 1-1/2" 1-1/2"Sinker Bars(8) Fi / 1-3/4"x 42'Insert Pump,RHBC Pump w/PA Ring D 10,344' 42' 1.75' 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x - - 37"RHBC E 10,386' 4' 1.660" Perforated Diptube F 10,390' 2.5' 1.250" 1-1/4"Memory Gauge New Rods Ran 10/02/14 (All rods/pump replaced/Re-ran Polish Rod) Bad HIM±10,631 Casing @ : : 10,634' PERFORATION DETAIL ON NEXT PAGE FISH DETAIL ON NEXT PAGE MAX HOLE ANGLE=3° @ 7,004' .4i Downhole Revised: 10/02/14 Updated by DMA 01-09-17 TD=10,828' PBTD=10,631' Swanson River Field ... H • • Well:SCU 32 08/PTD 160-045 SCHEMATIC API: 50-133-10118-00 Hileora Alaska,LLC PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re-perforated October 2011 10/16/1985 H1 10,518' 10,520' 10,515' 10,517' 2' Re-pert 08-18-01/10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 9 Re pert 10-16-1985/06-10-1995/08-18-2001 /10-02-2004 2/21/1961 H1 10,529' 10,530' 10,526' 10,527' 1' Re-perf 10-16-1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re-perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re-pert 10-16-1985/08-18-2001/10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re-pert 10-16-1985/06-10-1995/08-18-2001 /30-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re-pert 10-16-1985/06-10-1995/08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re-pert 10-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10-16-1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re-perf 10-16-1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple(Top of Fish) F 4.09' 2.375 4.25 Chemical Injection Sub I S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug(Bottom f Fish) Downhole Revised: 10/02/14 Updated by DMA 01-09-17 v of 7 j4. • • y1yyy,BA THE STATE Alaska Oil and Gas 411. ---s=� 0 of® T ® T e Conservation Commission Sf�z �� 333 West Seventh Avenue .ice'` " GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o ,”- Main: 907.279.1433 F ALAS�P Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operationsge, AlasED - r 9'Z Hilcorp Alaska, LLC � . 9 � 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Swanson River Field,Hemlock Oil Pool, SCU 32-08 Permit to Drill Number: 160-045 Sundry Number: 316-609 Dear Mr. Helgeson: 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, Daniel T. Seamount,Jr. Commissioner rr‘. DATED this i day of December, 2016. RBDNIS '`-DEC - 9 2016 • , \ �i�p �. �E TED , STATE OF ALASKA �� O R_. 0 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ►; .,� C 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ] ' Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate El Pull Tubing 0• Change`A�p ved P ogra ❑ Plug for Redrill ❑ Perforate New Pool 21Re-enterSusp Well ❑ Alter Casing ❑ Other: Tubing Repair El• 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development 0 • 160-045 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-10118-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO123B • Will planned perforations require a spacing exception? Yes ❑ No 2Soldotna Creek Unit(SCU)32-08. 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA 028996 • Swanson River Field/Hemlock Oil 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): 10,828' • 10,824'' 10,631' 10,628' —1,037 psi N/A 10,631'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4#/L-80 10,359' Packers and SSSV Type: N/A Packers and SSSV MD(ft)and ND(ft): N/A N/A N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic El Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: December 15, ❑ ElWDSPL ❑ Suspended 21Commencing Operations: OIL WINJ 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 Joe Kaiser-777-8393 Email jkaiser@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature �� Phone 907-777-8405 Date (Z fZ//(p COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Ill Mechanical Integrity Test ❑ Location Clearance ❑ Other: .)e Z—J Post Initial Injection MIT Req'd? Yes El No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: I 0 -' 4 oti RBDMS 0---DEC - 9 2016 APPROVED BY Approved b '� / COMMISSIONER THE COMMISSION Date: 12-4 7/lb e, /2„.-g-A, Submit Form and Form 10-403 Revi jd 11/2015 0 Rice ipwItAiLalid for 12 months from the date of approval. Attachments in Duplicate ..1(.774/4 /j6 /z 7./c • 1110 Well Prognosis Well: SCU 32-08 Hilcora Alaska,LL Date: 12/2/2016 Well Name: SCU 32-08 API Number: 50-133-10118-00 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: December 15th, 2016 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-045 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: — 1,500 psi @ 10,300' TVD (Fluid Level Calculations) Maximum Expected BHP: — 1,500 psi @ 10,300' TVD Max. Potential Surface Pressure: —1,037 psi (0.1 psi/ft gas gradient to surface) Brief Well Summary Soldotna Creek Unit 32-08 is a rod pump well with a Weatherford Roto-flex Unit. The rods were last replaced in October 2014. In November 2013, the pump was pulled as a leak in the tubing was identified in the tubing hanger. The top 3 joints of tubing were replaced with a new tubing hanger. On November 30th,2016 a jug test was performed on the well and the tubing did not hold suspecting that there was a hole in the tubing. The purpose of this work/sundry is to pulls the rods and repair/replace the hole in the tubing. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump. • Surface equipment (Roto-flex unit) disconnected and rolled back. Ready for WO rig • On 8/1/16 a fluid level measurement was collected with an Echometer at 8,160'with well flowing and 60 psi on the casing. Workover Rig Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer) on casing. 2. MIRU Moncla #401 WO Rig.Set to work on 12-hr shifts. 3. Pump casing volume of produced water down annulus, lube, and bleed pressure. 4. Nipple up rod striper head. LD polish rod and pull EL rods. t p; 6. LD pump and dip tube. a. Inspect and bucket test pump. 7. Drop standing valve to test tubing. Test tubing to 2,000 psi. a. If tubing test good, re-run pump and rods. b. If tubing does not test good, plan to pull the tubing. 8. RU Slickline and pull standing valve. 9. Set BPV. ND Rod Stripper head and Tree. a. If BPV does not seat or hold in hanger(possible cut threads) and lifting threads are intact, ( C' use blanking sub and test BOPE. Contingency if BPV or blankingsub do not work g y (perform rolling BOP test as follows): • Well Prognosis Well: SCU 32-08 Hilcorp Alaska,LL Date: 12/2/2016 b. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. c. With stack out of the test path, test choke manifold per standard procedure d. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) e. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. f. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure(floor valves, gas detection, etc.) g. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 10. NU BOPE. •L�v.) (5- 11. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/), i High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Notification to BLM is not required. c. Perform Test. d. Test VBR rams on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 12. L/D BOP test equipment. 13. Pump PW down tubing and casing to ensure well is dead."' lc...0 - 14. Pull tubing hanger free, unseat tubing anchor and POOH w/tubing. a. It is possible the tubing near the surface is worn and if found near surface, replace with new 2-7/8" tubing and RIH and reseat anchor. 15. Rack back tubing string (2-7/8" 8RD) a. Inspect tubing for holes/worn joints. 16. LD bad joints and replace 2 joints above and below each bad joint. 17. RIH with tubing. a. Set depth indicator sub at approximately 3,000ft. 18. Set tubing anchor and land new larger(3-1/2" or 4-1/2")tubing hanger. 19. Set TWC, ND BOPE, NU Tree and test to 3,000 psi, Pull TWC. 20. NU Rod Stripper. 21. PU existing dip tube, bottom hole pressure recorder and new 1-3/4"rod pump, replace and RIH with new rods as necessary in the string(sinker bars, 3/4", 7/8" and 1), space out the rods, install polish rod. 22. Fill tubing with PW, ND rod stripper. 23. Test wellhead and tubing to 1,000 psi, by stroking pump with rig or test pump. 24. RD Moncla#401 WO Rig. 25. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 26. Return to production with same surface safety system as previously installed. 27. Replace IA x OA pressure gauge if removed (6-5/8"x 13-3/8"). Attachments: 1. Actual Schematic • • Well Prognosis Well: SCU 32-08 Ililcorp:Uaska.L1; Date: 12/2/2016 2. Proposed Schematic 3. BOPE 4. Blank RWO Procedure Change Form Swanson River Field H 0 ACTUAL S C H E M AT I Well:SCU 32-08/PTD 160-045 Completion Ran: 11/23/13 "'f`"'°'�eFka 111 API: 50-133-10118-00 RKB:143'/GL:128'AMSL New KB—THF:15.00' CASING DETAIL A 1 Size WT Grade Conn ID Top Btm 22" - - - - Surface 28' 54.5 J-55 8RD 12.615" Surface 1,308' DV B 13-3/8" DV Collar 12.615" 1,308' 1,310' 1,4130418' I 54.5 1-55 8RD 12.615" 1,310' 3.014' 28 P-110 8RD 5.791" Surface 115' 24 N-80 BTC 5.921" 115' 6,477' 24 P-110 8RD 5.921" 6,477' 7,996' 2 6-5/8" DV Collar 5.921" 7,996' 7,998' 24 P-110 8RD 5.921" 7,998' 10,037' El 28 P-110 8RD 5.791" 10,037' 10,828' TUBING DETAIL II 2-7/8" 6.5 L-80 8RD 2.441" Surface 10,359' Il'JNew Tubing Ran 4/11/13 DV @ (replace 3 top jts 11/23/13) 7,996' 1 # Depth Length ID OD Description IR1 15' 1.7' 2.441" 7" Tubing Hanger)-Latch 2 2,989' 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor C 4 10,384' 0.65' 2.250" 3.5" Seating Nipple Illi 5 10,390' 5.65' 4.375" 4.5" Perforated Joint 111101.00110 3 6 61' 4.375" 4.5" 2-7/8"Tubing 6.4#IBT 7 10,434' 0.44' 4.375" 4.5" Bull Plug ' 4' ROD DETAIL # Depth Length OD Description A 36' 40' 1-1/2" Polish Rod,24'in well B 76' 18' 1" 1"EL Pony Rods(4',6',8') C 94' 2,000' 1" 1"x 25'EL Sucker rods w/ 4 XL guides per rod(80) 2,094' 3,200' .875" 7/8"x 25'EL Sucker rods w/ 4 XL guides per rod(128) 5,294' 4,850' .75" %"x 25'EL Sucker rods w/ 4 XL guides per rod(194) Top of fish @ 10,423' C 10,144' 200' 1-1/2" 1-1/2"Sinker Bars(8) 1-3/4"x 42'Insert Pump,RHBC Pump w/PA Ring D 10,344' 42' 1.75' 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37"RHBC E 10,386' 4' 1.660" Perforated Diptube F 10,390' 2.5' 1.250" 1-1/4"Memory Gauge(Welded coupling to screen) New Rods Ran 10/02/14 (All rods/pump replaced/Re-ran Polish Rod) BadPBT, ±10 63r # Casing @ 10,634' PERFORATION DETAIL ON NEXT PAGE FISH DETAIL ON NEXT PAGE _ MAX HOLE ANGLE=3° @ 7,004' A----- -- -----i Downhole Revised: 10/02/14 Updated by STP 10/03/14 TD=10,828' PBTD=10,631' Swanson River Field ACTUAL SCH E MATT Swanson River PTD 160-045 Completion Ran:11/23/13 ` Hilcora Alaska,LLC. API: 50-133-10118-00 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re-perf08-18-01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re-perforated October 2011 10/16/1985 H1 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-01/10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 9 Re-pert 30-16-1985/06-30-1995/08-18-2001 /10-02-2004 2/21/1961 H1 10,529' 10,530' 10,526' 10,527' 1' Re-pert 10-16-1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re-perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re-perf 10-16-1985/08-18-2001/10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re-pert 10-16-1985/06-10-1995/08-18-2001 /30-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re-perf 10-16-1985/06-10-1995/08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re-pert 10-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10-16-1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re-perf 10-16-1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple(Top of Fish) F 4.09' 2.375 4.25 Chemical Injection Sub I 5 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug(Bottom f Fish) Downhole Revised: 10/02/14 Updated by STP 10/03/14 Swanson River Field II PROPOSED SCHEMA C Well:50-133-0SCU 118 00160-045 APIHilearn Alaska.LL(: RKB:143'/GL:128'AMSL New KB—THF:15.00' CASING DETAIL A 1 L Size WT Grade Conn ID Top Btm 22" - - - - Surface 28' 54.5 J-55 8RD 12.615" Surface 1,308' DV @ , B 13-3/8" DV Collar 12.615" 1,308' 1,310' 1,308' 54.5 1-55 8RD 12.615" 1,310' 3.014' 28 P-110 8RD 5.791" Surface 115' LI 24 N-80 BTC 5.921" 115' 6,477' 24 P-110 8RD 5.921" 6,477' 7,996' 2 6-5/8" s J DV Collar 5.921" 7,996' 7,998' I24 P-110 8RD 5.921" 7,998' 10,037' � 28 P-110 8RD 5.791" 10,037' 10,828' TUBING DETAIL 2-7/8" 6.5 L-80 8RD 2.441" Surface 10,359' INew Tubing Ran 4/11/13 (replace 3 top jts 11/23/13) DV @ ' 7,996' # Depth Length ID OD Description III1 15' 62' 2.991" 7" Tubing Hanger J-Latch,w/2 joints of 3-1/2" tubing below hanger. 2 2,989' 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor C 0 1 4 10,384' 0.65' 2.250" 3.5" Seating Nipple 5 10,390' 5.65' 4.375" 4.5" Perforated Joint —11111...1111.1 3 6 61' 4.375" 4.5" 2-7/8"Tubing 6.4#IBT 7 10,434' 0.44' 4.375" 4.5" Bull Plug D ROD DETAIL E 11 4 # Depth Length OD Description 5 A 36' 40' 1-1/2" Polish Rod,24'in well F B 76' 18' 1" 1"EL Pony Rods(4',6',8') 6 C 94' 2,000' 1" 1"x 25'EL Sucker rods w/ 4 XL guides per rod(80) 7 _ 2,094' 3,200' .875" 7/8"x 25'EL Sucker rods w/ 4 XL guides per rod(128) ill< Top of fish 5,294' 4,850' .75" 3/4"x 25'EL Sucker rods w/ 4 XL guides per rod(194) @ 10,423' C 10,144' 200' 1-1/2" 1-1/2"Sinker Bars(8) 1-3/4"x 42'Insert Pump,RHBC Pump w/PA Ring D 10,344' 42' 1.75' 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x - 37"RHBC E 10,386' 4' 1.660" Perforated Diptube F 10,390' 2.5' 1.250" 1-1/4"Memory Gauge It` New Rods Ran 10/02/14 (All rods/pump replaced/Re-ran Polish Rod) Bad PBTD t10 631' Casing @ 10,634' PERFORATION DETAIL ON NEXT PAGE FISH DETAIL ON NEXT PAGE MAX HOLE ANGLE=3"@ 7,004' 4::::::::--::-_--::_:__::::t. Downhole Revised: 10/02/14 Updated by CAH 11/30/16 TD=10,828' PBTD=10,631' Swanson River Field 11 Well:SCU PROPOSED SCHEMA IC API: 501 3�011800160-045 Hiker')Alaska.LLC PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re-perforated October 2011 10/16/1985 H1 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-01/10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 9' Re-perf 10-16-1985/06-10-1995/08-18-2001 /30-02-2004 2/21/1961 H1 10,529' 10,530' 10,526' 10,527' 1' Re-perf 10-16-1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re-perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re-perf 10-16-1985/08-18-2001/10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10 Re-perf 10-16-1985/06-10-1995/08-18-2001' /10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re-perf 10-16-1985/06-10-1995/08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re-perf 10-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10-16-1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re-perf 10-16-1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple(Top of Fish) F 4.09' 2.375 4.25 Chemical Injection Sub S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug(Bottom f Fish) Downhole Revised: 10/02/14 Updated by CAH 11/30/16 • • SRF SCU 32-08 a H 2016 Moncla Rig#401 Hilrnrp: Mka.1,1L Knight Oil Tools BOP �Iu 1111111111 ,(t rill rill rill VI in) itli tt 2.57' Shaffer 7 1/16 5000 rill in) flirt-Cu l r 111 Ili illi 14,1i [TT / / \ 2 3/8-3 A variable I CAMERON �� N 3.68' H © H cr N (; © o ' O Blind H ((El 71/16 5000 \ H DSA \--"N_ *4Y / 4-1/6"SM x 2-1/16" 10M Jft (tt rft 411 til \--, \, Choke and Kill valves are 2 1/16 10M ii-HAVU-M-HIJJ tn . ,f,y; i, A — 1.56' J '#rte, ,e,11\, 11 if 47 /16 5000 t ' II L � ' 42'Y J _ / HCR 7-1/16" SM Drilling Spool w/one 4-1/16"5 M Outlets 0 • a22 / � c22 � 6 c 77 02e / g < � ° a<§ f E 0) ° c 2 , § 1 0. c 0. £ » < Z" - co k � � a) To > � xe� 7 22 a gE k \ en 0- a $ 2 © 2 1.. Z CO CO co / � � O o o / ° � re @ C � / B t / 12 a 2 J O co 9 k ( 0. ® 2S 0 �/ -a C g %O ■ 1-D, Eas 2 G « .0 Ck k = a) I- 2 a ' i 2 _ 2 a 0" \ ra c 7 c ea -a k p U -0 @ > 2 0 co 1-4 2 § � @ / ctli Q. « C > 0 0. 2 o » x § 0 el cc: & m : - 0 § > $ a) k $ g s � 0 x R � 2 it E .. % g k g U � g ■ > E 2 >,O co. a k 9 Q a 23 0 = m k WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. ¡to {? J..j S- Well History File # Digital Data Added to LaserFiche File 0 CD's - # - 0 DVD's - # - 0 Diskettes - # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # - 0 Mud Logs # - 0 Other # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No General Notes or Comments about this file. If any ofthe information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Ll Perforate 17 Other Ld Rod Pump Repair Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re-enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Q Stratigraphic ❑ Exploratory ❑ Service ❑ 160-045 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99503 50-133-10118-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA 028996 Soldotna Creek unit (SCU) 32-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: EC Total Depth measured 10,828 feet Plugs measured N/A feet T true vertical 10,824 feet Junk measured 10,631 (fill) feet NOV 0 5 201 Effective Depth measured 10,631 feet Packer measured N/A feet(� ® G true vertical 10,628 feet v true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation depth Measured depth See attached schematic True Vertical depth See attached schematic Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / L-80 10,359' MD 10,356' TVD Packers and SSSV (type, measured and true vertical depth) N/A; N/A N/A; N/A N/A; N/A N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A CANNED NOV 13 20i4, Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 35 39 81 180 180 Subsequent to operation: 43 66 100 160 175 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Explorato ❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledg . Sundry Number or N/A if C.O. Exempt: 314-530 Contact Stan Porhola Email soorholana.hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature a y,�-._. Phone 907-777-8412 DateAt Form 10-404 Revised 10/2012 /l /D •/r/ 14e Submit Original Only I Hilcorp Alaska, LLC Well Operations Summary Well Name AI Number Well Permit Number Start Date End Date SCU 32-08 50-133-10118-00 160-045 1 9/29/14 10/3/14 Daily Operations. 09/29/2014 - Monday Moncla Rig 401 left yard and to arrive on location. Pit liner arrived and laid down. Crews were locating supplies to enable them to attach and secure sections of pit liner. Light plant/heat gun/ and tape laid and pit liner welded together. Company man split rig crew. Half stayed rigging up pulling unit. Other half went to RIO pad to inventory and count existing rods. Rod connex box was loaded and hauled to wellsite. Rig substructure layed. Moncla crew could not get unit 401 into position. New welded fall arrest pole was going to hit trees. Decison was made to pull unit off pit liner and remove sub structure to improve clearance. RIG ON DOWN TIME. Post removal of substructure crew attempted to move rig into position when rig hand noticed smoke coming from electrical components in the engine compartment. Mechanic dispatched to location. 2.5 hrs of NPT, cause of failure was due to a bad alternator. Back up and running at 1930hrs. Many attempts to spot unit into location. Loader and winch truck set substructure after rig spotted up on well. Rig outriggers and supports down. Production will bleed tubing and casing down throughout the night. Finished for the night. Will resume operations at 0600. 09/30/2014 -Tuesday Safety meeting and JSA. Tubing and Casing pressured back up overnight. Obtained another bleed down tank and bled down pressure from tubing and casing through 1/2" high pressure hose to bleed down tank. Tubing bleed down tank ended up with 3 bbls of crude. While bleeding down tubing and casing crews repacked Rod BOPS and installed new inserts. Crews inventoried couplers and pulled all rod from connex box. Tool pusher informed that the rod didn't seem to be parted. Indications of stroking pump and weight of 24,500 lbs. (rod weight) Called town and attempted to stroke RHBC rod pump with rig. Stroked for 1 hr and did not see returns to surface. Pull Rod pack off and replace with rig packoff. Begin pulling rod. No parrafin on rods. Up weight 25k, Tool pusher informed that initial indication of rod parting may be inaccurate. Found rod parted at 8 065Ft. 80 Joints of .75" rod in hole. Selected correct overshot and grapple to prepare for fishing run in the morning. Black bear on location. Crews shut down and secured the well. TIW valve installed and closed. Tubing and casing valves isolated. 10/01/2014 - Wednesday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 32-08 50-133-10118-00 160-045 1 9/29/14 10/3/14 Daily Operations: Safety meeting and JSA. Tubing pressured up overnight. Bleeding down tubing. RIH overshot and 1-5/8" grapple. Rig crew having troubles with hydraulic tongs. RIH WT at 8,065' 25K. Up wt 25k. Stacked 2k down on fish to latch. On fish working up and down. Overpull of 44k to unseat pump. Audible confirmation that well went on VAC. Weight indicator broke back to 34K. Pump free started pulling out of hole. Pulled 5 stands and then we swapped reeves and used smaller block to pull the rest of stands. Hot oil pumping 150 degree water to clean rods as we tripped out of hole. ALL rods/pumps out of hole. Previous tubing tally verified and amout of rod counted when coming out was correct on tubing tally. Pump laid down and 6ft screen ready to have coupling welded on in the morning for pressure temperature tool. Locating new pump with Weatherford artificial lift crew. Correct pump was at compressor facility. Slick line crew rigging down from SRU 21-27. Slick line crew rigging up to make gauge ring run and scrapper run. RIH with 2.4in Gauge ring to 55ft. stack weight. Hot oil pumping 150 degree water. Gauge ring made it to 982 ft. Could not pass 982 ft. POOH. RIH with scratcher 2.38in to 3,000 feet. POOH. RIH/w 2.40" G ring to 982 ft. tight spot to 990ft. Fell through to 1,360 ft. Could not pass depth. POOH, metal marks. Hung up on POOH at 990 to 982ft. Multiple spang licks. RIH/w 2.30" G ring to 3,000 ft. No obstructions. POOH. RIH with 2.35" G ring to 10,396 Ft K no obstructions. No set downs. POOH. Rig down slick line. 10/02/2014 - Thursday Safety meeting and JSA. Correct pump was loaded out from Lexan/compressor building and brought to location. Brought 6ft screen to welders for repair of cracked screen. Was informed that there were no abilities to weld screen due to not having proper tools for welding stainless steel. Decision was made to run dip tube instead. 4 ft dip tube with perforated holes has been welded on for Pressure temperature tool. Rig crew spotting new rod. Ensure no flow on tubing. Rig down TIW valve and lift pump/ install 4ft Dip tube and memory Pressure Temperature tool. Function tested pump at suface. Placed pump in 5 gallon bucket of water and stroked until water was seen at discharge of pump. Pump details: Pump No. 3596/ Type of Pump RHBC/ Size: 2-1/2" x 1-3/4" x 36'x 36-1/2'x 37'. Length & Fit 36'w 1-3/4" ID/ Plunger type: 80 ring PA/ valve description: titanium Carbide. Max stroke: 372'/ Pin: 3/4". Accessories: sand seal at ball and seat. Hold down: 3 cup bottom. Pick up Rod and run: 8: 1-1/2" Weight bar. 194: 3/4" Rod. 128: 7/8" Rod. 80: 1" Rod. 1" x 4ft pony. Each Joint torqued with torque card. Pump landed in nipple at 10,384ft. Set pump. Indication felt by touch at surface. Picked up pump rod to 42" off bottom. Surface measurement from Rotaflex cement slab to top of 1.5 in polished rod is 146". Fluid packed tubing and pressure tested 650 psi for 5 minutes. Bleed pressure down and then stroked pump until pressure built up to 250 psi. Bleed to zero. Rigged down hot oil truck. Dispossed of fluid and filled hot oil truck with methanol for storage. 10/03/2014 - Friday Hold safety meeting and review JSA. Rig down Moncla 401. Load rig equipment on trailers and move to Moncla yard. Clean location. Swanson River Field ACTUAL SCHEMATIC Completion Ran: 1/223/13 045 Hilcoro Alaeka, LLC API: 50-133-10118-00 RKB: 143'/ GL: 128' AMSL New KB—THF: 15.00' Tn-1n 29RI DrtTn-7n FQ1, CASING DETAIL Size WT Grade Conn ID Top Btm 22" - 2.441" 7" Tubing Hanger J -Latch Surface 28' 1" EL Pony Rods (4', 6', 8') 54.5 J-55 8RD 12.615" Surface 1,308' 13-3/8" DV Collar 12.615" 1,308' 1,310' 54.5 J-55 8RD 12.615" 1,310' 3.014' 5.65' 28 P-110 8RD 5.791" Surface 115' 4.375" 24 N-80 BTC 5.921" 115' 6,477' 4.5" 24 P-110 8RD 5.921" 6,477' 7,996' 6-5/8" DV Collar 5.921" 7,996' 7,998' 24 P-110 8RD 5.921" 7,998' 10,037' 28 P-110 8RD 5.791" 10,037' 10,828' TUBING DETAIL 2-7/8" 6.5 L-80 I 8RD 1 2.441" 1 Surface 1 10,359' New Tubing Ran 4/11/13 (replace 3 top jts 11/23/13) # Depth Length ID OD Description 1 15' 1.7' 2.441" 7" Tubing Hanger J -Latch 2 2,989' 1" EL Pony Rods (4', 6', 8') 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor 4 10,384' 0.65' 2.250" 3.5" Seating Nipple 5 10,390' 5.65' 4.375" 4.5" Perforated Joint 6 42' 61' 4.375" 4.5" 2-7/8" Tubing 6.4# IBT 7 10,434' 0.44' 4.375" 4.5" Bull Plug ROD DETAIL # Depth Length OD Description A 36' 40' 1-1/2" Polish Rod, 24' in well B 76' 18' 1" 1" EL Pony Rods (4', 6', 8') C 94' 2,000' 1" 1" x 25' EL Sucker rods w/ 4 XL guides per rod (80) 2,094' 3,200' .875" 7/8" x 25' EL Sucker rods w/ 4 XL guides per rod (128) 5,294' 4,850' .75" %" x 25' EL Sucker rods w/ 4 XL guides per rod (194) C 10,144' 200' 1-1/2" 1-1/2" Sinker Bars (8) D 10,344' 42' 1.75' 1-3/4" x 42' Insert Pump, RHBC Pump w/ PA Ring 80 PA Ring, Sand Seal, 2-1/2" x 1-3/4" x 36" x 36-1/2" x 37" RHBC E 10,386' 4' 1.660" Perforated Diptube F 10,390 2.5' 1.250" 1-1/4" Memory Gauge (Welded coupling to screen) New Rods Ran 10/02/14 (All rods/pump replaced/Re-ran Polish Rod) )RATION DETAIL ON NEXT PAGEI F FISH DETAIL ON NEXT PAGE iLE = 3° @ 7,004' Nnhole Revised: 10/02/14 Updated by STP 10/03/14 Swanson River Field ACTUAL SCHEMATIC Completion Ran: 1/223/13-045 aaearn weak®, LLC API: 50-133-10118-00 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re-perf08-18-01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re -perforated October 2011 10/16/1985 H1 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-01 / 10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 91 Re -pert 10-16-1985 / 06-10-1995 / 08-18-2001 / 10-02-2004 2/21/1961 H1 10,529' 10,530' 10,526' 10,527' 1' Re -pert 10-16-1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re -perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re -pert 10-16-1985 / 08-18-2001 / 10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re -pert 10-16-1985 / 06-10-1995 / 08-18-2001 / 10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re -pert 10-16-1985 / 06-10-1995 / 08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re -pert 30-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10-16-1985 2/21/1961 H3 1 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re -pert 10-16-1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 1-14/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) F I 4.09' 2.375 4.25 Chemical Injection Sub S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug (Bottom f Fish) Downhole Revised: 10/02/14 Updated by STP 10/03/14 X60-a�5 \ji/THE STATE GOVERNOR SEAN PARNELL Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 32-08 Sundry Number: 314-530 Dear Mr. Helgeson: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Pax: 907.276.7542 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, �4 P�� 4, Cathy P. Yoerster Chair DATED this 36 day of September, 2014. Encl. SCANNED STATE OF ALASKA C,,3�' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED SEP 262014 G AOGC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Rod Pump Repair 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development P Stratigraphic ❑ Service ❑ 160-045 - 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99503 50-133-10118-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? No❑✓ Will planned perforations require a spacing exception? Yes F-1No Creek Unit (SCU) 32-08 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA 028996 il- Swanson River Field / Hemlock Oil. it. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 1 Plugs (measured): Junk (measured): 10,828 10,824 10,631 10,628 N/A 10,631' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 2-7/8" 6.4# / L-80 10,359 Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A N/A N/A 12. Attachments: Description Summary of Proposal ❑✓ 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: 09/29/14 Oil Q _ Gas ❑ WDSPL ❑ Suspended ❑ WINJ F]GINJ ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: i – "� Commission Representative: ( Sc b 4 L GSTOR ❑ SPLUG Ll 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson Phone: 907-777-8405 Email chelgesgn@_hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature Phone 907-777-8405 Date Z / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: „ I —5-3 UI 5-3 0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: �� • �IC 1 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: < i Submit Form and a�r jV0-qq� TevisT 1oreo1Q�� _ �ApWrov�d application is v id ¢[2 �brtw� f A d to of approv �,/ Attachments in Duplicate I7 L. �7 UUII.. II 11 ' ` V 1 VVV !✓1rj� �L) 4 �`� Hilmrp Alaska, M Well Prognosis Well: SCU 32-08 Date:9/26/2014 Well Name: SCU 32-08 API Number: 50-133-10118-00 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: September 29th, 2014 Rig: Moncla 401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-045 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP: Max. Allowable Surface Pressure: Brief Well Summary 1,500 psi @ 10,300' TVD (Fluid Level Calculations) — 1,500 psi @ 10,300' TVD 0 psi (Based on actual reservoir conditions and min water cut of 95% (0.435psi/ft) with added Safety Factor of 1,000' TVD of oil cap). Soldotna Creek Unit 32-08 was repaired and put into production in December 2012. The pump was replaced in January 2013. Debris from the previous workover seized the pump. The pump was replaced with a new pump in January. A hole in the tubing was found in the chemical injection mandrel and the tubing was re -run in April 2013. A parted rod was fished out and replaced in September 2013 and the well placed back on production. In November 2013, the pump was pulled as a leak in the tubing was identified in the tubing hanger. The top 3 joints of tubing were replaced with a new tubing hanger. On September 24th the rods parted in the well at approximately 7,100'. The purpose of this work/sundry is to repair parted rods for this Weatherford Rod Pump well. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump (suspect rods parted). • Fluid level is currently 6,900ft, based on echometer results on 9-26-14. Workover Rig Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. 3. MIRU Moncla #401 WO Rig. 4. Nipple up rod strippelbead. 5. LD polish rod and pull EL rods. Rack back the rods in basket and visually inspect guides, couplings, and rods, as pulling out of hole. 6. PU fishing assembly and RIH with rods and fish parted rods and pump. 7. LD and inspect pump, screen and all pulled rods. LD all rods that are marginal or do not pass inspection. 8. PU existing dip tube bottom hole pressure recorder and new 1-3/4" rod pump, replace and RIH with new rods as necessary in the string (sinker bars, 3/4", 7/8" and 1), space out the rods, install polish rod. 9. Fill tubing with PW, ND rod stripper, 10. Test wellhead and tubing to 500 psi, by stroking pump with rig. 11. RD Moncla #401 WO Rig. ilileorp Alaska. LL Well Prognosis Well: SCU 32-08 Date: 9/26/2014 12. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 13. Return to production with same surface safety system as previously installed. 14. Replace IA x OA pressure gauge if removed (6-5/8" x 13-3/8"). Attachments, 1. Actual Schematic Swanson River Field ACTUAL SCHEMATIC Completion Ran: 1/223/13045 Ilileorn Alaska. LLf. API: 50-133-10118-00 RKB: 143'/ GL: 128' AMSL New KB—THF: 15.00' A If !I 1 DV @ is I B DV @ 7,996' 2 C WT Grade D ID Top Btm 22" 3 E 7" F Surface G 4 1" x 8' EL Pony Rod, 1" x 2' EL Pony Rod 5 J-55 6 12.615" TD =10,828' PBTD = 10,631' Top offish @ 10,423' CASING DETAIL Size WT Grade Conn ID Top Btm 22" - 2.441" 7" Tubing Hanger J -Latch Surface 28' 1" x 8' EL Pony Rod, 1" x 2' EL Pony Rod 54.5 J-55 8RD 12.615" Surface 1,308' 13-3/8" DV Collar 12.615" 1,308' 1,310' 0.65' 54.5 J-55 8RD 12.615" 1,310' 3.014' 4.375" 28 P-110 8RD 5.791" Surface 115' 4.5" 24 N-80 BTC 5.921" 115' 6,477' Bull Plug 24 P-110 8RD 5.921" 6,477' 7,996' 6-5/8" DV Collar 5.921" 7,996' 7,998' 24 P-110 8RD 5.921" 7,998' 10,037' 28 P-110 8RD 5.791" 10,037' 10,828' TUBING DETAIL 2-7/8" 6.5 1 L-80 I 8RD 1 2.441" 1 Surface 1 10,359' New Tubing Ran 4/11/13 (replace 3 top jts 11/23/13) # Depth Length ID OD Description 1 15' 1.7' 2.441" 7" Tubing Hanger J -Latch 2 2,989' 1" x 8' EL Pony Rod, 1" x 2' EL Pony Rod 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor 4 10,384' 0.65' 2.441" 3.5" Seating Nipple 5 10,390' 5.65' 4.375" 4.5" Perforated Joint 6 1' 61' 4.375" 4.5" 2-7/8" Tubing 6.4# IBT 7 10,434' 0.44' 4.375" 4.5" Bull Plug ROD DETAIL # Depth Length OD Description A 39' 40' 1-1/2" Polished Rod, 24' in well B 79' 10' 1" 1" x 8' EL Pony Rod, 1" x 2' EL Pony Rod 89' 2,575' 1" 1" x 25' EL Sucker rods w/ 3 XL guides per rod (103) 2,664' 3,600' .875" 7/8" x 25' EL Sucker rods w/ 3 XL guides per rod (144) 6,264' 3,825' .75" %" x 25' EL Sucker rods w/ 3 XL guides per rod (153) C 10,089' 250' 1-1/2" 1-1/2" Sinker Bars (10) D 10,339' 1' 1" Browning On/Off Tool, J -Latch R hand release (Box X Pin) E 10,340' 2.5' 1" 1" x 30" Stabilizer Bar w/3/4" Pins F 10,343' 42' 1.75' 1-3/4" x 42' Insert Pump, RHBC Pump w/ PA Ring 80 PA Ring, Sand Seal, 2-1/2" x 1-3/4" x 36" x 36-1/2" x 37" RHBC G 10,385' 6' 1.5" Sand Screen New Rods Ran 4/11/13 (replace 1 ea %" rod 9/02/13) PERFORATION DETAIL ON NEXT PAGE FISH DETAIL ON NEXT PAGE MAX HOLE ANGLE = 3° @ 7,004' Downhole Revised: 11/24/13 Updated by STP 11/27/13 1A Swanson River Field ACTUAL SCHEMATIC Completion Ran: 1/223/13045 PERFORATION DETAIL API: 50-133-10118-00 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re-perf08-18-03 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re -perforated October 2011 10/16/1985 H1 10,518' 10,520' 10,515' 10,517' 2' Re -pert 08-18-01 / 10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 91 Re -pert 10-16-1985 / 06-10-1995 / 08-18-2001 / 10-02-2004 2/21/1961 H1 10,529' 10,530' 10,526' 10,527' 1' Re -pert 10-16-1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re -perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re-perf 10-16-1985 / 08-18-2001 / 10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re -pert 30-16-1985 / 06-10-1995 / 08-18-2001 / 10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re -pert 30-16-1985 / 06-10-1995 / 08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re -pert 30-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10-16-1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re -pert 30-16-1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 1-14/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' V Sqzd 10-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) F I 4.09' 2.375 4.25 Chemical Injection Sub S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 1 Bull Plug (Bottom f Fish) Downhole Revised: 11/24/13 Updated by STP 11/27/13 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, September 26, 2014 2:27 PM To: 'Chad Helgeson' Cc: Stan Porhola; Donna Ambruz Subject: RE: SCU 32-08 PTD # 160-045 Rod pump repair sundry Chad, Verbal approval granted to perform sundry work as outlined in the attached procedure. Submit hard copy as soon as possible. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwartz@alaska.aov). From: Chad Helgeson [ma iIto: chel4eson@hilcorp.com] Sent: Friday, September 26, 2014 1:33 PM To: Schwartz, Guy L (DOA) Cc: Stan Porhola; Donna Ambruz Subject: SCU 32-08 PTD # 160-045 Rod pump repair sundry G uy, Attached is the Sundry (10-403) for the well SCU 32-08 that we discussed this morning. We are hoping to put the rig on it on Monday to pull the rods and repair as necessary. The hard copies of this Sundry will be delivered this afternoon. If you have any questions, or need more info, please give me a call, 777-8405. Thanks for the help, Chad Helgeson STATE OF ALASKA . ALA..)mA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other Re-run Rod Pump • Performed: Alter Casing ❑ Pull Tubing 0~ Stimulate-Frac ❑ Waiver ❑ Time Extension E Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q• Exploratory ❑ 160-045 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-10118-00• 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA 028996 • Soldotna Creek unit(SCU)32-08 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Heml.;..,. 11.Present Well Condition Summary: (� EaEI"FID Total Depth measured 10,828 feet Plugs measured N/A feet DEC 0 2 2013 true vertical 10,824 feet Junk measured 10,631 (fill) feet C°°►► AOG C Effective Depth measured 10,631 feet Packer measured N/A feet true vertical 10,628 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation depth Measured depth See attached schematic True Vertical depth See attached schematic SEAMED APR 2 4 Z014 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 10,359'MD 10,356'ND Packers and SSSV(type,measured and true vertical depth) N/A;N/A N/A;N/A N/A;N/A N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 51 120 51 160 160 Subsequent to operation: 74 150 79 c 160 160 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development El . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑• Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: li 313-468 Contact Stan Porhola Email sporholaahilcorD.com Printed Name Stan Porhola Title Operations Engineer X' Signature Z 11/(/ Phone 907-777-8412 Date (((2_7/ 3 / 1.1.22•/y Fi3 , L DEC 1 3 2O1 Form 10-404 Revised 10/2012 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 32-08 50-133-10118-00 160-045 11/20/13 11/24/13 Daily Operations: 11/20/2013 -Wednesday Laid containment and sealed in. MIRU WOR and associated equipment. 11/21/2013 -Thursday RU blowdown lines from well to rig tank. Bled off well pressure. Prep rig to pull rods. Unseated pump and SOOH with rods and pump. Finished RU the Winterization Kit. MIRU SL. RIH with Temp/pressure survey to 10,400' wlm and set for 15mins. POOH. Readings were good. RDMO SL. 11/22/2013- Friday ND the Production Tree/ NU BOP's. Tested the BOPE (Witness waived by Jim Regg, AOGCC), Valves 250-3000psi, Rams 250- 3000psi, Annular 250-1500psi. Tested Gas Detection and Koomey Unit. No failures were recorded. MU lifting joint, PU to 79k,Jayed out of hanger. Stacked off to string weight at 62k. Released tbg anchor and PU and Jayed back into hanger. Backed out the lockdown pins and pulled tbg hanger. Set the slips and L/D the tbg hanger. The threads on the first joint looking up at the hanger were severely rod cut. The second joint had signs off rod wear. The third joint had no signs of wear. L/D the 1st 3 jts and secured well. SDFN. 11/23/2013 -Saturday L/D the first 3 joints. Dropped Test Plug. MU TIW and kelly hose. Pumped 40bbls of FSW down tbg. Pressured up to 1,600psi and held for 30 mins. Test okay. Bled off pressure. PU 3 new 2-7/8" 8rd tbg and MU hanger and landed with 62k# string weight. Jayed out of bowl and slacked off 48". Set tbg anchor and jayed back into hanger with tbg in 18k# in tension. Set BPV and ND BOP Stack. NU PT. Pulled BPV. MIRU SL. TIH w/2"JDC and latched Test Plug. POOH w/test plug. RDMO SL 11/24/2013 -Sunday Prep rig to run rods. PU sand/trash screen, rod pump (bucket tested good), on-off tool stabilizer bar, 10 1-1/2" sinker bars. PU the first 3/4" rod and set down. Tried to work down with no luck. TOOH with pump. The rod pump was coated with Parraffin. Cleaned pump and put 40 bbls of hot water down tbg. TBIH with screen, pump, on-off tool, stabilizer bar, 10 1- 1/2" sinker bars, 153 3/4" rods, 144 7/8" rods, 103 1" rods, 8' & 2' pony rod and polish rod. Seated the pump. Pumped 40 bbls of FSW to fill well. Stroked pump with rig and pressured up tbg to 500psi. Held for 10mins. Test ok. Bled off pressure and spaced pump out. Set rod clamp and secured well. SDFN. Swanson River Field • II ACTUAL SCH EMATI� 160-045 Completion Ran: 1/223/13 Hikora Alaska.LLC. API: 50-133-10118-00 RKB:143'/GL:128'AMSL New KB—THF:15.00' CASING DETAIL JA 1 Size WT Grade Conn ID Top Btm III 22" Surface 28' 54.5 1-55 8RD 12.615" Surface 1,308' DV @ , B 111 13-3/8"13-3/8" DV Collar 12.615" 1,308' 1,310' 1,308' 54.5 1-55 8RD 12.615" 1,310' 3.014' 28 P-110 8RD 5.791" Surface 115' 24 N-80 BTC 5.921" 115' 6,477' III 24 P-110 8RD 5.921" 6,477' 7,996' 2 6-5/8" DV Collar 5.921" 7,996' 7,998' "7, 24 P-110 8RD 5.921" 7,998' 10,037' w% 28 P-110 8RD 5.791" 10,037' 10,828' TUBING DETAIL 2-7/8" 6.5 L-80 8RD 2.441" Surface 10,359' New Tubing Ran 4/11/13 DV @ (replace 3 top jts 11/23/13) 7,996' # Depth Length ID OD Description 1 15' 1.7' 2.441" 7" Tubing Hanger)-Latch 2 2,989' 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor C 4 10,384' 0.65' 2.441" 3.5" Seating Nipple D A 5 10,390' 5.65' 4.375" 4.5" Perforated Joint 11111MMIND 3 6 61' 4.375" 4.5" 2-7/8"Tubing 6.4#IBT E 7 10,434' 0.44' 4.375" 4.5" Bull Plug F ROD DETAIL G 4 4 Depth Length OD Description 5 A 39' 40' 1-1/2" Polished Rod,24'in well B 79' 10' 1" 1"x 8'EL Pony Rod,1"x 2'EL Pony Rod 6 89' 2,575' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod(103) 2,664' 3,600' .875" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod(144) 7 6,264' 3,825' .75" %"x 25'EL Sucker rods w/ 3 XL guides per rod(153) < Top of fish @ 10,423' C 10,089' 250' 1-1/2" 1-1/2"Sinker Bars(10) 11/1/ D 10,339' 1' 1" Browning On/Off Tool,J-Latch R hand release(Box X Pin) E 10,340' 2.5' 1" 1"x 30"Stabilizer Bar w/3/4"Pins 1-3/4"x 42'Insert Pump,RHBC Pump w/PA Ring F 10,343' 42' 1.75' 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37"RHBC G 10,385' 6' 1.5" Sand Screen New Rods Ran 4/11/13 (replace 1 ea 3/d'rod 9/02/13) Bad pgTD±10,631 Casing @ 10,634' PERFORATION DETAIL ON NEXT PAGE FISH DETAIL ON NEXT PAGE MAX HOLE ANGLE=3° @ 7,004' 4: -:i DownhnIe Revised: 11/24/13 Undated by STP 11/27/13 iii • Swanson River Field ACTUAL SCH E MATT L Swanson 32-08 River PTD 160-045 Completion Ran:11/23/13 Hilcora Alaska,LLC API: 50-133-10118-00 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re-perf08-18-01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re-perforated October 2011 10/16/1985 H1 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-01/10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 9Re pert 10-16-1985/06-10-1995/08-18-2001' /10-02-2004 2/21/1961 H1 10,529' 10,530' 10,526 10,527' 1' Re-perf 10-16-1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re-perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re-perf 10-16-1985/08-18-2001/10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re-perf 10-16-1985/06-10-1995/08-18-2001 /10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re-perf 10-16-1985/06-10-1995/08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566 10,569' 3' Re-perf 10-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10-16-1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re-perf 10-16-1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple(Top of Fish) F 4.09' 2.375 4.25 Chemical Injection Sub S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug(Bottom f Fish) Downhole Revised: 11/24/13 Updated by STP 11/27/13 r yO 774, • • yw\s'\1�j s?. THE STATE Alaska Oil and Gas ofALASKA _ Conservation Commission OF T„w GOVERNOR SEAN PARNELL t x 333 West Seventh Avenue P Anchorage, Alaska 99501-3572 ALAS* Main: 907.279.1 433 SCANNED " , Fax: 907.276.7542 Stan Porhola Operations Engineer Hilcorp Alaska, LLC � 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Soldotna River Field, Hemlock Oil Pool, SCU 32-08 Sundry Number: 313-577 Dear Mr. Porhola: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / i Cathy P. oerster Chair, ommissioner DATED thisday of November, 2013. • Encl. • , STATE OF ALASKA 1 M , 'u � ALASKA OIL AND GAS CONSERVATION COMMISSION �I��`e : APPLICATION FOR SUNDRY APPROVALS A(_; _ / ' 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing El i Time Extension LI Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing ❑ j —,t?.... Sher[E 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number. `• Exploratory ❑ Development 160-045 �D • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-10118-00 ' /7,"S v 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)32-08 Will planned perforations require a spacing exception? Yes ❑ No 12 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA 028996' Swanson River Field/Hemlock Oil, 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 10,828 - 10,824 10,631 10,628 N/A 10,631'(fill) Casing Length Size MD ND Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: `Tubing Grade: Tubing MD(ft): N/A N/A 2-7/8" 6.5#/L-80 10,359 Packers and SSSV Type: N/A Packers and SSSV MD(ft)and ND(ft): N/A N/A N/A 12.Attachments: Description Summary of Proposal el 13.Well Class after proposed work: Detailed Operations Program U BOP Sketch U Exploratory U Stratigraphic U Development U - Service U 14.Estimated Date for 15.Well Status after proposed work: 11/09/13 Commencing Operations: Oil In ` Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sporholaCa�hilcorp.com, Printed Name Stan Porhola' Title Operations Engineer Signature ) " "'P�3.4/L. Phone 907-777-8412 Date tl/ L1/i3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3V3 - 5?7 Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ R5� 1 rr C7 NOV'v Other: . 3606 re: f P 7 Spacing Exception Required? Yes ❑ No C) Subsequent Form Required: / O"' Yd`--/ / APPROVED BY Approved by: (l` / J COMMISSIONER THE COMMISSION Date: //— f-�5 R443 ,Form 10-403(Revised 10/2012) Appr e Lind s fl'om the date of approval. � �ttachmenb it Duplicate `. • • Well Prognosis Well: SCU 32-08 Hilcorp Alaska,LLC Date: 11/04/2013 Well Name: SCU 32-08 API Number: 50-133-10118-00 Current Status: Oil Producer Leg: N/A Estimated Start Date: November 9th, 2013 Rig: Moncla#405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-045 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: —2,000 psi @ 10,500' TVD (Static survey and fluid level Calculations.) Maximum Expected BHP: —2,000 psi @ 10,500' ND Max.Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 95% (0.435psi/ft) with added Safety Factor of 1,000' TVD of oil cap) Brief Well Summary Soldotna Creek Unit 32-08 was repaired and put into production in December 2012. The pump was replaced in January 2013. Debris from the previous workover seized the pump. The pump was replaced with a new pump in January. A hole in the tubing was found in the chemical injection mandrel and the tubing was re-run in April 2013. A parted rod was fished out and replaced in September 2013 and the well placed back on production. Plan is to pull the , rods and pump, identify the tubing leak and replace the tubing string as necessary. - Notes Regarding Wellbore Condition • Possible leak in the tubing(plan to replace entire tubing string if necessary). Brief Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer)on casing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. 3. MIRU Moncla#405 WO Rig 4. Nipple up rod stripper head. 5. LD polish rod and LD EL rods. 6. LD pump, investigate pump damage. 7. Drop standing valve to test tubing.Test tubing to 2,000 p i, a. If tubing tests good, re-run pump and rods. b. If tubing does not test good, plan to pull tubing. 8. RU slickline, pull standing valve. 9. Set BPV. ND rod stripper head and tree. 10. NU BOPE and test to 250psi low/3,000s1 high (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24hrs in advance to witness, be ready to test when/if inspector arrives. b. Using 7-1/16" BOPE. 11. Pull tubing hanger free, unseat tubing anchor and POOH w/tubing. 12. Lay down tubing string(2-7/8" 8RD). a. Inspect tubing for holes/worn joints. 13. RIH w/new 2-7/8" 8RD 1-80 tubing. a. Set depth indicator sub at approx. 3,000'. • • Well Prognosis Well: SCU 32-08 Hilcorp Alaska,LLC Date:11/04/2013 14. Set tubing anchor and land existing Seaboard tubing hanger. 15. Set TWC, ND BOPE, NU tree and test. Pull TWC. 16. NU Rod stripper. 17. PU existing 1-3/4" rod pump, RIH with new 1-1/2" sinker bars and existing tapered EL rod string (3/4",7/8" and 1"), space out the rods, install polish rod. 18. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 19. RD Moncla#405. 20. Roll up Rotoflex pumping unit, recouple,and remove LOTO on motor. 21. Return to production with same surface safety system as previously installed. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Diagram • II • Swanson River Field ACTUAL S C H E M Al Compl ted?4/09/2013 60-045 Hilrorp:ua,k:,.i.1.c API: 50-133-10118-00 RKB:143'/GL:128'AMSL New KB—THF:15.00' CASING DETAIL A 1 Size WT Grade Conn ID Top Btm IIIg Surface 28' 22" 111 54.5 1-55 8RD 12.615" Surface 1,308' DV @ • B III; 13-3/8" DV Collar 12.615" 1,308' 1,310' 1,308' 54.5 1-55 8RD 12.615" 1,310' 3.014' 28 P-110 8RD 5.791" Surface 115' 24 N-80 BTC 5.921" 115' 6,477' �I` 24 P-110 8RD 5.921" 6,477' 7,996' 6-5/8" DV Collar 5.921" 7,996' 7,998' 24 P-110 8RD 5.921" 7,998' 10,037' III' 28 P-110 8RD 5.791" 10,037' 10,828' I TUBING DETAIL 2-7/8" 6.5 L-80 8RD 2.441" Surface 10,359' lI DV @ JEWELRY DETAIL 7,996' 1 # Depth Length ID OD Description IiI1 15' 1.7' 2.441" 7" Tubing Hanger J-Latch I 2 2,989' 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor 4 10,384' 0.65' 2.441" 3.5" Seating Nipple C III 5 10,390' 5.65' 4.375" 4.5" Perforated Joint Or 6 61' 4.375" 4.5" 2-7/8"Tubing 6.4#IBT 7 10,434' 0.44' 4.375" 4.5" Bull Plug D ROD DETAIL E F 4 # Depth Length OD Description i 5 A 5' 40' 1-1/2" Polished Rod,30'in well B 45' 8' 1" 1"x 8'EL Pony Rod 6 53' 2,700' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod(108) 2,753' 3,525' .875" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod(141) 7 6,278' 3,975' .75" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod(159) 4 , Top of fish @ 10,423' C 10,253' 30' 1" 1"x 30"Stabilizer Bar w/%"Pins(between K Bars) I�� I D 10,283' 1' Browning On/Off Tool,J-Latch R hand release(Box X Pin) E 10,284' 2.5' 1" 1"x 30"Stabilizer Bar w/3/4"Pins 1-3/4"x 42'Insert Pump,RHBC Pump w/PA Ring F 10,287' 42' 1.75' 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x ' 37"RHBC PERFORATION DETAIL ON NEXT PAGE Bad PBTD±10,631' illk Casing @ 10,634' FISH DETAIL ON NEXT PAGE MAX HOLE ANGLE=3° @ 7,004' A--> - Downhole Revised:09/02/13 Updated by STP 11/04/13 TD=10,828' PBTD=10,631' , 13 • Swanson River Field ACTUAL SCHEMA Completed: 60045 4/09/2013 Hilcoru Alaska.LI.0 API: 50-133-10118-00 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 Hi 10,518' 10,533' 10,515' 10,530' 15 Re-perforated October 2011 10/16/1985 Hi 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-01/10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 9' Re-perf 10-16-1985/06-30 1995/08-18-2001 /10-02-2004 2/21/1961 H1 10,529' 10,530' 10,526' 10,527' 1' Re-perf 10-16-1985 10/16/1985 Hi 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re-perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re-perf 10-16-1985/08-18-2001/10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re-perf 10-16-1985/06-10 1995/08 18-2001 /10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re-perf 10-16-1985/06-10-1995/08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re-perf 10-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10-16-1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re-perf 10-16-1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple(Top of Fish) F 4.09' 2.375 4.25 Chemical Injection Sub I S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug(Bottom f Fish) Downhole Revised:09/02/13 Updated by STP 11/04/13 Swanson River Field • ti °PROPOSED SCHEMA Pop D160-045 Proposed Hilmrn Ala..ka.LLC API: 50-133-10118-00 RKB:1437 GL:128'AMSL New KB—THF:15.00' CASING DETAIL A 1 Size WT Grade Conn ID Top Btm III - - -LL 22�� Surface 28' 54.5 J-55 8RD 12.615" Surface 1,308' DV @ B III 13-3/8" DV Collar 12.615" 1,308' 1,310'• 1,308' 54.5 1-55 8RD 12.615" 1,310' 3.014' 28 P-110 8RD 5.791" Surface 115' 111 24 N-80 BTC 5.921" 115' 6,477' q24 P-110 8RD 5.921" 6,477' 7,996' fmi 2 6-5/8" 1 II DV Collar 5.921" 7,996' 7,998' 24 P-110 8RD 5.921" 7,998' 10,037' q 28 P-110 8RD 5.791" 10,037' 10,828' r TUBING DETAIL 2-7/8" 6.5 L-80 8RD 2.441" Surface 10,359' II! DV @ JEWELRY DETAIL 7,996' 1 # Depth Length ID OD Description III1 15' 1.7' 2.441" 7" Tubing Hanger J-Latch 2 2,989' 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor C 4 10,384' 0.65' 2.441" 3.5" Seating Nipple CD I�I 5 10,390' 5.65' 4.375" 4.5" Perforated Joint LF 3 6 61' 4.375" 4.5" 2-7/8"Tubing 6.4#IBT 7 10,434' 0.44' 4.375" 4.5" Bull Plug E ROD DETAIL F G 4 # Depth Length OD Description 5 A 5' 40' 1-1/2" Polished Rod,30'in well B 45' 8' 1" 1"x 8'EL Pony Rod 6 53' 2,700' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod(108) 2,753' 3,525' .875" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod(141) 7 6,278' 3,675' .75" '/<"x 25'EL Sucker rods w/ 3 XL guides per rod(147) 1 < Top of fish @ 10,423' C 9,953' 300' 1-1/2" 1-1/2"Sinker Bars(12) 10 D 10,253' 30' 1" 1"x 30"Stabilizer Bar w/%"Pins(between K Bars) ± E 10,283' 1' Browning On/Off Tool,J-Latch R hand release(Box X Pin) - F 10,284' 2.5' 1" 1"x 30"Stabilizer Bar w/3/4"Pins 1-3/4"x 42'Insert Pump,RHBC Pump w/PA Ring G 10,287' 42' 1.75' 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x -- 37"RHBC PERFORATION DETAIL ON NEXT PAGE Bad PBTD 110,631 ilt Casing @ 10,634' FISH DETAIL ON NEXT PAGE MAX HOLE ANGLE=3° @ 7,004' ___ ____ Downhole Proposed Updated by STP 11/04/13 TD=10,828' PBTD=10,631' Swanson River Field ,,.. • ti �ROPOSED SCHEMA Proposed CompletoD160-045 Hilcora Alaska.LLC API: 50-133-10118-00 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re-perforated October 2011 10/16/1985 H1 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-01/10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 9 Re perf 10-16-1985/06-10-1995/08-18-2001' /10-02-2004 2/21/1961 H1 10,529' 10,530' 10,526' 10,527' 1' Re-perf 10-16-1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re-perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re-perf 10-16-1985/08-18-2001/10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re-perf 10-16-1985/06-10-1995/08-18-2001 /10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re-perf 10-16-1985/06-10-1995/08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re-perf 10-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10-16-1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re-perf 10-16-1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple(Top of Fish) F 4.09' 2.375 4.25 Chemical Injection Sub I S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug(Bottom f Fish) Downhole Proposed Updated by STP 11/04/13 ,‘ ti • • Swanson River 2013 Moncla Rig 405 Knight Oil Tools BOP Ililrurp.tlnwka_Ii.(: 1 0 0 iii iii I .I iii lii I 1 111 II 2.57' / Shaffer 7 1/16 5000 S. narl (f lfffil rf1 7 WitriFULUTIO 7 \ \ 2 3/8-3%2 variable /"--ti I CAMERON 3.68' H I, I 1 la Blind H Cr 7 1/16 5000 ) H \ \ It / / �I I tI I 1 1 1 _ Choke and Kill valves are 2 1/16 10M i ri" riCrinUTURTIMD " Ird ,...r. :I I 1.56' i 1 r l I 71/16 5000 $ Tri40 1 . _ . •, • 116 ■ I 1 61l1 STATE OF ALASKA RECEIVED ALADA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate L] Other L A Performed: Alter Casing ❑ Pull Tubing SI • Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development IS • Exploratory ❑ 160-045 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-10118-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA 028996 • Soldotna Creek unit(SCU)32-08 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil • 11.Present Well Condition Summary: Total Depth measured 10,828 - feet Plugs measured N/A feet true vertical 10,824 ' feet Junk measured 10,631 (fill) feet Effective Depth measured 10,631 feet Packer measured N/A feet true vertical 10,628 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation depth Measured depth N/A True Vertical depth N/A SCANNED N U: 2 013 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 10,359'MD 10,356'ND Packers and SSSV(type,measured and true vertical depth) N/A;N/A N/A;N/A N/A;N/A N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 64 21 67 160 160 Subsequent to operation: 109 31 7 150 150 14.Attachments: 15.Well Class after work: • Copies of Logs and Surveys Run N/A Exploratory, ❑ Development© Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 1 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-468 / Contact Stan Porhola Email sporholat�hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature tn�.. t„ I c v"t:'�'",-,,e Phone 907-777-8412 , , , Date 0;'C c.j`( I ' ,d) Form 10-404 Revised 10/2012 / Submit Original Offilt `o' • S Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 32-08 50-133-10118-00 160-045 8/31/13 9/2/13 Daily Operations: 08/31/2013-Saturday Continue RD and demob from SRU 21-27. LD rig and clean up miscellaneous items on location. Mob carrier to location. Wait on pit liner and trucks. Only one truck on location and first load out @ 12:00. Two additional trucks arrive @ 13:00. Install pit liner and haul loads to location. Spot equipment. Clean up SRU 21-27 pad. High congestion on last location due to simultaneous production work. Shut down for night 09/01/2013 -Sunday Monitor well-SITP 150 psi. Blow down casing and tubing to 0 psi and monitor. Continue RU-spot rig and raise mast,finish pit liner, RU to pull rods. WO production to shoot fluid level. Shoot fluid level on tubing and casing- not readable on tubing and 8,200' on casing. Pull polished rod-16 Klbs string weight. LD polished rod and stuffing box. MU rod table and PU 2 rods. Attempt to screw into fish- no luck. LD 2 rods. POOH w/ 1" rods (107). WO transfer for different style 7/8" rods. POOH w/ 7/8" rods (141) and 3/4" rods(18)to find rod parted in middle of top threads. Half of threads and 1.5" stop looking up @ 6,700' MD RKB. MU 2-5/16" OD cut-lip overshot dressed w/1.5" grapple and XO to 3/4" sucker rod. RIH w/overshot on sucker rods to top of fish. Tag fish @ 6,700' and attempt to engage w/ no luck. Rotate on fish and attempt to engage w/no luck. Attempt several more times w/rotating and tagging and no overpull or sign of engaging fish. POOH 2 rods, PU polished rod and stuffing box. Secure well and shut down for night. 09/02/2013- Monday Monitor well-well dead. LD polished rod and stuffing box. POOH w/overshot on sucker rods. LD overshot and inspect, some wear on grapple, no other marks on overshot- replace grapple. MU overshot. RIH w/2-5/16" OD cut-lip overshot w/ 1.5" grapple on sucker rods to top of fish. Set down on fish and hit 1X, PU and engage fish. Pull 4 Klbs over string weight and not free. Work rod string pulling up to 4 Klbs over and string came free and stroked pump. POOH to seating nipple and unseat pump, working string 4 Klbs over- no issue. POOH slowly w/overshot and sucker rod pump fish. LD overshot and parted rod. PU new rod and continue POOH to pump. Inspect all rods while POOH. Total rods- 108 (1"), 141 (7/8"), 159 (3/4"). No weight bars. OOH w/pump-function test pump and working properly. Some paraffin on screen, LD screen. Seals look good. RIH w/sucker rod pump assembly on existing rods. Change out 2 bad couplings and one rod, replace with new. PU pony rods, LD rod table and PU polished rod and stuffing box. Seat pump and confirm set. Install rod clamps. Secure well. Rig released to SCU 12B-09. • Swanson River Field Well:SCU ACTUAL SCHEMA-14k Completed: 0/ 20/20110 045 ['Hearn Alaska.I.T.C. API: 50-133-10118-00 RKB:143'/GL:128'AMSL New KB-THF:15.00' CASING DETAIL A 1 Size WT Grade Conn ID Top Btm III - - - 22" Surface 28' 54.5 J-55 8RD 12.615" Surface 1,308' DV @ , B III 13-3/8" DV Collar 12.615" 1,308' 1,310' 1,308' 54.5 1-55 8RD 12.615" 1,310' 3.014' 28 P-110 8RD 5.791" Surface 115' o24 N-80 BTC 5.921" 115' 6,477' r1 24 P-110 8RD 5.921" 6,477' 7,996' 2 6-5/8" DV Collar 5.921" 7,996' 7,998' - 24 P-110 8RD 5.921" 7,998' 10,037' III, 28 P-110 8RD 5.791" 10,037' 10,828' TUBING DETAIL 2-7/8" 6.5 L-80 8RD 2.441" Surface 10,359' III DV @ JEWELRY DETAIL 7,996' 1 # Depth Length ID OD Description III1 15' 1.7' 2.441" 7" Tubing Hanger)-Latch 2 2,989' 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor 4 10,384' 0.65' 2.441" 3.5" Seating Nipple C III 5 10,390' 5.65' 4.375" 4.5" Perforated Joint 3 6 61' 4.375" 4.5" 2-7/8"Tubing 6.4#IBT 1 7 10,434' 0.44' 4.375" 4.5" Bull Plug D I E ROD DETAIL F 4 # Depth Length OD Description 5 A 5' 40' 1-1/2" Polished Rod,30'in well B 45' 8' 1" 1"x 8'EL Pony Rod 6 53' 2,700' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod(108) 2,753' 3,525' .875" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod(141) ------- 7 6,278' 3,975' .75" '/,"x 25'EL Sucker rods w/ 3 XL guides per rod(159) Top of fish @ 10,423' C 10,253' 30' 1" 1"x 30"Stabilizer Bar w/'/"Pins(between K Bars) D 10,283' 1' Browning On/Off Tool,J-Latch R hand release(Box X Pin) — — E 10,284' 2.5' 1" 1"x 30"Stabilizer Bar w/3/4"Pins `— _ 1-3/4"x 42'Insert Pump,RHBC Pump w/PA Ring F 10,287' 42' 1.75' 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x ��_ 37"RHBC I — PERFORATION DETAIL ON NEXT PAGE Bad PBTD±10,631' Casing @ 10,634' FISH DETAIL ON NEXT PAGE 1 MAX HOLE ANGLE=3° @ 7,004' A'>...4<k Downhole Revised:09/02/13 Updated by STP 10/02/13 TD=10,828' PBTD=10,631' d Fie ver l ACTUAL SCHEMA AC Well:SCU Swanson River /PTD 160045 Completed: 10/20/2011 Hilcora Alaska.Id.0 API: 50-133-10118-00 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' . 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 H1 10,516' A 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 H1 10,518' , 10,533' 10,515' 10,530' 15 Re-perforated October 2011 10/16/1985 H1 10,518' , 10,520' 10,515' 10,517' 2' Re-perf 08-18-01/10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 9' Re-perf 10-16-1985/06-10-1995/08-18-2001 /10-02-2004 2/21/1961 H1 10,529' • 10,530' 10,526' 10,527' 1' Re-pert 10-16-1985 10/16/1985 H1 10,530' . 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' , 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' , 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re-perforated October 2011 6/10/1995 H2 10,546' . 10,550' 10,543' 10,547' 4' Re-pert 10-16-1985/08-18-2001/10-02-2004 2/21/1961 H2 10,550' . 10,560' 10,547' 10,557' 10' Re pert 10-16-1985/06 10-1995/08-18 2001 /10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re-pert 10-16-1985/06-10-1995/08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re-pert 10-16-1985 t 2/21/1961 H2 10,572' , 10,575' 10,569' 10,572' 3' Sqzd 10-16-1985 2/21/1961 H3 10,580' , 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' - 10,600' 10,589' 10,597' 8' Re-pert 10-16-1985 2/21/1961 H3 10,600' . 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' . 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' - 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10-16-1985 2/20/1961 WSO 10,681' . 10,682' 10,677' 10,678' 1' Sqzd 10-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple(Top of Fish) F 4.09' 2.375 4.25 Chemical Injection Sub I S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug(Bottom f Fish) Downhole Revised:09/02/13 Updated by STP 10/02/13 t • w w��\\I%% �s9 THE STATE Alaska Oil and Gas ofl L S}( 1 Conservation Commission TR,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS,' Main: 907.279.1433 O2,j tiv Fax 907.276.7542 Stan Porhola r Operations Engineer 1 /0 (4 5 Hilcorp Alaska, LLC ` U/ 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 32-08 Sundry Number: 313-468 Dear Mr. Porhola: 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, Daniel T. Seamount, Jr. Commissioner DATED this// day of September, 2013. Encl. 0 0 cbt)1144--4 ,RECEIVED STATE OF ALASKA R/Ile 1 AUG 2 8 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION ` APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing ❑ Other. Repair Rod Part 1151 4 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number. Exploratory ❑ Development Ei - 160-045 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic III Service I=1 6.API Number. Anchorage,Alaska 99503 50-133-10118-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Soldotna Creek Unit(SCU)32-08 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA 028996 ' Swanson River Field/Hemlock Oil . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,828 10,824 • 10,631 10,628 N/A 10,631'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 2-7/8" 6.4#/L-80 10,359 Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A N/A N/A 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program U BOP Sketch U Exploratory U Stratigraphic U Development U Service Li 14.Estimated Date for 15.Well Status after proposed work: 08/31/13 Commencing Operations: Oil Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: r.3a.f3 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: C` 52-L...A— GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is tie and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sporhola(a�hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature /d > — Phone 907-777-8412 Date l COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: e3 —E.(15- Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBI Mt OCT 1 0 20 Spacing Exception Required? Yes ❑ No Di Subsequent Form Required: /U—ti 0 Li APPROVED BY r Approved by: COMMISSIONER THE COMMISSION Date:g�`1 / 2.3 i‘. A•pove g 13 G4N AnEfrom Submn Form ane �1 ��Form 10-403(Revised 10/2012) Approved a I' 1 the date of approvaleG��ttachments in Duplicate • • . fir Well Prognosis Well: SCU 32-08 Hilcora Alaska,LL1 Date:8/28/2013 Well Name: SCU 32-08 API Number: 50-133-10118-00 Current Status: Oil Producer Leg: N/A Estimated Start Date: August 315t, 2013 Rig: Cloverleaf#4 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-045 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: —2,000 psi @ 10,500' ND (Static survey and fluid level Calculations.) Maximum Expected BHP: —2,000 psi @ 10,500' ND Max.Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 95% (0.435psi/ft) with added Safety Factor of 1,000' ND of oil cap) Brief Well Summary Soldotna Creek Unit 32-08 was repaired and put into production in December 2012. The pump was replaced in January 2013. Debris from the previous workover seized the pump. The pump was replaced with a new pump in January.A hole in the tubing was found in the chemical injection mandrel and the tubing was re-run in April 2013. Plan is to pull the parted rods and fish the remaining rods and pump and replace the parted rods as needed. Notes Regarding Wellbore Condition • The rod string is showing a weight of 15,000 lbs, indicating parted rods down the well at+/-6,200', which could be at the base of the 7/8" rods or top of the 3/4" rods. Brief Procedure: 1. Blow-down any pressure on the well and shoot fluid level(echometer)on casing and tubing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. . 3. MIRU Cloverleaf#4 WO Rig. 4. Nipple up rod stripper head. 5. LD polish rod and pull EL rods. Rack back the rods in basket. 6. LD parted rod (suspected part depth at+/-6,200'; may be a 7/8"or 3/4" rod). 7. Fish parted rods and LD parted rod. Rack back the rods in basket. 8. LD and inspect pump and dip tube. 9. PU existing dip tube(remove strainer screen on based of pump if installed)and existing 1-3/4" rod pump, RIH with tapered rod string(sinker bars,3/4",7/8" and 1"as previously run), Inspect rods and guides and replace as necessary and the pump,space out the rods, install polish rod. 10. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 11. RD Cloverleaf#4 WO Rig. 12. Roll up Rotoflex pumping unit, recouple, install new belt,and remove LOTO on motor. 13. Return to production with same surface safety system as previously installed. Attachments: 1. Actual Schematic • , • Swanson River Field Well:SCU 32-08/PTD 160-045 ACTUAL SCHEMAfC Well: 10/20/2011 P ii,i«era Aia,ka.t i C API: 50-133-10118-00 RKB:143'/GL:128'AMSL New KB-THF:15.00' CASING DETAIL A 1 Size WT Grade Conn ID Top Btm III 22" Surface 28' 54.5 J-55 8RD 12.615" Surface 1,308' al DV @ • B III i ': 13-3/8" DV Collar 12.615" 1,308' 1,310' 1,308' - I [1:■ 54.5 1-55 8RD 12.615" 1,310' 3.014' 28 P-110 8RD 5.791" Surface 115' III 24 N-80 BTC 5.921" 115' 6,477' 24 P-110 8RD 5.921" 6,477' 7,996' 2 6-5/8" IIDV Collar 5.921" 7,996' 7,998' 24 P-110 8RD 5.921" 7,998' 10,037' iii 28 P-110 8RD 5.791" 10,037' 10,828' Suspect TUBING DETAIL Rod part @ +/-6,200' 1 2-7/8" 6.4 L-80 8RD 2.441" Surface 10,359' III DV @ JEWELRY DETAIL 7,996' 1 # Depth Length ID OD Description III1 15' 1.7' 2.441" 7" Tubing Hanger J-Latch C I 2 2,989' 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor 4 10,384' 0.65' 2.441" 3.5" Seating Nipple i!i 5 10,390' 5.65' 4.375" 4.5" Perforated Joint sat - _ 3 6 61' 4.375" 4.5" Tubing 6.5#IBT D 7 10,434' 0.44' 4.375" 4.5" Bull Plug E ROD DETAIL F G 4 # Depth Length OD Description 5 A 30' 40' 1-1/2" Polished Rod,30'in well B 38' 8' 1" 1"x 8'EL Pony Rod H 6 39' 2,625' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod 2,749' 3,550' .875" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod 7 - 6,300' 3,725' 'A" g p .75" x 25'EL Sucker rods w/ 3 XL guides per rod Top of fish @ 10,423' C 10,024' 300' 1.5" 1-1/2"x 25'K Bars(weight bars) all D 10,325' 30' 1" 1"x 30"Stabilizer Bar w/'"Pins(between K Bars) - E 10,354' 1' Browning On/Off Tool,J-Latch R hand release(Box X Pin) F 10,355' 2.5' 1" 1"x 30"Stabilizer Bar w/3/4"Pins _ 1-3/4"x 42'Insert Pump,RHBC Pump w/PA Ring G 10,358' 42' 1.75' 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37"RHBC H 10,368' 13' 1.5" Dip Tube Bad PERFORATION DETAIL ON NEXT PAGE PBTD±10,631 Casing @ ::: 10,634' FISH DETAIL ON NEXT PAGE _-_- -_ _____i MAX HOLE ANGLE=3° @ 7,004' Updated by STP 08/28/13 TD=10,828' PBTD=10,631' • s • Swanson River Field ACTUAL SCHEMAtC Completed:leted?08/20/20110-045 Hilearn Alaska,LLC API: 50-133-10118-00 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G-1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10-12-1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re-perforated October 2011 10/16/1985 H1 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-01/10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' g Re-pert' 10-16-1985/06-10-1995/08-18-2001 /30-02-2004 2/21/1961 H1 10,529' 10,530' 10,526' 10,527' 1' Re-perf 10-16-1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re-perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re-perf 10-16-1985/08-18-2001/10-02-2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10 Re-pert' 10-16-1985/06-10-1995/08-18-2001 /10-02-2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re-perf 10-16-1985/06-10-1995/08-18-2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re-perf 10-16-1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10-16-1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10-16-1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re-perf 10-16-1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10-16-1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10-16-1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10-16-1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10-16-1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10-16-1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple(Top of Fish) F 4.09' 2.375 4.25 Chemical Injection Sub I S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug(Bottom f Fish) Updated by STP 08/28/13 • • Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Friday,August 30, 2013 2:39 PM To: 'Stan Porhola' Subject: RE:Verbal Approval request to pull parted rods on SCU 32-08 (PTD 160-045) You have verbal approval to proceed with RWO to replace pump rods on SCU 32-08 as outlined in your sundry application. If scope of work changes notify AOGCC immediately. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Stan Porhola [avaRo i,porecAii, r r ,=or ] Sent: Friday, August 30, 2013 2:37 PM To: Schwartz, Guy L(DOA) Subject: Verbal Approval request to pull parted rods on SCU 32-08 (PTD 160-045) Guy, We are requesting verbal approval to pull parted rods from SCU 32-08(PTD 160-045),one of our Rotaflex Rod Pump wells in Swanson River. Based on the rod pumps inability to lift fluids to surface and having a string weight of only 15,000 lbs, it appears that we have parted rods at+/-6,200' MD.A 10-403 sundry was submitted on 8/28/13. Let me know if you need any additional information. Regards, Stan Porhola I Oper.Itions finO veer. North Kenai Asset Team Hilcorp Alaska,LLC alit$•] C .'ri t ._ ,n 1 • '� STATE OF ALASKA 110 r: • ALASKA OIL AND GAS CONSERVATION COMMISSION n -i % 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations Lf Perforate ❑ Other u Repair Rod Pump Performed: Alter Casing ❑ Pull Tubing 0 Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC • Development 0 • Exploratory ❑ 160 -045 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 50- 133 - 10118 -00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA 028996 Soldotna Creek unit (SCU) 32 -08 • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Swanson River Field / Hemlock Oil • 11. Present Well Condition Summary: Total Depth measured 10,828 feet • Plugs measured N/A feet true vertical 10,824 feet Junk measured 10,631 (fill) feet Effective Depth measured 10,631 feet Packer measured N/A feet true vertical 10,628 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13 -3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6 -5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation depth Measured depth N/A SCANNED JUN 0 4 2013 True Vertical depth N/A Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.4# / L -80 10,359' MD 10,356' TVD Packers and SSSV (type, measured and true vertical depth) N /A; N/A N /A; N/A N /A; N/A N /A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 44 40 65 175 175 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development 0 ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil In • Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -161 Contact Chad Helgeson Email chelgesonahilcona.com Printed Name Chad Helgeson Title Operations Manager ./ Signature ��'� Phone 907-777-8405 Date Jr /�Z !/l 3 S 31 — 13 RBDMS �1 Form 10 -404 Revised 10/2012 S MAY 2 9 20 13 Submit Origina y • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 32 -08 50- 133 - 10118 -00 160 -045 4/4/13 4/10/13 Daily Operations: 04/04/2013 - Thursday MIRU WOR. PU on rods and rod pump was not seated. SOOH with rods and downhole pump. The pump was hung open at a quarter of a stroke, tried working pump free with no luck. Dropped standing value and pumped 80 bbls. Tbg would not pressure up. MIRU SL, RIH w/ 2 -1/4" blind box and tagged fluid at 1,500'. POOH. RIH w /2" JDC and to 10,340'. Latched SV and POOH w /SV. RD SL. 04/05/2013- Friday RU WOR equip. RU SL, RIH w/ 2" magnet to SN at 10,384' wim. POOH w /metal shavings recovered. RIH w /same and magnet was clean. PU a SV and RIH, set SV in SN at 10,384'. RU rig pump and pumped 80 bbls of PW and tbg would not test. POOH w/ SV. PU a 2" DD bailer and RIH, tag bullplug at 10,434'wlm. POOH no sample. RIH w/ collar stop and packoff plug. Set @ 10,353'wlm. Pumped 60 bbls and tbg did not test. RDMO SL. 04/06/2013 - Saturday Finished final RU and prep rig for BOPE Test 04/07/2013 - Sunday Tested BOPE per AOGCC regs (witness waived by Jim Regg, 250 low - 3000 high). Prep rig to pull PT and Control Line. ÷/ Released tbg hanger and tbg anchor. SOOH with 63 stands to chem injection mandrel. Found rod wear in mandrel. The pin end of the tbg joint that connects to the bottom of mandrel was split. TOOH with 4 more stands and found fliud. Tested the tbg to 500psi and held 15 mins. SDFN. 04/08/2013 - Monday Continued SOH w/ 2 -7/8" production tbg, broke down BHA, found no debris or solids, very little metal shavings. Put BHA back together and started TBIH, TBIH with 30 stands of 2 -7/8" Production Tbg and BHA. Secured well, SDFN. 04/09/2013 - Tuesday Continued TIH W/ 2 -7/8" Production String, Installed marker sub @ 2,989'. Continued TIH W/ Production string, Landed tbg hanger, J -ed out of hanger, set tbg anchor with 60,000# string weight, pulled up to 80,000# and j -ed back into hanger body, total of 20,000# pulled into tbg on hanger. Set BPV in Tbg hanger, Secured well, SDFN. II • • Swanson River Field SCHEMATIC Well: on River 32-08 / Field PTD 160-045 Completed: 10/20/2011 " ' k ' "" ".k . LLC API: 50- 133 - 10118 -00 RKB: 1437 GL: 128' AMSL New KB -THF: 15.00' CASING DETAIL A III 1 Size WT Grade Conn ID Top Btm - - - 22" Surface 28' 54.5 J -55 8RD 12.615" Surface 1,308' D @ g M 13 -3/8" DV Collar 12.615" 1,308' 1,310' 1 , 54.5 1 -55 8RD 12.615" 1,310' 3.014' 28 P -110 8RD 5.791" Surface 115' 24 N -80 BTC 5.921" 115' 6,477' 24 P -110 8RD 5.921" 6,477' 7,996' 2 6 -5/8" DV Collar 5.921" 7,996' 7,998' N 24 P -110 8R0 5.921" 7,998' 10,037' ®N�111 28 P -110 8RD 5.791" 10,037' 10,828' TUBING DETAIL II I 2-7/8" 6.4 L -80 8RD 2.441" Surface 10,359' DV @ JEWELRY DETAIL 7,996' 1 # Depth Length ID OD Description I - II 1 15' 1.7' 2.441" 7" Tubing Hanger J -Latch C 2 2,989' 2.441" 5" Marker Sub 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor 4 10,384' 0.65' 2.441" 3.5" Seating Nipple I _II 5 10,390' 5.65' 4.375" 4.5" Perforated Joint 3 6 61' 4.375" 4.5" Tubing 6.5# IBT D 7 10,434' 0.44' 4.375" 4.5" Bull Plug E F ROD DETAIL G 4 # Depth Length OD Description 5 A 30' 40' 1 -1/2" Polished Rod, 30' in well B 38' 8' 1" 1" x 8' EL Pony Rod H i 6 39' 2,625' 1" 1" x 25' EL Sucker rods w/ 3 XL guides per rod — 2,749' 3,550' .875" 7/8" x 25' EL Sucker rods w/ 3 XL guides per rod Mt 7 6,300' 3,725' .75" %" x 25' EL Sucker rods w/ 3 XL guides per rod II Top of fish @ 10,423' C 10,024' 300' 1.5" 1 -1/2" x 25' K Bars (weight bars) 1:` ' D 10,325' 30' 1" 1" x 30" Stabilizer Bar w/'/" Pins (between K Bars) E 10,354' 1' Browning On /Off Tool, J -Latch R hand release (Box X Pin) F 10,355' 2.5' 1" 1" x 30" Stabilizer Bar w/3/4" Pins 1 -3/4" x 42' Insert Pump, RHBC Pump w/ PA Ring G 10,358' 42' 1.75' 80 PA Ring, Sand Seal, 2 -1/2" x 1 -3/4" x 36" x 36 -1/2" x 37" RHBC == H 10,368' 13' 1.5" Dip Tube B PERFORATION DETAIL ON NEXT PAGE PBTD ±10,631 Casing @ -::: 10,634' FISH DETAIL ON NEXT PAGE _-_--- -_ _ - MAX HOLE ANGLE = 3° @ 7,004' Updated by DMA 05/24/13 TD = 10,828' PBTD = 10,631' • • Swanson River Field • SCHEMATIC ompl ted 2 0% 0/20110 045 Hileoro Alaska. LLC API: 50- 133 - 10118 -00 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G -1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10 -12 -1985 10/16/1985 1-11 10,516' 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re- perforated October 2011 10/16/1985 H1 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-01 / 10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 9' Re -pert 10-16-1985 / 06-10-1995 / 08 -18 -2001 / 10 -02 -2004 2/21/1961 H1 10,529' 10,530' 10,526' 10,527' 1' Re -perf 10 -16 -1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re- perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re -perf 10 -16 -1985 / 08 -18 -2001 / 10-02 -2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re -pert 10-16-1985 / 06-10-1995 / 08-18-2001 / 10 -02 -2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re -perf 10 -16 -1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10 -16 -1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10 -16 -1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re -perf 10 -16 -1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10 -16 -1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10 -16 -1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10 -16 -1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10 -16 -1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10 -16 -1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) F 4.09' 2.375 4.25 Chemical Injection Sub I S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug (Bottom f Fish) Updated by DMA 05/24/13 w w ��\ %%i s 9 THE STATE Alaska an Gas 11 °fALASKA Conservation Commission .ice_ GOVERNOR SEAN PARNELL 333 West Seventh Avenue ALAS Anchorage, Main: 99501-3572 907.279.1433 Fax: 907.276.7542 Chad Helgeson scANNED APR 0 5 2013 S Operations Manager ° Hilcorp Alaska, LLC 1 3800 Centerpoint Drive Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 32 -08 Sundry Number: 313 -161 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cat y P. oer ter Chair DATED this day of April, 2013. Encl. 0 0 '41/ ,„„,, (.., , -,„ ,,,,,- L ,„ , c rt ° STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AGOC 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ n o il- Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Pump Change ' Other. CI • 2. Operator Name: Hilcorp Alaska, LLC 4. Current W Number Well Class: 5. Permit to Drill Numbe Exploratory ❑ Development 0 160-045 + 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. 50- 133 - 10118 -00 . Anchorage, Alaska 99503 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Soldotna Creek Unit (SCU) 32 -08 , Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA 028996 Swanson River Field / Hemlock Oil ■ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,828 • 10,824 . 10,631 10,628 N/A 10,631' (fi11) Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13 -3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6 -5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 2 -7/8" 6.4# / L -80 10,359 Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A N/A N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development El Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 04/04/13 Commencing Operations: Oil El ' Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: z(• Z•13 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: G' S-0-11‘.14,r t`L- GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is Prue and correct to the best of my knowledge. Contact Chad Helgeson Phone: 907 - 777 -8405 Email cheloesonC hilcorp.com Printed Name Chad dH Helgeson � Title Operations Manager Signature L� �l":" 4+� Phone 907 - 777 -8405 Date Yz 3 COMMISSION USE ONLY J /i Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 _col Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4 / 3 0 CO / Sc:. idv t S I8DMS APR 0 i : s Spacing Exception Required? Yes ❑ No u Subsequent Form Required: /6 Y O I 1 r APPROVED BY Approved by: V i � , Oo COMMISSIONER THE COMMISSION Date: 4.— C— i �1 d i v' J Submit Form and "j j 0 e is ) Approved application is valid for 12 months from the da of apprpr ovall . Atta nts in Duplicat% \ � , ` r 3 e '17 . k. • • Well Prognosis Well: SCU 32 -08 Hilcorp Alaska, LL Date: 4/2/2013 Well Name: SCU 32 -08 API Number: 50- 133 - 10118 -00 Current Status: Oil Producer Leg: N/A Estimated Start Date: April 4th, 2013 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 160 -045 First CaII Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) AFE Number: 1350164 Current Bottom Hole Pressure: — 2,000 psi © 10,500' TVD (Static survey and fluid level Calculations.) Maximum Expected BHP: — 2,000 psi @ 10,500' TVD Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 95% (0.435psi /ft) with added Safety Factor of 1,000' TVD of oil cap) Brief Well Summary Soldotna Creek Unit 32 -08 was repaired and put into production in December 2012. The pump was replaced in January 2013. Debris from the previous workover seized the pump. The pump was replaced with a new pump in • January. Notes Regarding Wellbore Condition • The tubing was filled to be pressure tested and a pressure test was not achieved. It is likely debris on the traveling valves of the rod pump not allowing the pump to seat and obtain new inflow. However it is possible to have hole in the tubing as well. Brief Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing and tubing. 2. Nipple up rod stripper head. 3. LD polish rod and pull EL rods. (rack back the rods in basket, inspect rods looking for wear) 4. Pull pump, inspect pump to determine failure. 5. Drop standing valve to test tubing, Test tubing to 2,000 psi. a. If tubing does not test, RU slickline and RIH with packoff plug and set just above the seating nipple. Test tubing to 2,000 psi. b. If tubing doesn't test, continue to move test up the tubing to find the bad tubing section in 500ft increments. If hole in tubing is confirmed, see 2 procedure listed below for pulling • tubing. 6. RU slickline, pull standing valve. 7. RIH w/ bailer to tag bottom and clean out well sump. 8. Once all debris has been cleaned out, RIH w/ magnet and clean tubing. 9. PU 13ft dip tube, NEW rod pump, RIH with tapered rod string (3/4 ", 7/8" and 1 "), Inspect rods and guides and replace as necessary (3 rods per guide), land the pump, space out the rods, install - polish rod. 10. ND rod stripper head, install surface equipment onto well and test. • • Well Prognosis Well: SCU 32 -08 Hilcorp Alaska, LL Date: 4/2/2013 11. RD Williams #405. 12. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 13. Return to production. Alternate Procedure — Use if tubing has a hole in it Q r �7 , A. MIRU pits and pump and other necessary rig pieces t" A. workover. B. Set BPV, ND tree, NU BOPE and test to 250psi low /3,000psi high, annular to 250psi low /1,500psi high. a. Notify AOGCC 24hrs in advance to witness C. Pull 1 -latch tubing hanger. D. Release tubing anchor and pull 2 -7/8" 8rd EUE tubing. Inspect pipe looking for hole. E. Once hole is found, remove bad joints above and below hole. F. Run tubing back in the well with new joints. G. Land tubing hanger with tubing in tension (20,000 #). H. ND BOPE, NU tree and test (Ensure the tree is plumb and without any lean). I. NU Rod stripper. J. PU 13ft dip tube, new rod pump, RIH with tapered rod string (3/4 ", 7/8" and 1 "), Inspect rods and guides and replace as necessary, land the pump, test the tubing and pump to 500 psi, space out the rods, install polish rod. K. ND rod BOPE, install surface equipment onto well and test. L. RD Williams #405. M. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. N. Return to production. Attachments: 1. Schematic 2. BOP Schematic (If necessary) H . Swanson River Field SCHEMATIC Well: ted ?010/220/20011 0 045 Hikora Alaska. LLC API: 50- 133 - 10118 -00 RKB: 143'/ GL: 128' AMSL New KB —THF: 15.00' CASING DETAIL 41 A 1 L Size WT Grade Conn ID Top Btm III 22" Surface 28' , i 54.5 J -55 8RD 12.615" Surface 1,308' DV @ , B III 13 -3/8" DV Collar 12.615" 1,308' 1,310' 1,308' - 54.5 J -55 8RD 12.615" 1,310' 3.014' 1 28 P -110 8RD 5.791" Surface 115' 24 N -80 BTC 5.921" 115' 6,477' 2 6 -5/8" 24 P -110 8RD 5.921" 6,477' 7,996' I DV Collar 5.921" 7,996' 7,998' 24 P -110 8RD 5.921" 7,998' 10,037' Il l 28 P -110 8RD 5.791" 10,037' 10,828' TUBING DETAIL 2-7/8" 6.4 L -80 8RD 2.441" Surface 10,359' Ill DV @ JEWELRY DETAIL 7,996' # Depth Length ID OD Description 1 1 15' 1.7' 2.441" 7" Tubing Hanger J -Latch C I 2 3,991' 2.32' 2.43" 4" Chemical Injection Mandrel 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor 4 10,358' 0.65' 2.441" 3.5" Seating Nipple II 10,364' 5.65' 4.375" 4.5" Perforated Joint Li 3 6 61' 4.375" 4.5" Tubing 6.5# IBT D s 7 10,425' 0.44' 4.375" 4.5" Bull Plug E F ROD DETAIL G 4 # Depth Length OD Description 5 A 30' 40' 1 -1/2" Polished Rod, 30' in well B 38' 8' 1" 1" x 8' EL Pony Rod H " 6 39' 2,625' 1" 1" x 25' EL Sucker rods w/ 3 XL guides per rod 2,749' 3,550' .875" 7/8" x 25' EL Sucker rods w/ 3 XL guides per rod MI 7 6,300' 3,725' .75" '/" x 25' EL Sucker rods w/ 3 XL guides per rod { Top of fish @ 10,423' C 10,024' 300' 1.5" 1 -1/2" x 25' K Bars (weight bars) 7 1111/ D 10,325' 30' 1" 1" x 30" Stabilizer Bar w/'/" Pins (between K Bars) E 10,354' 1' Browning On /Off Tool, J -Latch R hand release (Box X Pin) F 10,355' 2.5' 1" 1" x 30" Stabilizer Bar w/3/4" Pins Pump w/ Ring 1 1-3/4" x 42' Insert Pump, RHBC Pum w PA Rin 4 G 10,358' 42' 1.75' 80 PA Ring, Sand Seal, 2-1/2" x 1-3/4" x 36" x 36-1/2" x _ -- 37" RHBC --- - H 10,368' 13' 1.5" Dip Tube Ba d PERFORATION DETAIL ON NEXT PAGE PBTD 110,631 Casing @ : •: •: • 10,634' FISH DETAIL ON NEXT PAGE _ _ _ _ _____ ___ _ _ __- MAX HOLE ANGLE = 3° @ 7,004' Updated by DMA 03/28/13 TD = 10,828' PBTD = 10,631' ., .. II • • Swanson River Field SCHEMATIC Well: SCU 32-08 / PTD 160 -045 Completed: 10/20/2011 Hilcoro Alaska, LLC API: 50- 133 - 10118 -00 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G -1 10,376' • 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10 -12 -1985 10/16/1985 H1 10,516' • 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 H1 10,518' • 10,533' 10,515' 10,530' 15 Re- perforated October 2011 10/16/1985 H1 10,518' • 10,520' 10,515' 10,517' 2' Re-perf 08-18-01 / 10-02-2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 9• Re -perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 / 10-02 -2004 2/21/1961 H1 10,529' • 10,530' 10,526' 10,527' 1' Re -perf 10 -16 -1985 10/16/1985 H1 10,530' . 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' , 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' • 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' • 10,566' 10,542' 10,563' 21' Re- perforated October 2011 6/10/1995 H2 10,546' • 10,550' 10,543' 10,547' 4' Re -perf 10 -16 -1985 / 08 -18 -2001 / 10 -02 -2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10 Re -pert 10 -16 -1985 / 06-10-1995 / 08-18-2001 ' / 10 -02 -2004 2/21/1961 H2 10,560' . 10,569' 10,557' 10,566' 9' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 2/21/1961 H2 10,569' , 10,572' 10,566' 10,569' 3' Re -perf 10 -16 -1985 2/21/1961 H2 10,572' • 10,575' 10,569' 10,572' 3' Sqzd 10 -16 -1985 2/21/1961 H3 10,580' , 10,584' 10,577' 10,581' 4' Sqzd 10 -16 -1985 10/16/1985 H3 10,585' • 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' • 10,600' 10,589' 10,597' 8' Re -perf 10 -16 -1985 2/21/1961 113 10,600' • 10,603' 10,597' 10,600' 3' Sqzd 10 -16 -1985 2/21/1961 H3 10,608' • 10,616' 10,605' 10,613' 8' Sqzd 10 -16 -1985 2/21/1961 H3 10,622' . 10,631' 10,619' 10,628' 9' Sqzd 10 -16 -1985 2/21/1961 H4/5 10,622' • 10,678' 10,619' 10,674' 56' Sqzd 10 -16 -1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10 -16 -1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) F 4.09' 2.375 4.25 Chemical Injection Sub I S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug (Bottom f Fish) I ! Updated by DMA 03/28/13 • • Soldotna Creek Unit SCU 32 -08 04/02/2013 11.1... ‘1.,.►... 1.1 (. Williams BOP 2013 • dill ir iii lit 1i1 iiii ii( 1 111 111 3.46' Shaffer 11" 5M _ 111 ill Ill 111 III 7 ShafferLWS -- 0- 0 - 2.75' _-I_ 11 5M __ 2 1/16 10M Choke and Kill Valves _ � 1111 1181.1111 III �: _ . 2.00' lamimiiru1.1i1 '`w- ll!I 111 111 III III _ .. 2.00 9" 5M tiL 11 lI P' Iiii; e, il wilt .19111 I"; 1rn I 1T1 ; _ I1 111 i1I 1 ilU ® ( °Jo A 0 _,...--- -- • • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, April 02, 2013 12:36 PM To: 'Chad Helgeson'; Ferguson, Victoria L (DOA); Regg, James B (DOA) Cc: Donna Ambruz Subject: RE: Swanson Rod Pump repair (SCU 32 -08 PTD 160 -045) Chad, You have verbal approval to proceed with the RWO on SCU 32 -08 ( PTD 160 -045) as proposed in the attached sundry application. Guy Schwartz Senior Petroleum Engineer AOGCC 907 -444 -3433 cell 907 - 7934226 office From: Chad Helgeson [m<anto :cheigeson= o hiicor Sent: Tuesday, April 02, 2013 11:35 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA); Regg, James B (DOA) Cc: Donna Ambruz Subject: Swanson Rod Pump repair Guy, 1 am attaching a Sundry that we are submitting hardcopy this afternoon for your review. Our favorite Rod pump well in Swanson River, SCU 32 -08 (PTD # 160 -045) stopped pumping again this past weekend. After performing some diagnostic testing yesterday with the unit, we feel that the pump has some debris in the pump and it needs to be pulled and repaired. This is a very similar job to what we did in January to change out the pump. The Williams rig #405 will be available to move on this well and start the work on Thursday of this week. I was wondering if we could get an expedited review or a verbal approval to proceed with the pulling the pump & rods and testing the tubing. Please let me know if you have any questions or need more information. Thanks Chad Helgeson Operations Manager North Kenai Asset Team Hilcorp Alaska, LLC Office: 907- 777 -8405 Mobile: 907 -229 -4824 1 7 ! • STATE OF ALASKA ' r r r„ fi ALASKA OIL AND GAS CONSERVATION COMMISSION t" i j' a REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well Li Plug Perforations U Perforate ❑ Other U Repair Rods Performed: Alter Casing ❑ Pull Tubing al Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development El Exploratory ❑ 160 -045 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ID Service ❑ 6. API Number: 0 Q) Anchorage, Alaska 99504 1 50- 133 - 10118 -00 r 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA 028996 — Soldotna Creek unit (SCU) 32 -08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): - N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 10,828 feet Plugs measured N/A feet true vertical 10,824 feet Junk measured 10,631 (fill) feet Effective Depth measured 10,631 feet Packer measured N/A feet true vertical 10,628 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13 -3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6 -5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner u C Perforation depth Measured depth See Attached Schematic SCANNED APR 0 3 2013 True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.4# / L -80 10,300' MD 10,297' TVD Packers and SSSV (type, measured and true vertical depth) N /A; N/A N /A; N/A N /A; N/A N /A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 92 40 73 200 310 Subsequent to operation: 79 35 118 90 240 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development al Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - la Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -389 / 312 -452 Contact Chad Helgeson Email cheIaeson(hilcorn.com Printed Name Chad Helgeson Title Operations Manager er Signature Phone 907 - 777-8405 Date *3 F I 8 DMS APR 02 20132 Form 10-404 Revised 10/2012 � K� Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 32 -08 50- 133 - 10118 -00 160 -045 10/13/12 12/9/12 Daily Operations: 10/13/2012 - Saturday Moved rig and surface equipment to location. Set rig containment and RU WOR, and equipment. SITP- 65 psi, SICP- 670 psi. Bled pressure off tbg and casing. Pumped 40 bbls of produced SW down casing to ensure dead. Removed stuffin box and rubbers. LD 40' polish rod, 1 -8' pony rod, and 1 -25 single 1" rod. Hung 303 rods back in rod basket, found rod had backed out of box @ 7,623 ft. ND wellhead and NU Bop. Function tested Bop's and annular valves. Finished rigging up rig floor and equipment. 10/14/2012 - Sunday MIRU Pollard Test Unit. RU test joint and tested BOP's and Manifold. Test good 250 low and 2500 High. PU 2 -7/8" production string. J -ed off tbg hanger and attempted to release tbg anchor. Sat down 40K lbs on anchor and seemed to unlatch. Fell down hole 20 °. PU and still was hung. Attempted to shear pens by pulling 120K Ibs on tbg. No progress. Hung tbg off on slips and MU 2" overshot loaded with 1 -5/8" grapple on production rods. TBIH w/ overshot and rods. Tagged up on fish. Sat down and latched rod box looking up and pulled up. Unseated pump with 8K Ibs over rod weight. SOON w/ rods, LD overshot and bad rod. 10/15/2012 - Monday Finished hanging remaining rods in rod basket. Attempted to pull tbg anchor again. Pulled 120K lbs, (54K lbs over string weight). No change. MIRU Pollard E -Line Unit. RIH w/ tbg punch and CCL. Located and logged tbg anchor. Perforated tbg at 10,340'. POOH. RBIH w/ radial torch cutter. Got on depth and cut tbg above tbg anchor. RDMO Pollard. Made rig ready to pull tbg. PU pn tbg and POOH w/ tbg hanger. LD tbg hanger and a single jt of 2 -7/8" IBT, 2 -8' pup jts. Removed first 4 control line clamps. MIRU Pollard control line spool. Attached control line to spool and continued SOOH w/ 2 -7/8" IBT tbg while removing clamps. Finished SOOH all 2 -7/8" IBT tbg. MU 5 -5/8" overshot loaded with 2 -7/8" grapple on 1 bumper jar, 6 Hilcorp drill collars, 1 accelerator jar and 1 stand of 2 -7/8" production IBT. 10/16/2012 - Tuesday Continued TIH w/ 5 -5/8" overshot on 2 -7/8" IBT production tbg. Tagged top of fish @ 10,377'. Sat down and engaged 2 -7/8" grapple. Jarred on fish, fish broke free, pulled up hole 40' and locked up again. Continued trying to POOH. Would not move any further. Beat back down hole 20', stuck again. Attempted to shuck grapple, could not get off fish, fish spinning in hole. MIRU Pollard E -Line Unit. RIH w/ 1- 11/16" radial torch cutter /CCL. Sat down @ 10,377' Could not get inside top of fish. POOH. RBIH w/ 1.5" LIB. Tagged top of fish same. Stroked obstruction with LIB. POOH. LIB showed sign of control line on top of tbg cut. RBIH w/ 1 -1/2" to 1 -3/4" swedge. Attempted to work at top of obstruction. Tried to stick. POOH. RDMO Pollard E -Line. 10/17/2012- Wednesday RBIH w/ 1 -1/2" to 1 -3/4" swedge. Attempted to work at top of obstruction, tried to stick. POOH. RDMO Pollard E -Line. MU power swivel. Started turning and jarring on overshot /grapple. Shucked grapple after 4 hrs of jarring. RD power swivel. SOOH w/ 2 -7/8" IBT tbg. Stood back drill collars. LD overshot /grapple. PU 5 -1/2" wash pipe with 5 -5/8" burn shoe. MU on drill collars and TBIH w/ 2 -7/8" IBT and burn shoe. PU power swivel. 10/18/2012 - Thursday Sat down on top of tbg anchor @ 10,402' Started burning on tbg anchor. Anchor appeared to be spinning and milling slowly. Tried burning over with different weight setting while pumping fluid and dry burning. Didn't make much progress with burn shoe. SOOH w/ 2 -7/8" IBT tbg to LD 30' jt of wash pipe and burn shoe. SOOH w/ 100 stands of production tbg. 1 10/19/2012 - Friday Finish SOOH w/ 2 -7/8" IBT tbg. LD wash pipe and burn shoe. Recovered 8 -10' of stainless chemical control line. MIRU Pollard slickline unit. RIH w/ 4.5" LIB on 5.5 centralizer. Stroked top of fish @ 10,387' wlm. POOH. LIB showed picture of clean circle of tbg looking up. RDMO Pollard slickline unit. MU, TIH w/ 5 -5/8" overshot loaded with 2 -7/8" extended grapple, 1- bumper jar, 6 drill collars, 1- accelerator jar and 161 stands of 2 -7/8" IBT. Tagged top of fish @ 10,377'. Engaged grapple and started jarring on anchor. Jarred approx 25 times and something pulled free. POOH w/ tbg and recovered 8' 10" piece of tbg. Tbg parted where we perforated previously before cutting. MU new 4 -1/8" overshot loaded w/ 2 -7/8" grapple. TBIH w/ overshot, 1 jt of 2 -7/8" tbg, bumper jar, 6 drill collars, accelerator jar and 100 stands of 2 -7/8" tbg. 10/20/2012 - Saturday Continued TIH w/ 2 -7/8" IBT tbg and 4 -1/8" overshot /grapple. Engaged 2 -7/8" grapple on top of fish @ 10,385'. MIRU Pollard e-Line. Made up 8' string shot on 5/8" rod. RIH, logged from plug up across overshot /BHA. Set string shot across slips and cone on tbg anchor and attempted to fire string shot. Saw no change on weight indicator of line weight in a -line unit. POOH. String shot never fired. Attempted same process 4 more times with same outcome. Change to new firing detenators after 2nd shot, still no change. Brought out new primer cord for string shot and detinator heads. RIH w/ string shot and fired across slips /cone @ 10,402'- 10,407'. No change on weight indicator. Attempted string shot agains, still no change. Jarred on anchor for 1.5 hrs, no progress. 10/21/2012 - Sunday MU 2 ft perforating gun and RIH. Perforated across slips @ 10,404'- 10,406'. POOH. Tried jarring tbg anchor free, still no movement. MU 6' perf gun and RBIH. Perforated tbg anchor from 10,398'- 10,404'. POOH. RD Pollard a -line. Jarred on tbg anchor for 1.5 hrs, something broke free down -hole. SOOH w/ 2 -7/8" WS. LD jars and overshot. Grapple had 10" piece of tbg. MIRU Pollard test truck. Tested Bop's and manifolds. Tested low 250 and high 2,500 psi for 10 mins each test. Tested good. 10/22/2012 - Monday TIH w/ overshot /grapple latch tbg. RIH w/ radial torch cutter, cut tbg. TIH w/ 4 -1/8" overshot loaded with 2 -7/8" grapple. TIH. Latched onto fish @ 10,386'. MIRU Pollard a -line. RIH w/ 1- 11/16" radial torch cutter. Cut tbg below grapple @ 10,396'. POOH. RDMO Pollard a -line. SOOH w/ 2 -7/8" WS. LD jars and overshot. Removed 10' of tbg from grapple. MIRU Pollard slickline. 10/23/2012 - Tuesday PU 5 -5/8" Pirahna mill. TBIH, tagged top of cement /fish @ 10,399'. Started circulating produced water, took 163 bbls to get returns. Started milling, milled 4' and started spinning. Beat down approx. 2' and started milling again. 10/24/2012- Wednesday Continued milling on tbg anchor. Milled down 3' on anchor and it started spinning. Beat down 2'. Continued milling made another foot, and started spinning again. SOOH w/ 2 -7/8" WS. Recovered 5' piece of anchor stuck in bottom of mill. Mill worn out completely. MU new 5 -5/8" Piranha mill. TBIH to tag top of fish @ 10,415'. MU power swivel and started milling. Milled for 3 hrs making almost a 2' of hole. Again fish started spinning. SOOH. Stood out with 76 stands of 2 -7/8" WS. 10/25/2012 - Thursday 2 Continued milling on fish. Milled down to 10,407'. Stopped making hole, circulated clean. SOOH w/ 2 -7/8" WS and mill. LD mill, mill was worn on outside edges only. MIRU Pollard slickline. RIH w/ 5" LIB. Stroked top of fish @ 10,404' wlm. POOH. LIB had 4 -5/8' OD marks. RBIH w/ 2 -1/4" gauge ring. Went inside of fish 2 -3', sat down at 10,407'. POOH. RDMO Pollard. MU 2 -7/8" tubing spear. PU accelerator jar, oil jar, 6 drill collars and bumper jars. TIH w/ 16 stands. On 17th stand tbg parted at collar and fell to bottom. MU 5- 9/16" overshot loaded with grapple to catch 2 -7/8" collar. TIH, tagged top of new fish @ 9,190'. Engaged grapple and PU. SOOH w/ 3 stands and fish fell off again. Attempted to engage grapple 2 more times. Would not catch collar. SOOH w/ overshot and WS. Changed grapple in overshot to catch 2 -7/8" tbg. TBIH w/ overshot /grapple. TIH w/ 68 stands. 10/26/2012 - Friday Continued TIH w/ overshot loaded with 2 -7/8 "grapple. Tagged top of fish @ 9,190'. Attempted to engage grapple for one hr, could not get on top of fish. SOOH w/ 2 -7/8" WS. MU new hollow mill guide overshot loaded with 2-7/8" grapple. TBIH, tagged top of fish @ 9,190'. MU power swivel, turned mill guide for 35 mins and engaged grapple down over top of fish. SOOH w/ 2 -7/8" with top overshot and lower grapple /BHA. LD overshot and top fish. Continued SOH. Bull nose on spear was bent but had markings on stop ring. Also the grapple was shucked off spear. MIRU Pollard slickline. RIH w/ 4.5" magnet. Tagged top of fish @ 10,402' wlm. POOH. Recovered hand full of fine metal shavings. MU 4.5" LIB. RBIH, tagged top of fish @ 10,402'. POOH. LIB had markings of 4 -5/8" OD and 3 -1/4" ID. RDMO Pollard Slickline. MU new 1230 Spear loaded with 2 -7/8" grapple. TIH, tagged top of fish @ 10,418' . Attempted to work spear inside of fish, no progress. POOH. Spear showed to have entered fish. Had markings to start of grapple but no deeper. Carbide on bull nose worn down and bent again. 10/27/2012 - Saturday Attempted to work spear inside of fish, no progress. POOH. Spear showed to have entered fish, had markings to start of grapple but no deeper (5 "). Carbide on bull nose worn down and bent again. PU 2.441" Pilot mill spear. TIH, tagged top of fish @ 10,418'. PU power swivel and began milling. Milled down to 10,423'. SOOH w/ 2 -7/8" WS and Pilot mill spear. LD spear, all carbide on spear was worn off, also showed metal marks up the shaft of spear 4'. 10/28/2012 - Sunday MU new 1230 spear loaded with 2.441" grapple. TBIH w/ 162 stands of 2- 7/8" tbg. Tagged top of fish @ 10,418'. Worked for 2 hrs trying to engage grapple. Went down to 10,421'. POOH. Recovered spear with no grapple, spear had metal marks up 4' on shaft. MIRU Pollard Slickline. MU and RIH w/ 4" magnet on 5" fluted centralizer. Tagged top of fish @ 10,466' wlm. POOH. Recovered very little metal shavings. Truck broke down inprocess. RD truck, MIRU new SLU. MU 4.5" LIB on same centralizer. RIH, tagged top of fish @ 10,464' wlm. Stroked jars and LIB. POOH. LIB had same markings as previous LIB. 4- 5/8" OD. MU 1.85" Gauge ring. RIH, tagged top of fish @ 10,464' wlm. Worked up and down several times. POOH. GR face had metal marks. MU 2.47" LIB. RIH, tagged @ 10,471'. POOH. LIB had marks from grapple. RDMO Pollard SLU. 10/29/2012 - Monday MIRU Pollard Test Unit. Installed test plug in hanger. Locked 4 pins in and started testing Bop's and surface equipment. Test /charted Bop's and equipment to 250 low and 2500 psi high. RDMO Pollard test truck. MU 5 -5/8" Overshot loaded with 4 -5/8" grapple on extended wash pipe, 5 -5/8" burn shoe. TIH, tagged top of fish @ 10,418'. MU power swivel. Milled down on fish to 10,421'. Stopped making hole and possibly spinning a little. RD power swivel and SOOH. Stood out with 97 stands of 2 -7/8" WS. 10/30/2012 - Tuesday Contined SOOH w/ 5 -5/8" burn shoe. Burn shoe worn completely out. MU new burn shoe and overshot loaded with 4 -5/8" grapple. TBIH, tagged top of fish @ 10,415'. MU power swivel and began burning over tbg anchor. Made 2' of hole down to 10,417'. Worked wash pipe /burn shoe over fish. PU and pulled 20K over string weight. Fish started dragging up hole for 20' and then fell off. Attempted to cram fish up in wash pipe several more times. Could not get fish to stick inside wash pipe again. SOOH w/ 2 -7/8" WS, 70 stands of 2 -7/8" IBT WS. 3 10/31/2012 - Wednesday Continued OOH w/ 2 -7/8" WS. LD 5 -5/8" overshot with wash pipe burn shoe extension. Burn shoe worn out completely, overshot had metal marks through inside. MIRU Slickline Unit. RIH w/ 5.5" magnet. Sat down on top of fish @ 10,471" WLM. POOH, recovered 2 hand fulls of metal, 1 slip from anchor. RBIH w/ magnet 3 more times, recovering same samples each time. Recovered 3 sets of slips total and made 1 foot of hole before coming up empty on magnet. RBIH w/ 5" LIB. Stroked top of fish @ 10,472'. POOH. LIB had markings of peice of metal on one side. RBIH w/ 2.5" LIB, tagged @ 10,477'. POOH. Recovered 2 small pieces of metal. RBIH w/ 2.25" GR. Tagged @ 10,477'. Worked up and down several times. POOH. GR had metal marks on face. RBIH w/ 4" magnet. Tagged @ 10,477'. POOH. Recovered a few more pieces of metal. RBIH w/ 2.75" magnet. Tagged @ 10,470'. POOH. Recovered small amount of metal shavings. RBIH w/ 2.7" LIB. Tagged @ 10,474'. POOH. One small piece of metal. RBIH w/ 5" LIB. Tagged @ 10,474'. POOH. Had same marks of metal on outside of LIB. RBIH w/ 4" magnet. Tagged @ 1,047'. POOH. Recovered 1 piece of metal. MU 2.5 JDC with 5 -5/8" overshot loaded with 3 -1/8" grapple. RIH, worked up and down on top of fish @ 10,475' wlm. Could not latch fish. POOH. RBIH w/ 4" magnet. Tagged @ 10,474'. POOH. Recovered a few more pieces of metal. Repeated same with 4" magnet. RBIH w/ 4.5" LIB. Tagged @ 10,474'. POOH. Still showed metal marks on face of LIB. MU 2.5 JDC with 5 -5/8" overshot loaded with 2 -7/8" grapple. RIH, worked up and down on top of fish @ 10,474' wlm, could not latch fish. POOH. RDMO Pollard slickline unit. 11/01/2012 - Thursday PU 5.625" mill and DC. TIH and tag at 10,418'. PU power swizel and drilled to 10,422'. Lost torque on mill, fish just spinning. PU and circulated BU. RD PS, SOOH and LD mill. MIRU SL, RIH w/ 4.5" LIB and tag at 10,480' WLM. POOH. Metal marks and small pieces. RIH w/ 4" magnet and tag to 10,480' wlm. POOH w/ metal pieces. RIH w/ 4" magnet and tag to 10,480' wlm. POOH w/ no junk on magnet. RIH w/ 5" LIB and tag @ 10,480' wim. POOH showing impression of 2.625" TBG. RIH w/ 4.5" Bell Guide and 10,480'. Worked over fish and POOH. Marks inside guide showing fish. RIH w/ 1.75" stem and swedge and tag @ 10,480' wlm. Could not work beside fish. POOH. RIH w /5" LIB and tag @ 10,480 'wim. POOH w /impression of 2.625" pipe. RDMO SL. TIH w/ overshot to latch fish. 11/02/2012 - Friday RIH w /overshot and PU 2,000 psi over. POOH w /no fish. MIRU SL. RIH w/ 5" LIB and tag 10,474' wim. POOH. Impression of junk. RIH w/ 5" magnet and tag at 10,474' wlm. POOH w/ metal shavings. RIH w/ 5" magnet and tag at 10,474' wlm. POOH w/ metal shavings. RIH w/ 5" magnet to 5,000' wlm. POOH w/ metal shavings. RIH w/ 4.5" LIB and tag at 10,474' wlm. POOH w/ impression 2 -7/8" pipe. RIH w/ 3 -1/8" grapple baited. RB running tool to 10,747' wim. PU wieghing 1,100 psi. Latched tool at 10,479' wlm. PU to 2,500 psi and sheared tool. POOH. RDMO SL. TIH w/ overshot and latched fish. PU 6,000 psi over and pulled off. Made several attempts to latch fish but could not latch. SOOH w/ string. 11/03/2012 - Saturday TOOH w/ 2 -7/8" string and overshot. No fish. MIRU SL. RIH w/ 5" magnet and tag @ 10,473' wim. POOH w/ piece of csg. RIH w/ 5" magnet and tag @ 10,473' wlm. POOH w/ clean magnet. RIH w/ 5" LIB and tag @ 10,473' wlm. POOH. LIB show 2- 7/8" pipe. RDMO SL. PU washpipe ext, 5 -5/8" burnshoe with 2 -7/8" ID to cut over collar and overshot on top. TIH and tag 10,422'. Cut over collar 15' and latch tbg. PU and jarred fish for 3 hrs. Fish moved 8'. Tbg parted 3' below elevators. String fell in hole. 11/04/2012 - Sunday PU 1 jt of 2 -7/8" 8rd w/ overshot and latched pipe 10' below BOP. PU and jarred on fish for one hr and broke free weighing 56k. TOOH, LD 2 -7/8" tbg. Fish broke off 2' below grapple. 2 -7/8" string was corded screwed and had bad threads. Sent strig into dock for inspection. PU overshot 6 DC and TOOH w/ 180 jts of new 2 -7/8" 8rd L -80. 11/05/2012 - Monday 4 • TIH w/ 180 jts of 2 -7/8 ". Latched fish at 10,417'. Jarred on fish for 6 hrs. Moved up hole 60'. Fish stopped moving, continued jarring and tbg parted. SOOH w/ 153 and 1 single. Left BHA and 13 jts with a collar looking up in the hole. Threads pulled out of collar. 11/07/2012 - Wednesday Continue jarring on fish until gam with no progress. MIRU SL. RIH w/ 1.85" LIB and tag @ 10,553' slm. POOH. RDMO SL. Worked bottom grapple free from fish and SOOH w /pipe. LD 2 OS and PU 3 jts of washpipe and wavey bottom burn shoe. TIH and tag. Started filling hole at report time. 11/08/2012 - Thursday Finished filling hole and broke cir. Tag top of fish @ 10,354'. Tag junk @ 10,370'. Mill down to 10,377'. Lost torque with mill. LD power swivel and SOOH. LD wavey bottom burn shoe, bottom of mill was wore smooth. PU new PKR type burn shoe and TIH. 11/09/2012 - Friday PU new PKR type shoe 5.5" OD x 4.5" ID and TIH. Tag TOF @ 10,350'. Worked over fish and tag at 10,374'. PU power swivel. Broke circ and started milling for 5hrs. Milled down to 10,379'. Stopped torqueing and making hole. LD power swivel. TOOH. Found control line wadded up inside washpipe. Shoe was 50% worn. PU new PKR type shoe 5.5" OD x 4.5" ID and TIH. 11/10/2012 - Saturday TIH w /PKR type shoe and tag TOF at 10,350'. Worked over fish and tag at 10,379'. PU power swivel, broke circ and started milling for 5 hrs. Made several PU and had trouble getting back down. POOH. Washpipe and shoe had no debris inside. Shoe was 10% worn. LD WP and shoe. PU jars and OS. TIH and tag fish at 10,350'. Latched on fish. PU and jarred on fish for 6 hrs. Fish never moved. Released off fish and TOOH. 11/11/2012 - Sunday SOOH w/ 159 stands and LD 4 DC, jars, 2 jts of washpipe and OS. PU 2 -7/8" collar with a no go bar welded across. TIH w/ 159 stands of 2 -7/8 ". Landed tbg hanger BOT @ 10,116'. Set BPV, ND BOP stack and NU Prod Tree. Pulled BPV. TIH w/ 136 stands of rods. PU polish rod and stuffing box. FOR @ 10,050'. RDMO Williams WOR. 11/12/2012 - Monday RDMO Williams WOR and clean location. 11/29/2012 - Thursday MIRU Williams 405 WOR. 11/30/2012 - Friday Continued rigging up WOR, installed winterization kit over equipment, circulated 180 bbls of produced saltwater down casing out tubing, made ready to pull rods from well. 12/01/2012 - Saturday Pulled Rods and hung back in rod basket. Installed 2 way check in hanger, attempted to test Bop's. Could not get them to test. Swapped out manifold with new manifold from night oil tools, also changed out hydrolic and manual HCR valves on kill side of flow cross. Tried to test again and door seals of pipe rams leaked. Changed door seals and continued testing. 12/02/2012 - Sunday Tested BOP and equipment. Tested rams from 250 low to 3000 high. Annular from 250 low to 2,500 high. All valves from 250 low to 3,000 high. Test was witness waived by Jim Regg, AOGCC at 4:45pm on 11/30/12. Removed 2 -way check. Pulled lock pins and unseated tbg hanger. Started POOH with 2 -7/8" 8 RD productions string. LD 324 jts of 2 -7/8" 8 Rd. Moved off location. MI and racked 357 joints of 2 -7/8" P -110 WS. 12/03/2012 - Monday TIH w/ 5- 9/16" overshot on 2 -7/8" P -110 WS. 12/04/2012 - Tuesday 5 Tallied 2 -7/8" P110 WS. MU 5- 9/16" overshot loaded with 2 -7/8" basket grapple on 4 -3/4" Bumper jar, 6 drill collars, oil jar, and accel jar. TIH w/ 324 joints of 2 -7/8" P110 WS. Tagged top of fish @ 10,415', engaged grapple, jarred on fish 5 times, pulling 54 thousand over string weight (total weight 130 thousand). Fish broke free on 5th pull. Started SOH w/ 2 -7/8" WS. Stood out with 162 stands. 12/05/2012 - Wednesday SOOH w/ overshot /grapple with fish. Recovered 8' piece of 2 -7/8" tbg. LD fish. MU new grapple in overshot. TBIH w/ 5- 9/16" overshot and 2 -7/8" grapple. Engaged the fish @ 10,423'. Attempted to jar free with no success. MIRU Pollard e-Line. RIH w/ 1- 11/16" radial torch and CCL. Logged tbg and BHA. Cut tbg @ 10,439'. POOH. RDMO Pollard Unit. Jarred on tbg for 35 mins and something broke free. SOOH w/ 2 -7/8" P110 WS. Recovered 13' of 2 -7/8" tbg. 12/06/2012 - Thursday TBIH w/ 2 -7/8" P110 WS. POOH. LD 2 -7/8" P110 WS. Unloaded and tallied 328 joints of 2 -7/8" 8RD production tbg. Started running in hole with production tbg and BHA. A bull -plug, 2 full jts of 4 -1/2" IBT tbg, 1 -6' slotted pup (4- 1/2 "), X -over (4 -1/2" X 2- 7/8 "), pump seating nipple, 2 joints of 2 -7/8" 8Rd, tbg Anchor and 166 joints of 2 -7/8" 8RD production tbg. Shut down to slip drill line. 12/07/2012 - Friday Finished slipping drill line. Made up BHA, (2 jts of 4 -1/2" IBT, 6' slotted sub, x -over and SN, 2 jts of 2 -7/8" 8RD and Wetherford retrievable tbg anchor). TIH w/ 198 jts of 2 -7/8" production tbg. 12/08/2012 - Saturday Installed chemical injection sub @ 4,000'. Ran 3/8 chemical control line. Put 2 bands per joint and 5 bands on injection sub. Landed hanger w/ 8,000 Ibs of tension, locked lock pins in. Installed 2 -way check. ND BOPs and NU welhead, test void. Tested good. 12/09/2012 - Sunday MU 2 -1/2" pump on rods and TIH. Spaced out pump and hung off polish rod. RDMO WOR. 6 . 14 Swanson River Field SCHEMATIC ompl ted? 0% %/20110 045 Hilcora Alarka. LI.0 API: 50- 133 - 10118 -00 RKB: 1437 GL: 128' AMSL New KB —THF: 15.00' CASING DETAIL j A I 1 Size WT Grade Conn ID Top Btm 1 PI 22" Surface 28' 54.5 J -55 8RD 12.615" Surface 1,308' DV @ • B III 13-3/8" DV Collar 12.615" 1,308' 1,310' 1,308' 54.5 J-55 8RD 12.615" 1,310 3.014' 28 P -110 8RD 5.791" Surface 115' 1 24 N -80 BTC 5.921" 115' 6,477' 24 P -110 8RD 5.921" 6,477' 7,996' 1_ i 2 6 -5/8" DV Collar 5.921" 7,996' 7,998' 24 P -110 8RD 5.921" 7,998' 10,037' 28 P -110 8RD 5.791" 10,037' 10,828' TUBING DETAIL 1I 2 -7/8" 6.4 L -80 8RD 2.441" Surface 10,359' DV @ JEWELRY DETAIL 7,996' 1 # Depth Length ID OD Description . 1 15' 1.7' 2.441" 7" Tubing Hanger) -Latch C 2 3,991' 2.32' 2.43" 4" Chemical Injection Mandrel 3 10,294' 2.32' 2.441" 6.625" Tubing Anchor 4 10,358' 0.65' 2.441" 3.5" Seating Nipple - 5 10,364' 5.65' 4.375" 4.5" Perforated Joint 3 6 61' 4.375" 4.5" Tubing 6.5# IBT D _ 7 10,425' 0.44' 4.375" 4.5" Bull Plug E F ROD DETAIL G r 4 # Depth Length OD Description 5 A 30' 40' 1 -1/2" Polished Rod, 30' in well B 38' 8' 1" 1" x 8' EL Pony Rod H i 6 39' 2,625' 1" 1" x 25' EL Sucker rods w/ 3 XL guides per rod 2,749' 3,550' .875" 7/8" x 25' EL Sucker rods w/ 3 XL guides per rod JAIL 7 6,300' 3,725' .75" '/<" x 25' EL Sucker rods w/ 3 XL guides per rod Top of fish @ 10,423' C 10,024' 300' 1.5" 1 -1/2" x 25' K Bars (weight bars) i:= ' D 10,325' 30' 1" 1" x 30" Stabilizer Bar w/'/" Pins (between K Bars) E 10,354' 1' Browning On /Off Tool, J -Latch R hand release (Box X Pin) . F 10,355' 2.5' 1" 1" x 30" Stabilizer Bar w/3/4" Pins 1 -3/4" x 42' Insert Pump, RHBC Pump w/ PA Ring G 10,358' 42' 1.75' 80 PA Ring, Sand Seal, 2 -1/2" x 1 -3/4" x 36" x 36 -1/2" x 37" RHBC 1 � H 10,368' 13' 1.5" Dip Tube Ba d PERFORATION DETAIL ON NEXT PAGE PBTD ±10,631 Casing @ :.: 10,634 FISH DETAIL ON NEXT PAGE _ _ _ _ _ ___ _ ___ _ _ __i MAX HOLE ANGLE = 3° @ 7,004' Updated by DMA 03/28/13 TD = 10,828' PBTD = 10,631' 1 ,. H Swanson River Field ,.. Well: SCU SCHEMATIC Completed: 0 / 0 045 0/2011 Hilcora Alaska, LLC API: 50- 133 - 10118 -00 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G -1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10 -12 -1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re -perf 08 -18 -01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re- perforated October 2011 10/16/1985 H1 10,518' 10,520' 10,515' 10,517' 2' Re -perf 08 -18 -01 / 10 -02 -2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 9 Re-perf 10 -16 -1985 / 06-10-1995 / 08-18-2001 ' / 30 -02 -2004 2/21/1961 H1 10,529' 10,530' 10,526' 10,527' 1' Re -perf 10 -16 -1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re -perf 08 -18 -01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re- perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re -perf 10 -16 -1985 / 08 -18 -2001 / 10 -02 -2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re -perf 10-16-1985 / 06-10-1995 / 08 -18 -2001 / 30 -02 -2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08-18 -2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re -perf 10 -16 -1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10 -16 -1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10 -16 -1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re -perf 10 -16 -1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10 -16 -1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10 -16 -1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10 -16 -1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10 -16 -1985 2/20/1961 W50 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10 -16 -1985 FISH DETAIL # Depth Length ID OD Description 10,423' 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) F 4.09' 2.375 4.25 Chemical Injection Sub I S 39 3.438 4.4 Screen Assembly 0.008" H 97.182 3.958 4.5 Blank pipe 10,519 0.75 0 5.188 Bull Plug (Bottom f Fish) Updated by DMA 03/28/13 THE STATE 'ALASKA GOVERNOR SEAN PARNELL Mr. Chris Myers Field Superintendent Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No -Flow Verification Soldotna Creek Unit 32-08 PTD 1600450 Dear Mr. Myers: Alaska Oil and Gas Conservation Commission March 13, 2013 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 On December 12, 2012 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Soldotna Creek Unit 32-08. The well is operated by Hilcorp Alaska, LLC (Hilcorp), completed as an artificially -lifted producer that relies on a rod pump system to bring production to surface. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up to the well and monitored three hours for flow to surface. During the flow monitoring period, liquid production did not exceed 6.3 gallons per hour and gas production was measured at rates less than 900 standard cubic feet per hour. Soldotna Creek Unit 32-08 meets the AOGCC requirements for a no -flow status determination. Hilcorp requested a safety valve system variance for its rod pump wells located in the Swanson River Field (Swanson River Unit and Soldotna Creek Unit) by letter dated December 31, 2012. In lieu of a surface safety valve (as required by 20 AAC 25.265), Hilcorp requests AOGCC consider an alternate configuration for well control equipment supported by the approved no flow status. The AOGCC decision regarding a required surface safety valve for Soldotna Creek Unit 32-08 will be addressed in response to Hilcorp's variance request. Sincerely, James B. Regg �7 Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors %, \ \I i %� sA THE STATE Alaska Oil and Gas h� t t ALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OA, Q. Anchorage, Alaska 99501 -3572 ALAS" Main: 907.279.1433 Fax: 907.276.7542 Chad Helgeson sCONED FEB 2 6 2 °13 Operations Engineer Hilcorp Alaska, LLC / 0 3800 Centerpoint Drive, Suite 100 j (0 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 32 -08 Sundry Number: 313 -028 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this 2. y of January, 2013. Encl. Li STATE OF ALASKA JAN 18 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION n TS //2.511 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon El Plug for Redrill ❑ Perforate New Pool ❑ Repair WeN ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ PuH Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Repair Rod Pump Other. 151 • 2. Operator Name: 4. Current Well Class: 5. Permit to DI Number. Hilcorp Alaska, LLC Exploratory ❑ Development El • 160-045 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service El 6. API Number. Anchorage, Alaska 99503 50-133-10118-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order govems well spacing in this pool? CO 123A Soldotna Creek Unit (SCU) 32-08 • Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA 028996 • Swanson River Field / Hemlock Oil - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,828 . 10,824 • 10,417 10,417 N/A 10,436 (Screens) Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13 -3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6 -5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 2 -7/8" 6.4# / L -80 10,417 Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A N/A N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 _ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: 1 —n- i3 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: C' 5 4 Z GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is\true and correct to the best of my knowledge. Contact Chad Helgeson Phone: 907 - 777 -8405 Email cheIaesonta'2hilcorp.com Printed Name Chad Helgeson Title Operations Engineer Signature , Phone 907 - 777 -8405 Date ///e 3 4 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: � 5 --0 ^ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ ' Other: i BDMS JAN 2 8 201 Spacing Exception Required? Yes ❑ No 12( Subsequent Form Required: /Q — Y6 CI, APPROVED BY Approved by: 41,...____ COMMISSIONER THE COMMISSION Date: / - L j - / 3 (-23-45 J � Submit Form and ' 9 F 1 vi d of m2� Approved application is valid for 12 months from the date of approval. .' att achments in Duplicate t7 Well Prognosis Well: SCU 32 -08 Hilcorp Alaska, LLC Date: 1/11/2013 Well Name: SCU 32 -08 API Number: 50- 133 - 10118 -00 Current Status: Oil Producer Leg: N/A Estimated Start Date: January 11, 2013 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 160 -045 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) AFE Number: 1350164 Current Bottom Hole Pressure: — 2,000 psi @ 10,500' TVD (Static survey and fluid level Calculations.) Maximum Expected BHP: — 2,000 psi @ 10,500' TVD Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions ' and min water cut of 95% (0.435psi /ft) with added Safety Factor of 1,000' TVD of oil cap) Brief Well Summary Soldotna Creek Unit 32 -08 was repaired and put into production in December 2012. The well quit pumping on January . 8, 2013. Diagnostic work performed indicated that it was a rod pump issue. Notes Regarding Wellbore Condition • During the last workover in 2012, there was a lot of milling that occurred and it is likely some debris was pulled into the pump and damaged the pump. • Brief Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing and tubing. 2. Attempt to pressure test the tubing with PW, to ensure that there is not a hole in the tubing and kill the well. 3. Nipple up rod stripper head. 4. LD polish rod and pull EL rods. (rack back the rods in basket) 5. Pull pump, inspect pump to determine failure. 6. Drop standing valve to test tubing, Test tubing to 2,000 psi 7. RU slickline, pull standing valve. 8. RIH w/ bailer to tag bottom and clean out well sump. 9. Once all debris has been cleaned out, RIH w/ magnet and clean well. 10. PU 13ft dip tube, NEW rod pump, RIH with tapered rod string (3/4 ", 7/8" and 1 "), Inspect rods and guides and replace as necessary (3 rods per guide), land the pump, space out the rods, install polish rod. 11. ND rod stripper head, install surface equipment onto well and test. 12. RD Williams #405. 13. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 14. Return to production. Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, January 11, 2013 3:06 PM pia) 160 o't s To: 'Chad Helgeson' Subject: RE: Williams Rig #405 Yes you have verbal appco l... see email below at 8:43am Good luck with the wellwork. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Chad Helgeson [mailto:chelgeson @hilcorp.com] Sent: Friday, January 11, 2013 3:02 PM To: Schwartz, Guy L (DOA) Subject: RE: Williams Rig #405 I am working on the Sundry now, but do we have verbal approval to move on this well this weekend, even though I probably won't get you the Sundry until Monday. Hopefully it is not too common, but we have purchased 2 more rod pump unit for 2 more workovers we are planning this spring, so if they continue to work, we will continue to have to fix them. Hopefully they last more than a month though. Chad From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Friday, January 11, 2013 1:27 PM To: Chad Helgeson Subject: RE: Williams Rig #405 Chad, For now yes.. add it on the sundry matrix for both 403 and 404. This is not a common operation in the past for either Hilcorp or Chevron. Though now it should be with a rig in the SRU doing workovers. For now , since it involves putting the rig onsite we would like to see a 403. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Chad Helgeson [mailto:chelgeson @hilcorp.com] Sent: Friday, January 11, 2013 12:29 PM To: Schwartz, Guy L (DOA) Subject: RE: Williams Rig #405 Thanks for the response. Does that mean I need to submit a 10 -403 or just a 10 -404 when the work is done? Do we need to add 1/23/2013 Page 2 of 2 . pulling rods to our matrix for submitting a 403? Chad From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov) Sent: Friday, January 11, 2013 8:43 AM To: Chad Helgeson; Ferguson, Victoria L (DOA); Regg, James B (DOA) Cc: Luke Saugier; Wade Hudgens - (C) Subject: RE: Williams Rig #405 Chad, You have verbal approval ( Commissioner Foerster) to move onto the well and pull rods and pump. 'This will require a sundry to be submitted for the time being though this would be one of the operations on the new sundry matrix that would only require a 10-404 in the future. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Chad Helgeson [mailto:chelgeson @hilcorp.com] Sent: Friday, January 11, 2013 6:33 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA); Regg, James B (DOA) Cc: Luke Saugier; Wade Hudgens - (C) Subject: Williams Rig #405 Hilcorp had the rod pump well SCU 32 -08 (PTD# 160 -045) fail this week. The pump quit pumping and the diagnostic testing has indicated there is a problem with the pump (debris plugging the travelling valve is the likely culprit). We were in the process of getting the rig ready for a fishing job on another well, but have decided to move the Williams rig #405 to SCU 32 -08 to pull the pump and rods from the well to investigate the problem. It is my understanding of the regulations that we do not need to submit a 10 -403 for the pulling of the rods from the well. We will not be removing the tree or adjusting the tubing or anchor located in this well. We have calculated the BHP on this well to be approx. 1200 psi. During the diagnostics testing of the pump, the tubing was filled and the well was killed. A rod stripper rubber will be used on top of the tree for pulling the rods and pump. Some slickline work may be necessary on the well when the pump is pulled, but that is all that is expected. When completed a new pump will likely be installed and put back in service. Please let me know if it is okay to proceed with this plan without a sundry for this work. Thanks Chad Hetgeson Operations Manager North Kenai Asset Team Hilcorp Alaska, LLC Office: 907 - 777 -8405 Mobile: 907 - 229 -4824 1/23/2013 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 12, 2012 SUBJECT: No -Flow Test Hilcorp / Swanson River Field SCU 32-8 PTD 1600450 - Soldotna Creek Unit December 12, 2013: 1 traveled to Hilcorp's Swanson River Field to witness a No -Flow Test on well SCU 32-8. On my arrival at the wellsite I met with Hilcorp's Lead Operator Chris Walgenbach and we discussed the operational details of the test. Mr. Walgenbach indicated that the wellrep ssure had been bled down and the wellbore was open to the tree cap with no plugs or restrictions. Well SCU 32-8 was lined up from the tree top swab valve through an Nu-flo flow meter (0 to 2200 SCFH span) to a 1" hose which terminated in an open top drum. The flow from the well was monitored for 3 hours and unassisted gas and liquid flow from the well during this test did not exceed 900 SCF or 6.3 gal hourly flow rate. SCU 32-8 meets the AOGCC requirements for a No -Flow status determination. Summary: I witnessed a successful No -Flow Test on Hilcorp's Swanson River Field well SCU 32-8. Attachments: none RJF 09/19/02 Page 1 of 1 No -Flow SCU 32-8 12-12-12 JJ (2).xls • • 4, \. * OF Art, s �, THE STATE Alaska Oil and Gas h ,i` '� fA LAS� Conservation Commission *h GOVERNOR SEAN PARNELL 333 West Seventh Avenue A'ALA Q. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 SCANNED JAN 2 5 2013 Fax: 907.276.7542 Chad Helgeson Operations Engineer 166 0 ( # 5 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit (SCU) 32 -08 Sundry Number: 312 -452 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy ". Foerster Chair DATED this day of December, 2012. Encl. V C. • • NOV 3 0 2.012 A STATE OF ALASKA �_�-'++_ ALASKA OIL AND GAS CONSERVATION COMMISSION A ®JC�iv r t APPLICATION FOR SUNDRY APPROVALS �' 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well IS ' Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing © • Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other ❑ 2. Operator Name: r. Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number Exploratory ❑ Development el • 160 -045 - 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. 1 Anchorage, Alaska 99503 50- 133 - 10118 -00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order govems well spacing in this pool? CO 123A Soldotna Creek Unit (SCU) 32 -08 • Will planned perforations require a spacing exception? Yes ❑ No SI • 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA 028996 Swanson River Field / Hemlock Oil e 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): r 10,828 ' 10,824 10,350. 10,350 N/A 10,350 (Screens) Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13 -3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6 -5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2 -7/8" 6.4# / L -80 10,300' Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A N/A N/A 12. Attachments: Description Summary of Proposal IS 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch SI • Exploratory ❑ Stratigraphic ❑ Development IS • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 11/30/12 Commencing Operations: Oil SI • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: 1/47 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: 6 S h4 _ GSTOR ❑ SPLUG ❑ c w a 17. I hereby certify that the foregoing 's true and correct to the best of my knowledge. Contact Chad Helgeson Phone: 907 - 777 -8405 Email chelgesonnhilcorp.com Printed Name Chad Helgeson Title Operations Engineer Signature �/i Y Phone 907 - 777 -8405 Date 11/29/2012 `f / u COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 12 r Plug Integrity ❑ BOP Test [07 Mechanical Integrity Test ❑ Location Clearance ❑ Other 300b / .034,_ Tao P 7 14- Coo Psz. Ahn u. t r Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 v o q APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: / 2 —. — / 2..,- ` Z i P - A4"--: f 114_ 0 b nu Submit Form and v For (4 se 4,N)A LApproved application is valid f .r 1 Mont from the date of approval. �J Attachments in Duplicate \ \� ��rrr * /1 - 3 -/7 � (-2/›.12_ \1. • • Well Prognosis Well: SCU 32-08 Hilcorp Alaska, LLC Date: 11/29/2012 Well Name: SCU 32 -08 API Number: 50- 133 - 10118 -00 Current Status: Oil Producer Leg: N/A Estimated Start Date: November 30 2012 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 160 -045 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) AFE Number: 1253095 Current Bottom Hole Pressure: — 2,000 psi @ 10,500' TVD (Static survey and fluid level Calculations.) Maximum Expected BHP: — 2,000 psi @ 10,500' TVD Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 95% (0.435psi /ft) with added Safety Factor of 1,000' TVD of oil cap) Brief Well Summary Soldotna Creek Unit 32 -08 was worked on in April 2012 and in October 2012. The well work was not completed in early November as the fish and anchor were not recovered from the well. The work was stopped because forward progress was not being made and need to look at the options on the well work. With a new evaluation on the well, the following program has been completed Notes Regarding Wellbore Condition • There is a fish remaining in the hole at 10,350ft consisting of 2 -7/8" tubing stub, 2ea crossover's, chem injection sub, screens, and blank pipe with a bull plug in the bottom. At the bottom on the bull plug there are 2ea spear assemblies that were tagged on slickline. Brief Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing and tubing. 2. MIRU Williams pulling unit. 3. Circulate PW through well, kill the well. 4. Nipple up rod stripper head. 5. LD polish rod and pull EL rods. (rack back the rods in basket) 6. Set BPV, ND tree, NU BOPE and test to 250psi low /3,000psi high, annular to 250psi low /1,500psi high. a. Notify AOGCC 24hrs in advance to witness 7. Pull J -latch tubing hanger. 8. Pull 2 -7/8" 8rd EUE tubing, LD tubing string. 9. PU overshot, drill collars and jars, RIH to latch 2 -7/8" tubing stub at 10,350ft. 10. RU a -line, RIH with gamma ray /CCL tool with cutter and cut between screens and chemical injection sub, based on CCL evaluation and tubing tally comparison. a. Tie -in gamma ray to logs to determine what actual top of tubing stub is based on perforated intervals. 11. POH w/ E -line. • • Well Prognosis Well: SCU 32 -08 Hilcorp Alaska, LLC Date: 11/29/2012 12. Attempt to pull fish out of the hole. 13. If fish comes out, POH LD fish a. RU slickline, RIH w/ magnets determine if there are any small pieces on the fish b. Remove any debris with magnet on slickline until magnet comes back empty c. PU burn shoe on wash pipe, jars, and drill collars, RIH and burn over fish until free or no additional progress is made with mill. d. POH and LD burn shoe and wash pipe. e. RU slickline and RIH w/ magnet and fish any new debris f. Run 2.5" gauge ring through the top of fish, (tag top of fish and bottom of screen assemblies) determine depth of open hole. g. RD slickline h. PU Spear with fishing BHA, RIH and latch fish and attempt to pull. If fish comes out, lay down BHA and RIH with slickline bailer to tag bottom and collect sample. i. RU completion and RIH and complete as originally proposed in October. 14. If 1 cut fish does not come free after attempting to pull, RIH w/ E -line and perforate below screens in blank pipe. 15. RIH with 2 " cutter and cut 2 -7/8" tubing above the chem injection sub. 16. POH with tubing stub, LD work string. 17. PU new 2 -7/8" 8rd EUE L -80 tubing with the following BHA. (bull plug, 30ft of blank 4.5" tubing, slotted flow sub, X0, cup type pump seating nipple, XO, Weatherford tubing anchor (approx. 10,300ft), annular depth indicator sub at approx. ,6000ft, and chemical injection sub at approx. 4,000ft. 18. Land tubing hanger with tubing in tension (3- 4,000 #'s). 19. ND BOPE, NU tree and test (Ensure the tree is plumb and without any lean). 20. NU Rod stripper, circulate well with PW maintaining a full hole. 21. PU 13ft dip tube, rebuilt rod pump, RIH with tapered rod string (3/4 ", 7/8" and 1 "), Inspect rods and guides and replace as necessary (3 rods per guide), land the pump, space out the rods, install polish rod. 22. ND rod BOPE, install surface equipment onto well and test. 23. RD Williams #405. 24. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 25. Return to production. Attachments: 1. Schematic 2. Proposed Schematic 3. BOP Schematic • e Swanson River Field , , i3 SCHEMATIC SCU 32 -08 / PTD 160 -045 Actual Completion 10 -20 -2011 Hilcory Alaska, LLC API# 50- 13340118 -00 -00 RKB: 1437 GL: 128' AMSL CASING DETAIL New KB —THF: 15.00' Size WT Grade Conn ID Top Btm 22" - - - - Surface 28' A 54.5 J -55 8RD 12.615" Surface 1,308' 13 -3/8" DV Collar 12.615" 1,308' 1,310' I I 54.5 J -55 8RD 12.615" 1,310' 3.014' 1 I�I; 28 P -110 8RD 5.791" Surface 115' a 24 N -80 BTC 5.921" 115' 6,477' II I 24 P -110 8RD 5.921" 6,477' 7,996' 6 - 5/8" DV Collar 5.921" 7,996' 7,998' II 24 P -110 8RD 5.921" 7,998' 10,037' 28 P -110 8RD 5.791" 10,037' 10,828' I II TUBING DETAIL I l l 2 -7/8" 6.4 L -80 8RD 2.441" Surface 10,116' III JEWELRY DETAIL n # Depth' Length' ID" OD" Description A 1 15 5.23 2.441 7 Seaboard Int. Tension Hanger, 7" Modified I�I' 10,350 1.1 2.25 3.688 Cup type seating nipple (Top of Fish) I F 4.09' 2.375 4.25 Chemical Injection Sub I S H 39 3.438 4.4 Screen Assembly 0.008" 97.182 3.958 4.5 Blank pipe !i 10,519 0.75 0 5.188 Bull Plug (Bottom f Fish) ROD DETAIL A 2,805 2,750 - 1" 1" Polish Rod Top 1 B B 6,356 3,550 - 7/8" Polish Rod Bottom C 10,100 3,742 - % '/" EL rods w/3,5,or12 per XL guides lit FISH @ 10,350' PERFORATION DETAIL ON NEXT PAGE r PBTD +- 10,631' 4 , a c:3 :: i TD = 10,828' PBTD = 10,631' MAX HOLE ANGLE = 3° @ 7,004' Revised By: TDF 11/29/2012 • • Swanson River Field , fi SCHEMATIC SCU 32 -08 / PTD 160 -045 Actual Completion 10 -20 -2011 Hilcorp Alaska, LLC API# 50- 133 - 10118 -00 -00 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G -1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10 -12 -1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re -perf 08 -18 -01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re- perforated October 2011 10/16/1985. H1 10,518' 10,520' 10,515' 10,517' 2' Re-perf 08-18-01 / 10-02-2004 2/21/1961 Hi 10,520' 10,529 10,517' 10,526' 9 Re perf 10 -16 -1985 / 06-10-1995 / 08-18-2001 ' / 10 -02 -2004 2/21/1961 Hi 10,529' 10,530' 10,526' 10,527' 1' Re -perf 10 -16 -1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re -perf 08 -18 -01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re- perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re -perf 10 -16 -1985 / 08 -18 -2001 / 10-02 -2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10' Re perf 10 -16 -1985 / 06-10-1995 / 08-18-2001 / 10 -02 -2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08-18 -2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re -perf 10 -16 -1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10 -16 -1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10 -16 -1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re -perf 10 -16 -1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10 -16 -1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10 -16 -1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10 -16 -1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10 -16 -1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10 -16 -1985 Revised By: TDF 11/29/2012 • • Swanson River Field PROPOSED SCU 32 -08 / PTD 160 -045 Actual Completion 10 -20 -2011 Hilcorp Alaska, LLC API# 50- 133 - 10118 -00 -00 RKB: 143'/ GL: 128' AMSL CASING DETAIL New KB -THF: 15.00' Size WT Grade Conn ID Top Btm A 1 22" Surface 28' [ El 54.5 1 -55 8RD 12.615" Surface 1,308' B 13 -3/8" DV Collar 12.615" 1,308' 1,310' DV @ III 54.5 J -55 8RD 12.615" 1,310' 3.014' 1,308' I - 28 P -110 8RD 5.791" Surface 115' I 24 N -80 BTC 5.921" 115' 6,477' 24 P -110 8RD 5.921" 6,477' 7,996' 6 -5/8" i 2 DV Collar 5.921" 7,996' 7,998' 1 24 P -110 8RD 5.921" 7,998' 10,037' 1 11 28 P -110 8RD 5.791" 10,037' 10,828' i l 3 TUBING DETAIL 2 -7/8" 6.4 L -80 8RD 2.441" Surface ±10,310' 111 JEWELRY DETAIL DV @ , # Depth' Length' ID" OD" De scription 7,996' ID 1 ±15 5.23 2.441 7 Seaboard Int. Tension Hanger, 7" Modified 2 ±4,000 0.68 2.438 4.5 Chem Injector w/ 3/8" Tubing C 3 ±6,000 Annular depth indicator sub 4 ±10,300 8.69 4.24 / 2.441 5.5 Weatherford retrievable tubing anchor 1 II 5 ±10,310 1.1 2.25 3.688 Cup type seating nipple i D II'L_ T 6 10,315 5 3.9 4.5 Ported /slotted sub ii ; Q.-J 7 ±10,377 62 3.958 4.5 Blank pipe 8 ±10,380 0.75 0 5.188 Bull Plug ROD DETAIL A ±2.25 40 - 1/1/2002 Polish rod B ±2,805 2,750 - 1 1" EL rods with 3 per XL guides C ±6,356 3,550 - 8 -Jul 7/8" EL rods with 3 per XL guides E D ±10,280 4,050 - Y. %" EL rods w/3,5,or12 per XL guides E ±10,310 40.92 2.25 RHBC rod pump w -3/4" SR pin x 1.8024 -14 box (2.5" x 1.75" x 36' x 36.5' x 37') 11411-' F ±10,311 2.313 Seating cup 5 G ±10,325 13' 1.26 1.66 Dip tube perforated on bottom 5 Lt); C( °( '/p rt ��e. - $0-1- 7 i 'd f dr r -1-.1".k. r 1 $ PERFORATION DETAIL ON NEXT PAGE Bad +- 10,631 Casing @ :::: 10,634 TD = 10,828' PBTD = 10,631' MAX HOLE ANGLE = 3° @ 7,004' Revised By TDF 11/29/2012 • • Swanson River Field PROPOSED SCU 32 -08 / PTD 160 -045 Actual Completion 10-20 -2011 f n Hilcorp Alaska, LLC API# 50- 133 - 10118 -00 -00 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G -1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10 -12 -1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re -perf 08 -18 -01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re- perforated October 2011 10/16/1985 H1 10,518' 10,520' 10,515' 10,517' 2' Re -perf 08 -18 -01 / 10-02 -2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' 9 Re perf 10-16-1985 / 06-10-1995 / 08-18-2001 ' / 30 -02 -2004 2/21/1961 H1 10,529' 10,530' 10,526' 10,527' 1' Re -perf 10 -16 -1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re -perf 08 -18 -01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re- perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re -perf 10 -16 -1985 / 08 -18 -2001 / 10-02 -2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10 Re-perf 10-16-1985 / 06-10-1995 / 08-18-2001 ' / 10 -02 -2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re -perf 10 -16 -1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10 -16 -1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10 -16 -1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re -perf 10 -16 -1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10 -16 -1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10 -16 -1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10 -16 -1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10 -16 -1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10 -16 -1985 Revised By TDF 11/29/2012 • • . Swanson River SCU 32 -08 BOPE 11/28/2012 1Idrorp %I...k.i. 1.1 SCU 32 -08 133/8X65/8X27/8 • I Ii1THTiU III Ill III U I1l Annular Preventer 7 1/16 5M 1I1 Iii Ill ICI 111 7 1/16 5 _ _ ® = Pipe rams - — - Blind rams MP . 1611" i ii 1: i i .4 . i • : - III on on _ , ef\ I}II(& 11 I lit III I.1 - r • Choke and Kill lines 2 1/16 5M w/ 2" Unbolt 111 1 11 111 I iI 111 connections for choke and kill hoses Iii III Iii III till 1s1 ill Ill 1.1 I lit ..:o 4i._ iii I .l l 110.; � 1 1■I��[�I.,. �� -i..; 111 , I.I 111 Il al al 111 ; III j iu' 1 :r +lr I all. 1 Page l of l • • 6 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, November 30, 2012 9:30 AM To: 'Chad Helgeson'; Ferguson, Victoria L (DOA) Cc: Tom Fouts - (C); donnierhuffman @yahoo.com; Donna Ambruz; Stan Golis; Wade Hudgens - (C) Subject: RE: SCU 32 -08 Sundry (PTD 160 -045) Chad, I reviewed the sundry procedure ... it looks good. I hope this time the fish can be brought to surface to allow a deeper pump set depth. You have verbal approval (per Commissioner Foerster) to proceed rk v r program on SCU 32-08. We shoul have the sundry ready early your proposed wo o e p ►Y Y Y next Y P p 9 week for pickup. Make sure you have a copy of this email on rig location with the submitted sundry outline until the approved copy is available. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Chad Helgeson [mailto:chelgeson @hilcorp.com] Sent: Friday, November 30, 2012 6:40 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Cc: Tom Fouts - (C); donnierhuffman @yahoo.com; Donna Ambruz; Stan Golis; Wade Hudgens - (C) Subject: SCU 32 -08 Sundry Guy, Attached is a Sundry we are delivering this morning. As we discussed on the phone late Wednesday afternoon, this is the well we plan to move the Williams rig to next and finish what we started in October. It is essentially one more fishing attempt on the well and then running the completion above the fish if it doesn't come out. I have included a procedure for the work and a drawings of what it currently looks like and what the proposed completion would be if the fish does not come out of the hole. We are going to start moving equipment to this location today with the hope of getting it rigged up and installing the winterization package by Sunday and possibly start pulling rods on Sunday and a probable BOP test on Monday. Please review and let me know if you have any questions and if we can get a verbal approval on this today. Thanks for your help. Chad Helgeson Operations Engineer Hilcorp Alaska, LLC Office: 907 - 777 -8405 Mobile: 907 - 229 -4824 11/30/2012 g w \, �� s THE STATE Alaska Oil and Gas °f ALASK - Conservation Commission jf GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF r4 P Anchorage, Alaska 99501 -3572 ALAS y ,44 ? .+ Main: 907.279.1433 Fax: 907.276.7542 Stan Golis Operations Manager (00 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 32 -08 Sundry Number: 312 -389 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy /Foe r Chair. DATED this 12 of October, 2012. Encl. . • ,Wv RECEIVED • STATE OF ALASKA �� OCT 0 2012 • ALASKA OIL AND GAS CONSERVATION COMMISSION S 1 i 2/ 1 ` APPLICATION FOR SUNDRY APPROVALS AO CC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 ' Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Repair Rods El 2. Operator Name: Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to DriN Number: Exploratory ❑ Development 0 ' 160-045 - 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99503 50-133-10118-00 ' 7. If perforating: 8. WeN Name and Number What Regulation or Conservation Order governs well spacing in this pool? N/A Sotdotna Creek Unit (SCU) 32-08 Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA 028996 ' Swanson River Field / Hemlock Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,828 ' 10,824 - 10,631 10,628 N/A 10,631 (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13 -3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6 -5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2 -7/8" 6.4# / N -80 10,463' Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A N/A N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 10/13/12 Commencing Operations: Oil El Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson Phone: 907 - 777 -8405 Email chelgesonCci2hilcoro.com Printed Name Stan Golis Title Operations Manager S Signature "`^ Phone 907 - 777 -8356 Date l t 1 1 U/ t YZ._ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: a 2. Plug Integrity ❑ BOP Test Q Mechanical Integrity Test ❑ Location Clearance ❑ Other: Bo ,p fi f fo 3 D O (L f ) 5- L Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: /0 — Yc y 14 t / 3 4 � r �,'l APPROVED BY / j Z Approved by: t fi ) 0 COMMISSIONER THE COMMISSION Date: (. 1 -- � ,� l Submit Form Du and ;� \ � 0 R 11,3 7� o f ev o 2 � I p�to a �EieA is veil for 12 months from the date of approval. di nets in plicate jY • Well Prognosis Well: SCU 32-08 Hilcorp Alaska, LLC Date: 10/10/2012 Well Name: SCU 32 -08 API Number: 50- 133 - 10118 -00 Current Status: Oil Producer Leg: N/A Estimated Start Date: October 13 2012 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 160 -045 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) AFE Number: 1253095 Current Bottom Hole Pressure: — 2,000 psi @ 10,500' TVD (Static survey on nearby well conditions) Maximum Expected BHP: — 2,000 psi @ 10,500' TVD Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 95% (0.435psi /ft) with added Safety Factor of 1,000' TVD of oil cap) Brief Well Summary Soldotna Creek Unit 32 -08 was worked on in April 2012 where damaged tubing was replaced and the pump was replaced. On 10 -4 -12, one of the rods parted. The pump has been gas locking and therefore a completion will be modified to aid operations of the well after the well is repaired. Notes Regarding Wellbore Condition • %" rod is parted at about 7,900 ft. Well is shut -in. ' Brief Procedure: 1. Prep location, decouple and roll back the rotoflex pumping unit. LOTO motor. 2. Blowdown any pressure on the well and shoot fluid level (echometer) on casing and tubing. 3. MIRU Williams pulling unit. Ched_c_fluiLLIeval, fill tubing with fluid volume, check fluid level again (determine static fluid level). r o d 4. Strip rod surface equipment, nipple up rod BOP. Test (250psi low /3000 psi high), Notify AOGCC_ (j 24hr in advance. 4- 5 r 5. LD polish rod and pull EL rods. (rack back the rods in basket) 6. RU rod fishing tools. RIH and fish parted rods with overshot 2 -1/8" on the bottom of the rods. tl 7. Pull rods (hang in basket) and LD pump. pv 8. Set BPV, ND tree, NU BOPE and test to 250 psi low 3 000 si high, annular to 250 psi low 1 500 si r0 ds high. OvRt -r s+ a. Noti AOGCC 24hrs in advance to witness 9. Pull 1 -latch tubing hanger. 10. Pull TIW auto -J tubing anchor with a straight pull of 50K over pull (may release earlier since it has been released 2 times) shear cone pins will shear and POH. 11. Standback the tubing checking it as it comes out of the well. Coil up the injection tubing. It will not 1 v11 be runback in the well. • Well Prognosis Well: SCU 32-08 , Hilcorp Alaska, LLC Date: 10/10/2012 12. LD anchor, screens and BHA. (rebuild Anchor on locations with TIW hand from Anchorage or Kenai), inspect screens to see if they are plugged or have very much sand in them. If they have sand, determine if they can be cleaned and rerun or find new screens that can be installed. 13. PU Slickline , RIH with 3.5" bailer and tag bottom. Note depth of fill. If full bailer comes out and it is at least 10,566, LD slickline. 14. PU new BHA. (bull plug, 60ft of blank 4.5" tubing, slotted flow sub (or ported sub), XO, cup type \\r pump seating nipple, XO, 150ft of 2 -7/8" tubing and rebuilt TIW auto J tubing anchor (10,350), and annular depth indicator sub at 3,000ft. 4CS//////) 15. Land tubing hanger with tubing in tension (3- 4,000 #'s). 16. ND BOPE, NU tree and test Ensure the tree is vertical and there is no angle on tree. 17. NU Rod BOP and test 18. PU 13ft dip tube, rebuilt rod pump, RIH with tapered rod string (3/4 ", 7/8" and 1 "), Inspect rods ta"" I and guides and replace as necessary (3 rods per guide), land the pump, space out the rods, install I ° 5 polish rod. 19. ND rod BOPE, install surface equipment onto well and test. 20. RD Williams #405. 21. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 22. Return to production. Attachments: 1. Schematic 2. Proposed Schematic 3. BOP Schematic . • • 11 Swanson River Field S CU 3 C5 2- 001-1 0 11p 8 / PTD 160 - 045 A ctual l etion 10 -20 -2011 A PI# 3 3 - 10118 -00 -00 Casing and Tubing Detail A RKB: 143'/ GL: 128' AMSL SIZE 1 WT 1 GRADE 1 CONN 1 ID 1 TOP 1 BTM. New KB — THF: 15.00' Casing 22" - - - - Surface 28' III 54.5 J -55 8RD 12.615" Surface 1,308' 1 B 13 -3/8" DV Collar 12.615" 1,308' 1,310' 54.5 J -55 8RD 12.615" 1,310' 3.014' ` ID 28 P -110 8RD 5.791" Surface 115' 24 N -80 BTC 5.921" 115' 6,477' — Cl ill 12 6 -5/8" 24 P -110 8RD 5.921" 6,477' 7,996' L , DV Collar 5.921" 7,996' 7,998' 1 -1 24 P -110 8RD 5.921" 7,998' 10,037' 28 P -110 8RD 5.791" 10,037' 10,828' Tubing III 2 -7/8" 6.4 1 N -80 1 IBT 1 2.441" 1 Surface 10,463' l j C Jewelry Detail III # Depth' Length' ID" OD" Description 1 15 5.23 2.441 7 Seaboard Int. Tension Hanger, 7" Modified II 2 3,044 .68 2.438 4.5 Annular depth indicator sub 3 10,344 8.69 4 5 5 TIW Auto jay te nsion set anchor w /(3) 1" non - concentric by- pass holes & 50 ,0004 emergency shear release III 9 4 10,385 1.1 2.250 3.688 Cup type seating nipple 5 10,390 4.09 2.375 4.25 Chemical Injection Sub i I ( 6 10,395 39 3.438 4.4 0.008" Screen assembly 7 10,435 97.18 3.958 4.5 Blank pipe _ 8 10,533 .75 0 5.188 Bull Plug I II D Rod Detail A 2.25 40 - 1 -1/2 Polish rod B 2,805 2,750 - 1 1" EL rods with 3 per XL guides C 6,356 3,550 7/8 7/8" EL rods with 3 per XL guides III D 10,407 4,050 % %" EL rods w/3,5,or12 per XL guides E 10,409 40.92 2.25 RHBC rod pump w -3/4" SR in x 1.8024 -14 box (2.5" x 1.75" x -0 36' x 36.5' x 37') 3 F 10,450 2.313 Seating cup G 10,513 62.67' 1.26 1.66 Dip tube w /30' perforated on bottom _ 4 _ 1 5 b Perforation History- E r Date Zone Top Btm Amt Comments ti - F October2011 '6-1' 10,376' 10,396' 20' Perforated October 2011 02 -20 -1961 WSO 10,496' 10,497' 1' Squeezed 10 -12 -1985 s. G - _ 10 -16 -1985 H1 10,516' 10,518' 2' Re- perf08 -18 -01 October2011 'H -1' 10,518' 10,533' 15 Re- perforated October 2011 10 -16 -1985 Hl 10,518' 10,520' 2' Re- perf08 -18-01 / 10 -02 -2004 02 -21 -1961 H1 10,520' 10,529 9' Re -perf 10 -16 -1985 /06-10-1995 / 08 -18 -2001 / 10 -02 -2004 7 11 8 02 -21 -1961 111 10,529' 10,530' 1' Re -perf 10 -16 -1985 10-16 -1985 HI 10,530' 10,532' 2 08 -18 -2001 H2 10,543' 10,545' 2' 10 -16 -1985 H2 10,545' 10,546' 1' Re- perf08 -18 -01 October 2011 'H -2' 10,545' 10,566' 21' Re- perforated October 2011 varu - -10s31 06 -10 -1995 H2 10,546' 10,550' 4' Re -perf 10 -16 -1985 / 08 -18 -2001 / 10-02 -2004 02 -21 -1961 H2 10,550' 10,560' 10' Re -perf 10 -16 -1985 / 06-10 -1995 / 08 -18 -2001 / 10-02 -2004 s 02 -21 -1961 H2 10,560' 10,569' 9' Re -perf 10 -16 -1985 / 06- 10-1995 / 08 -18 -2001 02 -21 -1961 H2 10,569' 10,572' 3' Re -perf 10 -16 -1985 a 02 - - 1961 H2 10,572' 10,575' 3' Sqzd 10-16 -1985 02 -21 -1961 H3 10,580' 10,584' 4' Sqzd 10-16 -1985 .... 10-16-1985 H3 10,585' 10,592' 7' TD = 10,828' PBTD = 10,631' 02 -21 -1961 H3 10,592' 10,600' 8' Re -perf 10 -16 -1985 MAX HOLE ANGLE = 3° @ 7,004' 02 -21 -1961 H3 10,600' 10,603' 3' Sqzd 10 -16 -1985 02 -21 -1961 H3 10,608' 10,616' 8' Sqzd 10 -16 -1985 02 -21 -1961 H3 10,622' 10,631' 9' Sqzd 10 -16 -1985 02 -21 -1961 H4/5 10,622' 10,678' 56' Sqzd 10 -16 -1985 02- 20-1961 WSO 10,681' 10,682' 1' Sqzd 10-16 -1985 SCU 32 -08 Asbuilt 4 -18 -2012 Updated by DMA 4 -18 -2011 • • Swanson River Field .14. PROPOSED SCU 32 -08 / PTD 160 -045 Actual Completion 10 -20 -2011 Hilcorp Alaska, l,l,c API# 50- 133 - 10118 -00 -00 RKB:143' / GL: 128'AMSL CASING DETAIL New KB THF: 15.00' Size WT Grade Conn ID Top Btm a ll i i, A 1 22" - - - - Surface 28' [1:■ 54.5 1 -55 8RD 12.615" Surface 1,308' 13 -3/8" DV Collar 12.615" 1,308' 1,310' B DV @ , 54.5 J -55 8RD 12.615" 1,310' 3.014' 1,308' ` 28 P -110 8RD 5.791" Surface 115' ER 12 24 N -80 BTC 5.921" 115' 6,477' 24 P -110 8RD 5.921" 6,477' 7,996' 6 -5/8" DV Collar 5.921" 7,996' 7,998' 24 P -110 8RD 5.921" 7,998' 10,037' 28 P -110 8RD 5.791" 10,037' 10,828' C TUBING DETAIL I -1 2 -7/8" 6.4 N -80 IBT 2.441" Surface ±10,553' JEWELRY DETAIL DV @ 7,996' # Depth' Length' ID" OD" Description I -I 1 ±15 5.23 2.441 7 Seaboard Int. Tension Hanger, 7" Modified '. 2 ±3,044 0.68 2.438 4.5 Annular depth indicator sub TIW Auto jay tension set anchor w /(3) 1" 3 ±10,344 8.69 4.24 / 2.441 5.5 non - concentric by -pass holes & 50,000# emergency shear release Li D 4 ±10,540 1.1 2.25 3.688 Cup type seating nipple 5 ±10,541 32.3 3.958 4.5 Blank pipe 6 ±10,573 0.75 0 5.188 Bull Plug ROD DETAIL gliellill A ±2.25 40 - 1/1/2002 Polish rod 3 IIINIOnr-- B ±2,805 2,750 - 1 1" EL rods with 3 per XL guides C ±6,356 3,550 8 -Jul 7/8" EL rods with 3 per XL guides E D ±10,407 4,050 - '% %" EL rods w/3,5,or12 per XL guides I E ±10,499 40.92 2.25 RHBC rod pump w -3/4" SR pin x 1.8024 -14 4 box (2.5 "x1.75 "x36'x36.5'x37) F ±10,540 - - 2.313 Seating cup F G ±10,603 62.67' 1.26 1.66 Dip tube w /30' perforated on bottom 5 6 Bad PERFORATION DETAIL ON NEXT PAGE +- 1 Casing @ PBTD 0 ' � . # __ 10,634 TD = 10,828' PBTD = 10,631' MAX HOLE ANGLE = 3° @ 7,004' Revised By TDF 10/10/2012 H . • • Swanson River Field • PROPOSED SCU 32 -08 / PTD 160 -045 Actual Completion 10 -20 -2011 Hilcorp Alaska, LLC API# 5043340118 -00 -00 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10/1/2011 G -1 10,376' 10,396' 10,373' 10,393' 20' Perforated October 2011 2/20/1961 WSO 10,496' 10,497' 10,493' 10,494' 1' Squeezed 10 -12 -1985 10/16/1985 H1 10,516' 10,518' 10,513' 10,515' 2' Re-perf 08-18-01 10/1/2011 H1 10,518' 10,533' 10,515' 10,530' 15 Re- perforated October 2011 10/16/1985 H1 10,518' 10,520' 10,515' 10,517' 2' Re -pert 08 -18 -01 / 10 -02 -2004 2/21/1961 H1 10,520' 10,529 10,517' 10,526' g Re -pert 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 / 10 -02 -2004 2/21/1961 H1 10,529' 10,530' 10,526' 10,527' 1' Re -pert 10 -16 -1985 10/16/1985 H1 10,530' 10,532' 10,527' 10,529' 2 8/18/2001 H2 10,543' 10,545' 10,540' 10,542' 2' 10/16/1985 H2 10,545' 10,546' 10,542' 10,543' 1' Re-perf 08-18-01 10/1/2011 H2 10,545' 10,566' 10,542' 10,563' 21' Re- perforated October 2011 6/10/1995 H2 10,546' 10,550' 10,543' 10,547' 4' Re -pert 10 -16 -1985 / 08 -18 -2001 / 10 -02 -2004 2/21/1961 H2 10,550' 10,560' 10,547' 10,557' 10 Re -pert 10-16-1985 / 06 -10 -1995 / 08 -18 -2001 / 30 -02 -2004 2/21/1961 H2 10,560' 10,569' 10,557' 10,566' 9' Re -pert 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 2/21/1961 H2 10,569' 10,572' 10,566' 10,569' 3' Re -pert 10 -16 -1985 2/21/1961 H2 10,572' 10,575' 10,569' 10,572' 3' Sqzd 10 -16 -1985 2/21/1961 H3 10,580' 10,584' 10,577' 10,581' 4' Sqzd 10 -16 -1985 10/16/1985 H3 10,585' 10,592' 10,582' 10,589' 7' 2/21/1961 H3 10,592' 10,600' 10,589' 10,597' 8' Re -pert 10 -16 -1985 2/21/1961 H3 10,600' 10,603' 10,597' 10,600' 3' Sqzd 10 -16 -1985 2/21/1961 H3 10,608' 10,616' 10,605' 10,613' 8' Sqzd 10 -16 -1985 2/21/1961 H3 10,622' 10,631' 10,619' 10,628' 9' Sqzd 10 -16 -1985 2/21/1961 H4/5 10,622' 10,678' 10,619' 10,674' 56' Sqzd 10 -16 -1985 2/20/1961 WSO 10,681' 10,682' 10,677' 10,678' 1' Sqzd 10 -16 -1985 Revised By TDF 10/10/2012 • • Swanson River SCU 32 -08 BOPE ll,.. 03/02/2012 SCU 32 -08 133/8X65/8X27/8 o j • 1■111 1 1 1 Annular Preventer 71/165M i1 , • 7 1/16 5M 0 _ ; —1 Pipe rams : 4 = - Blind rams IN _ III Ilt1 111 If 1 1!1 _ T n At' 0 :kill : , :II Al Olt ill 1; fib [if Ill Ill Ill" 0 : . 0 ! Choke and Kill lines 2 1/16 5M w/ 2" Unibolt 111 111111 III 1111 connections for choke and kill hoses Ill Ill Ill 111 I! - 1 In Ill il r is! I 1 III , —. =mill Oil: I!, I III c li ;A m ■ t . .7 1 u4 _ � ;- is' !l IE Ill Ill � ; iltl .......:,.,,,.. , a w f Ilr • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMI.ON APR 2 4 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations ❑ Perforate U Other U R &R Rods -DH Performed: Alter Casing ❑ Pull Tubing ell Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Pump- Tubing Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 160 -045 3. Address: 3800 Centerpoint Drive, Suite 100, Stratigraphic 0 Service ❑ 6. API Number: Anchorage, AK 99503 .` 50- 133 - 10118 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: Swanson River Field (FEDA 028996) Soldotna Creek Unit (SCU) 32 -08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): . N/A Swanson River Field / Hemlock Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,828 feet Plugs measured N/A feet true vertical 10,824 feet Junk measured 10,631 (fill) feet Effective Depth measured 10,631 feet Packer measured N/A feet true vertical 10,628 feet true vertical N/A feet Casing Length th Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13 -3/8" 3,014' 3,013' 2,730 psi 1,130 psi Intermediate Production 10,828' 6 -5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation depth Measured depth 10,376- 10,396;10,516- 10,533; 10,543- 10,572; 10,585- 10,600 feet True Vertical depth 10,373 - 10,393;10,512- 10,528; 10,539- 10,566; 10,581- 10,596 feet Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.4# / N -80 10,463' 10,459' Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N /A ,1. MAY 18 2012 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 10 Subsequent to operation: 25 22 45 0 195 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development Q vl Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil w El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 3/L - /Z. I Contact Stan Golis Printed Name Stan Golis Title Operations Manager Signature t..' Al-L0\ Phone 777 -8300 Date 4 4 j Z, c / 1 Z ` RBDMS APR 2 4 2012 �/s / � / `x�- Form 10-404 Revised 11/2011 ` " 7 / 4 - ---- Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 32 -08: RRR Tubing 50- 133 - 10118 -00 160 -045 4/9/12 4/16/12 ,Daily Operations; 04/09/2012 - Monday RU, PU polished rod and pony subs. Secured well with 2 -7/8" plug, needle valve and pressure gauge. POOH. 04/10/2012 - Tuesday RU SL and RIH w /gauge ring and D &D hole finder to 10,389' and attempt to test (no test). Continue to pull up hole and test tubing at multiple locations until reaching 100'. At this point test each joint to surface. No luck in testing. Set back pressure valve and remove tree continue to RU BOP for test. 04/11 /2012 - Wednesday NU BOPS for test. Removed tree from wellhead. Install BOP's for pressure testing. RU ported sub across the BOP stack. Tested Koomey and choke system. SD for night. 04/12/2012 - Thursday Continued BOP test. Testing passed. PU hanger and joint with two pup joints. RU slickline with C- cup 5/471 J-4,4.47 G standing valve plug. SN at 10,385'. Tubing tested to 1,500 psi for 15 minutes. Bleed pressure, equalised plug. POOH. RD SL. Picked up 31.5' joint of new 2 -7/8" tubing 6.4 lbs. with buttress threads. Made 1 ea 6' pup and 2 ea 2' pup joints. RIH i `'` - � w /hanger assembly and chemical injection line. Reset the anchor latch, pu led 20k into the tubing and landed hanger. 04/13/2012 - Friday (7 Removed choke lines and readied rig for move. Moved choke container. PU BOP and stored for rig move. Removed spacer flange from wellhead, re- installed tree and aligned flanges. Pulled back pressure valve. Picked up rod BOP system and installed on tree. Aligned to insure proper operations. Manipulated system and checked for proper operation. PU bottom hole assembly. RIH new rod pump system w/ double standing valves, tested good. RIH with assembly. RIH installing single joints of rods in same order as removed, taking care to torque to specifications. Continued RIH as per procedure. PU polish rod and make up for safety system during SD for night. Completed rod pump installation. Well secured. 04/14/2012 - Saturday RIH with pump rods. Used two additional rods to install pump in C nipple. Stroked pump and pulled two rods. PU polish rod, spaced out and ran test. RD equipment for moving. RTP. 04/14/2012 - Sunday Nothing to report. • Swanson River Field SCU 32 -08 / PTD 160 -045 Actual Completion 10 -20 -2011 API# 50- 133 - 10118 -00 -00 Casin ' and Tubin . Detail RKB: 1437 GL: 128' AMSL SIZE 1 WT GRADE CONN ID TOP BTM. New KB – THE: 15.00' Casing 22" - Surface 28' 1E1 ■ 54.5 J -55 8RD 12.615" Surface 1,308' 13 -3/8" DV Collar 12.615" 1,308' 1,310' B 54.5 J-55 8RD 12.615" 1,310' 3.014' ` I_� 28 P -110 8RD 5.791" Surface 115' c 24 N -80 BTC 5.921" 115' 6,477' 1] 1 2 24 P -110 8RD 5.921" 6,477' 7,996' 6 -5/8" DV Collar 5.921" 7,996' 7,998' 11 24 P -110 8RD 5.921" 7,998' 10,037' 28 P -110 8RD 5.791" 10,037' 10,828' Tubing 1BI 2 - 7/8" 1 6.4 1 N - 80 IBT 2.441" 1 Surface 10,463' I C Jewelry Detail Il # Depth' Length' ID" OD" Description 1 15 5.23 2.441 7 Seaboard Int. Tension Hanger, 7" Modified 2 3,044 .68 2.438 4.5 Annular depth indicator sub c 4.24 2 / TIW Auto jay tension set anchor w /(3) 1" non - concentric by- 1 3 10,344 8.69 5.5 .441 pass holes &50,000# emergency shear release 11 4 10,385 1.1 2.250 3.688 Cup type seating nipple 5 10,390 4.09 2.375 4.25 Chemical Injection Sub 6 10,395 39 3.438 4.4 0.008" Screen assembly 7 10,435 97.18 3.958 4.5 Blank pipe 8 10,533 .75 0 5.188 Bull Plug 1 - 1 D Rod Detail A 2.25 40 - 1 -1/2 Polish rod B 2,805 2,750 1 1" EL rods with 3 per XL guides C 6,356 3,550 7/8 7/8" EL rods with 3 per XL guides I I - I I D 10,407 4,050 - % 1:" EL rods w/3,5,or12 per XL guides E 10,409 40.92 2 25 RHBC rod pump w -3/4" SR pin x 1.8024 -14 box (2.5" x 1.75" x 36' x 36.5' x 37') 3 F 10,450 - - 2.313 Seating cup G 10,513 62.67' 1.26 1.66 Dip tube w /30' perforated on bottom 4 - -5 §— ___ Perforation History E _ Date Zone Top Btm Amt Comments F October 2011 G -1' 10,376' 10,396' 20' Perforated October 2011 02 -20 -1961 WSO 10,496' 10,497' 1' Squeezed 10 -12 -1985 G 10 -16 -1985 HI 10,516' 10,518' 2' Re- perf08 -18-01 simiwime October 2011 H -1' 10,518' 10,533' 15 Re - perforated October 2011 4' 10 -16 -1985 111 10,518' 10,520' 2' Re -perf 08 -18-01 / 10 -02 -2004 02 -21 -1961 H1 10,520' 10,529 9' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 / 10 -02 -2004 7 02 -21 -1961 HI 10,529' 10,530' 1' Re -perf 10 -16 -1985 10 -16 -1985 H1 10,530' 10,532' 2 08 -18 -2001 112 10,543' 10,545' 10 -16 -1985 H2 10,545' 10,546' 1' Re -perf 08 -18 -01 October 2011 'H -2' 10,545' 10,566' 21' Re- perforated October 2011 PBTD +- !O,631' 06 -10 -1995 H2 10,546' 10,550' 4' Re -perf 10 -16 -1985 / 08 -18 -2001 / 10 -02 -2004 1 it 02 -21 -1961 112 10,550' 10,560' 10' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 / 10 -02 -2004 02 -21 -1961 H2 10,560' 10,569' 9' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 02 -21 -1961 H2 10,569' 10,572' 3' Re -perf 10 -16 -1985 I 02 -21 -1961 112 10,572' 10,575' 3' Sqzd 10-16 -1985 02 -21 -1961 113 10,580' 10,584' 4' Sqzd 10 -16 -1985 ]0 -16 -1985 H3 10,585' 10,592' 7' TD= 10,828' PBTD = 10,631' 02 -21 -1961 H3 10,592' 10,600' 8' Re -perf 10 -16 -1985 MAX HOLE ANGLE =3 @ 7,004' 02 -21 -1961 113 10,600' 10,603' 3' Sqzd 10 -16 -1985 02 -21 -1961 H3 10,608' 10,616' 8' Sqzd 10 -16 -1985 02 -21 -1961 H3 10,622' 10,631' 9' Sqzd 10 -16 -1985 02 -21 -1961 114/5 10,622' 10,678' 56' Sqzd 10 -16 -1985 02 -20 -1961 WSO 10,681' 10,682' 1' Sqzd 10 -16 -1985 SCU 32 -08 Asbuilt 4 - - 2012 Updated by DMA 4 -18 -2011 • • Page 1 of 2 Schwartz, Guy L (DOA) From: Stan Golis [sgolis @hilcorp.com] , � o_ D'IC Sent: Friday, April 27, 2012 1:42 PM To: Schwartz, Guy L (DOA); Tom Fouts - (C) SY. CC 32 — ®S Cc: Larry Greenstein; Luke Keller; paullangley @internationalcompletion.com Subject: RE: Rig wellwork reports. As we discussed, our leak was in first tubing pup joint below the hanger. After we laid that pup down, we ran in with slickline to set a plug at bottom of tubing string and successfully pressure tested the entire production tubing string. After the successful pressure test, we re- latched into the tubing anchor and landed the tubing in the hanger. Thanks. Stan From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, April 27, 2012 1:27 PM To: Tom Fouts - (C) , Cc: Stan Golis; Larry Greenstein; Luke Keller Subject: RE: Rig wellwork reports. Tom, - What was the reason the tubing was not pulled out of the well and re -run ? Looks like you just reset the tubing anchor and added some new tubing then re- landing the hanger.... Am I reading this right in ' concluding your tubing hanger was your leak path and not a hole in the tubing so no tubing pull was needed.... Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Tom Fouts - (C) [mailto:tfouts @hilcorp.com] Sent: Friday, April 27, 2012 8:23 AM To: Schwartz, Guy L (DOA) Cc: Stan Golis; Larry Greenstein; Luke Keller Subject: RE: Rig wellwork reports. Guy, Please review the updated 10 -404 summary for SCU 32 -08. I have also provided a copy of the "Operations Summary Standards" which we employ when creating our summaries. We are hesitant to provide our Daily Rig Reports as they contain internal costs, vendors rates and proprietary information which I'm sure you can understand, we do not wish to have in the public record. If you feel there still deficiencies to the report, we will do our best to reconcile any issues you find. Sincerely, Tom Fouts I Construction Manager Hilcorp Alaska, LLC tfouts @hilcorp.com Direct: (907) 777 4/27/2012 • Page 2 of 2 • Mobile: (907) 351-5749 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Tuesday, April 24, 2012 4:02 PM To: Stan Golis Cc: Luke Keller; Tom Fouts - (C) Subject: Rig wellwork reports. All, When reporting rig workovers with a 10-404 please submit the full detailed daily report. The daily summary is not detailed enough for our records. I just received SCU 32 -08 10-404 with a one page daily summary log for the RWO.... please summit the daily reports from the rig for this well. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 4/27/2012 • (} y,G2 -lt Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 32 -08: RRR Tubing 50- 133 - 10118 -00 160 -045 4/9/12 4/16/12 Daily Operations: 04/09/2012 - Monday RU Aurora Rig, PU polished rod and pony subs and LD same. Secured well with 2 -7/8" plug, needle valve and pressure gauge. POOH. 04/10/2012 - Tuesday RU Slickline and RIH w /gauge ring and D &D hole finder to 10,389' and attempt to test tubing, unable to pressure up. Continue to pull up hole and test tubing at multiple locations until reaching 100', still unable to pressure up. At this point test each joint to surface. No luck in testing. Set back pressure valve and begin to remove tree. Notified AOGCC of upcoming BOP test. 04/11/2012 - Wednesday Removed tree from wellhead. Install BOP's for pressure testing. RU ported sub across the BOP stack. Tested Koomey and choke system. SD for night. 04/12/2012 - Thursday Continued BOP test from 250psi Low/ 3, 000psi High. PU hanger and joint with two pup joints LD same. Hole in tubing. RU Slickline with C- cup standing valve plug. Set at 10,385'. Tubing tested to 1,500 psi for 15 minutes. Bleed pressure, equalized plug. POOH. RD Slickline. Picked up 31.5' joint of new 2 -7/8" tubing 6.4# with buttress threads. Made up 1- 6' pup and 2- 2' pup joints. RIH w /hanger assembly and chemical injection line. Reset the anchor latch, pulled 20k into the tubing and landed hanger. 04/13/2012 - Friday Set BPV. Removed choke lines and readied rig for move. Moved choke container. ND BOP and stored for rig move. Removed spacer flange from wellhead, re- installed tree and aligned flanges. Pulled back pressure valve. Picked up rod BOP system and installed on tree. PU bottom hole assembly. RIH new rod pump system w/ double standing valves, tested good. RIH with assembly. RIH installing single joints of rods in same order as removed. Continued RIH as per procedure. PU polish rod and make up for safety system during SD for night. Completed rod pump installation. Well secured. 04/14/2012 - Saturday RIH with pump rods. Used two additional rods to install pump in C nipple at 10,385. Stroked pump and pulled two rods. PU polish rod, spaced out and ran test. RD equipment for rig move. Turn well over to production. 04/15/2012- Sunday Nothing to report. Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, April 05, 2012 8:44 AM � To: 'Stan Golis' / 6C7 — c 5 d Subject: RE: SRU 32-08 ID 312 -121) Tom, - That will suffice.. thanks for the response back. I agree if the environment is not corrosive and you haven't seen any indication in OA of leaking casing it isn't necessary. Guy Schwartz Senior Petroleum Engineer _ ' Ella AOGCC �� t))� 793 -1226 (office) 444 -3433 (cell) From: Stan Golis [mailto:sgolis @hilcorp.com] Sent: Thursday, April 05, 2012 8:03 AM To: Schwartz, Guy L (DOA) Cc: Chet Starkel; Tom Fouts - (C); Larry Greenstein; paullangley @internationalcompletion.com Subject: RE: SRU 32 -08 (PTD 312 -121) Guy, Regarding the need /requirement for a casing test: 1. There never has been an indication of an integrity problem with the 6 -5/8" production casing. 2. There never has been an indication of communication between the 13 -3/8" x 6 -5/8 ". 3. No flow well, and the production casing will be in low pressure service <250 psi. 4. This will be a packerless completion with open perforations. 5. Additionally, this well is in a low corrosion environment — e.g., negligible CO2 & H2S, not corrosive water, etc. 6. The incremental cost to test production casing is in the range of $25,000. Let me know if you would like to discuss further. Thanks. Stan From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, April 04, 2012 11:09 AM To: Stan Golis Subject: SRU 32 -08 (PTD 312 -121) Stan, I am reviewing the RWO to pull tubing and rod pump for SRU 32 -08. A production casing test is not part of the procedure as written. Can you justify this and give me some background on the last time the 6 5/8" casing was tested? Any OA pressure issues with this well in the past (13 3/8" X 6 5/8 ") ? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 4/5/2012 • TS [E [1 ALAHA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMItIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 I ( co Stan Golis Operations Manager Hilcorp Alaska, LLC A,14461EE) APR G 5 ZOI 3800 Centerpoint Dr., Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 32 -08 Sundry Number: 312 -121 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 79 Cathy . Foerster Chair An- DATED this J day of April, 2012. Encl. STATE OF ALASKA 9-fsii ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing la . Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: R &R Rods -DH Pump Tubing 0, 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Development 0 • Exploratory ❑ 160 -045 - 3. Address: - --11 r. Stratigraphic ❑ Service ❑ 3800 Centerpoint Dr., Suite 100 Anchorage, Alaska 99503 5 i : Q E 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Nuniber: property line where ownership or landownership changes: '.� N 4 l�,,�1 CFA Spacing Exception Required? Yes ❑ No 0 Soldotna Creek Unit 32, 8 ' MAR . 1� `' ad, 9. Property Designation (Lease Number): 10. Field /Pool(s): 1 Swanson River Facility FEDA028996 • Swanson River Field/ Hemlock Oil Pool ∎. • 012q k� ��i Gas Gobs. Commission 1 11. PRESENT WELL CONDITION SUMMARY Anchorage Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (ieac ir - d):.-- ---- -- measured): 10,828 ` 10,824 ' 10,631 10,627 Nov -28 10,631 (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13 -3/8" 3,014' 3,013' 2,730psi 1,130psi Intermediate Production 10,828' 6 -5/8" 10,828' 10,824' 7,440psi — 5,760psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,516- 10,532'; 10,543'- 10,512'- 10,528'; 10,539'- 10,572; 10,586- 10,600' 10,566'; 10,581'- 10,596' 2-7/8" 6.4#/ N -80 10,463 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A and N/A N/A and N/A 12. Attachments: Description Summary of Proposal la 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch © Exploratory ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/8/2012 Oil © . Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Golis Phone: 777 -8356 Printed Name Stan Golis Title Operations Manager Signature 1...- Phone 777 -8300 Date 3/30/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: a Z" 12 Plug Integrity ❑ BOP Test / Mechanical Integrity Test ❑ Location Clearance ❑ Other: A 3c D ,'=' ` 6 G'/ ' 7 s Subsequent Form Required: / D r- y aL/ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 4_5 (Z� g •� ORIGINAL QM Form 10-4 01 PR 0 6 10� Su b rrtiS,in Dup' a � ` r-"V • • Swanson River SCU 32 -8 March 30, 2012 .14 Hilcorp Alaska, LLC OBJECTIVE: • Shut -in oil well due to hole in tubing. Pull rods, downhole pump & tubing to locate and repair hole in tubing. Rerun tubing, rods and downhole pump to return to production. Current BHP: 2500 psi @ 10,376' MD Max Downhole Pressure: 2500 psi @ 10,376' MD (Based on offset well pressure surveys) MASP: 1465 psi (Based on a pressure gradient of 0.1 psi per foot of true vertical depth) PROCEDURE SUMMARY: 1. MIRU pulling unit. Load casing & tubing with FSW. ND wellhead assembly. NU rod B 2. PU on polished rod to unseat the pump. POOH with rod string & pump. ND rod BOPs. NU BOPs. Pressure test BOPs to 250 psi low /3000 psi high. 3. PU & release TIW tension set anchor @ 10,344' MD. POOH standing back 2 -7/8" tubing. Visually inspect tubing on TOOH for additional wear /holes. 4. PU and RIH with tubing anchor and 2 -7/8" production tubing. Set anchor @ 7 10, 350' ( + / -) MD. 5. ND BOPs. NU rod BOPs. RIH /d ole pump and tapered rod string. Space out & seat pump. i c's t 6 . ND rod BOPs. NU wel head assembly. 7. RDMO workover rig and equipment. 8. Hook up polished rod to rotaflex unit. Turn well over to production. Well Identifier REVISED BY: Initials MM -DD -YYYY • w • • Swanson River Field Chevron SCU 32 -08 / PTD 160 -045 Actual Completion 10 -20 -2011 API# 50- 133 - 10118 -00 -00 Casin , and Tubing Detail RKB: 143'/ GL: 128' AMSL SIZE WT GRADE CONN ID TOP BTM. New KB - THE: 15.00' Casing 22" - - - - Surface 28' 111 54.5 J -55 8RD 12.615" Surface 1,308' 13 -3/8" DV Collar 12.615" 1,308' 1,310' B 54.5 J -55 8RD 12.615" 1,310' 3.014' - 1111 28 P -110 8RD 5.791" Surface 115' 'c 24 N -80 BTC 5.921" 115' 6,477' l_l 12 24 P -110 8RD 5.921" 6,477' 7,996' 31 G ' 6 -5/8" DV Collar 5.921" 7,996' 7,998' C 24 P -110 8RD 5.921" 7,998' 10,037' I -� 28 P -110 8RD 5.791" 10,037' 10,828' Tubing 1 1 1 2 -7/8" 1 6.4 1 N -80 1 IBT 1 2.441" 1 Surface 1 10,463' 1 1 C Jewelry Detail II 11 Depth' Length' ID" OD" Description 1 15 5.23 2.441 7 Seaboard Int. Tension Hanger, 7" Modified 2 3,044 3 10,344 .68 8.69 2.438 4.5 Annular depth indicator sub 0 4.24 2.441 / TIW pass Auto holes jay & 50,0 tens00# ion set em anchor ergency w /(3) shear 1" non - concentric release by- 5.5 I1 4 10,389 1.1 2.250 3.688 Cup type seating nipple 5 10,390 4.09 2.375 4.25 Chemical Injection Sub 6 10,395 39 3.438 4.4 0.008" Screen assembly 7 10,435 97.18 3.958 4.5 Blank pipe 8 10,533 .75 0 5.188 Bull Plug 1 1 [ 11 1 D Rod Detail I 1 A 2.25 40 - 1 -1/2 Polish rod B 2,805 2,750 1 1" EL rods with 3 per XL guides � 4i C 6,356 3,550 7/8 7/8" EL rods with 3 per XL guides I BI D 10,407 4,050 . Y." 2 " EL rods w /3,5,or12 per XL guides E 10 40 25 RHBC rod pump w -3/4" SR pin x 1.8024 -14 box (2.5" x 1.75" x _ <k „y K 36' x 36.5' x 37') 3 F 10,450 - - 2.313 Seating cup E r G 10,513 62.67' 1.26 1.66 Dip tube w /30' perforated on bottom — 4 F - -- E -1 Perforation History - - Date Zone Top Btm Amt Comments October 2011 'G -1' 10,376' 10,396' 20' Perforated October 2011 __ _ 02 -20 -1961 WSO 10,496' 10,497' l' Squeezed 10 -12 -1985 -- 10 -16 -1985 HI 10,516' 10,518' 2' Re perf08 - 18 - 01 _ = October 2011 'H - 1' 10,518' 10,533' 15 Re perforated October 2011 10 -16 -1985 HI 10,518' 10,520' 2' Re- perf08 -18 -01 / 10 -02 -2004 = 02 -21 -1961 H1 10,520' 10,529 9' Re -pert 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 / 10 -02 -2004 7 1 1 02 -21 -1961 HI 10,529' 10,530' 1' Re -perf 10 -16 -1985 10 -16 -1985 HI 10,530' 10,532' 2 08 -18 -2001 112 10,543' 10,545' 2' 10 -16 -1985 H2 10,545' 10,546' 1' Re -perf 08 -18 -01 October 2011 1.1 10,545' 10,566' 21' Re perforated October 2011 ` PBTD + -W,631' 06 -10 -1995 H2 10,546' 10,550' 4' Re -perf 10 -16 -1985 / 08 -18 -2001 / 10 -02 -2004 1 !A 02 -21 -1961 112 10,550' 10,560' 10' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 / 10 -02 -2004 i 02 -21 -1961 H2 10,560' 10,569' 9' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 d 02 -21 -1961 112 10,569' 10,572' 3' Re-perf 10-16-1985 I 02 -21 -1961 112 10,572' 10,575' 3' Sqzd 10 -16 -1985 ""° � 02 -21 -1961 H3 10,580' 1%584' 4' Sqzd 10 -16 -1985 s` 10 -16 -1985 H3 10,585' 10,592' 7' TD = 10,828' PBTD = 10,631' 02 -21 -1961 113 10,592' 10,600' 8' Re -perf 10 -16 -1985 MAX HOLE ANGLE = 3° @ 7,004' 02 -21 -1961 H3 10,600' 10,603' 3' Sqzd 10 -16 -1985 02 -21 -1961 H3 10,608' 10,616' 8' Sqzd 10 -16 -1985 02 -21 -1961 113 10,622' 10,631' 9' Sqzd 10 -16 -1985 02 -21 -1961 114/5 10,622' 10,678' 56' Sqzd 10 -16 -1985 02 -20 -1961 WSO 10,681' 10,682' 1' Sqzd 10 -16 -1985 SCU 32 -08_Actual WBD_10 -20 -11 Updated by MGB 11 -03 -2011 1 • • Swanson River SCU 32 -08 BOPE .11 03/02/2012 1I korp ;1Iu.ka41.1.4 SCU 32 -08 133/8X65/8X27/8 v v r ilai Annular Preventer 7 1/16 5M 1 9 i1 t) 1 7 1116 5M _� ® _ Pipe rams - ll _ — Blind rams � 1.1 121121 1" : 7 1/16 5M I i � II 1 •�V Choke and Kill lines 2 1/16 5M w/ 2" Unibolt 111 111 111 111 111 connections for choke and kill hoses 7 1/16 5M 111 .Iii_Ii1_ti1 1!/ Iii gfg fin 1111I .. 1t, ..iii 112.- 111 111 Hi w [ o 0 1■ f [ c _, !11-1- 111 ■ 111 II 1 111 �r11�[0 .11111 Or • VE ID STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NO V 2 5 2 REPORT OF SUNDRY WELL OPERATIONS Ska 011 & Gas ? + Q E t ,. ; ;, ° r e , ra 1. Operations Abandon U Repair Well 11 Plug Perforations U Stimulate U Other H .,.... , F Performed: ' "r^ t,' Alter Casing ❑ Pull Tubing Q P erforate New Pool ❑ Waiver ❑ Time Extension Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 1151 Exploratory ❑ 160 -045 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic I: Service ❑ 6. API Number: 50- 133 - 10118 -00 — Q d 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028996 (Swanson River Facility) Soldotna Creek Unit (SCU) 32 -08 9. Field /Pool(s): Swanson River Field/ Hemlock Oil Field 10. Present Well Condition Summary: Total Depth measured 10,828 feet Plugs measured N/A feet true vertical 10,824 feet Junk measured 10,631 (Fill) feet Effective Depth measured 10,631 feet Packer measured N/A feet true vertical 10,627 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22^ 28' 28' Surface 3,014' 13 -3/8" 3,014' 3,013" 2,730psi 1,130psi Intermediate Production 10,828' 6 -5/8" 10,828' 10,824' 7,440psi 5,760psi Liner 10,516'- 10,532', 10,543'- 10,572', Perforation depth Measured depth 10,585- 10,600' feet ' -- f ft r; r, 4. 10,512'- 10,528', 10,53V-10,568', True Vertical depth 10,581'- 10,596' feet Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.4#/ N -80 10,463' 10,459' Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 11. Stimulation or cement squeeze summ N/A Intervals treated (measured): Review attached schematic. Treatment descriptions including volumes used and final pressure: 15 Bbls of NanoDissolve was spotted across zone and a (75 Bbl) 10% NanoDissolve 90% Jet A' mixture was used behind for placement and allowed to gravitate to equilibrium with reservoir pressure post TCP. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 109 25 27 200 185 Subsequent to operation: 50 44 24 20 160 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil , U Gas ❑ WDSPL U GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 3USP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Marcus Barbee Phone: 263 -7605 Printed Name Timothy C. Brandenburg y Title Drilling Manager Signature c..-- 1--c C,�.� ` Phone 276 -7600 Date 11/21/2011 Form 10 101 Re-iced Submit Original Only RSDMS NOV 2 8 20114 011,,^ ti-oi\41,,� • • Swanson River Field tro Chevron SCU 32 -08 / PTD 160 -045 Actual Completion 10 - 20 - 2011 API# 50- 133 - 10118 -00 -00 Casing and Tubing Detail A RKB: 143'/ GL: 128' AMSL SIZE 1 WT 1 GRADE 1 CONN 1 ID 1 TOP 1 BTM. New KB – THF: 15.00' Casing L-1 Lit. 22" - Surface 28' 54.5 J -55 8RD 12.615" Surface 1,308' 13 -3/8" DV Collar 12.615" 1,308' 1,310' B 54.5 J -55 8RD 12.615" 1,310' 3.014' 28 P -110 8RD 5.791" Surface 115' ' 4 24 N -80 BTC 5.921" 115' 6,477' 11 12 24 P -110 8RD 5.921" 6,477' 7,996' 6 -5/8" DV Collar 5.921" 7,996' 7,998' L i! 24 P -110 8RD 5.921" 7,998' 10,037' I 28 P -110 8RD 5.791" 10,037' 10,828' Tubing 1 -1 2 -7/8" 1 6.4 1 N -80 I IBT 1 2.441" 1 Surface I 10,463' C Jewelry Detail I # Depth' Length' ID OD" Description 1 15 5.23 2.441 7 Seaboard Int. Tension Hanger, 7" Modified 11 2 310,3,044 44 8.69 .68 2.438 4. 5 ' 5 S Annular pass holes depth & 50, in000# dicator emerg sub c 4.24 2 441 / TIW Auto jay tension set anchor w /(3) 1" non - concentric by- emergency shear release 3 I DI 4 10,389 1.1 2.250 3.688 Cup type seating nipple 5 10,390 4.09 2.375 4.25 Chemical Injection Sub 6 10,395 39 3.438 4.4 0.008" Screen assembly 7 10,435 97.18 3.958 4.5 Blank pipe 8 10,533 .75 0 5.188 Bull Plug I -I D Rod Detail II A 2.25 40 - 1 -1/2 Polish rod B 2,805 2,750 1 1" EL rods with 3 per XL guides C 6,356 3,550 7/8 7/8" EL rods with 3 per XL guides I -I D 10,407 4,050 - Y. '''A" EL rods w/3,5,or12 per XL guides E 10,409 40.92 2 25 RHBC rod pump w -3/4" SR pin x 1.8024 -14 box (2.5" x 1.75" x 36' x 36.5' x 37') 3 F 10,450 - - 2.313 Seating cup F G 10,513 62.67' 1.26 1.66 Dip tube w /30' perforated on bottom -4 _ F LA Perforation History r' 7 — = Date Zone Top Btm Amt Comments October 2011 G -1' 10,376' 10,396' 20' Perforated October 2011 Ti - 02 -20 -1961 WSO 10,496' 10,497' 1' Squeezed 10 -12 -1985 10 -16 -1985 HI 10,516' 10,518' 2' Re -perf 08 -18 -01 . = - October 2011 'H-1' 10,518' 10,533' 15 Re- perforated October 2011 - — � _ G 10 -16 -1985 H1 10,518' 10,520' 2' Re -perf 08 -18 -01 / 10 -02 -2004 02 -21 -1961 H1 10,520' 10,529 9' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 / 10 -02 -2004 7 1 1 02 -21 -1961 HI 10,529' 10,530' 1' Re -perf 10 -16 -1985 • 10 -16 -1985 111 10,530' 10,532' 2 08 -18 -2001 H2 10,543' 10,545' 2' 10 -16 -1985 H2 10,545' 10,546' 1' Re -perf 08 -18 -01 October2011 'H -2' 10,545' 10,566' 21' Re- perforated October 2011 1 PBTD+- 10,631' . 06 -10 -1995 H2 10,546' 10,550' 4' Re -perf 10 -16 -1985 / 08 -18 -2001 / 10 -02 -2004 .: 02 -21 -1961 112 10,550' 10,560' 10' Re -perf 10 -16 -1985 /06 -10 -1995 /08 -18 -2001 /10 -02 -2004 02 -21 -1961 112 10,560' 10,569' 9' Re perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 :: ....:.... :... 02 -21 -1961 112 10,569' 10,572' 3' Re -perf 10 -16 -1985 u : •: •:••:i•: ` ` 02 -21 -1961 1 10,572' 10,575' 3' Sqzd 10 -16 -1985 02 -21 -1961 H3 10,580' 10,584' 4' Sqzd 10 -16 -1985 _, 10 -16 -1985 H3 10,585' 10,592' 7' TD = 10,828' PBTD = 10,631' 02 -21 -1961 H3 10,592' 10,600' 8' Re -perf 10 -16 -1985 MAX HOLE ANGLE = 3° @ 7,004' 02 -21 -1961 H3 10,600' 10,603' 3' Sqzd 10 -16 -1985 02 -21 -1961 H3 10,608' 10,616' 8' Sqzd 10 -16 -1985 02 -21 -1961 H3 10,622' 10,631' 9' Sqzd 10 -16 -1985 02 -21 -1961 H4/5 10,622' 10,678' 56' Sqzd 10 -16 -1985 02 -20 -1961 WSO 10,681' 10,682' 1' Sqzd 10 -16 -1985 SCU 32- 08_Actual_WBD_10- 20- 11.docx Updated by MGB 11 -03 -2011 • Chevron IWO Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UW ChevNo Original RKB (ft) Water Depth (ft) SCU 32 -08 SOLDOTNA CK UNIT 32 -08 FEDA028996 5013310118 QA5262 143.00 Jobs • • Primary Job Type Job Category Objective Actual Start Date Actual End Date Clean -Out Major Rig 10/7/2011 Work Over (MRWO) Primary Wellbore Affected Wellbore UW1 Well Permit Number SCU 32 -08 501331011800 1600450 Dam: eons . • .: • 10/7/2011 00:00 - 1018/2011 00:00 Operations Summary MIRU Key Energy Rig # 3. Strip Rattigans on well head and test 500 psi. Unseat pump, hot oil treat the rod string and POOH & rack back tapered rod string and pump assembly with dip tube. Prepare to NU BOPE. Notify AOGCC and BLM of upcoming BOPE test. 10/812011 00:00 - 10/912011 00:00 Operations Summary NU BOPE while mixing 6% KCI. Test BOPE to 250psi low/ 3,000psi high. Witness waived by ( Jim Regg AOGCC & Justin Miller BLM). PUMU landing joint into surface hanger and attempt to release same, no joy. 10/9/2011 00:00.10/10/2011 00:00 Operations Summary Continue working surface hanger to release tension hanger; no joy. RU Eline. PUMU 1- 7/16" tool string w/ CCL & 6' tubing punch gun, RIH and punch holes from 10,064' - 10,070', POOH all shots fired. MU 1- 11/16" radial torch and RIH to 10,057' ELM, fire cutter and POOH & rig down e-line. MU landing joint and pull hanger to floor, break out same. Pump sized salt pill and circulate well over to 6% KCI. POOH with 2 -7/8" production tubing to 680' 10110/2011 00:00 - 10111/2011 00:00 Operations Summary Continue to POOH from 8,467' with cut 2 -7/8" production tubing. PUMU 4 -1/8" short catch overshot w/5 -5/8" scoop guide & RIH on 3 -1/2" work string to 2,522' 10/11/2011 00:00 - 10/12/2011 00:00 Operations Summary Continue to RIH from 2,522' to 9,990' and engage fish. POOH and recover 2 -7/8" production tubing and top half of Baker on -off tool. PUMU 4 -5/8" short catch overshot, 4 -3/4" bumper sub and RIH on 3 -1/2" work string to 1,726' 10112/2011 00:00 - 10113/2011 00:00 Operations Summary Continue to RIH to 10,284', engage fish and recover same. POOH to surface, LD fishing BHA and fish. PUMU 5- 13/16" packer plucker milling assembly and RIH on 3 -1/2" work string. 10113/2011 00:00 - 10/1412011 00:00 Operations Summary Continue to RIH to 10,293', mill packer to 10,296' and chase to 10,331', POOH with packer remains and LD milling assembly and milling BHA 10/14/2011 05:30 - 10/1512011 00:00 Operations Summary Continue to LD packer milling BHA. PUMU clean out BHA 5 -1/2" 3 blade junk mill with jars, collars, scrapper & circ sub & RIH on 3 -1/2" work string to 10,570'. work tools to 10,580'. MIRU ElinePUMU logging tool string 1- 11/16" tools w/ gamma ray, CCL 1011842011 00:00 - 10/1812011 00:00 Operations Sunmary RIH with logging tools to 10,362', log to 9,300' POOH. RD Eline. Reverse circulate the hole to Jet 'A' and POOH with 3 -1/2" work string. MIRU Eline PUMU 1- 11/16" logging tool string with gamma ray CCL, RIH to 10,567' & log to 9,500', POOH. Notify AOGCC & BLM of upcomming BOPE test. 101161201100:00 - 10117/2011 00:00 Operations Sunman/ _ Test RC PF re, 9Fnpei tnw/ 3 OOOpsi high, test annular to 250psi low/ 2,500psi high, (witness waived by Chuck Scheve AOGCC & Tom Zelenka BLM) PUMU 4 -5/8" TCP gun assembly 5spf 60 Degree phased and RIH on 3 -1/2" work string to 10,581', MIRU Eline & RIH to 10,199.5' w /1- 11/16" tool string & log on depth with gamma ray CCI, no adjustment necessary, POOH with e-line tools from 9,500'. Top shot 10,376' bottom shot 10,566', rig up drop bar lubricator. 10/1712011 00:00 - 10/18/2011 00:00 Operations Summary Fill back side w/ Jet 'A' and spot solvent at ported sub, set packer and drop firing bar. Positive indication of shots fired. Release packer and POOH from 10,580', LD packer and 4 -5/8" gun assembly. (all shots fired). PUMU lower completion assembly consisting of 4 -1/2" blank pipe, screens, chemical injection sub, seating cup nipple 1011812011 00:00 - 10119/2011 00:00 Operations Summary RIH on 2 -7/8" production tubing to TIW Tension set auto jay hanger, MU same, thread through and splice the chemical injection line and RIH clamping chemical injection line on 2 -7/8" tubing to 10,525', MU surface hanger and landing joint, terminate chemical injection line. RIH and land parent bowl run in lock down screw. 10/19/2011 00:00 - 10120/2011 00:00 Operations Summary Land tubing @ 10,533' & lock 25K#'s over tubing weight into surface hanger. ND BOPE, NU tree and test void 250 low 5000 high good test. PUMU rod pump and RIH on tapered rod string to 10,390' • • Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UW ChevNo Original RKB (ft) Water Depth (ft) SCU 32 -08 SOLDOTNA CK UNIT 32 -08 FEDA028996 5013310118 QA5262 143.00 1012012011 00:00 - 1012112011 00:00 Operations Summary Space out for polish rod, MU flapper valve and stuffing box, fill tubing with 20 Bbls of Jet 'A' and test tubing by stroking the rod pump to 500 psi for 30 minutes, good test. Rig down and move off location. • • S [E LI ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of California /60 — b 4 P.O. Box 196247 Anchorage, AK 99519 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 32 -08 Sundry Number: 311 -278 Dear Mr. Brandenburg: , E1 2,01t Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, -0 7/ Daniel T. Seamount, Jr. Chair DATED this v day of September, 2011. Encl. WC III civik c itilLRECERY" . El ' STATE OF ALASKA , 1 I SEP 0 9 2011 _.e ALASKA OIL AND GAS CONSERVATION COMMISSION 6 1'1 f /� -// APPLICATION FOR SUNDRY APPROVALS Alaska Oil & Gas Gons. Com►rnssron 20 AAC 25.280 1. Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Change pproved Program❑ Suspend❑ Plug Perforations Perforate 0 • Pull Tubing El - Time Extension❑ Operations Shutdown❑ Re -enter Susp. Well ❑ Stimulate El - Alter Casing Other: tertAc rod. ( >Kwap . El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: W(rk Union Oil Company of California Development 0 Exploratory ❑ 160 -045 - 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P.O.Box 196247, Anchorage, Alaska 99519 50- 133 - 10118 -00 - I 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 Soldotna Creek Unit (SCU) 32 -08 - 9. Property Designation (Lease Number): 10. Field / Pool(s): FEDA028996 (Swanson River Facility) - Swanson River Field / Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,828 - 10,824 - 10,598 10,594 N/A 10,598' (Fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13 -3/8" 3,014' 3,013' 2,730psi 1,130psi Intermediate Production 10,828' 6 -5/8" 10,828' 10,824' 7,440psi 5,760psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7 l 10,516'- 10,532', 10,543'- 10,512'- 10,528', 10,539'- 10,572', 10,585'- 10,600' _10,568', 10,581'- 10,596' 2-7/8" N -80 10,300' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Model D packer and N/A 10,300' MD / 10,296' TVD and N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Development 0 - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: /13/ 11 Oil 0 - Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: - Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marcus Barbee Phone 263 -7605 Printed Name 2 /' Timothy C. Brandenburg Title Drilling Manager Ii Signature ,/t , ', ! A Phone 276 -7600 Date 9/6/2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 1 1 t ! sC) 1 Plug Integrity BOP Test Nt Mechanical Integrity Test ❑ Location Clearance ❑ Other: T. S \ ok k,.vt- vt.. R ✓ B O I7 r" +-0 i so O f 1-4. ; teSt V R w A . o t 9 fo 0 0O p c.z . Subsequent Form Required: I 0 — y 04. APPROVED BY 2 r Approved bye , COMMISSIONER THE COMMISSION Date f i ) Form 10-403 Revised 1/2010 RBDMS SEP 14 R 1 / "� t p t tl .,, � A 1 A L Submit in Duplicate Chevron • • Soldotna Creek Unit %O. Well# SCU 32 -08 9/9/2011 OBJECTIVE: Pull existing completion, clean out fill to +/- 10,631', spot solvent treatment across perforated interval, re- perforate all existing open perforations, re- complete with new rod pump, screens, and chemical injection below the pump. Current BHP: 2,000 psi @ 10,500' TVD Max Downhole,Pressure: 2,000 psi @ 10,500' TVD (Based pressure temperature survey Sept. 2009) MASP: MASP:( ((Based on actual reservoir conditions and water cut of 50% (0.385psi /ft) with added Safety Factor of 1000' TVD of it cap) 2 o 0 o - t 050 = ql c c, o SR VJGA- PROCEDURE SUMMARY: 1 Prep location and pad, de- couple and roll back Rotaflex pumping unit & LOTO same. 2 MIRU Key Energy Rig # 3. 3 Strip rod surface equipment off well, NU rod BOPE, test same to 500 psi. -- 4 Lay down polislrod and Unseat rod pump. 5 Pull EL rods and pump assembly. 6 Install BPV, ND rod BOPE & Tree, NU BOPE & test same to 250 psi low/ 3, 00 psi high, test annular to 250 psi low/ 1,500 high./ 7 Pull production tubing, POOH and lay down same. 8 Mill production packer at 10,300' and recover same. 9 Fill Clean Out (FCO) sand to +/- 10,631' or to refusal. 10 Circulate hole to Jet 'A', spot chemical treatment across zone and TCP all perforations as depicted in proposed f schematic. 11 Run production tubing, landed in tension between the tension hanger @ +- 10,321' and the surface hanger. 12 ND BOPE / NU Tree & test; NU Rod BOPE & test. 13 PU rod pump, RIH on tapered rod string, land the pump, space out the rods, install the polish rod. 14 ND rod BOPE, strip surface equipment onto well and test. 15 RDMOL Key Energy Rig # 3. / 16 Roll up Rotaflex pumping unit, Re- couple same. 17 Return the well to production. SCU 32 -08 REVISED BY: TDF 09 -09 -2011 • •wanson River Field = . Chevron 9 -06 -09 API# 50- 133 - 10118 -00 CASING AND TUBING DETAIL RKB: 143'/ GL: 128' AMSL SIZE WT GRADE CONN ID TOP BTM. New KB — THF: 15.00' 22" - - - - Surface 28' 0 - L 54.5 J -55 8RD 12.615" Surface 1,308' 0 13 -3/8" DV Collar 12.615" 1,308' 1,310' R 54.5 J -55 8RD 12.615" 1,310' 3,014' ® 28 P -110 8RD 5.791" Surface 115' ° 24 N -80 BTC 5.921" 115' 6,477' B 6 -5/8" 24 P -110 8RD 5.921" 6,477' 7,996' DV Collar 5.921" 7,996' 7,998' L. 24 P -110 8RD 5.921" 7,998' 10,037' Q 28 P -110 8RD 5.791" 10,037' 10,828' Tubing 2 -7/8" 6.4 N -80 IBT 2.441" Surface 10,300' D JEWELRY DETAIL NO. Depth Length ID OD Item © > -- 1 15.0' 5.23' 2.441" - Seaboard International Tension Hange; 7" Modified © i 2 10,074' 1.09' 2.280" 3.062" Cup Type Seating Nipple, 2 -7/8" w/ XO's to Butt 3 10,075' 8.08' 2.992" 3.500" Ported Sub Crossover, 3 -1/2 ", 9.2 #, Butt P x 2 -7/8" Buttress Box " 4 10,083' 4.04' 2.992" 3.500" Pup Joint, 4' x 3 -1/2 ", 9.2 #, N -80, Butt Ili 5 10,087' 1.17' 2.992" 3.500" Ported Sub, 3 -1/2 ", 9.2 #, Butt BxP te © • © 6 10,088' 186.32' 2.992" 3.500" 6 Joints of 3 -1/2 ", 9.2 #, L -80, Butt tbg > _ _ 7 10,275' 1.48' 2.441" 4.250" XO, 3 - 1/2" x 2 - 7/8" © > 0 8 10,276' 10.01' 2.441" 2.875" Pup Joint, 10' x 2 -7/8 ", 6.4 #, N -80, Butt 9 10,286' 1.12' 2.188" 3.500" Otis "R" Profile ni r Ile, 2.188" w/ Butt BxP w/ Pity 0 > 6 10 10,287' 10.73' 2.312" 3.500" Ported Sub, Baker On/Off tool, Ported Collar 11 10,298' 1.58' 2.400" 3.430" Baker Model "E" Anchor Latch w/o seals El > F © 12 10,300' 2.78' 3.250" 5.468" Baker Model "D ", 82 -32, Perm Packer 9 > ROD DETAIL `� c 10 NO. Depth Length ID OD Item A 23.21' 40.35' 1.500" Polish Rod m > B 55.00' 2,525' 1.000" 1" EL Sucker Rod, w/ Slimhole Class T coupling w/ (3) 2.25" R &M 2.025" Stealth XL AF Rod Guides per rod (101 rods) C 2,580' 3,325' 0.875" 7/8" EL Sucker Rod, w/ Slimhole Class T coupling w/ (3) 2.25" R &M nt 1.812" Stealth XL AF Rod Guides per rod (133 rods) 12 D 5,905' 4,125' 0.750" 3/4" EL Sucker Rod, w/ Slimhole Class T coupling w/ 2.25" R &M E 1.625" Stealth XL AF Rod Guides per rod (165 rods) t E 10,030' 2.50' - 1.000" 30" stabilizer bar w/ collar 1.625" F 10,033' 40.92' - 2.150" 1 -3/4" RXBC Dbl valve Pump w/ Dual Seating Cups w/ Stabilizer . 2.340" Bar. G 10,074' 62.55' 1.28" 1.660" 1 -1/4" (1.660" OD) 1 -1/4" NPT Pin x 1.66 BTS -8 Box crossover to bull nose tubing w/ botttom 6' perfed (72 - 3/8" holes) Hr PERFORATION HISTORY Interval lil H2 Date Zone Top Btm Amt Comments 2/20/1961 WSO 10,496' 10,497' 1' SQZD 10 /12/85 10/16/1985 Hl 10,516' 10,518' 2' Re -pelf 8 /18/01 H3 10/16/1985 H1 10,518' 10,520' 2' Re -perf 8/1 8/01; 10/02/04 roF ros9s 2/21/1961 H1 10,520' 10,529' 9' Re -pelf 10 /16/85; 6/10/95;8 /18/01;10/02/04 9/05/09 2/21/1961 H1 10,529' 10,530' 1' Re.perf 10 /16/85 a ii 10/16/1985 HI 10,530' 10,532' 2' H4&5 8/18/2001 H2 10,543' 10,545' 2' 3 10/16/1985 H2 10,545' 10,546' 1' Re -pelf 8 /18/01 a3 6/10/1995 H2 10,546' 10,550' 4' Re -perf 10/16/85; 8/18/01; 10/02/04 2/21/1961 H2 10,550' 10,560' 10' Re -pelf 10/16/85; 6/10/95; 8/18/01; 10/02/04 2/21/1961 H2 10,560' 10,569' 9' Re -pelf 10/16/85; 6/10/95; 8/18/01; AIL 2/21/1961 H2 10,569' 10,572' 3' Re -pelf 10 /16/85 2/21/1961 H2 10,572' 10,575' 3' SQZD10 /12/85 TD = 10,828' PBTD = 10,631' 2/21/1961 H3 10,580' 10,584' 4' SQZD 10/12/85 MAX HOLE ANGLE = 3° *7,004' 10/16/1985 H3 10,585' 10,592' 7' 2/21/1961 H3 10,592' 10,600' 8' Re -pelf 10 /16/85 2/21/1961 H3 10,600' 10,603' 3' SQZD 10 /12/85 2/21/1961 H3 10,608' 10,616' 8' SQZD 10/12/85 2/21/1961 H4 &5 10,622' 10,678' 56' SQZD 10 /12/85 2/20/1961 WSO 10,681' 10,682' 1' SQZD 10 /12/85 SCU 32 -08 FINAL - Actual Well Schematic 9- 06- 09.doc Updated by STP 4 -12 -11 + • •wanson River Field SCU 32 -08 / PTD 160 -045 I= Chevron Proposed Completion 09 -06 -2011 / API# 50- 133 - 10118 -00 -00 Casine and Tubing Detail SIZE I WT GRADE CONN ID TOP BTM. RKB: 143'/ GL: 128' AMSL Casing New KB - THF: 15.00' 22" - - - - Surface 28' J A 54.5 J -55 8RD 12.615" Surface 1,308' ' �G 13 3/8" DV Collar 12.615" 1,308' 1,310' II 54.5 J-55 8RD 12.615" 1,310' 3,014' B 28 P -110 8RD 5.791" Surface 115' 1 24 N -80 BTC 5.921" 115' 6,477' g 24 P -110 8RD 5.921" 6,477' 7,996' I Ill 1 2 6 -5/8" DV Collar 5.921" 7,996' 7,998' 24 P -110 8RD 5.921" 7,998' 10,037' ` �.∎ 28 P -110 8RD 5.791" 10,037' 10,828' Tubing 2 -7/8" 16.4 I N -80 I IBT I 2.441" I Surface 10 463' 1 Jewelry Detail No. Depth Length ID OD Item p g 1 C 1 ±15.0' 5.23' 2.441" Seaboard International Tension Hanger, 7" Modified 2 ±3,000' _ 1.09' 2.441" 5.5" Depth Indicator Sub I 3 ±10,321' 15' 2.441" 5.75" TIW auto jay tension set hangar assembly 4 ±10,450' 1.05' 2.313 3.062 Cup Type Seating Nipple, 2 -7/8 w/ XO's to Butt 5 ±10,451' 4.1' 2.441" 4.335" Chemical Injection Sub 6 ±10,456' 40' 3.476" 4.40" 0.080 Mesh Screen 1 7 ±10,498' 60' 3.958" 4.5" Blank Pipe II 8 ±10,558' 1' 0 5.125" Bull Plug Rod Detail A ± -13' 40' 0 1 -1/2" Polish Rod 111 B ±2,805' 2,750' 0 1 "/2" (110) 1" EL Rods, 3 XL guides per rod 1 C ±6,356' 3,500' 0 .875"/1.81" (142) 7/8" EL Rods, 3 XL guides per rod D D ±10,407' 4,050' 0 .75 "/1.625" (162) 3/4" EL Rods, 3 XL guides per rod E ±10,412' 40' 0 2 -1/2" 25 -175 RHBC 36' X36 -1/2" X 37' Rod pump ! ±10,449' 40' 0 2.312" Seating Cup G I', ±10,513' 60' 1.26" 1.66" 1.66" Perf Pipe Perforation History Date Zone Top Btm Amt Comments 3 02 -20 -1961 WSO 10,496' 10,497' 1' Squeezed 10-12 -1985 10 -16 -1985 H1 10,516' 10,518' 2' Re- perf08 -18- 01/2011 4_ I F 10 -16 -1985 H1 10,518' 10,520' 2' Re -perf 08 -18 -01 / 10 -02 -2004 / 2011 5 T' r 02 -21 -1961 Hl 10,520' 10,529 9' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 / 10 -02 -2004 / 2011 02 -21 -1961 H1 10,529' 10,530' 1' Re -perf 10 -16 -1985 / 2011 G 10 -16 -1985 H1 10,530' 10,532' 2 Re- perf2011 6 08 -18 -2001 H2 10,543' 10,545' 2' Re- perf2011 10 -16 -1985 H2 10,545' 10,546' 1' Re -perf 08 -18 -01 7 i i 06 -10 -1995 H2 10,546' 10,550' 4' Re -perf 10 -16 -1985 / 08 -18 -2001 / 10 -02 -2004 / 2011 - 02 -21 -1961 H2 10,550' 10,560' 10' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 / 10 -02 -2004 / 2011 T 02 -21 -1961 H2 10,560' 10,569' 9' Re -perf 10 -16 -1985 / 06 -10 -1995 / 08 -18 -2001 / 2011 PBTD + - 10,631' 02 -21 -1961 H2 10,569' 10,572' 3' Re -perf 10 -16 -1985 / 2011 o 02 -21 -1961 H2 10,572' 10,575' 3' Sqzd 10 -16 -1985 / re -perf 2011 v 02 -21 -1961 H3 10,580' 10,584' 4' Sqzd 10 -16 -1985 / re -perf 2011 e 10 -16 -1985 H3 10,585' 10,592' 7' re -perf 2011 02 -21 -1961 H3 10,592' 10,600' 8' Re -perf 10 -16 -1985 / 2011 02 -21 -1961 H3 10,600' 10,603' 3' Sqzd 10 -16 -1985 / re -perf 2011 A = 10,828' = 10,631' 02 -21 -1961 H3 10,608' 10,616' 8' Sqzd 10 -16 -1985 / re -perf 2011 MAX HOLE ANGLE LE = = 3° *7,004 02 -21 -1961 H3 10,622' 10,631' 9' Sqzd 10-16-1985 / re-perf 2011 02 -21 -1961 H4/5 10,622' 10,678' 56' Sqzd 10 -16 -1985 02 -20 -1961 WSO 10,681' 10,682' 1' Sqzd 10 -16 -1985 SCU 32- 08_FINALProposed Well Schematic_2011- 09- 06.docm Updated by TDF 09 -09 -2011 0 Chet/ Ofl Swanson Rive r SCU 32 -08 IWO 04/06/2011 SCU 32 -08 BOP Dimensions Knight Oil Tools Stack 1.50' estimated for stripper head iii ii ia! III "ft J 0 0 3.96' 1 Hydril GK 11 -5000 III Ill Ill Ili III I 111 111 111 111 III 14.92' above grade Na° CIW -U = 4.54' _■IIIEMEI 0 Ill : . . P ■= allIIM iii III film 111 NM 1 _ 1119Uf1II'III III 2.00' �: .. , . LL: 1.74 (0 .1 ., III Ill Ill Iii al 1.00' ill 111 Xover spool 11 5M X 111 111 III 7 1/16" 5M NM IN III 1117111 111 I i 3.00' Spacer spool 7 1/16 5M X 7 1/16 5M III III Mill III STATE OFALASKA ALAS~IL AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS v.EGI~ 4~Z;lZDO~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Rod pump Recomplete Performed: Alter Casing ^ Pull Tubing ^~ ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Expioratory ^ 160-045 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic^ Service ^ 6. API Number: 2~ n/~~~~ b"~~~7< 50-1 33-1 01 1 8-90_~ ~ _ 8. Property Designation (Lease Number): 9. Well Name and Number: . ::: ' FEDA028996 [Swanson River Facility] ~ Soldotna CK Unit (SCU) 32-08 ~ 10. Field/Pool(s): , Swanson River Field/ Hemlock Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,828 feet Plugs (measured) N/A feet true vertical 10,824 feet Junk (measured) 10,598 (fill) feet Effective Depth measured 10,598 feet Packer (measured) 10,300 feet true vertical 10,594 feet (true vertical) 10,296 feet Casing Length Size ~ MD ~ ND Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 5,380 psi 2,670 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation depth: Measured depth: 10,506'-10,532', 10,545'-10,572', 10,576'-10,580', 10,585'-10,600', 10,603'-10,611', 10,617'-10,676' Tnie Vertical depth: 10,502'-10,528', 10,541'-10,568', 10,572'-10,576', 10,581'-10,596', 10,599'-10,607', 10,613'-70,672' Tubing (size, grade, measured and true vertical depth): 2-7/8" 6.4# L-80 10,300' MD 10,296' ND Packers and SSSV (type, measured and true vertical depth): ~Baker Model D 82-32 Perm Packer / N/A ~0;300' MD 10,296' ND N/A i ~ 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ;r';+t ' ' : , ; ,~ - , < N/A Treatment descriptions inGuding volumes used and finai pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 200 psi 120 psi Subsequent to operation: 114 48 119 205 psi 200 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development Q Service ^ Daily Report of Well Operations X 76. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPIUG ^ 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: 309-28rr- yQ 3 V-~~l~- Contact Mike Quick 263-7900 Printed Name Timothy C. Brandenburg Title Drilling Manager ''~---~---'''~~~ ,- " I,,% ~ ' C y Signature ':~~ Phone 276-7600 Date 9/22/09 ~..~.- ~ Form 10-404 Revised 7/2009 '"~~~~~~~`~" ~~~ ~~ Y ~~' ' r~~ Submit Original Only ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal We~l Name Lease Su~face UWI ChevNo Original RKB (ft) Water Depth (ft) SCU 32-08 SOLDOTNA CK UNIT 32-08 FEDA028996 5013310118 QA5262 143.00 Jot~ T'~' ' ~ a`~ ~, Primary JobType Job Category Objective Actual Start Date Actual End Date Pump Repair Major Rig 9/2/2009 9/7/2009 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number SCU 32-08 5013310118-00 1600450 t ~ ,.. H,. , ~ ~ ~ ,r ~, ~ ;~~ ~~` u an~ ~ % ` ~ rw ~,~rir.. ~s ~ k ~ ~ ~ ~ r. . ~;.,,~. ~ $1~f2008 00:00 - 9/3/2Q4~ 00:00 ~ ~ w,;, . „ < . ~~ ;.., ~ ,~, ~ Operations Summary Pump 50 bbl chemical treatment down annulus. MI/RU Key Energy Rig #3. Pump KCL down tubing, Strip off polish rod and surface equipment, install rod BOPE and test to 500 psi. POOH with 1" rods. 9/3f2009 ~00 - 9f412009 00:00 , ";il Operations Summary Finish POOH with Rods - recovered 101- 1", 133- 7/8", 60- 3/4" rods - 103 - 3/4" rods left in hole. TOF @ 735Q'. FtIH with overshot, working through parafin. Engage fish, Could not unseat pump, back off rods, POOH. Left an additional 60- 3/4" rods in hole, TOF @ 5850'. RIH with tubing punch, tag TOF at 5,894', fire at 5878', POOH. N/D Tree, Start to N/U BOPE. BLM & AOGCC's Jim Regg waived BOP test witness. ~ 9/4/2009 OOc00 - 9lSI2008 00:00 -' Operations Summary Complete N/U BOPE, change rams to 2-7/8, test BOPE to 250 psi low / 3000 psi high, test Koomey system - good. Pump 10 bbls water down tubing, release tubing hanger, POOH with 2-7/8" tubing to rods. Rods backed off, POOH w/ 15 - 3/4" rods. POOH w/ 6 stands tubing wet, pull 22 - 3/4" rods. Spot Wireline unit and rig up. 9/5l2009 OO:OQ`- 9!6l2009 00:00 ' ' ° _- , Operations Summary RIH and perforate tubing from 3,714'3,711', POOH and R/D wireline. POOH with 2-7/8" tubing, lay down completion equipment. R/U slickline, tag bottom at 10598'. M/U and RIH with rod pump completion on 2-7/8" 6.4# L-80 tubing to 10,300'. Space out and land hanger with 24000 # tension. Test hanger and mandrel seals to 3000 psi - good. N/D BOPE, N/U tree and test to 250 psi low / 5000 psi high for 30 minutes - good. Prep rods to RIH. ~ 9/6/2009 00:OE~,i 9~f2009 00:00 Operations Summary RIH with rod pump assembly on tapered rod string, space out and seat pump. Fill tubing with water, pressure test pump and tubing to 1000 psi for 30 min - good. Rig down, rig release at 1800 hrs. ~ ~ Swanson River Field ~ N O~A ~ 76 Soldotna Creek Unit Well SCU 32-8 API# 50-133-10118-00 CTUAL COMPLETION Original 2/22/61 Converted to Rod Pump on 8/16/O1 Tbg reran on 10/6/04 Rods reran w/ new pump on 9/2/09 RKB =22.IY C a s i n & T u b i n Size Wt Grade ID To Btm 2Y' Surf 28' 13-3/8" 54.5 12.615 Surf 3014' 6-5/8" 28 P-110 5.791 Surf I l5' $ o 6-5/8" 24 N-80 $.921 115' 647T ~ o. 6-5/8" 24 P-l 10 5.921 647T 10,037' ~~ 6-5/8" 28 P-110 5.791 10,03T 1Q828' ~ o Tubin 2-7l8" 6.4 N-80 2.441 Surf 1Q300' _Inwvl rv NO. Depth Top Btrn Le~glh ID OD n~ 75.00' 20.23' S.23' 2441 - Seaboard IMernational Tension Hanger 23.21' 63.55 40.35' - 1.500 Pbfsh Rod A 55' 2,580 2,525.00' - ~ 0 2.025 1" EL Sucker Rod, w/SimholeGass Toouqirg w/(3) 2.25" R8N1 Stealth XL AF Rod Gudes per rod (101 rods) 2,580' S,905 3,325.00' - 88 1.812 ~~8' ELSucker Imd, N/ Slimhole Class T coupling ~r/ (3) 225' R&M Stealth XL AF Rod Guides per rod (133 ~ods) 5,905 10,IXi0' 4,125.00' - 75 1.625 y4" ELSuCker Rod, H/ Slimhole Class T coupling W 225' R$~M SOe211h XL AF Rod Gudes per rod (165 rods) 10,030' 10,IXi3' 250' - 1.0 1~5 30" siabil¢er barvJ cdlar B 10,033' 10, 074' 40.92' - 2~ 1-3~4" RXBC Dbl valve Rmp w/ Dual Seating Cups w/ Shabil¢er Bar. C 10,074' 10.135 6255' 1.28 1.665 1-1/4" (1.660" OD) 1-114" NPT Pin x 1.66 BTSB Bnu crossaver to bull nose tudng w/ boritom 6' perfed (72- 3/B' hdes) 1 10,074' 10,075 1.09' 2.28 3.062 Cup Type Sea6ng Nipple, 2-7/S"w/ Xdsto BuH 2 10,075' 10,083 8.08' 2992 3.500 PoRed SubCrossover, 3-1/T', 9.7l~, Butt Px 2-7/8" Buttress Booc 3 10,083' 10,OBT 4.04' 2992 3.500 PupJoir~, 4' x 31l2", 9.21t, NSO, Butt 4 10,OBT 10,086 1.17' 2992 3.500 PbRed Sub, 31/2", 9.2k, Butt ~cP 10,090' 10,095 Pddedtbg plnChes 5 10,088' 10, 275 186.32' 2992 3.500 6 Jarts d 31/7', 9.21~, L$0, Butt tbg 10,775' 10, 275 1.48' 2441 4.250 XO, 31/2' x 2 7Ig' 6 10,776' 10,285 10.Ot' 2441 2.875 PupJoiM, 10' x 2-7/8", 6.4#, N-80, Butt 7 10, 286' 10,287' 1.12' 2188 3.500 Otis "f7' Profile nipple, 2.188" wl Butt B~ wl Plug. 8 10,28T 10,298 10.73' 2312 3.500 PoRed Sub, Baker ONOIf tool, Ported Cdlar 10,291' 10,297 Mdedtbg ptnches 9 10, 298' 10,300' 1.58' 24 3.430 Baker Model "E" Anchor LaU~h w!o seals 10 10,300' 10, 307 2.78' 3.25 5.468 Baker Model "D", 82-32 Rerm Packer. ~ P P r f n r a t i n n c Zone To Btm Ft SPF Date Comments H1 10,506 10,516 10 4 1985 S z. H1 1Q516 IQ526 10 12 '70,'85,'95 , `04 Reperf in '04 w/ 2.5" PJ. H1 10,526 10,532 6 12 1985 Perf in '85 w/ 5" TCP H2 10,545 10,572 27 12 '70,'85, 04 Reperf in '04 w/ 2.5" PJ. H2 10,576 10,580' 4 4 1985 S z. H3 1Q585 1Q600 15 12 '70,'85 Reperf in '85 w/ 5" TCP H3 10,603 10,6ll 9 4 1985 S z H4&5 1Q617 10,676 59 4 1985 S z. TD=10,828' PBTD=10,631' MaxDeHabon= 3° SCU 32-8 Actual Schematic 9-22-09.doc Updated 9/22/09 CVK • ~ ~~~ ~ v4 ~~~1~ ~ ;~ x ~ ~ ~ ~ '~ g ~ , ~ ~ ~ ~ ~ ~ ~U~ ~ ~E~' `ti ~~~ ~~~ ~~ ~ ~~~ ~ ~ i r ~ ~-~ , ~ ~ h J~~ ~ A ~ ~' ~ f ~ ~ ~ ~ ~ ~ ~`~ ~ ~~~ ~ ~~ ~ ~ { . 3 ~ ~~` f ~ I, ~ 4 ~ ' 3 Y t y ~ ~ ~-', ~g Fp {; @ ~ ~ ~ ~ SEAN PARNELL, GOVERNOR ~ ~v.~u 1£<~ c,...~ `~..-~ ~, L-...=~..- y ,d §'_k ~~~. s.~ p F,_ i~ <..-,~~:s' ..~ F ~ t- ~ ~. ~ ,~ .. ~ „ ~9 ` k~ ~-7~ OIL tusJV Vrv~,7 ~ 333 W. 7th AVENUE, SUITE 100 C01~5~RQATIOi~T COMnIISSIOI~I ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. Tirnothy C. Brandenburg Driiiing Manager Union Oil Company of California F.O. Box 196247 ~ !J.'~ Anchorage, AK 99519 ~ ~~d~ Re: ~wanson River Field, Hemlock Oil Pool, Soldotna CK Unit (SCU) 32-08 Sundry Number: 309-293 4 '~ O~l~ :~~:.~~'~~~ ~Al~f~ ,~ ~ ~ Dear Mr. Brandenberg: 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) b59-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this d~;cision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application #~or re~earing. A request for rehearing is considered timely if it is received by 4:3Q PM on the 23rd day following the date of this letter, or the next working day ~#' the 23rd day falls on a holiday or weekend. A person may not appeal a Gommission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED thi~~day of August, 2009 Encl. . ~ ~ ~~T ~ S Y ~~ ~ ` ~~~ ~' STATE OF ALASKA ~ ~? j~ , ~~ ~ ALAS~IL AND GAS CONSERVATION COMMI~ON ~,~ ~, i~~,:;, ~~~ ~, b~° APPLICATION FOR SUNDRY APPROVALS ~" y ~ zs (tvo9 20 AAC 25.280 ~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other 0 Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Rod & pump Change approved program^ Pull Tubing^ Perforate IVew Pool ^ Re-enter Suspended Well ^ ~ changeout 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Exploratory ~ Development ~ 160-045 ~ 3. Address: , Stratigraphic ~ Service ~ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-10118-00 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 ~ Soldotna CK Unit (SCU) 32-08 ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): FEDA028996 [Swanson River Facility] 22.15' Swanson River Field/Hemlock Oil Pool ~ 2~ PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): -10,828 10,824 10,585 10,581 N/A 10,585' (fill) Casing Length Size MD % TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,014' 13-3/8" 3,014' 3,013' 5,380 psi 2,670 psi Intermediate Production 10,828' 6-5/8" 10,828' 10,824' 7,440 psi 5,760 psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4# N-80 10,300' Packers and SSSV Type: Packers and SSSV MD (ft): Baker Model D 82-32 Perm Packer / N/A 10,300' / N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development ~^ - Service ^ 15. Estimated Date for 09 ~~~! La~`~ ~' 16. Well Status after proposed work: Commencing Operations: Oil ^~ - Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Quick 263-7900 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~ Pho 276-7600 Date 8/19/2009 COMMISSION USE ONLY - ~~~ n f ~.~v C diti l N tif i i ti d b C th t t it S N / p on o s o approva : o y omm on so a represen ve may w .un ry um er: ss a a ness Plug Integrity ^ BOP Test [~ Mechanical Integrity Test ^ Location Clearance ^ Other. T~S~' R(~ ~~~' ~"O 3000 pS,i, . - or 2o A A-~ ZS . 2 85 ( G~.) ~ o„j-~~w w~.f e?30 PE v L a.~~01'~clt~. Subsequent Form Required: ( Q- 4~ 4• • APPROVED BY roved b A : COMMISSIONER THE COMMISSION Date: ~ Z~ l pp y j R r ~ ; ~ ~~~ ~ ~:: ~ ~ 77~5 Form 10-403 Revised 06/2006 ~,` ~/ Submit in Duplicate • ~ Chevron Timothy C Brandenburg Union Oil Company of California ~ Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 ~ Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com August 19, 2009 E~ ~.. Commissioner :~ Alaska Oil & Gas Conservation Commission 333 W. 7`h Avenue Anchorage, Alaska 99501 Re: Swanson River Workover Program Variance Request for SCU 32-08 Dear Commissioner, UOCC is requesting a variance of 20 AAC 25.285 (c) (9) and (10) for well service work in ,/ the Swanson River Field, for SCU 32-08. UOCC is currently performing well intervention work with a"well servicing unit" provided by Key Energy. Key Energy mobilized the workover unit here from the Rocky Mountain area. After reviewing the BOPE rig up and equipment as used in UOCC's last Swanson River workover campaign in 2004, we feel that the proposed system is fit for purpose in well control capabilities and mobility to other BOPE configurations for this well service work. This variance request was granted for the KGSF #1 workover on Sundry Number 309-221, and was successfu!!y utilized on this well intervention. As in this same configuration successfully used in 2004, UOCC is asking for a variance of the kill line and choke line configuration and the choke manifold equipment requirements. We consider the application of this and all BOP configurations to be a well bore specific concern and do not intend or desire to consider this as an area wide or unilaterally applied configuration. UOCC appreciates your consideration of this proposal and Iooks forward to discussing any questions with the proposed configuration as needed. Attached is a brief description of the well to be worked on, and the proposed BOP configuration and schematic. Please let us know if we can provide any further information by contacting myself at 263- 7657 or Evan Harness at 263-7932. Sincerely, , ~ ~ ~. Timothy'C. Brandenburg c=..-%'J Drilling Manager Attachments: Summary of Swanson River Workover Program, BOP diagram, Choke diagram Union Oil Company of California / A Chevron Company Chevron ~ • ~ ~ Summarv of Kev Enerqv Riq #3 Specifics SCU 32-08 Workover The SCU 32-08 workover is to pull the existing completion, fish and cleanout to the base of the Hemlock (or as deep as possible) and run a new completion. The rig specifics are for the planned rig up on this well and are likely to change from well to well. Proposed Confiauration Rig Model The rig model is a Hopper Hydra-hoist, Back-model GXXTA. Drawworks The drawworks are GXXTA-MD 10x42; w/ Sand Drum 15,000 ft- 9/16" sand line. Derrick The derrick is a telescoping double, with 260,000 Ib capacity, 30" crown sheaves and McKissick 30" 150 ton 73A traveling block. Pipe Handling The pipe handling system is a HydraWalk-hydraulic catwalk, 38' long, 5' wide, 5' high. The base beam is internally guided and load bearing. The beam is load rated with 102' derrick and 10,000 of 2- 7/8" tubing to 58 mph winds. BOP Specifications Annular, 5M 7-1/16" Shaffer , , ~~~ Double gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram and blind ram Mud Cross, 5M, 7-1/16" BOP Diagram See attached. Accumulator 140 gallon KOOMEY Accumulator System. Includes 5 functions with manual bypass and remote panel. Fourteen 11 gallon accumulators with four 11 Gallon Nitrogen Bottles for backup. 210 gallon hydraulic tank with air operated hydraulic pump. Pits The pit consists of a 200 bbl tank partitioned into three isolatable compartments. An optional shale shaker is also available that is a 3'x4' Jr. Standard-hydraulic driven. Pump The pump is a National JWS-400 7"x4.5" Triplex rated to 5,000 psi on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Key Energy Rig #3 Specs (SCU 32-08).doc 7/27/09 Chevron • ~ ~ ~ Kill Line Valves The kill line valves consist of 2 ea. manually operated, 2-1/16", 5M valves attached to the mud cross with co-fle~c-4~ose with a Unibolt/Hub-flanged connectors. Choke Line The choke line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Choke Line Valves The choke line valves consist of 1 ea. manually operated, 2-1/16" 5M valve and 1 ea. automatically operated HCR valve that is attached to the mud cross with co-flex hose with a UnibolUHub-flanged connectors. Choke Manifold See attached. Choke Return Line/Diffuser Line The diffuser line will consist of 2", 5,000 psi hose with Unibolt connections. The line will run from the choke manifold to the diffuser tank. Diffuser Tank A diffuser tank will be placed adjacent to the mud pits with the capability of fluid transfer to the circulating system. Gas Detection There is a single gas LEL monitor and a single H2S monitor be placed at the work platform; and a single gas LEL monitor and a single H2S monitor at the shale shaker if used. PVT There is no PVT system for the circulation system on this workover rig, as is standard practice in this type of well service work. Key Energy Rig #3 Specs (SCU 32-08).doc 7/27/09 Chevron ~ • Soldotna Creek Unit ~ Well # SCU 32-08 ~ 8/19/09 OBJECTIVE: • Pull/fish rod pump & rerun same. PROCEDURE SUMMARY: 1. De-couple and roll back Rotaflex pumping unit, MIRU Key Energy Rig #3. 2. Strip rod surtace equipment off well, NU rod BOPE, test same to 1,500psi & lay down polish rod. ~ 3. Pump chemical treatment to clean rods, Pull EL rods / lay down same. 4. Fish rods and pump assembly. 5. Contingency: (If unable to fish rods & pump): __ -•''"~ % a) Install BPV, ND tree, NU BOPE & test same 250psi low/ ~p0psi high, pull BPV. / b) PUMU landing joint, unseat mandrel from tension hanger, lower string to neutral & release anchor by working right hand torque to anchor. c) Pull 2-7/8" production tubing w/ unfished rods & pump and lay down same d) RIH w/ 2-7/8" production tubing, latch into packer @ 10,300', space out and land tubing in tension. e) Install BPV, ND BOPE, NU tree, test same, NU rod BOPE & test same, pull BPV. ~~ 6. Pump chemical treatment. 7. PU rod pump, RIH on tapered rod string, land the pump, space out the rods, install the polish rod. 8. ND rod BOPE and strip surface equipment onto welL 9. RDMOL, roll up Rotaflex pumping unit and Re-couple. 10. Return the well to production. SCU 32-08 Operation Summary.doc REVISED BY: CVK 8/19/09 ~ • U~ O~~ ~Q Swanson River Field 76 Soldotna Creek Unit Well SCU 32-8 API# 50-133-10118-00 CTUAL COMPLETION Original 2/22/61 Converted to Rod Pump on 8/16/O1 Tbg reran on 10/6/04 Rods reran w/ new pump on 5/22/OS RKB =22.15' C a s i n & T u b i n Size Wt Grade ID To Btm 22" Surf 28' 13-3/8" 54.5 12.615 Surf 3014' 6-5/8" 28 P-110 5.791 Surf 115' ~ g 6-5/8" 24 N-80 5.921 115' 647T ~ 0. 6-5/8" 24 P-I10 5.921 6477' 10,037' y~ 6-5/8" 28 P-110 5.791 10,03T 10,828' = o Tubin 2-7/8" 6.4 N-80 2.441 Surf 1Q300' .1 e w e i r v NO. Depth Top Btm Length ID OD ~~m 15.00' 20.23' 5.23' 2.441 - Seaboard Intemational Tension Hanger 23.21' 63.56' 40.35' --- 1.500 Polish Rod (spaced out 7' above stuffing box w/ pump 2.14' off btm). A 64' 2,591' 2,527.00' --- ~ 0 2.025 1" EL Sucker Rod, w/ Slimhde Class T couping w/ (3) 225' RB~M StealU AF Rod Guides per rod 2,591' S,972' 3,380.73' --- a8 1.812 7/8" EL Sucker Rod, w/ Slinhde Class T coupling w/ (3) 2.25" R8M St~ XL AF Rod Guides per rod 5,972' 9,758' 3,785.80' --- ~5 1.625 3/4" EL Sucker Rod, w/ SlinhdeClass T coupling w/ (12) 2.25' R&M Ste XL AF Rod Guides per rod 9,758' 10,033' 275.28' --- 75 ~,625 3/4" EL Sucker Rod, w/ Slinhde Class T cot~pling w/ (5) 2.25" R&M Stea XL AF Rod Guides er rod 10,033' 10,035' 2.~8' --- ~,625 30" stabiizer bar w/colar B 10,035' 10,074' 39.14' --- z~ 13/4" RXBC Dbl vaNe Pumpw/ Dual Seating Cups w/ Stabilizer Bar. C 10,074' 10,1 18' 44. 21' 1.28 1.665 1-1 /4" (1 .660" O D) 1-1 /4" NPT B x P w/ ported bull nose 1 10,074' 10,075' 1.09' 2.28 3.062 Cup Type Seatng Nipple, 2-7/8" w/ XO's to Butt 2 10,075' 10,083' 8.08' 2.992 3.500 Ported Sub Crossover, 3-1/2", 9.2#, Butt P x 2-7/8" Buttress Box 3 10,083' 10,087' 4.04' 2.992 3.500 Pup Joint, 4' x~1/2", 92#, N-80, Butt 4 1 0,087' 10,088' 1.17' 2.992 3.500 Ported Sub, 3-1/7', 9.2#, Butt BxP 1 0,090' 10,096' Added tbg punches 5 10,088' 10,275' 186.32' 2.992 3.500 6 Joints of 3-1 /2", 9.2#, L-80, Butt tbg 10,275' 10,276' 1.48' 2.441 4.250 XO, 3-1 /2" x 2-718" 6 10,276' 10,286' 10.01' 2.441 2.875 Pup Joint, 10' x 2-7/S", 6.4#, N 80, Butt 7 10,286' 10,287' 1.12' 2.188 3.500 Otis "R" Profile nipple, 2.188" wl Butt BxP wlPlug. 8 10,287' 10,298' 10.73' 2.312 3.500 Ported Sub, Baker OnlOfftool, Ported Collar 10,291' 10,297' Added tbg punches 9 ~~ ?ra• ~ .. . . ., ' . . , -- G~ -. i- ~>>irhor l.A1rh WIO 5@0~S 10 1 Q300' ~ 10.302' 7_ ?8' 3 25 5_46S Baker Moqel "D", 82-32, Perm Packer. P P r f n r a t i n n c Zone To Btm Ft SPF Date Comments H1 10,506 10,516 l0 4 1985 S z. H1 10,516 1Q526 l0 12 '70,'85,'95 , `04 Reperf in '04 w/ 2.5" PJ. H1 10,526 10,532 6 12 1985 Perf in '85 w/ 5" TCP H2 10,545 10,572 27 12 '70,'85, 04 Reperf in '04 w/ 2.5" PJ. H2 10,576 10,580' 4 4 1985 S z. H3 IQ585 10,600 15 12 '70,'85 Reperf in '85 w/ 5" TCP H3 10,603 10,611 9 4 1985 S z H4&5 10,617 10,676 59 4 1985 S z. TD=10,828' PBTD=10,631' Max De~ia6on= 3° SCU 32-8 Actual Schematic 8-19-09.doc Updated 8/19/09 CVK • • U~ O~~ ~Q Swanson River Field 76 Soldotna Creek Unit Well SCU 32-8 API# 50-133-10118-00 PROPOSED COMPLET[ON /` Original 2/22/61 Converted to Rod Pump on 8/16/O1 Tbg reran on 10/6/04 Rods reran w/ new pump on 5/22/OS RKB =22.15' C a s i n & T u b i n Size Wt Grade ID To Btm 22" Surf 28' 13-3/8" 54.5 12.615 Surf 3014' 6-5/8" 28 P-110 5.791 Surf I l5' ~g o 6-5/8" 24 N-80 5.921 I 1 S 647T ~ a 6-5/8" 24 P-l l0 5.921 647T 10,037' ~~ 6-5/8" 28 P-I10 5.791 10,03T 10,828' ,r s .I e w e I r v NO. Depth Top Btm Length ID OD Item 15.00' 20.23' 5.23' 2.441 - Seaboarcl Intemationai Tension Hanger 23.21' 63.56' 40.35' --- 1.500 Polish Rod (spaced out 7' above stuffing box w/ pump 2.14' off btm). A 64' 2,591' 2,527.00' --- ~ 0 2.025 1" EL Sucker Rai, w/ Slimhde CFass T couping w/ (3) 2.25" R&M StealU AF Rod Guides per rod 2,591' 5,972' 3,380.73' --- ~ 1.812 ~~g' EL Sucker Rod, w/ Slinhde Class T coupling w/ (3) 2.25" R&M Stea XL AF Rod Guides per rod 5,972' 9,758' 3,785.80' --- ~5 1.625 3/4"ELSuckerRod,w/SlinholeClassTcouplingw/(12)2.25'R&MSte XL AF Rod Guides per rod 9,758' 10,033' 275.28' --- 75 ~,625 3/4"ELSuckerRod,w/SlinhdeClassTcouplingw/(5)2.25"R&MStea XL AF Rod Guides er rod 10,033' 10,035' 2.08' --- 1.625 30"stabiizerbazw/colar B 10,035' 10,074' 39.14' --- 2~ 13/4" RXBC Dbl vaWe Pumpw/ Dual Seating GLps w/ Stabilizer Bar. C 10,074' 10,718' 44.21' 128 1.665 1-1/4" (1.660" OD) 1-1/4" NPT B x Pw/ ported twll nose 1 10,074' 10,075' 1.09' 2.28 3.062 Cup Type Seatng Nipple, 2-7/8" w/ XO's to Butt 2 10,075' 10,083' 8.08' 2.992 3.500 Ported Sub Gossover, 3-1/2", 92~F, Butt P x 2-7/8" Butt2ss Box 3 10,083' 10,087' 4.04' 2.992 3.500 Pup Joint, 4' x 31/2", 9.2#, N-80, Butt 4 10,087' 10,088' 1.17' 2.992 3.500 Ported Sub, 3-112", 9.2#, Butt BxP 10,090' 10,096' Added tbg punches 5 10,088' 10,275' 186.32' 2.992 3.500 6 Jointsof3-1/2", 9.2#, L-80, Butt tbg 10,275' 10,276' 1.48' 2.441 4.250 XO, 3-1/7' x 2-7/8" 6 10,276' 10,286' 10.01' 2.441 2.875 Pup Joint, 10' x 2-7/8", 6.4#, N~O, Butt 7 10,286' 10,287' 1.12' 2.188 3.500 Otis "R° Profile nipple, 2.188" wl Butf BxP wl Plug. 8 10,287' 10,298' 10.73' 2.312 3.500 Ported Sub, Baker On/Offtool, Ported ColYar 10,291' 10,297' Added tbg punches 9 10.298' 10,300' 1.58' 2.4 3 430 Baker Ma1ei "F" Anchor Latch wlo seals 10 10,300' 10,302' 2.78' 325 5.468 Baker Model "D", 82-32, Perm Packer. P e r f o r a t i o n s Zone To Btm Ft SPF Date Comments Hl 1Q506 10,516 10 4 1985 S z. Hl 10,516 10,526 10 12 '7Q'85,'95 , `04 Reperf in '04 w/ 2.5° PJ. H1 10,526 IQ532 6 12 1985 Perf in '85 w/ 5" TCP H2 10,545 IQ572 27 12 '70,'85, 04 Reperf in '04 w/ 2.5" PJ. H2 10,576 10,580' 4 4 1985 S z. H3 10,585 10,600 15 12 '70,'85 Reperf in '85 w/ 5" TCP H3 10,603 10,611 9 4 1985 S z H4&5 10,617 10,676 59 4 1985 S z. TD=10,828' PBTD= IQ631' Max Detia6on= 3° SCU 32-8 Proposed Schematic 8-19-09.doc Updated 8/19/09 CVK Chevron • BOP~Diagram ~ ~ SCU 32-08 Workover ~ 08/19/2009 Annular preventer, Shaffer, 7 1/16 5M Flanged 2.58' 6.16' I haffer Chasovoy 7 1/16 5 Plp@ R8m stdd X 7, ~1 ,5M stdd 1.75' (~n~) ~~~~ Blind Ram Mud Cross, 7 1/16 5M FE X 7 1/16 5M FE w/ 2 1/16 5M - X 3 1/8 5M EFO Kill line 2 1/16 5M Choke line 2 1/16 5M oo. o0 1.83' o '~' Lr'_ Unibolt ~ HCR Unibolt DSA 31/85MX21/165M Chevron ~ Swanson River ~ 2009 Workover Program ~ Rod BOPE 8/11/2009 Rod Plate for Landing Elevators Rod BOP, VBR 0"to 1" Rattigan FromPump /~ ~~~ 0 ~~~ ~~~ 0 To Choke ) :~ ~\ ßì~Uj~' ~'~'l:r,6) ) JUN 2 11. 2005 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 22.15' RKB 8. Property Designation: Swanson River Field 11. Present Well Condition Summary: Total Depth measured 10,828 feet true vertical 10,824 feet Effective Depth measured 10,585 feet true vertical 10,581 feet Casing Length Size Structural Conductor 28' 22" Surface 3014' 13-3/8" Intermediate Production 10828 6-5/8" Liner Perforation depth: Measured depth: 10,516' - 10,600' True Vertical depth: 10,512' - 10,596' Tubing: (size, grade, and measured depth) Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development [2] Stratigraphic D Stimulate U Other LJ Pulled and reran rods Waiver D Time Extension D and rod pump. Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 160-045 Service D 6. API Number: 50-133-1011800 9. Well Name and Number: SCU 32-08 10. Field/Pool(s): Hemlock Formation Plugs (measured) Junk (measured) 10585' MD TVD Burst Collapse 28' 28' 3014' 3013' 5380 psi 2670 psi 10828' 10824' 7440 psi 5760 psi SCANNEL JUN 2 1 2005 2-7/8", N-80 10,300' Packers and SSSV (type and measured depth) Rod pump well - Baker Model "0" 32-26 Perm Packer @ 10,300' 12. Stimulation or cement squeeze sumn N/A Intervals treated (measured): N/A 13. Treatment descriptions including volumes used and final pressurE N/A Oil-Bbl Prior to well operation: 0 pump siezed Subsequent to operation: 149 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 79 13 15. Well Class after proposed work: Exploratory n Development IJl 16. Well Status after proposed work: OilG] Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. x Contact Steve Tyler 263-7649 o 150 Service n GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: N/A prin::~~:: Ti;Y C_~bêÁ S;.--7 -~ Form 10-404 Revised 04/2004 Title Drilling Manager Date ?-,-I?--oS Phone 907-276-7600 RBDMS 8FL JUN 21 2005 (~'\\ r' i '""'., I' \ '" , ~~ , ........... Submit Original Only UNOCALe API # 50-133-10118-00 RKB =22.15' .J b. 4L ~ rn ~ ¡gl > ~ . . . I )a ,oj, ¡ :. .I .~ JIZ"ŒI4II ( IT] ) ŒJ ŒJ @] +----ill C 1 em 2 3 4 HI H2 H3 ~ TD= 10,828' PBTD= 10,631' Max Deviation = 3° SCD 32-8 Actual completion 05-05 ) ) Swanson River Field Soldotna Creek Unit Well SCU 32-8 Original 2/22/6] ACTUAL COMPLETION Casing & Tubing Size Wt Grade ID Top Btm 22" SUlf 28' 13 YH" 54.5 12.615 Surf 3014' 6 %" 28 P-II0 5.791 Surf 115' 1ì c: _ 0 6%" 24 N-80 5.921 115' 6477' ~ '¡;; - ~ 6%" 24 P-IlO 5.921 6477' 10,037' ~g~ 6%" 28 P-IlO 5.791 10,037' 10,828' ~...,.~ ~.s:S Tubing 2 }Ix" 6.4 N-80 2.441 Surf 10,300' NO. Jewelry Top Btm Length ID OD Item 15.00' 20.23' 5.23' 2.441 - Seaboard International Tension Hanger 23.21' 63.56' 40.35' - 1.500 Polish Rod (spaced out 7' above stuffing box wI pump 2.14' off btm). 64' 2,591' 2,527.00' - 1.0 1" EL Sucker Rod, wI Slim hole Class T coupling wI (3) 2.25" R&M StealH 2.025 AF Rod Guides per rod 2,591' 5,972' 3,380.73' - .88 7/8" EL Sucker Rod, wI Slim hole Class T coupling wI (3) 2.25" R&M Stea 1.812 XL AF Rod Guides per rod 5,972' 9,758' 3,785.80' - .75 3/4" EL Sucker Rod, wI Slim hole Class T coupling wI (12) 2.25" R&M Ste 1.625 XL AF Rod Guides per rod 9,758' 10,033' 275.28' - .75 3/4" EL Sucker Rod, wI Slimhole Class T coupling wI (5) 2.25" R&M Stea 1.625 XL AF Rod Guides per rod 10,033' 10,035' 2.08'- 1.0 30" stabilizer bar wI collar 1.625 10,035' 10,074' 39.14' - 2.15 1-3/4" RXBC Obi valve Pump wI Dual Seating Cups wI Stabilizer Bar. 2.34 10,074' 10,118' 44.21' 1.28 1.6651-1/4" (1.660" 00) 1-1/4" NPT B x P wI ported bull nose 10,074' 10,075' 1.09' 2.28 3.062 Cup Type Seating Nipple, 2-7/8" wI XO's to Butt 10,075' 10,083' 8.08' 2.992 3.500 Ported Sub Crossover, 3-1/2", 9.2#, Butt P x 2-7/8" Buttress Box 10,083' 10,087' 4.04' 2.992 3.500 Pup Joint, 4' x 3-1/2", 9.2#, N-80, Butt 10,087' 10,088' 1.17' 2.992 3.500 Ported Sub, 3-1/2", 9.2#, Butt BxP 10,090' 10,096' Added tbg punches 10,088' 10,275' 186.32' 2.992 3.500 6 Joints of 3-1/2",9.2#, L-80, Butt tbg 10,275' 10,276' 1.48' 2.441 4.250 XO, 3-1/2" x 2-7/8" 10,276' 10,286' 10.01' 2.441 2.875 Pup Joint, 10' x 2-7/8", 6.4#, N-80, Butt 10,286' 10,287' 1.12' 2.188 3.500 Otis "R" Profile nipple, 2.188" wI Butt BxP wI Plug. 10,287' 10,298' 10.73' 2.312 3.500 Ported Sub, Baker OnlOff tool, Ported Collar 10,291' 10,297' Added tbg punches 10,298' 10,300' 1.58' 2.4 3.430 Baker Model "E" Anchor Latch wlo seals A B 5 6 7 8 9 Zone Top HI 10,506 HI 10,516 HI 10,526 H2 10,545 H2 10,576 H3 10,585 H3 10,603 H4&5 10,617 Perforations Btm Ft SPF Date Comments 10,516 10 4 1985 Sqz. 10,526 10 12 '70,'85,'95 Reperf in '04 wi 2.5" , '04 PJ. 10,532 6 12 1985 Perf in '85 wi 5" TCP 10,572 27 12 '70, '85,04 Reperf in '04 wi 2.5" PJ. 10,580' 4 4 1985 Sqz. 10,600 15 12 '70,'85 Reperf in '85 wi 5" TCP 10,611 9 4 1985 Sqz 10,676 59 4 1985 Sqz. Actual 06/09/05 CRW , ., .:.:,:. . ... L':.:;(:';·.'·;·".'··;;:::::;'''.::·:::::.':·;'."J:j . :.~ : ...,'.:::.....: '. .... . . . ... ... . . . . . :.. : : ... . ..: ~,.,::'~~~:.~'~~ . ...... . , . .. .. . .. . . .. . . . . ... . . . ~ SCU 32-8 :..~::':: ·:':\::"'::'::'~>:I~~~~~~~'::'::u~:'I'~1~;~~;:;~~~::·::,".:L::<"I~~~~¿~~2';::::::';; :«I:,);~;1~2;i::~": ':1;;;';; "L':,;,: ...,~ r~: Primary Job Type I Primary Well bore Affected :~¡ .. ~. f:i Rod Repair Main Hole ~.i. o~o '0 ~¡ Jobs j ¡ill? 163501 AFE No, \TYlerlWalsh ac Eng t ~~~~'~'^~~~~ ¡~(DailY OperaÙ~·~s . n .. .. no. . n n on o. .~on 0 On 00." ~_ .0. on. ¡¡¡¡: 2/3/200500:00 - 2/4/200500:00 ¡~~: Operations Summary i, Trouble Shooting Well :0:.' ¡¡¡¡ 5/16/2005 00:00 - 5/17/200500:00 ~¡r Operations Summary ili~ SIMOPS. Remove flow line. Install stuffing box. Clamp off polish rod and remove bridle. Roll unit back. ~¡, 5/17/200500:00 - 5/18/200500:00 ¡¡¡¡Operations Summary ¡® SIMOPS with prod. PJSM. Stage pulling unit. :0.. §¡ 5/18/2005 00:00 - 5/19/2005 00:00 ¡~?: Operations Summary ~¡¡: SIMOPS with prod. Staging/ RU pulling unit. :~: 5/19/2005 00:00 - 5/20/2005 00:00 ¡~~ Operations Summary ~ RU to tubing and pump. Monitor fluid level in tubing. FL @ 4120'. Lay down polish rod. POOH with rods. LD pump and dip tube.. Inspect pump. RIH tag ¡¡~: seating nipple @ 10074 WLM. RIH and tag 10282 (4' of fill on R nipple plug). POOH. FL at 3400' WLM. ¡~~: 5/20/2005 00:00 - 5/21/2005 00:00 ~ Operations Summary ~¡ POOH with WL Bail fill. Latch onto prong in R nipple and pull prong out of plug. Tagged fill at 10585. Fill casing and tubing with lease oil. Pumped 135 bbls ¡f:' no returns on annulus. PT tubing to 1000psi and held. :;::-- ¡¡¡¡; 5/21/200500:00 - 5/22/200500:00 lOperations Summary ¡fTagged fill and collected sample. PU 6',1-9/16" 4 SPF tubing punch. Shot holes between on/off tool and tubing anchor (10291 -10297). RIH 6',1-9/16" 4 .. i: SPF tubing punch. Shot 10090 - 10096. Brush/scratch R nipple area. Set PR plug at 10286. Set P prong in PR plug. Perform injectivity test. 2 bpm with ~~ ~! tubing on vacuum. RU and pump 15 bbls of PAO-33 mixed with 15 bbls Xylene with 10 bbls diesel spacer. Displaced with 36 bbls crude oil. RIH with dip tube f ¡¡~: and new pump. RIH with rods. W: ~ ~ ~ 5/22/2005 00:00 - 5/23/2005 00:00 ~~ ¡~r Operations Summary ¡ ~i¡' Cont RIH with rods. PU/MU 40' long polish rod, work on space out. PU and stroke pump. Verify pump operational. MU pony rod to polish rod. Adjusted ~~ t~: spacing. RD. ¡* ~ ~ ¡ 6/6/200500:00 - 6/7/2005 00:00 ¡:~ ~~:Operations Summary m¡ ~~: Production bringing well on. ~1 ¡~: 6/7/200500:00 - 6/8/2005 00:00 j~ ¡t Operations Summary ~¡ ~ i i ~ ~ ~ t ¡ I I ~ ~ L~_---,,---_J ~~ ~ l I~ . ,. RECEI\/ED ^ P R 0 {) ') n l- h' . l' ,. {.. .J UNOCAL€Ø - Alaska Timothy C. Brandenburg Drilling Manager Unocal Alaska Tel 907.263.7657 Cell 907-3507920 Fax 907-263-7884 E-mail: brandenburgt@unocal.com Alaska Oil r.\i. G<1S COliS. COillillisSIOlf Anchorzge April 29, 2005 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. ylh Avenue Anchorage, Alaska 99501 Re: Request for Variance-Swanson River Mr. Aubert, We are requesting a variance of 20 MC 25.285 (c) (9) and (10). We are preparing to perform well intervention work with a "well servicing unit" provided by Nabors Alaska Drilling, currently stacked at Swanson River. We augmented the BOP equipment on the unit to satisfy our internal standards. Last year we worked with you to obtain a variance to work over several wells in the Swanson River field. We continue to believe the proposed system is superior in well control capabilities to BOPE configurations that are presently in use in the United States and Canada for wells with equivalent pressure and flow regimes. , bD -' 046 We are greatly appreciative of your consideration of this proposal and look forward to meeting with you to discuss any issues with the proposed configuration. Attached you will find a brief description of the wells to be worked on; the highest maximum anticipated surface pressure (MASP) and the proposed BOP configuration. Additionally you will find a schematic of the proposed BOPE layout. ~?el~. ~C ~ a Timothy ~4ndenbur~· / Drilling Manager Attachments ~ANNED NOV 1 7 2005 , . Union Oil Company of California / Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http://www.unocal.com ~ ~: Well Descriptions Well Work Inventory SCU 32-08 ,ltÐ- M5 SRU 23-15 SCU 22-04 SCU 314-04 S RU 14-15 SRU 12-15 Reservoir The highest BHP of any well to be worked on at this time is 3000 psi @ 10,900' TVD (Hemlock) which is equivalent to a .275 psi/ft gradient or a 5.29 ppg EMW. Fully evacuated, the MASP would be as follows: 3000 psi BHP - (10,900' TVD x .1 psi/ft Gas Gradient) = 1,91 Opsi MASP. Proposed Confiauration BOP's Annular,5K 7-1/16" or 11" Double gate, 5K, 7-1/16" or 11" Mud Cross, 7-1/16" and 11" (optional based on BOP height) Accumulator 1 - 90 gallon Bounty Accumulator System 9-10 gallon Barksdale Control Valves Marsh Gauges 1 - Pump, Union Pump Comp., Model #BIT-532-55 1 - Newman Electric Motor 4 - 11 Gallon Nitrogen Bottles Pits The pit consists of a 150 bbl tank partitioned into 50 bbl compartments. Pump The pump is an Western Roughrider 1000 Triplex on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line will consist of 2", 3000 psi Iron or 2", 5000 psi hoses with integral Fig 1502 hammer Unions. Kill Line Valves The kill line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16",5K valves attached to either the mud cross or the tubing spool annulus valve. Choke Line Valves The choke line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16". 5k valves that will be attached to either the outlet below the lower rams on the double gate or the mud cross. Choke Line The choke line will consist of 2",5,000 psi hoses with 2-1/16" 5m API Flange. Choke Manifold The choke manifold is 2-1/16", 5K with two manual chokes and four valves. Choke Return line/Gas Buster Line The gas buster line will consist of 2", 5000 psi hose with 1502 Unions. The line will run from the choke manifold to the gas buster. Gas Buster The gas buster is located in one of the three 50 bbl compartments of the pits. It is constructed with an open bottom that utilizes the hydrostatic level in the tank for the water leg. The gas buster vents vertically. Gas Detection We are proposing that a single gas LEL monitor be placed at the work platform. PVT We are proposing to work with out a PVT system as the wells to be worked will not be capable of circulation at surface or the reservoir will be isolated. UNOCAL SWANSON ~ ~ --- I ~ ~ r-- I I I II Pipe Ram II I I " Blinds II I I I ~~SAI~ 2" 5M MGV 2" 5M MGV I [I] œ [JJ11" or 7-1/16" SM Annular SM Studded Top and Flanged Bottom ~11"or7-1/16"5M DBL dÞ Optional 3111" or 7-1/16" SM Drilling Spool w/ 2 ea 4" SM OTL 12", 5m Hose wI flange connections. 1 11" or 7-1/16" SM Hydril Annular BOP 2 11" or 7-1/16" SM Shaffer LWS Double BOP 3 11" or 7-1/16" SM Drilling Spool w/2 ea 4" SM OTL (Optional) 4 2 1/16 SM Manual Gate Valve 5 2 1/16 SM Manual Gate Valve 6 2 1/16 SM Manual Gate Valve 7 2 1/16 SM Manual Gate Valve ~c"- 2" 5m High Pressure hose. To Flow Back Tank ~ STATE OF ALASKA ALAS~, }IL AND GAS CONSERVATION COMMlt}N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Suspend U Performed: Alter Casing D Repair Well D Change Approved Program D Pull Tubing D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Operation Shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Development [2] Stratigraphic D Perforate U Waiver U Other ~ Stimulate D Time Extension D Rod Changeout Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 160-045 Service D 6. API Number: 50-133-10118 9. Well Name and Number: SCU 32-08 10. Field/Pool(s): Swanson River Field/Hemlock 7. KB Elevation (ft): 22.15' 8. Property Designation: Soldotna Creek Unit 11. Present Well Condition Summary: Total Depth measured 10,828' true vertical 10,828' feet feet Plugs (measured) n/a Junk (measured) 10,601' top of fill Effective Depth measured 10.601' true vertical 10.601' feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Size 28' 22" 3,014' 13-3/8" 10,828' 6-5/8" MD TVD Burst Collapse 28' 3,014' 28' 3,014 cemented to surface 853 psi 1,130 psi 10,828' 10,828' 895 psi 10,140 psi Perforation depth: Measured depth: 10,506 to 10,676 " ,N 15<.. i, E" II", SCA j~ ~cJ True Vertical depth: 10,506 to 10,676 ? (7 20Gl~ .,.J (, 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a RECErVED 2-7/8" 6.4# N-80 @10,300' DEe ~ 2 2004 Baker Model D Permanent Packer @ 1 0,29~laska Oil i GII CORl. Corrmission Anchorage RBDMS BFL DEC 2 3 1004 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 42 83 150 115 108 85 15. Well Class after proposed work: Exploratory D Development [2] 16. Well Status after proposed work: Oil [2] Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 114 316 Tubing Pressure 170 170 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service D x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: Contact Steve Tyler 263-7649 Printed Name Tim C. Brandenburg signature? -:r ~ Form 10-404 Revised 12/2003 $ Title Drilling Manager Phone 907-276-7600 Date 12/16/2004 OR\G\NAL ) ) 3/23/04 Assembled work platform and staged. Laid out area for felt and liner containment. AOGCC out and witnessed NO-Flow test. 3/24/04 Laid down full length sucker rod under polish rod. Located a new 27/8" BOP. Secured well. Snubbed off BOP and riser to platform legs and Rotoflex unit. 3/25/04 Initial up weight 12700#, pull all 1" rods (107), all 7/811 rods (124), and 7 of the 3/411 rods with 12 guides each, found pin threads parted on top of 8th 3/411 rod. Have remaining 135 - 3/411 rods with 12 guides each, 11 - 3/411 rods with 5 guides each, and 19 - 3/4" rods with 3 guides each, along with pump. Start to mobilize additional 1" rods for fishing purposes. Remaining rod weight 6723# 3/26/04 Shot fluid level on tubing and casing, Casing 4085', Tubing 1613'. 3/29/04 PTSM with crews. ND riser and rod table, remove work BOP and secured well. Wellsafe out and nippled down gas detection equipment. Rig Accepted @ O:OOhrs. 9-28-104 9/28/04 Test BOPE T/1500psi. Rig Accepted 9-28-104 @ O:OOhrs.Pick up rods and put in derrick. Run 30 rods in Hole then stand back in Derrick Make up fishing tool RIH tagged @ 175' worked our way through to 250' coming out to look at fishing tool. Tool alright R.I.H. W I Fishing tool stop @ 175', Worked through to 490',520' could not go down POOH, Mobilized Pollard Wireline for gauge runs. Rig down to rig up pollard. PJSM wI Pollard, R/URIH WI 2.25 gauge ring T/6,029' tag top of fish. POOH Paraffin on Tools RIH WI 2,38 gauge ring to 6,029 tag fish, POOH tight spot @ 768' WLM. RIH. WI 2.38 gauge ring T/6029' tag fish -POOH. Fluid @ 1,570' tight spot @ 768' WLM,. RIH WI 2.38 gauge ring T/6029' tag fish -POOH pump 30 gals diesel 1 QT solvent - work area @ 768' several times no improvement, tight spot coming out slow @ 520' POOH. RD Pollard down, RU Tlrun fishing tool. RIH WI fishing tool 2.30 Overshot P/U 7/8" rods. RIH WI Fishing Tool 2.30 Overshot P/U 7/8" rods 1337/811 rods, bring in 1" rods, RU to Annulus and junk tank, RIH WI 111 Rods, tagged and latched up overshot, pulled up and stroked pump. 9/29/04 RIH and tag top of rods at 6015', PU and locate collar at 5083, drop down and make tubing punch at 5086'. POOH and RD APRS. Set BPV 2.5" CIW type H. Bled pressure off hanger void and ND tree. NU BOP. 9/30/04 Continue to NU BOP hook up choke line and spot choke skid, install rams and function test BOP. Tested BOPE to 250 PSI low and 3000 PSI high. AOGCC Lou Grimaldi witness test. Pull TWC check, MU landing joint WI TIW valve and head pin. Un J from hanger string weight 70M drop down and attempt to rotate out of anchor. LD landing joint, PU and LD hanger and slick joint along with 2 pup joints. POOH with 2 7/811 IBTC tubing. Filling hole at 2.5 times metal displacement. SCU32-08, summary, last revised 10/07/04, page 1 ) ) 10/1/04 POOH W/2 7/811 IBTC tubing to top of rod fish LD perforated joint. Remove overshot. LD tubing elevators and bails, RU rod elevator and PU rods (10M weight), PU to 30M lock break down and monitor to see if pump comes free.. Stack rods out on bottom and locked up pump done blind back off. POOH 12 stands of 3/4" rods. RU and pull tubing to rod fish 18 stands. During previous blind back off had 2 other back off points happen. POOH with rods then tubing, latch rods and PU found additional free rods POOH and pull tubing until rod fish is exposed. Perform blind BO using new bushing and power tongs. Locked pump by setting rod weight down POOH with 3/411s until fish POOH with tubing set back. Perform another blind back off using bushing. POOH with 12 stands of 3/4" sucker rods. RU and pull tubing to fish, pull 15 stands of 2.875" IBTC tubing. RU to strip rods and LD. Strip tubing and rods OOH lying down. 10/2/04 Stripping out of hole. 2 7/811 tubing. 3/4" Rods. LD pump still inside tubing. RU Pollard WL, RIH with 2.5 GR and tagged bottom at 10601', POOH and RIH with 20' of 2.511 dummy guns to 10595' with no problem POOH. RD and secure well RU SWS, have pre arming safety meeting with all parties involved. Test lubricator to 200 PSI low and 1500 PSI high. RIH with Gun run #1 Correlate with SWS log Gamma Ray I CCL 8/18/2001, on depth and perforated from 10546' - 10560' (14'), at 19:15 Hrs, good indication of firing. POOH and LD guns, inspect and found all to have fired. 2.511 HSD Powerjet, 6SPF, 60 degree phasing. MU gun run #2, RIH, Correlate with SWS log Gamma Ray I CCL 8/18/04, on depth and perforate 10518' - 10528' (10'), at 21 :15 Hrs, good indication of firing. POOH and LD guns, inspect and found all shots fired. 2.5" HSD Powerjet 6 SPF 60 Degree phasing. Secure well and rig down SWS equipment ND dry hole tree from top of BOP I remove blind from Mud Crossl pitcher nipple and install flow line. Rig up to run completion. 10/3/04 PU BHA and run in hole RIH W/2 7/811 IBT 6.4# L-80 Tubing, drifting every stand MU tubing hanger and landing joint land same 56K up and down weight. Un J from hanger and drop down to set anchor for putting tubing in tension. 10/4/04 While trying to get anchor to set, tubing backed off 1 joint below the tubing hanger. PU landing joint and laid down, laid down hanger and slick joint. PU 3 joints of 2 7/8" tubing RIH and screw into fish Pull to surface and LD fish. POOH with 2 7/8" tubing rack back in stands retrieved 159 stands and a single POOH and LD BHA, BOT anchor tool remained in hole, coupling that connected anchor to XO badly deformed. Lubricate and fuel rig. RU Pollard RIH with 4.5" LIB tag top of fish at 10284 slickline measurement, POOH, and RD slickline. Complete Pollard RDMU I and RIH with BOT spear and bumper sub assembly RIH with 2 7/8" IBTC tubing (Attempt to fish anchor.) 10/5/04 PU and start to move packer up POOH with packer pull first 10 stands slow watching for hang- up At 2200' packer hung up with 1 OK over pull, worked pipe down and pulled up several times, pumped approximately 40 gallons diesel down annuls with PAO-33 Paraffin inhibiter, Pulled a couple of more stands with the same results hanging on each casing collar. AT 115' casing changed from 24 to 28 PPF 6 5/811 casing. . LD total 1 0 joints from derrick, 8 joints from string and 2 joints racked out. MU completion BHARIH TISTD 24 dog collar and hand slips first 10 stands. 10/6/04 SCU32-08, summary, last revised 10/07/04, page 2 ". ) ) Continue to RIH with 2 7/8" tubing from derrick, PU 3 singles to latch in to packer. Pull 20M over, release from the on off tool and space out MU hanger, land Un J from hanger, stab back on the on off tool. PU 20M over string weight and engage hangar. LD landing joint, set 2.5" CIW type BPV, ND BOP, MU pumping tree, and test void to 5000 PSI, Pull BPV and set TWC pressure test tree to 3000 PSI, bleed pressure off and pull TWC. Pump 40 BBL of diesel down tubing to flush chasing with 60 BBL lease water. RU to run rods, and build work platform PU pump and RIH PU 57 3/4" rods from ground and RIH with 76 3/4" rods form derrick PU 33 new 3/4" rods form ground and RIH FI derrick 133 joints 7/8" rod change handling T/111 rods RIH with 101 111 rods tag bottom on 102 LD 2 rods. 10/7/04 Continue to space out utilized 1, 211 pony rod with guide under polish rod, 1, 8" pony with no guides, 1, 4" pony with 3 guides. Pressure up tubing by rod annulus too 1000 PSI to verify pump on seat all went well, PT to 1000 PSI. Stroked pump to verify working RD. 11/4/04 MI/RU 11/5/04 RU Pollard slick line. RIH tag R plug W/2.2" LID @ 10294'. RIH and tag seating nipple @10092' with W/2.30" GR POOH and RD. PU and MU dip tube, seating cups and mechanical disconnect on bottom of pump RIH with rod string. 11/6/04 Carrier unit fuel pump problem downtime while running rods. Continue running rods from rod basket, (1643/4" rods, 1357/8" rods & 99 1" rods). Strip off rod table and BOPs. P/U 3 joints 1" rods, RIH and tag seating nipple at 14.42" in. Set down 15K to seat seal assembly in landing nipple. Pick up rods while measuring to top of pump stroke. Picked up 2K over to unseat out of nipple. Set back down and seat in nipple. Measure for space out, lay down two joints. Remove floor, rod tongs and prepare Swaco pump. Pick up one 2' EL Pony Rod, one 8' EL Pony rod and P/U Polished Rod. Re-seat pump. Pump 15 Bbls diesel down tubing and test to 1000# with pump in down stroke for 15 minutes (OK). Pick up to top of rod pump stroke and Test same (OK). Run rod string down, clamp off polished rod above stuffing box, Rig down tools, blow down pump, and Vac truck pits clean. Rig down floor. RID guidelines, scope down derrick, hang off blocks, and lay down derrick. RODS: (1643/4", 1357/8", 100 1", one 2' EL Pony rod and one 8' EL Pony rod) Rig Released at midnight SCU32-08, summary, last revised 10/07/04, page 3 ~ ' 'of UNOCALe API# 50-133-10118-00 RKB =22.15' J L #It. ~ [I] ~ NO. @ > ~ ~ . ŒJ A IT] ~ @] ) ~ II] B C 1 [ffi 2 3 4 5 1H1 "'';i",<y",,,y,,,),:,~ ~: TD= 10,828' PBTD= 10,631' Max Deviation = 3° SCD 32-8 Actual completion 11-044 Top 15.00' 2.41' 4' 2,534' 5,914' ) ) Swanson River Field Soldotna Creek Unit Well SCU 32-8 Original 2/22/61 ACTUAL COMPLETION Casing & Tubing Size Wt Grade ID Top Btm 22" Surf 28' 13 %" 54.5 12.615 Surf 3014' 6 %" 28 P-110 5.791 Surf 115' "CI c: 2 0 6 %" 24 N-80 5.921 115' 6477' ~.;; - p.. 6 %" 24 P-110 5.921 6477' 10,037' ~§~ 6 %" 28 P-110 5.791 10,037' 10,828' ~M~ Q:SS Tubing 2 Ys" I 6.4 I N-80 I 2.441 I Surf I 10,300' Btm 20.23' 38.18' Jewelry OD Item Seaboard International Tension Hanger 1.500 Polish Rod (spaced out 7' above stuffing box wI pump 2.14' off btm). 1.0 1" EL Sucker Rod, wI Slimhole Class T coupling wI (3) 2.25" R&M Stealth 2.025 AF Rod Guides per rod .88 7/8" EL Sucker Rod, wI Slim hole Class T coupling wI (3) 2.25" R&M Steal 1.812 XL AF Rod Guides per rod .75 3/4" EL Sucker Rod, wI Slim hole Class T coupling wI (12) 2.25" R&M Ste~ 1.625 XL AF Rod Guides per rod .75 3/4" EL Sucker Rod, wI Slim hole Class T coupling wI (5) 2.25" R&M Steal 1.625 XL AF Rod Guides per rod 1.0 1.625 2.15 2.34 1.28 1.6651-1/4" (1.660" 00) 1-1/4" NPT B x P wI ported bull nose 2.28 3.062 Cup Type Seating Nipple, 2-7/8" wI XO's to Butt 2.992 3.500 Ported Sub Crossover, 3-1/2", 9.2#, Butt P x 2-7/8" Buttress Box 2.992 3.500 Pup Joint, 4' x 3-1/2", 9.2#, N-80, Butt 2.992 3.500 Ported Sub, 3-1/2", 9.2#, Butt BxP 2.992 3.500 6 Joints of 3-1/2",9.2#, L-80, Butt tbg 2.441 4.250 XO, 3-1/2" x 2-7/8" 2.441 2.875 Pup Joint, 10' x 2-7/8",6.4#, N-80, Butt 2.188 3.500 Otis "R" Profile nipple, 2.188" wI Butt BxP wI Plug. 2.312 3.500 Ported Sub, Baker OnlOff tool, Ported Collar 1.96 3.430 Baker Model "E" Anchor Latch wlo seals 2.00 Baker Model "0", 32-26, Perm Packer. Length ID 5.23' 2.441 - 35.77' - 2,534' 2,530.00'- 5,914' 3,380.73'- 9,739' 3,824.53'- 9,739' 10,014' 275.28' - 3O" stabilizer bar wI collar 10,014' 10,016' 10,016' 10,055' 6 7 8 9 10 10,055' 10,074' 10,075' 10,083' 10,087' 10,088' 10,275' 10,276' 10,286' 10,287' 10,298' 10,300' 10,074' 10,075' 10,083' 10,087' 10,088' 10,275' 10,276' 10,286' 10,287' 10,298' 10,300' 10,302' 2.08'- 39.14' - 20.00' 1.09' 8.08' 4.04' 1.17' 186.32' 1.48' 10.01' 1.12' 10.73' 1.58' 2.78' 1-3/4" RXBC Obi valve Pump wI Dual Seating Cups wI Stabilizer Bar. Perforations Zone Top Btm Ft SPF Date Comments HI 10,506 10,516 10 4 1985 Sqz. HI 10,516 10,526 10 12 '70,'85,'95 Reperf in '04 wi 2.5" , '04 PJ. HI 10,526 10,532 6 12 1985 Perf in '85 wi 5" TCP H2 10,545 10,572 27 12 '70,'85, 04 Reperf in '04 wi 2.5" PJ. H2 10,576 10,580' 4 4 1985 Sqz. H3 10,585 10,600 15 12 '70,'85 Reperf in '85 wi 5" TCP H3 10,603 10,611 9 4 1985 Sqz H4&5 10,617 10,676 59 4 1985 Sqz. Actual 11/23/04 CRW ) ) Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com / t,'¡!~ .kø,'..,. #éØ,'CJ \,¡I i:\{tf' '~!' i UNOCAL Debra Oudean G & G Technician Date: November 29, 2004 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 ~llIdD r·.··.'~~·'i·· . '. '. INtERVAL B." . WELL 'LOG TYPE' SCALE LOG DATE LOGGED LINE CD Ð'I..ot>t '~'KGSF~iÄ"""'"'''''lpE'f~'FÔRAllNG'RECORD 3 3/8' HSO"GÙN' ..' ... "'15 INCH J 10/2.1/200.1 6100.6.15Ò·........, .. '1'" '1'1": ' . .., ¡SCU''''24A':()'5'''''''I'p'L'ÜG'''S'ET'''R'ï~'c'õ'R'D'''2'''7ï8"'HJ\iIï'sU"RT'ÕÑ'"Êz's'v''' ....... """'''''''''''''''''''''''''S'''i'N'CH''''''''''''''':1"'''''1''öï''2''1'/2'6Ò¡''9'63S:'9'63S'''''''''''''''I''""""';""""""1""'1""'''1 \ q~ ~~ _ <J§~;}~~~~_]~~f~~~~f~~~~~T~~~~~~~:~'2~HSD2Ö06 'PJ 6SPf:--i~ :~~~ J: ~;~~;~~~~ i;~~~: ~:~~ _ i : I: ~ r'tõ--f>l.q !SCU312-09 [SLIM CEMENT MAP TOOL ¡SINCH 10121/200.t1.t300-nOO IIi 1 I t C{J tJ '""I) Z$ \~~_~_3,!3_-9~_:~~M~~_~~!~N_~~_L.~~~-2 H·S-D-~?~_[Ã~~~-._-~-~-_~,~~_·_Js ~~~C~_~,[~.!~~~~O~r~~qi~,~)~O~-,-[~~=~[I=¡ - .. ¿ J ISCU 32-08 ." COMPLETION RECO.RD 2.5 HSD POWERET 6 SPF 60 5 INCH 10/3/2004.,.10200-10565 1 '. 11 It;o-o,51 :DEGREE PHASED ,¡ '00-15.2.. ~CU43B-0~,-rC~~~LETION'RE~ORD2.5H~DPO~ERJETS· 151t~CH , 11/3/200.115857.5867 I 1 11, ,'-. _() <leI- ¡SRU 23-27 HALLIBURTON G. UN CORRELATION LOG RESERVOIR 5 INCH 10/17/200.1 5100-7760 1 1 UN 1 \..1 SATURATION TOOL , rjqq. o~f ~SRU 32A-15 '¡CEMENT TOP TEMP'SURVEv"GR/CCL' ',' _.. [1/5INCH:- 1""912712004JO-'9600 - .. [ .. Î 1 ;~:~~i::~::~;;':"1'~~~!!¡!~~:~~~;i;;;;;;;~~;:~,::::,6~".,..J:;:~:..._,....;;:::;:.::::~::;:..__,.,_,;..,.,~l "- /"""."",,,,,,,,,,,,,,,,,,,..,,,,,,,,,,,,,,,,,,,,,,,,,,,,"""", """,,,,,,,,,,,,,,,,,,,,,,,,,.,,,,,,,,,,,,,,,,,,,,,, "",,,,,,,,,,,,,,,,,,,,,,,,,,,,,""',,,,,,,,,,,,,-,"',",,,,,,"".""", ",,,,,,,,,,,,,,,,,,,,,,,,,",,,,,,,,,,,,,, """""".",,,,,,,,,""",""",,",',",",",,,,,,,,,,,,,,""""'."",.,..".",,",,",., ".",,,.,,,,,,,,,¡ ~(;Þ~\ì~NE\ '1 f' r' ;;.~, ~:þ f-thJ ,,) Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Date: /Z/~~ ATASIiA OIL AND GAS CONSERVATION COMMISSION 160-0IlS- (êù If fA\ V r? ~illJ P {i\ r1 T;'\ (0" í1 n r¡;\ ~ "ì I I ~ \\, U1 ¡ r I I I Þ,; I LI \ ! I I,~ \, \ù~) I ~ ( / lJ \ '0 U Lrù I ~ LJ d Lf\J LS iJ \J L.,. U\~ Lrù FRANK H. MURKOW5KI, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 22,2004 Mr. Philip J. Krueger Drilling Manager Unocal Alaska PO Box 196247 Anchorage AK. 99509-3330 RE: Swanson River Field W orkover BOPE Configuration Dear Mr. Krueger: Per 20 AAC 25.285 (h), the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska ("Unocal")'s request for variance from the workover blowout prevention equipment ("BOPE") requirements of 20 AAC 25.285 (c) and (e), during operations on wells in the subject field. This variance is applicable to Swanson River Field wells SCD 32-08, SCU 33-33, SCU. 312-09, SCU 24A-05, SCU 21-03, SRU 23-27, and SRU 32A-15. AOGCC finds that Unocal's requested variance provides at least an equally effective means of ensuring well control as that required by regulation. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd 'day falls on a hqliday or weekend. A person may not appeal a Commission decision to Superior Court yfilesHehearing has been requested. ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, J \Dit DATE P.I. Supervisor 1(113 ~+~ : March 24, 2004 THRU: FROM: Lou Grimaldi, Petroleum Inspector SUBJECT: No-Flow Test Unocal, Swanson River SCU 32-8 Soldotna Creek Unit PTO 160-045 NON-CONFIDENTIAL Tuesday, March 23, 2004: I witnessed a No-Flow verification in the Swanson River Field # SCU 32-8 Soldotna Creek Unit. Following is a timeline and well status during test. 1245 Arrive location, tubing/casing open to atmosphere with no flow evident. 1300 Well shut-in @ 0 psi 1400 0 psi, Open well to atmosphere with no flow evident. Shut-in well @ 0 psi. 1450 0 psi, Open well to atmosphere with no flow evident. 1530 Well open to atmosphere, no flow evident. Conclude test. SUMMARY: I witnessed No-Flow verification on UNOCAL's Swanson River well #SCU 32-8 in the Soldotna Creek Unit. NON-CONFIDENTIAL CC. .:.:.z. No-Flow seD 32-8 03-23-04 LG.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAl_' 20 ACC 25.280 1. Type of request Abandon J--1 Suspend J J Ops Shutdown J--1 Perforate J--J Variance r--1 Annular Disposal J--J Alter Casing J--J Repair Well [] Plug Perforations J--J Stimulate J--J Time Extension r-J Other J--J Change Approved Program [--1 Pull Tubing J--J Perforate New Pool J--1 Re-enter Suspended Well j--J 2. Operator Name: 4. Current Well Class 5. Permit to Drill Number: Union Oil Company of California/Unocal 160-045 3. Address: Development [] Exploratory J--J 6. APl Number: PO Box 19-0247, Anchorage, AK 99519 Statigraphic J--J Service J--1 50-133-10118 7. KB Elevation (ft): 15' KB 9. Well Name/Number: SCU 32-8 / 8. Property Designation: Swanson River Field 10. Field/Pool(s): Swanson River Field/Hemlock 11 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): TVD (ft): Eft Dep MD(fi): Eft Depth TVD (ft): Plugs (measured): 10,828 10,828 10,631 10,631 n/a Casing Length Size MD TVD Burst Collapse Structural Conductor 13' 22" 28' 28' cemented to surface Surface 2,999' 13-3/8" 3,014' 3,014 853 psi 1,130 psi Intermediate Production 10813' 6-5/8" 10,828' 10,828' 895 psi 10,140 psi Liner Perf Depth MD (ft): Perf Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,516-10,600' 10,516-10,600' 2-7/8" 6.4#, L-80 10,300' Packers and SSSV Type: Packers and SSSV MD (ft): Baker 6-5/8" model "D: Packer 10,300' 12. Attachments: Detailed Operations Summary 13. Well Class after proposed work: Description Summary of Proposal [] BOP Sketch [-1 Exploratory [--1 Development J-~ Service J-"l 14. Estimated date for commencing operations: 15. Well Status after proposed work: 12/15/2003 //"' 16. Verbal Approval: Date: Oil [] Gas r'-J Plugged J-"J Abandoned r--J Comission Representative: WAG [--J GINJ r-J WlUJ ~ WDSLP J--1 17. I hearby certify that the foregoing is true to the best of my knowledge. Contact: Steve Tyler (263-7649,! Printed Name: Phil Krueqer Title: Drilling Manager .Signature: ,~~/ A~"~ Phone: 263-7628 Date: 11/26/03 Conditions of approval: Notify Commission so representative may witness Sundry Number: "~0~-~ ~'~ Plug integrity BOP Test Mechanical Integrity Test Location clearance Other: Subsequen~ form required 10- O"gJ""~O~' ......, '~ BY ORDER OF THE t,~/~~~ Approved by:... ,°i~ll'J,..~_,.,, _ ,._ Commissioner COMISSlON Date Submit in duplicate Form 1~)-403 Revised 2/2003 ICI RRENT COMPLETION] Swanson River Field Soldol~na Creek Unit Well SCU 32-8 Original 2/22/6t Last Completed 8/16/01 Rods Ran 8/20/01 RKB =22.15' Casing & Tubing Wt Grade iD T~ Top Btm Size 22" Surf 28' 13 %" 54.5 12.615 Surf 3014' 6 s/a" 28 P-110 5.791 Surf 1 I5' 6 -s/8" 24 N-80 5.921 115' 6477' 6 Vs' 24 P-110 5.921 6477' 10,037' 6%" 28 P-llO 5.791 10,037' 10,828' Tubing 2Vd' t 6.4 } N-80 [ 2.441 ] Surf · 10,300' H3 H4&5 Depth Jewelry Item Seaboard International Tension Hanger Polish Rod (spaced out 7' above stuffing box w/ pump 2.14' off btm). 1" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 2.25" R&M Stealth XL AF Rod Guides per rod EL Sucker Rod, w/Slimhole Class T coupling w/(3) 2.25" R&M Stealth AF Rod Guides EL Sucker Rod, w/Slimhote Class T coupling w/(12) 2.25" R&M Stealth ×L AF Rod Guides per rod 3/4" EL Sucker Rod, wi Slimhote Class T coupling w/(5) 2.25" R&M Stealth XL AF Rod Guides per rod 3/4" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 2.25" R&M Stealth AF Rod Guides per rod 1-3/4" RXBC Dbt valve Pump w/Dual Seating Cups w/Stabilizer Bar. 1~1/4" (1.660" OD) 1-1/4" NPT B x P w/ported bull nose Cup Type Seating Nipple, 2~7/8" w/XO's to Butt Pup Joint, 6' x 2-7/8", 6.4#, N-80, Butt Ported Sub, 2~7/8", 7.2#, Butt BxP 3 Joints of 2-7/8", 6.4#, L-80, Butt tbg Otis "R" Profile nipple, 2,188" w/Butt BxP w/Plug, Pup Joint, 6' x 2-7/8", 6.4#, N-80, Butt Ported Sub, 2-7/8", 7.2#, Butt BxP Baker Model "E" Anchor Latch w/o seals Baker Model "D", 32-26, Perm Packer. Perforations Zone __Top Btm Ft SPF Date Comments H1 10,506 10,516 10 4 1985 Sqz. H1 10,516 10,526 I0 12 '70,'85, Reperfin '85 w/5' TCP '95 HI 10,526 10,532 6 12 1985 Perfin '85 w/5" TCP : It2 10,545 10,572 27 12 '70,'85 Reperfin '85 w/5" TCP. H2 10,576 10,580' 4 4 1985 Sqz. H3 10,585 10,600 15 12 '70,'85 Reperfin '85 w/~' TCP H3 ~10,603 10,611 9 4 1985 Sqz H4&5 10,617 10,676 59 4 1985 Sqz. TD= 10,828' PBTD= 10,631' Ma× Deviation = 3° SCU 32-8 Current dwg 8-16-01 Proposed 3/21/01 SLT Swanson River Field SCU 32-08 Rod Repair Job / 1. Disconnect Rotaflex f/rod string. Slide Rotaflex back 10'. 2. MIRU Production Hoist. 3. Strip off stuffing box and LD polish rod. 4. Strip on Workover rod BOPE, pump-in sub and rod table. 5. NU surface lines, choke manifold plumbed to Flow-back tank. 6. Utilize rod elevators and hydraulic rod tongs, POOH w/rod string. 7. PUMU overshot. RIH w/rod string. Latch rod string fish, pull/jar pump off seat. POOH LD rods and pump. 8. PUMU new pinup assy. RIH w/tapered rod string. Seat pump in seating nipple. Reciprocate rod string to insure pump is functioning. 9. Space-out rod string. Strip offBOPE, Pmrtp-in sub and table. Strip on stuffing box and polish rod. Land same on stuffing box. 10. Release rig. 11. Slide Rotaflex back into position. Attach bridle to rod string. 12. turn well over to production. Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe Dan Williamson Drilling Manager 9/14/01 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Subsequent Well Work Report; SCU 32-8 Workover Swanson River Field, Alaska Dear Commissioner Heusser: Unocal Alaska Resources hereby submits its subsequent report of wellwork operations for the subject well. Please find enclosed a Report of Sundry Operations (Form 404), a Workover Summary Report and an updated wellbore schematic. If you have any questions or require additional information, please contact Bill Penrose at 258-3446, Drilling Manager S£P g 001 Alaska Oil & G~J:~ C,~n~:. Cerni.'r,ssior~ ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: Convert to Rod Pump 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL Development: X 15' KB 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 Stratigraphic: Swanson River Unit Service: 4. Location of well at surface 8. Well number 1850' FNL, 1970' FEL, Sec. 8, T7N, R9W, SM SCU 32-8 At top of productive interval 9. Permit number/approval number Same At effective depth Same 50- 133-10118 At total depth 11. Field/Pool Same Swanson R. Field/Hemlock 12. Present well condition summary Total depth: measured 10,828 feet Plugs (measured) true vertical 10,828 feet Effective depth: measured 10,631 feet Junk (measured) true vertical 10,631 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 13' 22" Cmtd to surface 28' 28' Surface 2,999' 13-3/8" 1900 sx in 2 stages 3,014' 3,014' Intermediate Production 10,813' 6-5/8" 1400 sx in 2 stages 10,828' 10,828' Liner Perforation depth: measu red 10,516' - 10,532', 10,545' - 10,572', 10,585' - 10,600' true vertical 10,516' - 10,532', 10,545'- 10,572', 10,585' - 10,600' Tubing (size, grade, and measured depth) 2-7/8", 6.4#, L-80 Tubing to 10,300' Packers and SSSV (type and measured depth) O0 1 Baker 6-5/8" Model 'D' Packer @ 10,300' 13. Stimulation or cement squeeze summary NA Alaska Oil & Gas Cons. Commissir,~ Intervals treated (measured) Anchorage NA Treatment description including volumes used and final pressure NA 14. Representative Daily Averaqe Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7/01 205 60 15 45 250 Subsequent to operation 9/01 292 90 8 45 200 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Dan Williamson~~.~A,~~~Title: Drilling Manager Form 10-404 Rev 06,15/88 ORIGINAL SUBMIT iN DUPLICATE ~ Unocal Alaska Drilling Workover Summary Report SCU 32-8 8/12/01 to 8/23/01 8/12/01 MIRU KH&R Rig #9. Accept rig at 1600 hrs, 8/12/01. Take on base oil and R/U to pump down tbg w/returns from annulus to gas buster. Pump base oil down tbg. 8/13/01 Pump base oil down annulus. Monitor well - both stable w/fluid level below surface. Install BPV, N/D tree, N/U BOPE and test to 250/3000 psi - OK. P/U landing joint and screw into tbg hanger. Pull hanger to rig floor, shearing retrievable pkr downhole. POH and L/D completion. 8/14/01 Continue POH and L/D completion. M/U 6-5/8" csg scraper and scrape top joint of 6- 5/8" csg. Remove csg scraper and M/U storm pkr. Set storm pkr at 25'. N/D BOPE and install tbg bowl adapter for tension tbg hanger. N/U BOPE and test broken flanges to 3000 psi - OK. POH and L/D storm pkr. POH and L/D remainder of old 2-7/8" completion. M/U Baker 6-5/8" Model 'D' packer and RIH, picking up new 2-7/8" tbg. 8/15/01 Continue RIH w/packer, picking up new 2-7/8" tbg. Set packer at 10,300'. POH w/ packer setting tool, standing back 2-7/8" tbg. M/U completion assy and RIH. 8/16/01 Finish RIH w/completion assy. Tag up on pkr, space out, anchor into pkr and land out with 11K lbs of tension at the tbg hanger. Set BPV, N/D BOPE, N/U tree and test tree to 250/5000 psi- OK. Clean rig. Released rig at 2400 hrs, 8/16/01. 8/18/01 Shoot fluid level - 5070'. R/U to perforate. Locate fill at 10,553' w GR/CCL. M/U 1- 11/16" strip Gun #1 and RIH. Perforate H2 sand 10,556'- 10,566'. POH, all shots fired. M/U Gun #2 and RIH. Perforate H2 sand 10,543'- 10,556'. POH, all shots fired. M/U Gun #3 and RIH. Perforate H1 sand 10,516'- 10, 528'. POH. 8/19/01 Finish POH w/Gun #3, all shots fired. RDMO wireline unit. Shoot fluid level - 5040'. 8/20/01 Shoot fluid level - 4500'. Witnessed by AOGCC's Lou Grimaldi. Set plug in R-nipple at 10,285' w/slickline. 8/21/01 MIRU rod running equipment. N/D swab valve and tree cap, N/U rod BOPE and flow nipple. 8/22/01 Spot and R/U tank and pump truck. Pump 50 bbls base oil down tubing. Sort, strap and tally rods. 8/23/01 8/24/01 P/U and RIH w/rod pumping BHA. P/U and RIH w/rod string. Tag up on seating nipple and space out. R/D rod running equipment. Strip on check valve and stuffing box. Install rod stabilizers. Demob rod running equipment. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser. DATE: Chairman THRU: Tom Maunder,--~' ~'~ ~_,~~,.~~~ P. I. Supervisor FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector August 20, 2001 No-Flow Test Unocal SCU 32-8 Swanson Riv, er Field SCU PTD 160-45 NON,CONFIDENTIAL Monday. August 20, 200!: I witnessed No-Flow verification on UNOCAL's Soldotna Creek Unit #32-8 in the Swanson River Field. I arrived to find the wireline crew rigged up and ready to run an R plug in the down hole seating nipple. The wells tubing and annulus were both static. Fluid levels were shot and determined fluid to be at approximately 4500' in the tubing. I witnessed the plug being run and fluid level was evident at the level mentioned above. I observed the well in this condition for approximately two hours. I explained to Steve Tyler (Unocal rep.) that if the wells conditions changed (pressure buildup) the Commission should be notified immediately. The well exhibited inability to flow to surface unassisted and I recommend it be granted No-Flow status. SUMMARY: I witnessed No-Flow verification on UNOCAL's SCU 32-8 in the Swanson River Field. NON-CONFIDENTIAL cc; Attachment: None No-Flow UNOCAL SCU 32-8 8-20-01 LG.doc Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 Alaska Ms. Joan Miller Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Ms. Miller: Re: Soldotna Creek Unit Well SCU 32-8 APl # 50-133-10118-00 On June 10, 1995 the following intervals were reperforated in Well SCU a32-8: BENCH TOP (MD) BOTTOM {'MD) FEET HB1 10,520 10,529 9 HB2 10,546 10,569 23 Total 32 Very truly yours, · Candace Williams REC iVE OEC I 1 1995 Alaska 0il & Gas Cons. Commission Anchorage ~ STATE OF ALASKA . ..1 ALASKA 0~ ,~ND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging ~.. Perforate _X Return to P'rod. Pull tubin~l After ~asin~l 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE~ AK 99519 - 6247 Location of well at surface 1850' S and 1970' W of NE comer, Sec. 8, T7N, R9W, SB&M At top of productive interval Same as above At effective depth Straight Hole At total depth Same as above Repair well 5. Type of Well: Development ~x Exploratory Stratigraphic Service Pull tubin~ Other __ 6. Datum elevation (DF or KB) 143' RKB feet 7. Unit or Property name ,-~ §oldotna Creek Unit ~8/~elJ number 10. APl number 50-133-10118-00 11. Field/Pool Swanson River/Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 28' Surface 3014' Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary feet feet feet feet Plugs (measured) Junk (measured) Size Cemented 22" 13-318" 1900 sx 10,828' 6-5/8" 700 sx 14. Measured depth True vertical depth 28' 28' 3014' 3014' 10,828' 10,828' 10016'-10532'; 10545'-10072'; 10589'-10600' RECEiV L) Straight Hole 2-7/8",6.5~,N-80to10,506'UD {~EC 1 1 1995 6-5/8", Baker FH packer ~ 10,465' M~aska Oil & Gas Cons. ~;omrnission An~crcgc Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Prior to well operation 6/9/95 137 5297 20 2650 1300 Subsequent to operation 6/11/95 156 5654 25 27O0 1300 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run *See Below Daily Report of Well Operations Oil X Gas Suspended Service 17. I hereby certify that the fo~go'l~g is ~ ~tn~correct~tR the best of my knowledge. Form 10-404 Rev 06/15188 SUBMIT IN DUPLICATE Unocal Corporation P.O. Box 196247 Anchorage, AK 99519 (907) 263-7805 UNOCALe Marie Vaughn Drilling Engineer PED Tuesday, July 18, 1995 Mr. Russ Douglas AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Douglas: Between May 25, 1995 and June 10, 1995 fill was cleaned out of Swanson River Field well SCU 32-8 (APl #50-133-10118-00) from 10,569'-10,576' WLM and the following intervals were perforated: Hemlock bench 1 from 10,520'-10,529' & Hemlock bench 2 from 10,546'-10,569' with 2-1/8" Enerjet guns, 4 SPF, 0 deg phasing. Production test before (4/25/95) 146 BOPD, 24 BWPD, 6.7 MMCFD. Production test after (6/11/95) 156 BOPD, 25 BWPD, 5.7 MMCFD. Sincerely, MLV/leg ~'-"~' STATE OF ALASKA -""~ ALA. ., OIL AND GAS CONSERVATION COMk ' REPORT OF SUNDRY WELL OPER 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Perforate X_'' /r"X'///~~'~l~U Pull tubing _ _ Alter casing Repair well _ _ Pull tubing _ _ Othe __ I~ing Cleanout 2. Name of Operator Union Oil Company of California (UnOcal) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: Development X Exploratory __ Stratigraphic_ _ Service 4. Location of well at surface 1850' 'S and 1970' W of NE Corner, Sec. 8, T7N, R9W, SB&M At top of productive interval At effective depth Straight Hole At total depth 6. Datum elevati&n~or KB) 143' KB 7. Unit or Property name Soldotna Creek Unit feet 8. Well number SRU 32-8 9. Permit number/approval number 60 -0045 10. APl number 50-133-10118-00 11. Field/Pool Hemlock 12. 13. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth Structural Conductor 28' 22" 28' Surface 3014' 13-38/" 1900 sx 3014' True vertical depth 28' 3014' Intermediate Production 10828' 6-5/8" 700 sx 10828' 10828' Liner Perforation depth: measured 10516'-10532'; 10545'-10572'; 10586'-10600' true vertical Straight Hole Tubing (size, grade, and measured depth) 2-7/8", 6.5#, N-80 to 10,506' MD Packers and SSSV (type and measured depth) 6-5/8", Baker FH Packer @ 10,465' MD Stimulation or cement squeeze summary Cleaned out fill f/10,569'- 10,576' WLM RECEIVED JUL 2 ? 1995 Ai~sI~ Oil & Gas Cons. 6ommissio~ Intervals treated (measured) Perforated Hemlock Bench I F/10,520'-10,529' with 2-1/8" Enerjet 4 SPF, 0 deg phasing. Perforated Hemlock Bench 2 F/10,546'-10,569' with 2-1/8" Enerjet, 4 SPF, 0 deg phasing. Treatment description including volumes used and final pressure N/A 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 146 6700 24 156 5700 25 Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Daily Report of Well Operations x Oil Gas _ _ Suspended _ _ Signed G. Russell Schmidt~;~L~ Title Drilling Manager Form 10-404 Rev 06/15/88 Service Date 7/18/95 SUBMIT IN DUPUCATE SWANSON RIVER SCU 32-8 DAY 1 (05/25/95) HOLD PRE-JOB SAFETY MTG. RU DOWELL SCHLUMBERGER COILED TBG UNIT. NU BOP'S, TEST, OK. COMPLETE BOPE CHECKLIST. MU BHA: 1.5 CTC, 1.5" ST BAR, 2 XO'S, 1.75" DBL FLAPPER & 1.75" WASH NOZZLE. SECURE UNIT FOR THE NIGHT. SCU 32-8 DAY 2-4 (05/26-28/95) FUU DOWELL CTU, TEST BOPE. RIH W/1-1/2" CT U/WASH ASSY. TAG BOTTOM AT 10573' ATTEMPT TO WASH NO PROGRESS. SPOT 24 BBLS XYLENE TO SOAK. WAIT 30 MINS ATTEMPT TO WASH NO PROGRESS. POOH. P/U 2.125". BAKER MOTOR W/2.15" CARBIDE MILL. RIH TAG BOTTOM AT 10587'. CLEAN OUT 10593' COULD MAKE NO FURTHER PROGRESS. PUMP SEVERAL XANVIS PILLS CONTINUE TO WORK W/MOTOR TO CLEANOUT LOST 2' COULD NOT CLEAN OUT PAST 10591' (CTM). (5 HRS) POOH, MILL WORN 1/2" TO 518" ON OUTSIDE EDGE. 1.75" INNER CIRCLE CARVED IN BOTTOM. RJD CTU. PJU SLICKLINE. RIH W/2.25" IMPRESSION BLOCK TAG AT 10576' (WLM) I.B. HAD 1.75" OD. QUARTER CIRCLE. (NEAR MATCH TO BAILER BOTTOM THAT WAS PREVIOUSLY LOST IN AN EARLIER WIRELINE OPERATION). SET ORFICE VALVE AT 5329'. RETURN WELL TO PRODUCTION AT 12:00 HRS ON 5/28/95. RECEIVED jUL 2 7 t~l~ska 0ii & Gas Cons. Commission .Ai'lCi'10,': STATE OF ALASKA ~ ' ALASF~'"~)IL AND GAS CONSERVATION C" MISSION APPLIC -,rlON FOR SUNDRY APPROVALS Plugging ~ Time extension Stimulate Pull tubing __ Vmianoe P~--omte X -- 6.~-atum ele~n 1. Type of request: Abandon __ 8uapend __ Alter oasing__ Repair well __ Change approved program ~ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 1850' S & 1970' W of NE cor., Sec. 8, T7N, R9W, SM At top of productive interval Straight Hole At effective depth At total depth 12. Present well condition summary Total depth: measured true vertical 10828 10824 feet feet Type of Well: Expk~to~/ KB: 143' feet 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 32-8 9. Permit number 60-0045 10. APl number 50-133-10118-00 11. Field/Pool Swanson River/Hemlock Plugs (measured) Effective depth: measured 10634 true vertical 10630 feet feet Junk (measured) Casing Length Structural Conductor 28' Surface 3014' Intermediate Production 10828' Uner Perforation depth: measured Size Cemented 22' Driven 13-3/8" 1900 sx 6-5/8" 700 sx 10516-10532,10545-10572,10589-10600 Measured depth 8I 3014' True vertical depth 8I 3014' 10828' RECEIVED true vertical 10516-10532, 10545-10572, 10589-10600 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, N-80 @ 10507' paCkers and SSSV (type and measured depth) Baker 'FH' @ 10465' DEC - 9 199,t 13. Attachments Description summary of proposal __ Detailed operations progran~:__ BOP sketch 14. Estimated date for commencing Operation ~15. 12/2O/93 16. If proposal was verbally approved Oil X_ Gas _ Name of approver Date approved Sen/ice 17' I he{~Y celllfY th~ f~e~n~ c°rrect t°'~e~e best °f mY kn°wledge'~ / ' FOR COMMISSION USE ONLY Status of well classification as: Suspended_ Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test Mechanical Integrity Te~__. Approved by the order of the Commission Form 10-403 Rev 06/15/88 Location clearance _ Subsequent form required 10- ~ o h Original Signed By David W. Johnston Approved Copy Returned ~--l~-?~ Commissioner Date SUBMIT IN TRIPUCATE ~- December 8, 1993 Swanson River Well SCU 32-8 Perforating Procedure 1. Obtain a well test. 2. Load robing with crude if necessary. . . Hold safety meeting with appropriate personnel. Rig up electric line unit. (,4 pump-in sub is required on lubricator) 5. Pressure test lubricator to 3500 psi for five minutes. 6. Shut down all welding and radio transmissions. , RIH and perforate intervals as instructed by Unocal representative. (When gun is 200' below surface, welding and radio transmissions may resume.) , POOH. (When gun is 200' below surface, shut down all welding and radio transmissions.) 9. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH MEASURED TVD FEET H1 10517-10532 10513-10528 15 H2 10547-10572 10543-10568 25 I-I3 10585-10600 10581-10596 15 TOTAL 55 RECEIVED DEC -9 199~ Al~ka Oil & ~as Cons. Commi6~ion Anehoraoe ARCO Alaska, Inc. Post Office Bo~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering June 25, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 32-8 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to acidize well SCU 32-8 with a mud acid treatment. We propose to stimulate well SCU 32-8 with 40 bbls of 7.5% HC1 and 80 bbls of 6% HC1 - 1.5% HF in a two stage treatment. With your approval, we would like to begin this work as soon as possible. If you have any questions please contact David Pursell at 263-4258. Sincerely, 7~~~-~ T. Wellman Regional Engineer TW:DAP:ch:0034 Attachment cc' S.W. Ohnimus UNOCAL Corporation A. 1~ Kukla Marathon Oil Company .~'~k~.Oil & Gas Cons. Com~is~io~ Anchora~ ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate X Change approved program _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 1850' S and 1970' W of NE corner, Sec. 8, T7N, R9W, SB&M At top of productive interval At effective depth Straight Hole At total depth 6. Datum elevation (DF or KB) 143' RKB 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 32-8 9. Permit number (~o-- oo4~- feet 10. APl number 5o-1 33-1 011 8-00 11. Field/Pool Hemlock 12. Present well condition summary Total Depth: measured true vertical feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet 13. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10,516 - 10,532'; Length Size 28' 22" 3014' 13-3/8" 10,828' 6~5/8" measured: 10,545 - 10,572'; true vertical: Straight Hole Cemented Measured depth .... 28' 1900 SX 301 4' 700 SX 1 0,828' 10,589 - 10,600' Tubing (size, grade, and measured depth 2-7/8", 6.5#, N-80 to 10,506' MD Packers and SSSV (type and measured depth) 6-5/8", Baker FH packer. @ 10,465' MD Attachments Description summary of proposal _ True vertical depth 28' 3014' 10,828' ~,-,,~a.O~l & 6as Cons. Comr~l/ssio~ ~ Anchora~ Detailed operation program X BOP sketch 14. Estimated date for commencing operation ~ 15. Status of well classification as: June, 1990 I Oil X Gas __ 16.If proposal was verbally approved Name of approver Date approved Service ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Suspended ._ Title Cook Inlet Regional Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-~'t IIAppr°val No~?~ ,. ~,,~-{:2! Approved by the order of the Commission Commissioner Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned , Date ~.¢~/,2~)~O SUBMIT IN TRIPLICATE Well- scu 32-8 Spud Date: 1/3/61 r3riginal RKB: 22' ,~ of Hemlock:10,506'UD Max. Hole Angle: A J Alaska Inc. - Swanson River, APl#: 133-10118-00 Completion Date: 2/22/61 Hanger Type Shaffer 3° Well Type: Producer Last Workover: 9/85 Hanger: Shaffer Angle @Hemlock: All Depths are RKB MD to Top of Equipment. Jewelry 1 23' 2 39' 3 1672' 4 3005' 5 3956' 6 4750' 7 5329' 8 10,422' 9 10,465' 10 10,503' 11 10,505' 12 10,507' Tubing Hanger Fatigue Nipple Camco MM Mandrel wi Dummy Camco MM Mandrel w/Dummy Camco MM Mandrel w/Dummy Camco MM Mandrel wi Dummy Camco MM Mandrel w/Dummy Camco MM Mandrel w/Dummy Baker "FH" Packer 2 7/8" x 6 5/8" Otis "S" Nipple Tubing Pup Baker Shear Sub 0 H1 H2 H3 10 11 12 Minimum ID: 2.441" (~ 10.503 ¢Otis "S" Nioole} - . Casing and Tubing 22" 13-3/8" 6-5/8" 2 7/8" 0 54.5# 0 28# P-110 0 24# N-80 115' 24# P-110 6477' 28# P-110 10,037' 6.5# N-80 0 28' 3014' 115' 6477' 10,037' 10,828' 10,507' Perforation Data Interval Zone FT SPF 10,506'-10,516' H1 10' 4 10,516'-10,526' 10' 12 10,526'-10,532 6' 12 10,545'-10,572' H2 27' 12 10,576'-10,580' 4' 4 10,585'-10,600' H3 15' 12 10,603'- 10,611' 9' 4 10,617'-10,676' H4,5 59' 4 Descriotion Surface Casing Production Casing Liner Tubing Date Comments 1985 SQZ. '70,'85 Reped 1985 Ped '70,'85 Reperf 1985 SQZ. '70,'85 Reperf 1985 SQZ. 1985 SQZ. PBTD = 10,631 '~'i~'"~ ''~ TD = 10,828' ~: :'~'~'~'~' Anchoraffa Well SCU 32-8 By: JLB 10/23/89 Well SCU 324~ Mud Acid Treatment · Procedure 1. MIRU pump trucks and spot acid tanks. 2. Pump 40 bbls 7.5% HC1 w/additives followed by 80 bbls 6% HC1- 1.5% HF w/additives. 3. Displace w/NH4CI and lease crude. 4. RD pump trucks and KIP. TRANSM, ITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED M, ATERIALS WELL NAME: ,..~~ -.~-(:~ We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. j. L. Weaver Chevron U.S.A. Inc. 3001 C Street Anchorage, AK 99503 RECIPIENT PLEASE ACKNOWLEDGE COMPANY: BY: DATE: BY: Senders~ Instructions:- These transmittal sheets are made on NCR (No Carbon Required) paper' With' three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send Original under sepa- rate cover to addressee. {If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this form. EXP-180-8 (CD-3-82) Printed 'In U.S.A. THE FOLLOWING'IS A LIST OF MATERIAL ENCLOSED HEREWITH CaECK AND A~VISE II~EDIATELY. - /j:i~ "/~TRANSi~TTAL AND AcK2:._$TLEDG~NT- OF;RECEIPT OF MATERIAL- (ALASKA) PLEASE .~feu 3-~1-Z7 .. · · , ANCHORAGE. 'Received and Checked'by: ~:~: ~/?'~-/7"" ~/_--_~_~'! Remazks: ( f :8 1ItQJAt~{IJ.; !(]'~JJ.¡ r~ 14,~{~~~' Q ".~' !~~J.'~J1J.Jt~)I~ r, líYj~i$~~~t lij~~,~§J, ;IJil~. P. O. BOX 7.839 18 AN.CHORAGE Þpr1 4, 196j ALASKA '. \ ., \ J "'. PRODUCING DEPARTMENT llL.!o.Pf1aN£ aR 7.6201 c V. CHATIERTON OIS'1 RICT SUPE,"Nl CNOl'NT .. CONF t DENTIA[ M.!'. :',1. H 8 ~;OJï5tF:. r Xegional 011 .~::. Ge.a &u~rvisor Un1 ted btates (~;ological S\.4r'J'ey P. 0, Box 259 ~".... Anchorage, ¡\1.8.Sk, Ii! ~. T. .R. Marsh~,ll Chief', Petroleu.n~ branch Department of Natural Reaourcee D1via:1.on of Nines and iA.1:uerDls 329 F,econò f\ venue Þnchor.:1ge, !\laE;kB Le' ' :',: ;,~, ~ . ' ,.'. .' ¡.,' "', "" ~ , .' ". ,L.\ r... ~j , tFH.. Gentlemen: we enclose herewlth fer y\)ur files and iJlfoJ~t,',ion) cnmpletic,;. reports of remedial work on wells ßoldotna Cree¥.. ~~3"'9, ~aud 14-34. Very truly yours, I' \ t-.c C. V. CRAT'n.RTON l\tt8.chmen't COMPLETION REPORT - PA~KER AND GAS LIFT INSTALIATION SOLDOTNA CREEK UNIT 32~ ~CTION 8: T. 7 N.~ Ro9 W.: ~Seward B &M ---- , , Il STA~~ OIL COMPA~ OF CALIFORNIA, W.O.I. - OPEPATOR Page 2. November 1~ ,,1962 Commenced work at 8:00 P.M. Moved rig and rigged up. November 2~ 1962 Killed well with 80 pcf Black Magic mud using ~lliburton. and installed BOPE. Removed x-mas tree November 3, 1962 Pulled 2 7/8" tubing out of hole. with packer and gas lift mandrels. Ran 7" casing scraper. Reran 2 7/8" tubing Ail tubing 2 7/8", 6.5~, N-80, 8RD Rg 2. TUBING DETAIL K.B', to landing flange Landing flange 50 joints 2 7/8" Camco MM mandrel 45 joints 2 7/8" Camco MM mandrel 40 joints 2 7/8" Camco MM mandrel 32 Joints 2 7/8" Camco M~ mandrel 29 joints 2 7/8" Camco MM mandrel 26 joints 2 7/8" Camco MM mandrel 22 joints 2 7/8" Camco MM mandrel tubing w/RD valve tubing w/RD valve tubing w/ED valve tubing w/RD valve tubing w/RD valve tubing w/RD valve tubing w/CEV valve 83 joints 2 7/8" tubing Camco sleeve valve 1 joint 2 7/8" tubing Camco CO safety joint Pup Joint Brown 2 7/8" X 7" ES-16-1 packer 2 Joints 2 7/8" tubing Camco D nipple 5 joints 2 7/8" tubing Venturi shoe Tubing landed at Depth 17.00 · 85 17.85 1580.08 1597.93 13.05 1610.98 14~0.42 3031.40 13. lO 3044.5o 1262.82 43o7.32 13,15 4320.47 lO10.56 5331.o3 13.1o 5344.13 913.75 6257.88 13. lO 6270.98 816.95 7087.93 13.1o 71Ol. O3 686.38 7787.41 12.80 7800.21 2582.29 l0382.50 2.62 10385.12 31.55 10416.67 1. lO 10417.77 10.06 10427.83 5.95 10433.78 60.07 10493,85 · 92 10494.77 157.o4 10651.81 · 6 10652.46 November 4:,,~,, 1962 Removed BOPE. Reinstalled and tested x-mas tree with 4500~ psi - 0I~ Flowed well. Set packer at 10,428'. Rig released at l:OO PM, November 4, 1962. Returned well to production. S. R. NANSEN SRE:pb UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS Tk~ followin,('j is a correct report 'of operations a~,d produ~ctiot, fi~chedin~ driglino~ and producin, g we~s)/or t~ ~o,,~~ o/'_ ............. _~0ye.~r ............. /~_ 62, . .......... so!_dotna._Crook..U~t ......................... ~,~ ~.~.~ ....... ~o~ ~_.~3~ ........................... c~~..~~~.o~.~c9~.._0~, oA~, ~.o.x. .................................. ~_~or~es.A!aska ,s~ ,~e~ 'C.' 7. ~~0~'" thousmz~s) ~ none, so ~COVE [LRD i - 8 ~ SCU 32-8 i ~~ B~ok N~c mae' ~ed 2 7/8" ~bi~o ~ casing sorapero ~r~ 2 7/8" tgb~ eq~pped w~tk packer o~ Landed tub~ at / _ U.S.GoSo M. ~t. Soyster State - T R. ~arshall Richfiel~ - C.[Wo Perry / RoIR. Ritter Files - ~oduc!ng t- NOTE. There were ......................................runs or sales of oil; .................................................. M cu. ft. of gas sold; runs Or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Repor~ on this form is required for each calendar month, regardless of tl)e status of operations, and must be filed in duplicate'with ~he supervisor by the 0th of ~he succeeding month, unless otherwise directed by the supervisor. ($~y lg~) PRODUCING DEPARTMENT TELEPHONE BR. 7--620I DISTRICT SUPERINTENDENT ' C. V. CHATTERTON P. O. BOX 7-839 ° ANCHORAGE ° ALASKA CONFIDENTIAL Mr. R. V. Murphy Alaska 0il & Gas Conservation Commission 329 Second Avenue Anchorage, Alaska Dear Sir: Enclosed, herewith, is the Completion Report for Soldotna Creek Unit Well 32-8 (lO), for your information and files. Very truly yours, STANDAP~ OIL CO~ANY OF CALIFORNIA Western Operations, Inc. C. g. CHATTERTON Enclosure OO~LETION RE~ORT - I~W WELL STA~ OIL COMPA~ OF CALI~~ - WESTERN OPEPATIONS, GPERA~OR AREA: PROPERTY: WELL NO.: LOCATION: Eenal Peminsula, Cook Inlet Area, Alaska Soldotna Creek Unit sou 3s-8 Surface: IAND 0FFI~: Anchorage Lease No.: 0289~6 SECTION: 8, TOWNSHIP: 7 N., BANGE: 9 W., Seward 1550 feet south ~d 1970 feet west from ~rth~st corer Section 8 p~Ject~--~s~p 7 no~h, ~ 9 west, Se~rd B a M. ELEVATION: 143' K. B. E. B. is 1~' a~ove ground. PRODUC TI ON: Da~ly Average: ~35 B/D Flowing Oil': ~1 Gravity: ~8° Water: ~ ~P: 1900 psi Gas: 90 ~F ~ean 8/6~" TOTAL DEP~: 10,828' SUMMARY PLU~S: 10,828 - 10,785 ' JUEK: None GASING: COnductor at Casing cemented at 6 5/8" Casing cemented at 014 ' 10,8~8' / . ls~ stage around shoe with through DY at 1~08' sacks. .arou~d shoe with ~ through DV at 7996' APR 6 !9(H COMPLETION REPORT - PACKER AND GAS LIFT INSTALLATION : , ,, , . ,, ~ __, , , ,,_, ~ , L ,,,, , ,, , ., , . ~ - ~ ~ S...TA~. OIL..C .~..ANY OF CALIFORNIA - WESTERN OPERATIONS INC. - OPERATOR . · .=_ , . . , , , , 1,11 _ · L , - . AREA: Kenai Peninsula, Cook Inlet Area, Alaska PROPERTY: Boldotna Creek Unit LAND OFFICE: Anchorage LEASE NO.: 028996 WELL NO,: SCU 32-8 Section 8, Township 7 North, Range 9 West, Seward B & M. LOCATION: Surface: 1850' South and 1970' West from Northeast Corner, Section 8, Projected Township 7 North, Range 9 West, Seward B & M. ELEVATION: 143' K.B. DATE: April 2, 1963 K.B. is~5' a~ovej~round. / -..,' ,,-.,%.. BY: .'~~, C. 'V. CNATTERT~)N, District superintfendent .CONTRACTOR: Santa Fe Drilling Company, Rig ~85 DATE COMMENCED REMEDIAL WORK: November 1, 1962 DATE COMPLETED REMEDIAL WORK: November 4, 1962 TOTAL DEPTE: 10,828' PLu~s: lO, 828 - 1o, 785 ' CAS lNG: 22" cemented at 28' i 8" 3 2/ cemented at .3,014' 6 5/8" cemented at 10,828' PERFORATIONS: As before. Page ~"' Jet ~"' Jet ~-" Jet Jet ~-" Jet ~" Jet Holes at 10,496 10,497' Holes at 10,681 ~ 10,682' holes Der foot 10, 520 - 10, 530' Holes Der foot 10,550 - 10,575' Holes per foot 10,580 - 10,584' Holes per foot 10~592 - 1%603' Holes per foot 10,608 - 10~616' Holes per foot 10,62~ - 10,678' SURVEYS: 1. Schlumberger I-ES Log interval 3, 018 - 100' 2. Schlumberger Sonic Log interval 3, 022 - 100' 3. Schlumberger I-ES Log interval 10, 820 - 3',010' 4. Schlumberger Sonic Log interval 10,817 5. 8chlumberger Microlog interval 10,816 - 9,500' and 4,000 - 3,000' 6. Schlumberger Dipmeter Log interval 10~820 - 9, 380' 7. Schlumberger Gamma 'Ray Log interval 10,774 - 9,774' 8. Schlumberger Cement Bond Log interval 10,772 - 8,800' and 8,150 - 6,170' 9. Baroid Mud Log interval 6,575 - 10,828' DRILL S~.~M ~ESTS: 1, H.0.~. W.S.0.~i on ~ - ½" holes 10~$96 - 10,$97' W.$.O. 2. ~.c.~. w.s.o.~e on 5 -~" holes 10,681 - 10,68~' W.S.___90. Page 3. S uddea at 7:OO D~lled ~" hole 0 - 1~' J~~. ~ !~6! D~lled ~" hole 106 - ~,693' Drilled 1~" .hole 106' .drilled 2, ~87' drilled 80 pcf mud 86 pcf~ mud 2,693 - 3,02~' 331' drilled Circulated and conditioned mud one hour. P.O. Ran back open ended. Attempted to ru~ I-ES Log, hit bridge at 180'. Ram in with !~" bit, O.O. bridge. Rem I-ES Log interval 3,018 - 100', Sonic Log interval 3~O22 - 100'. Ra~ in, plugged bit. Pulled wet string. Ran in with 18 5/8" hole opener. Opened 12~" hole to 18 5/8" hole 0 - 350' 350' opened 86 pcf mud Opened 1~" hole to 18 5/8" hole 350 - 2,896' 2,546' opened 91 pcf mud Opened 1~" hole to 18 5/8" hole 2, 896 - 3, 02~' L~8' qpened Otrculeted end conditioned mud. Ran 73 Joints of 13 3/8" casing. CEMENTING DETAIL: Oemen~ed 13 3/8" castn~ a~ 3,01~' in two ste~es wi%h 1900 sacks o£ cemen~ %rea%~ wl~h O. bottom'rubber COMPLETION REPORT SOLDOTNA CREEK UNIT WELL SCU B2-8 Section 8, T. 7 N., R. 9 W.~ Seward 'S NoA W,'o.i:' Page !.s_t .:stage_ around shoe with 600 sacks of cement. Pumped 50 bbls. of water ahead, mixed 600 sacks of cement in 35 rains, using Halliburton truck, displaced in 30 mins. using rig pumps. Average slurry weight 116~. Bumped plug with 1500 psi. ~ull circulation throughout. ~d :_Stage_ through DV at lB08'. Dropped DV bomb, opened DV ports in 35 mins. Pumped 50 bbls. of water ahead, mixed 1BO0 sacks of cement in 90 mins. using Halliburton truck, displaced in 14 rains, using rig pum~s. Average slurry weight ll6~. Closed DV ports with 1500 psi. Full circulation throughout. Cement in place at 7:45 PM. CASING DETAIL: ALL 73 joints or 2994.70' Below K.B. 19.33' Landed at '301~. 03' Ja_~ua..ry. 8, 1961 Equipped with Halliburton Shoe, Float Collar and DV Collar 92 p cf mud Flanged up. Tested CBC with 1500 psi OK. kelly cock with 1500 psi OK. weak. Repaired pipe rams. 'Installed B.O.P.E. and tested with 1500 psi for 15 mins. OK. Drilled mouse hole. Tested pipe rams and D.O. DV. Tested pipe rams and DV, pipe rams Tested pipe rams and DV with 1500 psi. 76 pcf mad OK. D.O. Cement, float and shoe. Drilled 12~" hole 3,024 - 3,751' 727' drilled Drilled 10 5/8" hole 3,751 - B, 868' ll7' drilled 76 pcf mud Twisted off at 3868' at 12:O1 AM. Left 10 5/8" bit, i1 - 7 B/4" DC and tool Joint pin in hole. Top of fish at 3528'. Ran in with Bowen 7 5/8" overshot with 6~" slips and 5 ~/4" pack off. Caught fish and chained out. Drilled 10 5/8" hole 3,868 - 3,990' 1£2' drilled Twisted off ~t ~90'. Left l0 5/8" bit, 13 - 7 3/$" D.C.'s~ cross-over sub, tool joint pin off of ~" D.P.' 418' of fish. Top of fish at ~572'. Ran in with 7 5/8" overshot, 6~" spiral grapple and 5 S/~" p~ck off. Caught fish and chained out. Put on lO Joints of fresh D.P. above D.C. 's. 73 pcf mud COMPLETION EEPORT SOLDO~tA CREEK UNIT WELL SCU 32-8 Section 8, T, 7 N., E,, 9 W.~ Seward B & M Fofmz%' w':o Page 3~ 990 ~ 0~1' 91' drilled Twisted off at ~)81'. Left 10 ~/8" bit, iS - 7 3/4" D.O.'s, cross-over sub and tool Joint pin off of 4~" D.p., ~18' of fish. Top of fish S863". Ran in with Bowen 7 5/8" overshot, 6~" spiral grapple and 5 S/$" pack off. Caught fish, chained out. Drilled 10 5/8" hole 4,081 - 4,268'. 187' drilled 7S pcf mud Drilled 10 5/8" hole 4,268 - 6,110' 1,842' drilled 73 ' 75 pcf mud January l~,~ 1961 Drilled 10 ~/8" hole 6,110 - 6, 328' 218' drilled ~stea off at 6~28,. Left l0 5/8" bit, 12 - 7 3/4" D.C., cross-over s~b azu~ 1 ~ofnt of ~" D.P. Length of fish 342'. ~ of fish 7986'. Ran in with Bowe~ 7 ~/8" overshot with 6" ~rapple ~nd 5 3/~" pack off. Worked over fish. 0haine~ out. Drilled 10 ~/8" hole 6~ 328 - 6~ 372' 4~' drilled 78 pcf mud .JanuarY.!6 .r...Feb~ry la, 1961 Drilled 10 ~/8" hole 6, 372 - 10,~13~ ~,0~1~ drillet Installed t~rol~ Mud Lo~n~ Unit at 6~7~' January 16, 1961 80 - 98 pcf mud COMPIETION REPORT SOLDOTNA CREEK UNIT WELL SCU 32-8 Section 8, T. 7 N.~ R. 9 W., Seward B &.M ...... Page 6. Drilled lO 5/8" hole 10,413 - lO, 526' 113' drilled Los circulation at 10,526'. Pulled up into 13 3/8" casing an~ circulated. P.O. Attempted to fill hole with drilling fluid with fill-up line from surface. 'Fluid level wouldn't come up above 200'. Mixed 160 bbls. of lost circulation material. Ran into 10,526' and spotted lost circulation material. 98.5 pcf mud ~.~..br~ua~ 14, 1961 Picked up new bit, ran in to shoe of 13 3/8" casing and circulated. Staged back to bottom. Drilled 10 5/8" hole 10,526 - 10,615' Regained full circulation. drilled 95 pcf mud Orilled lO 5/8" hole 10,615 - 10,736' 121' drilled 95 pcf mud Drilled 10 5/8" hole 10,736 - 10,828' T.D. 92' drilled Conditioned mud. Ran Schlumberger I-ES Log interval 10~8£0 -. 3, olo'. Baroid mud logging unit released. 95.5 pcf mud Ran Schlumberger Sonic Log interval 10,817 - 3, O10', Micro Log lntervmlm 10,816 - 9,500' and 4,000 - 3,000', and Continuous Dipmeter interval 10,820 - 9,380'. Conditioned hole. Commenced running 6 5/8" casing. 95.5 pcf mud Completed running 6 5/8" casing. CEMENTING DE~IL: Cemented 6 ~/8" casing at 10,8R8' in two stages with 1400 sacks of cement treated with O. ~ ER-4 using Ealliburton power equipment. Used i top rubber plug. COMPLETION REPORT SOLDOTNA CREEK UNIT WELL SCU 32-8 Section 8, T. 7 N., R. 9 W., Seward B C'0'"f' Page 7. ~.e..~.r~a. ~ 18, 1961 Continued 1.st......S~tage around shoe with 700 sacks of cement. Pumped 30 bbls, of water ahead, mixed 700 sacks of cement in 25 rains, using Halliburton truck, displaced in 35 rains, using rig pumps. Average slurry weight ll7~. Bumped plug with 1500 psi. Full circulation. 2nd Stage through DV at 7996'. Dropped DV bomb~ opened DV ports in 50 rains. ~ed~26 bbls. of water ahead, mixed 700 sacks of cement in 25 rains, using Halliburton truck, displaced in 25 rains, using rig pumps. Average slurry weight 117~. Closed-DV ports with 2000 psi. Fall circulation. Cement in place at 12:30 PM. CASING DE~A'IL : Top 4 Joints or 123' Next 147 joints or 6, 362' Next 89 joints or 3,560' Bottom 19 Joints or 779' ALL 259 Joints or 10,836' Above K.B. (-) 8' ..... _ ~ _ : z. '.. · .... , ., .~,. ,,, ~,, ~ ,~. ,,. · u '.~ · ~ ........ Landed at 10,828' 6 5/8" 28~p 110 L8 R cross over Joint 65/8" 24~ N 80 B.T. cross o'ver Joint 6 5/8"' ll0 L 8 6 5/8" ~8~P llO L 8 R E~uipped ~th ~ker ~ffe~ntial fill-~ shoe on bottom ~d ~fferential fill-up co~r i Joint above. Flanged up. Installed BOPE~ Tested secondary packoff with 3500 psi. OK. F~e~ ._.r~. ry ..19,... 196.% Tested BOPE and C.S.O. with 1500 psi. ~OK. Ran in to D.V. and tested pipe rams, hydril and Kelly cock with 1500 psi. OK. D.O.D.V. Tested DV with 2500 psi. OK. Ran in to 10,785'. Conditioned mud and reduced weight. 92.8 pcf mud ~ebrua..~., ~q~ Ra~ Schlumberger Cement Bond Log interval 10,772 - 8~ 800' and 8150 - 6170 ~, Gamma Ray Log interval 10,77~ - 9,774'. Ran Schlumberger Jet gun and perf'd. 5 - ½" holes 10,~96 - 10,~97'. Ran Halliburton W.S.O. ~l on 5 - ½" Jet holes - lC, 497'. Halliburton WSO ~est ~l on 5 - ~" Jet holes at 10,~96 - 10,497'. WSO TEST: TooI assembly as follows: 2 outside BT recorders, 5' of 2 7/8" perf'd, tail pipe, 6 5/8" Type "C" hookwall packer, VR safety Joint, hydraulic jars, 2 inside BT recorder~ hydrospring tester, and du~l closed in valve. Used 2855' of W.C. Ran on lO, 410', 2 7/8" EUE tubing. COMPLETION REPORT SOLDOTNA CREEK UNIT WELL SOU 32-8 Section 8, T. 7 N.,. R. 9 W., Seward B &.M co'f Page 8. Set packer at 10,%38' with 18' of tail to 10,%56'. No Initial Shut-in Period. Opened tool to surface at 12:41 P.M. for 62 rains, flow test. Immediate faint blow slowly decreasing throughout test. Shut in tool at 1:43 P.M. for 31 min. FSI Pressure. Pulled packer loose at 2:14 P.M. Recovered 180' net rise. All drilling fluid, filtrate testing 38 G/G salinity. Ditch tested 38 G/G salinity. PRESSURE DA~A: IH IF FF FSI FE Top inside 67%1 1338 1439 3725 6709 Bottom inside 6695 1313 1405 3693 6695 Top outside 6785 1298 1403 3700 6757 Bottom outside 6767 1~02 1399 3699 6767 Pulled tester. Ran Schlumberger Jet gun and perf'd. 5 - ½" holes 10,681 - 10,682' for W.S.O. ~2. 92 pcf mud Ran Halliburton W.S.O. Test ~2 on.5 - ½" Jet holes 10,681 - 10,682'. Halliburton WSO Test ~2 on 5 - ½" Jet holes at 10,681 - 10,682'. WSO TEST: Tool assembly as follows: 2 outside BT recorders, 5' of 2 7/8" perf'd, tail pipe, 6 5/8" Type "C" hookwall packer, VR safety joint, hydraulic Jars, 2 inside BT recorder, hydrospring tester, and dual closed in valve. Used 2855' of W.C. Ran on 10,628', 2 7/8" EUE tubing. Set packer at 10,647', with 18' of tail to 10,665'. No Initial Shut-in Period. Opened tool to surface at 1:41 A.M. for 61 min. flow test. Puff blow and dead after 2 minutes. Dead throughout remainder of test. Shut in tool at 2:42 A.M. for 33 min. FSI pressure. Pulled packer loose at 3:15 A.M. Recovered 10' net rise. All drilling fluid. Filtrate testing 38 G/G. ~. Ditch tested ~8 G/G salinity. PRESSURE DATA: IH IF FF FSI FH Top inside 6850 1245 1245 2019 6850 Bottom inside 6820 1218 1218 1982 6820 Top outside 6928 1243 1243 2021 6928 Bottom outside 6916 1251 1251 2016 6916 COMPLETION REPORT SOLDOTNA CR~ UNIT WEL~ SOU B2-8 Section_ ..8,.:: T:: 7=N.,...R~: ..9..=...~,, .Seward. OIL CO. OF CALIFORFZ% W.O'I page 9. Ran Schlumberger jet gun and perf'd 4 - ½" holes per foot the following intervals: 10,678 - 10,622'; 10,616 - 10,608'; 10,603 - 10,592'; 10,584 tO, 580'; 10,575 ' 10,550'; 10,530 - 10,520'. Ran in with 2 7/8" tubing with Venturi shoe on bottom to 10,775'. Circulated and rotated hole clean. Pulled up landed 2 7/8" tubing at 10,646'. TUBING DETAIL: 3S8 Joints 2 7/8" EUE TUBING Venturi shoe Tubing' Hanger Rotary table to h~nger Tubing hung at 10, 628.20 ' .67'. .79' ....... 16.50' COMPLETION DETAIL: Installed Xmas tree and tested with 9750 psi for 5 rains. Held OK. Com- menced displacing mud with oil at 5:45 A.M. Pumped 50 bbls. of w~ter ahead, followed by 420 bbls. of crude oil. stOPPed circulating at 9:45 A.M. For- mation oil to surface at 11:~0 A.M. Flowed oil to sum~ until 12:30 P.M. Started flowing to trap at 12:45 P.M. Representative flow rate and cuts as follows: Flow Period Tbg. Press. ..... ;_% ~ ,, -- ;:-: '_~.. ::'.c ::cc __~ . "~ :" -~"~ 2. hrs. 612 B/D lO8 10/64 1500 1~25 l. 0.5 0.3 o 2. 0.3 T o 0.2 0.3 37.0© 36.3© Crap Pres s. 75 shut well in at 2: BO P.M. Shut in pressures; tubing pressure 19OO psi, casing pressure 1700 psi. Produced estimated 180 bbls. formation oil. Flowed 170 bbls. to tank and estimated 10 bbls. to sump. Installed Cosasco plug. Rig released 5 P'M, February 22, 1961. Installed Willis flow bean to obtain rates. JDK: lo COMPLETION REPORT SOLDOTNA CREEK UNIT WELL SOU 32-8 Se~t~o~ ~ ~. ~ ~.~ ~. ~ W.~ Se~ Page 580' 024 ' 200 ' 7o~' 7, oo1~' 7,2~0~ 7,7~' 7~10~ 8,1~' 310' 8~720' 9,~7'~ 9,~' 9,~0' 10,~3' ~,2~' O° -. 45' 2° - ~o . 4~' 2° - 15' 2° - '0' 2° - O' 3° - O' 2° - O' 1° - 30' 1° - 45' io . ~' 10 - 45' 2° - O' 2° - O' 2° - O' 2° - 30' 2° - ~o . 30' 2° - 2° - O' STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE i iii i i ii WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* W ELI. W ELL DR V Other b. TYPE OF COMPLETION: W F, LI, OVER EN BACK nESVR. Other __ 2. NAME OF OPERATOR SUBMIT IN DUPLICATE* ( Se~ other ln- slructioHs on reverse side: 3. ADDRESS OF OP~.RATOR 4. LOCATION Ob' WELL (Report location clearly and ia accordance with any 8tare requirements)* At surface 5. APl NU'M. EA~CAL CODE LEASE DESiGNATiON A.ND SERIAL NO. 7. IF INDIA.N, ALLOTTEE OR TRIBE NAME 8. UNIT,FA.R.NI OR LEASE NAME 9. WELL NO. 10. FIELD AND POOL, OR WILDC&T 11. SEC., T., R., M,, (BOTTOM I-IOI.,E OI~JECTIVE) At top prod. interval reported below At total depth I-IOW i~Y* ROTARY TOOLS 22. PRODUCING INTERVAL(S), OF THIS COMPLETIO~N--TOP, BOTTOM, NAME (MD AND TVD)* 12. PERMIT NO. ELEVATIONS (DF, RKB, RT, GR, ETC)*ll7. ELEV, CASINGtIEAD INTERVALS DR(LLED BY CABLE TOOI,S 23. WAS DIRECTIONAL SURVEY MADE 1 24. TY~PE ELECTRIC AND OTHEI{ LOGS }{UN IISI ~i II ' · - ii i i i CASING RECORD (Report all strings set in well) WEIGHT, LB/FT, DEPTH SET (MD) HOLE SIZE CA, SI~4G SiZE 26. LINEn lq~Ec O~ 27. [8.' PERFoRATioNS Op¢_aXl T~) PI~O]~3C~OI~ (interval, size and nurnber) i i i i ~o. %°DU~i0~ DATE FIRST PI%ODUCTION [ ~ODUCTION MEI[IO'D (Flowit~g, gan lift, pnrnp~g--size and type of pump) CIiOXE SIZ~ ~PgOD'N ~0~ OI~BBB. GA~MCF. FLOW, TUBING ]CAS~G PRESSURE [CAL~~ 'OI~BBL. GAte. CF. LIST OF ATTACHMENTS CEMLNTING RECOR,D AYAOUNT PULLED TUBING REC OP~D $Ci]EEN (MD) SIZE ~- DEP~q-I SET (MDt ]PACKER SET (MD) i i i 29. ACZD, Si~OT, Fi~AC2 URE, C~,IENT SQUEeZe, ETC. D~lli 1NT~V.~ (MD) ] AMOUNt ~'~D I'2!ND OF M~Ei~AL [V~ELL ~TATUS (Producing or ]¥¢ATEH,--BBL. [ GAS-OIL WA~BBL. lOlL GRAVITY-AP1 (CORR.) I'TEST WITNESSED BY '33.'I hereby certify that the foregoing and attached information is complete and correct as determined from all-available' re~drds SIGNED TITLE *(See InstructiOns and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is des~cjned for submitting a complete al~d correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in ether spaces on this form and in any attachments. Items 20, anJ 22:: If this well is completed for separate, preduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~cduci~.9 interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interw~l reported in iten~ 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item'S6: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing anci the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ,~ItY OW POitMATION TES'I'.'~ IN('LUI)IN(; INTEH. V^I~ TE.$'rED. I'HE~$URE DATA ~COVEI{I~ OF OIL~ GAS, aS. G~GIC MARK~ WAT~ AND MUD , _ NAME M~AS. ~t ~U~ V~T. ,, DATA. A?'~ACI[ ~RIE~ D~CRIP~ONS O~ LITIIOLOGY. pOrOSITY. ~RAC~. .APP~NT DIP$ AND DEI'EC~'EI) SllOWS OF OIL. G~ OH XVA~. UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budgt,t Burenu N,. 42 &pproval ~ xl,ires LESSEE'S MONTHLY REPORT OF OPERATIONS State ...... A!~5!~ ................ Coz~nty __~._~...~__Peai~k.la~ ...._Field ....... gFa. n.s_o~ ~v~_ z'. ................................ .: The followin~ is a correct report of operations and productio~, (includD~v~ drillb~6~ a~d prod~cinv~ wells) for the month W ........... ~~ ........ 196~__, ___~Q!~t~ ~ceek ,.~%~ OIL C0..0~ Phone ................... Dgg~aY~Y._~.-~g.0.l ..................................... ¢?',.t'., title Di~.C~.Ct S~eriatcn~at-A~ SEC. AND ] ~ELL DaYs ~ I OALI,()N5 OF BA}HtEI,S O~' RI'L fA RKS ~ OF ~ TWP. I~ANGE] NO Paovucz~ ~ARRELS O~' O~ ORAVITY ~ CU. FT. OF GAS IIAaOI INE ~WATE,, tlr (If drilling, depth; if ~hut dotvn cause: ~ (In thousands) l~',-'c~('~:~;~ ~ lol~(77,~'~f:fi- , date and result of test for g~)lino ...................... , ....... ] "" ~ ' '~1 c(.utent of gas) ',$ol~ ¢,.~ek U~t 32-8~(%0) ~ 9W Dri~ed l~ 5/8" hot& ~6 - 10,526'. ~st ct~:~tion at 10,526'. ~o~ed l~O bbls. of lost oireu~tlon mteeigl a~ 10,526'. ~Dri~led lO 5/8" hol~ 10,~26 - 10,828' T.D. ~n IES, So~c, Micro and ~p~ter logs. Cemen~d 6 5/8" casi~ at 10,828'. First ~th 700 sac~. ~coud u~ge th~u~ D.V. at 7)~' with 700 sa~s. ~Ins~lled ~d tes~ ~E. D.O. ~ tested D.V. Established ~O's mat ~% - 10,497' and 10,681 - 10,682'. Perf'd. 4 - -~-" holes [per ft. 10,678 - 10~622'; 10,616 - 10,6~'; 10,603 - 10,592'; zo,58o'; z0 ,5 5- o,55o'; o, 3o . zo, SaO', c.o. to ~10,~/5' ~ 2 7/~ tubi~ at 10,645' ins~l~d and tested ~ · ~ tree. Dlsp~ced ~d with oil.' ~ow~d ~8o~ B/D oil~ 130 ~F/D 0.5~ cut~ 0.3% wster~ 0.2% S & M~ 3~° C.G. g released 5 PM Feb~a~ ~, 1961. :~: ~.S.~.8. ~ ~. [. ~7sger (2) Ri~fieldl ~ Co~. -C. W. PerW ] W.C. Bishop ' ~z~loz-ation .......................................... NoTz.--Thcre wcrc ....................................... runs or sa]os of oil; ................................................ BI cu. £t. of gas sold; ............................................. runs or sales of~,,,a%iine,, during, ibc month. (Write, "no" where aprfiit,,bh,.) NoT~.--Repor[ on this form ia required for each ealc;xdar mo~lih, ' '~ '~' of ,,e duplicate with thc supervisor by thc 6th of the succooclir~g mo,;th, ui0ess otherwise directr::l 1,~- thc :~upervi-'ur. Forni LF..qSEE'S MONTHLY REPORT OF OPERATIONS SOO P.M. 10 f'J. ah. Cil Cor~ ~lovatio: · D.O.C. Drllle¢ Dr~ ]_led 5,/~" bc fi~. D 1 led l( sh. D~ L. Hill C. B:l ~op J. T~i~e~ off ami - 39~'~'. 'i'w~i ].e 3990 ~1'. ~/8" ~ ~1 - Nows.--~ ~ ................................... runs or ~ o~ off; ............................................ M eu. ft, et las ~fld; titus ~ ~m of g~line du~M the month. (Wfl~ "no" w~ a~~.) N~.--~ ~ ~ ~ ~ ~~ for ~h ~ndar m~ ~~ of t~ s~t~ of o~mt~, and m~ ~ ~ In ~~ ~ ~ ~~r by ~ 8~ ~ ~e ~i~ month, u~ othe~ ~~ by the su~rv~r. Creek Unit No. 32-8 (I1) ]:samui 12-9',, cs: 13-3/8# @ 30~L~' 6-$/8~ @ 108~' ~,/780 mt amd oboe & 700 mt thru DV ~.7/8' tbs hum8, APPLICATION FOR PERMIT TO DR~LL, DEEPEN OR PLUG BACK APPLICATION TO DRILL DEEPEN [] NAME OF COMPANY OR OPERATOR Address City P. o. 7-8 tach ma DESCRIPTION OF Vv'ELL AND LEASE PLUG BACK CI DATE ~e~r 6, 1960 State Name of lease 1%Vell number Elevation (ground) Well location (~ive footage from section lines) Section--township--range or block & survey Field ~ reservoir (If wildcat, so state) Distance, in miles, and direction from nearest town or post office N'earest distance from proposed location to property or lease line: feet County Distance from proposed location to nearest drilling, completed or applied---for well on the same lease: feet Proposed depth: Rotary or cable tools IA1)prox. date work will stare re, r 1960 Nulrlber of acres in lease: Number of wells en lease, including this well, completed in oF drilling to .this reservoir: If lease, purchased with one or more wells drilled, from Whom purchased: Name Address Status of bond Remarks: (If this is an application to deepen or plug back, briefly doscrtbe work to he done, giving present producing zone' and expected new producing zOne) CERTIFICATE: I, the undersigned, state that I am the~,~,, of the ~-?J'~.~F~ (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction, and that the facts stated therein are true, correct and complete to the best of ray knowledge. Permit Number: Approval Date: A?~rov¢~ Approved By: Notice: Before s~'~' 2;' ,.' ?.';"[.b,"r, % 'i "[ ..... P~'t"~'"C~l~'b6'~r~ ti~ou ~ave°ille r given _ . A'hska D~t. of ]~atural t~esources See mstrhS~r6n on ~everse Side of ~orm Alaska Oil and Gas conservation Commission ApplicatiOn to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958 ~X~ , (SUBMIT. IN TRIPLICATE) UNITED STATES DEPARTMENT Of THE INterior GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS NOTICE OF INTENTION TO DRILL NOTICE OF INTENTION TO CHANGE PLANS NOTICE OF IN1ENTION TO TEST WATER SiIUT;OFF NOTICE OF INTEN]ION TO RE-DRILL OR REPAIR WELL NOTICE OF INTENTION TO SHOOT OR ACIDIZE . NOTICE OF INTENTION TO PULL OR ALTER CASING NOTICE OF INTENTION TO ABANDON WELL _: ..................... SUBSEQUENT REPORT OF WATER SHUT-OF~ SUBSEQUENT REPORT OF SHOOTING OR AClDIZING SUBSEQUENT REPORT OF ALTERING CASING SUBSEQUENT REPORT 0~'RE-DRILLING OR REPAIR SUBSEQUENT REPORT OF ABANDONMENT SUPPLEMENTARY WELL HISTORY . {INDICATE AI3OVE BY CHECK I~AF~K ~iATURE OF F~£POf~T, t40: ;CE. OR OTH~;R DATA) Well No. ~2 .--8. (ZO)is located/ ?.~1. ft. from_is, line and ],d/3:) ft, from J~ ]{ne of (~ See. and ~ce. N,, ) (~p.) (Range) (Mcri,ii,.m) (Fivld) ((.'.uld. y or Sul)divi.~i,,'.0 (State ~ ~errit. r~ ) ~.~. The elevation of thc;~~ above sea level is Z~3... ft. (A~:.~m~) DETAILS OF WORK lng points, and ail other importavt propoaed work) 1. D::Ill to.."~;90' , log, ~ ce~nt !.3 3/8" ]~. ~lecti?ely jot '~'' I ~lnderstand that this plan of work must receive apFrov&l in writing by the Geologlc~l '~ urvcy before operati,)r~s