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Home My WebLink About194-0851. 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 Tbg Swap 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 10,930 feet N/A feet true vertical 10,920 feet See Schematic feet Effective Depth measured 10,618 feet 9,138 feet true vertical 10,611 feet 9,138 feet 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 9,202' MD 9,202' TVD Packers and SSSV (type, measured and true vertical depth)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: 322-106 Sr Pet Eng: 10,500psi Sr Pet Geo:Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 50 10,140psi Ryan Rupert, Operations Engineer ryan.rupert@hilcorp.com 907-777-8503Dan Marlowe, Operations Manager, 907-283-1329 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 235 1601 0 190 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 35 Gas-Mcf MD 46' 2,022' 190 Structural TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 194-085 50-133-10120-01-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028996 Swanson River Field / Hemlock Oil Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Soldotna Creek Unit (SCU) 41A-08 measuredPlugs Junk measured N/A Length 46' 2,022' Size Conductor Surface Intermediate 20" 11-3/4" Production Liner 9,745' 1,468' Casing 46' 2,022' 9,745' 5" 9,745' 10,925'10,915' 7"3,830psi 3,070psi 6,340psi Burst Collapse 1,510psi t Fra O 6. A PG , R Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 3:35 pm, Apr 08, 2022 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.04.08 15:20:29 -08'00' Dan Marlowe (1267) Rig Start Date End Date 3/2/22 3/29/22 03/02/2022 - Wednesday FL shot = 3034' MD in 2-7/8" x 7" annulus. Tried, but unable to get a good tubing FL shot. PJSM, warmed eq and walk arounds. SI Tbg/IA 0psi, R/u Rod handing tools, B/o stuffing box, P/u on rod string wt 23k pulled 5k over and unseated pump, well when on slight vac, started filling tbg with 130 deg water, worked rods and tbg started taking fliud @ 3bpm. Pumped 90bbls of 130deg water to flush tbg. Re seat pump and filled with 40bbls attempting jug up tbg but was unsuccessful. (Possible hole in the tbg). L/d Stuffing box and Polish rod, R/u work floor and rod stripper head, POOH w/hanging back 114 1" EL Rods, 138 7/8" Rods, 100 3/4" Rods, L/d 12 1-1/2" sinker bars, Rod Pump, 22' dip tube (bottom 2' perf) and memory gauge. Found no visual wear on rod string nd minimal paraffin. Sent pump to P&S shop for rebuild. L/d handling tools and stripper head, M/u TIW and secured well, Arranged pad to R/u SL in the AM. SDFN Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 41A-08 50-133-10120-01-00 194-085 03/21/2022 - Monday Cont. Hauled equipment and rig from 32-08, Laid containment and set in base beam and carrier, spotted in rig pump and pit. Fill pit with 8.4 PW. SI Tbg 0psi, SI IA 50psi, Bled off gas from IA, hooked up circulating lines and fluid packed IA with 120bbls of 8.4ppg PW, fluid packed tubing with 1bbls before catching pressure. monitored well static. Cont arranging and rigging up equipment on Pad, Raised and scoped up Derrick, secured guy lines, R/u worked floor and Rod handling tools. Spotted heater and winterization around carrier. SDFN. 03/22/2022 - Tuesday Rig Start Date End Date 3/2/22 3/29/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 41A-08 50-133-10120-01-00 194-085 03/23/2022 - Wednesday 03/25/2022- Friday PJSM, Made walk arounds and warmed up eq. Pulled BPV, M/u circulating eq. Bullhead PW down the IA, catch pressure @ 130bbls away, continued Pumping 1.5bpm/800psi,. Pumped full IA volume (280+bbls). SD pump monitored for 30mins-Tbg/IA static R/d circ eq. P/u 2-7/8" handling eq. M/u 2-7/8" Landing jts, J out of suspension hanger slack off to string wt @ 45k, rotated pipe 8 turns to the right, worked pipe several times and tbg anchor released, P/u and J back into hanger. BOLDS and pulled hanger to rig floor, PUW 45k. Removed cap line, L/d hanger and landing jt. Hung cap sheave L/d 1 jt and threaded cap to spooler. Mechanic arrived , swapped out HPU and take back to dock for schedule maintenance. Spot in L/d machine and racks. POOH L/d 2-7/8" L-80 Tbg and spooling 1/4" capstring f/9271' t/6,203'. L/d Chem Inj Sub. No visible wear in tbg joints or sub. Tbg pulled dry. Secured well and SDFN. PJSM, warmed up eq. SI Tbg/IA 0psi. MIRU Pollard S/L, Tested Lubricator 1500psi-good test, M/u circ hose and spotted vac truck. RIH w/wire scratched to 2,500' to surface while flushing tbg with 30bbls of 180deg water, POOH. L/d wire scratcher. M/u 2.39" GR and RIH beat down thru tight spots @ 1118', 1313',1566',4390' and 4490', appears to be setting down on collars. Cont RIH tagged seat nipple @ 9,219'SLM. POOH L/d GR, tool was clean with metal rubbing on the outside from tapping thru collars. M/u and RIH w/wire scratcher to 2,500' flushed tbg with 10bbls of 180deg water. POOH, L/d scratcher was clean. M/u 1-11/16" Caliper Log Tool, RIH to 9137' (tbg anchor), logged up to surface @ 50fpm. L/d caliper and download data, send to analyst, standby for readings. M/u 2" DD Bailer, RIH tagged @ 9,278'slm, (59' of rat hole below seat nipple) Worked bailer, POOH, found fluid level @ 2,800', Recover small amount of formation sand. L/D bailer. Dropped cup style standing valve, filled tbg with 30bbls, attempted to pressure test tbg pumped 40bbls @ 2.5bpm and could not catch pressure, SD pump well was on slight vac. RDMO S/L, secured well. SDFN. 03/24/2022 - Thursday PJSM, warmed eq. SI Tbg/IA 0psi. Cont, building containment and set in Pit, Pump and Choke house. Set the BPV, N/d Tree, Inspected hanger, plugged off control line port and M/u blanking test sub. N/u 4' spacer spool and 7-1/16" Triple stack BOP's, M/u Kill/Ck hoses and control lines, finished torqueing stack, function test Bop's. R/u work floor and winterization, built 2-7/8" test jt ,P/u BOP testing eq. Flooded stacked and purged air out of system, Shell tested Bop's 250-2500psi-good. Tested BOP's per Sundry as following, Annular 250-2500psi, Rams 250-2500psi, Valves 250-2500psi, Test gas detection and preformed Accumulator Drawdown. Tested with 2-7/8" Test Jt, No failures were recorded. Test time was 2hrs, Test was witnessed by AOGCC Inspector Lou Laubenstein. R/d Testing eq. drained stack, blew lines and equipment dry. Secured well SDFN Rig Start Date End Date 3/2/22 3/29/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 41A-08 50-133-10120-01-00 194-085 03/26/2022 - Saturday PJSM, walk arounds and warmed eq. POOH F/6,203' T/68' L/d 2-7/8" 6.5# L-80 EUE completion. Filling IA 5bph with PW. Last 10jts above the Tbg Anchor were corkscrewed, 1 of the Tbg Anchor Springs was bent out and the slips where dulled. Found a hole in the Tbg 20' below the Anchor. Pump seat nipple was in good shape. Will flip nipple and rerun with completion. P/u 3-1/2" Handling tools, Pulled the slotted sub and the 3-1/2" mud Jts OOH, B/o the bull plug and drained the Mud Jts, recovered formation sand, L/d the Mud Jts. P/u 4-1/2" handling tools, M/u 4-1/2" Bull Plug, 2 jts of 4-1/2" 12.6# IBT Mud Jts, 4-1/2" IBT Slotted Sub and XO to 2-7/8" EUE. P/u 2-7/8" Handling tools, M/u 2-7/8" Cut Type Seating Nipple, 1 Jt of 2-7/8" 6.5# P-110 EUE, 7" Slimhole Tbg Anchor Catcher w/carbide slips. Secured well and SDNF. 03/27/2022 - Sunday PJSM discussed daily activities, warmed up eq. M/u Chemical Injection Foot Valve, secured w/ 3 SS bands above tbg collar @ 9,334', RIH with Rod Pump completion, P/u 2-7/8" 6.5# P-110 EUE 8rd Tbg and spooling 1/4" capstring f/136' T/hanger depth, Band capstring 1st 5 joints then every other joint thereafter. EOT (Bull plug) @ 9,270' Slotted Sub @ 9,204' Seat Nipple @ 9,202' Tbg Anchor @ 9,166'. M/u Hanger and Landing Jt, M/u 1/4" capstring to hanger, Landed completion w/43k down on Hanger, RILDS, Made 1/4" to the left and released out of Hanger, S/O 41" turned pipe 7 rounds to the left and set Tbg Anchor, Made P/u and S/o to release slack in Anchor, Set string on Anchor all good, P/u and engaged hanger. Landed completion 18k in tension. Dropped cup type standing valve, R/u circulating eq. slow filled tbg while working air out, pressure up on tbg t/2000psi, could not get a good test. Troubleshooting, after several attempts could not find any issues with surface equipment leaking. Secured well SDFN. Rig Start Date End Date 3/2/22 3/29/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 41A-08 50-133-10120-01-00 194-085 03/28/2022 - Monday Held PJSM,. R/u SL, PT Lub, RIH 2" JDC, tagged standing valve @ 9,212'SLM, Unseated standing valve, R/u mud pump, flushed tbg w/10bbls, reseat and fill Tbg, MIT-T to 2000psi- held and charted for 30mins, good test. bled off and R/u testing eq. Unseated standing valve and let tbg equalize, POH L/d standing valve and RDMO SL. L/d Landing Jt, Set BPV, Removed winterization, Cleared and R/d work floor, removed kill/choke hoses and control lines from stack,. N/D7- 1/16" BOP's and 4' space spool, N/U Tbg head, packed off tested hanger 500-5000psi for 5mins-good test. Organized eq on trailers for rig move. R/u work floor and rod handling eq., M/u rod stripper head, P/u 1-3/4" RHBC rod pump, bucket tested pump good, M/u 1.35" x 22' dip tube (bottom 2' perf). RIH w/Rod pump completion, as following dip tube. pump, 1-stabilizer bar, 12-1.5" sinker bars, 100 3/4" EL rods w/no guides, 138 7/8" EL rods w/no guides, 113 1" EL rods w/4 XL guides per rod, 6',4',2' Pony Rods w/1 XL guide per pony. M/u Polish rod and stuffing box, seated pump spaced out 38" off bottom, leaving 130" of polish rod above concrete pad. Filled tbg, pumped up Tbg to 1000psi w/rod pump-good test. 03/29/2022 - Tuesday PJSM and PTW, warm-up equipment. Secure polished rod and R/D rod handling equipment. R/D Pits, mud pump. Load trailers, clean pits. Scope and lay down derrick, continue cleaning pits and loading trailers. R/D auxiliary equipment. Mobe equipment to RTD and D&D to prep for move to Beluga. Final report for SCU 41A-08. Well: SCU 41A-08 PTD: 194-085 API: 50-133-10120-01-00 Updated by CRR 4-8-22 SCHEMATIC ROD DETAIL (3/28/22) Depth Length When New Description -40 Re-used Polished Rod, 30’ in well 40’12’3/28/22 1” guided Pony Rods 52’2,825’5/27/14 1” 113 count x 25’ EL Sucker rods w/ 4 XL guides per rod 2,877’3,450’3/10/13 7/8” 138 count x 25’ EL Sucker rods w/ No guides 6,327’2,500’3/10/13 3/4” 100 count x 25’ EL Sucker rods w/ No guides. 8,827’300’Re-used 1-1/2” 12 count x 25’ sinker bars (12) 9,127’3’Re-used 3/4” sinker bar 9,130’42’3/28/22 1-3/4” x 40’ Insert Rod Pump - 25-175-36-365-37 9,172’22’Re-used Dip Tube (bottom 2 ft are perforated) CASING DETAIL Size WT Grade Conn ID Top Btm 20”-Surf 46’ 11-3/4”47#J-55 11”Surf 2,022’ 7”29#N-80 6.184”Surf 290’ 7”26#N-80 6.276”290’1,219’ 7”23#N-80 6.366”1,219’4,952’ 7”26#N-80 6.276”4,952’6,617’ 7”23#N-80 6.366”6,617’8,427’ 7”29#P-110 6.184”8,427’9,745’ 5”18#L-80 4.276”9,457’10,925’ JEWELRY DETAIL (3/27/22) #Depth ID When New Description 1 30’2.441”3/27/22 Tubing Hanger – J Latch 2 3,008’2.441”Re-used 2-7/8” Marker sub for IA FL shots (4.5” OD) 3 9,133’3/27/22 Chemical injection foot valve banded to outside of tubing 4 9,167’2.375”3/27/22 Tubing anchor (Tech-slim) with carbide slips (50k to release) 5 9,202’2.280”Re-used 2-7/8” Seating Nipple 6 9,204’3.833”3/27/22 4-1/2” Perforated joint (6’) 7 9,210’-3/27/22 4-1/2” IBT tubing (60’) 8 9,270’-3/27/22 4-1/2” Bull Plug / end of assembly FISH DETAIL (9/26/16) 9 9,401’2.500”Seating Nipple with cut off 2-7/8” tubing 10 9,406’2.441”Anchor Separator w/ 4’ pup; 2-1/16” IJ tubing – 120’ 11 9,440’1.995”On/Off Tool 12 9,446’1.995”5” Arrowset 1X Packer 13 10,084’1.995”WL Re-entry Guide PERFORATION DETAIL ON NEXT PAGE Prime Mover: Weatherford Rotoflex TUBING DETAIL Size WT Grade Conn ID Top Btm When New 2-7/8”6.5#P110 8RD 2.441”Surf 9,202’3/27/22 1/4” chemical injection line banded to outside of tubing Surf 9,133’3/27/22 Well: SCU 41A-08 PTD: 194-085 API: 50-133-10120-01-00 Updated by CRR 4-8-22 SCHEMATIC PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments G-2 10,188' 10,192' 10,185’ 10,189’ 4' 10,196' 10,209' 10,193’ 10,206’ 13' H-2 10,281' 10,297' 10,277’ 10,293’ 16' 10,283’ 10,299’ 10,279’ 10,295’ 16’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-3 10,312’ 10,328’ 10,308’ 10,324’ 16’ 1-11/16” Enerjet, 6 spf, 90 phase 10,316’ 10,332’ 10,312’ 10,328’ 16’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-4 10,336' 10,344' 10,331’ 10,339’ 8' 10,338’ 10,346’ 10,333’ 10,341’ 8’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-5 10,356' 10,371' 10,351’ 10,366’ 15' 10,356’ 10,382’ 10,351’ 10,377’ 26’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-6 10,403’ 10,407’ 10,398’ 10,402’ 4’ 1-11/16” Enerjet, 4 spf, 0 phase H-7 10,413’ 10,432’ 10,408’ 10,426’ 19’ 1-11/16” Enerjet, 4spf, 0 phase 10,414’ 10,431’ 10,409’ 10,425’ 17’ 3-1/2” HC, 6 spf, 60 phase 3/2013 10,435’ 10,443’ 10,429’ 10,437’ 8’ 1-11/16” HC, 4 spf, 0 phase H-8 10,456’ 10,480’ 10,450’ 10,474’ 24’ 1-11/16” HC, 4 spf, 0 phase 10,446’ 10,481’ 10,440’ 10,475’ 35’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-9 H-9 10,502’ 10,516’ 10,496’ 10,510’ 14’ 1-11/16” HC, 4 spf, 0 phase 10,503’ 10,513’ 10,497’ 10,507’ 10’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-10 10,541’ 10,564’ 10,534’ 10,557’ 23’ 1-1/16” HC, 4 spf, 0 phase 10,541’ 10,568’ 10,534’ 10,561’ 27’ 3-1/2” HC, 6 spf, 60 phase 3/2013 10,544’ 10,564’ 10,537’ 10,557’ 20’ 3-1/2” HC, 6 spf, 60 phase 3/2013 10,564’ 10,620’ 10,557’ 10,613’ 50’ 1-11/16” Enerjet, 6 spf, 90 phase 10,617’ 10,632’ 10,610’ 10,625’ 15’ 1-11/16” Enerjet, 2 spf, 0 phase H-11 10,674’ 10,684’ 10,666’ 10,676’ 10’ 1-11/16” Enerjet, 10 spf, 180 phase H-12 10,709’ 10,725’ 10,701’ 10,717’ 16’ 1-11/16” Enerjet, 2 spf, 0 phase H-13 10,764’ 10,776’ 10,755’ 10,767’ 12’ 1-11/16” Pivot, 10 spf, 180 phase 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Rod Pump Tbg Swap 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 10,930 feet N/A feet true vertical 10,920 feet See Schematic feet Effective Depth measured 10,618 feet 9,138 feet true vertical 10,611 feet 9,138 feet 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 9,202' MD 9,202' TVD Packers and SSSV (type, measured and true vertical depth)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: 322-106 Sr Pet Eng: 10,500psi Sr Pet Geo:Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 50 10,140psi Ryan Rupert, Operations Engineer ryan.rupert@hilcorp.com 907-777-8503Dan Marlowe, Operations Manager, 907-283-1329 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 235 1601 0 190 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 35 Gas-Mcf MD 46' 2,022' 190 Structural TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 194-085 50-133-10120-01-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028996 Swanson River Field / Hemlock Oil Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Soldotna Creek Unit (SCU) 41A-08 measuredPlugs Junk measured N/A Length 46' 2,022' Size Conductor Surface Intermediate 20" 11-3/4" Production Liner 9,745' 1,468' Casing 46' 2,022' 9,745' 5" 9,745' 10,925'10,915' 7"3,830psi 3,070psi 6,340psi Burst Collapse 1,510psi t Fra O 6. A PG , R Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 3:35 pm, Apr 08, 2022 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.04.08 15:20:29 -08'00' Dan Marlowe (1267) Rig Start Date End Date 3/2/22 3/29/22 03/02/2022 - Wednesday FL shot = 3034' MD in 2-7/8" x 7" annulus. Tried, but unable to get a good tubing FL shot. PJSM, warmed eq and walk arounds. SI Tbg/IA 0psi, R/u Rod handing tools, B/o stuffing box, P/u on rod string wt 23k pulled 5k over and unseated pump, well when on slight vac, started filling tbg with 130 deg water, worked rods and tbg started taking fliud @ 3bpm. Pumped 90bbls of 130deg water to flush tbg. Re seat pump and filled with 40bbls attempting jug up tbg but was unsuccessful. (Possible hole in the tbg). L/d Stuffing box and Polish rod, R/u work floor and rod stripper head, POOH w/hanging back 114 1" EL Rods, 138 7/8" Rods, 100 3/4" Rods, L/d 12 1-1/2" sinker bars, Rod Pump, 22' dip tube (bottom 2' perf) and memory gauge. Found no visual wear on rod string nd minimal paraffin. Sent pump to P&S shop for rebuild. L/d handling tools and stripper head, M/u TIW and secured well, Arranged pad to R/u SL in the AM. SDFN Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 41A-08 50-133-10120-01-00 194-085 03/21/2022 - Monday Cont. Hauled equipment and rig from 32-08, Laid containment and set in base beam and carrier, spotted in rig pump and pit. Fill pit with 8.4 PW. SI Tbg 0psi, SI IA 50psi, Bled off gas from IA, hooked up circulating lines and fluid packed IA with 120bbls of 8.4ppg PW, fluid packed tubing with 1bbls before catching pressure. monitored well static. Cont arranging and rigging up equipment on Pad, Raised and scoped up Derrick, secured guy lines, R/u worked floor and Rod handling tools. Spotted heater and winterization around carrier. SDFN. 03/22/2022 - Tuesday Rig Start Date End Date 3/2/22 3/29/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 41A-08 50-133-10120-01-00 194-085 03/23/2022 - Wednesday 03/25/2022- Friday PJSM, Made walk arounds and warmed up eq. Pulled BPV, M/u circulating eq. Bullhead PW down the IA, catch pressure @ 130bbls away, continued Pumping 1.5bpm/800psi,. Pumped full IA volume (280+bbls). SD pump monitored for 30mins-Tbg/IA static R/d circ eq. P/u 2-7/8" handling eq. M/u 2-7/8" Landing jts, J out of suspension hanger slack off to string wt @ 45k, rotated pipe 8 turns to the right, worked pipe several times and tbg anchor released, P/u and J back into hanger. BOLDS and pulled hanger to rig floor, PUW 45k. Removed cap line, L/d hanger and landing jt. Hung cap sheave L/d 1 jt and threaded cap to spooler. Mechanic arrived , swapped out HPU and take back to dock for schedule maintenance. Spot in L/d machine and racks. POOH L/d 2-7/8" L-80 Tbg and spooling 1/4" capstring f/9271' t/6,203'. L/d Chem Inj Sub. No visible wear in tbg joints or sub. Tbg pulled dry. Secured well and SDFN. PJSM, warmed up eq. SI Tbg/IA 0psi. MIRU Pollard S/L, Tested Lubricator 1500psi-good test, M/u circ hose and spotted vac truck. RIH w/wire scratched to 2,500' to surface while flushing tbg with 30bbls of 180deg water, POOH. L/d wire scratcher. M/u 2.39" GR and RIH beat down thru tight spots @ 1118', 1313',1566',4390' and 4490', appears to be setting down on collars. Cont RIH tagged seat nipple @ 9,219'SLM. POOH L/d GR, tool was clean with metal rubbing on the outside from tapping thru collars. M/u and RIH w/wire scratcher to 2,500' flushed tbg with 10bbls of 180deg water. POOH, L/d scratcher was clean. M/u 1-11/16" Caliper Log Tool, RIH to 9137' (tbg anchor), logged up to surface @ 50fpm. L/d caliper and download data, send to analyst, standby for readings. M/u 2" DD Bailer, RIH tagged @ 9,278'slm, (59' of rat hole below seat nipple) Worked bailer, POOH, found fluid level @ 2,800', Recover small amount of formation sand. L/D bailer. Dropped cup style standing valve, filled tbg with 30bbls, attempted to pressure test tbg pumped 40bbls @ 2.5bpm and could not catch pressure, SD pump well was on slight vac. RDMO S/L, secured well. SDFN. 03/24/2022 - Thursday PJSM, warmed eq. SI Tbg/IA 0psi. Cont, building containment and set in Pit, Pump and Choke house. Set the BPV, N/d Tree, Inspected hanger, plugged off control line port and M/u blanking test sub. N/u 4' spacer spool and 7-1/16" Triple stack BOP's, M/u Kill/Ck hoses and control lines, finished torqueing stack, function test Bop's. R/u work floor and winterization, built 2-7/8" test jt ,P/u BOP testing eq. Flooded stacked and purged air out of system, Shell tested Bop's 250-2500psi-good. Tested BOP's per Sundry as following, Annular 250-2500psi, Rams 250-2500psi, Valves 250-2500psi, Test gas detection and preformed Accumulator Drawdown. Tested with 2-7/8" Test Jt, No failures were recorded. Test time was 2hrs, Test was witnessed by AOGCC Inspector Lou Laubenstein. R/d Testing eq. drained stack, blew lines and equipment dry. Secured well SDFN Rig Start Date End Date 3/2/22 3/29/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 41A-08 50-133-10120-01-00 194-085 03/26/2022 - Saturday PJSM, walk arounds and warmed eq. POOH F/6,203' T/68' L/d 2-7/8" 6.5# L-80 EUE completion. Filling IA 5bph with PW. Last 10jts above the Tbg Anchor were corkscrewed, 1 of the Tbg Anchor Springs was bent out and the slips where dulled. Found a hole in the Tbg 20' below the Anchor. Pump seat nipple was in good shape. Will flip nipple and rerun with completion. P/u 3-1/2" Handling tools, Pulled the slotted sub and the 3-1/2" mud Jts OOH, B/o the bull plug and drained the Mud Jts, recovered formation sand, L/d the Mud Jts. P/u 4-1/2" handling tools, M/u 4-1/2" Bull Plug, 2 jts of 4-1/2" 12.6# IBT Mud Jts, 4-1/2" IBT Slotted Sub and XO to 2-7/8" EUE. P/u 2-7/8" Handling tools, M/u 2-7/8" Cut Type Seating Nipple, 1 Jt of 2-7/8" 6.5# P-110 EUE, 7" Slimhole Tbg Anchor Catcher w/carbide slips. Secured well and SDNF. 03/27/2022 - Sunday PJSM discussed daily activities, warmed up eq. M/u Chemical Injection Foot Valve, secured w/ 3 SS bands above tbg collar @ 9,334', RIH with Rod Pump completion, P/u 2-7/8" 6.5# P-110 EUE 8rd Tbg and spooling 1/4" capstring f/136' T/hanger depth, Band capstring 1st 5 joints then every other joint thereafter. EOT (Bull plug) @ 9,270' Slotted Sub @ 9,204' Seat Nipple @ 9,202' Tbg Anchor @ 9,166'. M/u Hanger and Landing Jt, M/u 1/4" capstring to hanger, Landed completion w/43k down on Hanger, RILDS, Made 1/4" to the left and released out of Hanger, S/O 41" turned pipe 7 rounds to the left and set Tbg Anchor, Made P/u and S/o to release slack in Anchor, Set string on Anchor all good, P/u and engaged hanger. Landed completion 18k in tension. Dropped cup type standing valve, R/u circulating eq. slow filled tbg while working air out, pressure up on tbg t/2000psi, could not get a good test. Troubleshooting, after several attempts could not find any issues with surface equipment leaking. Secured well SDFN. Rig Start Date End Date 3/2/22 3/29/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 41A-08 50-133-10120-01-00 194-085 03/28/2022 - Monday Held PJSM,. R/u SL, PT Lub, RIH 2" JDC, tagged standing valve @ 9,212'SLM, Unseated standing valve, R/u mud pump, flushed tbg w/10bbls, reseat and fill Tbg, MIT-T to 2000psi- held and charted for 30mins, good test. bled off and R/u testing eq. Unseated standing valve and let tbg equalize, POH L/d standing valve and RDMO SL. L/d Landing Jt, Set BPV, Removed winterization, Cleared and R/d work floor, removed kill/choke hoses and control lines from stack,. N/D7- 1/16" BOP's and 4' space spool, N/U Tbg head, packed off tested hanger 500-5000psi for 5mins-good test. Organized eq on trailers for rig move. R/u work floor and rod handling eq., M/u rod stripper head, P/u 1-3/4" RHBC rod pump, bucket tested pump good, M/u 1.35" x 22' dip tube (bottom 2' perf). RIH w/Rod pump completion, as following dip tube. pump, 1-stabilizer bar, 12-1.5" sinker bars, 100 3/4" EL rods w/no guides, 138 7/8" EL rods w/no guides, 113 1" EL rods w/4 XL guides per rod, 6',4',2' Pony Rods w/1 XL guide per pony. M/u Polish rod and stuffing box, seated pump spaced out 38" off bottom, leaving 130" of polish rod above concrete pad. Filled tbg, pumped up Tbg to 1000psi w/rod pump-good test. 03/29/2022 - Tuesday PJSM and PTW, warm-up equipment. Secure polished rod and R/D rod handling equipment. R/D Pits, mud pump. Load trailers, clean pits. Scope and lay down derrick, continue cleaning pits and loading trailers. R/D auxiliary equipment. Mobe equipment to RTD and D&D to prep for move to Beluga. Final report for SCU 41A-08. Well: SCU 41A-08 PTD: 194-085 API: 50-133-10120-01-00 Updated by CRR 4-8-22 SCHEMATIC ROD DETAIL (3/28/22) Depth Length When New Description -40 Re-used Polished Rod, 30’ in well 40’12’3/28/22 1” guided Pony Rods 52’2,825’5/27/14 1” 113 count x 25’ EL Sucker rods w/ 4 XL guides per rod 2,877’3,450’3/10/13 7/8” 138 count x 25’ EL Sucker rods w/ No guides 6,327’2,500’3/10/13 3/4” 100 count x 25’ EL Sucker rods w/ No guides. 8,827’300’Re-used 1-1/2” 12 count x 25’ sinker bars (12) 9,127’3’Re-used 3/4” sinker bar 9,130’42’3/28/22 1-3/4” x 40’ Insert Rod Pump - 25-175-36-365-37 9,172’22’Re-used Dip Tube (bottom 2 ft are perforated) CASING DETAIL Size WT Grade Conn ID Top Btm 20”-Surf 46’ 11-3/4”47#J-55 11”Surf 2,022’ 7”29#N-80 6.184”Surf 290’ 7”26#N-80 6.276”290’1,219’ 7”23#N-80 6.366”1,219’4,952’ 7”26#N-80 6.276”4,952’6,617’ 7”23#N-80 6.366”6,617’8,427’ 7”29#P-110 6.184”8,427’9,745’ 5”18#L-80 4.276”9,457’10,925’ JEWELRY DETAIL (3/27/22) #Depth ID When New Description 1 30’2.441”3/27/22 Tubing Hanger – J Latch 2 3,008’2.441”Re-used 2-7/8” Marker sub for IA FL shots (4.5” OD) 3 9,133’3/27/22 Chemical injection foot valve banded to outside of tubing 4 9,167’2.375”3/27/22 Tubing anchor (Tech-slim) with carbide slips (50k to release) 5 9,202’2.280”Re-used 2-7/8” Seating Nipple 6 9,204’3.833”3/27/22 4-1/2” Perforated joint (6’) 7 9,210’-3/27/22 4-1/2” IBT tubing (60’) 8 9,270’-3/27/22 4-1/2” Bull Plug / end of assembly FISH DETAIL (9/26/16) 9 9,401’2.500”Seating Nipple with cut off 2-7/8” tubing 10 9,406’2.441”Anchor Separator w/ 4’ pup; 2-1/16” IJ tubing – 120’ 11 9,440’1.995”On/Off Tool 12 9,446’1.995”5” Arrowset 1X Packer 13 10,084’1.995”WL Re-entry Guide PERFORATION DETAIL ON NEXT PAGE Prime Mover: Weatherford Rotoflex TUBING DETAIL Size WT Grade Conn ID Top Btm When New 2-7/8”6.5#P110 8RD 2.441”Surf 9,202’3/27/22 1/4” chemical injection line banded to outside of tubing Surf 9,133’3/27/22 Well: SCU 41A-08 PTD: 194-085 API: 50-133-10120-01-00 Updated by CRR 4-8-22 SCHEMATIC PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments G-2 10,188' 10,192' 10,185’ 10,189’ 4' 10,196' 10,209' 10,193’ 10,206’ 13' H-2 10,281' 10,297' 10,277’ 10,293’ 16' 10,283’ 10,299’ 10,279’ 10,295’ 16’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-3 10,312’ 10,328’ 10,308’ 10,324’ 16’ 1-11/16” Enerjet, 6 spf, 90 phase 10,316’ 10,332’ 10,312’ 10,328’ 16’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-4 10,336' 10,344' 10,331’ 10,339’ 8' 10,338’ 10,346’ 10,333’ 10,341’ 8’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-5 10,356' 10,371' 10,351’ 10,366’ 15' 10,356’ 10,382’ 10,351’ 10,377’ 26’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-6 10,403’ 10,407’ 10,398’ 10,402’ 4’ 1-11/16” Enerjet, 4 spf, 0 phase H-7 10,413’ 10,432’ 10,408’ 10,426’ 19’ 1-11/16” Enerjet, 4spf, 0 phase 10,414’ 10,431’ 10,409’ 10,425’ 17’ 3-1/2” HC, 6 spf, 60 phase 3/2013 10,435’ 10,443’ 10,429’ 10,437’ 8’ 1-11/16” HC, 4 spf, 0 phase H-8 10,456’ 10,480’ 10,450’ 10,474’ 24’ 1-11/16” HC, 4 spf, 0 phase 10,446’ 10,481’ 10,440’ 10,475’ 35’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-9 H-9 10,502’ 10,516’ 10,496’ 10,510’ 14’ 1-11/16” HC, 4 spf, 0 phase 10,503’ 10,513’ 10,497’ 10,507’ 10’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-10 10,541’ 10,564’ 10,534’ 10,557’ 23’ 1-1/16” HC, 4 spf, 0 phase 10,541’ 10,568’ 10,534’ 10,561’ 27’ 3-1/2” HC, 6 spf, 60 phase 3/2013 10,544’ 10,564’ 10,537’ 10,557’ 20’ 3-1/2” HC, 6 spf, 60 phase 3/2013 10,564’ 10,620’ 10,557’ 10,613’ 50’ 1-11/16” Enerjet, 6 spf, 90 phase 10,617’ 10,632’ 10,610’ 10,625’ 15’ 1-11/16” Enerjet, 2 spf, 0 phase H-11 10,674’ 10,684’ 10,666’ 10,676’ 10’ 1-11/16” Enerjet, 10 spf, 180 phase H-12 10,709’ 10,725’ 10,701’ 10,717’ 16’ 1-11/16” Enerjet, 2 spf, 0 phase H-13 10,764’ 10,776’ 10,755’ 10,767’ 12’ 1-11/16” Pivot, 10 spf, 180 phase STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________SOLDOTNA CK UNIT 41A-08 JBR 04/05/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Test performed with 2 7/8 test joint. #2 Rams N/A, completion being pulled is 2 7/8". Close times; Annular 6 sec, VBR 2 sec, Blinds 2 sec, HCR 1 sec. Test Results TEST DATA Rig Rep:Kevin ReedOperator:Hilcorp Alaska, LLC Operator Rep:Wade Hudgens Contractor/Rig No.:Hilcorp 401 PTD#:1940850 DATE:3/24/2022 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopLOL220326113416 Inspector Lou Laubenstein Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 2 MASP: 1997 Sundry No: 322-106 Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 2 PManual Chokes 0 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 7-1/16"P #1 Rams 1 2-3/8" x 2- 7/8 P #2 Rams 1 3-1/2"NA #3 Rams 1 Blind P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16"P HCR Valves 1 2-1/16"P Kill Line Valves 3 2-1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2600 200 PSI Attained P15 Full Pressure Attained P32 Blind Switch Covers:Pyes Nitgn. Bottles (avg):P6 @ 2150 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA 9 9 99 9 9 9 9 9 9 9 9 Close times; Annular 6 sec, VBR 2 sec, Blinds 2 sec, HCR 1 sec. 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: 3/24/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 41A-08 (PTD 194-085) Caliper Survey 03/23/2022 Please include current contact information if different from above. 194-085 T36463 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.29 10:01:03 -08'00' 7\SHRI5HTXHVW$EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHU5RG3XPS7EJ6ZDS 2SHUDWRU1DPH&XUUHQW:HOO&ODVV 3HUPLWWR'ULOO1XPEHU ([SORUDWRU\ 'HYHORSPHQW $GGUHVV6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU 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ĨŽƌŽŶůǇϭϬĚĂǇƐĂŶĚŝƐĐƵƌƌĞŶƚůǇŶŽƚƐƵƌĨĂĐŝŶŐĨůƵŝĚƐ͘WdĚŽǁŶƚŚĞƚƵďŝŶŐŝŶůĂƚĞͲϮϬϮϭĚŝĚŶ͛ƚƉĂƐƐ͘^ŽĂƚƵďŝŶŐ ŚŽůĞĐĂŶ͛ƚďĞƌƵůĞĚŽƵƚ͘/ĨƌĞƋƵŝƌĞĚ͕ƚŚŝƐƐƵŶĚƌǇĐŽǀĞƌƐƉƵůůŝŶŐƚŚĞƚƵďŝŶŐĂƐǁĞůů͘dŚĞĚŽǁŶŚŽůĞƌĞƐĞƌǀŽŝƌ ĐŽŶĨŝŐƵƌĂƚŝŽŶŚĂƐŶ͛ƚďĞĞŶĐŚĂŶŐĞĚŝŶƚŚŝƐǁĞůůƐŝŶĐĞƚŚĞE&dŝŶϮϬϭϯ͕ĂŶĚŶŽƉƌŽĚƵĐƚŝǀŝƚǇĞŶŚĂŶĐĞŵĞŶƚƐŶŽƌ ĐŚĂŶŐĞƐŚĂǀĞŽĐĐƵƌƌĞĚ͘ dŚĞŐŽĂůŽĨƚŚŝƐƉƌŽũĞĐƚŝƐƚŽĚĞƚĞƌŵŝŶĞƚŚĞĐƵƌƌĞŶƚĨĂŝůƵƌĞŵĞĐŚĂŶŝƐŵĚŽǁŶŚŽůĞĂŶĚƌĞŵĞĚŝĂƚĞ͕ƌĞƚƵƌŶŝŶŐƚŚĞƌŽĚ ƉƵŵƉĐŽŵƉůĞƚŝŽŶƚŽƐĞƌǀŝĐĞ͘EŽĐŚĂŶŐĞƐƚŽƚŚĞƌĞƐĞƌǀŽŝƌƉƌŽĚƵĐƚŝǀŝƚǇͬĐŽŶĨŝŐƵƌĂƚŝŽŶĂƌĞƉůĂŶŶĞĚ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ x WĞƌƚŝŶĞŶƚŚŝƐƚŽƌǇ o ϭϬͬϭϯͬϭϲ͗ZtKƉƵůůĞĚƚƵďŝŶŐĂŶĚĂƚƚĞŵƉƚĞĚƚŽƌĞůĞĂƐĞĂŶĚƉƵůůĂŶĐŚŽƌƐĞƉĂƌĂƚŽƌͬƌƌŽǁƐĞƚ ƉĂĐŬĞƌŝŶϱ͟ůŝŶĞƌ͘ŽƵůĚŶ͛ƚŐĞƚĂƐƐĞŵďůǇƚŽƌĞůĞĂƐĞ͕ƐŽĐƵƚϮͲϳͬϴ͟ƚƵďŝŶŐĂŶĚƌĞĐŽŵƉůĞƚĞĚ ĂďŽǀĞ o ϯͬϭϴͬϭϯ͗tĞůůƉĂƐƐĞĚŝƚ͛ƐŵŽƐƚƌĞĐĞŶƚK'E&d o ϯͬϭϭͬϭϯ͗ZtKƚŽƌĞƚƌŝĞǀĞ'>ĐŽŵƉůĞƚŝŽŶĂŶĚŝŶƐƚĂůůƌŽĚƉƵŵƉĐŽŵƉůĞƚŝŽŶĨŝŶŝƐŚĞĚ o ϯͬϵͬϭϯ͗ůĂƐƚƌĞƐĞƌǀŽŝƌŵŽĚŝĨŝĐĂƚŝŽŶ͗WĞƌĨƐĂĚĚĞĚĚƵƌŝŶŐZtKǁŚŝůĞĐŽŵƉůĞƚŝŽŶǁĂƐŽƵƚŽĨŚŽůĞ x ^ĂĨĞƚǇƐǇƐƚĞŵ͗ o tĞůůŽƉĞƌĂƚĞƐǁŝƚŚŽƵƚĂƚƌĂĚŝƚŝŽŶĂů^^sƐǇƐƚĞŵƉĞƌK';ƐĞĞĂƚƚĂĐŚĞĚͿ o tĞůůŝƐĞƋƵŝƉƉĞĚǁŝƚŚĨƵŶĐƚŝŽŶĂůůǇĞƋƵŝǀĂůĞŶƚĐŽŵƉŽŶĞŶƚƐƉĞƌĂƚƚĂĐŚĞĚůĞƚƚĞƌĨƌŽŵϵͬϮϰͬϭϯ x ƵƌƌĞŶƚǁĞůůĐŽŶĨŝŐƵƌĂƚŝŽŶ;&ĂůůͲϮϬϮϭͿ o ĂŶƉƵŵƉĚŽǁŶ/ĨƌĞĞůǇ o ĂŶƉƵŵƉĚŽǁŶĂƚϬ͘ϴďƉŵĂĨƚĞƌĨůƵŝĚƉĂĐŬĞĚ ^hϰϭͲϴ ZŽĚƉƵŵƉǁĞůůZtK sĞƌƐŝŽŶϮ ZtKWƌŽĐĞĚƵƌĞ͗ ϭ͘ ŶƐƵƌĞZŽƚŽĨůĞǆƐƵƌĨĂĐĞƉƵŵƉƵŶŝƚŝƐƵŶĐŽƵƉůĞĚ͕ƐŬŝĚĚĞĚďĂĐŬ͕ĂŶĚƚŚĞŵŽƚŽƌŝƐ>KdK Ϯ͘ D/Zh,ŝůĐŽƌƉƌŝŐηϰϬϭ WƵůůZŽĚƐĂŶĚWƵŵƉ͗ ϯ͘ ůĞĞĚĚŽǁŶĂŶǇƌĞƐŝĚƵĂůƚƵďŝŶŐĂŶĚ/ƉƌĞƐƐƵƌĞ ϰ͘ ƚƚĞŵƉƚƚŽĨůƵŝĚƉĂĐŬƚŚĞ/ǁŝƚŚƉƌŽĚƵĐĞĚǁĂƚĞƌ;ϴ͘ϰƉƉŐͿ͘/ĨĨŝůůƵƉǀŽůƵŵĞŝƐƵŶĐůĞĂƌ͕ƉƵŵƉĂŶĞŶƚŝƌĞ /ǀŽůƵŵĞ;ϮϴϴďďůƐͿ ϱ͘ ƚƚĞŵƉƚƚŽĨůƵŝĚƉĂĐŬƚŚĞƚƵďŝŶŐǁŝƚŚƉƌŽĚƵĐĞĚǁĂƚĞƌ;ϴ͘ϰƉƉŐͿ͘/ĨĨŝůůƵƉǀŽůƵŵĞŝƐƵŶĐůĞĂƌ͕ƉƵŵƉĂŶ ĞŶƚŝƌĞƚƵďŝŶŐǀŽůƵŵĞ;ϰϴďďůƐͿ ϲ͘ sĞƌŝĨǇŶŽĨůŽǁďĞĨŽƌĞEƉĂĐŬŽĨĨͬƐƚƵĨĨŝŶŐďŽǆ;KWŶŽƚƌĞƋƵŝƌĞĚĨŽƌƌŽĚƉƵůůŝŶŐͬƌƵŶŶŝŶŐͿ ϳ͘ WhŽŶƌŽĚƐĂŶĚĂƚƚĞŵƉƚƚŽƵŶƐĞĂƚƉƵŵƉŶŽƚŝŶŐƐƚƌŝŶŐǁĞŝŐŚƚ ϴ͘ /ĨƉƵŵƉŝƐƐƵĐĐĞƐƐĨƵůůǇƵŶƐĞĂƚĞĚ͕ƉƵŵƉĂƚƵďŝŶŐǀŽůƵŵĞ;ϰϴďďůƐͿĚŽǁŶƚŚĞƚƵďŝŶŐƚŽĨůƵƐŚ ŚǇĚƌŽĐĂƌďŽŶƐŽƵƚŽĨƚŚĞƚƵďŝŶŐ͕ĂŶĚĐůĞĂŶƌŽĚƐ͘hƐĞŚŽƚĨůƵŝĚŝĨƉŽƐƐŝďůĞ͘ ϵ͘ WKK,ǁŝƚŚƌŽĚƐ͕ǀŝƐƵĂůůǇŝŶƐƉĞĐƚŝŶŐĂŶĚƌĂĐŬŝŶŐďĂĐŬ EŽƚĞ͗/ĨƌŽĚƐƚƌŝŶŐŝƐƚŽďĞůĞĨƚĂĐƌŽƐƐƚŚĞǁĞůůŚĞĂĚ͕ĞŝƚŚĞƌƚŚĞǁĞůůŵƵƐƚďĞŵĂŶǁĂƚĐŚĞĚ͕KZƚŚĞƉŽůŝƐŚƌŽĚ ƐƚĂďďĞĚďĂĐŬŽŶƚŽƚŚĞƌŽĚƐƚƌŝŶŐĂŶĚƚŚĞƉĂĐŬŽĨĨͬƐƚƵĨĨŝŶŐďŽǆƌĞŝŶƐƚĂůůĞĚ͘ ϭϬ͘ /ĨƌŽĚƐĂƌĞĨŽƵŶĚƚŽďĞƉĂƌƚĞĚ͕ZhĨŝƐŚŝŶŐĂƐƐĞŵďůǇ͕ĂŶĚZ/,ǁŝƚŚĞǆŝƐƚŝŶŐƌŽĚƐĂƐĂǁŽƌŬƐƚƌŝŶŐƚŽĨŝƐŚ ĚŽǁŶŚŽůĞƌŽĚƐĂŶĚƉƵŵƉ ϭϭ͘ /ĨƵŶĂďůĞƚŽĨůƵƐŚƚƵďŝŶŐŝŶƐƚĞƉƐĂďŽǀĞ͕ďƵƚĐĂŶŝŶũĞĐƚŶŽǁĂĨƚĞƌƉƵŵƉŝƐƵŶƐĞĂƚĞĚ͕ƉƵŵƉĂƚƵďŝŶŐ ǀŽůƵŵĞ;ϰϴďďůƐͿĚŽǁŶƚŚĞƚƵďŝŶŐƚŽĨůƵƐŚŚǇĚƌŽĐĂƌďŽŶƐŽƵƚŽĨƚŚĞƚƵďŝŶŐ͕ĂŶĚĐůĞĂŶƌŽĚƐ͘hƐĞŚŽƚĨůƵŝĚ ŝĨƉŽƐƐŝďůĞ͘ ϭϮ͘ WKK,ǁŝƚŚƌĞŵĂŝŶŝŶŐƌŽĚƐĂŶĚƉƵŵƉ ϭϯ͘ Zh^>ǁŝƚŚĂůƵďƌŝĐĂƚŽƌ ϭϰ͘ ^ĞƚƉůƵŐĂƚƐĞĂƚŝŶŐŶŝƉƉůĞĂƚϵ͕ϮϬϭ͛ĂŶĚD/dͲdƚƵďŝŶŐƚŽϮϬϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ ϭϱ͘ WƵůůƉůƵŐ͕ZDK^> ^hϰϭͲϴ ZŽĚƉƵŵƉǁĞůůZtK sĞƌƐŝŽŶϮ WƵůůΘZƵŶĐŽŵƉůĞƚŝŽŶ;ŝĨŶĞĐĞƐƐĂƌǇͿ͗ ϭϲ͘ /ŶƐƚĂůůWsͬdt ϭϳ͘ EǁĞůůŚĞĂĚ͕EhKW͛ƐĂŶĚƚĞƐƚ Ă͘ WƌŽǀŝĚĞϮϰŚƌŶŽƚŝĐĞƚŽK';ŶŽƚŝĨŝĐĂƚŝŽŶƚŽ>DŝƐEKdƌĞƋƵŝƌĞĚͿ ď͘ WdƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚͬϮϱϬϬƉƐŝĂŶŶƵůĂƌ Đ͘ dĞƐƚŽŶϮͲϳͬϴ͟ƚĞƐƚũŽŝŶƚ ϭϴ͘ WƵůůWsͬdt ϭϵ͘ WƵŵƉϭ/ǀŽůƵŵĞ;ϮϴϬďďůƐͿŽĨƉƌŽĚƵĐĞĚǁĂƚĞƌ;ϴ͘ϰƉƉŐͿƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽĨŽƌŵĂƚŝŽŶƚŽĨůƵƐŚ ŚǇĚƌŽĐĂƌďŽŶƐĨƌŽŵĂŶŶƵůƵƐͲďũŵ ϮϬ͘ WƵŵƉϭƚƵďŝŶŐǀŽůƵŵĞ;ϲϭďďůƐͿŽĨƉƌŽĚƵĐĞĚǁĂƚĞƌ;ϴ͘ϰƉƉŐͿƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽĨŽƌŵĂƚŝŽŶƚŽĨůƵƐŚ ŚǇĚƌŽĐĂƌďŽŶƐĨƌŽŵƚƵďŝŶŐͲďũŵ Ϯϭ͘ hŶƐĞĂƚƚƵďŝŶŐŚĂŶŐĞƌĂŶĚĚŽǁŶŚŽůĞĂŶĐŚŽƌ͕ĂŶĚƌĞƚƌŝĞǀĞϮͲϳͬϴ͟ĐŽŵƉůĞƚŝŽŶ ϮϮ͘ DĂŬĞƵƉŶĞǁůŽǁĞƌĐŽŵƉůĞƚŝŽŶĂŶĚƚƵďŝŶŐĂŶĐŚŽƌŽŶϮͲϳͬϴ͟ƚƵďŝŶŐ Ϯϯ͘ Z/,ĂŶĚůĂŶĚϮͲϳͬϴ͟ĐŽŵƉůĞƚŝŽŶďŽƚƚŽŵŽĨĂƐƐĞŵďůǇĂƚцϵ͕ϮϳϬ͛D Ϯϰ͘ Zh^>ǁŝƚŚĂůƵďƌŝĐĂƚŽƌ Ϯϱ͘ ^ĞƚƉůƵŐĂƚƐĞĂƚŝŶŐŶŝƉƉůĞĂŶĚD/dͲdƚƵďŝŶŐƚŽϮϬϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ Ϯϲ͘ WƵůůƉůƵŐ͕ZDK^> Ϯϳ͘ EKW͛Ɛ ZƵŶƌŽĚƐͬƉƵŵƉ͗ Ϯϴ͘ WhƉƵŵƉĂŶĚĚŝƉƚƵďĞĂƐƐĞŵďůǇ Ϯϵ͘ Z/,ŽŶƚĂƉĞƌĞĚƌŽĚƐƚƌŝŶŐ ϯϬ͘ ^ƉĂĐĞŽƵƚƌŽĚƐ͕ůĂŶĚƉƵŵƉĂŶĚŝŶƐƚĂůůƉŽůŝƐŚƌŽĚ ϯϭ͘ EhƉĂĐŬŽĨĨͬƐƚƵĨĨŝŶŐďŽǆ ϯϮ͘ WdƚƵďŝŶŐƚŽϭϬϬϬƉƐŝ ϯϯ͘ ZDKZŝŐηϰϬϭ ϯϰ͘ ZŽůůƵƉZŽƚŽĨůĞǆƐƵƌĨĂĐĞƉƵŵƉŝŶŐƵŶŝƚ͕ƌĞĐŽƵƉůĞ͕ĂŶĚƌĞŵŽǀĞ>KdK ϯϱ͘ ZĞƚƵƌŶǁĞůůƚŽƉƌŽĚƵĐƚŝŽŶǁŝƚŚƐĂŵĞƐƵƌĨĂĐĞƐĂĨĞƚǇƐǇƐƚĞŵƐĂƐƉƌĞǀŝŽƵƐůǇŝŶƐƚĂůůĞĚ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚǁĞůůŚĞĂĚĚƌĂǁŝŶŐ;ŶŽĐŚĂŶŐĞƐͿ Ϯ͘ ƵƌƌĞŶƚ^ĐŚĞŵĂƚŝĐ ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϰ͘ ZŝŐϰϬϭKW^ĐŚĞŵĂƚŝĐ;ϳͲϭͬϭϲ͟dƌŝƉůĞϱŬͿ ϱ͘ ZŝŐϰϬϭĨůŽǁĚŝĂŐƌĂŵ ϲ͘ E&d;ϯͬϭϴͬϮϬϭϯͿ ϳ͘ ^s^ůĞƚƚĞƌ;ϵͬϮϰͬϭϯͿ ϴ͘ ĞƌŝĂůϲϲϬ͛ŵĂƉ ϵ͘ ZtKƐƵŶĚƌǇĐŚĂŶŐĞĨŽƌŵ 6ZDQVRQ5LYHU 6&8 &XUUHQWDQG3URSRVHG:HOOKHDG ^ǁĂŶƐŽŶZŝǀĞƌ ^hϰϭͲϬϴ ϭϭв͛͛yϳΖ͛yϮϳͬϴ 'ƌĂĚĞ>ĞǀĞů ^ƉĞĐŝĂůƌŽƐƐ͕ϮϵͬϭϲϱD&y ϮϳͬϴhϴƌĚǁͬϮͲϮϭͬϭϲ ϱD^^K dƵďŝŶŐŚĂŶŐĞƌ͕^ĞĂďŽĂƌĚ͕ KƚĞŶƐŝŽŶ͕ϳϭͬϭϲϱDyϮ ϳͬϴhůŝĨƚĂŶĚƐƵƐƉ͕ǁͬϮЪ ƚǇƉĞ,Ws͕ϯͬϴĐŽŶƚƌŽůůŝŶĞ͕ ϱΖ͛ƐůŝĐŬŶĞĐŬ͕ůĞĨƚƚŽƌĞůĞĂƐĞ͕ ƌŝŐŚƚƚŽĞŶŐĂŐĞ &ƵůůƐƚĂŝŶůĞƐƐƐƚĞĞůĨŽƌ ĐŚĞŵŝĐĂůŝŶũĞĐƚŝŽŶ sĂůǀĞ͕ǁŝŶŐ͕t<DͲD͕Ϯϭͬϭϲ ϱD&͕,tK͕ƚƌŝŵ sĂůǀĞ͕ǁŝŶŐ͕t<DͲD͕Ϯϭͬϭϲ ϱD&͕,tK͕ƚƌŝŵ ĚĂƉƚĞƌ͕^ĞĂďŽĂƌĚ͕ϳϭͬϭϲ ϱD&yϮϵͬϭϲϱDǁͬϱΖ͛WW ƐĞĂůƉŽĐŬĞƚ͕ЪĐŽŶƚƌŽůůŝŶĞ Ğǆŝƚ͕ĂůůŽǇŵĂƚĞƌŝĂů ƚƚĂĐŚŵĞŶƚƐƉŽŽů͕&DͲd͕ ϳϭͬϭϲϱDyϳϭͬϭϲϱD dƵďŝŶŐŚĞĂĚ͕^ŚĂĨĨĞƌͲdϱϱ>ϭ͕ ϭϯϱͬϴϯDyϳϭͬϭϲϱDǁͬϮͲ ϮϭͬϭϲϱD^^K sĂůǀĞ͕ǁŝŶŐ͕t<DͲD͕Ϯϭͬϭϲ ϱD&͕,tK͕ƚƌŝŵ YƚǇϮ ĂƐŝŶŐŚĞĂĚ͕^ŚĂĨĨĞƌ<͕ϭϯ ϱͬϴϯDyϭϭв^Kt͕ǁͬϮͲϮ >WK tĞůů͗^hϰϭͲϬϴ Wd͗ϭϵϰͲϬϴϱ W/͗ϱϬͲϭϯϯͲϭϬϭϮϬͲϬϭͲϬϬ ŽǁŶŚŽůĞZĞǀŝƐĞĚϬϱͲϮϳͲϭϰ hƉĚĂƚĞĚďǇDϬϯͲϬϯͲϮϮ ^,Dd/ dh/E'ZKd/> ηdŽƉ>ĞŶŐƚŚKĞƐĐƌŝƉƚŝŽŶ ϱ͛ϰϬ͛ϭͲϭͬϮ͟WŽůŝƐŚĞĚZŽĚ͕ϯϬ͛ŝŶǁĞůů;EĞǁϱͲϮϳͲϭϰͿ ϰϱ͛Ϯ͕ϴϱϮ͛ϭ͟ϭϭϰĐŽƵŶƚǆϮϱ͛>^ƵĐŬĞƌƌŽĚƐǁͬϰy>ŐƵŝĚĞƐƉĞƌƌŽĚ;EĞǁϱͲϮϳͲϭϰͿ Ϯ͕ϴϵϳ͛ϯ͕ϰϰϯ͛ϳͬϴ͟ϭϯϴĐŽƵŶƚǆϮϱ͛>^ƵĐŬĞƌƌŽĚƐǁͬEŽŐƵŝĚĞƐ;EĞǁϯͬϭϬͬϭϯͿ ϲ͕ϯϰϬ͛Ϯ͕ϱϭϮ͛ ϯͬϰ͟ϵϯĐŽƵŶƚǆϮϱ͛>^ƵĐŬĞƌƌŽĚƐǁͬEŽŐƵŝĚĞƐ͘dŽƉϳũŽŝŶƚƐŚĂǀĞϰy> ŐƵŝĚĞƐƉĞƌƌŽĚ;EĞǁϯͬϭϬͬϭϯͿ ϴ͕ϴϱϮ͛ϯϬϮ͛ϭͲϭͬϮ͟ϭϮĐŽƵŶƚǆϮϱ͛tĞŝŐŚƚďĂƌƐ;ϭϮͿ ϵ͕ϭϵϲ͛ϰϯ͛ ϭͲϯͬϰ͟ϭͲϯͬϰ͟ǆϰϬ͛/ŶƐĞƌƚZŽĚWƵŵƉηϳϮϯϰ;EĞǁϴͬϭϳͬϮϭͿ ϮϱͲϭϳϱͲϰϬͲϱͲϬͲϬ ϭ͛ϭͲϭͬϮ͟ŝƉdƵďĞ ^/E'Edh/E'd/> ^ŝǌĞtd'ƌĂĚĞ/dŽƉƚŵ ϮϬ͟^ƵƌĨϰϲ͛ ϭϭͲϯͬϰ͟ϰϳη:Ͳϱϱϭϭ͟^ƵƌĨϮ͕ϬϮϮ͛ ϳ͟ϮϵηEͲϴϬϲ͘ϭϴϰ͟^ƵƌĨϮϵϬ͛ ϳ͟ϮϲηEͲϴϬϲ͘Ϯϳϲ͟ϮϵϬ͛ϭ͕Ϯϭϵ͛ ϳ͟ϮϯηEͲϴϬϲ͘ϯϲϲ͟ϭ͕Ϯϭϵ͛ϰ͕ϵϱϮ͛ ϳ͟ϮϲηEͲϴϬϲ͘Ϯϳϲ͟ϰ͕ϵϱϮ͛ϲ͕ϲϭϳ͛ ϳ͟ϮϯηEͲϴϬϲ͘ϯϲϲ͟ϲ͕ϲϭϳ͛ϴ͕ϰϮϳ͛ ϳ͟ϮϵηWͲϭϭϬϲ͘ϭϴϰ͟ϴ͕ϰϮϳ͛ϵ͕ϳϰϱ͛ ϱ͟ϭϴη>ͲϴϬϰ͘Ϯϳϲ͟ϵ͕ϰϱϳ͛ϭϬ͕ϵϮϱ͛ dh/E' ϮͲϳͬϴ͟ϲ͘ϱη>ͲϴϬϮ͘ϰϰϭ͟^ƵƌĨϵ͕ϮϬϭ͛ ϮͲϯͬϴ͟ϰ͘ϳηEͲϴϬϭ͘ϵϵϱ͟ϵ͕ϰϯϬ͛ϭϬ͕Ϭϴϱ͛ :t>Zzd/> EŽ͘ĞƉƚŚ//ƚĞŵ ϭϭϱ͛Ϯ͘ϰϰϭ͟dƵďŝŶŐ,ĂŶŐĞƌʹ:>ĂƚĐŚ Ϯϯ͕ϬϬϰ͛Ϯ͘ϰϰϭ͟ϮͲϳͬϴ͟ŚĞŵŝĐĂů/Ŷũ^ƵďǁͬЬ͟ĐŽŶƚƌŽůůŝŶĞ;>ŝǀĞsĂůǀĞͿ ϯϵ͕ϭϯϳ͛Ϯ͘ϰϰϭ͟ϳ͟tĞĂƚŚĞƌĨŽƌĚdƵďŝŶŐŶĐŚŽƌ;ϯϱ<^ŚĞĂƌͿ;EĞǁϭϬͬϮͬϭϲͿ ϰϵ͕ϮϬϭ͛Ϯ͘ϯϭϱ͟ϮͲϳͬϴ͟^ĞĂƚŝŶŐEŝƉƉůĞ ϱϵ͕ϮϬϯ͛Ϯ͘ϵϵϮ͟ϯ͘ϱ͟^ůŽƚƚĞĚ^Ƶď ϲϵ͕Ϯϳϭ͛ͲϯͲϭͬϮ͟ƵůůWůƵŐ ϳϵ͕ϰϬϭ͛Ϯ͘ϱϬϬ͟^ĞĂƚŝŶŐEŝƉƉůĞǁŝƚŚĐƵƚŽĨĨϮͲϳͬϴ͟ƚƵďŝŶŐ ϴϵ͕ϰϬϲ͛Ϯ͘ϰϰϭ͟ŶĐŚŽƌ^ĞƉĂƌĂƚŽƌǁͬϰ͛ƉƵƉ͖ϮͲϭͬϭϲ͟/:ƚƵďŝŶŐʹϭϮϬ͛ ϵϵ͕ϰϬϳ͛Ϯ͘ϰϰϭ͟yͲŽǀĞƌϮͲϯͬϴ͟ƉŝŶǆϮͲϳͬϴ͟ďŽǆ ϭϬϵ͕ϰϰϬ͛ϭ͘ϵϵϱ͟KŶͬKĨĨdŽŽů ϭϭϵ͕ϰϰϲ͛ϭ͘ϵϵϱ͟ϱ͟ƌƌŽǁƐĞƚϭyWĂĐŬĞƌ ϭϮϭϬ͕Ϭϴϰ͛ϭ͘ϵϵϱ͟t>ZĞͲĞŶƚƌǇ'ƵŝĚĞ WZ&KZd/KEd/>KEEydW' 1HZ7XELQJ5DQ 1HZURGVUDQ 1HZSXPSUDQ tĞůů͗^hϰϭͲϬϴ Wd͗ϭϵϰͲϬϴϱ W/͗ϱϬͲϭϯϯͲϭϬϭϮϬͲϬϭͲϬϬ ŽǁŶŚŽůĞZĞǀŝƐĞĚϬϱͲϮϳͲϭϰ hƉĚĂƚĞĚďǇDϬϯͲϬϯͲϮϮ ^,Dd/ WZ&KZd/KEd ŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿŵƚŽŵŵĞŶƚƐ 'ͲϮϭϬ͕ϭϴϴΖϭϬ͕ϭϵϮΖϭϬ͕ϭϴϱ͛ϭϬ͕ϭϴϵ͛ϰΖ ϭϬ͕ϭϵϲΖϭϬ͕ϮϬϵΖϭϬ͕ϭϵϯ͛ϭϬ͕ϮϬϲ͛ϭϯΖ ,ͲϮϭϬ͕ϮϴϭΖϭϬ͕ϮϵϳΖϭϬ͕Ϯϳϳ͛ϭϬ͕Ϯϵϯ͛ϭϲΖ ϭϬ͕Ϯϴϯ͛ϭϬ͕Ϯϵϵ͛ϭϬ͕Ϯϳϵ͛ϭϬ͕Ϯϵϱ͛ϭϲ͛ϯͲϭͬϮ͟,͕ϲƐƉĨ͕ϲϬƉŚĂƐĞϯͬϮϬϭϯ ,ͲϯϭϬ͕ϯϭϮ͛ϭϬ͕ϯϮϴ͛ϭϬ͕ϯϬϴ͛ϭϬ͕ϯϮϰ͛ϭϲ͛ϭͲϭϭͬϭϲ͟ŶĞƌũĞƚ͕ϲƐƉĨ͕ϵϬƉŚĂƐĞ ϭϬ͕ϯϭϲ͛ϭϬ͕ϯϯϮ͛ϭϬ͕ϯϭϮ͛ϭϬ͕ϯϮϴ͛ϭϲ͛ϯͲϭͬϮ͟,͕ϲƐƉĨ͕ϲϬƉŚĂƐĞϯͬϮϬϭϯ ,ͲϰϭϬ͕ϯϯϲΖϭϬ͕ϯϰϰΖϭϬ͕ϯϯϭ͛ϭϬ͕ϯϯϵ͛ϴΖ ϭϬ͕ϯϯϴ͛ϭϬ͕ϯϰϲ͛ϭϬ͕ϯϯϯ͛ϭϬ͕ϯϰϭ͛ϴ͛ϯͲϭͬϮ͟,͕ϲƐƉĨ͕ϲϬƉŚĂƐĞϯͬϮϬϭϯ ,ͲϱϭϬ͕ϯϱϲΖϭϬ͕ϯϳϭΖϭϬ͕ϯϱϭ͛ϭϬ͕ϯϲϲ͛ϭϱΖ ϭϬ͕ϯϱϲ͛ϭϬ͕ϯϴϮ͛ϭϬ͕ϯϱϭ͛ϭϬ͕ϯϳϳ͛Ϯϲ͛ϯͲϭͬϮ͟,͕ϲƐƉĨ͕ϲϬƉŚĂƐĞϯͬϮϬϭϯ ,ͲϲϭϬ͕ϰϬϯ͛ϭϬ͕ϰϬϳ͛ϭϬ͕ϯϵϴ͛ϭϬ͕ϰϬϮ͛ϰ͛ϭͲϭϭͬϭϲ͟ŶĞƌũĞƚ͕ϰƐƉĨ͕ϬƉŚĂƐĞ ,Ͳϳ ϭϬ͕ϰϭϯ͛ϭϬ͕ϰϯϮ͛ϭϬ͕ϰϬϴ͛ϭϬ͕ϰϮϲ͛ϭϵ͛ϭͲϭϭͬϭϲ͟ŶĞƌũĞƚ͕ϰƐƉĨ͕ϬƉŚĂƐĞ ϭϬ͕ϰϭϰ͛ϭϬ͕ϰϯϭ͛ϭϬ͕ϰϬϵ͛ϭϬ͕ϰϮϱ͛ϭϳ͛ϯͲϭͬϮ͟,͕ϲƐƉĨ͕ϲϬƉŚĂƐĞϯͬϮϬϭϯ ϭϬ͕ϰϯϱ͛ϭϬ͕ϰϰϯ͛ϭϬ͕ϰϮϵ͛ϭϬ͕ϰϯϳ͛ϴ͛ϭͲϭϭͬϭϲ͟,͕ϰƐƉĨ͕ϬƉŚĂƐĞ ,ͲϴϭϬ͕ϰϱϲ͛ϭϬ͕ϰϴϬ͛ϭϬ͕ϰϱϬ͛ϭϬ͕ϰϳϰ͛Ϯϰ͛ϭͲϭϭͬϭϲ͟,͕ϰƐƉĨ͕ϬƉŚĂƐĞ ϭϬ͕ϰϰϲ͛ϭϬ͕ϰϴϭ͛ϭϬ͕ϰϰϬ͛ϭϬ͕ϰϳϱ͛ϯϱ͛ϯͲϭͬϮ͟,͕ϲƐƉĨ͕ϲϬƉŚĂƐĞϯͬϮϬϭϯ ,Ͳϵ ,Ͳϵ ϭϬ͕ϱϬϮ͛ϭϬ͕ϱϭϲ͛ϭϬ͕ϰϵϲ͛ϭϬ͕ϱϭϬ͛ϭϰ͛ϭͲϭϭͬϭϲ͟,͕ϰƐƉĨ͕ϬƉŚĂƐĞ ϭϬ͕ϱϬϯ͛ϭϬ͕ϱϭϯ͛ϭϬ͕ϰϵϳ͛ϭϬ͕ϱϬϳ͛ϭϬ͛ϯͲϭͬϮ͟,͕ϲƐƉĨ͕ϲϬƉŚĂƐĞϯͬϮϬϭϯ ,ͲϭϬ ϭϬ͕ϱϰϭ͛ϭϬ͕ϱϲϰ͛ϭϬ͕ϱϯϰ͛ϭϬ͕ϱϱϳ͛Ϯϯ͛ϭͲϭͬϭϲ͟,͕ϰƐƉĨ͕ϬƉŚĂƐĞ ϭϬ͕ϱϰϭ͛ϭϬ͕ϱϲϴ͛ϭϬ͕ϱϯϰ͛ϭϬ͕ϱϲϭ͛Ϯϳ͛ϯͲϭͬϮ͟,͕ϲƐƉĨ͕ϲϬƉŚĂƐĞϯͬϮϬϭϯ ϭϬ͕ϱϰϰ͛ϭϬ͕ϱϲϰ͛ϭϬ͕ϱϯϳ͛ϭϬ͕ϱϱϳ͛ϮϬ͛ϯͲϭͬϮ͟,͕ϲƐƉĨ͕ϲϬƉŚĂƐĞϯͬϮϬϭϯ ϭϬ͕ϱϲϰ͛ϭϬ͕ϲϮϬ͛ϭϬ͕ϱϱϳ͛ϭϬ͕ϲϭϯ͛ϱϬ͛ϭͲϭϭͬϭϲ͟ŶĞƌũĞƚ͕ϲƐƉĨ͕ϵϬƉŚĂƐĞ ϭϬ͕ϲϭϳ͛ϭϬ͕ϲϯϮ͛ϭϬ͕ϲϭϬ͛ϭϬ͕ϲϮϱ͛ϭϱ͛ϭͲϭϭͬϭϲ͟ŶĞƌũĞƚ͕ϮƐƉĨ͕ϬƉŚĂƐĞ ,ͲϭϭϭϬ͕ϲϳϰ͛ϭϬ͕ϲϴϰ͛ϭϬ͕ϲϲϲ͛ϭϬ͕ϲϳϲ͛ϭϬ͛ϭͲϭϭͬϭϲ͟ŶĞƌũĞƚ͕ϭϬƐƉĨ͕ϭϴϬƉŚĂƐĞ ,ͲϭϮϭϬ͕ϳϬϵ͛ϭϬ͕ϳϮϱ͛ϭϬ͕ϳϬϭ͛ϭϬ͕ϳϭϳ͛ϭϲ͛ϭͲϭϭͬϭϲ͟ŶĞƌũĞƚ͕ϮƐƉĨ͕ϬƉŚĂƐĞ ,ͲϭϯϭϬ͕ϳϲϰ͛ϭϬ͕ϳϳϲ͛ϭϬ͕ϳϱϱ͛ϭϬ͕ϳϲϳ͛ϭϮ͛ϭͲϭϭͬϭϲ͟WŝǀŽƚ͕ϭϬƐƉĨ͕ϭϴϬƉŚĂƐĞ tĞůů͗^hϰϭͲϬϴ Wd͗ϭϵϰͲϬϴϱ W/͗ϱϬͲϭϯϯͲϭϬϭϮϬͲϬϭͲϬϬ hƉĚĂƚĞĚďǇDϬϯͲϬϯͲϮϮ WZKWK^^,Dd/ dh/E'ZKd/> ηdŽƉ>ĞŶŐƚŚKĞƐĐƌŝƉƚŝŽŶ ddϭͲϭͬϮ͟WŽůŝƐŚĞĚZŽĚ͕ϯϬ͛ŝŶǁĞůů;EĞǁϱͲϮϳͲϭϰͿ ddϭ͟ϭϭϰĐŽƵŶƚǆϮϱ͛>^ƵĐŬĞƌƌŽĚƐǁͬϰy>ŐƵŝĚĞƐƉĞƌƌŽĚ;EĞǁϱͲϮϳͲϭϰͿ ddϳͬϴ͟ϭϯϴĐŽƵŶƚǆϮϱ͛>^ƵĐŬĞƌƌŽĚƐǁͬEŽŐƵŝĚĞƐ;EĞǁϯͬϭϬͬϭϯͿ ddϯͬϰ͟ϵϯĐŽƵŶƚǆϮϱ͛>^ƵĐŬĞƌƌŽĚƐǁͬEŽŐƵŝĚĞƐ͘dŽƉϳũŽŝŶƚƐŚĂǀĞϰy> ŐƵŝĚĞƐƉĞƌƌŽĚ;EĞǁϯͬϭϬͬϭϯͿ ddϭͲϭͬϮ͟ϭϮĐŽƵŶƚǆϮϱ͛tĞŝŐŚƚďĂƌƐ;ϭϮͿ ddϭͲϯͬϰ͟ϭͲϯͬϰ͟ǆϰϬ͛/ŶƐĞƌƚZŽĚWƵŵƉηϳϮϯϰ;EĞǁϴͬϭϳͬϮϭͿ ϮϱͲϭϳϱͲϰϬͲϱͲϬͲϬ dϭͲϭͬϮ͟ŝƉdƵďĞ ^/E'Edh/E'd/> ^ŝǌĞtd'ƌĂĚĞ/dŽƉƚŵ ϮϬ͟^ƵƌĨϰϲ͛ ϭϭͲϯͬϰ͟ϰϳη:Ͳϱϱϭϭ͟^ƵƌĨϮ͕ϬϮϮ͛ ϳ͟ϮϵηEͲϴϬϲ͘ϭϴϰ͟^ƵƌĨϮϵϬ͛ ϳ͟ϮϲηEͲϴϬϲ͘Ϯϳϲ͟ϮϵϬ͛ϭ͕Ϯϭϵ͛ ϳ͟ϮϯηEͲϴϬϲ͘ϯϲϲ͟ϭ͕Ϯϭϵ͛ϰ͕ϵϱϮ͛ ϳ͟ϮϲηEͲϴϬϲ͘Ϯϳϲ͟ϰ͕ϵϱϮ͛ϲ͕ϲϭϳ͛ ϳ͟ϮϯηEͲϴϬϲ͘ϯϲϲ͟ϲ͕ϲϭϳ͛ϴ͕ϰϮϳ͛ ϳ͟ϮϵηWͲϭϭϬϲ͘ϭϴϰ͟ϴ͕ϰϮϳ͛ϵ͕ϳϰϱ͛ ϱ͟ϭϴη>ͲϴϬϰ͘Ϯϳϲ͟ϵ͕ϰϱϳ͛ϭϬ͕ϵϮϱ͛ dh/E' ϮͲϳͬϴ͟ϲ͘ϱη>ͲϴϬϮ͘ϰϰϭ͟^ƵƌĨϵ͕ϮϬϭ͛ ϮͲϯͬϴ͟ϰ͘ϳηEͲϴϬϭ͘ϵϵϱ͟ϵ͕ϰϯϬ͛ϭϬ͕Ϭϴϱ͛ :t>Zzd/> EŽ͘ĞƉƚŚ//ƚĞŵ ϭdϮ͘ϰϰϭ͟dƵďŝŶŐ,ĂŶŐĞƌʹ:>ĂƚĐŚ ϮdϮ͘ϰϰϭ͟ϮͲϳͬϴ͟ŚĞŵŝĐĂů/Ŷũ^ƵďǁͬЬ͟ĐŽŶƚƌŽůůŝŶĞ;>ŝǀĞsĂůǀĞͿ ϯdϮ͘ϰϰϭ͟ϳ͟tĞĂƚŚĞƌĨŽƌĚdƵďŝŶŐŶĐŚŽƌ;ϯϱ<^ŚĞĂƌͿ ϰϵ͕ϮϬϭ͛Ϯ͘ϯϭϱ͟ϮͲϳͬϴ͟^ĞĂƚŝŶŐEŝƉƉůĞ ϱdϮ͘ϵϵϮ͟ϯ͘ϱ͟^ůŽƚƚĞĚ^Ƶď ϲdͲϯͲϭͬϮ͟ƵůůWůƵŐ ϳϵ͕ϰϬϭ͛Ϯ͘ϱϬϬ͟^ĞĂƚŝŶŐEŝƉƉůĞǁŝƚŚĐƵƚŽĨĨϮͲϳͬϴ͟ƚƵďŝŶŐ ϴϵ͕ϰϬϲ͛Ϯ͘ϰϰϭ͟ŶĐŚŽƌ^ĞƉĂƌĂƚŽƌǁͬϰ͛ƉƵƉ͖ϮͲϭͬϭϲ͟/:ƚƵďŝŶŐʹϭϮϬ͛ ϵϵ͕ϰϬϳ͛Ϯ͘ϰϰϭ͟yͲŽǀĞƌϮͲϯͬϴ͟ƉŝŶǆϮͲϳͬϴ͟ďŽǆ ϭϬϵ͕ϰϰϬ͛ϭ͘ϵϵϱ͟KŶͬKĨĨdŽŽů ϭϭϵ͕ϰϰϲ͛ϭ͘ϵϵϱ͟ϱ͟ƌƌŽǁƐĞƚϭyWĂĐŬĞƌ ϭϮϭϬ͕Ϭϴϰ͛ϭ͘ϵϵϱ͟t>ZĞͲĞŶƚƌǇ'ƵŝĚĞ WZ&KZd/KEd/>KEEydW' 1HZ7XELQJ5DQ7%' 1HZURGVUDQ7%' 1HZSXPSUDQ7%' tĞůů͗^hϰϭͲϬϴ Wd͗ϭϵϰͲϬϴϱ W/͗ϱϬͲϭϯϯͲϭϬϭϮϬͲϬϭͲϬϬ hƉĚĂƚĞĚďǇDϬϯͲϬϯͲϮϮ WZKWK^^,Dd/ WZ&KZd/KEd ŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿŵƚŽŵŵĞŶƚƐ 'ͲϮϭϬ͕ϭϴϴΖϭϬ͕ϭϵϮΖϭϬ͕ϭϴϱ͛ϭϬ͕ϭϴϵ͛ϰΖ ϭϬ͕ϭϵϲΖϭϬ͕ϮϬϵΖϭϬ͕ϭϵϯ͛ϭϬ͕ϮϬϲ͛ϭϯΖ 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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: 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 10,930 feet N/A feet true vertical 10,920 feet 10,618 (fill) feet Effective Depth measured 10,618 feet 9,138 feet true vertical 10,611 feet 9,138 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-7/8" 6.5# / L-80 9,201' MD 9,201' TVD Tubing (size, grade, measured and true vertical depth)2-3/8" 4.7# / N-80 10,085' MD 10,083' TVD 9,446' MD Packers and SSSV (type, measured and true vertical depth)Tripoint AS1-X; N/A 9,446' TVD 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: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: 10,140psi Burst 6,340psi 46' 2,022'3,070psi Collapse 1,510psi 10,500psi 3,830psi Casing Structural 20" 11-3/4" Length 46' 2,022' 9,745' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 160 Casing Pressure Liner 1,468' 8 10,915' 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-310 175 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 30 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 194-085 50-133-10120-01-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 00 Soldotna Creek Unit (SCU) 41A-08 N/A FEDA028996 Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River Field / Hemlock OilN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 7" 5" 9,745'9,745' WINJ WAG 0 Water-Bbl MD 46' 2,022' 10,925' 125 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 3:07 pm, Sep 15, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.09.15 14:47:36 -08'00' Dan Marlowe (1267) DSR-9/15/21 RBDMS HEW 9/16/2021 BJM 11/3/21 SFD 9/20/2021 Rig Start Date End Date 6/28/21 8/20/21 Pre-spud with crew to review Sundry, review JSA for pulling rod completion. Open to well, no pressure and on a vac. Mobilize rod equipment to wellhead. Prep wellhead and RU to pull rod completion. Lift and secure polished rod, string PUW 15k. Break off and LD polished rod and pups. Begin pulling 1" rods, no fluid on rods (very unusual) and lots of sticky, sandy material sticking to any upsets down hole. Total of 113 1" rods recovered. Swap out handling equipment to 7/8" x 3/4" elevators and dies. Continue POH with 7/8" rods. Floorhand working Derrick mismanaged stand, dropped stand (3 jts) of 7/8" rod, ~150 lbs. No injuries or damage. Stop work, bring crew together to discuss incident. Conduct safety stand-down while Co Rep makes notifications. Discuss operation and job responsibilities during stand- down. Inspect equipment. Continue with pulling the 7/8" followed by 3/4" sections of rods from well. No fluid or oil coating on rods. Lay down heavy weight sucker rods. Pull pump out of hole, large slug of sand / oil cake pulled out above pump section. Very thick. Pull pump section, set in false bowl, attempt to set down on rod but no movement. Break off and lay down. Make calls to confirm plan forward. Secure site and secure well. 07/01/2021 - Thursday Safety Meeting with crew. Discussed dropped object incident and lesson learned. Discuss plan forward for the day, inspect and service lift and handling equipment. Conduct walk through of using elevators in derrick. Change out dies in rod tongs for RIH. RIH with rod string pulled previously. Hot Oil truck on location. Heat up 65 bbls to 200 degrees, RU and pump down hole to clean tubing of paraffin / sand mix. SIMOPS: Offload Rod Pump and place back in storage, offload new rods and rod pups at P&S Yard. Continue to RIH with pulled rod string. Line up and circulate down with 200 deg water again. Caught fluid at 10 bbls away, circ pressure rose to 600 psi at 15 bbls with tubing pressure of 150 psi. Broke over, continue to pump. Circ pressure rose to 800 psi, tubing pressure continued to increase to ~400 psi at 52 bbls away. Down on circulation. SIMOPS: dress out tongs for POH. POH with rod assembly laying down 1 by 1. Rods coming out fairly clean, no hydrocarbon residue to drip off. Hang string off in blocks, secure well by closing in rod packoff and stripper assembly. Well on slight vacuum. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 41A-08 50-133-10120-01-00 194-085 06/30/2021 - Wednesday 06/29/2021 - Tuesday PJSM with crew, discuss pre-spud of upcoming work on SCU 41A-08. No approval from AOGCC, release majority of crew. Retrieve crossovers, low pressure lines needed to rig up mud pump to well. Replace hydraulic fitting on Rod Tong hydraulic connection. Open to well, 32 psi on well. Bleed off to bleed trailer, 6 psi but rate falling off. Wait on delivery of mud pump (wait on trucking). Install 1502 valves, line out hoses, stage in fluids. Open to well, no pressure or gas at surface. Stage in pump. Begin well kill. Circulate down 8.4 ppg produced water, well taking all fluid and no gas to surface. At ~25 bbls into circulating, begin to take fluid through bleeder line. Off with pump to see if well will burp, well on slight vac. Break circulation again, getting fluid returns again. Open to well, on slight vac. Use gravity feed, took ~5 more bbls. No more vac, will not take any more fluid. Monitor well for 1 hour, no pressure and well static. Suck back fluid to truck, RD circulation lines while monitoring well. Well static. Secure location. 06/28/2021 - Monday MIRU with HAK 401 Carrier, generator, tool shacks, office and comms tower. Stage in bleed trailer. Release crew while waiting on orders - State is reviewing Sundry for approval. How is well secured for the night? dropped stand (3 jts) of 7/8" rod, ~150 lbs. No injuries or damage. Stop work, bring crew together to discuss incident. Begin well kill. Circulate down 8.4 ppg produced water, well taking all fluid and no gas to surface. At ~25 bbls into circulating, begin to take fluid through bleeder line. Off with pump to see if well will burp, well on slight vac. Break circulation again, getting fluid returns again. Open to well, on slight vac. Use gravity feed, took ~5 more bbls. No more vac, will not take any more fluid. Monitor well for 1 hour, no pressure and well static. Line up and circulate down with 200 deg water again. Caught fluid at 10 bbls away, circ pressure rose to 600 psi at 15 bbls with tubing pressure of 150 psi. Hang string off in blocks, secure well by closing in rod packoff and stripper assembly. W Pull pump out of hole, large slug of sand / oil cake pulled out above pump section. V Rig Start Date End Date 6/28/21 8/20/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 41A-08 50-133-10120-01-00 194-085 Held PJSM cleaning threads on rod box and pin ends. Raise & scope up derrick, secure derrick and center over well. Continue cleaning rod box and pin ends , cleaning paraffin out of handling equipment. Strap and tally BHA, 3/4" and 7/8" rods, continue cleaning rod connections and handling equipment. Pick up 40 x 1-3/4" type RHBC rod pump number 7234 DATE 9-26-19 conduct pump test (good test ) make up 22 ft dip tube with 2 ft. of prefs and continue in hole picking up 1-1/2 wt bars. Continue in hole picking up 3/4" rods to 1,150 ft. secure well for night. 08/18/2021 - Wednesday Held PJSM Run in hole with 3/4" rods from 1,150 ft. to 1,600 ft Pump dragging, allowing plunger to insert into pump barrel, then pump barrel would fall and bottom out on plunger, not showing any drag on weight indicator, Pick up 11k, S/O wt 11k. Called ops team, pooh to check pump, rig up rod board to pooh. Pooh racking back 3/4" rods at 1,500 ft, 1,425 ft. had 500 to 600 # over pull and continue to pooh laying out the 1-1/2" weight bars, pump and dip tube, top of pump had paraffin on it, secure well, will pump hot water and run slick line gauge to clear paraffin from tbg. Clean remaining 1" rods, house keeping crew departed rig for night. 08/08/2021 - Sunday Move in From SRU 241-16. Rig up Slicklilne to the Point of Pickup. Rig down Crane and Move to Assist Production with picking a tree on SCU 43B-8. Rig up Crane- Rig up Slickline Hot Oil P/T lub 2,500 PSI, PASS. RIH/w 2-7/8" Braided Line Brush to 3,600' SLM set down W/t to 3,686' pooh-tools covered in paraffin. RIH/w 2-7/8" Braided Line Brush to 3,600' SLM set down W/t to 3,686', pooh-tools covered in paraffin. Hot oil truck pumps 70 BBL heated @ ~205 deg down well. RIH/w 3' 1-1/2" Stem/w 2-7/8" Braided Brush to 9,282' SLM (9,271' RKB neg 11' Correction) tag bull Plug pickup to 9,212' SLM (9201' RKB) locate nipple Brush for 10 mins POOH. RIH/w 2" JUC /w 2-7/8'' standing valve to 9,212' SLM (9,201' RKB) w/t then set down on SV prong. Start Testing with Hot oil Truck failing- start working tools to seat SV test slow leak appears to be SV. Bleed off pressure let vac go away then work tools free start pooh with multiple hang ups at 9,186', 9,097', 9,039', 8,990', 8,930', 8,740'. WT through pooh. Hang up at 3,271' SLM sheared. POOH. OOH pin sheared there is some paraffin on tools. RIH W/ 2'' JDC to 3,271' latch. POOH. OOH W/ plug. Lay down lubricator. Sign out, turn in permits. Leave facility. 08/16/2021 - Monday Travel to Swanson River. Lay out liner and spot base Beam, put carrier landings down and spot carrier, spot pusher shack, generator, and bang board. Held Orientation at main office with crews and John Coston. Pick up bundles of rods at p & S yard, pick up pump and polish rods at compressor plant. Install rod basket on derrick, Mechanic repaired transmission filter housing sort and organize bundles of rods, load pipe rack with rods, cleaning pins and boxes. 08/17/2021 - Tuesday 07/02/2021- Friday PJSM with crew regarding today's operations, emphasis on opening to well and handling the rods as they come out of the well. POH with rod string. Lay down one by one, bundle 7/8" and 3/4" in separate bundles. Complete laydown, secure well in preparation for installing Dry-Hole tree. Prep location for rigging down. RD unit, load trailers. Move equipment to CLU-005. RD unit, continue in hole picking up 1-1/2 wt bars. Continue in hole picking up 3/4" rods to 1,150 ft. secure well for night. pooh to check pump, rig up rod board to pooh. Brush to 3,600' SLM set down W/t to 3,686' pooh-tools covered in paraffin. Rig Start Date End Date 6/28/21 8/20/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 41A-08 50-133-10120-01-00 194-085 08/20/2021- Friday Held PJSM continue running hole picking up 1" rods f/ 6,325' to tagging seating nipple at 9,187 ft. Pick up wt. 20k s/o wt 19.5k, set down 5k on nipple, stroke pump up and verify pump seating in nipple, saw 1k over pull pulling out of nipple. Set down 5k on seating nipple stroke pump up, to verify seating in nipple, saw 1k over pull coming out of nipple, Slack off and locate bottom of pump pick up 18", then pickup 126", continue picking spacing out for 40 ft. polish rod, lay out landing rods and pick up polish rod and install pack off, Ran total of 1-1/2" dip tube with 2 ft of perfs- 40 ft. x 1- 3/4" RHBC pump (pump number 7234) size 25-175-40-5-0-0. pump man Weatherford, (12) 1-1/2" x 25' weight bars 301.80 ft , (93 ) 3/4" x 25' EL sucker rods with no guides & (7) 3/4" rods with 4 XL guides per rod total 3/4" rods 100 = 2,512.14' x/o collar, (138 ) 7-8" X 25 ft. EL sucker rods with NO XL guides per rod ( used ) = 3,443.16', x/o collar. (114 ) 1" x 25 ft. EL sucker rods with 4 XL guides per rod ( New 5-27-14) = 2,852.13', total 9,152.93'. Fill tbg with 45 bbls water from vac truck, function test pump (good test) pressure test pack off to 1,000 psi for 5 minutes (good test). Scope down and lay down derrick rig down rod basket, get pad ready for rig move. 08/19/2021 - Thursday Held PJSM , H/UP rod tongs, strap 1" rods on pipe rack, house keeping while waiting on slick line. Pump 65 bbls of 100° water down tbg with vac truck plus 15 gallons of PA077. Pig up Pollard lubricator, Rih hole with 2.35" brush to 4,000 ft. while pumping 350 gallons diesel. Pooh with brush had a few 1" chucks of paraffin in brush. Slick line RIH with 2.33 gauge ring to 9201 ft. POOH with no problems. RIH with 2.44" Brush to 2,500 ft. made two passes with bush very little paraffin on brush. RIH with 2.35" gauge ring to 3,000 ft. POOH. RIH with 2.40" gauge ring set down at 861 ft. 1,020 ft. and 1,120 ft. appeared to be setting down on collars, pooh. Laid out gauge, rig down slick line. Pick up 40 x 1-3/4" type RHBC rod pump number 7234 DATE 9-26-19 conduct pump test ( good test ) make up 22 ft. dip tube with 2 ft. of prefs and continue in hole picking up (12) 1-1/2" wt. bars, 100 3/4" EL rods. 138 EL rods to 6,325 ft. pick up 16k S/o wt. 15k Secure well of night. continue in hole picking up (12) 1-1/2" wt. bars, 100 3/4" EL rods. 138 EL rods to 6,325 ft. continue picking spacing out for 40 ft. polish rod, lay out landing rods and pick up polish rod and install pack off, R ready for rig move. Soldotna Creek Unit Well: SCU 41A-08 Completion Ran: 10-1-2016 PTD: 194-085 API: 50-133-10120-01-00 Downhole Revised 05-27-14 Updated by DMA 08-26-21 SCHEMATIC CASING AND TUBING DETAIL Size WT Grade ID Top Btm 20” Surf 46’ 11-3/4” 47# J-55 11” Surf 2,022’ 7” 29# N-80 6.184” Surf 290’ 7” 26# N-80 6.276” 290’ 1,219’ 7” 23# N-80 6.366” 1,219’ 4,952’ 7” 26# N-80 6.276” 4,952’ 6,617’ 7” 23# N-80 6.366” 6,617’ 8,427’ 7” 29# P-110 6.184” 8,427’ 9,745’ 5” 18# L-80 4.276” 9,457’ 10,925’ TUBING 2-7/8” 6.5# L-80 2.441” Surf 9,201’ 2-3/8” 4.7# N-80 1.995” 9,430’ 10,085’ JEWELRY DETAIL No. Depth ID Item 1 15’ 2.441” Tubing Hanger – J Latch 2 3,004’ 2.441” 2-7/8” Chemical Inj Sub w/ ¼” control line (Live Valve) 3 9,137’ 2.441” 7” Weatherford Tubing Anchor (35K Shear) 4 9,201’ 2.315” 2-7/8” Seating Nipple 5 9,203’ 2.992” 3.5” Slotted Sub 6 9,271’ - 3-1/2” Bull Plug 7 9,401’ 2.500” Seating Nipple with cut off 2-7/8” tubing 8 9,406’ 2.441” Anchor Separator w/ 4’ pup; 2-1/16” IJ tubing – 120’ 9 9,407’ 2.441” X-over 2-3/8” pin x 2-7/8” box 10 9,440’ 1.995” On/Off Tool 11 9,446’ 1.995” 5” Arrowset 1X Packer 12 10,084’ 1.995” WL Re-entry Guide ROD DETAIL # Depth Length OD Description A 0 40’ 1-1/2” Polished Rod, 30’ in well (New 5-27-14) B 40’ 4’ 1” 1” x 4’ EL Pony Rod w/ 1 XL guide per rod 44’ 6’ 1” 1” x 6’ EL Pony Rod w/ 1 XL guide per rod 50’ 2,925’ 1” 1” x 25’ EL Sucker rods w/ 4 XL guides per rod (New 5-27-14) 2,975’ 3,450’ 7/8” 7/8” x 25’ EL Sucker rods w/ “No” XL guides per rod (Used) 6,425’ 2,500’ 3/4” 3/4” x 25’ EL Sucker rods w/ “No” XL guides per rod (Used) C 8,925’ 300’ 1-1/2” 1-1/2” x 25’ K Bars (weight bars) D 9,225’ 2.75’ 1” 1” x 30” Stabilizer Bar w/ ¾” Pins (between K Bars) E 9,228’ 43’ 1-3/4” 1-3/4” x 42’ Insert Pump, RHBC Pump (Reran Used Pump 1/18/17) 80 PA Ring, Sand Seal, 2-1/2” x 1-3/4” x 36” x 36-1/2” x 37” RHBC F 9,291’ 1’ 1-1/2” Dip Tube PERFORATION DETAIL ON NEXT PAGE Soldotna Creek Unit Well: SCU 41A-08 Completion Ran: 10-1-2016 PTD: 194-085 API: 50-133-10120-01-00 Downhole Revised 05-27-14 Updated by DMA 08-26-21 SCHEMATIC PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments G-2 10,188' 10,192' 10,185’ 10,189’ 4' 10,196' 10,209' 10,193’ 10,206’ 13' H-2 10,281' 10,297' 10,277’ 10,293’ 16' 10,283’ 10,299’ 10,279’ 10,295’ 16’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-3 10,312’ 10,328’ 10,308’ 10,324’ 16’ 1-11/16” Enerjet, 6 spf, 90 phase 10,316’ 10,332’ 10,312’ 10,328’ 16’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-4 10,336' 10,344' 10,331’ 10,339’ 8' 10,338’ 10,346’ 10,333’ 10,341’ 8’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-5 10,356' 10,371' 10,351’ 10,366’ 15' 10,356’ 10,382’ 10,351’ 10,377’ 26’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-6 10,403’ 10,407’ 10,398’ 10,402’ 4’ 1-11/16” Enerjet, 4 spf, 0 phase H-7 10,413’ 10,432’ 10,408’ 10,426’ 19’ 1-11/16” Enerjet, 4spf, 0 phase 10,414’ 10,431’ 10,409’ 10,425’ 17’ 3-1/2” HC, 6 spf, 60 phase 3/2013 10,435’ 10,443’ 10,429’ 10,437’ 8’ 1-11/16” HC, 4 spf, 0 phase H-8 10,456’ 10,480’ 10,450’ 10,474’ 24’ 1-11/16” HC, 4 spf, 0 phase 10,446’ 10,481’ 10,440’ 10,475’ 35’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-9 H-9 10,502’ 10,516’ 10,496’ 10,510’ 14’ 1-11/16” HC, 4 spf, 0 phase 10,503’ 10,513’ 10,497’ 10,507’ 10’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-10 10,541’ 10,564’ 10,534’ 10,557’ 23’ 1-1/16” HC, 4 spf, 0 phase 10,541’ 10,568’ 10,534’ 10,561’ 27’ 3-1/2” HC, 6 spf, 60 phase 3/2013 10,544’ 10,564’ 10,537’ 10,557’ 20’ 3-1/2” HC, 6 spf, 60 phase 3/2013 10,564’ 10,620’ 10,557’ 10,613’ 50’ 1-11/16” Enerjet, 6 spf, 90 phase 10,617’ 10,632’ 10,610’ 10,625’ 15’ 1-11/16” Enerjet, 2 spf, 0 phase H-11 10,674’ 10,684’ 10,666’ 10,676’ 10’ 1-11/16” Enerjet, 10 spf, 180 phase H-12 10,709’ 10,725’ 10,701’ 10,717’ 16’ 1-11/16” Enerjet, 2 spf, 0 phase H-13 10,764’ 10,776’ 10,755’ 10,767’ 12’ 1-11/16” Pivot, 10 spf, 180 phase 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,930'10,618' (fill) Casing Collapse Structural Conductor Surface 1,510 psi Intermediate Production 3,830 psi Liner 10,500 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 907-632-4113 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng todd.sidoti@hilcorp.com 10,920'10,618'10,611'1,460 psi N/A 9,446' MD; 9,446' TVD - N/A Perforation Depth TVD (ft): Tubing Size: 2-7/8" COMMISSION USE ONLY Authorized Name: 10,140 psi Tubing Grade: 6.4# / L-80 Tubing MD (ft): 9,424 See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028996 194-085 50-133-10120-01 Soldotna Creek Unit (SCU) 41A-08 Swanson River Field / Hemlock Oil Length Size 123B Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 4.7# / N-80 TVD Burst 10,085 6,340 psi MD 3,070 psi 46' 2,022' 46' 2,022' 9,745'7" 20" 11-3/4" 46' 2,022' 9,745' Perforation Depth MD (ft): See Attached Schematic 9,745' 5" Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: June 28, 2021 10,925'1,468' 2-3/8" 10,915' Tripoint AS1-X; N/A Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 12:35 pm, Jun 24, 2021 321-310 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.06.23 14:51:23 -08'00' Taylor Wellman (2143) DLB 06/24/2021 X BJM 6/28/21 Rod-pumped well with passing No-Flow test. Approval to pull rods without BOPs is approved under 20 AAC 25.288, on the condition that it has been first killed and flow-checked prior to pulling rods. NA DLB -00 DLB DSR-6/24/21 10-404 dts 6/28/2021 JLC 6/28/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.28 20:36:39 -08'00' RBDMS HEW 6/30/2021 Well Prognosis Well: SCU 41A-08 Date: 6/23/2021 Well Name: SCU 41A-08 API Number: 50-133-10120-01-00 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: June 28, 2021 Rig: 401 Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 194-085 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 AFE Number: Current Bottom Hole Pressure: ~ 2,500 psi @ 10,400’ TVD (BHP Buildup interpretation 6/6/2006) Max. Expected BHP: ~ 2,500 psi @ 10,400’ TVD Max. Potential Surface Pressure: ~1,460 psi (Max BHP – 0.1 psi/ft gradient) Brief Well Summary Soldotna Creek Unit 41A-08 was drilled in 1994 as a sidetrack of the original Hemlock injection well SCU 341-08. SCU 41A-08 was initially completed in the lower Hemlock (H10-H13 sands) free flowing at approximately 100 BOPD and low GOR. From 1996 – 2001, the H4 – H10 sands were added to the completion in an effort to blow down gas injected into the Hemlock in SCU 341-08. Significant paraffin deposition throughout the life of the well has led to regular mechanical and solvent (xylene) treatments. In 2001, the H2-H5 sands were added and the well began flowing on gas lift. The Tyonek G-Zone was added in 2007 with no noticeable production contribution. The completion was converted to Rotaflex rod pump in March 2013. In July 2021, it is suspected that the rods have parted deep, close to the pump. The purpose of this work/sundry is to repair parted rods for this Rotaflex Rod Pump well. Notes Regarding Wellbore Condition x Well is currently not producing on rod pump (suspect parted rods). x Rotaflex unit will be uncoupled and motor LOTO prior to rig mobilization. x Well operates without a SSV system per AOGCC approved variance. 401 Procedure: 1. Blow-down any pressure on the well and shoot fluid level on casing. 2. MIRU rig 401. 3. Load well with 8.4ppg produced water. 4. Set slips and remove Rotoflex clamp from polished rod head. 5. Nipple down pack-off. 6. Nipple up rod stripper head. 7. LD polish rod and pull EL rods. Note pickup weight to estimate depth of part. 8. Visually inspect rods while racking them back in basket until parted rod is found. Discard 3 rods above part. LD parted rod. 9. PU overshot and RIH. Fish parted rod. Discard 3 rods below part. Pull remaining rod string with pump. 10. LD and inspect rods, pump and dip tube and all pulled rods. 11. PU existing dip tube and new or rebuilt 1-3/4” rod pump, replace and RIH with existing tapered rod string (sinker bars, 3/4”, 7/8” and 1), space out the rods, install polish rod. 12. ND rod stripper, install surface equipment onto well and test pack off to 1,000 psi. 13. RD Moncla #401 WO Rig. Pump casing volume of produced water down IA to flush hydrocarbons from the wellbore. Bleed tubing and load with produced water. bjm Verify no flow before ND packoff. No-flow test performed 3/18/13 is still valid. Overshot will be deployed with rods. Displace tubing fluids into perfs when pump is pulled free and flow path down tubing is opened up to flush hydrocarbons out of tubing and into perfs. bjm Well Prognosis Well: SCU 41A-08 Date: 6/23/2021 14. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 15. Return to production with same surface safety system as previously installed. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. No Flow Verification Letter Soldotna Creek Unit Well: SCU 41A-08 Completion Ran: 10-1-2016 PTD: 194-085 API: 50-133-10120-01 Downhole Revised 05-27-14 Updated by TCS 6-22-21 SCHEMATIC CASING AND TUBING DETAIL Size WT Grade ID Top Btm 20”Surf 46’ 11-3/4”47#J-55 11”Surf 2,022’ 7”29#N-80 6.184”Surf 290’ 7”26#N-80 6.276”290’1,219’ 7”23#N-80 6.366”1,219’4,952’ 7”26#N-80 6.276”4,952’6,617’ 7”23#N-80 6.366”6,617’8,427’ 7”29#P-110 6.184”8,427’9,745’ 5”18#L-80 4.276”9,457’10,925’ TUBING 2-7/8”6.5#L-80 2.441”Surf 9,201’ 2-3/8”4.7#N-80 1.995”9,430’10,085’ JEWELRY DETAIL No.Depth ID Item 1 15’2.441”Tubing Hanger –J Latch 2 3,004’2.441”2-7/8” Chemical Inj Sub w/ ¼” control line (Live Valve) 3 9,137’2.441”7” Weatherford Tubing Anchor (35K Shear) 4 9,201’2.315”2-7/8” Seating Nipple 5 9,203’2.992”3.5” Slotted Sub 6 9,271’-3-1/2” Bull Plug 7 9,401’2.500”Seating Nipple with cut off 2-7/8” tubing 8 9,406’2.441”Anchor Separator w/ 4’ pup; 2-1/16” IJ tubing – 120’ 9 9,407’2.441”X-over 2-3/8” pin x 2-7/8” box 10 9,440’1.995”On/Off Tool 11 9,446’1.995”5” Arrowset 1X Packer 12 10,084’1.995”WL Re-entry Guide ROD DETAIL #Depth Length OD Description A 0 40’1-1/2”Polished Rod, 30’ in well (New 5-27-14) B 40’4’1”1” x 4’ EL Pony Rod w/ 1 XL guide per rod 44’6’1”1” x 6’ EL Pony Rod w/ 1 XL guide per rod 50’2,925’1”1” x 25’ EL Sucker rods w/ 4 XL guides per rod (New 5-27-14) 2,975’3,450’7/8”7/8” x 25’ EL Sucker rods w/ “No” XL guides per rod (Used) 6,425’2,500’3/4”3/4” x 25’ EL Sucker rods w/ “No” XL guides per rod (Used) C 8,925’300’1-1/2”1-1/2” x 25’ K Bars (weight bars) D 9,225’2.75’1”1” x 30” Stabilizer Bar w/ ¾” Pins (between K Bars) E9,228’43’ 1-3/4”1-3/4” x 42’ Insert Pump, RHBC Pump (NEW 10/12/16) 80 PA Ring, Sand Seal, 2-1/2” x 1-3/4” x 36” x 36-1/2” x 37” RHBC F 9,291’1’1-1/2”Dip Tube PERFORATION DETAIL ON NEXT PAGE Soldotna Creek Unit Well: SCU 41A-08 Completion Ran: 10-1-2016 PTD: 194-085 API: 50-133-10120-01 Downhole Revised 05-27-14 Updated by TCS 6-22-21 SCHEMATIC PERFORATION DATA Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)Amt Comments G-2 10,188'10,192'10,185’10,189’4' 10,196'10,209'10,193’10,206’13' H-2 10,281'10,297'10,277’10,293’16' 10,283’10,299’10,279’10,295’16’3-1/2” HC, 6 spf, 60 phase 3/2013 H-3 10,312’10,328’10,308’10,324’16’1-11/16” Enerjet, 6 spf, 90 phase 10,316’10,332’10,312’10,328’16’3-1/2” HC, 6 spf, 60 phase 3/2013 H-4 10,336'10,344'10,331’10,339’8' 10,338’10,346’10,333’10,341’8’3-1/2” HC, 6 spf, 60 phase 3/2013 H-5 10,356'10,371'10,351’10,366’15' 10,356’10,382’10,351’10,377’26’3-1/2” HC, 6 spf, 60 phase 3/2013 H-6 10,403’10,407’10,398’10,402’4’1-11/16” Enerjet, 4 spf, 0 phase H-7 10,413’10,432’10,408’10,426’19’1-11/16” Enerjet, 4spf, 0 phase 10,414’10,431’10,409’10,425’17’3-1/2” HC, 6 spf, 60 phase 3/2013 10,435’10,443’10,429’10,437’8’1-11/16” HC, 4 spf, 0 phase H-8 10,456’10,480’10,450’10,474’24’1-11/16” HC, 4 spf, 0 phase 10,446’10,481’10,440’10,475’35’3-1/2” HC, 6 spf, 60 phase 3/2013 H-9 H-9 10,502’10,516’10,496’10,510’14’1-11/16” HC, 4 spf, 0 phase 10,503’10,513’10,497’10,507’10’3-1/2” HC, 6 spf, 60 phase 3/2013 H-10 10,541’10,564’10,534’10,557’23’1-1/16” HC, 4 spf, 0 phase 10,541’10,568’10,534’10,561’27’3-1/2” HC, 6 spf, 60 phase 3/2013 10,544’10,564’10,537’10,557’20’3-1/2” HC, 6 spf, 60 phase 3/2013 10,564’10,620’10,557’10,613’50’1-11/16” Enerjet, 6 spf, 90 phase 10,617’10,632’10,610’10,625’15’1-11/16” Enerjet, 2 spf, 0 phase H-11 10,674’10,684’10,666’10,676’10’1-11/16” Enerjet, 10 spf, 180 phase H-12 10,709’10,725’10,701’10,717’16’1-11/16” Enerjet, 2 spf, 0 phase H-13 10,764’10,776’10,755’10,767’12’1-11/16” Pivot, 10 spf, 180 phase 56 Soldotna Creek Unit Well: SCU 41A-08 Completion Ran: 10-1-2016 PTD: 194-085 API: 50-133-10120-01 Downhole Revised 05-27-14 Updated by TCS 06-23-21 PROPOSED SCHEMATIC CASING AND TUBING DETAIL Size WT Grade ID Top Btm 20” Surf 46’ 11-3/4” 47# J-55 11” Surf 2,022’ 7” 29# N-80 6.184” Surf 290’ 7” 26# N-80 6.276” 290’ 1,219’ 7” 23# N-80 6.366” 1,219’ 4,952’ 7” 26# N-80 6.276” 4,952’ 6,617’ 7” 23# N-80 6.366” 6,617’ 8,427’ 7” 29# P-110 6.184” 8,427’ 9,745’ 5” 18# L-80 4.276” 9,457’ 10,925’ TUBING 2-7/8” 6.5# L-80 2.441” Surf 9,201’ 2-3/8” 4.7# N-80 1.995” 9,430’ 10,085’ JEWELRY DETAIL No. Depth ID Item 1 15’ 2.441” Tubing Hanger – J Latch 2 3,004’ 2.441” 2-7/8” Chemical Inj Sub w/ ¼” control line (Live Valve) 3 9,137’ 2.441” 7” Weatherford Tubing Anchor (35K Shear) 4 9,201’ 2.315” 2-7/8” Seating Nipple 5 9,203’ 2.992” 3.5” Slotted Sub 6 9,271’ - 3-1/2” Bull Plug 7 9,401’ 2.500” Seating Nipple with cut off 2-7/8” tubing 8 9,406’ 2.441” Anchor Separator w/ 4’ pup; 2-1/16” IJ tubing – 120’ 9 9,407’ 2.441” X-over 2-3/8” pin x 2-7/8” box 10 9,440’ 1.995” On/Off Tool 11 9,446’ 1.995” 5” Arrowset 1X Packer 12 10,084’ 1.995” WL Re-entry Guide ROD DETAIL # Depth Length OD Description A 0 40’ 1-1/2” Polished Rod, 30’ in well (New 5-27-14) B 40’ 4’ 1” 1” x 4’ EL Pony Rod w/ 1 XL guide per rod 44’ 6’ 1” 1” x 6’ EL Pony Rod w/ 1 XL guide per rod 50’ 2,925’ 1” 1” x 25’ EL Sucker rods w/ 4 XL guides per rod (New 5-27-14) 2,975’ 3,450’ 7/8” 7/8” x 25’ EL Sucker rods w/ “No” XL guides per rod (Used) 6,425’ 2,500’ 3/4” 3/4” x 25’ EL Sucker rods w/ “No” XL guides per rod (Used) C 8,925’ 300’ 1-1/2” 1-1/2” x 25’ K Bars (weight bars) D 9,225’ 2.75’ 1” 1” x 30” Stabilizer Bar w/ ¾” Pins (between K Bars) E 9,228’ 43’ 1-3/4” 1-3/4” x 42’ Insert Pump, RHBC Pump (Reran Used Pump 1/18/17) 80 PA Ring, Sand Seal, 2-1/2” x 1-3/4” x 36” x 36-1/2” x 37” RHBC F 9,291’ 1’ 1-1/2” Dip Tube PERFORATION DETAIL ON NEXT PAGE Soldotna Creek Unit Well: SCU 41A-08 Completion Ran: 10-1-2016 PTD: 194-085 API: 50-133-10120-01 Downhole Revised 05-27-14 Updated by TCS 06-23-21 PROPOSED SCHEMATIC PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments G-2 10,188' 10,192' 10,185’ 10,189’ 4' 10,196' 10,209' 10,193’ 10,206’ 13' H-2 10,281' 10,297' 10,277’ 10,293’ 16' 10,283’ 10,299’ 10,279’ 10,295’ 16’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-3 10,312’ 10,328’ 10,308’ 10,324’ 16’ 1-11/16” Enerjet, 6 spf, 90 phase 10,316’ 10,332’ 10,312’ 10,328’ 16’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-4 10,336' 10,344' 10,331’ 10,339’ 8' 10,338’ 10,346’ 10,333’ 10,341’ 8’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-5 10,356' 10,371' 10,351’ 10,366’ 15' 10,356’ 10,382’ 10,351’ 10,377’ 26’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-6 10,403’ 10,407’ 10,398’ 10,402’ 4’ 1-11/16” Enerjet, 4 spf, 0 phase H-7 10,413’ 10,432’ 10,408’ 10,426’ 19’ 1-11/16” Enerjet, 4spf, 0 phase 10,414’ 10,431’ 10,409’ 10,425’ 17’ 3-1/2” HC, 6 spf, 60 phase 3/2013 10,435’ 10,443’ 10,429’ 10,437’ 8’ 1-11/16” HC, 4 spf, 0 phase H-8 10,456’ 10,480’ 10,450’ 10,474’ 24’ 1-11/16” HC, 4 spf, 0 phase 10,446’ 10,481’ 10,440’ 10,475’ 35’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-9 H-9 10,502’ 10,516’ 10,496’ 10,510’ 14’ 1-11/16” HC, 4 spf, 0 phase 10,503’ 10,513’ 10,497’ 10,507’ 10’ 3-1/2” HC, 6 spf, 60 phase 3/2013 H-10 10,541’ 10,564’ 10,534’ 10,557’ 23’ 1-1/16” HC, 4 spf, 0 phase 10,541’ 10,568’ 10,534’ 10,561’ 27’ 3-1/2” HC, 6 spf, 60 phase 3/2013 10,544’ 10,564’ 10,537’ 10,557’ 20’ 3-1/2” HC, 6 spf, 60 phase 3/2013 10,564’ 10,620’ 10,557’ 10,613’ 50’ 1-11/16” Enerjet, 6 spf, 90 phase 10,617’ 10,632’ 10,610’ 10,625’ 15’ 1-11/16” Enerjet, 2 spf, 0 phase H-11 10,674’ 10,684’ 10,666’ 10,676’ 10’ 1-11/16” Enerjet, 10 spf, 180 phase H-12 10,709’ 10,725’ 10,701’ 10,717’ 16’ 1-11/16” Enerjet, 2 spf, 0 phase H-13 10,764’ 10,776’ 10,755’ 10,767’ 12’ 1-11/16” Pivot, 10 spf, 180 phase From:Jake Flora - (C) To:McLellan, Bryan J (CED) Cc:Taylor Wellman; Donna Ambruz; Todd Sidoti - (C) Subject:FW: [EXTERNAL] RE: SCU 41A-08 (PTD 194-085) Rod Repair Date:Friday, June 25, 2021 10:24:57 AM Attachments:Swanson rod pump wellhead configuration.pdf Hello Bryan, I’m helping Todd while he’s in the field. I drew up the attached wellhead configuration of a typical Swanson rod pump well to show the components and explain their functions. The rod stripper function is to clean the rods and not make a mess while pulling them. Your email below indicates that they are type of pressure containment or well control which they are not. The rod pump wells are proven ‘no flow’, through a no flow test, and they are being pumped because they cannot flow on their own. Let me know if you need anything further or call if you prefer to discuss any of the proposed steps involved in the rod repair. Thanks, Jake Flora 720-988-5375 From: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Sent: Thursday, June 24, 2021 11:06 AM To: Cole Bartlewski <cbartlewski@hilcorp.com>; Jake Flora - (C) <Jake.Flora@hilcorp.com> Subject: Fwd: [EXTERNAL] RE: SCU 41A-08 (PTD 194-085) Rod Repair can you help with this From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Wednesday, June 23, 2021 3:35 PM To: Todd Sidoti - (C) Subject: [EXTERNAL] RE: SCU 41A-08 (PTD 194-085) Rod Repair Todd, Can you send me: 1. a diagram of the wellhead and rod stripper head configuration. 2. A product information sheet for the rod stripper head. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Sent: Wednesday, June 23, 2021 10:25 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: SCU 41A-08 (PTD 194-085) Rod Repair Hi Bryan, Here is some information and backup documentation on these rod changeouts. If the rods and pump last more than 2 years it is a very good run. I have attached a previous sundry where Guy noted that no BOPs are required for these jobs. I will let you chew on this and we can talk later. Thanks, Todd Todd Sidoti | Kenai Ops Engineer | Hilcorp Alaska | 907-632-4113 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Stuffing Box: seals and lubricates polish rodFlow CrossRod Stripper: Removes oil and paraffin from rods when pulling them Rod Packoff:Element that seals on polish rod when changing out stuffing box packingPolish RodESD: if the lower stuffing box seals fail, the bucket fills with wellbore fluid, and a float switch shuts down the well. Typical Rod Pump Wellhead Configuration: Rod Packoff:Element that seals on polish rod when changing out stuffing box packing, or can be used to close on rods to change out rod stripper elementRod Stripper: Removes oil and paraffin from rods when pulling them Rig 401 stripper assembly for pulling rods:- Existing polish rod and stuffing box are laid down- Existing stripper, oiler, & packoff are unthreaded from flowcross- Workover stripper assembly (pictured) is made up to flow cross- A rod clamp holds the rods in place while swapping assemblies- The pup joint between stripper and packoff are adjusted as needed to space the assembly at the rig floor height From:Todd Sidoti - (C) To:McLellan, Bryan J (CED); Jake Flora - (C) Cc:Taylor Wellman; Donna Ambruz Subject:RE: [EXTERNAL] RE: SCU 41A-08 (PTD 194-085) Rod Repair Date:Monday, June 28, 2021 3:12:15 PM Attachments:SCU 41A-08 Surface Piping Diagram.pdf Hi Bryan, No work affecting the reservoir or productivity index has been performed since the no-flow test in 2013. The only operations have been rod repairs and a failed attempt at converting the well to a gas lift design. 41A-08 is approximately 4050’ away from SCU 322C-04 injection at the H1 interval. It is also located across a fault which acts as an additional baffle/barrier to fluid movement. SCU 41A- 08 is not considered part of any active injection pattern at Swanson River. The rod packoff is angled like a VBR and will close on all sizes of rod and polished rod. The flowline will be disconnected during this operation. I have attached a drawing of how piping will be configured during the operation. We will monitor for flow on tubing and IA sides. We will kill the well down the IA. There are checks in the pump and will only be able to pump down the tubing when the pump is unseated. The rod string is used to perform the fishing and pump installation. Please let me know if you have any further questions. Thanks, Todd From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Monday, June 28, 2021 12:29 PM To: Jake Flora - (C) <Jake.Flora@hilcorp.com> Cc: Taylor Wellman <twellman@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Subject: RE: [EXTERNAL] RE: SCU 41A-08 (PTD 194-085) Rod Repair Jake, Todd, A couple questions: 1. Will the rod packoff on the workover stripper assembly be set up to close on the sucker rods, or the polished rod, or both? 2. What will your surface piping look like while pulling rods? Please send a drawing. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jake Flora - (C) <Jake.Flora@hilcorp.com> Sent: Friday, June 25, 2021 10:25 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Subject: FW: [EXTERNAL] RE: SCU 41A-08 (PTD 194-085) Rod Repair Hello Bryan, I’m helping Todd while he’s in the field. I drew up the attached wellhead configuration of a typical Swanson rod pump well to show the components and explain their functions. The rod stripper function is to clean the rods and not make a mess while pulling them. Your email below indicates that they are type of pressure containment or well control which they are not. The rod pump wells are proven ‘no flow’, through a no flow test, and they are being pumped because they cannot flow on their own. Let me know if you need anything further or call if you prefer to discuss any of the proposed steps involved in the rod repair. Thanks, Jake Flora 720-988-5375 From: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Sent: Thursday, June 24, 2021 11:06 AM To: Cole Bartlewski <cbartlewski@hilcorp.com>; Jake Flora - (C) <Jake.Flora@hilcorp.com> Subject: Fwd: [EXTERNAL] RE: SCU 41A-08 (PTD 194-085) Rod Repair can you help with this From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Wednesday, June 23, 2021 3:35 PM To: Todd Sidoti - (C) Subject: [EXTERNAL] RE: SCU 41A-08 (PTD 194-085) Rod Repair Todd, Can you send me: 1. a diagram of the wellhead and rod stripper head configuration. 2. A product information sheet for the rod stripper head. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Sent: Wednesday, June 23, 2021 10:25 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: SCU 41A-08 (PTD 194-085) Rod Repair Hi Bryan, Here is some information and backup documentation on these rod changeouts. If the rods and pump last more than 2 years it is a very good run. I have attached a previous sundry where Guy noted that no BOPs are required for these jobs. I will let you chew on this and we can talk later. Thanks, Todd Todd Sidoti | Kenai Ops Engineer | Hilcorp Alaska | 907-632-4113 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. STATE OF ALASKA RECEIVED AKA OIL AND GAS CONSERVATION COASION FEB 0 1 2017 REPORT OF SUNDRY WELL OPERATIONS CC 1.Operations Abandon LJ Plug Perforations LJ Fracture Stimulate Li Pull Tubing U 'Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill Cl srforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well❑ Other: Repair Rod Pump ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Exploratory DevelopmentEx ❑ p ry ❑ 194-085 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic Service ❑ 6.API Number: Anchorage,AK 99503 50-133-10120-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028996 Soldotna Creek Unit(SCU)41A-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 10,930 feet Plugs measured N/A feet true vertical 10,920 feet Junk measured 10,618(fill) feet Effective Depth measured 10,618 feet Tubing Anchor measured 9,138 feet true vertical 10,611 feet true vertical 9,138 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 46' 20" 46' 46' Surface 2,022' 11-3/4" 2,022' 2,022' 3,070 psi 1,510 psi Intermediate Production 9,745' 7" 9,745' 9,745' 6,340 psi 3,830 psi Liner 1,468' 5" 10,925' 10,915' 10,140 psi 10,500 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-7/8" 6.5#/L-80 9,201'MD 9,201'TVD Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.7#/N-80 10,085'MD 10,083'TVD 9,138'MD Packers and SSSV(type,measured and true vertical depth) Tubing Anchor;N/A 9,138'TVD N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): /s. rr C� '7 _� N/A SCANNED k'fiA ' v c Lu t , 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 0 140 140 Subsequent to operation: 35 189 180 50 185 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 Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q 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: 317-016 Contact Joe Kaiser-777-8393 Email jkaiserAhilcorp.com Printed Name Chad Helgeson Title Operations Manager �,�J Signature Phone Phone 907-777-8405 Date 1/I/1 7 RBDMS UV F - 3 2017 Form 10-404 Revised 5/2015 /- .z-t "/7 Submit Original Only iV, z•-/ 7 • • Hi corp Alaska, LLC i Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 41A-08 Moncla 401 50-133-10120-01 194-085 1/16/17 1/18/17 Daily Operations: 01/16/2017- Monday Held Pre Job Meeting at Moncla's Office Mob Moncla 401 and associated equipment to location. Laid containment and spotted bean and rig.SDFN. 01/17/2017-Tuesday Held PJSM, discussed daily activities. MIRU Moncla 401, raised derrick and RU floor. Prep rig floor to unseat pump and pull rod string. SITP 20psi. MIRU blowdown trailer and bled off tbg to Opsi. Latched polish rod and BO/LD the stuffing box. Latched and PU on the polish rod and unseated the rod pump. BO/LD the polish rods. NU the rod stripper head. MIRU vac truck. Pumped 60 bbls of hot water and w/1 drum of 077 paraffin cutter down the tbg. Note had to work rod string while pumping due to paraffin buildup. RDMO vac truck.TOOH standing back rod completion. L/D sinker bars and rod pump.Visually inspected rod string and pump. Replaced 3 rod boxes in the 1" section. Out side of the pump showed no sign of wear. Bucket tested the pump, good. Secured well and SDFN. Night watch on tower. 01/18/2017 -Wednesday Held PJSM. Shut down due to temp at-32°. Waiting on temp to warm above-20°to be able to work the rig. BO stuffing box, RU rod stripper head , MU memory gauge, 1" x 22' dip tube (2' of perf on bottom), 1-3/4" x 36' 80 ring rod pump (pulled From SCU 32-08) and bucket tested pump, good test.TIH w/rod string, menory gauge, dip tube, pump, 13 sink bars 1-1/2" rods, 100 3/4" EL sucker rods, 138 7/8" EL sucker rods, 116 1" EL rods and tagged seat nipple. PU/MU 6' and 4' pony rods, stuffing box and polish rod. Seated rod pump. Spaced pump out 32' off bottom and landed with rod clamps leaving 152" of polish rod above the Rotaflex slab. MIRU vac truck pump 15 bbls to fill tbg string. RDMO vac truck. Stroked rod pump with rig and pressured up on tbg to 750psi, good test. BO guide lines and lower derrick. Secured well and SDFN. ,fit • 0 Soldotna Creek Unit Well: SCU 41A-08 SCHEMATIC Completion Ran: 10-1-2016 tlikiwi, 1 la-1.1.III PTD: 194-085 API: 50-133-10120-01 RKB=15' A CASING AND TUBING DETAIL 1 20" Size WT Grade ID I Top Btm 20" Surf 46' B 11-3/4" 47# 1-55 11" Surf 2,022' 7" 29# N-80 6.184" Surf 290' 7" 26# N-80 6.276" 290' 1,219' 7" 23# N-80 6.366" 1,219' 4,952' 11-3/4" 7" 26# N-80 6.276" 4,952' 6,617' 2 7" 23# N-80 6.366" 6,617' 8,427' 7" 29# P-110 6.184" 8,427' 9,745' 5" 18# L-80 4.276" 9,457' 10,925' TUBING 2-7/8" 6.5# L-80 2.441" Surf 9,201' 2-3/8" 4.7# N-80 1.995" 9,430' 10,085' C 3 JEWELRY DETAIL —Tali. INitv No. Depth ID Item 1 15' 2.441" Tubing Hanger-1 Latch Dlli 4 2 3,004' 2.441" 2-7/8"Chemical In)Sub w/A"control line(Live Valve) 3 9,137' 2.441" 7"Weatherford Tubing Anchor(35K Shear) E 4 9,201' 2.315" 2-7/8"Seating Nipple 5 9,203' 2.992" 3.5"Slotted Sub F5 6 9,271' - 3-1/2"Bull Plug 7 9,401' 2.500" Seating Nipple with cut off 2-7/8"tubing 8 9,406' 2.441" Anchor Separator w/4'pup;2-1/16" J tubing-120' 6 Tag Top @ 9 9,407' 2.441" X-over 2-3/8"pin x 2-7/8"box 9,304' 10 9,440' 1.995" On/Off Tool 9/26/2016 11 9,446' 1.995" 5"Arrowset 1X Packer I. 12 10,084' 1.995" WL Re-entry Guide I 8 et 9 ROD DETAIL # Depth Length OD Description A 0 40' 1-1/2" Polished Rod,30'in well(New 5-27-14) 10 B 40' 4' 1" 1"x 4'EL Pony Rod w/1 XL guide per rod ® 44' 6' 1" 1"x 6'EL Pony Rod w/1 XL guide per rod 11 7" 50' 2,925' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(New 5-27-14) 12 2,975' 3,450' 7/8" 7/8"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) G-2 6,425' 2,500' 3/4" 3/4"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) H-2 = C 8,925' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) H-3 D 9,225' 2.75' 1" 1"x 30"Stabilizer Bar w/%"Pins(between K Bars) H-4 = 1-3/4"x 42'Insert Pump,RHBC Pump(Reran Used Pump H-5 = E 9,228' 43' 1-3/4" 1/18/17) 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37"RHBC H-6 _-=.- F 9,291' 1' 1-1/2" Dip Tube H-7 — H-8 H-9 =-- Ar.,..r.Tag Fill H-1010,583' 3/8/13 H-11 = H-12 PERFORATION DETAIL ON NEXT PAGE H-13 — L.iAir4e1 fat74j* 5" TD=10,930' PBTD=10,835' Max Hole Angle=9.1 deg Downhole Revised 05-27-14 Updated by JEK 01-31-17 ...11 • 0 Soldotna Creek Unit Well: SCU 41A-08 SCHEMATIC Completion Ran: 10-1-2016 I IIIPurr 'I,-Lt.Is.c PTD: 194-085 API: 50-133-10120-01 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments G-2 10,188' 10,192' 10,185' 10,189' 4' 10,196' 10,209' 10,193' 10,206' 13' 10,281' 10,297' 10,277' 10,293' 16' H-2 10,283' 10,299' 10,279' 10,295' 16' 3-1/2"HC,6 spf,60 phase 3/2013 H-3 10,312' 10,328' 10,308' 10,324' 16' 1-11/16"Enerjet,6 spf,90 phase 10,316' 10,332' 10,312' 10,328' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,336' 10,344' 10,331' 10,339' 8' H-4 10,338' 10,346' 10,333' 10,341' 8' 3-1/2"HC,6 spf,60 phase 3/2013 H-5 10,356' 10,371' 10,351' 10,366' 15' 10,356' 10,382' 10,351' 10,377' 26' 3-1/2"HC,6 spf,60 phase 3/2013 H-6 10,403' 10,407' 10,398' 10,402' 4' 1-11/16"Enerjet,4 spf,0 phase 10,413' 10,432' 10,408' 10,426' 19' 1-11/16"Enerjet,4spf,0 phase H-7 10,414' 10,431' 10,409' 10,425' 17' 3-1/2"HC,6 spf,60 phase 3/2013 10,435' 10,443' 10,429' 10,437' 8' 1-11/16"HC,4 spf,0 phase H-8 10,456' 10,480' 10,450' 10,474' 24' 1-11/16"HC,4 spf,0 phase 10,446' 10,481' 10,440' 10,475' 35' 3-1/2"HC,6 spf,60 phase 3/2013 H-9 10,502' 10,516' 10,496' 10,510' 14' 1-11/16"HC,4 spf,0 phase H-9 10,503' 10,513' 10,497' 10,507' 10' 3-1/2"HC,6 spf,60 phase 3/2013 10,541' 10,564' 10,534' 10,557' 23' 1-1/16"HC,4 spf,0 phase 10,541' 10,568' 10,534' 10,561' 27' 3-1/2"HC,6 spf,60 phase 3/2013 H-30 10,544' 10,564' 10,537' 10,557' 20' 3-1/2"HC,6 spf,60 phase 3/2013 10,564' 10,620' 10,557' 10,613' 50' 1-11/16"Enerjet,6 spf,90 phase 10,617' 10,632' 10,610' 10,625' 15' 1-11/16"Enerjet,2 spf,0 phase H-11 10,674' 10,684' 10,666' 10,676' 10' 1-11/16"Enerjet,10 spf,180 phase H-12 10,709' 10,725' 10,701' 10,717' 16' 1-11/16"Enerjet,2 spf,0 phase H-13 10,764' 10,776' 10,755' 10,767' 12' 1-11/16"Pivot,10 spf,180 phase Downhole Revised 05-27-14 Updated by JEK 01-31-17 • • *.\��1/7 s7 THE STATE Alaska Oil and Gas °fALASKA Conservation Commission 333 West Seventh Avenue ' — c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 !�� ' Main: 907.279.1433 (4'',, ':" 1‘18. Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations ManagercANN ` � '. Hilcorp Alaska, LLC 3 800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 41A-08 Permit to Drill Number: 194-085 Sundry Number: 317-016 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, Cathy . Foerster �/ Chair DATED this I A`day of January, 2017. RDDPIIS (%--JAN 2 5 2017 • • RECEIVED • STATE OF ALASKA J 1 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS )A/,N 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations El Fracture Stimulate ❑ Repair Well 0 - Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Rod Part/Pump Repair 111. 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development Q - 194-085 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ElService ii 6.API Number: Anchorage,Alaska 99503 50-133-10120-01 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 123B Will planned perforations require a spacing exception? Yes ElNo ElSoldotna Creek Unit(SCU)41A-08 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996 Swanson River Field/Hemlock Oil . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 10,930' • 10,920' ' 10,618' 10,611' 1,460 psi N/A 10,618'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 46' 20" 46' 46' Surface 2,022' 11-3/4" 2,022' 2,022' 3,070 psi 1,510 psi Intermediate Production 9,745' 7" 9,745' 9,745' 6,340 psi 3,830 psi Liner 1,468' 5" 10,925' 10,915' 10,140 psi 10,500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: 2-7/8" Tubing Grade: 6.4#/L-80 Tubing MD(ft): 9,424 See Attached Schematic See Attached Schematic 2-3/8" 4.7#/N-80 10,085 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Tripoint AS1-X;N/A 9,446'MD;9,446'TVD-N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory El Stratigraphic❑ Development❑., - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: January 16,2017 OIL Q , WINJ El WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS El WAG ❑ GSTOR El SPLUG ❑ Commission Representative: GINJ El Op Shutdown ❑ Abandoned El 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 ilii/i7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317 - 6tCR. Plug Integrity ❑ BOP Test El Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes EI No Subsequent Form Required: /(j --41 01 1 RBD S LL- JAr1L. 57017 APPROVED BY Approved by: 0, COMMISSIONER THE COMMISSION Date: /— I 3 f 7 o 1 7 Submit Form and Form 10-403 Revis 11/20115— t/2015RteipNiklamlid for 12 months from the date of approval. �� Attachments in Duplicate rr/7'T// ...a 0 / (2. /> • • Well Prognosis Well: SCU 41A-08 Hilcory Alaska,Lb Date: 1/12/2017 Well Name: SCU 41A-08 API Number: 50-133-10120-01 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: January 16th, 2017 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 194-085 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: —2,500 psi @ 10,400' TVD (BHP Buildup interpretation 6/6/2006) Max. Expected BHP: —2,500 psi @ 10,400' ND Max. Potential Surface Pressure: —1,460 psi (0.1 psi/ft gas gradient to surface) Brief Well Summary Soldotna Creek Unit 41A-08 was drilled in 1994 as a sidetrack of the original Hemlock injection well SCU 341-08. • SCU 41A-08 was initially completed in the lower Hemlock(H10-H13 sands)free flowing at approximately 100 BOPD and low GOR. From 1996—2001,the H4—H10 sands were added to the completion in an effort to blow down gas injected into the Hemlock in SCU 341-08. Significant paraffin deposition throughout the life of the well has led to regular mechanical and solvent(xylene) treatments. In 2001,the H2-H5 sands were added and the well began flowing on gas lift. The Tyonek G-Zone was added in 2007 with no noticeable production contribution.The completion was converted to Rotaflex rod pump in March 2013. In October 2016, the tubing was cut, pulled, and tubing anchor was replaced. In January 2017, diagnostics show that the pump failed or the • ,iE rods have a deep part and need repaired. 4E- The purpose of this work/sundry is to utilize the Moncla#401 rig to replace the rod pump or repair the arted . rods. r� Notes Regarding Wellbore Condition , ( t ro' • Surface equipment(Roto-flex unit) disconnected and rolled back. Ready for WO rig. 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 stripper head. 5. LD polish rod and pull EL rods.Visually inspect rods while racking them back in basket. a. Contingency: i. If parted rod is found, replace 3 rods above and below rod part. LD parted rod. ii. PU overshot and RIH. Fish parted rod. Pull remaining rod string with pump. 6. LD and inspect rods, pump and dip tube and all pulled rods. . 7. PU existing dip tube and new or rebuilt 1-3/4" rod pump, replace and RIH withexistin tapered rod string(sinker bars, 3/4", 7/8" and 1), space out the rods, install polish rod. - 8. ND rod stripper, install surface equipment onto well and test pack off to 1,000 psi. 9. RD Moncla #401 WO Rig. 10. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. • • Well Prognosis Well: SCU 41A-08 Hilcorp Alaska,LL Date: 1/12/2017 11. Return to production with same surface safety system as previously installed. 12. Replace IA x OA pressure gauge if removed (7"x 11-3/4"). Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Blank RWO Procedure Change Form • • Soldotna Creek Unit Well: SCU 41A-08 , H SCHEMATIC Completion Ran: 10-1-2016 I; l...,r,, uird.a.1.1.4. PTD: 194-085 API: 50-133-10120-01 RKB=15' A [ CASING AND TUBING DETAIL 1 20, Size WT Grade ID Top Btm I L 20" Surf 46' B 11-3/4" 47# J-55 11" Surf 2,022' 7" 29# N-80 6.184" Surf 290' 7" 26# N-80 6.276" 290' 1,219' 7" 23# N-80 6.366" 1,219' 4,952' 11 3/4" 7" 26# N 80 6.276" 4,952' 6,617' 2 7" 23# N-80 6.366" 6,617' 8,427' 7" 29# P-110 6.184" 864,:469261722'; ,427' 9,745' 5" 184 L-80 4.276" 9,457' 10,925' TUBING 2 7/8" 6.5# L 80 2.441" Surf 9,201' 2-3/8" 4.74 N 80 1.995" 9,430' 10,085' C 3 JEWELRY DETAIL 5 No. Depth ID Item 1 15' 2.441" Tubing Hanger-J Latch D Suspeted 2 3,004' 2.441" 2-7/8"Chemical Inj Sub w/'/<"control line(Live Valve) 4 bad pump 3 9,137' 2.441" 7"Weatherford Tubingh E - or deep rod Anchor(35K Shear) part 4 9,201' 2.315" 2-7/8"Seating Nipple 5 9,203' 2.992" 3.5"Slotted Sub F 5 6 9,271' - 3-1/2"Bull Plug J r, a t 7 9,401' 2.500" Seating Nipple with cut off 2-7/8"tubing 8 9,406' 2.441" Anchor Separator w/4'pup;2-1/16"IJ tubing-120' 6 Tag Top @ 9 9,407' 2.441" X-over 2-3/8"pin x 2-7/8"box - 9,304' 10 9,440' 1.995" On/Off Tool 9/26/2016 11 9,446' 1.995" 5"Arrowset 1X Packer 12 10,084' 1.995" WL Re-entry Guide 7 8 ROD DETAIL 9 # Depth Length OD Description A 0 40' 1-1/2" Polished Rod,30'in well(New 5-27-14) t 10 B 40' 4' 1" 1"x 4'EL Pony Rod w/1 XL guide per rod Q+ 41; 44' 6' 1" 1"x 6'EL Pony Rod w/1 XL guide per rod 11 T 50' 2,925' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(New 5-27-14) 12 2,975' 3,450' 7/8" 7/8"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) G-2 6,425' 2,500' 3/4" 3/4"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) H-2 = C 8,925' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) H-3 = D 9,225' 2.75' 1" 1"x 30"Stabilizer Bar w/'Y."Pins(between K Bars) H-4 = E 9,228' 43' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump(NEW 10/12/16) H-5 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37"RHBC H-6 = F 9,291' 1' 1-1/2" Dip Tube H-7 H-8 H-9 Tag Fill H-1010,583' 3/8/13 H-11 = I H-12 = PERFORATION DETAIL ON NEXT PAGE H-13 TD=10,930' PBTD=10,835' Max Hole Angle=9.1 deg Downhole Revised 05-27-14 Updated byJEK 1-10-17 .. H • Soldotna Creek Unit Well: SCU 41A-08 SCHEMATIC Completion Ran: 10-1-2016 Ritrnrp thotka.i.i.i: PTD: 194-085 API: 50-133-10120-01 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10,188' 10,192' 10,185' 10,189' 4' 2 10,196' 10,209' 10,193' 10,206' 13' 10,281' 10,297' 10,277' 10,293' 16' H-2 10,283' 10,299' 10,279' 10,295' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,312' 10,328' 10,308' 10,324' 16' 1-11/16"Enerjet,6 spf,90 phase H-3 10,316' 10,332' 10,312' 10,328' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,336' 10,344' 10,331' 10,339' 8' H-4 10,338' 10,346' 10,333' 10,341' 8' 3-1/2"HC,6 spf,60 phase 3/2013 10,356' 10,371' 10,351' 10,366' 15' H-5 10,356' 10,382' 10,351' 10,377' 26' 3-1/2"HC,6 spf,60 phase 3/2013 H-6 10,403' 10,407' 10,398' 10,402' 4' 1-11/16"Enerjet,4 spf,0 phase 10,413' 10,432' 10,408' 10,426' 19' 1-11/16"Enerjet,4spf,0 phase H-7 10,414' 10,431' 10,409' 10,425' 17' 3-1/2"HC,6 spf,60 phase 3/2013 10,435' 10,443' 10,429' 10,437' 8' 1-11/16"HC,4 spf,0 phase 10,456' 10,480' 10,450' 10,474' 24' 1-11/16"HC,4 spf,0 phase H-8 10,446' 10,481' 10,440' 10,475' 35' 3-1/2"HC,6 spf,60 phase 3/2013 H-9 10,502' 10,516' 10,496' 10,510' 14' 1-11/16"HC,4 spf,0 phase H-9 10,503' 10,513' 10,497' 10,507' 10' 3-1/2"HC,6 spf,60 phase 3/2013 10,541' 10,564' 10,534' 10,557' 23' 1-1/16"HC,4 spf,0 phase 10,541' 10,568' 10,534' 10,561' 27' 3-1/2"HC,6 spf,60 phase 3/2013 H-10 10,544' 10,564' 10,537' 10,557' 20' 3-1/2"HC,6 spf,60 phase 3/2013 10,564' 10,620' 10,557' 10,613' 50' 1-11/16"Enerjet,6 spf,90 phase 10,617' 10,632' 10,610' 10,625' 15' 1-11/16"Enerjet,2 spf,0 phase H-11 10,674' 10,684' 10,666' 10,676' 10' 1-11/16"Enerjet,10 spf,180 phase H-12 10,709'. 10,725' 10,701' 10,717' 16' 1-11/16"Enerjet,2 spf,0 phase H-13 10,764' 10,776' 10,755' 10,767' 12' 1-11/16"Pivot,10 spf,180 phase Downhole Revised 05-27-14 Updated by JEK 1-10-17 • Soldotna Creek Unit H0 Well: SCU 41A-08 PROPOSED SCHEMATIC Completion Ran: 10-1-2016 Ililrurp nl«,1.n.I 1i PTD: 194-085 API: 50-133-10120-01 RKB=15' A is T� CASING AND TUBING DETAIL 1 L20-, Size WT Grade ID Top Btm 20" Surf 46' B 11-3/4" 47# J-55 11" Surf 2,022' 7" 29# N-80 6.184" Surf 290' 7" 26# N-80 6.276" 290' 1,219' 7" 23# N-80 6.366" 1,219' 4,952' 11-3/4" 7" 26# N-80 6.276" 4,952' 6,617' 2 7" 23# N-80 6.366" 6,617' 8,427' 7" 29# P-110 6.184" 8,427' 9,745' 5" 18# L-80 4.276" 9,457' 10,925' TUBING 2-7/8" 6.5# L-80 2.441" Surf 9,201' 2-3/8" 4.7# N-80 1.995" 9,430' 10,085' 3 JEWELRY DETAIL s - No. Depth ID Item 1 15' 2.441" Tubing Hanger–J Latch D 4 2 3,004' 2.441" 2-7/8"Chemical Inj Sub w/X"control line(Live Valve) 3 9,137' 2.441" 7"Weatherford Tubing Anchor(35K Shear) E 4 9,201' 2.315" 2-7/8"Seating Nipple 5 9,203' 2.992" 3.5"Slotted Sub F - 5 6 9,271' - 3-1/2"Bull Plug 7 9,401' 2.500" Seating Nipple with cut off 2-7/8"tubing " 8 9,406' 2.441" Anchor Separator w/4'pup;24/18"IJ tubing 120' 6 Tag Top @ 9 9,407' 2.441" X-over 2-3/8"pin x 2-7/8"box 9,304' 10 999991144422400000076131::: ,440' 1.995" On/Off Tool 9/26/2016 11 9,446' 1.995" 5"Arrowset 1X Packer 12 10,084' 1.995" WL Re-entry Guide 7 8 - � , ROD DETAIL 9 # Depth Length OD Description Alir A 0 40' 1-1/2" Polished Rod,30'in well(New 5-27-14) 10 B 40' 4' 1" 1"x 4'EL Pony Rod w/1 XL guide per rod �� — 44' 6' 1" 1"x 6'EL Pony Rod w/1 XL guide per rod 11 7' 50' 2,925' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(New 5-27-14) 12 2,975' 3,450' 7/8" 7/8"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) G-2 6,425' 2,500' 3/4" 3/4"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) H-2 C 8,925' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) H-3 D 9,225' 2.75' 1" 1"x 30"Stabilizer Bar w/3/4"Pins(between K Bars) H-4 E 9,228' 43' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump(NEW 10/12/16) H-5 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37"RHBC H-6 F 9,291' 1' 1-1/2" Dip Tube H-7 H-8 H-9 ....<Tag Fill H-10 10,583' 3/8/13 H-11 I H-12 PERFORATION DETAIL ON NEXT PAGE H-13 G'.. esgrr"i. s" TD=10,930' PBTD=10,835' Max Hole Angle=9.1 deg Downhole Revised 05-27-14 Updated byJEK 1-11-17 .. H H . • Soldotna Creek Unit Well: SCU 41A-08 PROPOSED SCHEMATIC Completion Ran: 10-1-2016 Ili!um Alit Li.I,1. PTD: 194-085 API: 50-133-10120-01 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10,188' 10,192' 10,185' 10,189' 4' 2 10,196' 10,209' 10,193' 10,206' 13' H-2 10,281' 10,297' 10,277' 10,293' 16' 10,283' 10,299' 10,279' 10,295' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,312' 10,328' 10,308' 10,324' 16' 1-11/16"Enerjet,6 spf,90 phase H-3 10,316' 10,332' 10,312' 10,328' 16' 3-1/2"HC,6 spf,60 phase 3/2013 H-4 10,336' 10,344' 10,331' 10,339' 8' 10,338' 10,346' 10,333' 10,341' 8' 3-1/2"HC,6 spf,60 phase 3/2013 10,356' 10,371' 10,351' 10,366' 15' H-5 10,356' 10,382' 10,351' 10,377' 26' 3-1/2"HC,6 spf,60 phase 3/2013 H-6 10,403' 10,407' 10,398' 10,402' 4' 1-11/16"Enerjet,4 spf,0 phase 10,413' 10,432' 10,408' 10,426' 19' 1-11/16"Enerjet,4spf,0 phase H-7 10,414' 10,431' 10,409' 10,425' 17' 3-1/2"HC,6 spf,60 phase 3/2013 10,435' 10,443' 10,429' 10,437' 8' 1-11/16"HC,4 spf,0 phase 10,456' 10,480' 10,450' 10,474' 24' 1-11/16"HC,4 spf,0 phase H-8 10,446' 10,481' 10,440' 10,475' 35' 3-1/2"HC,6 spf,60 phase 3/2013 H-9 10,502' 10,516' 10,496' 10,510' 14' 1-11/16"HC,4 spf,0 phase H-9 10,503' 10,513' 10,497' 10,507' 10' 3-1/2"HC,6 spf,60 phase 3/2013 10,541' 10,564' 10,534' 10,557' 23' 1-1/16"HC,4 spf,0 phase 10,541' 10,568' 10,534' 10,561' 27' 3-1/2"HC,6 spf,60 phase 3/2013 H-10 10,544' 10,564' 10,537' 10,557' 20' 3-1/2"HC,6 spf,60 phase 3/2013 10,564' 10,620' 10,557' 10,613' 50' 1-11/16"Enerjet,6 spf,90 phase 10,617' 10,632' 10,610' 10,625' 15' 1-11/16"Enerjet,2 spf,0 phase H-11 10,674' 10,684' 10,666' 10,676' 10' 1-11/16"Enerjet,10 spf,180 phase H-12 10,709' 10,725' 10,701' 10,717' 16' 1-11/16"Enerjet,2 spf,0 phase H-13 10,764' 10,776' 10,755' 10,767' 12' 1-11/16"Pivot,10 spf,180 phase Downhole Revised 05-27-14 Updated byJEK 1-11-17 • • V. § kms P ' Q a) & � 2 R & Q 2 ■ 77 So12 ._ 2 0.a § f « E ® o a 2 § Q § 03 co a I O. c \ « L'.- �• / 0 0 u) m 7 � 20 p am E a 0- § 11 � � ■ a)2 ■ ■ z_ re$ C 3 .' 9 co ix @ 0 - i / Ws o _o 2 CD « c .@• c k k � § ig — C a) % U ■ a) 0 a) < 0 ]. a = § s_ 2 k •'� -a 2 a) a) o - - k 43 .� § k 2En co 80 c w ■ 7 @ ■ ta U 2 > � � co � Q O CC A § 0 a a. 4 cid Q A / E 0 v) 2 ® R » a Q ■ o c c a U .< 2 .g a CO $ 2 L U � � < iZ E 0 .. ii .. g ■ k 2 2 >,o g 0_ a. V k 2 a. Q Z1 k RFCEIVED STATE OF ALASKA NOV 15 ?015 • AIL OIL AND GAS CONSERVATION COM ION s REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon LI Plug Perforations ❑ Fracture Stimulate H Pull Tubing IJ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Other: Repair Rod Pump CI 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 194-085 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service ❑ 6.API Number: Anchorage,AK 99503 50-133-10120-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028996 Soldotna Creek Unit(SCU)41A-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 10,930 feet Plugs measured N/A feet true vertical 10,920 feet Junk measured 10,618(fill) feet Effective Depth measured 10,618 feet Tubing Anchor measured 9,138 feet true vertical 10,611 feet true vertical 9,138 feet Casing Length Size MD ND Burst Collapse Structural Conductor 46' 20" 46' 46' Surface 2,022' 11-3/4" 2,022' 2,022' 3,070 psi 1,510 psi Intermediate Production 9,745' 7" 9,745' 9,745' 6,340 psi 3,830 psi Liner 1,468' 5" 10,925' 10,915' 10,140 psi 10,500 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-7/8" 6.5#/L-80 9,201'MD 9,201'ND Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.7#/N-80 10,085'MD 10,083'ND 9,138'MD Packers and SSSV(type,measured and true vertical depth) Tubing Anchor;N/A 9,138'ND N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A SHt4MAE I 6, "rig 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: 46 24 138 83 180 Subsequent to operation: 57 48 202 175 180 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 Q 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: 316-450 Contact Joe Kaiser-777-8393 Email jkaiser@hilcorp.corn Printed Name Chad Helgeson Title Operations Manager Signature gt/1"? .. Phone907-777-8405 Date lift 5/1(0 Form 10-404 Revised 5/2015 /7,2',-'-6"(. RBDMS t,t, NOV 1 6 2016 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 41A-08 Moncla 401 50-133-10120-01 194-085 9/19/16 10/12/16 Daily Operations: 09/19/2016- Monday Mobe Moncla 401 from Kenai Yard to SCU 41-08. Laid contaiment. Secured equipment and SDFN. 09/20/2016-Tuesday Held JSA and discussed daily Ops. Finished laying pit liner. Spotted beam and rig. Raised derrick and RU floor. Prep rig floor to unseat pump and pull rod string. SITP 150psi. MIRU blowdown trailer and bled off tbg to 0 psi. Latched polish rod and BO/LD the stuffing box. Latched and PU on the polish rod and unseated the rod pump. BO/LD the polish rods. NU the rod stripper head. MIRU vac truck. Pumped 70 bbls of hot water and paraffin cutter down the tbg. Note: had to work rod string while pumping due to paraffin buildup. RDMO vac truck. Continue spotting associated rig equipment and sealed in containment. Built containment to LD rods in with tbg on a vacuum,TOH LD pony rods and 56 1" EL rods, pulled heavy at time due to paraffin build up. PU/MU the polish rod and stuffing box, secured well and SDFN. 09/21/2016-Wednesday Held JSA and discussed daily ops. BO/LD stuffing box and polish rod, continued LD rod string with periodic drag. BO/LD pump.The fishing neck and fluid outlet was broke away from the pump body causing the drag come out of the hole. Inspected rod guides and boxes with minimal amout of wear. Cleaned and pinned back rig floor. Prepped BOP's stack to NU.Tried to install a back pressure valve in the tbg hanger profile.Treads would only makeup a 1/8" of a turn. Tried 2 different profile plugs with the same results. Contacted the engineer and discussed plan and option. Received AOGCC approval for contingency plan. Dropped test plug to land in the seating nipple at 9,401'. MU Kelly hose and pumped 22 bbls to fill tbg string. Pressured up on tbg to 1,5000i and charted for 10 mins. Good test. ND the production, inspected hanger lifting treads to be in good condition, NU BOP stack. Secured well and SDFN. 09/22/2016-Thursday Held PJSM, discussed daily job activities MU Koomey lines to BOP Stack, MU kill/choke lines. RU handle rails and stairwell to rig floor. Vac standing rain water from containment. RU Triplex pump and tank to test BOPE. PU/MU test jt and floor valves. Flood BOPE equipment and circulated thru BOPE. Performed shell test 3,500psi.Test failed with connection leak.Tightened connections and retested good.Tested BOPE as follows: gas detection, pressure tested annular 250-3,500psi, rams 250-3,500psi,valves 250-3 500psi. Performed Koomey drawdown test. No failures recorded. AOGCC witness by Matt Herrera. BO/LD test jt and blanking sub, MIRU SL, tested 2,500psi. RIH w/2"JDC and set down @ 500'. POOH. PU and tbg scratcher and cleaned paraffin at 500'. Continued RIH to 4,000'. POOH. RIH w/2"JDC and tagged plug at 9,404', on plug and could not latch. POOH, recover a piece of rubber from pulling tool. RIH w/same and latched plug and waited for well to equalize. POOH. LD test plug. RDMO SL. Secured well and SDFN. . . • IIHilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 41A-08 Moncla 401 50-133-10120-01 194-085 9/19/16 10/12/16 Daily Operations: 09/23/2016- Friday Held PJSM, discussed Hazards and daily ops. SICP 100psi, MU Kelly hose to csg, bled off csg pressure through check to gas buster. Swap valves and pumped 70 bbls down csg. Monitor well on vac. MU 2-7/8" landing joint. PU 52K and turned pipe 1/4 turn to the left. Dropped out of parrant bowl and started take wieght on packer. Packer was not set in tension. PU and jayed back into hanger, BOLDS and turned pipe to right and tried releasing the packer with no luck. Continued work pipe for several hours to release the AS1 packer, unsuccessful. Note: No indication of movement in the packer. Discussed plan with engineer to release from the On/Off tool.Turn pipe to the left and worked for several hrs and cound not release from On/Off tool. Note: No indication of movement in the packer. PU on pipe to 115K. Set in slips and BO/LD tbg hanger and landing jt. MU 2-7/8" landing jt and continued to work pipe trying to release packer with no luck. Set pipe in slip with 115K in tension. Secured well and SDFN. 09/24/2016-Saturday Held PJSM and discussed daily ops. Continued working pipe trying to release packer. Set pipe in set with 15 ' , tension, MIRU Pollard EL, test lub to 2,500psi,good test. RIH with CCL and chemical cutter and cut tbg at 9,43 ' leave 12' of 2-1/16" above the 2-7/8" cut. POOH and RDMO EL PU on tbg with 10K overpull then tbg came free.TOWWith 94 stands of 2-7/8" 8rd tbg. Cut 3,000' of chem injection line while TOH. Secured well and SDFN. 09/25/2016-Sunday Held PJSM and discussed daily ops. TOH with 53 stands and single and one cut jt of 2-7/8" EUE 6.5#8rd. MIRU WL, RIH with 5.75" LIB and tag @ 9,307'. POOH. RDMO. LIB showed 2-1/16" pipe looking up. MU 5-3/4" cut lip guide, bowl and top sub loaded with 2-1/16" grapple.TIH w/ 146 stands 2-7/8" EUE and tagged TOP fish @ 9,304'. Spaced out pipe and swallowed fish and could not latch up after several attempts. Discussed with engineer and decided to TOH and trouble shoot OS. Secured well and SDFN. 09/26/2016- Monday Held PJSM.TOH with 146 stands of 2-7/8" 8rd and OS, LD same. Removed 2" grapple and showed marks of the TOF measuring 2-5/32". PU/MU 5-3/4" cut lip guide bowl top sub loaded with 2-5/32" grapple.TOH w/same and tagged top of fish @ 9,300'. Oriented cut lip guide over and swallowed TOF. Set down and couldn't latch fish after several attemps. MIRU SL test to 2,500-good test. RIH w/ 1.18" swedge, weight bar and knuckle jt tagged inside "Y" Block @ 9,470' SLM and counld not work thru. POOH. LD weight bar to shorten toolstring. RIH w/1.18" swedge and knuckle jt tagged in same spot and could not work thru. POOH. RDMO SL. Secured well and SDFN. 09/27/2016-Tuesday Held PJSM, discussed daily ops. TOH with 5-3/4" OS on stands. Staggered stands breaks while TOH. BO/LD OS. Sent chemical sud to Pollard for redress.Tallied completion jewlery,TIH with completion as follow: 3-1/2" EUE bull plug, 2 jts of 3-1/2" EUE 9.2#8rd L-80, 3-1/2" slotted sub, XO 3-1/2" x 2-7/8" EUE 8rd, 2-7/8" seating nippe (2.31" ID), 2 Jts of 2-7/8" EUE 6.5#8rd L-80, 7" Weatherford tbg anchor(35K shear) and 100 stands of 2-7/8" EUE 6.5#8rd L-80. Set in slips. Secured well and SDFN. O • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 41A-08 Moncla 401 50-133-10120-01 194-085 9/19/16 10/12/16 Daily Operations: 09/28/2016-Wednesday Held PJSM, discussed daily ops. MIRU Pollard to run 1/4" control line, PU/MU 2-7/8" chemical inj sub and MU control (t- line to same. Continued TIH with completion banding control line every other joint. PU 7" tbg hanger and connected pc, 1 control to same. MU landing jt and landed hanger weighing 50K up/49K dn. RILDS.J-out of hanger and marked pipe at 40".Turned pipe 8 rounds to the left and set anchor. PU 8K in tension_and anchor slipped up hole. Released anchor and made several attempts to set with no luck. Slacked off 6" below set point and turned pipe 9-1/2 rounds to the left. PU to 4K over and tbg anchor released causing the tbg to back off losing 7K in string weight, called engineer and discussed plan. RU Pollard spooler. BO/LD tbg hanger and TOH w/3,000' of 1/4" control line and 118 stands 2-7/8". 1,700' of completion string left in hole.TOF is a 2-7/8". Pin end looking up. MU/PU 5-3/4" cut lip guide OS,grapple loaded to catch 3-1/8". TIH with same to 7,420'. Established parameters 42K up/41K dn and worked cut lip over.TOF at 7,420'. Latched up and pulled 7K over. Released tbg anchor and racked back 2 stands. Secured well and SDFN. 09/29/2016-Thursday Held PJSM, SITP Opsi, SICP Opsi. BO/LD TIW.TOH on a single with 116 stands of 2-7/8" EUE, BO/LD OS. Continued SOOH and L/D tbg anchor, seating nipple and racked backed 3-1/2" mud jts. Displaced w/40 bbls of PW while tripping. MU/PU 7" test plug and 2-7/8" test jt. Flooded BOP stack and circulated thru BOP's. Lined up valves and performed shell test. 250-3,500psi, good test.Tested BOPE as follows: gas detection, pressure tested annular 250-3,500psi, rams 250-3,500psi,valves 250-3,500psi. Performed Koomey drawdown test. No failures recorded.AOGCC witness waived by Jim Regg. 09/30/2016- Friday PJSM rig time, replaced starter on Moncla's generator. PU/MU 6" bit, 7" csg scraper, sub and XO. TIH with same on 2- 7/8" EUE 6.5 8rd and worked scraper from 9,050'to 9,200' while pumping 3 BPM. No tight spots were encountered. TOH on stands w/ BHA and LD same tallied completion jewlery,TIH with completion as follow: 3-1/2" EUE bull plug, 2 jts of 3-1/2" EUE 9.2#8rd L-80, 3-1/2" slotted sub, XO 3-1/2" x 2-7/8" EUE 8rd, 2-7/8" seating nippel (2.31" ID), 2 jts of 2-7/8" EUE 6.5#8rd L-80, a new 7" Weatherford tbg anchor(35K shear) and 4 stands of 2-7/8" EUE 6.5#8rd L-80. Set anchor and confirmed anchor was functioning. Released anchor and set slips. Secured well and SDFN. 10/01/2016-Saturday Held PJSM, continued TIH with competion string. MIRU Pollard spooler, PU chemical injection sub @ 3,000' and MU 1/4" control line to same. Cont TIH securing control with 3/4" SS bands every other jt. PU/MU 7" tbg hanger and connected control line to same. Landed hanger with PU 50K/SO 49K. RILDS.J-out of hanger and SO 40" turned pipe to the left and set tbg hanger. PU and landed tbg hanger with 18K in tension. Completion depths as follows: 3-1/2" bull plug @ 9,271', 3-1/2" slotted sub @ 9,203', 2-7/8" seat nipple (2.31" ID)@ 9,201', 7" BA tbg anchor @ 9,137', chemical injection sub @ 3,002'. Set BPV and RD Floor. ND BOP stack, NU production tree and tested 5K, good test. Disconnected kill/ck lines and Koomey lines. Prep equipment for rig move. Secured Well and SDFN. 10/02/2016-Sunday RDMO Moncla 401 and associated equipment. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 41A-08 Moncla 401 50-133-10120-01 194-085 9/19/16 10/12/16 Daily Operations: 10/10/2016- Monday PJSM, laid contaiment, spotted beam and MIRU Moncla 401. Raised derrick and secured guide lines. RU floor and rod handling tools. Sorted rods in the order they run in hole. Secured Well and SDFN. 10/11/2016-Tuesday VI- Held PJSM, warmed up equipment. RU rod stripper head, MU memory gauge, 1" x 22' dip tube (2' of perf on bottom), „S 1-3/4" x 36' spayed metal rod pump and bucket tested pump,good test.TIH w/rod string, memory gauge, dip tube, pump, 13 sink bars 1-1/2" rods, 100 3/4" EL sucker rods, 138 7/8" EL sucker rods, 116 1" EL rods and tagged seat nipple. Measured spaceout and LD 2 1" rods. PU/MU 6' and 4' pony rods, stuffing box and polish rod. Secured well and SDFN. 10/12/2016-Wednesday Held PJSM. seated rod pump. Spaced pump out 30' off bottom and landed with rod clamps leaving 158" of polish rod above the Rotaflex slab. MIRU Vac truck pump 15 bbls to fill tbg string. RDMO Vac truck. Stroked rod pump with rig and pressured up on tbg to 750psi, good test. Cleaned and cleared rig floor, RD floor and derrick. RDMO Moncla 401. Well to production. H . ip Soldotna Creek Unit Well: SCU 41A-08 SCHEMATIC Completion Ran: 10-1-2016 flii.,.rp u,i.k.1,1.1,4 PTD: 194-085 API: 50-133-10120-01 RKB=15' A CASING AND TUBING DETAIL II I 1 • L70„ Size WT Grade ID Top Btm 20" Surf 46' B I I 11-3/4" 47# 1-55 11" Surf 2,022' 7" 29# N-80 6.184" Surf 290' 7" 26# N-80 6.276" 290' 1,219' 7" 23# N-80 _ 6.366" 1,219' 4,952' 11-3/4" 7" 26# N-80 6.276" 4,952' 6,617' 2 7" 23# N-80 6.366" 6,617' 8,427' 7" 29# P-110 6.184" 8,427' 9,745' 5" 18# L-80 4.276" 9,457' 10,925' TUBING 2-7/8" 6.5# L-80 2.441" Surf 9,201' 2-3/8" 4.7# N-80 1.995" 9,430' 10,085' C 3 JEWELRY DETAIL Tamil lionew- — 1:'_ No. Depth ID Item o4 1 15' 2.441" Tubing Hanger-1 Latch 4 fr 2 3,004' 2.441" 2-7/8"Chemical lnj Sub w/'A"control line(Live Valve) 3 9,137' 2.441" 7"Weatherford Tubing Anchor(35K Shear) E 4 9,201' 2.315" 2-7/8"Seating Nipple 5 9,203' 2.992" 3.5"Slotted Sub F 5 6 9,271' - 3-1/2"Bull Plug 7 9,401' 2.500" Seating Nipple with cut off 2-7/8"tubing 8 9,406' 2.441" Anchor Separator w/4'pup;2-1/16"U tubing—120' 6 Tag Top @ 9 9,407' 2.441" X-over 2-3/8"pin x 2-7/8"box Ci. 9,304' 10 9,440' 1.995" On/Off Tool 9/26/2016 11 9,446' 1.995" 5"Arrowset 1X Packer cfrxr'''' ,,„ 12 10,084' 1.995" WL Re-entry Guide 7 8 pi ROD DETAIL 9 # Depth Length OD Description A 0 40' 1-1/2" Polished Rod,30'in well(New 5-27-14) 10 B 40' 4' 1" 1"x 4'EL Pony Rod w/1 XL guide per rod At' J, """0"744' 'i +q 44' 6' 1" 1"x 6'EL Pony Rod w/1 XL guide per rod 11 7 50' 2,925' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(New 5-27-14) 12 2,975' 3,450' 7/8" 7/8"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) G-2 6,425' 2,500' 3/4" 3/4"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) H-2 = C 8,925' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) H-3 = D 9,225' 2.75' 1" 1"x 30"Stabilizer Bar w/'/"Pins(between K Bars) H-4 = E 9,228' 43' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump(NEW 10/12/16) H-5 = 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37"RHBC H-6 = F 9,291' 1' 1-1/2" Dip Tube H-7 — H-8 =— H-9 „.....f Tag Fill H-10 10,583' 3/8/13 H-11 = I H-12 — PERFORATION DETAIL ON NEXT PAGE H-13y Lw'� 5" TD=10,930' PBTD=10,835' Max Hole Angle=9.1 deg Downhole Revised 05-27-14 Updated by JEK 11-14-16 • Soldotna Creek Unit Well: SCU 41A-08 . H 0 SCHEMATIC Completion Ran: 10-1-2016 Ilili r,i %l«.L:,.i.I.i. PTD: 194-085 API: 50-133-10120-01 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10,188' 10,192' 10,185' 10,189' 4' 2 10,196' 10,209' 10,193' 10,206' 13' 10,281' 10,297' 10,277' 10,293' 16' H-2 10,283' 10,299' 10,279' 10,295' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,312' 10,328' 10,308' 10,324' 16' 1-11/16"Enerjet,6 spf,90 phase H-3 10,316' 10,332' 10,312' 10,328' 16' 3-1/2"HC,6 spf,60 phase 3/2013 H-4 10,336' 10,344' 10,331' 10,339' 8' 10,338' 10,346' 10,333' 10,341' 8' 3-1/2"HC,6 spf,60 phase 3/2013 10,356' 10,371' 10,351' 10,366' 15' H-5 10,356' 10,382' 10,351' 10,377' 26' 3-1/2"HC,6 spf,60 phase 3/2013 H-6 10,403' 10,407' 10,398' 10,402' 4' 1-11/16"Enerjet,4 spf,0 phase 10,413' 10,432' 10,408' 10,426' 19' 1-11/16"Enerjet,4spf,0 phase H-7 10,414' 10,431' 10,409' 10,425' 17' 3-1/2"HC,6 spf,60 phase 3/2013 10,435' 10,443' 10,429' 10,437' 8' 1-11/16"HC,4 spf,0 phase 10,456' 10,480' 10,450' 10,474' 24' 1-11/16"HC,4 spf,0 phase H-8 10,446' 10,481' 10,440' 10,475' 35' 3-1/2"HC,6 spf,60 phase 3/2013 H-9 10,502' 10,516' _10,496' 10,510' 14' 1-11/16"HC,4 spf,0 phase H-9 10,503' 10,513' 10,497' 10,507' 10' 3-1/2"HC,6 spf,60 phase 3/2013 10,541' 10,564' 10,534' 10,557' 23' 1-1/16"HC,4 spf,0 phase 10,541' 10,568' 10,534' 10,561' 27' 3-1/2"HC,6 spf,60 phase 3/2013 H-10 10,544' 10,564' 10,537' 10,557' 20' 3-1/2"HC,6 spf,60 phase 3/2013 10,564' 10,620' 10,557' 10,613' 50' 1-11/16"Enerjet,6 spf,90 phase 10,617' 10,632' 10,610' 10,625' 15' 1-11/16"Enerjet,2 spf,0 phase H-11 10,674' 10,684' 10,666' 10,676' 10' 1-11/16"Enerjet,10 spf,180 phase H-12 10,709' 10,725' 10,701' 10,717' 16' 1-11/16"Enerjet,2 spf,0 phase H-13 10,764' 10,776' 10,755' 10,767' 12' 1-11/16"Pivot,10 spf,180 phase Downhole Revised 05-27-14 Updated by JEK 11-14-16 " OF T7S • 41)#—\\ 11/7,-4s, � • THE STATE Alaska Oil and Gas • F j of L /� SKA Conservation Commissiont �� 333 West Seventh Avenue *ti , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFA 9 Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager u;pflt4E® SEP.2 9 2016 Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil1 Poo , SCU 41A-08 Permit to Drill Number: 194-085 Sundry Number: 316-450 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, 016Pt-e-c...4>4.-----._ Cathy P.7 . oerster Chair DATED this 7 day of September,2016. RBDMS VzSEP - 8 2016 • • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 3 1 2016 APPLICATION FOR SUNDRY APPROVALS 0 r cif //L 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well E. Operations shutdown El Suspend El Perforate [� I,tl,,,Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Rod Repair/Convert to GL❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ . 194-085 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic IllService ❑ 6.API Number. Anchorage,Alaska 99503 50-133-10120-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 123B Soldotna Creek Unit(SCU)41A-08 Will planned perforations require a spacing exception? Yes ❑ No ❑., 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996- 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): 10,930' • 10,920' - 10,618' 10,611' 1,460 psi N/A 10,618'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 46' 20" 46' 46' Surface 2,022' 11-3/4" 2,022' 2,022' 3,070 psi 1,510 psi Intermediate Production 9,745' 7" 9,745' 9,745' 6,340 psi 3,830 psi Liner 1,468' 5" 10,925' 10,915' 10,140 psi 10,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: 2-7/8" Tubing Grade: 6.4#/L-80 Tubing MD(ft): 9,424 See Attached Schematic See Attached Schematic 2-3/8" 4.7#/N-80 10,085 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Tripoint AS1-X;N/A 9,446'MD;9,446'ND-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: September 19,2016 OIL 0 - WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email jkaiser( hilcora.com Printed Name Chad Helgeson Title Operations Manager ' f Signature Phone 907-777-8405 Date -75 1/ f/ c COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3k• - i5a Plug Integrity ❑ BOPt111Tess � Mechanical Integrity Test ❑ Location Clearance Other: ,‹ -SSW E'c► p ( F 't ze_c,S,,t,{2. r i. 1 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ii Subsequent Form Required: to-- 40 4 RBDMS c;\-- SEP - 8 2016 efi APPROVED BY Approved by: tii /9 ai.Lefr COMMISSIONER —� THE COMMISSION Date:9 �� "/i Ill Submit Form and 0 444tiA4Iid Form 10-403 Revised 11/2015 for 12 months from the date of approval. Attachments in Duplicate • ll • • Well Prognosis Well: SCU 41A-08 Hilcorp Alaska,LLf. Date:8/31/2016 Well Name: SCU 41A-08 API Number: 50-133-10120-01 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: September 14th, 2016 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 194-085 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: —2,500 psi @ 10,400' TVD (BHP Buildup interpretation 6/6/2006) Max. Expected BHP: —2,500 psi @ 10,400' TVD Max. Potential Surface Pressure: —1,460 psi (0.1 psi/ft gas gradient to surface) Brief Well Summary Soldotna Creek Unit 41A-08 was drilled in 1994 as a sidetrack of the original Hemlock injection well SCU 341-08. SCU 41A-08 was initially completed in the lower Hemlock(H10-H13 sands)free flowing at approximately 100 BOPD and low GOR. From 1996—2001, the H4—H10 sands were added to the completion in an effort to blow down gas injected into the Hemlock in SCU 341-08. Significant paraffin deposition throughout the life of the well has led to regular mechanical and solvent(xylene) treatments. In 2001, the H2-H5 sands were added and the well began flowing on gas lift. The Tyonek G-Zone was added in 2007 with no noticeable production contribution.The completion was converted to Rotaflex rod pump in March 2013. As of August 2016, well diagnostics shows that the tubing anchor is loose and pumping at a reduced rate. The purpose of this work/sundry is to utilize the Moncla #401 rig to recomplete this well with a Gas Lift completion. Notes Regarding Wellbore Condition • Surface equipment(Roto-flex unit) disconnected and rolled back. Ready for WO rig. 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 stripper head. 5. LD polish rod and pull EL rods. 6. LD pump and dip tube. a. Inspect and bucket test pump. 7. Set BPV. ND Rod Stripper head and Tree. 8. Notify AOGCC 24hrs in advance to conduct Rig Inspection. 9. NU BOPE. tAivN 10. Test BOPE to 250psi Low 3 500psi High, annular to 250psi Low 4t�� / g , /1,,S00-psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test. b. Notify AOGCC 24 hrs in advance of BOP test. • • Well Prognosis • Well: SCU 41A-08 Hikrorp Alaska,LLC Date:8/31/2016 c. Notification to BLM is not required per email from Amanda Eagle dated 8/30/2016. d. Test VBR rams on 2-7/8" test joint. e. Test VBR rams on 2-3/8" test joint. f. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 11. L/D BOP test equipment. 12. Pump PW down tubing and casing to ensure well is dead. 13. Pull tubing hanger free,tubing and Arrowset packer. a. At the Engineer's discretion and if the tubing packer appears to be intact, the gas lilft completion maybe vacated. In this case, Hilcorp will notify AOGCC.✓ b. If the packer will not pull free and tubing is unanchored. Wireline will RIH and cut tubing at 9,250'and proceed with running a rod pump completion. 14. Pull tubing string (2-7/8" 8RD and 2-3/8"8RD) and rack back tubing. a. Inspect tubing for holes/worn joints. b. Laydown: i. Bad joints ii. Depth Indicator Sub iii. Tubing Anchor Separator assembly iv. Packer 15. RU Slickline 16. RIH with Bailer, collect sample, POOH. RD Slickline 17. If fill cannot be removed with slickline, PU existing 2-3/8" and 2-7/8"tubing (add joints as required for fill cleanout), and a clean out assembly(mill or mule shoe). RIH with cleanout assembly and reverse circulate with PW to remove any fill. POOH. 18. If fill is removed: a MIRU E-line, PT lubricator to 2,500 psi Hi and 250 psi Low. b. RU wireline guns. c. RIH and reperforate the following intervals: Zone Sands Top(MD) Btm (MD) FT Hemlock G-2 ±10,188' ±10,209' 21 Hemlock H-6 ±10,403' ±10407' 4 Hemlock H-10 ±10,564' ±10,632' 68 Hemlock H-11 ±10,674' ±10,584' 10 Hemlock H-12 ±10,709' ±10,725' 16 Hemlock H-13 ±10,764' ±10,776' 12 i. Proposed perfs shown on the proposed schematic in red font. ii. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. . iii. Correlate using Correlation Log provided by Reservior Engineer iv. Use Gamma/CCL/to correlate. v. Install Crystal gauges on well before perforating. Record tubing pressures before and after each perforating run. vi. All perforations in table above are located in the Hemlock Pool based on / Conservation Order No. 123B Rule 5. d. RD E-line. . . • Well Prognosis • Well: SCU 41A-08 IIileoi p Alaska,LLC Date:8/31/2016 19. PU 5" x 2-3/8" hydraulic packer and completion jewelry and RIH w/completion on 2-7/8" EUE 8rdTubing and 2-3/8" 8rd EUE tubing. Use Stainless steel bands to secure 3/8""control line to completion. Minimize excess pipe dope when running completion. Completion jewelry per proposed schematic: a. WL entry guide b. X-nipple (RHCP plug body loaded) c. 5" Packer d. 2-3/8" Chemical Injection Mandrel (loaded with live valve) e. 2-3/8" GLMs(loaded with live valves) f. 2-3/8" x 2-7/8" Crossover g. 2-7/8" GLMs (loaded with live valves) h. 3-1/2" x 2-7/8" Crossover i. 3-1/2"Tubing Hanger 20. Space out packer at 10,118' and set packer a minimum of 5' from a collar. a. Leave tubing tail to land —30' above top of Tyonek G-zone (near 10,158'). 21. Land tubing in hanger. Close the lockdown pins. 22. Drop ball and rod. Ensure rod seats into loaded X-Nipple. 23. Pressure up tubing to 3,000 psi and set packer hydraulic packer. 24. Test tubing at 3,000 psi for 30 min with chart. 25. Test casig to 2,500 psi for 30 min with chart. (If fluid is required to fill annulus, slowly pump 1-2 bpm to ensure the GL orifices do not get washed out. ) 26. Set TWC, ND BOPE, NU tree and test. Pull TWC. 27. RD Moncla#401 WO Rig. 28. RU Slickline. 29. PT Lubricator to 2,500 psig Hi and 250 psig Low for 10 min. 30. RIH and pull RHCP ball and rod and plug in 2-3/8" X-nipple. RD Slickline. 31. Return to production with new surface safety system as previously installed. (Test as per AOGCC regulations.) 32. Replace IA and OA pressure gauge if required (7" x 11-3/4"). Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Blank RWO Procedure Change Form H . • Soldotna Creek Unit Well: SCU 41A-08 . H SCHEMATIC Completion Ran: 03/10/13 IIikorri.164,1.1,1,4, PTD: 194-085 API: 50-133-10120-01 RKB=15' A CASING AND TUBING DETAIL 1 L20 Size WT Grade ID Top Btm 20" Surf 46' B 11-3/4" 47# J-55 11" Surf 2,022' 7" 29# N-80 6.184" Surf 290' 7" 26# N-80 6.276" 290' 1,219' 7" 23# N-80 6.366" 1,219' 4,952' 11-3/4" 7" 26# N-80 6.276" 4,952' 6,617' 2 7" 23# N-80 6.366" 6,617' 8,427' 7" 29# P-110 _ 6.184" 8,427' 9,745' 5" 18# L-80 4.276" 9,457' 10,925' TUBING 2-7/8" 6.5# L-80 2.441" _ Surf 9,401' D 2-3/8" 4.7# N-80 1.995" 9,439' 10,085' D E FJEWELRY DETAIL ;1'1 �Al Z 4 No. Depth ID Item 1 15' Tubing Hanger-1 Latch 2 2,970' 2.441" Chemical Injection Sub 5 3 9,401' 2.500" Seating Nipple 4 9,406' 2.441" Anchor Separator w/4'pup;2-1/16"IJ tubing-120' 6 5 9,407' 2.441" X-over 2-3/8"pin x 2-7/8"box 7...:250 10.- 7 6 9,440' 1.995" On/Off Tool 7 9,446' 1.995" 5"Arrowset 1X Packer 8 10,084' 1.995" WL Re-entry Guide L 7" ROD DETAIL # Depth Length OD Description A 0 40' 1-1/2" Polished Rod,30'in well(New 5-27-14) B 40' 4' 1" 1"x 4'EL Pony Rod w/1 XL guide per rod 44' 2,975' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(New 5-27-14) Drill%" 3,019' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) hole in 6,569' 2,500' 3/4" 3/4"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) collar @ 10,036' xBars(weight bars) C 9,069' 300' 1-1/2" 1-1/2" 25'K i 1 D 9,369' 31' 1" 1"x 30"Stabilizer Bar w/3/4"Pins(between K Bars) E 9,400' 1' Browning On/Off Tool,1-Latch R hand release(Box X Pin) F 9,401' 2.5' 1" 1"x 30"Stabilizer Bar w/3/4"Pins G 9,404' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump(5/27/16) s 8 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37"RHBC H 9,446' 13' 1-1/2" Dip Tube G-2 H-2 H-3 H-4 H-5 H-6 H-7 H-8 H-9 Tag Fill H-10 10,583' 3/8/13 H-11 H-12 PERFORATION DETAIL ON NEXT PAGE H-13 L J. #'�` ---51x4,2t4Rj. 5" TD=10,930' PBTD=10,835' Max Hole Angle=9.1 deg Downhole Revised 05-27-14 Updated by DMA 06-17-16 4110 Soldotna Creek Unit Well: SCU 41A-08 . H • SCHEMATIC Completion Ran: 03/10/13 1144”4-11 v1;14.4.I.I 4 PTD: 194-085 API: 50-133-10120-01 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10,188' 10,192' 10,185' 10,189' 4' 2 10,196' 10,209' 10,193' 10,206' 13' 10,281' 10,297' 10,277' 10,293' 16' H-2 10,283' 10,299' 10,279' 10,295' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,312' 10,328' 10,308' 10,324' 16' 1-11/16"Enerjet,6 spf,90 phase H-3 10,316' 10,332' 10,312' 10,328' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,336' 10,344' 10,331' 10,339' 8' H-4 10,338' 10,346' 10,333' 10,341' 8' 3-1/2"HC,6 spf,60 phase 3/2013 10,356' 10,371' 10,351' 10,366' 15' H-5 10,356' 10,382' 10,351' 10,377' 26' 3-1/2"HC,6 spf,60 phase 3/2013 H-6 10,403' 10,407' 10,398' 10,402' 4' 1-11/16"Enerjet,4 spf,0 phase 10,413' 10,432' 10,408' 10,426' 19' 1-11/16"Enerjet,4spf,0 phase H-7 10,414' 10,431' 10,409' 10,425' 17' 3-1/2"HC,6 spf,60 phase 3/2013 10,435' 10,443' 10,429' 10,437' 8' 1-11/16"HC,4 spf,0 phase 10,456' 10,480' 10,450' 10,474' 24' 1-11/16"HC,4 spf,0 phase H-8 10,446' 10,481' 10,440' 10,475' 35' 3-1/2"HC,6 spf,60 phase 3/2013 H-9 10,502' 10,516' 10,496' 10,510' 14' 1-11/16"HC,4 spf,0 phase H-9 10,503' 10,513' 10,497' 10,507' 10' 3-1/2"HC,6 spf,60 phase 3/2013 10,541' 10,564' 10,534' 10,557' 23' 1-1/16"HC,4 spf,0 phase 10,541' 10,568' 10,534' 10,561' 27' 3-1/2"HC,6 spf,60 phase 3/2013 H-10 10,544' 10,564' 10,537' 10,557' 20' 3-1/2"HC,6 spf,60 phase 3/2013 10,564' 10,620' 10,557' 10,613' 50' 1-11/16"Enerjet,6 spf,90 phase 10,617' 10,632' 10,610' 10,625' 15' 1-11/16"Enerjet,2 spf,0 phase H-11 10,674' 10,684' 10,666' 10,676' 10' 1-11/16"Enerjet,10 spf,180 phase H-12 10,709' 10,725' 10,701' 10,717' 16' 1-11/16"Enerjet,2 spf,0 phase H-13 10,764' 10,776' 10,755' 10,767' 12' 1-11/16"Pivot,10 spf,180 phase Downhole Revised 05-27-14 Updated by DMA 06-17-16 H . • Soldotna Creek Unit Well: SCU 41A-08 . H Proposed Schematic PTD: 194-085 "ikur1i 1in..ka•1.1.1 API: 50-133-10120-01 ii RKB=15' A CASING AND TUBING DETAIL 1 Size WT Grade ID Top Btm 20" 20 Surf 46' 2 in i, 11-3/4" 47# 1-55 11" Surf 2,022' 7" 29# N-80 6.184" Surf 290' 7" 26# N-80 6.276" 290' 1,219' 3 Iili 117" 23# N-80 6.366" 1,219' 4,952' 11-3/4" 7" 26# N-80 6.276" 4,952' 6,617' 4 MK i 7" 23# N-80 6.366" 6,617' 8,427' 7" 29# P-110 6.184" 8,427' 9,745' 111 5" 18# L-80 4.276" 9,457' 10,925' 5 I TUBING 2-7/8" 6.5# L-80 2.441" Surf 9,350' 6 i 2-3/8" 4.7# N-80 1.995" "'9,350' 10,084' II 7 IS i JEWELRY DETAIL 8 , No Depth ID OD Item 1 -19' 2.441" - 3-1/2"Tubing Hanger w/X0 to 2-7/8"8RD g Mli il 2 2,350' 2.441" 4.500" 2-7/8"SF0-1 GLM#9(Live Valve) El 3 -4,250' 2.441" 4.500" 2-7/8"SFO-1 GLM#8(Live Valve) 10 Am 4 "5,700' 2.441" 4.500" 2-7/8"SF0-1 GLM#9(Live Valve) ,1 5 -6,750' 2.441" 4.500" 2-7/8"SF0-1 GLM#8(Live Valve) Li io 6 -7,500' 2.441" 4.500" 2-7/8"SF0-1 GLM#7(Live Valve) 1 P 7 8,000' 2.441" 4.500" 2-7/8"SF0-1 GLM#6(Live Valve) 8 8,500' 2.441" 4.500" 2-7/8"SF0-1 GLM#5(Live Valve) L 7" 9 `9,000' 2.441" 4.500" 2-7/8"SFO-1 GLM#4(Live Valve) 10 -9,350' 1.995" 3.670" X0,2-7/8"8RD x 2-3/8"8RD 11 -9,500' 1.990" 3.350" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 12 i 12 10,051' 1.990" 3.350" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Orifice) 13 10,084 1.990" 3.350" Chemical Injection Mandrel(1/2"control line) I 14 10,118' 2.680" 3.750" 5"x 2-3/8"Hydraulic Packer 15 10,148' 1.875" 3.050" X-Nipple 13 16 -10,158' 1.995" 3.050" WL Entry Guide 1yr I _, 14 ii gi 15 or 16 `.-_:;l_'',/ Port Temp f@ TVD MD Sire Depth TCF PSC PSO PTRO Description G-2 H-2 ' 10 2350 2350 16 98 0.923 1061 1200 1235 IPOR-1 9 4250 4250 16 116 0.890 1036 1137 1205 IPOR-1 H-3 = 8 5700 5700 16 129 0.868 1011 1079 1180 IPOR-1 H-4 = 7 6750 6750 16 143 0.846 986 1030 1145 IPOR-1 H-5 = 6 7500 7500 16 153 0.830 961 984 1115 IPOR-1 H-6 = 5 8000 8000 16 159 0.821 936 959 1085 IPOR-1 H-7 4 8500 8500 16 164 0.814 911 934 1055 IPOR-1 H-8 3 9000 9000 16 167 0.810 886 909 1030 IPOR-1 H-9 2 9500 9500 16 170 0.805 861 889 1010 IPOR-1 H-10 = 1 10050 10051 20 174 0.800 ORIFICE-1 H-11 H-12 H-13 LNW 0 5„ TD=10,930' PBTD=10,835' Max Hole Angle=9.1 deg Downhole Revised 05-27-14 Updated by JEK 08-31-16 . H • • Soldotna Creek Unit Well: SCU 41A-08 Proposed Schematic PTD: 194-085 Hiknrii^'""1'a.1.1,4 API: 50-133-10120-01 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10,188' 10,192' 10,185' 10,189' 4' G-2 10,196' 10,209' 10,193' 10,206' 13' 10,188' 10,209' 10,185' 10,206' 21' 3-1/2"HC,6 spf,60 phase(Proposed) . 10,281' 10,297' 10,277' 10,293' 16' H-2 10,283' 10,299' 10,279' 10,295' 16' 3-1/2"HC,6 spf,60 phase 3/2013 H-3 10,312' 10,328' 10,308' 10,324' 16' 1-11/16"Enerjet,6 spf,90 phase 10,316' 10,332' 10,312' 10,328' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,336' 10,344' 10,331' 10,339' 8' H-4 10,338' 10,346' 10,333' 10,341' 8' 3-1/2"HC,6 spf,60 phase 3/2013 10,356' 10,371' 10,351' 10,366' 15' H-5 10,356' 10,382' 10,351' 10,377' 26' 3-1/2"HC,6 spf,60 phase 3/2013 10,403' 10,407' 10,398' 10,402' 4' 1-11/16"Enerjet,4 spf,0 phase H-6 10,403' 10,407' 10,398' 10,402' 4' 3-1/2"HC,6 spf,60 phase(Proposed) ' 10,413' 10,432' 10,408' 10,426' 19' 1-11/16"Enerjet,4spf,0 phase H-7 10,414' 10,431' 10,409' 10,425' 17' 3-1/2"HC,6 spf,60 phase 3/2013 10,435' 10,443' 10,429' 10,437' 8' 1-11/16"HC,4 spf,0 phase H-8 10,456' 10,480' 10,450' 10,474' 24' 1-11/16"HC,4 spf,0 phase 10,446' 10,481' 10,440' 10,475' 35' 3-1/2"HC,6 spf,60 phase 3/2013 H-9 10,502' 10,516' 10,496' 10,510' 14' 1-11/16"HC,4 spf,0 phase H-9 10,503' 10,513' 10,497' 10,507' 10' 3-1/2"HC,6 spf,60 phase 3/2013 10,541' 10,564' 10,534' 10,557' 23' 1-1/16"HC,4 spf,0 phase 10,541' 10,568' 10,534' 10,561' 27' 3-1/2"HC,6 spf,60 phase 3/2013 H-30 10,544' 10,564' 10,537' 10,557' 20' 3-1/2"HC,6 spf,60 phase 3/2013 10,564' 10,620' 10,557' 10,613' 50' 1-11/16"Enerjet,6 spf,90 phase 10,617' 10,632' 10,610' 10,625' 15' 1-11/16"Enerjet,2 spf,0 phase 10,564' 10,632' 10,557' 10,625' 68' 3-1/2"HC,6 spf,60 phase(Proposed) - 10,674' 10,684' 10,666' 10,676' 10' 1-11/16"Enerjet,10 spf,180 phase H-11 10,674' 10,684' 10,666' 10,676' 10' 3-1/2"HC,6 spf,60 phase(Proposed) 10,709' 10,725' 10,701' 10,717' 16' 1-11/16"Enerjet,2 spf,0 phase • H-12 10,709' 10,725' 10,701' 10,717' 16' 3-1/2"HC,6 spf,60 phase(Proposed) H-13 10,764' 10,776' 10,755' 10,767' 12' 1-11/16"Pivot,10 spf,180 phase 10,764' 10,776' 10,755' 10,767' 12' 3-1/2"HC,6 spf,60 phase(Proposed) Downhole Revised 05-27-14 Updated by JEK 08-31-16 • • s .a „" C4:1) r 5 0 a) L V o ai V Hca c 03 _i O QL V U a Q.a c• a) a .... E 49 Eo rn -(11.C 'a -aE = Q.mr C 3 Q -0 (I) CO• o m N aa)) _0a act.- o0 = L c L ._ a 0_ � — RS a) L N .to M -0 a) d d -2 8) .41' 5Z 0 G aoo CU CI)) CU CD Cr o c 0 Z 0 0 i o • 45 a o u 0 co 0 0 O a cu >cu a4 o = 7 n C C) c N 3 a =0 CU 0 CD 3 � o C .15 aQ O 'a d i ° _a ° d a 3 v a co m _CA �` Hca c C w 2 a) Cl) of O c W 1)3 o co o> �a o 4Oi a C o 0 c. 4 ,�' ° as o c cn 0 3 - Q a Fto - d c _ a) v t ° _` ° N O N>� = a)Z1. 1 ; a E V a) o as ..,CaCO 0- 0- 1.1. 0 ii °aa Z1 a a a a) STATE OF ALASKA AAA OIL AND GAS CONSERVATION COMM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing_I Operations shutdown LI Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well❑ Other: Rod Repair ❑I 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 194-085 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-10120-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028996 Soldotna Creek Unit(SCU)41A-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 10,930 feet Plugs measured N/A RECEIVED true vertical 10,920 feet Junk measured 10,618(fill) feet JUN 1 7 2016 Effective Depth measured 10,618 feet Packer measured 9,446 feet true vertical 10,611 feet true vertical 9,446 feet AOGCC Casing Length Size MD TVD Burst Collapse Structural Conductor 46' 20" 46' 46' Surface 2,022' 11-3/4" 2,022' 2,022' 3,070 psi 1,510 psi Intermediate Production 9,745' 7" 9,745' 9,745' 6,340 psi 3,830 psi Liner 1,468' 5" 10,925' 10,915' 10,140 psi 10,500 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-7/8" 6.4#/L-80 9,424'MD 9,424'ND Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.7#/N-80 10,085'MD 10,083'ND 9,446'MD Packers and SSSV(type,measured and true vertical depth) Tripoint Arrowset 1X 9,446'ND N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): p P� 9 r N/A SCANNED JAN 0 2U1? 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: 80 65 169 200 200 Subsequent to operation: 32 49 78 260 240 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development[] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 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: 316-252 Contact Joe Kaiser-777-8393 Email jkaisert hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature 67(71/71,.../ .._ Phone 907-777-8405 Date 6,/l7fir 6, L1 . ,C Form 10-404 Revised 5/2015 RBDMS IN J(jj,1 L 1 2016 4 `,�',mit Original Only S • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 41A-08 Moncla 401 50-133-10120-01 194-085 5/24/16 5/26/16 Daily Operations: 05/24/2016-Tuesday Held PJSM. Laid containment and spotted beam and MIRU Moncla 401. Sealed in containment. Raised the derrick and RU the floor and split the block. RU floor and tools to pull rods. MIRU blowdown tank and bled off tbg. BO and LD stuffing box and polish rod.TOH w/3 1" rods and the box/coupling was parted between the 3rd and 4th 1" rod. MU 'V TIW valve and secured well. SDFN. P4` 05/25/2016-Wednesday Held PJSM, BO/LD TIW. PU/MU 2-5/16" S-10 OS loaded with 2 spiral grapple.TIH and tagged TOP 90' worked OS and engaged fish. PU to 21K and saw pump stroke. Continued picking up string and over pulled 2K and OS came free.TOH and the barrel on OS was swollen out and left spiral grapple on TOF. Waited on OS from Pollard to arrive. PU/MU 2- 5/16" S-10 OS loaded with 2 spiral grapple.TIH and tagged TOP 90'worked OS and engaged fish. PU to 21K and saw pump stroke. Continued picking up and unseated pump at 5K over string weight. MIRU vac truck and pumped 70bbls of hot water mix with 70 gals of paraffin cutter down tbg.TOH, LD fishing rods and OS. Recovered 1st spiral grapple we ran in the hole. Continued TOH racking back 1", 7/8" and 3/4" rods. LD 12 sinker rods and rod pump. Inspected rods coupling and guides. All good. Picked up a used 1-3/4" rod pump from the SCU 33-33 and TIH w/same. Ran 3/4" and 7/8" rods in the hole. PU/MU polish rod and stuffing box, secured well and SDFN. 05/26/2016-Thursday Held PJSM, discussed daily activities. BO the stuffing box and polish rod. LD same. Continued TIH with rod string. Replaced the first six 1" rods. 3 above and 3 below the parted coupling.Tagged seat nipple, MU stuffing box and seated pump, filled tbg with PW, stroked pump and PT to 900psi, good test. Spaced out pump 36" of bottom. Hung off polish rod 142" from the unit's slab. RDMO Moncla 401 and associated equipment to Moncla yard. Cleaned wellhead and cellar. Skid rota flex unit and hook-up the polish rod. Well to sales. • • Soldotna Creek Unit , H Well: SCU 41A-08 SCHEMATIC Completion Ran: 03/10/13 I I Ir,tr„ %Ie..:,.I I s PTD: 194-085 API: 50-133-10120-01 RKB=15' A CASING AND TUBING DETAIL 1 20" Size WT Grade ID Top Btm 20" Surf 46' B 11-3/4" 47# 1-55 11" Surf 2,022' 7" 29# N-80 6.184" Surf 290' 7" 26# N-80 6.276" 290' 1,219' 7" 23# N-80 6.366" 1,219' 4,952' 11-3/4" 7" 26# N-80 6.276" 4,952' 6,617' 2 ' 7" 23# N-80 6.366" 6,617' 8,427' 7" 29# P-110 6.184" 8,427' 9,745' 5" 18# L-80 4.276" 9,457' 10,925' TUBING 2-7/8" 6.5# L-80 2.441" Surf 9,401' c 2-3/8" 4.7# N-80 1.995" 9,439' 10,085' D E F JEWELRY DETAIL G H x,4 No. Depth ID Item 1 15' Tubing Hanger-1 Latch 2 2,970' 2.441" Chemical Injection Sub 3 9,401' 2.500" Seating Nipple 4 9,406' 2.441" Anchor Separator w/4'pup;2-1/16"I1 tubing–120' 6 5 9,407' 2.441" X-over 2-3/8"pin x 2-7/8"box , ,1"›< 7 6 9,440' 1.995" On/Off Tool 7 9,446' 1.995" 5"Arrowset 1X Packer 8 10,084' 1.995" WL Re-entry Guide „ 7” ROD DETAIL # Depth Length OD Description A 0 40' 1-1/2" Polished Rod,30'in well(New 5-27-14) B 40' 4' 1" 1"x 4'EL Pony Rod w/1 XL guide per rod 44' 2,975' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(New 5-27-14) Drill'A" 3,019' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) hole in 6,569' 2,500' 3/4" 3/4"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) collar @ 10,036' C 9,069' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) D 9,369' 31' 1" 1"x 30"Stabilizer Bar w/%"Pins(between K Bars) E 9,400' 1' Browning On/Off Tool,1-Latch R hand release(Box X Pin) F 9,401' 2.5' 1" 1"x 30"Stabilizer Bar w/3/4"Pins G 9,404' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump(5/27/16) =8 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37"RHBC H 9,446' 13' 1-1/2" Dip Tube G-2 =– H-2 H-2 — H-3 H-4 H-5 — H-6 =— H-7 H-7 — H-8 =– H-9 =– ae................Tag H-9Tag Fill H-10 10,583' 3/8/13 H-11 — H-12 — PERFORATION DETAIL ON NEXT PAGE -1 H-13 — TD=10,930' PBTD=10,835' Max Hole Angle=9.1 deg Downhole Revised 05-27-14 Updated by DMA 06-17-16 • Soldotna Creek Unit r .11 Well: SCU 41A-08 • SCHEMATIC Completion Ran: 03/10/13 nil,mit 1.1,i4:1.I,1.A. PTD: 194-085 API: 50-133-10120-01 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10,188' 10,192' 10,185' 10,189' 4' 2 10,196' 10,209' 10,193' 10,206' 13' 10,281' 10,297' 10,277' 10,293' 16' H-2 10,283' 10,299' 10,279' 10,295' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,312' 10,328' 10,308' 10,324' 16' 1-11/16"Enerjet,6 spf,90 phase H-3 10,316' 10,332' 10,312' 10,328' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,336' _ 10,344' 10,331' 10,339' 8' H-4 10,338' 10,346' 10,333' 10,341' 8' 3-1/2"HC,6 spf,60 phase 3/2013 10,356' 10,371' 10,351' 10,366' 15' H-5 10,356' 10,382' 10,351' 10,377' 26' 3-1/2"HC,6 spf,60 phase 3/2013 H-6 10,403' 10,407' 10,398' 10,402' 4' 1-11/16"Enerjet,4 spf,0 phase 10,413' 10,432' 10,408' 10,426' 19' 1-11/16"Enerjet,4spf,0 phase H-7 10,414' 10,431' 10,409' 10,425' 17' 3-1/2"HC,6 spf,60 phase 3/2013 10,435' 10,443' 10,429' 10,437' 8' 1-11/16"HC,4 spf,0 phase 10,456' 10,480' 10,450' 10,474' 24' 1-11/16"HC,4 spf,0 phase H-8 10,446' 10,481' 10,440' 10,475' 35' 3-1/2"HC,6 spf,60 phase 3/2013 H-9 10,502' 10,516' 10,496' 10,510' 14' 1-11/16"HC,4 spf,0 phase H-9 10,503' 10,513' 10,497' 10,507' 10' 3-1/2"HC,6 spf,60 phase 3/2013 10,541' 10,564' 10,534' 10,557' 23' 1-1/16"HC,4 spf,0 phase 10,541' 10,568' 10,534' 10,561' 27' 3-1/2"HC,6 spf,60 phase 3/2013 H-10 10,544' 10,564' 10,537' 10,557' 20' 3-1/2"HC,6 spf,60 phase 3/2013 10,564' 10,620' 10,557' 10,613' 50' 1-11/16"Enerjet,6 spf,90 phase 10,617' 10,632' 10,610' 10,625' 15' 1-11/16"Enerjet,2 spf,0 phase H-11 _ 10,674' 10,684' 10,666' 10,676' 10' 1-11/16"Enerjet,10 spf,180 phase H-12 10,709' _ 10,725' 10,701' 10,717' 16' 1-11/16"Enerjet,2 spf,0 phase H-13 10,764' 10,776' 10,755' 10,767' 12' 1-11/16"Pivot,10 spf,180 phase Downhole Revised 05-27-14 Updated by DMA 06-17-16 • OF T� • • `' THE STATE Alaska Oil and Gas ofALASKA Conservation Commission 333 West Seventh Avenue ^, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 p Q. • Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager ' Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 41A-08 Permit to Drill Number:}1 y - 0$S )� Sundry Number: 316-252 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, P(494-44CIC Cathy P. F erster Chair DATED this c3 day of May, 2016. RBDMS MAY 0 5 2016 0 • ECEIVED STATE OF ALASKA APR 2 9 "" ALASKA OIL AND GAS CONSERVATION COMMISSION ( 431/1 APPLICATION FOR SUNDRY APPROVALS =-t'd... ,, b 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q . 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 Repair_L 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development ❑✓ . 194-085 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-10120-01 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 1238 Soldotna Creek Unit(SCU)41A-08 - Will planned perforations require a spacing exception? Yes ❑ No El 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996 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): 10,930' - 10,920' - 10,618' 10,611' 1,000 psi N/A 10,618'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 46' 20" 46' 46' Surface 2,022' 11-3/4" 2,022' 2,022' 3,070 psi 1,510 psi Intermediate Production 9,745' 7" 9,745' 9,745' 6,340 psi 3,830 psi Liner 1,468' 5" 10,925' 10,915' 10,140 psi 10,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: 2-7/8" Tubing Grade: 6.4#/L-80 Tubing MD(ft): 9,424 See Attached Schematic See Attached Schematic 2-3/8" 4.7#/N-80 10,085 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Tripoint AS1-X;N/A 9,446'MD;9,446'TVD-N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q '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: May 16,2016 Commencing Operations: OIL 0 ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email jkaiserca hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature �iJ' L,/' Phone 907-777-8405 . Date it ci/7 C' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 1 ^ 2__S Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS L - MAY 0 5 2016 Spacing Exception Required? Yes ❑ No ❑r Subsequent Form Required: /0—yby CtV/.61.7 APPROVED BY Approved by: Crc7 -�_ COMMISSIONER THE COMMISSION Date: 5--3—/ �(� � o —J^/eO Submit Form and Form 10-403 Revised 11/2015j��iiibbb r tr ��(((rs��ii, for 12 m the from the date of approval. Attachments in Duplicate / ...412 ,,i. • • Well Prognosis Well: SCU 41A-08 Ilitron)Alaska,LLC Date:4/29/2016 Well Name: SCU 41A-08 API Number: 50-133-10120-01 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: May 16th, 2016 Rig: Moncla 401 V Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 194-085 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: — 2,500 psi @ 10,400' TVD (BHP Buildup interpretation 6/6/2006) Max. Expected BHP: — 2,500 psi @ 10,400' TVD Max. Potential Surface Pressure: —1,000 psi (Testing surface equipment, step 9) Brief Well Summary Soldotna Creek Unit 41A-08 was drilled in 1994 as a sidetrack of the original Hemlock injection well SCU 341-08. SCU 41A-08 was initially completed in the lower Hemlock (H10-H13 sands)free flowing at approximately 100 BOPD and low GOR. From 1996—2001, the H4—H10 sands were added to the completion in an effort to blow down gas injected into the Hemlock in SCU 341-08. Significant paraffin deposition throughout the life of the well has led to regular mechanical and solvent (xylene) treatments. In 2001, the H2-H5 sands were added and the well began flowing on gas lift. The Tyonek G-Zone was added in 2007 with no noticeable production contribution. The completion was converted to Rotaflex rod pump in March 2013. In April 2016, it is suspected that the rods have parted shallow. The purpose of this work/sundry is to repair parted rods for this Rotaflex Rod Pump well. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump (suspect parted rods). • Rotaflex unit will be uncoupled and motor LOTO prior to Moncla mobilizing. • Tubing tested to 400 psi and no leaks. Workover Rig Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer) on casing. iL 2. MIRU Moncla#401 WO Rig. 3. If required, kill well with 8.4ppg produced water. 4. Nipple up rod stripper head. 5. LD polish rod and pull EL rods.Visually inspect rods while racking them back in basket until parted rod is found. Replace 3 rods above and below rod pact. LD parted rod. 6. PU overshot and RIH. Fish parted rod. Pull remaining rod string with pump. 7. LD and inspect rods, pump and dip tube and all pulled rods. 8. PU existing dip tube and new or rebuilt 1-3/4" rod pump, replace and RIH with existing tapered rod string (sinker bars, 3/4", 7/8" and 1), space out the rods, install polish rod. 9. ND rod stripper, install surface equipment onto well and test pack off to 1,000 psi. 10. RD Moncla#401 WO Rig. 11. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. . . , ll • 0 Well Prognosis Well: SCU 41A-08 Hilcorp Alaska,LLC Date:4/29/2016 12. Return to production with same surface safety system as previously installed. 13. Replace IA x OA pressure gauge if removed (7" x 11-3/4"). Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Blank RWO Procedure Change Form • . ti H . Soldotna Creek Unit Well: SCU 41A-08 ACTUAL SCHEMATIC Completion Ran: 03/10/13 iiiil ,ta, ‘11r-Li.114 PTD: 194-085 API: 50-133-10120-01 RKB=15' A " CASING AND TUBING DETAIL 1L20Size WT Grade ID Top Btm 20" Surf 46' B 11-3/4" 47# J-55 11" Surf 2,022' 7" 29# N-80 6.184" Surf 290' 7" 26# N-80 6.276" 290' 1,219' Suspected 7" 23# N-80 6.366" 1,219' 4,952' Rod Part 11-3/4" 7" 26# N-80 6.276" 4,952' 6,617' 2 7" 23# N-80 6.366" 6,617' 8,427' 7" 29# P-110 6.184" 8,427' 9,745' 5" 18# L-80 4.276" 9,457' 10,925' TUBING 2-7/8" 6.5# L-80 2.441" Surf 9,401' G 2-3/8" 4.7# N-80 1.995" 9,439' 10,085' D E G JEWELRY DETAIL 1;1 i®/ ;®+ 4 No. Depth ID Item 1 15' Tubing Hanger—1 Latch 2 2,970' 2.441" Chemical Injection Sub 5 3 9,401' 2.500" Seating Nipple 4 9,406' 2.441" Anchor Separator w/4'pup;2-1/16"IJ tubing—120' 65 9,407' 2.441" X-over 2-3/8"pin x 2-7/8"box h'®"meq 7 6 9,440' 1.995" On/Off Tool 7 9,446' 1.995" 5"Arrowset 1X Packer 8 10,084' 1.995" WL Re-entry Guide G . .7" ROD DETAIL # Depth Length OD Description A 0 40' 1-1/2" Polished Rod,30'in well(New 5-27-14) B 40' 4' 1" 1"x 4'EL Pony Rod w/1 XL guide per rod 44' 2,975' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(New 5-27-14) Drill'A" 3,019' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) hole in 6,569' 2,500' 3/4" 3/4"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) collar @ 10,036' C 9,069' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) D 9,369' 31' 1" 1"x 30"Stabilizer Bar w/'/<"Pins(between K Bars) E 9,400' 1' Browning On/Off Tool,.1-Latch R hand release(Box X Pin) F 9,401' 2.5' 1" 1"x 30"Stabilizer Bar w/3/4"Pins G 9,404' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump(New Pump 5-27-14) `8 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37"RHBC H 9,446' 13' 1-1/2" Dip Tube G-2 H-2 H-3 H-4 H-5 H-6 H-7 H-8 H-9 Tag Fill H-10 10,583' 3/8/13 H-11 H-12 PERFORATION DETAIL ON NEXT PAGE H-13 Q' T ai ail • .5" TD=10,930' PBTD=10,835' Max Hole Angle=9.1 deg Downhole Revised 05-27-14 Updated by JEK 4-21-16 . . HH . Soldotna Creek Unit Well: SCU 41A-08 ACTUAL SCHEMATIC• Completion Ran: 03/10/13 IIikrnrp 1I1k'.r<:r.11.4 PTD: 194-085 API: 50-133-10120-01 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10,188' 10,192' 10,185' 10,189' 4' 2 10,196' 10,209' 10,193' 10,206' 13' 10,281' 10,297' 10,277' 10,293' 16' H-2 10,283' 10,299' 10,279' 10,295' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,312' 10,328' 10,308' 10,324' 16' 1-11/16"Enerjet,6 spf,90 phase H-3 10,316' 10,332' 10,312' 10,328' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,336' 10,344' 10,331' 10,339' 8' H-4 10,338' 10,346' 10,333' 10,341' 8' 3-1/2"HC,6 spf,60 phase 3/2013 10,356' 10,371' 10,351' 10,366' 15' H-5 10,356' 10,382' 10,351' 10,377' 26' 3-1/2"HC,6 spf,60 phase 3/2013 H-6 10,403' 10,407' 10,398' 10,402' 4' 1-11/16"Enerjet,4 spf,0 phase 10,413' 10,432' 10,408' 10,426' 19' 1-11/16"Enerjet,4spf,0 phase H-7 10,414' 10,431' 10,409' 10,425' 17' 3-1/2"HC,6 spf,60 phase 3/2013 10,435' 10,443' 10,429' 10,437' 8' 1-11/16"HC,4 spf,0 phase 10,456' 10,480' 10,450' 10,474' 24' 1-11/16"HC,4 spf,0 phase H-8 10,446' 10,481' 10,440' 10,475' 35' 3-1/2"HC,6 spf,60 phase 3/2013 H-9 10,502' 10,516' 10,496' 10,510' 14' 1-11/16"HC,4 spf,0 phase H-9 10,503' 10,513' 10,497' 10,507' 10' 3-1/2"HC,6 spf,60 phase 3/2013 10,541' 10,564' 10,534' 10,557' 23' 1-1/16"HC,4 spf,0 phase 10,541' 10,568' 10,534' 10,561' 27' 3-1/2"HC,6 spf,60 phase 3/2013 H-30 10,544' 10,564' 10,537' 10,557' 20' 3-1/2"HC,6 spf,60 phase 3/2013 10,564' 10,620' 10,557' 10,613' 50' 1-11/16"Enerjet,6 spf,90 phase 10,617' 10,632' 10,610' 10,625' 15' 1-11/16"Enerjet,2 spf,0 phase H-11 10,674' 10,684' 10,666' 10,676' 10' 1-11/16"Enerjet,10 spf,180 phase H-12 10,709' 10,725' 10,701' 10,717' 16' 1-11/16"Enerjet,2 spf,0 phase H-13 10,764' 10,776' 10,755' 10,767' 12' 1-11/16"Pivot,10 spf,180 phase Downhole Revised 05-27-14 Updated by JEK 4-21-16 ' , HH . 0 Soldotna Creek Unit Well: SCU 41A-08 PROPOSED SCHEMATIC Completion Ran: 03/10/13 I1ilrnr{i Nla-1.:,.1 I c PTD: 194-085 API: 50-133-10120-01 RKB=15' A CASING AND TUBING DETAIL _1 1 1 20" Size WT Grade ID Top Btm 20" Surf 46' B 11-3/4" 47# J-55 11" Surf 2,022' 7" 29# N-80 6.184" Surf 290' 7" 26# N-80 6.276" 290' 1,219' 7" 23# N-80 6.366" 1,219' 4,952' 11-3/4" 7" 26# N-80 6.276" 4,952' 6,617' 2 ' 7" 23# N-80 6.366" 6,617' 8,427' 7" 29# P-110 6.184" 8,427' 9,745' 5" 18# L-80 4.276" 9,457' 10,925' TUBING 2-7/8" 6.5# L-80 2.441" Surf 9,401' C is ,J 2-3/8" 4.7# N-80 1.995" 9,439' 10,085' D E F JEWELRY DETAIL G H SI 4 No. Depth ID Item 1 15' Tubing Hanger–1 Latch 2 2,970' 2.441" Chemical Injection Sub 5 3 9,401' 2.500" Seating Nipple 4 9,406' 2.441" Anchor Separator w/4'pup;2-1/16"IJ tubing–120' ff6 5 9,407' 2.441" X-over 2-3/8"pin x 2-7/8"box 6 9,440' 1.995" On/Off Tool 7 9,446' 1.995" 5"Arrowset 1X Packer 8 10,084' 1.995" i WL Re-entry Guide G 7" ROD DETAIL # Depth Length OD Description A 0 40' 1-1/2" Polished Rod,30'in well(New 5-27-14) B 40' 4' 1" 1"x 4'EL Pony Rod w/1 XL guide per rod 44' 2,975' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(New 5-27-14) Drill'A" 3,019' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) hole in 6,569' 2,500' 3/4" 3/4"x 25'EL Sucker rods w/ "No"XL guides per rod(Used) collar @ 10,036'----... 0,036' C 9,069' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) D 9,369' 31' 1" 1"x 30"Stabilizer Bar w/%"Pins(between K Bars) E 9,400' 1' Browning On/Off Tool,J-Latch R hand release(Box X Pin) F 9,401' 2.5' 1" 1"x 30"Stabilizer Bar w/3/4"Pins G 9,404' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump(Replace Pump) 8 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37"RHBC H 9,446' 13' 1-1/2" Dip Tube G-2 — H-2 H-3 H-4 H-5 — H-6 H-7 H-8 — H-9 = ihe.............Tag Fill H-1010,583' 3/8/13 H-11 — H-12 — PERFORATION DETAIL ON NEXT PAGE H-13 !..-iiiTZAr.1 .1&017,4* .5„ TD=10,930' PBTD=10,835' Max Hole Angle=9.1 deg Downhole Revised 05-27-14 Updated by JEK 4-21-16 . lit • Soldotna Creek Unit Well: SCU 41A-08 PROPOSED SCHEMATIC Completion Ran: 03/10/13 Ilikurii t;«i.:,.III: PTD: 194-085 API: 50-133-10120-01 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10,188' 10,192' 10,185' 10,189' 4' 2 10,196' 10,209' 10,193' 10,206' 13' 10,281' 10,297' 10,277' 10,293' 16' H-2 10,283' 10,299' 10,279' 10,295' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,312' 10,328' 10,308' 10,324' 16' 1-11/16"Enerjet,6 spf,90 phase H-3 10,316' 10,332' 10,312' 10,328' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,336' 10,344' 10,331' 10,339' 8' H-4 10,338' 10,346' 10,333' 10,341' 8' 3-1/2"HC,6 spf,60 phase 3/2013 10,356' 10,371' 10,351' 10,366' 15' H-5 10,356' 10,382' 10,351' 10,377' 26' 3-1/2"HC,6 spf,60 phase 3/2013 H-6 10,403' 10,407' 10,398' 10,402' 4' 1-11/16"Enerjet,4 spf,0 phase 10,413' 10,432' 10,408' 10,426' 19' 1-11/16"Enerjet,4spf,0 phase H-7 10,414' 10,431' 10,409' 10,425' 17' 3-1/2"HC,6 spf,60 phase 3/2013 10,435' 10,443' 10,429' 10,437' 8' 1-11/16"HC,4 spf,0 phase 10,456' 10,480' 10,450' 10,474' 24' 1-11/16"HC,4 spf,0 phase H-8 10,446' 10,481' 10,440' 10,475' 35' 3-1/2"HC,6 spf,60 phase 3/2013 H-9 10,502' 10,516' 10,496' 10,510' 14' 1-11/16"HC,4 spf,0 phase H-9 10,503' 10,513' 10,497' 10,507' 10' 3-1/2"HC,6 spf,60 phase 3/2013 10,541' 10,564' 10,534' 10,557' 23' 1-1/16"HC,4 spf,0 phase 10,541' 10,568' 10,534' 10,561' 27' 3-1/2"HC,6 spf,60 phase 3/2013 H-10 10,544' 10,564' 10,537' 10,557' 20' 3-1/2"HC,6 spf,60 phase 3/2013 10,564' 10,620' 10,557' 10,613' 50' 1-11/16"Enerjet,6 spf,90 phase 10,617' 10,632' 10,610' 10,625' 15' 1-11/16"Enerjet,2 spf,0 phase H-11 10,674' 10,684' 10,666' 10,676' 10' 1-11/16"Enerjet,10 spf,180 phase H-12 10,709' 10,725' 10,701' 10,717' 16' 1-11/16"Enerjet,2 spf,0 phase H-13 10,764' 10,776' 10,755' 10,767' 12' 1-11/16"Pivot,10 spf,180 phase Downhole Revised 05-27-14 Updated by JEK 4-21-16 0 • V — c d w d > 4.3= to a) v0 3 � C oas v � � a 0) ( o c ca.0U aaa 7 Q `.r E s• E co C -a U c � N co JD E 2 • Q.m C. _ a a) U)55 Y d H aa) to a a op o a t• .—m. Q = a 0_ 0- co 2 co .co M d d co oi 2 a v i Z D co mco rn� Z o C U CC et co w O Uy Z F- O co - o C1 0 -0 n. O a 03> ea a o = CL �' V co a Cl) 3 d asU a) O � O c 415 4. aQ U O " a, d i ° . °a ° aa `° a m Ca ,� as co u1i0 c W U o >ct o L U a ° � O L0a e. 4. Q Ca O CO m Q - C3 as Eo a) aQa I :" '—' O c �' a) C) Q Q' ".� as oa) a y g C.) 0 0 Z1 x ,� EU rn > co a 0_ V �n �n a ° a a g3 U a) 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 re"3: ps...the first page in this file. m ~ ell History File # Digital Data Added to LaserFiche File 0 CD's - # 0 DVD's - # 0 Diskettes - # - DYes o No DYes o No DYes o No Oversized Material Added to LaserFiche File DYes o No DYes o No DYes o No o Maps # o MudLogs#_ o Other # General Notes or Comments about this file. If any of the 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. J C7 '''it'' 71 p �..� sl --ii---i.:--_-5.6-7:14 i (� 3333 dJesi Sevei(rr Avenue ' / C,<)�'4.1?IaitOf2 SEAN Hnchorage Alaska 99501 3572 Mc in 907 279 1 233 Stan PorholaQ Operations Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field/Hemlock Oil Pool, Soldotna Creek Unit 41A-08 Sundry Number: 314-326 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° ;)-(_.-(4V-c--.__ Cathy . Foerster Chair DATED this day of May, 2014. Encl. SCANNED JUL: 1 6 2014 ` RECFIVEL) ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 20, 2014APPLICATION FOR SUNDRY APPROVALS Map 5�m I AO 20 AAC 25.280 G CC 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other:Rod Pump Repair ❑J • 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: • Exploratory ❑ Development Q 194-085 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service El6.API Number: Anchorage,Alaska 99503 50-133-10120-01 - 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)41A-08 • Will planned perforations require a spacing exception? Yes Iii No 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996 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): 10,930' 10,920 1 10,618 10,611 N/A 10,618'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 46' 20" 46' 46' - Surface 2,022' 11-3/4" 2,022' 2,022 3,070 psi 1,510 psi Intermediate Production 9,745' 7" 9,745' 9,745' 6,340 psi 3,830 psi Liner 1,468' 5" 10,925' 10,915 10,140 psi 10,500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: 2-7/8" Tubing Grade: 6.4#/L-80 Tubing MD(ft): 9,424 See Attached Schematic See Attached Schematic 2-3/8" 4.7#IN-80 10,085 Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): Tripoint AS1-X;N/A 9,446'MD;9,446'ND-WA 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch ❑ Exploratory n Stratigraphicn Development n • Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 05/22/14 Oil Q ' Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhda Phone: 907-777-8412 Email soorholaehilcorD.com Printed Name Stan Por 5/90//1 ola Title Operations Engineer Signature /.\-• (10.-k Phone 907-777-8412 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Ski-1-32(0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: 7z. 4/6 i;. �-ttrpc it C/--ot /prr,r',-..-.c_vv0."7 rt.( QhsDe o`• . f Y / (j ✓ Spacing Exception Required? Yes ❑ No Subsequent Form Required: it, —y t,q APPROVED BY Approved by: �.64.7 COMMISSIONER THE COMMISSION Dates 7 511. /11 SSubmit Form and ppLiM'�0-Pre 7g. APrIVVi NaAtmonths from the date of approval. AttachmentsiDu Duplicate • •/ i4► • T 11 Well Prognosis Well: SCU 41A-08 Hilcorp Alaska,LL Date:5/19/2014 Well Name: SCU 41A-08 API Number: 50-133-10120-01 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: May 22"d, 2014 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 194-085 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: —2,500 psi @ 10,400' ND BHP Buildup interpretation 6/6/2006 Maximum Expected BHP: —2,500 psi @ 10,400 ND Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir pressure as measured by static pressure survey run —6-6-2006. Working fluid (gradient of.442 psi/ft)will balance reservoir pressure at 4,744 ft. ND. Brief Well Summary Soldotna Creek Unit 41A-08 was drilled in 1994 as a sidetrack of the original Hemlock injection well SCU 341-08. SCU 41A-08 was initially completed in the lower Hemlock(H10-H13 sands)free flowing at approximately 100 BOPD and low GOR. From 1996—2001,the H4—H10 sands were added to the completion in an effort to blow down gas injected into the Hemlock in SCU 341-08. Significant paraffin deposition throughout the life of the well has led to regular mechanical and solvent(xylene)treatments. In 2001,the H2-H5 sands were added and the well began lifting on gas lift. The Tyonek G-Zone was added in 2007 with no noticeable production contribution.The completion was converted to Rotaflex rod pump in March 2013. The purpose of this work/sundry is to repair parted rods for this Rotaflex Rod Pump well. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump (suspect parted rods). • Tubing tested to 600 psi and no leaks. 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 stripper head. As j" 5. LD polish rod and pull EL rods. Rack back the rods in basket. 6. LD and inspect pump and dip tube and all pulled rods. 7. PU existing dip tube and new 1-3/4" rod pump, replace and RIH with new tapered rod string (sinker bars, 3/4", 7/8" and 1),space out the rods, install polish rod. 8. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 9. RD Moncla#401 WO Rig. 10. Roll up Rotoflex pumping unit, recouple,and remove LOTO on motor. Well Prognosis Well: SCU 41A-08 Hilcorp Alaska,LL Date:5/19/2014 11. Return to production with same surface safety system as previously installed. 12. Replace IA x OA pressure gauge if removed (7"x 11-3/4"). Attachments: 1. Actual Schematic f :. . fi ACTUAL SCHEMATIC Soldotna Creek Unit Well: SCU 41A-08 Completion Ran: 03/10/13 Hil.orp ‘Iii-Li.1.I.4. PTD: 194-085 API: 50-133-10120-01 RKB=15' A CASING AND TUBING DETAIL ..I 1 1 L20„ Size WT Grade ID Top Btm 20" Surf 46' B 11-3/4" 47# J-55 11" Surf 2,022' 7" 29# N-80 6.184" Surf 290' SUSPECTED ROD PART AT+/-2,000' 7" 26# N-80 6.276" 290' 1,219' 7" 23# N-80 6.366" 1,219' 4,952' I 11-3/4" 7" 26# N-80 6.276" 4,952' 6,617' 2 I 7" 23# N-80 6.366" 6,617' 8,427' 7" 29# P-110 6.184" 8,427' 9,745' 5" 18# L-80 4.276" 9,457' 10,925' TUBING 2-7/8" 6.4# L80 EUE 2.441" Surf _ 9,401' C 2-3/8" 4.7# N80 1.995" 9,439' 10,085' D E F JEWELRY DETAIL G PAI;':' si 4 No. Depth ID Item 1 15' _ Tubing Hanger—J Latch 2 2,970' 2.441" Chemical Injection Sub 5 3 9,401' , 2.500" Seating Nipple 4 9,406' 2.441" Anchor Separator w/4'pup;2-1/16"IJ tubing—120' 6 5 9,407' 2.441" X-over 2-3/8"pin x 2-7/8"box �� - "401 4 7 6 9,440' . 1.995" On/Off Tool 7 9,446' 1.995" 5"Arrowset 1X Packer 8 10,084' 1.995" WL Re-entry Guide G ,N.7" ROD DETAIL # Depth Length OD Description A 0 40' 1-1/2" Polished Rod,30'in well B 4' 4' 1" 1"x 4'EL Pony Rod w/1 XL guide per rod 8' 125' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod Drill i" 133' 2,850' 1" 1"x 25'EL Sucker rods w/"No"XL guides per rod hole in 2,974' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ "No"XL guides per rod collar @ 10,036 6,524' 2,500' 3/4" 3/4"x 25'EL Sucker rods w/ "No"XL guides per rod ' C 9,024' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) D 9,324' 31' 1" 1"x 30"Stabilizer Bar w/'/"Pins(between K Bars) E 9,355' 1' Browning On/Off Tool,J-Latch R hand release(Box X Pin) F 9,356' 2.5' 1" 1"x 30"Stabilizer Bar w/3/4"Pins AM 8 G 9,401' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump(Installed 6-04-13) _ 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37"RHBC G-2 H 9,414' 13' 1-1/2" Dip Tube H-2 H-3 H-4 H-5 H-6 H-7 — H-8 — H-9Tag Fill / @ H-10 ` 10,583' 3/8/13 H-11 — H-12 = PERFORATION DETAIL ON NEXT PAGE H-13 =:--- 4 t fi'5„ TD=10,930' PBTD=10,835' Max Hole Angle=9.1 deg Downhole Revised 05-17-14 Updated by STP 05-19-14 ACTUAL SCHEMATIC Soldotna Creek Unit Well: SCU 41A-08 Completion Ran: 03/10/13 *Il orp:r100.6.i.i.0 PTD: 194-085 API: 50-133-10120-01 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 2 10,188' 10,192' 10,185' 10,189' 4' G- 10,196' 10,209' 10,193' 10,206' •13' 10,281' 10,297' _ 10,277' 10,293' 16' H-2 10,283' 10,299' 10,279' 10,295' _ 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,312' 10,328' _ 10,308' 10,324' 16' 1-11/16"Enerjet,6 spf,90 phase H-3 10,316' 10,332' 10,312' 10,328' 16' 3-1/2"HC,6 spf,60 phase 3/2013 10,336' 10,344' _ 10,331' 10,339' 8' H-4 10,338' 10,346' 10,333' 10,341' 8' 3-1/2"HC,6 spf,60 phase 3/2013 10,356' 10,371' 10,351' 10,366' 15' H-5 10,356' 10,382' _ 10,351' 10,377' 26' 3-1/2"HC,6 spf,60 phase 3/2013 H-6 10,403' 10,407' 10,398' 10,402' 4' 1-11/16"Enerjet,4 spf,0 phase 10,413' 10,432' 10,408' 10,426' 19' 1-11/16"Enerjet,4spf,0 phase H-7 10,414' 10,431' _ 10,409' 10,425' 17' 3-1/2"HC,6 spf,60 phase 3/2013 10,435' 10,443' 10,429' 10,437' 8' 1-11/16"HC,4 spf,0 phase 10,456' 10,480' 10,450' 10,474' 24' 1-11/16"HC,4 spf,0 phase H-8 10,446' 10,481' 10,440' 10,475' 35' 3-1/2"HC,6 spf,60 phase 3/2013 H-9 10,502' 10,516' 10,496' 10,510' 14' 1-11/16"HC,4 spf,0 phase H-9 10,503' 10,513' 10,497' 10,507' 10' 3-1/2"HC,6 spf,60 phase 3/2013 10,541' 10,564' 10,534' 10,557' 23' 1-1/16"HC,4 spf,0 phase 10,541' 10,568' 10,534' 10,561' 27' 3-1/2"HC,6 spf,60 phase 3/2013 H-10 10,544' 10,564' 10,537' 10,557' 20' 3-1/2"HC,6 spf,60 phase 3/2013 10,564' 10,620' 10,557' 10,613' 50' 1-11/16"Enerjet,6 spf,90 phase 10,617' 10,632' 10,610' 10,625' 15' 1-11/16"Enerjet,2 spf,0 phase H-11 10,674' 10,684' 10,666' 10,676' 10' 1-11/16"Enerjet,10 spf,180 phase H-12 10,709' 10,725' 10,701' 10,717' 16' 1-11/16"Enerjet,2 spf,0 phase H-13 10,764' 10,776' 10,755' 10,767' 12' 1-11/16"Pivot,10 spf,180 phase Downhole Revised 05-17-14 Updated by STP 05-19-14 Davies, Stephen F (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Wednesday, May 21, 2014 12:45 PM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L(DOA); Ferguson, Victoria L(DOA); Bettis, Patricia K (DOA) Subject: RE: Rush Sundry Applications for SCU 41A-08 (194-085) and SCU 12A-04 (174-021) - Explanations Needed Steve, The urgency on the sundries for SCU 41A-08 (194-095)and SCU 12A-04 (174-021) was based on recent Rod Failures of these wells and the anticipated availability of a workover rig to pull the rods from these wells. We have since seen a delay in the availability of the rig and anticipate the workover rig to be available on Friday, May 23rd at the earliest. It was anticipated that these sundries would have short reviews due to the nature of the work(pulling/running sucker rods). Guy Schwartz said he is looking into requests such as these not requiring sundry approval in the future.The 7 rod pump wells at Swanson River create a unique aspect where when we have failed rods,we can move onto these wells quickly if the workover rig is available, as opposed to other operations. We are continuing to strive to get scopes of work out as soon as possible, anticipating future needs such as when a well is perforated and comes back non-productive. In this case, our sundry applications will anticipate this step and address future work in the original sundry, thus reducing the short turnaround or verbal approval requests being made from our office. Stan From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, May 21, 2014 12:27 PM To: Stan Porhola Cc: Schwartz, Guy L(DOA); Ferguson, Victoria L(DOA); Bettis, Patricia K (DOA) Subject: Rush Sundry Applications for SCU 41A-08 (194-085) and SCU 12A-04 (174-021) - Explanations Needed Stan, At noon today, May 21st, I received two Applications for Sundry Approvals for SCU 41A-08 (194-095) and SCU 12A-04 (174-021) with "Rush" notes attached to them. The estimated dates for commencing the requested operations are May 22nd and May 24th, respectively. There is no explanation of why urgency is needed. For these two Sundry Applications, please explain in detail what led to the need for short notice. I'll hold these two applications until the requested explanations arrive via email. I'm going to repeat the text of an email sent last week by Guy Schwartz to Daniel Taylor, with minor modifications: AOGCC's guidelines, below, were published in last month's AADE bulletin. Please adhere to this standard. Submitting sundries 3-4 days before work is expected to start is not acceptable. Verbal Approvals for Sundries: 1 Verbal approvals should be rare. In order for the Commission to properly vet the incoming sundries two weeks of notice are required. When well work does come up unexpectedly and there is no way to avoid requesting verbal approval the following steps should be taken: 1) Call the staff AOGCC engineer that will be handling the request and explain the situation. 2) Follow up with an email requesting verbal approval with an outline of the scope of work and steps to be taken for the required well work. Include as much detail as possible. (always include the well name and permit to drill number in the email subject line!!!) 3) The email must include information outlining the reason that the sundry request is verbal. Explain in detail what led to the need for short notice such as unexpected pressures, last minute rig changes, ESP failure, etc. 4) Post the email authorizing the verbal approval on the well site. 5) Submit a 10-403 as soon as possible. Include a copy of the verbal approval email in the sundry application. Please let me know if you have any questions. • Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@@alaska.sov. 2 Eli/ . STATE OF ALASKA y ALA.OIL AND GAS CONSERVATION COMMON JUL 12 2013 • REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon [J Repair Well 11 Plug Perforations Li Perforate LJ Other U Rod Pump Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac Li Waiver❑ Time Extension❑ Replacement 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 GI ' Exploratory ❑ 194-085 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-10120-01 7.Property Designation(Lease Number): 8.Well Name and Number: / Soldotna Creek Unit(SCU)41A-08 ,I/ 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 10,930 feet • Plugs measured N/A feet true vertical 10,920 feet Junk measured 10,618(fill) feet Effective Depth measured 10,618 feet Packer measured 9,446 feet true vertical 10,611 feet true vertical 9,446 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 46' 20" 46' 46' Surface 2,022' 11-3/4" 2,022' 2,022' 3,070 psi 1,510 psi Intermediate Production 9,745' 7" 9,745' 9,745' 6,340 psi 3,830 psi Liner 1,468' 5" 10,925' 10,915' 10,140 psi 10,500 psi Perforation depth Measured depth No Changes SCANNED SCANNED True Vertical depth No Changes 2-7/8" 6.4#/L-80 9,424'MD 9,424'ND Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.7#/N-80 10,085'MD 10,083'ND 9,446'MD Packers and SSSV(type,measured and true vertical depth) Tripoint Arrowset lX 9,446'ND 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 56 95 60 190 Subsequent to operation: 234 48 56 200 200 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development IS, Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0, t 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: 313-277 Contact Chad Helgeson Email chelcieson(p�hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature Phone 907-777-8405 Date 741 J3 St OZ C z lnr smog 74743 � Submit Original Only Form 10-404 Revised 10/2012 (r� • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 41A-08 50-133-10120-01 194-085 6/4/13 6/4/13 Daily Operations: 06/04/2013-Tuesday RD Pumping unit and skidded back. MIRU WOR. PU on rods and unseated pump. Pumped 50 bbls of produced water down tbg to clean rods before pulling. TOOH w/rods and L/D pump. MIRU SL,RIH w/2"Drive Down Bailer to 9,300'. POOH. Fluid level was at 4,260'wlm. Lost bailer bottom in hole. PU a 2"LIB and tag at 9,375'wlm. POOH. LIB showed top of bailer bottom. TIH w/2"spear and tag at 9,375'wlm. POOH w/the bailer bottom. PU new 1.75"ROS pump and TIH w/rods. Seated pump and spaced out pump 10"off bottom. RDMO WOR. SDFN. OF T y e , • y w '\� \ \ I % s, THE STATE Alaska Oil and Gas OfA _ ASKA t reP I AIW- - Conservation Commission I GOVERNOR SEAN PARNELL 333 West Seventh Avenue *,o ALAS'' Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Stan Perhola SCANNED JUN 2D13 Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 �Q Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 41A -08 Sundry Number: 313 -277 Dear Mr. Perhola: 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, Daniel T. Seamount, Jr. Commissioner DATED this day of June, 2013. Encl. II I 4 ,( b .i U n. r 0, e:: a -- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 .-0,.,)I ; '' / ,_ ` 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Wel ] Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull TubinL Time Extension ❑ Operations Shutdoww ❑ Re -enter Susp. Wel ❑ Stimulate ❑ Alter CasinL Other Rod Pump Replacement ID • 2. Operator Name: r. Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number Exploratory ❑ Development in 194 -085. 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number Anchorage, Alaska 99503 50-133-10120-01 7. If perforating: 8. Well Name end Number. What Regulation or Conservation Order governs well spacing in this pool? Soldotna Creek Unit (SCU) 41A -08 • Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028996 Swanson River Field / Hemlock Oil . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10,930 ' 10,920 10,618 10,611 WA 10,618' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 46' 20" 46' 46' Surface 2,022' 11 -3/4" 2,022' 2,022' 3,070 psi 1,510 psi Intermediate Production 9,745' 7" 9,745' 9,745 6,340 psi 3,830 psi Liner 1,468' 5" 10,925' 10,915 10,140 psi 10,500 psi Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: 2 -7/8" Tubing Grade: 6.4# / L-80 Tubing MD (ft): 9,424 See Attached Schematic See Attached Schematic 2 -3/8" 4.7# / N-80 10,085 Packers and SSSV Type: Packers and SSSV MD (t) and ND (ft): Tripoint Arrowset •X Pkr - N/A 9,446' MD: 9,446' ND - N/A 12. Attachments: Description Summary of Proposal 151 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphitfl Development 171 Service [1 14. Estimated Date for 15. Well Status after proposed work: 06/04/13 Commencing Operations: Oil ig - 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 Porhda Phone: 907 - 777-8412 Email sporhola@hiicorp.com Printed Name Stan Porhola Title Operations Engineer 2p Signature jw∎ b1(„ / Phone 907 - 777-8412 Date ( // 3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number Plug Integrity ❑ BOP Test Q Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS JUN 11 20 Spacing Exception Required? Yes ❑ No 121 Subsequent Form Required: to — if 4 11 APPROVED BY /0 // Approved by: % COMMISSIONER THE COMMISSION Date:/ ///�� l • 7./3 Submit Form and ' Form 10-403 (Revised 10/2012) AppO Rl#i V V l fjliJ12 months from the date of ap j oval. Attachments n icate / t -j• t 7 v'` /x� ,; • • Well Prognosis Well: SCU 41A -08 Hilcorp Alaska, LLC Date: 6/03/2013 Well Name: SCU 41A -08 API Number: 50- 133 - 10120 -01 Current Status: Producing Oil Well Leg: N/A Estimated Start Date: June 4, 2013 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 194 -085 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: < 2,500 psi @ 10,400' TVD BHP Buildup interpretation 6/6/2006 Maximum Expected BHP: — 2,500 psi @ 10,400 TVD Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir pressure as measured by static pressure survey run —6 -6 -2006. Working fluid (gradient of .442 psi /ft) will balance reservoir pressure at 4,744 ft. TVD. Brief Well Summary Soldotna Creek Unit 41A -08 was drilled in 1994 as a sidetrack of the original Hemlock injection well SCU 341 -08. SCU 41A -08 was initially completed in the lower Hemlock (H10 -H13 sands) free flowing at approximately 100 BOPD and low GOR. From 1996 — 2001, the H4 — H10 sands were added to the completion in an effort to blow down gas injected into the Hemlock in SCU 341 -08. Significant paraffin deposition throughout the life of the well has led to regular mechanical and solvent (xylene) treatments. In 2001, the H2 -H5 sands were added and the well began lifting on gas lift. The Tyonek G -Zone was added in 2007 with no noticeable production contribution.'/ 4 •z-<3 Notes Regarding Wellbore Condition o n ,v �`�`"�'j zit) f' 313- 0� 3 • Travelling valve appears to be stuck or possible pump damage, based on Dyno testing. Tubing tested to • 2,000 psi and no leaks. OBJECTIVE OF WORKOVER Replace downhole rod pump. Rig 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 Williams 405 WO Rig 4. Nipple up rod stripper head. " 5. LD polish rod and pull EL rods. (rack back the rods in basket) 6. LD pump, investigate pump damage. • • Well Prognosis Well: SCU 41A -08 Hilcorp Alaska, LLC Date: 6/03/2013 7. PU new 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, land the pump, space out the rods, install polish rod. 8. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 9. RD Williams #405. 10. Roll up Rotoflex pumping unit, recouple, install new belt, and remove LOTO on motor. 11. Return to production with same surface safety system as previously installed. _ n J(! o Fib /'L Attachments: (� 1. As -built Schematic H • • Soldotna Creek Unit Well: SCU 41A -08 SCHEMATIC Completion Date: 03/10/13 !blimp • Ia-aa.1,1.u. PTD: 194 -085 A API: 50- 133 - 10120 -01 RKB = 15' CASING AND TUBING DETAIL 1 L20" Size WT Grade ID Top Btm 20" Surf 46' B 11 -3/4" 47# 1 -55 11" Surf 2,022' 7" 29# N -80 6.184" Surf 290' 7" 26# N -80 6.276" 290' 1,219' 7" 23# N -80 6.366" 1,219' 4,952' 11 -3/4" 7" 26# N -80 6.276" 4,952' 6,617' 2 7" 23# N -80 6.366" 6,617' 8,427' 7" 29# P -110 6.184" 8,427' 9,745' 5" 18# L -80 4.276" 9,457' 10,925' TUBING 2 -7/8" 6.4# L80 EUE 2.441" Surf 9,401' C i 2 -3/8" 4.7# N80 1.995" 9,439' 10,085' D E JEWELRY DETAIL G 90 4 No. Depth ID Item ilk A 1 15' Tubing Hanger -1 Latch 2 2,970' 2,441" Chemical Injection Sub 5 3 9,401' 2.5" Seating Nipple 4 9,406' 2.441" Anchor Separator w/ 4' pup; 2- 1/16" IJ tubing - 120' Fy 6 `<; 5 9,407' 2.441" X -over 2 -3/8" pin x 2 -7/8" box - 0,7"-A . -"„ 7 6 9,440' 1.995" On /Off Tool 7 9,446' 1.995" 5" Arrowset 1X Packer 8 10,084' 1.995" WL Re -entry Guide 7" ROD DETAIL # Depth Length OD Description A 0 40' 1 -1/2" Polished Rod, 30' in well B 4' 4' 1" 1" x 4' EL Pony Rod w/ 1 XL guide per rod 8' 125' 1" 1" x 25' EL Sucker rods w/ 4 XL guides per rod Drill %" 133' 2,850' 1" 1" x 25' EL Sucker rods w/ "No" XL guides per rod hole in 2,974' 3,550' 7/8" 7/8" x 25' EL Sucker rods w/ "No" XL guides per rod collar @ 6,524' 2,500' 3/4" 3/4" x 25' EL Sucker rods w/ "No" XL guides per rod 10,036' C 9,024' 300' 1 -1/2" 1 -1/2" x 25' K Bars (weight bars) D 9,324' 31' 1" 1" x 30" Stabilizer Bar w/ 3/4" Pins (between K Bars) E 9,355' 1' Browning On /Off Tool, 1-Latch R hand release (Box X Pin) F 9,356' 2.5' 1" 1" x 30" Stabilizer Bar w/3/4" Pins 8 G 9,401' 42' 1 -3/4" 1 -3/4" x 42' Insert Pump, RHBC Pump #3332 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 H 9,414' 13' 1 -1/2" Dip Tube H -2 H -3 H -4 H -5 H -6 H -7 H -8 H -9 -- Tag Fill H -10 10,583' 3/8/13 H -11 H - 12 = PERFORATION DETAIL ON NEXT PAGE H -13 L.. : 1 *, *et 5" TD = 10,930' PBTD = 10,835' Max Hole Angle = 9.1 deg Updated by DMA 05 -10 -13 • Soldotna Creek Unit n 0 Well: SCU 41A -08 SCHEMATIC Completion Date: 03/10/13 :Brake 1la.aa. i14: PTD: 194 -085 A API: 50- 133 - 10120 -01 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments 10,188' 10,192' 10,185' 10,189' 4' G-2 10,196' 10,209' 10,193' 10,206' 13' 10,281' 10,297' 10,277' 10,293' 16' H-2 10,283' 10,299' 10,279' 10,295' 16' 3 -1/2" HC, 6 spf, 60 phase 3/2013 10,312' 10,328' 10,308' 10,324' 16' 1- 11/16" Enerjet, 6 spf, 90 phase H -3 10,316' 10,332' 10,312' 10,328' 16' 3 -1/2" HC, 6 spf, 60 phase 3/2013 10,336' 10,344' 10,331' 10,339' 8' H-4 10,338' 10,346' 10,333' 10,341' 8' 3 -1/2" HC, 6 spf, 60 phase 3/2013 10,356' 10,371' 10,351' 10,366' 15' H-5 10,356' 10,382' 10,351' 10,377' 26' 3 -1/2" HC, 6 spf, 60 phase 3/2013 H -6 10,403' 10,407' 10,398' 10,402' 4' 1- 11/16" Enerjet, 4 spf, 0 phase 10,413' 10,432' 10,408' 10,426' 19' 1- 11/16" Enerjet, 4spf, 0 phase H -7 10,414' 10,431' 10,409' 10,425' 17' 3 -1/2" HC, 6 spf, 60 phase 3/2013 10,435' 10,443' 10,429' 10,437' 8' 1- 11/16" HC, 4 spf, 0 phase 10,456' 10,480' 10,450' 10,474' 24' 1- 11/16" HC, 4 spf, 0 phase H-8 10,446' 10,481' 10,440' 10,475' 35' 3 -1/2" HC, 6 spf, 60 phase 3/2013 H -9 10,502' 10,516' 10,496' 10,510' 14' 1- 11/16" HC, 4 spf, 0 phase H -9 10,503' 10,513' 10,497' 10,507' 10' 3 -1/2" HC, 6 spf, 60 phase 3/2013 10,541' 10,564' 10,534' 10,557' 23' 1- 1/16" HC, 4 spf, 0 phase 10,541' 10,568' 10,534' 10,561' 27' 3 -1/2" HC, 6 spf, 60 phase 3/2013 H -10 10,544' 10,564' 10,537' 10,557' 20' 3 -1/2" HC, 6 spf, 60 phase 3/2013 10,564' 10,620' 10,557' 10,613' 50' 1- 11/16" Enerjet, 6 spf, 90 phase 10,617' 10,632' 10,610' 10,625' 15' 1- 11/16" Enerjet, 2 spf, 0 phase H -11 10,674' 10,684' 10,666' 10,676' 10' 1- 11/16" Enerjet, 10 spf, 180 phase H -12 10,709' 10,725' 10,701' 10,717' 16' 1- 11/16" Enerjet, 2 spf, 0 phase H -13 10,764' 10,776' 10,755' 10,767' 12' 1- 11/16" Pivot, 10 spf, 180 phase Updated by DMA 05 -10 -13 • RECEiVFD STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMM ION . � I 0 201',' REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon LJ Repair Well L] Plug Perforations L] Perforate U • Other [ j Install Rod Pump • Performed: Alter Casing ❑ Pull Tubing El • 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: Hilcorp Alaska, LLC • Name: Development Exploratory ❑ • 194 -085 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: M Anchorage, Alaska 99504 50- 133 - 10120 -01 7. Property Designation (Lease Number): 8. Well Name and Number: Soldotna Creek Unit (SCU) 41A -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 10,930 feet ' Plugs measured N/A feet true vertical 10,920 feet Junk measured 10,618 (fill) feet Effective Depth measured 10,618 feet Packer measured 9,446 feet true vertical 10,611 feet true vertical 9,446 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 46' 20" 46' 46' Surface 2,022' 11 -3/4" 2,022' 2,022' 3,070 psi 1,510 psi Intermediate Production 9,745' 7" 9,745' 9,745' 6,340 psi 3,830 psi Liner 1,468' 5" 10,925' � 10,915' 10,1 psi 10,500 psi 10,p1 Perforation depth Measured depth See Attached Schematic N� MA + � 1 4 2 U i True Vertical depth See Attached Schematic 2 -7/8" 6.4# / L -80 9,424' MD 9,424' TVD Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.7# / N -80 10,085' MD 10,083' TVD 9,446' MD Packers and SSSV (type, measured and true vertical depth) Tripoint Arrowset 1X 9,446' TVD 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: 20 10 40 800 200 Subsequent to operation: 276 163 69 200 180 14. Attachments: 15. Well Class after work: • Copies of Logs and Surveys Run N/A Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 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: 313 -093 Contact Chad Helgeson Email chelgeson(a)hilcoro.com Printed Name /�J� Chad Helgeson Title Operations Manager Signature el- �% //� Phone 907-777 -8405 Date 57/0113 RBDMS MAY 10 2013' S --- /` 03 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 41A -08 50- 133 - 10120 -01 194 -085 2/27/13 3/12/13 Daily Operations: 02/28/2013 - Thursday Pollard Slickline Unit, RIH W/ 1.75 gauge ring to 10,554' wlm, Tagged bottom, POOH. RBIH W/ PX Plug body, sat down @ 9,246' wlm, tried to work down, could not get down. POOH. RIH W/ 1.85" GR to 10,114' (EOT). POOH. RIH W/ 2" PX Plug body, could not get any deeper than 9,246'. POOH. RIH W/ 2.3 B/L Brush, sat down @ 9,256', worked down to 9,457', could not get any deeper. POOH. Added 5' stem and RBIH, tagged @ 9,483', worked tools down to 10,114' had to make multiple • runs to brush tbg clean from 9,483' to 10,014', brushed sliding sleeve and nipple until tools would fall freely thru them. POOH. RIH W/ 2" PX Plug body, set in nipple at 10,055' wlm, POOH. RBIH W/ 2" JDC w/ equilizer prong, set prong in plug body @ 10,051', POOH. RBIH W/ 2" BO shifting tool, stung sleeve @ 9,856', jarred up on XA Sleeve, Tbg pressure dropped from 780 psi - 500 psi. POOH. Checked tools to ensure pin was good. RDMO Pollard slickline unit. 03/01/2013 - Friday Started MIRU of Williams 405 Work -over Rig, MIRU WOR, set up winterization kit on rig, MIRU manifolds, pits and pump, installed winterization kit over equipment. Circulated 450 BBIs of produced saltwatwer down tbg and out casing. Tested casing to 2,000 psi, charted good test for 30 mins. MIRU Pollard Slickline Unit, RIH W/ 2" JDC to 10,077', latched prong, Picked up on prong and well went on vac, started out of hole and pulled up to 9,846' wlm, Tools hung up, pulled up to 1,800 #, tried jarring up on tools, no movement, attempted to jar tools back down, no movement. Tried to pump tools up and down hole, no movement. After beating down on tools for 30 mins, they started moving down hole. Beat tools down hole to 9,925' wlm, dropped 5' X 1.25" cutter bar, cut wire and POOH w/ remaining wire. RDMO Pollard slickline Unit. 03/02/2013 - Saturday Installed BPV in wellhead, ND Wellhead and NU BOP's, tested Bop's to 250 low and 3,000 High, charted for 10 mins on each test. (Witness waived by Jim Regg AOGCC 2/28/13) Tested annular preventor to 250 low and 1500 psi on high. Finished rigging up winterization kit, lay down machine and made ready to start pulling tbg out of hole. 03/03/2013 - Sunday Discussed pulling limits on old tbg in hole. MU landing joint in tbg hanger, PU to 79,000# on landing joint and hanger pulled out easy, never saw any change with seal assembly coming free, TOH laying down 2 -7/8" IBT Tbg and 2 -3/8" IBT Tbg, laid down seal assembly and moved in new 2 -3/8" / 2 -7/8" Production string, racked and tallied Tbg. MU 4 -1/8" Burn shoe, 2 boot baskets, bumper jar, oil jar, and 6 drill collars, Started TIH on 2 -3/8" production tbg, total of 29 joints of 2 -3/8 ", Continue TIH w/ 2 -7/8 ", total of 96 joints. 03/04/2013 - Monday Continued TIH W/ Burn shoe, tagged top of packer @ 10,025', burned over packer for 8 hrs, made just over 2' and quit making hole, believe shoe to be worn out, SOOH W/ 2 -7/8" WS, Stood out with total of 131 stands. 03/05/2013 - Tuesday Finished SOH W/ worn burn shoe, MU New Burn shoe, TBIH, tagged packer 10,027', burned on packer for 45 mins and fell through, continued pushing packer down til it stopped at 10,406'. RD Power swivel, SOOH W/ 2 -7/8" WS and burn shoe, MU 4' spear with 2.5" grapple, TIH, tagged top of packer @ 10,406', drove spear down 4' and engaged grapple inside packer, Started SOH, showed drag for first few casing collars. Continued SOON W/ 2 -7/8" WS, SO total of 149 stands. 03/06/2013 - Wednesday Continued SOOH W/ spear loaded W/ 2.5" grapple, LD grapple, grapple was full of sand and metal debris. MU 3 -1/8" • Overshot loaded W/ 3" spiral grapple, TIH, Tagged top of fish, pushed fish down hole 72 ft, landed @ 10,436 ft, attempted to engage fish with grapple, no success. SOOH W/ 2 -7/8" WS, LD Overshot, cut lip guide marked up and first 3 inches of inside of guide marked up. Fish never entered grapple. MIRU Pollard Slickline, RIH W/ 3.80" swedge, and 3.5" Magnet, tagged top of liner @ 9,431' wlm, POOH, recovered 2 cups of metal shavings and debris. Made same run 2 more times recovering same debris each run. RIH W/ 5 -1/2" centralizer, and 4.5" Magnet, tagged top of liner @ 9,431" wlm, POOH, recovered 2 cups of metal shavings and debris. RBIH W/ 1.80" swedge, tagged TOF @ 10,486', POOH, RBIH W/ Bow flex and 3" LIB, Tagged TOF @ 10,486', POOH, had 2 marks on opposite side in circular pattern. RBIH W/ Bow Flex and 3.5" Magnet, tagged top of liner @ 9,431" wlm, POOH, recovered very little metal shavings. RBIH W/ 3.80" Swedge, Tagged TOF several times @ 10,486', POOH. No marks. RBIH W/ 3.80" Swedge W/ 4' X 1 -3/4" drive down bailer, Tagged fish @ 10,493', stroked bailer 2 times down to 10,500'. Bailer 1/3 full of sand, Swedge showed 3" circle. RDMO Pollard Slickline Unit. MU Tappered Tap on 2 -7/8" WS, Started TIH, Total of 43 Stands in hole. 03/07/2013 - Thursday • • Continued TIH W/ tappered Tap, Tagged top of fish @ 10,468', MU Power swivel, turned tap down into top of fish and pushed down to 10,500 ft. PU 25k # over string weight and fish started moving up hole, fish dragging 10 -14k # over string weight. PU to around 9,500 ft and weight come up to 82k #, tried to work thru tight spot and dropped fish. Chased fish back to bottom and attempted to make tap back up in fish, could not get it to stay in fish, would pull of with 12k # over pull off bottom, SOOH W/ 2 -7/8" WS and LD Tappered Tap, MU 8' spear loaded with 2.56" grapple, TIH and engaged top of fish @ 10,500', PU to 68k # and set jars off several times, parted tbg 20 ft below surface, MU 5 -3/4" overshot loaded W/ 2 -7/8" collar catch grapple. TIH on 2 jts of 2 -7/8" WS, engaged tbg collar 40 ft below surface, Worked tools @ 20K # over string - weight, jarred 10 times and both fish began to move up hole, LD overshot after first stand and continued LD 2 -7/8" Tbg, LD total of 29 joints of 2 -7/8" WS, continued SOH, stood out with total of 84 stands, Fish continued to drag until entering the 7" casing, had to work thru tight spot at 9,500 ft. 03/08/2013 - Friday Continued SOH W/ Fish, LD drill collars, bumper jars, accelerator jars, spear, packer and tbg tail (2 jts 2- 3/8 "). TBIH W/ 45 stands of 2 -7/8" WS, MU Halliburton Retrievable Storm Packer, TIH on 4 jts of 2 -7/8" WS, set packer, test and charted for 30 min to 3,200 psi, test good, ND Spool piece to Bop's, Install new Hanger spool on well head, NU Bop's and retested breaks, tested and charted breaks 250 low and 3,000 high for 10 mins. PU 2 stands of 2 -7/8" WS, stung back into storm packer, PU and released packer, SOH W/ WS, LD storm packer and continued SOOH, MIRU Pollard Slickline Unit, RIH W/ 1.75" Magnet on centralizer, tagged bottom @ 10,568 ft, POOH, Recovered 1 cup of metal shavings. RBIH W/ 3.80" centralizer and 3.75" Magnet, tagged bottom @ 10,580', POOH, Recovered Same amount of metal shavings. RBIH W/ 3.5" GR, Tagged bottom @ 10,584', POOH. RBIH W/ 3.0" Drive down bailer, Tagged bottom @ 10,583', Worked tools and POOH, Recovered very little sand and mud in bailer. MIRU Pollard E -Line Unit, NU shooting flange on top of annular preventer, Armed 1st Gun, PU, RIH W/ 27' gun and GR /CCL, logged from bottom @ 10,572'- 9,400', Correlated depths, dropped down to desired depth and perforated H10 from 10,541'- 10,568'. POOH. Ensured all guns fired. Armed 2nd Gun, PU, RIH W/ 10' gun and CCL, logged single pass, Correlated depths, dropped down to get on desired depth and stuck gun @ 10,544'. Attemped to pull free up to 3,200# on string tension. Fired gun at depth with 500# over pull and gun came free. Re- perforated 10 ft section of H10 from 10,544'- 10,564'. POOH, Ensured guns fired. 03/09/2013 - Saturday Armed 3rd Gun, PU, RIH W/ 10' gun and CCL, logged single short pass, Correlated depths, dropped down to desired depth and perforated H9 from 10,503'- 10,513'. POOH. Ensured all guns fired. Armed 4th Gun, PU, RIH W/ 15' gun and CCL, logged single short pass, Correlated depths, dropped down to desired depth and perforated H8 from 10,466'- 10,481'. POOH. Ensured all guns fired. Armed 5th Gun, PU, RIH W/ 17' gun and CCL, logged single short pass, Correlated depths, dropped down to desired depth and perforated H7 from 10,414'- 10,431'. POOH. Ensured all guns fired. Armed 6th Gun, PU, RIH W/ 26' gun and CCL, logged single short pass, Correlated depths, dropped down to desired depth and perforated H5 from 10,356'- 10,382'. POOH. Ensured all guns fired. Armed 7th Gun, PU, RIH W/ 7' gun and CCL, logged single short pass, Correlated depths, dropped down to desired depth and perforated H4 from 10,338'- 10,345'. POOH. Ensured all guns fired. Armed 8rd Gun, PU, RIH W/ 16' gun and CCL, logged single short pass, Correlated depths, dropped down to desired depth and perforated H3 from 10,316'- 10,332'. POOH. Ensured all guns fired. Armed 9th Gun, PU, RIH W/ 16' gun and CCL, logged single short pass, Correlated depths, dropped down to desired depth and perforated H2 from 10,283'- 10,299'. POOH. Ensured all guns fired. ND Shooting flange and RDMO Pollard E -Line Unit,Fluid started at 1,100 ft before first gun and ended up at 3,320 ft at last run. PU WLRG on 2 jts of 2 -3/8" 8RD, with a ported collar on top, TIH W/ 10 stands of 2 -3/8 ", 5" Arrowset 1X packer, on /off tool, 1 jt of 2 -3/8" 8 Rd, Y -Block separator with 4' pup, seat nipple, and remaining 2 -7/8" 8 RD to surface. Tagged top of liner, PU and spaced out Tbg, to land y -Block 13ft above liner top. Set Arrowset 1X packer with 22,000# tension over string weight at 79,000# total. RUN CHEMICAL INJECTION LINE DOWN TO 2,978 FT. 03/10/2013 - Sunday Dropped standing valve down tbg, tested tbg to 3,000 psi, test good and charted. Set back pressure valve in Tbg hanger and ND Bop's, NU new wellhead. MIRU Pollard Slickline Unit, RIH W/ 2" JDC to 9,363', latched SV and POOH, RDMO Pollard Slickline Unit. Made rig and equipment ready to run Pump and rods in well. PU & RIH W/ 6' gas anchor /screen on bottom of 2 -1/2" X 1 -3/4" X 36' RHBC PA w /sand seal, 1- 1" X 30' 3/4 Stabilizer Bar; 1- On /Off Tool 3/4 Box X Pin (Browning RH Release); 1- 1" X 30' 3/4 stabilizer Bar; 12- 1 -1/2" X 25' Grade C Sinker Bars; 11- 1" X 30' stabilizer bars, (1 between each weight bar); 100- 3/4" X 25' Slick EL Rods; 140- 7/8" X 25' Slick EL Rods; 114- 1" X 25' Slick EL Rods; 5- 1" X 25' XL guided stealth EL Rods, (4 p /rod); 1- 1" X 4' single guide EL Pony Rod; 1- 1 1/2" X 40' Polish Rod. We then seated pump, loaded tbg and test against pump seal and pump to 600 psi, bled pressure off and stroked fluid to surface using the rig. 03/11/2013 - Monday Rigged down winterization kit, equipment and workover rig. Stage all equipment on new pad. Slid new Rotoflex up to top of rods. . • • II Soldotna Creek Unit Well: SCU 41A -08 SCHEMATIC Completion Date: 03/10/13 tlikmn 11014.a.1.1.1. PTD: 194 -085 A API: 50- 133 - 10120 -01 RK8 = 15' CASING AND TUBING DETAIL surf e WT Grade ID Top Btm 20" 20 7" " Surf 46' B 11 -3/4 " 47# J - 11" Surf 2,022' 29# N -80 6.184" Surf 290' 7" 268 N -80 6.276" 290' 1,219' 7" 238 N -80 6.366" 1,219' 4,952' 1 1 -3/4" 7" 26# N -80 6.276" 4,952' 6,617' 2 ' 7" 238 N -80 6.366" 6,617' 8,427' 7" 29# P -110 6.184" 8,427' 9,745' 5" 18# L -80 4.276" 9,457' 10,925' TUBING 2 -7/8" 6.4# L80 EUE 2.441" Surf 9,401' C \ 2 -3/8" 4.78 N80 1.995" 9,439' 10,085' D E F 3 JEWELRY DETAIL G Ht xi 4 No. Depth ID Item 1 15' Tubing Hanger -1 Latch 2 2,970' 2,441" Chemical Injection Sub 5 3 9,401' 2.5" Seating Nipple 4 9,406' 2.441" Anchor Separator w/ 4' pup; 2-1/16"11 tubing —120' 6 5 9,407' 2.441" X -over 2 -3/8" pin x 2 - 7/8" box �� 7 6 9,440' 1.995" On /Off Tool 7 9,446' 1.995" 5" Arrowset 1X Packer _ 8 10,084' 1.995" WL Re -entry Guide G '7 „ ROD DETAIL # Depth Length OD Description A 0 40' 1 - 1/2" Polished Rod, 30' in well B 4' 4' 1" 1" x 4' EL Pony Rod w/ 1 XL guide per rod 8' 125' 1" 1" x 25' EL Sucker rods w/ 4 XL guides per rod Drill 'A" 133' 2,850' 1" 1" x 25' EL Sucker rods w/ "No" XL guides per rod hole in 2,974' 3,550' 7/8" 7/8" x 25' EL Sucker rods w/ "No" XL guides per rod collar @ 6,524' 2,500' 3/4" 3/4" x 25' EL Sucker rods w/ "No" XL guides per rod 10,036' C 9,024' 300' 1 -1/2" 1 -1/2" x 25' K Bars (weight bars) D 9,324' 31' 1" 1" x 30" Stabilizer Bar w /'4" Pins (between K Bars) E 9,355' 1' Browning On /Off Tool, J -Latch R hand release (Box X Pin) F 9,356' 2.5' 1" 1" x 30" Stabilizer Bar w/3/4" Pins JIMIL 8 G 9,401' 42' 1 - 3/4" 1 - 3/4" x 42' Insert Pump, RHBC Pump #3332 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 -2 H 9,414' 13' 1 -1/2" Dip Tube H -2 H -3 = H -4 — H-5 H -6 = H -7 H -8 — H 9 Tag fill H - 10 10,583' 3/8/13 H -11 = H-12 = PERFORATION DETAIL ON NEXT PAGE H -13 — Z— ' 4 .. - &5„ TD = 10,930' PBTD = 10,835' Max Hole Angle = 9.1 deg Updated by DMA 05 -10 -13 • • II Soldotna Creek Unit Well: SCU 41A -08 SCHEMATIC Completion Date: 03/10/13 name 1.14.1.a. 1,1.4, PTD: 194 -085 A API: 50 -133- 10120 -01 PERFORATION DATA Zon Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments e G-2 10,188' 10,192' 10,185' 10,189' 4' 10,196' 10,209' 10,193' 10,206' 13' 10,281' 10,297' 10,277' 10,293' 16' H -2 10,283' 10,299' 10,279' 10,295' 16' 3 -1/2" HC, 6 spf, 60 phase 3/2013 10,312' 10,328' 10,308' 10,324' 16' 1- 11/16" Enerjet, 6 spf, 90 phase H-3 10,316' 10,332' 10,312' 10,328' 16' 3 -1/2" HC, 6 spf, 60 phase 3/2013 10,336' 10,344' 10,331' 10,339' 8' H -4 10,338' 10,346' 10,333' 10,341' 8' 3 -1/2" HC, 6 spf, 60 phase 3/2013 10,356' 10,371' 10,351' 10,366' 15' H -5 10,356' 10,382' 10,351' 10,377' 26' 3 -1/2" HC, 6 spf, 60 phase 3/2013 H -6 10,403' 10,407' 10,398' 10,402' 4' 1- 11 /16" Enerjet, 4 spf, 0 phase 10,413' 10,432' 10,408' 10,426' 19' 1- 11/16" Enerjet, 4spf, 0 phase H -7 10,414' 10,431' 10,409' 10,425' 17' 3 -1/2" HC, 6 spf, 60 phase 3/2013 10,435' 10,443' 10,429' 10,437' 8' 1- 11/16" HC, 4 spf, 0 phase 10,456' 10,480' 10,450' 10,474' 24' 1- 11/16" HC, 4 spf, 0 phase H -8 10,446' 10,481' 10,440' 10,475' 35' 3 -1/2" HC, 6 spf, 60 phase 3/2013 H -9 10,502' 10,516' 10,496' 10,510' 14' 1- 11/16" HC, 4 spf, 0 phase H -9 10,503' 10,513' 10,497' 10,507' 10' 3 -1/2" HC, 6 spf, 60 phase 3/2013 10,541' 10,564' 10,534' 10,557' 23' 1 -1 /16" HC, 4 spf, 0 phase 10,541' 10,568' 10,534' 10,561' 27' 3 -1/2" HC, 6 spf, 60 phase 3/2013 H -10 10,544' 10,564' 10,537' 10,557' 20' 3 -1/2" HC, 6 spf, 60 phase 3/2013 10,564' 10,620' 10,557' 10,613' 50' 1- 11/16" Enerjet, 6 spf, 90 phase 10,617' 10,632' 10,610' 10,625' 15' 1- 11/16" Enerjet, 2 spf, 0 phase H -11 10,674' 10,684' 10,666' 10,676' 10' 1- 11/16" Enerjet, 10 spf, 180 phase H -12 10,709' 10,725' 10,701' 10,717' 16' 1- 11/16" Enerjet, 2 spf, 0 phase H -13 10,764' 10,776' 10,755' 10,767' 12' 1- 11/16" Pivot, 10 spf, 180 phase Updated by DMA 05 -10 -13 • • MEMORANDUM State of Alaska AOGCC TO: Jim Regg 'e>�9 q/1 q/13 DATE: 3/18/13 P. I. Supervisor FROM: Bob Noble SUBJECT: Hilcorp Alaska LLC Petroleum Inspector No-Flow Test SCU 41A-08, PTD 194-085 3/18/13 On arrival to the Swanson River Field office I met with Hilcorp Alaska representative Marty Guth and Hilcorp well operator Max Finch. We went over what the AOGCC requirements were for testing the well. I also had Marty show me the test equipment that he was going to use to do the no-flow test. Everything looked very acceptable. Max told me that the well had been open to atmosphere for approximately 8 hours. On arrival at the well I found it to still be open to atmosphere though a 2-inch hose with no sign of bleeding any gas. Marty then hooked up his 1/2" test gauge and flow meter. He then lined up the IA and the tubing to flow through the test equipment. There was no sign of flow after test equipment was hooked up. The test results are as follows: Time Pressures Status Flow Rate Remarks (psi) (scfm) 10:10 0/0/0 S/I well 0 11:10 1/1/0 Open well 1 - 0 psi , 0 scfm in 2 sec 11:11 0/0/0 S/I well 0 12:11 1/1/0 S/I 0 12:41 1/1/0 S/I 0 13:11 1/1/0 Open well 1 - 0 psi, 0 scfm in 2 sec - 13:12 0/0/0 S/I 0 13:20 0/0/0 Open well 0 Pressures —tubing/inner annulus/outer annulus Flow Rate — standard cubic feet per minute (scfm) This well seemed to be dead and unable to flow to surface unassisted. The very small amount of gas that built up could have been gas break out. There was a total of 4 scf of gas produced during the test. Attachments: none SCANE 4E t t.0 2013-0318_No-Flow_SCU_41 A-08_bn.docx J • • • ' w \�� j j� s THE STATE Alaska Oil and Gas ° ALASKA Conservation Commission *�„ GOVERNOR SEAN PARNELL 333 West Seventh Avenue OJTQ. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Chad Helgeson Operations Manager NED LIAR 11 M rp Hilcorp Alaska , LLC S 3800 Centerpoint Drive Anchorage, AK 99503 ( Y Re: Swanson River Field, Hemlock Oil Pool, SCU 41A -08 Sundry Number: 313 -093 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, -tI Daniel T. Seamount, Jr. Commissioner • DATED this 2 . day of February, 2013. Encl. 10,41K,I, RECEIVED • ry fti FEB 2 2 2013 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair WeC] Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate 0 • Pull TubinE , Time Extension ❑ Operations Shutdowi ❑ Re -enter Susp. Wel ❑ Stimulate ❑ Alter Casing0 Other. Install Rod Pump n 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development El . 194 -085 , 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service 111 6. API Number: Anchorage, Alaska 99503 50-133-10120-01 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123A ' Soldotna Creek Unit (SCU) 41A -08 ' Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028996 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): 10,930 ' 10,920 • 10,618 10,611 N/A 10,618' (fill) Casing Length Size MD 7VO Burst Collapse Structural Conductor 46' 20" 46' 46' Surface 2,022' 11 -3/4" 2,022' 2,022' 3,070 psi 1,510 psi Intermediate Production 9,745' 7" 9,745' 9,745 6,340 psi 3,830 psi Liner 1,468' 5" 10,925' 10,915' 10,140 psi 10,500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 2 -7/8" Tubing Grade: 6.4# / L -80 Tubing MD (ft): 9,277 See Attached Schematic See Attached Schematic 2 -3/8" 4.6# / N -80 10,050 Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): HES BWD Pkr - N/A 10,039' MD; 10,038' TVD - N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphirjn Development [] Service n 14. Estimated Date for 15. Well Status after proposed work: Operations: 02/28/13 Commencing Oil g p Q 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 chelgesonethilcorp.com Printed Name Chad Helgeson Title Operations Manager s onn Signature �' '� 7/ Phone 907-777-8405 Date ZA Z` /3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 515 i � f � n n Plug Integrity ❑ BOP Test R Mechanical Integrity Test ❑ Location Clearance ❑ V(v Other: g 3 � NO r SL 1 3,e- f-" / 4 `V c � F ( v 1 C 5 - f - & e r E-4-,b; L i z e (!' G st - h - ' FEB 2 7 20 Spacing Exception Required? Yes 0 No Lb Subsequent Form Required: IQ-L/014 I APPROVED BY 07/45 Approved by: / COMMISSIONER THE COMMISSION Date: Z - Z S r1 • 3 Submit Form and Q J � L Approved ap cation is valid for 12 months from the date of approval. Attachments in Duplicate / R .I f ^ • • Well Prognosis Well: SCU 41A -08 Hilcorp Alaska, LL Date: 2/22/2013 Well Name: SCU 41A -08 API Number: 50- 133 - 10120 -01 Current Status: Producing Oil Well Leg: N/A Estimated Start Date: February 28, 2013 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 194 -085 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) AFE Number: AFE 1222643 Current Bottom Hole Pressure: < 2,500 psi @ 10,400' TVD BHP Buildup interpretation 6/6/2006 Maximum Expected BHP: — 2,500 psi @ 10,400 TVD Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir pressure as measured by static pressure survey run —6 -6 -2006. Working fluid (gradient of .442 psi /ft) will balance reservoir pressure at 4,744 ft. TVD. Brief Well Summary Soldotna Creek Unit 41A -08 was drilled in 1994 as a sidetrack of the original Hemlock injection well SCU 341 -08. • SCU 41A -08 was initially completed in the lower Hemlock (H10 -H13 sands) free flowing at approximately 100 BOPD and low GOR. From 1996 — 2001, the H4 — H10 sands were added to the completion in an effort to blow down gas injected into the Hemlock in SCU 341 -08. Significant paraffin deposition throughout the life of the well has led to regular mechanical and solvent (xylene) treatments. In 2001, the H2 -H5 sands were added and . the well began lifting on gas lift. The Tyonek G -Zone was added in 2007 with no noticeable production contribution. Notes Regarding Wellbore Condition • The well currently makes about 20 BOPD and 40 BWPD. • Wellbore maximum deviation below sidetrack is less than 10 degrees. - OBJECTIVE OF WORKOVER Reperforate select Hemlock intervals and convert well from gas li ft to rod pump artificial lift. The current gas • lift completion will be pulled and the packer at 10,039 will be removed to facilitate removal of fill as required to reperforate. Pre Work over Rig Procedure: 1. Pre pulling unit activities. 2. Close and tag (lock out/ tag out /bleed) pressure sources to wellhead from flow lines and gas lift supply lines. 3. Shoot fluid levels on casing and tubing. Record pressures on tubing and casing. 4. RU slick line unit and pull first gas lift valve below fluid level in tubing. 5. RIH with 1.75 gauge ring and tag fill in casing. . • • Well Prognosis Well: SCU 41A -08 Hilcorp Alaska, LL Date: 2/22/2013 6. Run 1.875" GR to 9,920'. 7. Set tubing stop /plug @ 9,900'. 8. Conduct JSA on rig up operations. Work -over Rig Procedure 9. MIRU Williams pulling unit. 10. Load well with lease produced water (8.5 ppg) filling well down tubing and take returns on casing. 11. Pressure up on tubing to 2,000 psi on casing for pressure test Isolate pump and chart record test for 30 minutes. cas:.+a 12. RU slick line. 13. RIH with tubing punch and punch hole above plug @ 9,900' to drain tubing. RIH with slick line with tubing stop /plug and set at 500 ft. 14. Rig up circulating manifold and bleed pressure off tubing through same to working tank. , ,15. Pressure test Tbg plug to 3,000 psi. for 5 minutes after isolating from pressure pump. ee."`' (& 16. ND tree, NU BOPE and test to 250 psi low /3,000 psi high, annular to 250 psi low /1,500 psi high. a. Notify AOGCC 24hrs in advance to witness. b. BOPE test results must be reported in daily operations report AND MUST BE PROVIDED TO THE AOGCC WITHIN 5 DAYS. c. Notify BLM 48 hours in advance of BOP test 17. Pull tubing stop or BPV and install 2 -7/8 EUE N 80 handling sub in hanger. 18. Back out tbg hanger hold down pins and pick up on hanger. NOTE: Install safety chains on elevators with enough slack for hanger to clear top of BOP stack. 19. With hanger free, record tbg weight while picking up tubing. Do not exceed 40,000Ib above string weight on tbg head connection to pull locator seal assembly out of HES BWD packer at 10,039 ft. If seals are stuck in packer RU a -line and cut 2 3/8 tubing 10 ft. above locator seal assy. Fish same with overshot and bumper jars on work string. 20. If seal assembly pulls free, TOOH with tubing and gas lift mandrels. LD tubing and send mandrels to shop for cleaning and inspection. NOTE: Use a wear ring above stripper rubber to center tubing in BOP stack while pulling tubing. Exercise caution when side pocket mandrels approach stripper head assy. 21. PU 4 -5/8" Packer retrieval assembly (burning shoe, wash pipe, bumper sub, jars, drill collars) and 2 -7/8" work string. 22. TIH and burn over packer until comes free and push down. 23. PU overshot or spear (dressed for 2 -3/8 tbg), bumper jars, and collars to fish BHA. 24. POOH with BHA. 25. RU slick line and RIH with pump bailer to recover milling debris. Alternate trips with magnets may be required for strip gun debris. 26. RIH with 3.75 gauge ring and junk basket to +/- 10,590'. ( t, ,L( /a 7 ') 27. RD slick line. 28. Pick up test packer and set in casing at +/- 500 ft. Pressure test packer to 3000 psi. 29. ND BOP and install Seaboard tubing hanger spool on top of Shaffer -T5511 tubing Head. NU BOP and test to 3000 psi. All connections separated /made up during this operation must be tested and documented. 30. POOH with test packer. ( p 31. MIRU E -line unit to perforate. • • Well Prognosis Well: SCU 41A -08 Hilcorp Alaska, LL Date: 2/22/2013 32. Correlate perforating depths to 5" CBL by Schlumberger Dated 30 October 1994. Log measured from KB elev = 160.6 ft. and permanent datum Ground level elevation is 134.0 ft. 33. Perforate Hemlock intervals as follows for maximum diameter entry hole charges in ^'3.5 "OD carrier 6 spf on 60 deg phase. H10 10,541'- 10,568' H9 10,503'-10,513' H8 10,446' - 10,481' ('`l H7 10,414'- 10,431' E' H5 10,356'- 10,382' H4 10,338'- 10,345' H3 10,316'- 10,332' H2 10,283'- 10,299' Note: Record fluid levels and time of day for each RIH with E -line. 34. RDMO E -line unit. 35. PU New 2 7/8 EUE 8rd L -80 tubing. 36. Run tubing and BHA for rod pump completion per attached wellbore diagram. In order to set packer below liner hanger, tag top of liner with Anchor Separator and then pick up 10 -12 ft to set packer in casing below liner hanger. 37. Space out tubing to land tubing in hanger with 35,000 Ibs tension at packer. 38. Drop equalizing standing valve and Toad tubing. 39. Test tubing to 5,000 psi. 40. ND BOP and NU wellhear.Test wellhead to 5,000 psi 41. RU slick line and RIH to standing valve. Latch and open bypass on standing valve to drain tubing. Retrieve standing valve and RDMO slick line. 42. Run bottom hold down insert pump on API 86 rod string per design with 300 ft of sinker bars and on /off tool above down hole pump. Space out rods for polish rod elevation, and load tubing with clean produced water. 43. Hang off polish rod on spacer spool above stuffing box to protect finish on polish rod. 44. RDMO work over rig. 45. Position pumping unit and secure to base per manufacturers recommendations. 46. Hang polish rod on pump and space out to unload well. Re space rods for proper pump operation as well unloads at design pump speeds. 47. Turn well over to production. it ,. Nd i / sf Attachments: 1. As -built Schematic 2. As -built Wellhead 3. Proposed Schematic 4. Proposed Wellhead 5. BOP Schematic • 0 Soldotna Creek Unit Well: SCU 41A -08 SCHEMATIC Completion Date: 11/9/94 Hil• urp Slik4.a. 111 PTD: 194 -085 API: 50- 133 - 10120 -01 RKB = 26.5' 1 CASING AND TUBING DETAIL J L20" Size WT Grade ID Top Btm 20" Surf 46' 11 -3/4" 47# J -55 11" Surf 2,022' 7" 29# N -80 6.184" Surf 290' 7" 26# N -80 6.276" 290' 1,219' 7" 23# N -80 6.366" 1,219' 4,952' 11 -3/4" 7" 26# N -80 6.276" 4,952' 6,617' i 1 7" 23# N -80 6.366" 6,617' 8,427' 7" 29# P -110 6.184" 8,427' 9,745' 1 2 5" 18# L -80 4.276" 9,457' 10,925' TUBING ilEr i 3 2 -7/8" 6.40# L -80 2.441" Surf 9,277' NI 2 -3/8" 4.60# N -80 1.995" 9,277' 10,050' MR i 4 I' U ■ 5 i .2 6 JEWELRY DETAIL Nit No. 1 Depth ID Item 1 4,486' Camco MMG -P GLM 7 2 5,518' - Camco MMG -P GLM 3 6,480' - Camco MMG -P GLM 4 7,463' - Camco MMG -P GLM 5 8,488' Camco MMG -P GLM 6 9,243' Camco MMG -P GLM 2- 3/8 "x2 -7/8" Butt XO 7 9,276' 7 8 9,887' - XA Sleeve 9 10,038' 1.993" Locator sub w /seals 10 10,039' - HES BWD Packer • • 8 11 10,050' - 2- 5/16 "x2 -3/8" Butt XO III 9 12 10,083' 1.875" HES "X" Nipple •I 13 10,114' Wireline Re -entry Guide 10 1 PERFORATION DATA 11 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments im 10,188' 10,192' 10,185' 10,189' 4' 12 G -2 ME 10,196' . 10,209' 10,193' 10,206' 13' 13 11-2 10,281' 10,297' 10,277' 10,293' 16' G -2 H -3 10,312' ' 10,328' 10,308' 10,324' 16' 1- 11/16" Enerjet, 6 spf, 90 phase H -2 = H -4 10,336' . 10,344' 10,331' 10,339' 8' H -3 H -5 10,356' • 10,371' 10,351' 10,366' 15' H -4 H -6 10,403' . 10,407' 10,398' 10,402' 4' 1- 11/16" Enerjet, 4 spf, 0 phase H -5 10,413' 10,432' 10,408' 10,426' 19' 1- 11/16" Enerjet, 4spf, 0 phase H-7 H -6 10,435' . 10,443' 10,429' 10,437' 8' 1- 11/16" HC, 4 spf, 0 phase = H -7 H -8 10,456' 10,480' 10,450' 10,474' 24' 1- 11/16" HC, 4 spf, 0 phase H -8 = H -9 10,502' . 10,516' 10,496' 10,510' 14' 1- 11/16" HC, 4 spf, 0 phase H -9 Tag Fill 10,541' " 10,564' 10,534' 10,557' 23' 1- 1/16" HC, 4 spf, 0 phase H -10 = 10,641' H -10 10,564' ' 10,614' 10,557' 10,607' 50' 1- 11/16" Enerjet, 6 spf, 90 phase 9/30/12 H -11 10,617' . 10,632' 10,610' 10,625' 15' 1- 11/16" Enerjet, 2 spf, 0 phase H -12 H -11 10,674' • 10,684' 10,666' 10,676' 10' 1- 11/16" Enerjet, 10 spf, 180 phase H -13 = H -12 10,709' 10,725' 10,701' 10,717' 16' 1- 11/16" Enerjet, 2 spf, 0 phase L► 5„ H -13 10,764' • 10,776' 10,755' 10,767' 12' 1- 11/16" Pivot, 10 spf, 180 phase TD = 10,930' PBTD = 10,835' Max Hole Angle = 9.1 deg Updated by DMA 02 -22 -13 H • 0 Swanson River SCU 41 -08 02/21/2013 Ibknr1 tlarka. 1.Lt Swanson River Tubing hanger, Shaffer T55- SCU 41 -08 AJ, 7 X 2 7/8 IBT lift and 113/4X7X27/8 susp,w /2 %Cossascoor Type H BPV BHTA, Bowen, 2 9/16 5M FE X 2'/ Bowen quick union III 111 - 1111 F c' P FL' P Valve swab, WKM M, ^ " C� O P C� \" O P 2 9/16 5M FE, HWO, AA 0 0 �t`�' �`� �r�' \. ■ ' &, it a Ja\ 6< J a \ J 6 5 � � 0 0 0 �, X1 11 Valve wing, CIW -FC, ' p a A 4 o' j 21 /165MFE,HWO,AA ir I Ti; lic is 1 � �� 1 Valve upper master, 0 0 , CIW -FC, 2 9/16 5M FE, E. r , O HWO,AA , 0 0 Adapter, Grayloc E -25 X 11 29/165M • J 11 1 ' Valve lower master, eV � WKM -B, 2 9/16 10M w/ p Grayloc E -25 ends, HWO, AA � [� Adapter, Shaffer -APO, 7 1/16" ]�� 5M studded X 2 9/16 1OM _ _ Grayloc E -25 top : w; Tubing head, Shaffer ii T T55 LI, 135/83MX =.:1 In 7 1/16 5M w/ 2- 2 1/16 -� lit 5M SSO, 7" Type 1 secondary seal in head c, 1111 Vll ■■ l �• iii S w � Casing head, Shaffer KD, " 135/83MX 11 3/4 SOW, 111 . 1 111 w/ 2- 2" LPO, 7" KD slips and packoff assy in head '_ J Valve, plug, Rockwell, I fill it I , � I t ■-i�:! 2', LPO, C r, II • Soldotna Creek Unit Well: SCU 41A -08 PROPOSED Completion Date: 11/9/94 HiI,•orit Un- La. 1.1.4 PTD: 194 -085 API: 50- 133 - 10120 -01 RKB = 26.5' CASING AND TUBING DETAIL Size WT Grade ID Top Btm _I 20" Surf 46' L20" 11 -3/4" 47# J -55 11" Surf 2,022' 7" 29# N -80 6.184" Surf 290' 7" 26# N -80 6.276" 290' 1,219' 7" 23# N -80 6.366" 1,219' 4,952' 7" 26# N -80 6.276" 4,952' 6,617' 1, 2, 3 7" 23# N -80 6.366" 6,617' 8,427' 11-3/4" 7" 29# P -110 6.184" 8,427' 9,745' 5" 18# L -80 4.276" 9,457' 10,925' 4 TUBING 2 -7/8" 6.4# L80 EUE 2.441" Surf 9,424' 2 -3/8" 4.7# N80 1.995" 9,429' "'10,100' i5h E19 JEWELRY DETAIL No. Depth ID Item 5 III`� 7 1 ±3,025' Rod string 1" x 3,025' 2 ±7,350' Rod string 7/8" x '4,325' ®, �� 8 3 ±9,075' Rod string' " x ^'1,725' i , 10 4 ±9,389' Sinker Bars 1.5" x 300' S ±9,424' 1.75" Pump 1.5" x 35' , 10 6 ±9,428' 2.441" Pup Jt 2 -7/8" x 3.5' + MHD Seating Nipple a 11 7 ±9,428' -- 2- 1/16" IJ tubing - 120' 8 ±9,429' A4' erSeparator /ys. tr, 111 01 -1 12 9 ±9,430' 2 -5/8 box x 2 -3/8" pin x over 10 ±9,431' ±30' x 2 -3/8" tubing 11 ±9,463' 1.78" On /Off Tool .. 12 ±9,472' 1.992" Arrowset 1X Packer 13 ±10,100' 1.992" WL Re -entry Guide PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Drill' /." G-2 10,188' 10,192' 10,185' 10,189' 4' hole in 10,196' 10,209' 10,193' 10,206' 13' collar @ H -2 10,281' 10,297' 10,277' 10,293' 16' 10,036' H -2 10,283' • 10,299' 10,279' 10,295' 16' 3 -1/2" HC, 6 spf, 60 phase H -3 10,312' , 10,328' 10,308' 10,324' 16' 1- 11/16" Enerjet, 6 spf, 90 phase ' . H -3 10,316 10,332' 10,312' 10,328' 16' 3 -1/2" HC, 6 spf, 60 phase H -4 10,336' 10,344' 10,331' 10,339' 8' H -4 10,338' • 10,346' 10,333' 10,341' 8' 3 -1/2" HC, 6 spf, 60 phase 13 H -5 10,356' 10,371' 10,351' 10,366' 15' H -5 10,356' . 10,382' 10,351' 10,377' 26' 3 -1/2" HC, 6 spf, 60 phase G-2 H -6 10,403' 10,407' 10,398' 10,402' 4' 1- 11/16" Enerjet, 4 spf, 0 phase H -2 = H -7 10,413' 10,432' 10,408' 10,426' 19' 1- 11/16" Enerjet, 4spf, 0 phase H - = H -7 10,414' . 10,431' 10,409' 10,425' 17' 3 -1/2" HC, 6 spf, 60 phase H-4 H -7 10,435' 10,443' 10,429' 10,437' 8' 1- 11/16" HC, 4 spf, 0 phase H -8 10,456' 10,480' 10,450' 10,474' 24' 1- 11/16" HC, 4 spf, 0 phase H - = H -8 10,446' • 10,481' 10,440' 10,475' 35' 3 -1/2" HC, 6 spf, 60 phase H -6 H -9 10,502' 10,516' 10,496' 10,510' 14' 1- 11/16" HC, 4 spf, 0 phase H -7 = H -9 10,503' • 10,513' 10,497' 10,507' 10' 3 -1/2" HC, 6 spf, 60 phase H -8 = H -10 10,541' 10,564' 10,534' 10,557' 23' 1- 1/16" HC, 4 spf, 0 phase H - T Fill H -10 10,541' • 10,568' 10,534' 10,561' 27' 3 -1/2" HC, 6 spf, 60 phase H -10 10,564' 10,620' 10,557' 10,613' 50' 1- 11/16" Enerjet, 6 spf, 90 phase H-10 10,641' H -10 10,617' 10,632' 10,610' 10,625' 15' 1- 11/16" Enerjet, 2 spf, 0 phase 9/30/12 H -11 = H -11 10,674' 10,684' 10,666' 10,676' 10' 1- 11/16" Enerjet, 10 spf, 180 phase H -12 = H -12 10,709' 10,725' 10,701' 10,717' 16' 1- 11/16" Enerjet, 2 spf, 0 phase H -13 H -13 10,764' 10,776' 10,755' 10,767' 12' 1- 11/16" Pivot, 10 spf, 180 phase Li'w r rjho °' , 5„ TD = 10,930' PBTD = 10,835' Max Hole Angle = 9.1 deg Updated by DMA 02 -22 -13 x • • wanson PROPOSED SCU4108 02/21/2013 Iblrnrp flax& a. 1.I.(. Swanson River Tubing hanger, Seaboard, SCU 41 -08 ECO tension, 7 1/16 5M X 2 11' /." X 7" X 2 7/8 7/8 EUE lift and susp, w/ 2''/ type H BPV, 3/8 control line, 5" slickneck, left to release, right to engage Full stainless steel for chemical injection Special Cross, 2 9/16 5M FE X 27 /8EUE8rdw /2 -21/16 5M SSO 0 Valve, wing, WKM -M, 2 1/16 _ _ = 1 5M FE, HWO, DD trim ` ' . � 0 Valve, wing, WKM -M, 2 1/16 �� J 0 5M FE, HWO, DD trim ISO C J A Adapter, Seaboard, 7 1/16 ' I JL� ' ig 5M FE 29 /165M w /5 "Pp /Q% Attachment spool, FMC -TC, .,,,;11 �� seal pocket, ''Acontrol line 7 1/16 5M X 7 1/16 5M 1 exit, alloy material 1 � Grade Level r ■. 0 0 Tubing head, Shaffer- T55L1, :ID lam" ' 13 " 13 5/8 3M X 7 1/16 5M w/ 2- \ A � 2 1/16 5M SSO r ' ,' fur Valve, wing, WKM -M, 2 1/16 5M FE, HWO, DD trim Qty 2 - kg 1110All , ® 1 firii 0 - Casing head, Shaffer KD, 13 5 /83MX11L O SOW,w /2 -2 i' 1. "' I 4 , 111 i F. - v, • • . Swanson River SCU 41A -08 02/20/2013 Holt—mil %I:.•k... 1.11 Swanson River Williams BOP 2013 • • (11111'111 MI Ifl 11111 - 1 1 3.46' Shaffer 11 "5M 1111 111 111 111 111 - i Shaffer LWS _ II is ; s — J ? 2.75' 11" 5M _ 2 1/16 10M Choke and Kill Valves ,0111111 ' ; 111 111111 IP IV a . ; I H r l �'° / `! 2.00' -- - : 11L111.11tl;li1.iii - • j `E ' ; 1!1 1!1 18 Ill X 2.00 9 "5M mill v 1f1 ill 1!1 ® iI% 1n1 I II ii. 0 al 11111 111 L • • 1 I \ I - - - r - - t 1 i 1 / II I `\\\ ` I _ , r , LU U U I 1 I IOU I 111111 A 1 i 1 el a 1 - -- : I ::<:. - -- I I i 1 - MY - I U1 - - -- 1111 I 1 IN - - -- i�1 1 ■ � 1 A 1 i - l 1 _� 1 I I I/ I I t • 1 I sal d Isi • I 1 1 I II II I ' I jL w its Q-2737 DRAWN BY: A.C. DEMNY DATE: 07/07/11 Ch@Vl"011 Francisco Castro Chevron North America Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: fcbn@chevron.com December 4, 2007 To: AOGCC Howard Okland 333 W. 7t" Ave. Ste#100 Anchorage, AK 99501 PERMIT # ~ API NUMBER I WELL LOG TYPE SCALE LOG DATE J WTEr2VAL LOGGED RUN # i B- FILM LINE ~ it CD --- -NOTES LAS, PDS, DLIS COMPLETION -- - - ~- -- - RECORD 1 11116" POWER SCU 41A- SPIROL 7.5" 14-Jul- 9950 - 194-085-0 501331012001 8 SPF 5" 07 10420 1 1 1 1 PDS COMPLETION RECORD TTS 2 7/8" SRU 31- RETRIEVABLE 13-Jan- 1300 - 180-114-0 501332033600 33 BRIDGE PLUG 5" 07 1550 1 1 1 1 PDS C ~"~,th1~ DEC ~ 2~~~" Please acknowledge receipt by signing and returning one copy of this trans~nift~a4 or FAX to. 907 263 7828. Received By: Date: ,,,_, '" . STATE OF ALASKA I ALASKA Oil AND GAS CONSERVATION COMM SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED AUG 0 1 2007 qiaska Oil & Gas Cons. CammissÎon 3. Address: P.O. Box 196247, Anchorage, AK 99519 Plug Perforations Perforate New Pool 0 Perforate [2] 4. Well Class Before Work: Development [2] Stratigraphic 0 Stimulate Other Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 94-85 ' 6. API Number: 50-133-10120-01 ,/ 9. Well Name and Number: SCU 41A-08 ( 10. Field/Pool(s): LJ Soldotna Creek Unit ./!c,-IoeJ- ()¡! r~( 1. Operations Abandon Repair Well Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Union Oil Company of California Name: Exploratory 0 Service 0 7. KB Elevation (ft): 26.5' 8. Property Designation: .. J Þ Swanson River Field Fe-o A z,ß"" /' e-. v. Þ? 11. Present Well Condition Summary: Total Depth measured 10,930 / true vertical 10,920 feet feet Plugs (measured) none Junk (measured) None Effective Depth measured 10,618 true vertical 10,614 feet feet Casing Length Size MD TVD Burst Collapse Structural Conductor 46' 20" 46' 46' Surface 2015' 11-3/4" 2022' 2022' 3,070 psi 1,510 psi Intermediate Production 9731' 7" 9745' 9745' 7,240 psi 5,410 psi Liner 1483' 5" 10,925' 10,915' 10,140 psi 10,490 psi Perforation depth: Measured depth: See attach Schematic SCANNED AUG 1 4·2·0D7 True Vertical depth: See Attach Schematic Tubing: (size, grade, and measured depth) 2-7/8", L-80, 9277' 2-3/8", N-80, 10,050' Packers and SSSV (type and measured depth) HES BWD Packer - 10,039' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 40 850 psi 40 870 psi 15. Well Class after work: Exploratory 0 16. Well Status after work: Oil[2] Gas 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl Prior to well operation: 60 Subsequent to operation: 63 14. Attachments: New Schematic Copies of Logs and Surveys Run Daily Report of Well Operations o Tubing Pressure 220 psi 220 psi Development [2] Service 0 x WAG 0 GINJ 0 WINJ 0 WDSPL Sundry Number or N/A if C.O. Exempt: 3 ~C)~-')~ a <Õf, o Contact Billy Applewhite Printed Name Timothy C. Brandenburg Signature Title Drilling Manager '-- Form 10-404 Revised 04/2006 C Phone 907-276-7600 Date 7/24/2007 OR I GIN A L RBDMS BFl AU6 13 1007 $.~~"~~.p:> Chevron . . . Trading Bay Unit Well # seu 41A-08 7/24/07 PROCEDURE SUMMARY: SLICKLINE: · 7/8/07: Brush and tlushto 2000'; 1.80"GRto 10,588'. 1-114" bailer to 10,616'. · 7/9/07: Ran 1-3/4" bailer to 10,618'. · 7/11/07: Ran temp/press gauges to 1 0,544' . · 7-13-07: Ran 1-3/4" dummy guns to 10,597'. E-LINE: · 7/14/07: Perforate from 10,188' to 10,209' / SRU 241-16 REVISED BY: BCA 3/15/07 RKB = 26.5' Surf 46' 47# J-55 11" Surf 2022' 7" 29# N-80 6.184" Surf 290' T' 26# N-80 6.276" 290' 1219' 7" 23# N-80 6.366" 1219' 4952' 7" 26# N-80 6.276" 4952' 6617' 1 7" 23# N-80 6.366" 6617' 8427' 7" 29# P-110 6.184" 8427' 9745' 2 5" 18# L-80 4.276" 9456.8' 10,925..3 ' 3 Tubing: 2-7/8" 6.40# L-80 2.441 " Surf 9277' 4 2-3/8" 4.60# N-80 1.995" 9277' 10,050' 5 6 1 4486' Cameo MMG-P GLM 7 2 5518' Cameo MMG-P GLM 3 6480' Cameo MMG-P GLM 4 7463' Cameo MMG-P GLM 5 8488' Cameo MMG-P GLM 6 9243' Cameo MMG-P GLM 7 9276' 2-3/8"x2-7/8" Butt XO 8 9887' XA Sleeve 9 10,038' 1. 993" Locator sub w/seals 10 10,039' HES BWD Packer 11 10,050' 2-5/16"x2-3/8" Butt XO 12 10,083 ' 1.875" HES "X" Nipple 10 13 10,114' Wireline Re-entry Guide G-2 10,188' 10,193' 5' 1-11/16" Enerjet, 7.5spf, 45 pbase G-2 10,]96' 10,209' 13' 1-] 1116" Enerjet, 7.5 spf, 45 phase H-3 10,312' 10,328' 16' 1-11/16" 6 spt: 90 phase H-5 10,403' 10,407' 4' ]-] 1116" Enerjet, 4 spt: ° phase H-7 10,413 ' 10,432' ] 9' 1-11116" Enerjet, 4spf, ° phase H-12 10,709' ]0,725' 16' 1-] 1116" Enerjet, 2 spf, 0 pbase H-8 10,564' 10,614' 50' 1-11116" Enerjet, 6 90 phase H-I0 10,6] 7' 10,632' 15' ] -11 /16" Enerjet, o phase H-l1 10,674' 10,684' 10' 1-11116" Enerjet, 10 spf, 180 phase H-J3 10,764' 10,776' ]2' 1-11/16" Pivot, 10 spf,J80 phase H-I0 10,54] , 10,564 ' 23' 1-1116" 4 spf, 0 phase TD = 10,930' PBTD = 10,835" H-9 10,502' 10,576' 74' 1-11116" HC, 4 spf, 0 phase Max Hole Angle = 9.1 <leg H-8 10,456' 10,480' 24' 1-11/16" HC, 4 spf, 0 phase SRU 4]A-08 New Schematic.doc DRA WN BY: BCA REVISED: 7/24/07 . ~V~VŒ (ID~ ~~~~[K(~ . AI~ASKA. OILAlVD GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 Re: Swanson River Unit, HemlockjG Oil Pool, SCD 41A-08 Sundry Number: 307-230 u,-o'3S- \q, iCA.~ED JUL 11 2007 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note. the conditions of approval set out in the enclosed form. . When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this 10 day of July, 2007 Enc!. ·P"l::S 7 )10/7 Gtr -1{)'i ~ STATE OF ALASKA 1 7~'9-P? RECEIVED ALASKA Oil AND GAS CONSERVATION COMM ION APPLICATION FOR SUNDRY APPROVALS JUL 0 6 2007 20 MC 25.280 " n:¡ o. f'.~n í'n,,<, 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 """Wâiver 0 Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 crnchOrage Time Extension Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory 0 94-85 3. Address: Stratigraphic 0 Service 0 6. API Number: P.O. Box 196247, Anchorage, AK 99519 50-133-10120-01 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 0 No 0 SCU 41A-08 / 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool( s): Swanson River Field 26.5' Soldotna Creek Unit 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,930' - 10,920' 10,614' 10,608' - Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2015' 11-3/4" 2022' 2022' 3,070 psi 1,510psi Intermediate Production 9731' 7" 9745' 9745' 7240 psi 5410 psi Liner 1483' 5" 10,925' 10.915' 10,140 psi 10,490 psi Perforation Depth MD (ft) Perforation Depth TVD (ft) Tubing Size: Tubing Grade: Tubing MD (ft) See Attached Schematic See Attached Schematic 2-7/8,2-3/8" L-80, N-80 9277', 10,050' Packers and SSSV Type: Packers and SSSV MD (ft): HES BWD Packer 10,039' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 7/20/2007 16. Well Status after proposed work: Commencing Operations: Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler - 263-7649 Printed Name Timothy C Brandenburg Title Drilling Manager Signature -;? . -¿;;:2-, ..f) ~ - Date 7/2/2007 -'""' é L-) ~.~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (31)7- ~~ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: ~(c.\" c.Ð"\~ \ <t~ ~\ ~ ""-~ "'- -\- ~(J:_C~' ~ ~ t)a~~<- t}-$ , ~ "1 ~ Subsequent Form Required: 4~mtf2 ~ "q~ISSIONER APPROVED BY ?-/t>- Dr- Approved by: THE COMMISSION Date: __A OR I bml '- -- Dr&" JUt 1. 1 LUU/ Submit in DUPlica~.;} Form 10-403 Revised 06/2006 n ~ Chevron === . . Trading Bay Unit Well SCU 41A-08 7/2/07 OBJECTIVE: · Add G2 sand perfs to existing Hemlock producing well. PROCEDURE SUMMARY: · Rig up hot oiler and slickline unit - Brush & flush tubing. · Bail fill to 10,632'. · Perform gaslift survey/PBU. · Perforate G2 sands from 10,188'-10,193' and 10,196'-10,209' SCD 41A-07 REVISED BY: BCA 7/2/07 RKB = 26.5' 46' 11-3/4" 47# J-55 II" Smf 2022' 7" 29# N-80 6.184" Surf 290' 7" 26# N-80 6.276" 290' 1219' 7" 23# N-80 6.366" 1219' 4952' 7" 26# N-80 6.276" 4952' 6617' 1 7" 23# N-80 6.366" 6617' 8427' 7" 29# P-II0 6.184" 8427' 9745' 2 5" 18# L-80 4.276" 9456.8' 10,925..3' :3 Tubing: 2-7/8" 6.40# L-80 2.441 " Smf 9277' 4 2-3/8" 4.60# N-80 1.995" 9277' 10,050' 5 6 1 4486' Cameo MMG-P GLM 7 2 5518' Cameo MMG-P GLM 3 6480' Cameo MMG-P GLM 4 7463' Cameo MMG-P GLM 5 8488' Cameo MMG-P GLM 6 9243' Cameo MMG-P GLM 7 9276' 2-3/8"x2-7/8" Butt XO 8 9887' XA Sleeve 9 10,038' 1.993" Locator sub w/seals 10 10,039' RES BWD Packer 11 10,050' 2-5/16"x2-3/8" Butt XO 12 10,083' 1.875" RES "X" Nipple HI 13 10,114' Wireline Re-entry Guide H-3 10,312' 10,328' 16' 1-11/16" Enerjet, 6 spf, 90 phase H-5 10,403' 10,407' 4' 1-11/16" 4 spf, 0 phase H-7 10,413' 10,432' 19' 1-11/16" Enerjet, 4spf, 0 phase H-12 10,709' 10,725' 16' 1-11/16" Enerjet, 2 spf, 0 phase H-8 10,564 ' 10,614' 50' 1-11/16" Enerjet, 6 spf, 90 phase H-I0 10,617' 10,632' 15' 1-11/16" Enerjet, 2 phase H-ll 10,674' 10,684' 10' 1-11/16" Enerjet, 180 phase H-13 10,764' 10,776' 12' 1-11/16" Pivot, 10 spf, 180 phase H-10 10,541 ' 10,564 ' 23' 1-1/16" HC, 4 spf, 0 phase H-9 10,502' 10,576' 74' 1-11/16" HC, 4 spf, 0 phase H-8 10,456' 10,480' 24' 1-11/16" 4 spf, 0 phase TD = 10,930' PBTD = 10,835" H-7 10,435' 10,443' 8' 1-11/16" 4 spf, 0 phase Max Hole Angle = 9.1 deg H-2 10,371 ' 10,386' 15' 1-11/16" Enerjet, 4 spf, 60 phase SRU 41A-08 Schematic.doc DRAWN BY: BCA REVISED: 6/18/07 RKB = 26.5' G-2 10,188' 10,193' 5' 1-11/16" Enerjet, 7.5 G-2 10,196' 10,209' 13' 1-11/16" Enetjet, 7.5 spf, 45 phase H-3 10,312' 10,328' 16' 1-11/16" Enerjet, 6 90 phase H-5 10,403 ' 10,407' 4' 1-11/16" EneJ.jet, 4 spf, 0 phase Perf 10,188' -10,193' H-7 10,413' 10,432' 19' 1-11/16" Enerjet, 4spf, 0 phase Proposed Perf 10,196'-10,209' H-12 10,709' 10,725' 16' 1-11/ 16" EneJ.jet, 2 o phase H-8 10,564 ' 10,614' 50' 1-11/16" Enerjet, 6 90 phase H-lO 10,617' 10,632 ' 15' 1-11/16" Enerjet, 2 spf,O phase H-ll 10,674' 10,684 ' 10' 1-11/16" Enerjet, 10 180 H-13 10,764' 10,776' 12' 1-11/16" Pivot, 10 spf, 180 phase H-lO 10,541 ' 10,564' 23' 1-1/16" HC, 4 spf, 0 phase TD = 10,930' PBTD = 10,835" H-9 10,502' 10,576' 74' 1-11/16" HC, 4 spf, 0 phase Max Hole Angle = 9.1 !leg H-8 10,456' 10,480' 24' 1-11/16" 4 spf, 0 phase SRU 41A-08 Propose Schematic.doc 11-3/4" 47# J-55 Jj" Surf 2022' 7" 29# N-80 6.184" Surf 290' T' 26# N-80 6.276" 290' 1219' 7" 23# N-80 6.366" 1219' 4952' 7" 26# N-80 6.276" 4952' 7" 23# N-80 6.366" 6617' T' 29# P-11O 6.184" 8427' 5" 18# L-80 4.276" 9456.8' 10,925..3' Tubing: 2-7/8" 6.40# L-80 2.441 " Surf 9277' 2-3/8" 4.60# N-80 1.995" 9277' 10,050' 1 2 3 4 5 6 7 8 9 10 Jj 12 13 4486' 5518' 6480' 7463' 8488' 9243' 9276' 9887' 10,038' 10,039' 10,050' 10,083 ' 10,114' Cameo MMG-P GLM Cameo MMG-P GLM Cameo MMG-P GLM Cameo MMG-P GLM Cameo MMG-P GLM Cameo MMG-P GLM 2-3/8"x2-7/8" Butt XO XA Sleeve 1.993" Locator sub w/seals HES BWD Packer 2-5/16"x2-3/8" Butt XO 1.875" HES "X" Nipple Wireline Re-entry Guide DRAWN BY: BCA 7/2/07 r-- STATE OF ALASKA ,'~ ALA, .. OIL AND GAS CONSERVATION COM\". _SION REPORT OF SUNDRY WELL OPERATIONS 3. Address: PO Box 196247, Anchorage, AK 99516 Operation Shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic D Perforate ~ Waiver U Stimulate 0 Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory 0 94-85 ServiceD 6. API Number: 50-133-10120-01 9. Well Name and Number: SCU 41A-08 10. Field/Pool(s): Swanson River/Hemlock Other U 1. Operations Abandon U Suspend U Performed: Alter Casing 0 Repair Well 0 Change Approved Program 0 Pull Tubing 0 2. Operator Union Oil Company of California Name: 7. KB Elevation (ft): 146.6' KB 8. Property Designation: Swanson River 11. Present Well Condition Summary: Total Depth measured 10,930' true vertical 10,920' feet feet Plugs (measured) Junk (measured) Effective Depth measured 10,835' true vertical 10,825' feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Size MD TVD Burst Collapse 3,070 psi 1,510 psi 7240 psi 5,410 psi 10,140 psi 10,490 psi 2015' 11-3/4" 2022' 2022' 9731' 1483' 7" 5" 9745' 10929' 9745' 10919' Perforation depth: Measured depth: 10403-10407,10413-10432,10435-10443, 10456-10480, 10502-10516, 10541-10564, 10617-10632,10674-10684,10709-10725,10764-10774 True Vertical depth: 10398-10402,10407-10426,10429-10437, 10450-10474, 10496-10510, 10534-10557, 10610-10624,10666-10676,10701-10716,10755-10765 Tubing: (size, grade, and measured depth) 2-7/8",6.4# @ 9,277'; 2-3/8", 4.6# @ 10,114' Packers and SSSV (type and measured depth) HES perf pkr@10,039' RECEIVED MAY 1 4 2004 k 0'1 & Gas Cons Commission Alas a I . Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 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 15 22 840 8 38 850 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 37 45 Tubing Pressure 190 220 13. Service 0 x GINJ D WINJ D WDSPL 0 SUndry Number or N/A if C.O. Exempt: Contact Steve Tyler 907-263-9649 Printed Name Philip J. Krueger Title Drilling Manager Signature ~/¡L~ Form 10-404 Revised 12/2003 Phone 907-276-7600 Date 5/10/2004 RBDMs BFL NAY 1 ., '~n~ Spud: 10 14 94 Completed: 11/9(94 Lost Workover: 1 /9/94 0.0 - 4ô.O' 20" 00 CSG 0.0 - 290.0' 7" 00 29.00llft "-80 PROO CSG ~ 290.0 - 1219.0' 7" 00 26.00l/fl N-æ PROD CS<; 0.0 - 2022.0' 11 3/4" 00 47.00l/ft J-55 5œF CSC 2022.0 - 2022.0' ~OE SCU 41A-8 Top of Hemlock: 1O2~O Ft. Swanson River Fjeld Angle @ Hemlock: 8 Oegs. API No.: 50-133-10120-01 Hanger: Shaffer 26.5 - 27.O'.waR Schaffer Hgr. 1219.0 - 4952.0' 7" 00 23.00l/ft N-80 PROD CSG ( ~952.Q - 6617.0' 7" 00 26.00#/ft N-8Q PROO CSC 7015.0 - 10m)' SrGCOOAR 6617.0 - 8427.ß' .,. 00 29.00f/ft N-80 PROD CSG 9«6.0 - 9456.8' IìEENlRY JOINT nw LG ræ Bock 9456.8 - 9460.5' HANGER mY HHP !/gr. &4-27.~'- $745:0'1' 00 29JIOllfl P-IIO PROD CSG'" 97«'0 - 9145.0'. SHOE 1o/2~/94r Wiled W'l1do'l 10039.6 - 10050.2' PACKER tE5 BWO PIer. l - , Gas un Oil Well Plugged 8<1ck SCU341-8 Redrilled 10/14/94 LostPerf'd 7/10/97 10789.0 - 1Q8J5.0' All 2/7/96 Sick-tine Tog 10835.0 - 10930.0' C[N[Nf PLI,K; 9456.8 - 10925.3' 5" OD 18.00l/n L-BO LIt£R 108B0.2 - 108821" FLCOlLAR T1W (l r' ì:t L ~ ì j ~ r ; _J - - : l' f , L ~ -; ... ; . W «86.2 - «94.8' GASLiFT VAlVE 11 COJTK;O MUC-P GlN 5517.9 - 5526.5' ('..\SUIT VAlVE 12 Cameo tilG-P GUl 6480.2 - 6488.8' GASUFf VN..Vf. J Cameo Mt.tG-P elM 7-463.1 - 7It11.7' CASlJT VAlVE #4 Cornea MMC-P GIJ,t 8488.1 - 8496.7' GASI.J1 VALVE 15 Comeo UMG-? GI.J.I 26.5 - 92772.' 2.815" 00 6.4O#/n l-80 roo 9234.1 - 924-2.7' OOlFT VAlVE 16 Comco MUG-P Q.,M 9216.6 - 9277.'1 CROSSOVER 2 3/8" J 2 1/8" 8TC 10050.0 - 10050.4' UUŒSJrJE 92711 - 10050ß' 2SJfl OD ..6O#/ft..N-8{) 1:BG 10038.6 - 10039.8' 3.256" 00 1.99.3" JD LOCATOR JOINT Stroi<jht Stat 9887.2 - 9890.3' 3.51" OD t.81S" II) ~ HES-$SÐ XA 10114.3 - 10115.0' 2.81." OD 1.99" 10 tAUl£SHOE tiC R&-Enlry QDde 1<Xro.2 - 10051.9' CROSSCfÆR 2 15/16" x 23/8" 8TC 10050.2 - 10114.3' 1375" 00 4.601Ift. N-8O TOG l00J9.8 - 10040.8' SfÞLS 10082.6 - 1008l9' 2.707" 00 1.815"10 INÐNG NIPPlE HES X 10312.0 - 10328.0' PEJfS H-3, 7/10/97. 6tfF, 16', Ilt/t6n Enecjet rev Guns. 90 Phos 10013.0 - 10407.0' PERFS H-6. 2/1/96. 4K'F, 4'. 1 11/16" Enerjet Guns, 0 Phase 10413.0 -10432.0' PERFS H-7. 2/1/9ô. 4HW, 19', 111/16" Enerjet Guns, 0 Phase 10709.0 - 10725.ß' PERfS H-12, 7/3/95.2tPF. 16', 1 11/16" Enerjet Qlns. 0 Phose 10564.0 - 10614.0' PERFS H-B, 7/10/97, afr. 50', 111/16" Enerjet retr Guns. 90 Phas 10611.0 - 10632.0' PERFS H-10. 7/14/95, 2HJf. 15', 1 11/16" Enerjet Guns, 0 Phase 10614.0 - 10684.0' PERFS H-11. 2/8/95, -4HPf, 10', 111/16" Pivot Guns, 180 Phose 10674.0 - 1œ84.0' PEffS H-11, 12/6/94. 5HPF. 10, I 11/16" fnerjel Guns, 0 Phase 10764.0 - (}174.5' PEIJS "-13, 12/6/94, 5HPF, 10.5' 1 11/16" Enerjet GIllS, 0 Phase 10764.0 - 10776.0' PæS H-I3, 11/10/94. ~PF, 12', 11/16" Pivot Cuns, 180 Phose - - - . - VJ¿, KB ElEV: 145.6' PSID: 10835' TD: 10030' r r ( l 2/12/04 SRU 41A-08 Operations Summary PJSM. Rigged up on well and pressure tested 50012500. Discussed conflict wI Anchorage between perf intervals and lithology shown on two versions of tie-in log. Resolved action. WIH with gun gamma/CCL and 15 foot gun to get new tie-in log. Sent electronic file to Anchorage for new perf intervals. Spotted gun per new depths and fired. Perforated 10,356 - 10,371 (15feet) using new tie-in log. Logged up and POOH. WIH wI reconfigured tool string. CCL only and 8 foot gun. Tied in wI prior tie-in log. Fired gun # 2 and perforated 10,338 -10,346 (8 feet). Logged up and POOH. WIH with CCL and 15 foot gun. Tied in wI marked line and collars. Fired gun # 3 and perforated 10,314 - 10,330 (16 feet). Logged up and POOH. WIH wI gun and CCL. Tied in. Fired gun # 4 and perforated 10,282 - 10,298 (16 feet). Logged up and POOH. Rigged off well. Laid down lubricator, BOPs, put cap on well, turned over to operations. SDFN PLAN: Will pick up SWS equipment and load out SWS tomorrow AM. Summary: Perforated the following per new tie-in log. Gun #1: 10,356-10,371 (15) Gun # 2: 10,338-10,346 (8) Gun # 3: 10,314-10,330 (16) Gun # 4: 10,282-10,298 (16) Unocal Alaska 909 W 9th Ave Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 Email: oudeand@unocal.com UNOCALi> "<~"'--Alaska Debra A Oudean G & G Technician February 26, 2004 DATA TRANSMITTAL To: From: Lisa Weepie Debra Oudean 333 W 7tn Ave, Suite 100 909 W. 9th Avenue AnchoraQe, AK 99501-3539 AnchoraQe, AK 99519-6247 AOGCC Unocal Alaska Transmitting as follows: COMPLETION RECORD SAFE 1.56 HSD PJ ..... ... . ...... . . . '" ..... . . PERF RECORD 111/16 POWER SPIRALS 7.5 SPF .. .. . . COMPLETION RECORD 111/16 POWER SPIRALS 7.5 !SPF .... . .. , COMPLETION RECORD 2 HSD 6 SPF POWERJET 60 5 INCH DEGREE PHASED ÇOMPLETION RECORD 2.5 HSD 6 SPF PJ COMPLETION RECORD 1.56 HSD PJ 6SPF IRESERYOIR'SATURATION T60L_SIGMA~O~E ' 'GAMMA RAY CCL 1.56 POWER JETS 1606 HMX RECEIVED FEB 2 7 2004 l~a8ka Oil & Gas Cons. Commision Þ¡ochorage of this transmittal or FAX to 907 263-7828. Date: ~~~~ ~ ~tA{~NED l~Ji~~~ 1 5 2004 \::;? \~~ fY\ ~ ~ Unocal Corporation '--' P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe Dan Williamson Drilling Manager Monday, March 27, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Soldotna Creek Unit Well SCU 41A-8 APl No. 50-133-10120-01 10-404 Perforate Hemlock bench Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the perforation of the H7, 8, 9 & 10 benches in well SCU 41A-8. The following intervals were perforated on 11/7/99: Bench Top Bottom Feet H7 10,435 10,443 8 H8 10,456 10,480 24 H9 10,502 10,516 14 H10 10,541 10,564 23 Total: 69 If you have any questions, please contact Ralph Holman at 263-7838. ORIGINAL RECEIVED 10 2000 AI~ Oil & Gas Cm~s. Commis~n Sincerely~ · Dan Williamson Drilling Manager STATE OF ALASKA '~ :' ALASKA O,,_ AND GAS CONSERVATION ~OMMISSION REPORT OF SUNDRY WELL OPERATIONS ,. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 146.6' KB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Soldotna Creek Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 470' FNL, 480' FWL, Sec. 9, T7N, R9W, SM SCU 41A-8 At top of productive interval 9. Permit number/approval number 441' FNL, 517' FEL, Sec. 8, T7N, R9W, SM 94-85 At effective depth 10. APl number 400' FNL, 517' FEL, Sec. 8, T7N, R9W, SM 50-133-10120-01 At total depth 11. Field/Pool 396' FNL, 603' FEL, Sec. 8, T7N, R9W, SM Swanson River/Hemlock 12. Present well condition summary Total depth: measured 10930 feet Plugs (measured) true vertical 10920 feet Effective depth: measured 10835 feet Junk (measured) true vertical 10825 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2015' 11-3/4" 1900 sx 2022' 2022' Intermediate Production 9731' 7" 1800 sx 9745' 9745' Liner 1483' 5" 250 sx 10929' 10919' Perforation depth: measured 10403-10407, 10413-10432, 10435-10443, 10456-10480, 10502-10516, 10541-10564, 10617-10632, 10674-10684, 10709-10725, 10764-10774 true vertical 10398-10402, 10407-10426, 10429-10437, 10450-10474, 10496-10510, 10534-10557, 10610-10624, 10666-10676, 10701-10716, 10755-10765 Tubing (size, grade, and measured depth) 2-7/8", 6.4# @ 9277'; 2-3/8", 4.6# @ 10114' Packers and SSSV (type and measured depth) HES Perf pkr.1003 , RECEIVED 13. Stimulation or cement squeeze summary ~p~ 10 2000 ,ntervalstreated (measured) 0 RIG IN A L Treatment description including volumes used and final pressure- AJ~c~0fal~ 14. Representative Daily Avera.qe Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 18 6616 9 1300 1100 Subsequent to operation 24 7183 9 1140 .. 1100 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Reportof Well Operations: Oil: /Y~ Gas: ' Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~/~. __ ¢'¢,, ,~ "/~ ~ Title: .~¢, //~///", Date: ~'/~ --,~-" ~ ~ r,,, Form 10-404 Rev 06/15/88 ,/ ,/ SUBMIT IN DUPLIC ,SeoJosi~:cai klal:er'~,!:~Js Inv~n?or'y DATA T DATA._PLUS " ..... 5 ~.~ 08 6336 9 ~. -.- 08 S C E I'd E N T ..9 i~..-. 0 ~:, '~ S L. rs, T/C N L. 9 ~ --- 0 ~.~ S ~,~ I.J D -.-~..-.- 08 S k1 U D 9~....0~'Sa PERF REr'r',RD~,~ ~975x'" --- 'i 092. 8. ~,',-~+ 00 -.. 10827 .~'~. 9'752 .... 10920 ~d'S'""~572 '-- 'i 0896 ~760~' 10930 ~ o ~ s 2 .-. -~ i 5 9 o ~105~8 .... i076a DI L/' LDT/CNL/,'S R Ar"e dr'y ci'i"Lch s,smpi:es r'equ'¥r'ed? yes ~Anci r"ece'~'ved?~t.s i~u, ~ W a s 'tz h e w e i i o o r' e d ?y e s ~ y s 'i' s ~.~:. d e s o r" -~ p't: '~' <:> n r' e c e ~ ',/e zs r', o . ..,, yes Rece:l' red'> ~..$.:, ~ · .. Well 'i'~s 5:n cornp'i'~'ar~ce ¥' .... ...~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: PeRorate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: x 146.6 KB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Soldotna Creek Unit 4. Location of well at surface 8. Well number 470' FNL, 460' FWL, Sec. 9, T7N, R9W, SM SCU 41A-8 At top of productive interval 9. Permit number/approval number 441'FNL, 517'FEL, Sec. 8, T7N, R9W, SM 0R , /'~, , ~. , .~ L 94-85 At effective depth i ii.."..,I: ~ 1_~ 10. APl number 50- 133-10120-01 At total depth 11. Field/Pool 396' FNL, 603' FEL, Sec. 8, T7N, R9W, SM Swanson RivedHemlock 12. Present well condition summary Total depth: measured 10930 feet Plugs (measured) true vertical 10920 feet Effective depth: measured 10835 feet Junk (measured) true vertical 10825 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2015' 11-3/4" 1900 sx 2022' Intermediate Production 9731' 7" 1800 sx 9745' Liner 1483' 5" 250 sx 10929' PeRoration depth: measured 10403-10407; 10413-10432; 10617-10632; 10674-10684; 10709-10725; 10764-10774.5 true vertical 10394-10398; 10404-10423; 10608-10632; 10665-10675; 10700-10716; 10755-10765.5 Tubing (size, grade, and measured depth) 2-7/8", 6.4~ @ 9277' 2-3/8", 4.6~ @ 10114' Packers and SSSV (type and measured depth) ! .'i:' i.'~' ::' i~, . HES Perm Packer @ 10039' !;%. i'_," 13. Stimulation or cement squeeze summary ~ r -~:'~ ,,.,,;.., ;..,. i;,) Intervals treated (measured) Treatment description including volumes used and final pressure ~:~'..!,.';.:~'i'.'_;~-: 01i ~ ii:'.:::.;; i";,.'.': ~:. ;".;', ~;i;:': 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1/20/96 70 26 18 825 200 Subsequent to operation 2/11/96 82 9830 13 1 400 1350 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: x Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: ,,-I .('"i/i ISigned: _]UN'~t"-L'~J~,~~"'~ Title: ~'~¢~.U...(i'-4Q\ ~~-"~('~"~-- Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Unocal Corporatior Oil & Gas Operations 909 West 9th Avenue, RO. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL March 4, 1996 Alaska Mr. David Johnston, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Commissioner Johnston: Re: Soldotna Creek Unit - Well SCU 41A-8 APl NUmber 50-133-10120-01 This is to inform you that on 2/7/96 Unocal perforated the following intervals in SCU 41A-8 in the Soldnotna Creek Unit: BENCH TOP (MD) BOTTOM (MD) FEET HB6 10,403 10,407 4 HB7 10,413 10,432 19 Total 23 Attachment Very truly yours, -. i i , /1 ,'.,-',, G. Russell Schmidt Drilling Manager ' '-,,. STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION R£PORT OF SUNDRY INI=LL OPFR TION$ Operations performed: Operation shutdown Stimulate Plugging .--.. Perforate Pull tubing After casing Repair well 5. Type of Well: Development Exploratory Stratigraphic Service Pull tubing Other 6. Datum elevation (DF or KB) 146.6 KB 7. Unit or Property name Soldotha Creek Unit 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 470' FNL, 480' FEL, Sec. 8. T7N, R9W, SM At top of productive interval '441' FNL, 517' FEL, Sec. 8, T7N, R9W, SM At effective depth ORIGINAL 10930 feet Plugs (measured) 10920 feet 8. Well number SCU 41A-8 9. Permit number 10. APl number 50-133-10120-01 11. Field/Pcol Swanson River/Hemlook At total depth . 396' FNL, 603' FEL, Sec. 8, T7N, R9W, SM 12. Present well condition summary Total depth: measured true vertical feet Effective depth: measured 10930 feet Junk (measured) true vertical 10920 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2015' 11-3/4" 1900 sx 2022' Intermediate Production 9731' 7" 1800 sx 9745' Liner 1483' 5" 250 sx 10929' Perforation depth: measured 10674-10684'; 10709-10725'; 10617-10632'; 10764-10776' true vertical 10608-10623'; '10665-10675; 10700-10716'; 10755-10767' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 2-7/8", 6.4~ @ 9277' 2-3/8" 4.6~ @ 10050' HES Perm Packer @ 10039' 13. Stimulation or cement squeeze summary Intervals treated (measured) Anchorage 14. Treatment description including volumes used and final pressure Pdor to well operation --Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data 83 W 116 24 875 208 656 40 825 Tubing Pressure 180 340 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby cerl~ that/~e~foregoing isle and correct to the best of my knowledge. Signed G. ® l . ~ Title Drilling Manager Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, RO. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL December 6, 1995 Alaska Ms. Joan Miller Statistical Technician Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Ms. Miller: Re: Soldotna Creek Unit - Well SCU 41A-8 APl Number 50-133-10120-01 This is to inform you that Unocal perforated the following intervals in SCU 41A-8 in the Soldotna Creek Unit: BENCH TOP (MD) BOTTOM (MD) FEET DATE HB 10 10617' 10632' 15' 7/14/95 HB 12 10709' 10725' 16' 7/3/95 TOTAL 31' Very truly yours, /-~ ; Candace Williams ~ ~ ~ ( ~/ ';:):. : ~ ...- .) . i' "" oj V VJ ~ \:) ~ ~ ... . """. - ",,/ o¥ .... STATE OF ALASKA AL gA OIL AND GAS CONSERVATION COk' '. ;SION REPOR'r OF SUNDRY WELL OI--i,-:RATIONS 1. Operations performed: Operation shutdown Pulltubing _ _ Alter casing__ 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 4. Location of well at surface 470' FNL, 480' FEL, Sec. 8, T7N, R9W, SM At top of productive interval 441' FNL, 517' FEL, Sec. 8, TTN, Rgw, SM At effective depth At total depth 396' FNL, 603' FEL, Sec. 8, T7N, Rgw, SM Stimulate X Plugging _ _ Perforate Repair well _ _ Pull tubing m -- -- Other X Coil Tubing Cleanout 5. Type of Well: Development X Exploratory __ Stratigraphic__ Service _ _ 6. Datum eleva~on (DF or KB) 145.6 KB 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 41A-8 feet 9. Permit number/approval number ~/,-.~" _ ,,~, 10. AJ=I ~umber ~ 4'/ 50-133-10120-01 11. Field/Pool Swanson River Field/Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2015' Intermediate 10,930' 10,920' 10,930' 10,920' feet Plugs (measured) feet feet Junk (measured) feet Size Cemented 11-3/4" 1900 sx Production 9731' 7" 1800 sx Liner 1483' 5" 250 sx Perforation depth: measured 10764'-10776'; 10674'- 10684' MD Measured depth 2022' 9745' 10,929 True vertical depth true vertical 10755'-10767'; 10665'- 10675' TVD Tubing (size, grade, and measured depth) 2-7/8", 6.4# @ 9277' 2-3/8", 4.6# @ 10050' Packers and SSSV (type and measured depth) HES Perm Packer @ 10039' 13. Stimulation or cement squeeze summary 14. Cleaned out fill to 10,777' (CTM) Intervals treated (measured) Inhibited Hemlock bench 11 -F/10,674'-10,864' w/10 bbls F 75 N foamer Acidized Hemlock bench 13 F/10,764'-10,776' w/8 bbls 7.5% HCl & 24 bbls HF. Treatment description including volumes used and final pressure 3600 psi @ 0.3 BPM w/foam @ HB11 2800 psi @ 1 BPM w/HCI @ HB 13, 2650 psi @ 1.08 BPM w/HF @ HB 13 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 118 91,000 5 Prior to well operation Subsequent to operation 89 64,000 11 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run__ I Daily Report of Well Operations x _ Oil x _ Gas __ Suspended _ _ ,7., hereby certify that the fc~(i~i~g. ~t~d~~ ct ,o the best of my knowledge. Signed G. Russell Schmidt M[j~,~.V..~/~-.~,,.¢,~..~% Title Drilling Manager Form 10-404 Rev 06/15/88 r --, Service Date 07/19/95 SUBMIT IN DUPLICATE SCU 41A-8 DAY 1 (06/01/95) COMMENCE OPERATIONS ON SCU 41A-8 AT 12:00 HRS ON 6/1/95. MIRU DOWELL COIL TUBING UNIT. DAY 2-3 (06/02-03/95) M/U MOTOR AND 1.8' MILL ASSY ON 1.5" CTU. RIH TAG PARRAFIN/ASPHALTENES AT 460' COULD NOT PASS. PUMP XYLENE SWEEPS AND CLEANED OUT TO 1667' FIRST GLM, TUBING CLEAR BELOW THAT. RIH TAG BOTTOM 10647'. CLEAN OUT WELL TO 10772' COULD CLEAN OUT NO FURTHER. POOH. BREAK DOWN INJECTOR HEAD TO L/D BHA. RIGHT FRONT OUT RIGGER OF CRANE BROKE WELL PAD CAUSING CRANE TIP TO FORWARD LAYING THE CRANE BOOM AND INJECTOR ON THE COIL TUBING REEL AND CAB. DAMAGE TO INJECTOR REEL AND CAB. THERE WERE NO INJURIES. SECURED WELL UP RIGHT CRANE. SUSPEND OPERATIONS ON 6/3/95 AT 17:00 HRS. DOWELL EQUIP. WILL BE SENT BACK TO TOWN ON 6/5/95 FOR REPAIRS. DAY 4 (06/04/95) R/D DOWN DOWELL SEND EQUIPMENT TO TOWN FOR REPAIR. DAY 5-6 (06/09-10/95) R/U REPAIRED DOWELL CTU. TEST bOP'S. RIH WNVASH NO77LE TO 10798'. SPOT 30 BBLS XYLENE LET SOAK CIRCULATE OUT SAME. PERFORM INJECTiViTY TEST W/LEASE WATER .6 BPM @ 3540 PSI. PERFORM ACID STIMULATION. PUMP N2 FOAM DiVERTER FOLLOWED BY 360 GAL. HCL FOLLOWED BY 840 GAL. MUD ACID FINAL INJECTION RATE 1.1 BPM @ 2650 PSI. KICK WELL OFF W/N2. RETURN TO PROD. POOH. R/D DOWN AND MOVE EQUIP. COMPLETED OPERATIONS @ 20:00 HRS ON 6/11/95. FINAL REPORT. Unocal Corporation P.O. Box 196247 Anchorage, AK 99519 (907) 263-7805 UNOr. Marie Vaughn Drilling Engineer PED Tuesday, July 18, 1995 Mr. Russ Douglas AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Douglas: Between June 1, 1995 and June 11, 1995 fill was cleaned out of Swanson River Field well SCU 41A-8 (AP! #50-133-10120-01) from 10,647'-10,650', 10,760'-10,761'; and 10,774'-10,777' CTM, and the following intervals were inhibited and acidized: Hemlock bench 11 from 10,674'-10,864' w/10 bbls F 75N foamer and Bench 13 from/10,764'- 10,776' w/8.8 bbs 7.5% HCi & 24 bbls HF. Production test before (6/08/95) 118 BOPD, 5 BWPD, 91 MMCFD. Production test after (6/20/95) 89 B©PD, 11 BWPD, 64 MMCFD. Sincerely, Made L. Vaughn MLV/leg Unocal Energy Res°urce~ l/ ' 909 West 9th, P.O. BOX 1~=~.,...-.. Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCAL · ' "Debra Childers "Clerk ; DATA TRANSMITTAL #6 Larry Grant '' 3001 Porcupine Anchorage,, AK 99501 Alaska Oil & Gas iii , ii From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal February 7, 1995 One blueline and sepia of the following Soldotna Creek Unit 41A-8 I Perforating Record Soldotna Creek Unit 41A-8 ! Cement Evaluation Log Swanson River Unit 34-15 Completion Record Tapes and listing RECEIV[D FEB 0 7 1995 ~,la§ka 011 & (~as Cons. C0mmissl~.n Anchorage Please acknowledge receipt by signing and,re_.tuming one ,c.~py of this transmittal or FAX to (907) 263-7828. Received by; Date: .... ~-~., STATE OF ALASKA -~-- ALASI' ilL AND GAS CONSERVATION COM~ J ;ION WELL COMPLETI(J OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS ~--~ SUSPENDED ~-~ ABANDONEDD SERVICE r-~ _ _ _ 2. Name of operator 7. Permit Number UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 94-85 3. Address 8..~PI Number P.O. BOX 196247 ANCHORAGE, AK 99519 .......................... ~ ........ / ~(~3~-.;1~1.20-01 4. Location of well at surface ;_-' {~,~;,i~, ~',~.~] , ~~ ~r~{~rf~~l~ J~[O~_ ~ '~Z?~~' 10. Well Number ' "~ "' ....... . .~:_~_.... ~ SOU 41A-8 ~'FNL, 517'FEL. Soc. O,~N, R9W, SM ; ~) ~ 11. Field .d Pool At To~ Dep~ ~ ............ . ~'~NL, 603' FEL, Sec. 8, ~N, Rgw, SM SWANSON RWER FIELD/HEMLOCK 5. Elevation in feet (indicate KB, DF, etc.)16.Le~e Designa~on ~d Seri~ No. 145.6 KB~ A-028~6 12. Date Spudded 13. Date T.D. Reached ~ 14. Date Comp., Susp. or ~d. ~ 15. Water Dep~, E o~hore ~ 16. No. of Completions 10/14/94 10/~/94J 11/~/94J N/A Feet MSLJ 1 17. Tot~ Dep~ (MD+~D) 18. Plug Back Dep~ (MD+~D) 19. Directional Su~ 20. Dep~ ~ere SSSVset J21. ~ickness of Per,rest 109~' MD/I~20'~D 108~' MD/1~26'~D YES ~ NO N/A feet MD N/A I 22. Type Electric or Other Logs Run DI~SF~CN~LDT/G R/SP/CBL 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. G~DE TOP ~ BOSOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 11 -3/4" 47~ J-55 15' 2022' 17-1/2" 1900 SX 0 7" 26-~ N-80 14' 9745' KOP 9-7/8" 1800 SX 0 5" 18~ L-80 9446' 10,~9' 6" 250 SX 0 24. Pedorafions open to Production (MD+~D of Top ~d Bo~om and ~25. TUBING RECORD inte~al, size and number) SIZE J DEPTH SET (MD) ~ PACER SET (MD) MD: 10,764'-10,776', 10,674'-10,684' 2-7/8" 6.4~ 9277' 2-3/8" 4.6" 100~' 100~' ~D: 10,755'- 10,767', 10,6~'- 10,675' 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) ~ AMOUNT & KIND OF MATERIAL USED NONE 27 PRODUCTION TEST Date First Production ~ Me~od of Operation (Flowing, g~ I~, etc.) 11/7/94~ G~ ~ Date of Test Hours Tested PRODUCTION FOF OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL ~TIO 12/27/94 24 TEST PERIOD 129 581 14 ---~ 4504 Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS- MCF WATER- BBL OIL G~VI~-API (cor0 Press. N/A N/A 24-HOUR ~TE 129 581 14 26 28. CORE DATA Br'o[ doscription o[ I,~holo~g, porosi~, [ractur~, app~ont dips and prosonco of o,I, ~ or wator. 8ubm,t ~r~h~ ~ ~ ~ ~ A~.ska 0~1 & Gas Cons. Commission Anch0r;. '~ Form 10-407 Submit in duplicate rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Hemlock Fm. 10240' 10236' NONE RECEIVED Aiaska/_}il & Gas Cons. Comm]ssion Anchor~ 31. LIST OF A'I-I'ACHMENTS Daily work summing, survey lisUng 32. , hereby(~~rel~j~~ correct to the best of my knowledge 19 Signed G. RUSSELLSCHMIDT TrUe DRILUNG MANAGER Date ~ _ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate 'none'. SCU 41A-8 CURRENT STATUS DECEMBER 5, 1994 11-3/4" ~ 2022' 2-7/8" GLM'S AS FOLLOWS: 1) 4486' 3) 6489' 4) 7472' 5) 8497' 6) 9243' 2-7/8" 6.4//L-80 TUBING 0-9,277' DV7015' TOP OF 5" LINER ~ 9,446' 2-3/8" X 2-7/8" XO ~ 9,277' 2-3/8" 4.6//L-80 BTC TUBING 9,277'-10,039' 7" 29# N-80 CASING 9745' (KOP) 5" lg# L-gO LINER ~ 10,929' TD ~ 10,930' "XA" SLEEVE @ 9,890' "BWD" PACKER ~ 10,039' "X" NIPPLE ~ 10,084' 2-3/8" TUBING TAIL ~ 10,115' H-11 PERFS 10,674'-10,684' H-13 PERFS 10,764'-10,776' PBTD 10,835' RECEIVED -2 1995 Alaska Oil & Gas Cons. Commission Anchor,--.., SRU 41A-8 DAY 0 (10/10/94) MI RIG AS A TURNKEY RIG MOVE. SRU 41A-8 DAY 0 (10/11/94) TURNKEY RIG MOVE DAY 2. SCU 41A-8 DAY 0 (10/12/94) TURNKEY RIG MOVE DAY 3. SCU 41A-8 DAY 0 (10/13/94) TURNKEY RIG MOVE DAY 4. SCU 41A-8 DAY 1-3 (10/14-16/94) ACCEPT RIG @ 18:00 HRS 10/14/94. INSTALL BPV. ND TREE & NU BOP. TEST SAME, OK. RU & RUN FREE PT. TBG FREE @ 10,005'. CUT TBG @ 10,005' W/NO SUCCESS. STUCK CUTTER IN HANGER ON TRIP OUT OF HOLE. JARRED FREE. ATTEMPTED SECOND CUT @ 9940'. CIRC WELL CLEAN. POOH LD TBG, INC. SCU 41A-8 DAY 4 (10/17/94) 10.2 PPG (WBM) FINISH LD 3-1/2" TBG. PU BIT & SCRAPER. RIH. TAG TBG STUB AT 9892'. CHANGE WELL OVER TO DRLG MUD DAY 5 (10/17/94) 9816' ETD (EZSV) 10.2 PPG (WBM) 7" ¢__. 9797' TEST CSG TO 3500 PSI, OK. POOH. RAN CET F/9890'-63~'~ ~./~/ SET BRIDGE PLUG @ 9816'. TIH W/WHIPSTOCK. 9799'/2' 10.2 PPG (WBM) 7" @ 9797' SET WHIPSTOCK ON BRIDGE PLUG @ 9816'. MADE STARTER MILL RUN F/9797'-9799'. TOH. MADE WINDOW MILL RUN. MILL NOT CUTTING, TOH. TIH W/STARTER MILL AND MILLED 9797'-9799'. SCU 41A-8 9760' ETD (PACKER) DAY 6 (10/20/94) 10.4 PPG (WBM) 7" @ 9760' TOH. PU WINDOW MILL AND TIH. ATTEMPT TO CUT WINDOW AT 9797', NO SUCCESS. TOH. 10,030'/270' DAY 8-10 (10/21-23/94) 10.4 PPG (WBM) 7" @ 9745' RAN & SET 7" WHIPSTOCK PACKER ON WIRELINE AT 9760'. TIH Wi#2 WHIPSTOCK. MILLED F/9745'-9749' W/STARTER MILL. TOH. TIH W/WINDOW MILL & MILLED F/9746'-9760'. TOH. TIH BIT #2 & WINDOW DRESSING ASSY. REAMED F/9745'-9760' & DRLD F/9760'- 9768'. TOH. CONDUCT BOP TEST. TIH W/BIT #3. DRLD F/9768'- 9770'. CONDUCT LOT. 14.9#/GAL EMW. DRLD F!9770'-10,030'. 10,030'/270' DAY 11 (10/24/94) 10.5 PPG (WBM) 7" @ 9745' DRILLED 6" HOLE FROM 10,030' TO 10,187'. POOH. TRIP FOR BIT. RIH. DRILL 6" HOLE FROM 10,187' TO 10,212'. 10,647'/435' DAY 12 (10/25/94) 10.5 PPG (WBM) 7" @ 9745' RECEIVED Gas Corn;. Cotn~'nission Anchor; DRLD FROM 10,212' TO 10,467'. 10,647'/435' DAY 13 (10/26/94) 10.5 PPG (WBM) 7" @ 9745' DRLD FROM 10,647' TO 10,930' (TD). CIRC BTMS UP. 10,930' TD DAY 15-17 (10/28-30/94) 10.5 PPG (WBM) 7"@ 9745' CONT RIH Wi5" LINER TO 10930'. CMT W/250 SX CMT & .3% HALAD & 344 & .2% CFR- 3 &.1% HR-5. BUMPED PLUG & RELEASED F/HANGER. TOH. CONDUCT WEEKLYBOP TEST. TIH WI6" CLEANOUT ASSBLY. TAGGED CMT @ 8908'. CLEAN OUT F/8908'- 9446' (TOL). TOH. TIH WI4-112" CLEANOUT ASSBLY. TAGGED CMT @ 10833' & CLEANED OUT TO 10,835'. TEST CSG TO 3000 PSI (OK). TOH. RU WIRELINE & RAN CET/CBT F/10,829'-9400'. RD WIRELINE. TIH TO 10,833'. 10,930' TD DAY 20 8.7 PPG (KCL) 7"@ 9745' TURNKEY RIG MOVE DAY 1. SCU 41A-8 10,930' TD DAY 20 8.7 PPG (KCL) 7"@ 9745' TURNKEY RIG MOVE DAY 2-4. DAY 18 (10/31/94) 8.7 PPG (KCL) 7"@ 9745' RECEIVED i" F' 13_ , _ r'~'.r~ ~'2 'i99{~ kb. ska 0ii & Gas Cons. Commission Anchor~ CHANGE WELL OVER TO 8.7 PPG KCL. TOH. LD DRILLPIPE. RU WIRELINE. RAN & SET PRODUCTION PACKER AT 10, 040' W/TAIL AT 10,115'. RD WIRELINE. CHANGE RAMS IN BOP. 10,930' TD DAY 19 (11101194) 8.7 PPG (KCL) 7"@ 9745' RIH W/2-3/8" X 2-7~8" COMPLETION TBG. STAB INTO PKR & TEST, OK. SPACE OUT& LAND IN HANGER. ND BOP. SCU 41A-8 10,930' TD DAY 20 ( 11/02/94) 8.7 PPG (KCL) 7"~___. 9745' ND BOP, NU TREE. SHIFT "XA" SLEEVE OPEN. CIRCULATE TUBING WITH LEASE CRUDE SPOTTING 9 BBLS ON BACKSIDE FOR FREEZE PROTECTION. SHIFT"XA" SLEEVE CLOSED. SET BPV. RELEASED RIG AT 1400 HRS 11/2/94. SCU 41A-8 10,930' TD DAY 21 8.7 PPG (KCL) 7"@ 9745' TURNKEY RIG MOVE DAY 6. RECEIVED /~!~.sJ',a. 0il & Oas Coris. Oornmi.ssion SCU 41A-8 10,930' TD DAY 21 8.7 PPG (KCL) 7"¢_, 9745' TURNKEY RIG MOVE DAY 5. 10,835 ETD DAY 21 7"@ 9745' D.C. $ 400,500 CUM: $ 932,089 AFE $ 1,332,589 AFE #742508 PERFORATE HEMLOCK H-13 AT 10,764 - 10,776 WITH 1-11/16" PIVOT GUN AT 4 JSPF. COSTS INCLUDE PERF, P&A, AND RIG MOVE. 10,835 ETD DAY 21 7"@ 9745' WELL WILL NOT PRODUCE ON GAS LIFT. SCU 41A-8 10,835 ETD DAY 21 7"@ 9745' 12/5/94: PERFORATE HEMLOCK H-11 F/10674'-10684' AT 6 JSPF W/1-11/16" 8 GRAM ENERJET STRIP GUNS PHASED AT 0 DEGREES. DAY 21 7"@ 9745' PUMPED 171 BO & 2 BW/24 HRS. SCU 41A-8 10,835 ETD DAY 21 7"@ 9745' U.O. 98.48643% DEV-OIL REDRIILL HEMLOCK PUMPED 145 BO & 0 BW/24 HRS. UNOCAL SCU 41A-8 41A-8 Slot #41A-8 Swanson River Unit Kenai, Alaska S U R V E Y L I S T I N G by Baker Hughes INTEQ Your ref : EMS <9928 - 10930'> Our ref : svy4513 License : Date printed : 1-Nov-94 Date created : 1-Nov-94 Last revised : 1-Nov-94 Field is centred on 0.000,0.000,0.00000,+ Structure is centred on 341760.000,2455540.000,0.00000,N Slot location is n60 43 5.891,w150 53 1.185 Slot Grid coordinates are N 2455540.000, E 341760.000 Slot local coordinates are 0.00 N 0.00 E Reference North is True North UNOCAL SURVEY LISTING Page 1 SCU 41A-8,41A-8 Your ref : EMS <9928 - 10930'> Swanson River Unit,Kenai, Alaska Last revised : i-Nov-94 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOFt Sect 9745.00 0.00 0.00 9745.00 0.00 N 0.00 E 0.00 9928.00 5.65 311.70 9927.70 6.00 N 6.73 W 3.09 10021.00 7.43 304.85 10020.10 12.48 N 15.08 W 2.09 10113.00 8.87 305.43 10111.16 19.99 N 25.75 ~ 1.57 10206.00 9.11 310.47 10203.02 28.93 N 37.19 W 0.88 0.00 Tie-In Pt (Ass~aed Vertical) 8.86 19.36 32.36 46.78 10297.00 8.88 309.16 10292.90 38.04 N 48.12 ~ 0.34 10340.00 8.38 303.34 10335.42 41.86 N 53.31 ~ 2.34 10482.00 8.05 297.25 10475.96 52.09 N 70.79 W 0.66 10574.00 7.85 292.00 10567.08 57.40 N 82.34 ~ 0.82 10667.00 7.55 291.87 10659.24 62.05 N 93.90 ~ 0.32 60.83 67.25 87.51 100.14 112.45 10761.00 7.04 290.71 10752.48 66.39 N 105.02 W 0.56 10853.00 6.41 293.35 10843.85 70.42 N 115.01 ~ 0.76 10930.00 6.41 293.35 10920.37 73.83 N 122.90 W 0.00 124.21 134.85 143.37 Projected Data - NO SURVEY All data is in feet unless otherwise stated Coordinates from Slot #41A-8 and TVD from RKB (162.00 Ft above mean sea level). Vertical section is from N 0.00 E 0.00 on azimuth 300.99 degrees. Declination is 0.00 degrees, Convergence is -0.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL SURVEY LISTING Page 2 SCU 41A-8,41A-8 Your ref : EMS <9928 - 10930'> Swanson R~ver Un~t,Kenai~ Alaska last revised : 1-Nov-94 Comments in wellpath MD TVD Rectangular Coords. Co~l~ent 9745.00 9745.00 0.00 N 0.00 E Tie-In Pt (Assumed Vertical) 10930.00 10920.37 73.83 N 122.90 W Projected Data - NO SURVEY Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised 41A-8 ST not specified 11162.00 2460041.09 308632.56W 17-May-94 All data ~s in feet un[ess otherwise stat~ Coordinates fv~ S~ot ~41A-8 a~ TVD fv~ RKB (162.00 Ft a~ve ~an sea [eve[). Bott~ hole distance is 143.37 on azi~th 300.~ de~vees fv~ ~e~[head. Ve~t~e~[ ~eet~on ~ fp~ N 0.00 E 0.00 on azi~th 300.~ degrees. Declination ~s 0.00 degrees, 6onvergence ~s -0.~ degrees. Calculation uses the ~in~ cuvvatu~e ~th~. P~esent~ by Bake~ ,u~hes INTE~ Unocal Energy Resourc~ ~ision Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNO .L Alaska TO: Larry Grant ALASKA OIL & GAS 3001 PORCUPINE DR ANCHORAGE, AK 99501 November 22, 1994 FROM: Debra Childers UNOCAL P.O. BOX 196247 ANCHORAGE, AK 99519 ~,~Transmitting one blueline and one sepia of the following Ivan River Unit 13-31 Dual Induction/Gamma Ray Compensated Densilog/Neutron/Garnma Ray / S°ld°tna Creek Unit 41A'8 Compensated Neutron/Litho-Density Dual Induction-SFL Mudlog Tape and listing Swanson River Unit 32A-15 Mudlog Please acknowledge reciept by signing and returning one copy of this document transmittal to the address listed above. Thank You. Alaska Oil & Gas Cons. Commissiol~' Anchorage MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David Joh~on, ' Chairm,,,~/ Blair Wondzell, ~ P. I. Supervisor /''f~ FROM: Doug Amos, ~ SUBJECT: Petroleum Inspebtor DATE: FILE NO: October 16, 1994 : a9shjobd.doc BOPE Test Nabors 154 Unocal SCU 41A-8 Swanson Rv. Field PTD No. 94-85 Friday, October 14, 1994: I traveled to Unocal's Swanson River Field, SCU 41A-8 well to witness the BOPE test on Nabors Rig No. 154. Saturday. October 15, 1994: Due to a longer than normal nipple up the test was delayed until 6:00 PM. As the attached BOPE test form indicates, there were no failures, however during the test the two way check valve in the tubing failed. The valve was pulled and replaced, this problem along with a malfunctioning test pump resulted in a test time of 8:00 hours. I found the rig and location in good condition. The drilling personnel were courteous, understood the test procedure and the operation of all their BOP Equipment. SUMMARY: Witnessed the successful BOPE Test at Unocal's Swanson Rv. SCU 41A-8 well on Nabors 154. 8 test hours 24 valves tested No failures Attachment: A9SHJOBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial X Workover: Nabors Rig No. 154 PTD# Unocal Rep.: SCU 41A-8 Rig Rep.: Set @ 10,813 Location: Sec. X Weekly Other DATE: 10/15/94 94-85 Rig Ph.# 283-5530 Shane Hauck Marvin Rogers 8 T. 7N R. 9W Meridian Seward Test MISC. INSPECTIONS: Quan. Pressure P/F Location Gen.: OK Well Sign OK 1 250/5000 Housekeeping: OK (Gen) Drl. Rig OK 1 250/5000 Reserve Pit N/A 1 250 / 5000 P 1 250 / 5000 P BOP STACK: Annular Preventer Upper Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F Test 1 250/3500 P Pressure 250 / 5000 1 250/5000 P I 250/5OOO P 1 250/5000 P 1 250/5000 P I 250/5000 P 2 250/5000 PIP N/A N/A N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Methane Gas Det. OK OK H2S Detectors N/A N/A CHOKE MANIFOLD: No. Valves 16 No. Flanges Manual Chokes 1 Hydraulic Chokes 2 I P/F P 38 250/5000 P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4@2100 3000 I P 1250 P minutes 35 sec. minutes 5 sec. X Remote: X Psig. Number of Failures 0 Test Time 8 Hours Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AC)GCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good Test. The long test time was due to a leak in the two way check valve in the tubing. The valve had to be pulled and repaired and restet during the test. The upper & lower kelly could not be tested until the tubing is pulled. Distribution: odg-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector FI-021L (Rev. 2/93) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: {JOBD.XLS Doug Amos ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 24,1994 G Russell Schmidt, Drlg Mgr Unocal P O Box 196247 Anchorage, AK 99519 Re: Well # Company Permit # Surf Loc- Btmhle Loc Soidotna Creek Unit 41A-8 Unocal 94-85 470'FNL, 480'FEL, Sec 8, T7N, R9W, SM Straight hole Dear Mr Schmidt: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-ddll does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. David W BY ORDER OF jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA -:-' ALASK )IL AND GAS CONSERVATION CC ' .vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill ~ 1 lb. Type of well. Exploratory ~; Stratigraphic Test ~ Development Oil Re-Entry [ Deepen []I Service [] Development Gas ~] Single Zone []-] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or K~) 10. Field and Pool Union Oil Company of California (UNOCAL) KB 134 feet Swanson River/Hemlock 3. Address 6. Property Designation I P.O. Box 196247, Anch~age, AK 99519 A-028996 4. Location of well at surface 7. Unit or property name 11. Type Bond (SE~ACC~.0~ 470' FNL, 480' FEL, Sec. 8, T7N, R9W, SM Soldotna Creek United Pacific Ins. Co. At top of productive interval 8. Well number Number Straight Hole SCU 41A-8 U62-9269 At total depth 9. Approximate spud date Amount Straight Hole August 5, 1994 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth property line 3600 feet 1200 feet 1120 11,000 feet 16. To be completed for deviated wells 17. Anticipated Pressure(.. ~AAC 25.035 (~)(~) Kickoff depth 10090 feet MaximLrn hole angle 3 * M~r. um =uric. 1947 psicj Atto'al depth ('I'VD) 11,000' psic. I 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (inciudestage data) 20" 31' 15' 15' 46' 46' Construction cmt 17-1/2" 11-3/4" 47# J55 S8R 2007' 15' 15' 2022' 2022' 1900 sx 9-7/8" ~ 7" 26-29 N80 ButtLT&C 10799' 14' 14' 10813' 10,813' Stcj1-700sxstg2-1100sx I Window at 10,050' 6" 5" 18# L80 BU'I-r 1300' 9700' 9700 11000' 11,000' 50 bbls ceme_nL 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary P~ E C E ~V ~ Total.depth: measured 10,814' feet Plugs (measured) None trueverticai 10,814' feet j~Ji~J ~ 7 Effective depth: measured 10,735' feet Junk (measured) Nonce.. true vertical 10,735' feet ,~.u,~,~_ -~," 0[I & Oas Cons. Commission Anch0ragr,.' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 31' 20" Constr. 46' 46' Surface Intermediate 2007' 11-3/4' 1900 sx 2022' 2022' Production 10799' 7" 1800 sx 1 0813' 1 0813' Liner Perforation depth: measured 10256'-10280'; 10288'-10370'; 103.90'-10465'; 10478'-10492'; 10512'-10572' true vertical Same 20. Attachments Filing fee [~ Property plat ~ BOP Sketch~ Diverter Sketch ~ Drilling program ~ Drilling fluid pr,~rar~_- . ...~ Time vs d@pth plot ['-] Refraction analysis ~ Seabed report r"] 20 AAC 25.050 requirements 21.1 hereby ck~.~g~ correct to the best of my knowledge Signed G. RUSSELL SCHMIDT Title DRILLING MANAGER Date 06/08/94 Commission Use Only Permit Number IAPI number Approval date ... (]f~ See cover letter .~. ~'//- <~.~ 50-/~,.7~--//0/,~--.-o-<::3 / G~ '~- Y-"~' for other requirements Cond,tior~s of approval Samples required ~ Yes ~ No Mud Icg required ['-] es -j~ No Hydrogen sulfide measures ~ Yes .~ No Directional survey required ~] Yes ~ No Required workingpressurefor BOPE [-] 2Mi ~ 3Mi [~ 5Mi ~ 10Mi [-] 15M Other: Original Signea By by the order of Approved by David W. Johnston Commissioner the commission Date ¢;/~. Form 10-401 Rev. 12-1-85 Submit in ~licatb Swanson River Well SCU 41A-8 Rough Redrill Procedure May 18, 1994 1. Rig up slick line and run a guage ring to 10,099'. 2. Install BPV, move in the drilling rig 3. Remove the tree, install and test the 13-5/8" BOPE. 4. Put the tubing in tension, rig up wireline, run a free point. Cut the tubing as low as possible in the 3-1/2" tubing (assume 10,090'). 5. Pull and lay down the tubing. 6. Pick up drill pipe while RIH with a bit and 7" casing scraper to 10,090'. 7. Run a CBL and casing inspection log. CBL log from 10,090' to 9000' and casing inspection log to surface. Note: an old CBL log shows TOC at 8960'. 8. RIH and set a bottom trip whipstock, orientation is not needed. Perform the milling operations (three trips). 9. Drill 6" hole to a TVD of 10,895' plus the needed ratholeo This would have been a deepening operation if the wellbore mechanics had allowed. Directional concerns should be to get the well back to vertical after a minimum stepout in any direction. 10. Log the 6" hole section. 11 Run and cement 5" 15~ L-80 butt thread liner with a liner top packer and seal bore. 12. Pick up a bit and 7" casing scraper, clean out to the liner top at +/- 9,700'. 13. Pick up 2-7/8" drill pipe, a bit and 5" casing scraper, and clean out the 5" casing. 14. Change over to brine. 15. POOH. Run a CBL log with 1000 psi held on the casing. 16. RIH with the drill pipe and POOH laying down. 17. Pick up and run a 2-3/8" x 5" packer, 2-3/8" and 2-7/8" tbg, and gas lift equipment with the tail set above the top zone of interest. RECEIVED JU[q 17 ]994 Ai~sk~ 0il & 6as Cons. Commission Anchorage 18. Install BPV's, remove the BOPE, install the tree and test to 5000 psi. 19. Rig down and move the rig out. 20. Install the production lines 21. Achieve drawdown with gas lift and perforate the zones from the bottom up with 1-11/16" strip guns. Test each zone after it is perforated. RECEIVED diJi~,~ '1 7 i994 Oil & Gas Cons. Commission Anchorag .¢., SCU 341-8 Current Status Spud June 1961 KB= 15' 11-3/4' @ 2022' DV @ 7015' TOC in annulus calc @ 10,710' 7' @ 10,813' 'T'D @ 10,814' X0 3-1/2' EUE 8RD to 3-1/2' CS HYDRIL at 8860' XO 3-1/3' CS HYDRIL to 2-7/8' EUE 8RD at 10,099' OTIS "S' profile at 10,131' OTIS 'XA' Sleeve at 10,164' Baker "FI-i' packer at 10,199' Camco 'MM' man~lrei at 10,237' H-1 Zone perforations from 10,256'-280' Brown HS-16-1 packer at 10,281 Camco 'MM' Mandrel at 10,318' H3, H4 & H5 zone perforations from 10,288-10,370' Brown HS-16-1 packer at 10,375' OTIS 'S' profile at 10,381' H-8 perforations from 10,390'-465' Camco 'MM- manclrel at 10,414' H-9 perforations from 10,478'-492' Baker "F' packer at 10,499' Camco 'D' profile at 10,504' H-lO Zone perforations from 10,512'-572' RECEIVED ETD at 10,735' jUN '1 7 '1994 Oil & 6as Cons. Commission Anchorage GRB 5-18-94 SCU 341-8 Spud June 1961 Proposed Hemiock Abandonment KB= 15' 11-3/4' @ 2022' OV @ 7015' 2-7/8" Cement retainer at 10,11 Tubing perm at 10,190' Tubing perfs at 10,215' 2-7/8' Cement retainer at 10,220' Tubing perm at 10,275' Tubing perM at 10,290' 2-7/8' Cement retainer at 10,295' Tubing perm at 10,370' Tubing perm at 10,3,90' 2-7f8' Cement retainer at 10,395' Tubing perm mt 10,495' 2.7/8' Cement retainer at 10,550' 7' @ lO,813' TD @ 10,814' X0 3-1/2" EUE 8RD to 3-1/2" CS HYDRIL at 8860' XO 3-1/3" CS HYDRIL to 2-7/8" EUE 8RD at 10,099' OTIS 'S' profile at 10,131' OTIS 'XA' Sleeve at 10,164' Baker 'FI-I' paci(er at 10,199' Camco 'MM' manctrel at 10,237' H-1 Zone perforations from 10,258'-280' Brown HS-16-1 packer at 10,281 Cat~3o 'MM' Mandrel at 10,318' H3, H4 & H5 zone perforations from 10,288-10,370~ Brown HS-16-1 pacJ<er at 10,375' O1~ profile at 10,381' H-813edera~ from 10,390'-465' Camco "MM' m~ at 10,414' H-g perforations from 10,478'-492' Baker "F' pac~er at 10,499' Camco 'D' profile at 10,504' H.10 Zone perforations from 10,512'-572' Tubing tail at 10,567' ETD at 10,735' ECE!VED JUN ] 7 '~994, 0il & 6as Cons, Commission GRB 5-18-94 Anchorag~ SCU 41A-8 Proposed Hemlock Completion 11-3/4" @ 2O22' OV @ 7015' KB= 15' 2-7/8" 6.4# L-80 Butt tubing Side pocZet GLM's Uner hanger with liner top packer at 9700' 7' Window at 10,050' 2-3/8" 4.6# L-80 tubing 5" stab in packer at 11,200' "X" type profile below the packer 5" 18# Butt casing RECEIVED JUi~ I ¥ i974 Gas Cor~s. Commission A_nchora,g¢ TD at 11,000' GRB 5-19-94- SWANSON RIVER WELL ~ 41A-8 REDRILL Anticipated Pressures for the 6,, hole section Mud weight = 9.3 ppg = 0.484 psi/ft 7" window is proposed to be at 10,050'MD, 10,050' TVD Total Depth of the 6" hole is 11,000' MD, 11,000' TVD Estimated Fracture gradient at the window = 0.9 psi/ft Pore Pressure Gradient = 0.458 psi/ft Gas Gradient (assume worst case) = 0.0 psi/ft Kick intensity and tYPe: Assume a 30 bbl gas entry at TD (worst case) Assume a kick intensity of 1 ppg Circulate the gas entry out using the drillers method Assume no gas entering into solution with the mud 3-1/2" drill pipe x 7" casing annulus = 0.0252 bbl/ft Gas pressure upon entry = 11,000' ((.458 + 1 (.052)) = 5,610 psi The shoe will not break down as the fracture pressure at the shoe is 0.9 psi/ft x 10,050' = 9454 psi Assume the temperature of the gas remains constant thus: PV = P'V' P = 5,610 psi V = 30 bbls By trial and error keeping the BHP constant at 5,610 psi P' = 1947 psi V' =-86 bbls AS a check calc BHP from the surface: Surface Pressure + Gas Column + Mud Column = BHP Gas Column = 86 bbl/0.0252 = 3413' Mud Column = 11,000' TVD - 3413' = 7587' Surface Pressure =- 1947 psi 3413' * 0 psi/ft = 0 psi 7587' * .484 psi/ft = 3672 psi 5619 psi The BHP was kept just above the pore pressure meaning P' and V' were calculated properly. Maximum Surface Pressure = 1947 psi at 11,000' TVD Oas Oons. 6ommission SWANSON RIVER WELL SCU 41A-8 MUD TYPE: PHPA Polymer system Weight: 9.1 - 9.3 ppg Funnel Viscosity: 40-50 Sec/Qt Plastic Viscosity: 15-20 Yield Point: 10-15 #/100 cuft pH: 9.0 - 9.6 API filtrate < 6 cc 33-5 43~--~ 43-5 ~/~7 /,927 (,.~, .~, ~,e, ,o ) ,~ l l SZo' 314-4 37,7/vN ., 3'// (/-3, 3~-9 ~/0. 0 .~,377 (~-~, ~-/o~ ",~ow~ 323-4 7,7 + (/-d, ~-/o3 "10745 321-9 ,~ 7, ~/v/,/ + 34-4 ~,o~ $,I, o, · 24A-9 (~-~. ~ 11030 LEGEND SWANSON RIVER FIELD PRODUCTION DATA MAP CUM. PROD. - MBBLS HEMLOCK ZONES PRODUCING WELL BO + BW + MCFD 4,576 (~-S,8,~0) 193 + 56 + 3,944 JUN ,., .-.,,,~ [~it & Gas Cons. Commission Anchorage -. ~ '~ontract OPTION I Exhibit E FILL-UP FLOW .mNNULAR BOP i 0" 3000 PIPE RAMS 10" 5000 psi BMND RAMS 10" 5000 psi ~-- ~ DPjI.rJNG I ~'~ KILL ~ SPOOL - -'-~ ~o' 5000 p-~,~~~)~ CHOKE LINE 3" 5000 psi ! !, 3" 5000 psi I 10" 5000 I BOP STACK 10" 5000 psi ,,:.~ ..... , & Cas Oons, Commis$io~ Anchorago !C~ontract OPTION 2 Exhibit FILL- ;.UP FLOW ~> =NNULAR SOP 13~,73000 Fsi PIPE RAMS i ~ 3%" 5000 ~ BLIND RAMS ; , 135/~" 5000 psZ _ I ! DRII.I,fNGt KILL ~ ~POOL 3" 5000 psi }! [ 3" 5000 psi PIPE RAMS j 135/8"5000 psi ,' BOP S,TACK 13%" 5000 psi Items A & B are remote actuated chokes. Al. 1 items are rated t~ 10,000 psi ~ ? ' ' ' ~ 7~(ZZZZZ. Z."Z,,'.,'. ':'.'~'. '. ', '. '. '.'. ', '.' '.,' Active Mud System l,Tl ,5 l) l) , [1 ]#1 ,,, ,,, I"'"'l JILl, ['ll $[}{ [I{)N - 72 lll}l, Il: 20() llill, .lllll]l,/IN¢:ll H z'.;:l'llll,/IN{:ii /' 7-~'-r ///////// ~'~.,'-'~. -,r;,-- TT~'~7'T////////////////rV'7--,r]r'~-7 [-,, 312' l ............................................................ 442' ............................................................ VOIAJME PIT 4.37 BBI, 5.OBBL/INCI! b'ANI) / . TOTAL IJSAilI,E VOI,IJME .- 1001 II111, - 11.7 IlIli,/IN{;li Unocal Energy Resourc~'-"-~ivision Unocal Corporation ~ 909 West 9th Avenue, P.O. b~,_x 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 Facsimile 263-7698 UNOCAL June 15, 1994 Kevin A. Tablet Land Manager Alaska Mr. David W. Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 SCU 41A-8 Application for Permit to Drill Dear Mr. Johnston: Enclosed please find, in triplicate, Union Oil Company of California's application for Permit to Drill for Soldotna Creek Unit Well No. 41A-8. We also enclose a check in the amount of $100.00 to cover the application fee. We note that the proposed location of this redrill is in a quarter section which currently has two abandoned wells; therefore the spacing acreage as governed by Conservation Order No. 123 is not affected by our proposed redrill. Please contact Mr. George Buck at 263-7865 upon your approval or if there are any questions. Very truly yours, . Elizabeth A.R. Shepherd Project Landman RECEIVED dU~ ~ ? 1994 Alaska 0il & 8as Cons. Commission Anchorage ,. ~. STATE OF ALASKA .... ALA~ OIL AND GAS CONSERVATION COMMK )N APPLICA' FOR SUNDRY APPROVALS 1. Type of request: Abandon X Suspend Operations shutdown Alter casing__ Repair wel! __ Plugging __ Change approved program . .. Pull tubing __ Variance 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 Location of well at surface 470' FNL, 480' FEL, Sec. 8, 'ITN, R9W, SM At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole 15. Type of Well: I Development X_ [ Exploratory c %~/JUN ~ 7 1994 Gas Cons. C0mmiss~0. Re-enter suspended well Tirne extension Stimulate Perforate Other 6. Datum elevation (DF or KB) KB 134 7. Unit or Property name Soldotna Creek 8. Well number SCU 341-8 9. Permit number 10. APl number 50-133-10120-00 11. Field/Pool Swanson River/Hemlock feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate ProduclJon Liner Perforation depth: 10,814' feet 10,814' feet 10,735' feet 10,735' feet Plugs (measured) PS plug 10,381' Junk (measured) None Length Size Cemented Measured depth True vertical depth 31' 20" Constr. Cmt 46' 46' 2007' 11-3/4" 1900 sx 2022' 2022' 10,798' 7" Stage 1-700 sx 10,813' Stage 24100 sx measured 10256'-10280', 10288'-10370', 10390'-10465', 10478'-10492', 10512'-10572' 10,813' true vertical 10256'-10280', 10288'-10370', 10390'-10465', 10478'-10492', 10512'-10572' ? Tubing (size, grade, and measured depth) 3-1/2", NS0 to 10099' and 2-7/8" NS0 to 10567' Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal_ _ Detailed operations program_ x BOP sketch x_ 14. Estimated date for commencing operation July 15, 1994 16. If proposal was verbally approved Date approved 15' Status of well classification as: Oil _ _ Gas __ Suspended _x Name, of approver Service 17. I here~Ic¢~t~ f~e~~nd correct to the best of my knowledge. Signed G. Russell Schmidt Title Drilling Manager ?~te 06/09/94 FOR COMMISSION USE ONLY Conditions of approval: NoUfy Commission so representative may witness Plug Integrity __ BOP Test __ Location clearance __ ,/ Mechanical Integrity Test__ Subsequent form required 10- Approved by the order of the Commission Form 10-403 Rev 06/15/88 Commissioner Date SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST ~EOL ~ ~o uN~# PROGRAM: exp [] dev [] redrll~ serv [] ADMINISTRATION 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number ............... 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ...... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ......... 9. Operator only affected party .............. 10. Operator has appropriate bond in force ........ 11. Permit can be issued without conservation order. 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... .,-,,,_-A-Z/,. Z ENGINEERING APPR 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................ Y N7 Surface casing protects all known USDWs ......... Y CMT vol adequate to circulate on conductor & surf csg.. Y CMT vol adequate to tie-in long string to surf csg' . . . Y CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............. ~ N If a re-drill, has a 10-403 for abndnmnt been approved..Y N Adequate wellbore separation proposed .......... Y~ N If diverter required, is it adequate ........... ¥ ~ ~.~. Drilling fluid program schematic & equip list adequate .~ N BOPEs adequate ..................... ~ N BOPE press ~ating adequate; test to ~di~ psig. N Choke manifold complies w/API RP-53 (May 84) ....... Y~---4~-~ Work will occur without operation shutdown ....... ~ N Is presence of H2S gas probable ............. Y ~ GEOLOGY ,%PPR D TE 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/~ 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ......... /Y N 34. Contact name/phone for weekly progress reports . . . /. Y N [exploratory only] GEOLOGY: ENGINEERIN~: COMMISSION: Comments/Instructions: z · '"'ORMS~cheklist rev 03/94 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simp!ify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. RECEIVED FEE~ 0 ? !995 Oil & Gas Cons, Commission Anchorage GeoQuest *O?EN HOLE gDIT* WBLL: SCU41A-8 FIELD: SWANSON RIVER API tt50-133-10120-01 CO~fl?ANY: UNOOAL OO~{ENTS: DIL/LDT/CNL/GR ONTY: KENAI STATE: ALASKA LOG: 00T-27-1994 TAPE: 28-00T-94 1600 BPI KB ELE¥: 160.6 RUN #: ONE START: 10928 STOP: 9752 JOB #: erif icat.lo~ L] sotino AlasKa computino center 2~-OCT-1994 1! :23 SERviCE N~ D~TF : 04/10/~7 O~IGI~ R~E[. NA~E : 599555 CONTINUATION ~ : nO P~EvIOU$ PEEL PA~E: **** TAPE HE~DPR **** SERVICE MA~ : I, DT15 DaT~' : 94/lO/27 O~I~IN : CSU T~PF ~A~E ': 599555 CONTINUATIOn! ~ ! O0 P~EVIOU$ ~APE : CO~ENT : SC~;LUMBERGFR ~ELL SERVICES CSU TAPE SfRVlCE : PLaY ¥~R~ION : 40.2 DATE : 94/1o/27 ~AX REC SIZE : ~0~4, F~L~ TYPE : P~ L~S? PILE : DATA FOR~A~' SPECIFICATIt]M ~ECO~D ** ** SET 'TYPE - 64E~ ** TYPE R~P~ CODE mm~mmmmmmm~mmmmmmmmmmm:mmm~mmmm 1. 66 2 66 0 3 v9 98 4 66 5 66 6 73 7 65 INCH 8 73 60 9 65 lin ].!. 66 i~ 68 I4 ~5 .lIN 16 66 0 66 0 mmmmmmmmmm#mmm~mmmmm#mmmmmmm~m AlasKa Computlna Center TE L? SS PE RW D~ DP CF CN T~ ** SET TYPE - C~)AN ** ID QRDEP ~ bOG TYPE CL~SS mmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmm L,T TOW I~~ 07 2~0 O! 0 5 TO~) CPS 07 354 Ol 0 5 TOw CPS 07 354 01 o 5 WO~ C~$ 07 354 O1 m 5 Tw TOt, CPS 07 354 O1 n K 1 TO~ CPS 07 354 02 0 5 2 TOw CPS 07 354 02 0 5 f TO~ O~ 3~8 Ol 0 5 O~ TU~4 G/C] 07 350 02 0 5 Hn ~Oq G/C3 07 356 01 o 5 H? TOW V/V 07 890 O1 0 5 Ra TOW 07 470 01 0 5 TC TOW CPS 07 420 Ol 0 5 TC TO~! CPS 07 4~O 01 0 5 PW TOg V/V 07 890 O0 0 5 NDOD TOg V/V 07 890 00 0 5 NPHI TO~4 V/V O? 890 00 0 5 RFOC TOH V 07 000 O0 0 5 IFRF TO- 07 000 O0 0 5 CIDP TOW MM/~ 07 1!0 4.6 0 5 CI~P TO~ ~/~ 07 1~0 44 0 5 IDPg TOg OHM~ 07 1~0 46 0 5 I~P~ TOg O~M~ 07 1~0 44 0 5 IIR~ ~Og ~/u 07 000 o0 0 5 'IIXD TOW ~/~ 07 000 00 0 5 IIR~ TOW M~/. 07 000 00 0 5 IIX~ TO~ M~/~ 07 000 00 0 5 CILD ~Og MM/~ 07 1!0 46 0 5 CIL~ TOg M~/~ 07 !~0 44 0 5 iLO TO~ OgMu 07 I~0 46 0 5 IL~ TO),{ OwM~ 07 120 44 0 5 CSF!, TO)~ N~/~ 07 2~0 01 0 5 SWLU ?Og 0~ 07 2~0 O! 0 ~ G~ TO!,~ GAPI 07 3~0 O1 0 5 HTEW TO~ LBF 07 000 O0 0 5 ~RE$ TO~ O~!~ 07 0o0 00 0 5 MTE~ TOW D~GC 07 000 00 O 5 SD TOg MV ~7 0~0 01 0 5 DATA ** ** D~PTH = 10980.000 FEET ** TENS.TO~ '4065.000 CALI~.TO~ ~.799 b$.TOw 645.500 LITH.TOH PEW.TOw ~6,672 RHOB,TOH ~.~i9 TNR~.TOg 1.591 CFTC.TOH 3~02.220 m~m~MmNmmmmmmmmmmmmmmmmmmmmmmmmmmmm NUmB NUmB SIZE REPR PROCESS ..limb SA~P Et~E~. . CODE: .LH~X) i I 4 6a 8000000000 1 1 2 49 8400000000 1 1 2 49 800~000000 ~ I 2 49 8000000000 1 t 2 4q 8000000000 1 1 2 40 800000000~ 1 1 2 40 ~0.00000000 1 1 2 49 ~000000000 ! 1 2 49 8402040000 1 1 4 6~ 8~02040000 1 1 4 68 8~00000000 t 1 4 68 8402040000 I 1 4 68 8442000000 1 I 4 6~ 8~00000400 1 1 4 68 8~00000400 1 1 4 68 8242000400 1 1 4 6~ 824~0n0400 1 1 4 68 8242000000 I 1 2 49 8000020000 . 1 1 2 79 8000000000 t 1 2 49 8000000000 1 1 2 40 8000000000 1 I 2 49 8000000000 1 1 2 49 8000000000 1 1 2 49 8000000000 1 i 2 40 8000000000 1 1 2 49 8000000000 1 1 2 49 8000000000 1 1 2 49 8000000000 1 I 2 49 8000000000 1 1 2 49 8000000000 ! ! 2 49 8000000000 1 I 2 49 8000000000 1 1 2 49 8000000000 1 I 2 49 8400000000 1 1 2 49 8000000000 1 1 2 49 8000000000 1 1 2 49 8000000000 LL.TOH 332.250 SSI.TOM 305.500 SSO.TOH DRI;O.TOH 0.100 DPHI.TO~ CNTC,TOH 599.4.464 626.500 434.750 0.322 0.151 ~erlflcatio~ List,.no crger AlasK, a Computing Center NPO~.TOH 0.151 gPMI.TO~] CIDD.TOP 5~2.500 ClgP.TPg I~RD.TOU 433.5~0 IIXD.TOH C!Ln.TO~ 547.500 CILM.TOH CSFL.TO~ ~.000 SFLU.TOH ~PE~.T0g 0.5~9 UTE~.TOH ~, D~pmH = ~0730.000 FEET TFN,~. TOM ~755. 000 CAf,I. i,$. TON 1902. 000 f, [TH. TOg PEw. wO~ ~ 7.2 ~ PdOb. T~RA.TOP 5.0~4 NDOP.TO~ 0.7a7 5~Pgl .TOH. CIDP.TU~ ~ 7.1 ~5 CIuP. I~R~. TO~ ~ 5. 500 I I ~O. CSFf,.TOH 0.635 ,~FLU.TOH gRES. TUP 0.551 ~TE*~. TOH 28-0CT-1994 I~ :23 0.~St ~FOC.TOH 375.500 !DPi'I.TDH 6~.156 TIPM.TOH 376.K00 ILD.TOH 2.617 GR.TOH ~.875 SP.T~H I O. 293 LL. TOH 78¢.00n S$:1 .TOH '23.147_. CNTC.TOH 0.697 ~FOC.TOH 23.o..1,6 .TD~>H.TOH -0.964 ~ IP~4. Tt?H 19. ]44. J.I.,D. T~H 574. 000 G~.TOH 71. J. 88 SP.TOH **** FTLF TRAILE~ F!L~ NA~E : TO}I .005 VERSION : 40.2 D~Tw : o4/10/27 ~X R~C S!Z~ : ~0~4 FIL~ TYPE ! PR **** FIL~ NEADER **** SFRVICE : PL~Y VFRglO~i : 40.2 D~T~ ~ 0411n/~7 M~X REC s]'g~ : 1094 FILE TYPE ~ PR ** DATA FORgAT SPECIF!C~TIUN ~ECU~D ** SET TYPE - 64EB ** ---; ...... ................. TY E R CODE V~LI!E 1 ¢6 2 66 0 0.!89 1.917 350.000 !.826 97.P75 1.6.391 996.n00 ~58.75o -0.05? 1516.472 0.683 59.344 18.42~ 43.781. !06.875 tFRE.TL]N I~PH.TUM I?X~.TOH !L~.TOH bU.TOM IJDHI.TUH IFRE.TO~'! I~PH.T0~ IT×".TO~ ~0 2.660 ~6.8~8 2.654 -327.500 1.993.000 400.250 0.7qO 0.703 2O 43.406 1.902 51.656 999.000 .got AlasKa ,Comp~tf, no Center T~N'~ T N CAbI bU TON $S1 TO~! $$2 R~OP TOH D~HO TOH T~RA CWTC C~TC N~O~ RVOC IFR? ~O~ C!DP TO~ CIMP IDP~ I~Pg TON I~RD TOg IIR~ TOg IIX~ CILD TO~ ILD ~0~ 3 79 4 66 1 5 66 1 6 73 -5~8 7 65 INCH 8 73 60 9 65 ,lin I.~ 66 10 1~ 68 1~ 66 1~ 65 .lin lS 66 73 0 66 ** ORDE~ ~ bOG TYPE CLASS NOD II~ImIIIlI[~IIIII[IIIIIII[~iiIIIiliIiItiI CPS CPS CPS CPS CPS G/C3 G/C3 V/V CPS CPS V/V V'!V V/V V ~ 1 4 6~ 07 2~0 O1 0 6 1 1 2 49 07 354 O1 0 6 1 i 2 4O 07 354 O! 0 6 1 1 2 40 07 354 O1 0 6 1 i 2 4g 07 354 Ol 0 6 1 I 2 49 07 354 02 O ~ I ! 2 49 07 354 o2 0 6 1 1 2 49 07 358 Ol 0 6 1 ! 2 49 07 350 02 0 6 1 1 4 6~ 07 356 nl 0 fi I ! 4 6~ 07 890 O1 0 6 1 1 4 6~ 07 4~0 O1 0 6 I 1 4 68 07 4~0 Ol n 6 1 i 4 68 07 4~0 Ol 0 6 1 I 4 :68 07 890 O0 0 6 1 1 4 68 07 890 O0 0 6 1 I 4 6~ 07 800 O0 0 6 1 1 4 68 OV 000 00 0 6 1 1 2 49 07 OOO O0 0 6 1 1 2 79 07 110 4-6 0 6 1 1 2 49 07 110 44 0 6 1 I 2 49 07 120 46 0 6 I 1 2 49 07 190 44 0 6 1 1 2 49 07 00.0 O0 0 6 I 1 2 49 07 000 O0 0 6 1 I 2 49 07 000 O0 0 6 1 1 2 .49 07 000 O0 0 6 1 i 2 49 07 110 46 0 6 1 1 2 49 07 ll, O ~4 0 6 1 1 2 49 07 1~0 46 0 6 I i 2 49 MMtN OWMM M~I~ OHM~ ! ~mi! ODE (HFX) 8000000000 8400000000 8nOOOOOnOO 8000000000 8000000000 8000000000 8000000000 800000000O 8~0704,0000 8202040000 820O000000 840~040000 8~4~000000 8~00000400 8800000400 8242000400 B~4~000400 8~42000000 80000~0000 8oooooonoo 8000000000 8000000000 8000000000 8000000000 8000000000 8000000000 80000nO000 8000000000 8000000000 8000000000 8000000000 ~-rl tlCatlon Alaska Com[.)~'~t~no Center z}~-OCT-1, gg4 11,173 PAGE: mmmmmmm mm m ! mmm .mmmmmmm mm IEM TO~ OHM~ 0~ 120 44 CSFL TO~ M~/~ 07 210 O1 SWLU TO~ O~g~ 07 220 O1 G~ TO- GAP! 07 310 HTEN ~O~ 5gF 07 OOO O0 ~E$ ~OU 0}~ 07 000 O0 gTE~ TOg DEGC 07 000 O0 SP ~OD N 0 6 1 1 n 6 1 1 0 ~ 1 1 0 6 1 1 0 6 1 1 0 fi 1 1 O 6 1 1 2 40 800n000000 2 49 8000000000 2 40 80000nOn00 2 49 8400000000 2 49 8000000000 2 49 8000000000 2 49 8000000000 ** DEPTH TFN~. TO~.,] 4100.000 CAI.,1. TOH LS.TOW 632.500 LITH.TOH PE~'. TE)~ J. 6.672 RI~OB.TOH T~R ~. TO~ i. 6 ! 5 CFTC.TOH NPOP.TOn 0.155 ~,~PH I ,'POH CIDP.TON 5~.000 CI~P.TOH IIRD.TU~ 432. 750 IIXD.TOH CILD.TOn 546.000 CIt~M.TOH CSFL.TOu 302.750 SFLU.TOH ~PE~q.TOw 0.5~2 ~TE~.TON 2.79g LL,TOH 75.563 $S1,TOH P.~4P DRHO,TOH 3~37,406 C~TC,TOH 0,I~5 Pf'OC.TOH 381.250 !DPH.TOH 64.000 2.61! G~,TOH 70.875 SP.TOH 322.250 LU.TOH 317.000 SS?.TOW 0.118 DPHT.TO~ 6147.714 TMPg,TOH 0.~94 355.000 IIXU.T{]g !. 030 95.438 HTE~I.TO~ -3.~I~ ** DFPTH = ~0500.O00 FE~T T~NS.T[JH 5660.000 CALI.TO}I B$.TO}I 209.750 LITH.TO}~ PE~,TO~ 5'533 R'HOB.TOH TMR~.TOB 2.395 CFmC.TOH NPOP.TO~ 0.240 uP~II.TQH CIDP.TOW 9!.750 CI~P.TOH ITRD,TOW ~2,000 TtXD',TOE CILn,TO, 91,875 CILM,TOM CSF~,TOW ~2,375 SFIoU,TOH MRES,TOW 0.625 ~TEM,TOH 6.793 LL.TOtl 6~.000 $SI,.TOH ?.497 DRHO.TOH 1592.541 CNTC.TOH 0,27~ RFOC,TOH 91,563 IDPH.TOH 2.588 I!PM,TOH 9~.500 I!,D.TOH 12.13~ GR.TOH ~5~,438 SP,TOH 155.125 bU.TO;~! 252.500 SS2.TO~ o.04o DPBT.TOU 3598.056 TsP~I.TO~ O.!69 IPRE.TOg 10.89! IgPg.TOg 87.625 i!XU.TOH 10.883 IL~.~OH 94.000 HTE~.~Ou -25.~81 ** DFPTB = ~0000,000 FEET TF~$.T£)H 5565.000 CAbI.TOH LS.TO~ 365.250 LITH.TOH PEW.TO~ 4,938 ~iOB,TOH TNR~.TOM 2.353 CFTC~TOH NPOP.TOW 0.246 MPHI*TOH CTDP.TO~ 196.500 CI~P.TOM IIRD.TOu 175.250 IIXD.TOH CILD.TOW 200.175 CII,~.TOH CSFL.~O~ 1~9.375 SFLU.TOH MPES,~OW 0,630 ~TEM.TOli 7,034 I,L.TOH 83.250 SSI..TOH 2.369 D~gO.TOH 1527,709 CNTC,TOH O,249 PFOC,TOH 1.92,500 TDP[I,TOH 20,~25 ~IR~4,TOH 195.R75 II.,D.TOH 5.777 GR.TOH ~6.625 SP.TOH ~,89.250 bU.TOH 255.500 0,02? DPHT.TO~ 355~.615 T~PH.TO~ 0..~77 IWRE.TOH 5.086 IHPH.TOP ~84.250 IT~M.TOH 4.092 Ib~.TCH 42.063 HTE~.TOW -20.281 621,0~0 435.000 0.308 0.155 ~0 2.6~1 28.7~9 2.615 -337.000 289 500 22:soo 0.093 0,250 2O 10.914 7.2]4 10.805 950.500 352.250 337.000 0.170 0.249 20 5.191 1,3.648 5.102 1078.000 erq~r Alask'~ romput~,no Center 2R-OCT-1994 1~:23 ~* DFPTH -- 9723.000 TFNS.T[.)H 5360,000 CALI.TO~{ b$.TOP 155.6~5 LIT[{.TOH DE~.TO~ ~5.773 PHOB.TOH T~Rn.TO~ 3.938 CFTC.TOH N~O~.TOu 0.404 NP~I.TOH CIDm. TOu ~9.4~8 CI~P.TOH I!RD.~O~ ~7.531 IIYD.TOH C~L~.TOw ~9.188 CIbN.TOH CSF!,,.TOu ~000,000 SFI,U.TOH 6.094 LL.TOH 16.656 6$1.TnH 2.125 40~.677 CNTC,TOH 0.54~ ~FOC.TDH 49.938 !DPH.TOH ~08,125 II~.TOH 4~,031 ILD.TOH 0.500 GR.TOH 67.250 **** F~LF TRAILER **** $~RVIC~ ! mb~ VF:R~IC~ : 40,2 DhT~ : o4/~0/97 MAX REC SIZE : ~0~4 FILE TYP~: ~ PR LA5~ ~ILE : S~RVICE ~AM~ : LDT!5 DAT~ : 94/10/27 O~ICI~ : CSU T~P~ ~A~E ~ 590555 CON~I~LJAT!O~~ ~ : O0 P~EvI. OU$ ~ADE Cn~ENT : SC~b!~MBEPG~:R wE[.,[., SEPVTCFS CSU TAP~ **** REEb TRA!LEP **** ATE '" : ~4../10/27 OP!C!~ : CSt! RFEL NA~E : 599555 PP~vlOUS DE~D : CO~:~E~T : SCHL[!SBERGER WFbL SERVICFS CSU TAPE 76.563 76.625 -0.735 51..406 40.875 52.094 34.563 69.875 SS2.TOH DPHI.TOM TNPN.TOM I~Rw. TON iwPU.TOH PAGE: 158.125 117.875 0.3~8 0.506 2O 20,0].6 35.531 23.234 1057.000 ALASKA COmPUTInG CENTER ~mmmmmmm~mmmmmmmmmmmmmmm~mmmm* GeoQuest · OPEN ~OLE EDIT* WELL: SCU41A-8 FIELD: SWANSON RIVER API #50-133-10120-01 COMPANY: UNOCAL COMMENTS: DIL/LDT/CNL/GR CNTY: KENAI STATE: ALASKA LOG: 0~T-27-1994 TAPE: 28-0~T-94 1600 BPI KB ELEV: 160.6 RUN #: ONE START: 10928 STOP: 9?52 JOB #: .dr AlasKa Comp:]tino Center **** RFE[, HEADE~ SFRVlCE NAME ! LDTI5 DATF : q4/10/P7 O~IgI~ ~ CSU REEl. NA~E : 599555 CONTINUATION ~ : aO PREVIOUS REEb : CO~EN% : SC~;LU~RERGER W~L[, SEPV!CFS CSU TAPE **** TAPM HEADFR **** SFRVICE NA~M : LDT15 DATF : 9411~/27 O~I~IN : CSU T~P~ ~A~E ': 599555 CONTINUATIO~ ~ : O0 PREVIObS ~APE : CO~ENT : SC~bU~SERGMR WEbL SERVICES CSU TAPE **** FILM HEADER **** F!b~ NA~E : TO~ .005 $~RV1CE : PL~Y ¥~RSION : 40.2 DATE : g4/10/~7 MAX REC SIZE F~LF TYPE : PR b~$? FILE : ** DA~A FORe, AT SPECIFICATION RECORD ** 2 66 0 3 v9 98 4 66 5 66 6 73 7 65 INCH 8 73 60 9 65 J.~, 66 {lINo 12 68 !3 66 ~ ~5 .~I.~: 16 66 0 66 .~asKa Cgmp,..lt.lno (,:enter $* SET TYPE - CNAN ** ID ~RDER .... ~ bOG TYPE CLASS ~OD MIJ~B .... $~P EL, EM C . TENS TOH b~F 07 6~5 91 0 5 1 I 4 CAD! TOW l~~ 07 280 01 O 5 1 1 2 L[, TO~ CPS 07 354 Ol o 5 1 I 2 LU TOW CPS 07 35~ 0! o 5 1 I 2 55 TO~ C~$ 07 354 O1 n 5 1 1 2 LIT~ TO~ CPS 07 354 O1 O 5 1 I 2 SSi TON CPS 07 354 02 0 5 1 I 2 S~2 TO~ CmS 07 354 02 0 5 1 1 2 PEF TOW 07 358 01 0 5 ! I 2 R~O~ TO, G/C] 07 350 02 0 5 1 1 4 D~HO TOw G/C3 07 356 01 o 5 1 1 4 DPH? TOW V/V 07 890 O1 0 5 I 1 4 TMRt TOW 07 470 01 0 5 1 I 4 CFTC TOw CPS 07 4~0 Ol 0 5 1 I 4 CNTC TOH CDS 07 420 01 O 5 1 I 4 T~PW TO, V/V 07 800 o0 0 5 1 1 4 NDO~ ~O~ V/V 07 800 ~0 0 5 1 I 4 NPH? T()~4 V/V 07 SO0' 00 0 5 1 I 4 RFOC TO~ V 07 000 O0 0 5 1 1 2 IFRF wO" 07 000 00 0 5 1 1 2 CID~ TOw ~)~/u 07 110 a6 0 5 1 I 2 CI~P TO~..~ ~u/u 07 1]0 44 0 5 1 I 2 IDPW TOH OMM~ 07 120 d6 0 5 1 1 2 I~P~ ~O~ OHM~ 07 1~0 44 0 5 ~ I 2 IIR~ ~ON M~tu 07 0o0 o0 n 5 1 1 2 'IIXD TOH ~/~ 07 000 O0 o 5 1 I 2 IIR~ WOu ~/,~ 07 000 O0 0 5 1 1 2 IiX~ TOt~ H~/u 07 000 00 n 5 ! 1 2 CIL~ TON ~/~ 07 1~0 4,6 0 5 ~ I 2 CI5, TO'~4 ~/~ 07 110 44 0 5 i I 2 'II, D TON ON~ 07 120 46 0 5 1 1 2 IL~ TON O~M~ 07 120 44 0 5 1 I 2 CSF!,, TO!,.~ M~/~ 07 210 01 O 5 1 ! 2 S~LU ?O~ O~ 07 .2~0 0! 0 5 1 1 2 O~ TO~.~ G~PI 07 31.0 OI o 5 1 I 2 HTEN TON LBF 07 000 0() 0 5 1 1 2 MRES TO~ OHM~ 07 0OO 00 0 5 1 i 2 MTE~ ~0;4 DEGC 07 000 00 0 5 1 1 2 S~ TON. ~V 07 0~0 01 0 5 ! 1 2 #m~mmmmmmmmmmmm~mmmmmmm#mmmmm~#mm mm#mm##mmmmmmmmmmmmmmmmm mmmmmmmmlml{mmmmmmmm ~m~m ~m .~m~ 8000000000 4g 8400000000 49 8000000000 49 8000000000 49 8000000000 4O 8oo000000n 49 8000000000 49 8000000000 49 8402040000 8202040000 68 8200000000 68 8402040000 68 8442000000 68 8~00000400 68 8~00000400 6? 8242000400 6n 824~0n0400 8242000000 49 8000020000 79 8000000000 49 8000000000 ~000000000 49 ~00o0o0000 49 800a000000 49 8000000000 40 8000000000 49 8000000000 49 8000000000 49 8000000000 49 8000000000 49 8000000000 49 8000000000 49 8000000000 49 8000000000 49 8400000000 49 8000000000 49 8000000000 49 8000000000 49 8800000000 DATA ** DEPTH : t. 0980.000 FEET TENS.TOH 4065,000 CALI,TOH 2.799 bb. TOH LS.TO, 645.500 LITH.TOH 91.000 SSi.TOM PEW.TO~ ~6,672 RHOB.TOH ~.!!9 DR!{O.TOH TNRA.TOg 1.591 CFTC-TOH 3~02.220 CNTC.TOH 332.250 305.500 0.t00 5994.464 LU.TO}4 SS2.TOH DPH!.TON T~PN.TON 626.500 434.750 0.322 0.151 .... ~ificatlon 5istlno ~£ger AlasKa Computing Center NPOP.TOH 0.15! CIDD.TOW 522.500 CI~P.TOH iTRD.TOW 433.500 II×D.TOH C!LD.TO, 547.500 CILM'TOH CSFL.TOH 382.000 gFLU.TOH ~E~.TO~ 0.549 ,TE~.TOH TENS.TOM 5755.000 CA!,I.IOH L$.TON 1992.000 LITH.TOH PE~.TO~ 17.2~ PHOB.TOH T~RA.TOU 5.0~4 ~FTC.TOH NPO~.TOH 0.7~7 5~PHI.TnH CIDP.TO~ ~7.125 CI~P.TO}t ITR~.TO~ ~5.500 II~O.TOH C%LD.TOW ~2.8~8 CIbM.TOH C~F~.TOH 0.635 ~RE$.TO~ 0.551 ~TE~.TOH FEET 2~-OCT-1994 I~:~3 0.~81 RFOC.TOH ~75.500 IDPH.TOH 63.~56 TIPM.TOH 376'500 ILD.TOH 2.617 GR.TOH bO.~'75 SP.TDH I 0. 203 Lb. TOM ~85.000 SS1 .TOM 1 .~46 .~23..l 4'~ CNTC.TOFI 0.697 ~FOC.TOH 23.n16 I [.)PH . T. Og -0.964 19. 344 ILD. TOH 74. 000 GR.TOH 71.J88 SP.TOH **** FTLF TRAILE~ **** F!L~ NA~E : 'rO~ .005 $~RVICE : PD~Y VERSION : 40.2 DAT? : o4t10/~7 ~X R~C SIZ~ : ~0~4 FILE TYPE ~ PR BAST FII,E : **** FlbE ;lEADER **** Fib? NA~E : TO~ .006 SFRVICE : PLaY VFR~ION : 40 2 DAT~ ~ 04}101~7 F~ TYP~ LaST FILE ** DATA FORMAT SPECIF!CATIO~ RECORD ** 0.!89 1.91'2 350.000 1.826 97.875 16.391 996.o00 ~58.750 1516.47~ 0.683 58.344 18.42~ 4].781. !06.875 -3.32~ IPRE.TOH IMPH.TUW IIX~.TOH IL~.TOH HTEM.TO~ bU.TOH S$~.TOH DPHI.TOP TgPH.TOW IFRK.TOH I~PH.TOH ITXU.TO" IL~.TOH HTEN.TOM PAGE: 20 2.660 26.828 2.654 -327.500 1993.000 400.250 0.7¢0 0.703 43.406 1.902 51.656 999.000 ~JLaSK~ t;.omPt].tlno center 5 66 6 73 7 65 INCH 8 73 60 9 65 ,lin I~ 66 10 1~ 68 1~ 66 1~ 65 ,lIN 1~ 66 73 16 66 0 66 · , SET ~YPf: - CHAM ** NAME SERV UNIT SERVICE API AP! APl AP1 FILE NUMO N[tMB SIZE REPR PROCESS ID ORDER ~ bOG TYPE CLASS ~OD NUmB SA~P ELEM CODE (HEX) TFN~ TO~ L~F 07 635 ~ n 1 1 4 6~ 8000000000 CALI TO~ I~ 07 2~0 O1 0 6 1 1 2 49 8400000000 LL TO;4 CPS 07 354 01 0 6 1 bU TO~ CPS 07 354 O1 0 6 1 LS ~O~ CPS 07 354 01 o 6 ! L~T~ TOH CPS 07 354 01 0 6 1 SS1 TOH CPS 07 354 02 $$2 TO~ CPS 07 354 PFF TOu 07 358 01 0 6 1 RPOP TOP G/C~ 07 350 02 0 D~HO TOP G/C3 07 356 nl 0 6 1 DPHI TO~ V/V 07 890 T~!R~ TO~ 07 490 CFTC TOg CPS 07 4~0 Ot n 6 1 C~TC TO~ CPS 07 4~0 01 0 6 1 TNP~ TO~,~ V/¥ 07 890 O0 0 6 N~O~ TOg V/V 07 890 00 0 6 NPHI TO~ V/V 07 8g0 00 RFOC TO~ V 07 000 00 0 6 IFR? TOP 07 000 00 O 6 CIDP TOU ~/u 07 1~0 CIMP TO~ M~/~ 07 1~0 44 0 6 'IDP" T0H OMMP 07 120 ~6 0 6 IPP~ TOg OMMM 07 190 44 0 6 IIR~ T0~ MP/~ 07 000 00 0 6 I IIXD TO~-; M~/P 07 000 O0 0 6 R ~ TON M~/~ 07 000 00 0 · Xp T~ ~P/~ 07 000 00 0 6 1 CIL~ TOH M~/P 07 110 46 0 6 C!b~ TO~ ~/~ 07 110 44 0 6 ILD TO~ OMMM 07 1~0 46 0 6 2 2 2 2 2 2 2 4 4 4 4 4 4 4 4. 2 2 2 2 2 2 2 2 2 2 2 2 4~ 49 49 49 49 49 49 6~ 6~ 68 68 68 6~ 6~ 49 79 49 49 49 49 4g 49 49 49 49 49 49 sn0o00on00 8000000o0o 8000000000 $oo00o0o0o 800000000O 800000000O 840~040000 82{}~040000 8200000000 840~040000 844~000000 8~00000400 8800000400 8~42000400 824~000400 824~000000 ~0000~0000 8000000000 8000000000 8000000000 ~000000000 BO00000000 8000000000 8000000000 8000000000 8000000000 8000000000 8000000nO0 8000000000 v er.~., f ~ cat i on' Alaska Compute. nc Center 2~-OCT-1994 12:23 PAGE: ILM TOH O~MM 07 120 44 0 6 I I 2 49 8000000000 CSft., TOJ~ M~/~ 07 210 01 n 6 1 I 2 49 8000000000 SFhU TON O~M~ 07 220 01 0 6 1 1 2 4g 8000000000 G~ TO}~ GAP! 07 31,0 01 0 6 1 1 2 49 8400000000 ~TEN ~O~ ~F 07 00o 00 0 6 1 1 2 49 8000000000 ~RE$ ~Ou OU~ 07 000 O0 0 6 1 1 2 49 8000000000 ~TE~ TO~4 DEGC 07 000 O0 0 6 1 1 2 49 8000000000 SD ~UN ~V 07 010 01 0 6 1 1 2 40 880000000n mm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm#mmmm-mmmmmmmmmmmmmmmmmmmmmmm TFN$.TO*.I LS.TO~ DEF,TO~ T~R~.TON NPOP.TOg~ C?DP,TO~ IIRD.TG~ C~L~,TOg CSFS.mO~ ~PE~.TO~ T~Ng. TOH LS.TO}~ PE~,TO~ T~R~.TO~ C~DP.TOP I?RD.TOW C~LD.TOg CSF!..TO~ MRES,TO~ LS.TON 'PEF.TO~ TNR~.TOg NPOP.TOU CIDP.TOM IIRD.TO~ D~PTH = !0q83.O00 FEET ** ~100.000 C~LI'.TOH 2.79g LL.TOH 32~.250 632.50~ LITH..TOH 75.563 SS1.TOH 312.000 SS?.TO}~ 16,672 RHOB.TOH 2.~4~ DRHO,TOH 0,118 DPHI.TO~ 1,615 CFTC,TOH 3~37.~06 CNTC.TOM 6147.714 T~Pg,TOH 0,155 ~PHI.TOH 0,185 RFOC.TOH 0.194 5~2.000 CI~P.TOH 381.250 !DPH.TOH 1.914 I~PH.TO~ 4~2.750 IIXD.TOH 64.000 !I~.TOH 355.000 546.000 CILM.TOH 352.950 ILD.TOH J.830 IL~.TOH 382.750 SFLU.TOH 2.61~ GR.TOH 95.438 0.582 ~TEM.TOH 70.875 SP.TOM -3.818 DEPTH = ~.0500.000 FEET ** 5660.000 CALI..TO}{ 6.993 LL.TOH ~.55 ~25 LUoTO~4 209.750 LITH.TOH 6~.000 SSi.TOM ~52~~00 5.b33 RHOB.TOH ~.4.97 DRHO.TOH O.~40 DPHI.TO~ 2..395 CFtC.TOM 159~.541 CNTC.TOH 3598.056 T~PH mOH 0.240 ~P~{I,TOH 0.27~ RFOC.TOH 0.1.69 I~R~Og 91.750 CI~P.TOH 91.563 IDPH-TOH 10..~91 82,000 ~'IX~:.TOH 2,588 !!~M.,TOH 87,625 I!X~.TOM 91,875 CILH,TOH 92,500 ILD,TON 10.883 82.375 SFLU.TOH 12.~33 GR.TOH 94.000 0.625 ~TE~.TOH 69.43B SP.TON -25.~8~ DKPTH = ]0000.000 FEET 5565.000 CALI..TOH 7.~34 LL.TOH !89.250 365.250 !,ITH.TOH 83.250 SS1..TOH 255..500 SS2.TON 4.938 RMO0.TOH 2.369 DRNO,TOH 0.02~ DPHI.TOg 2.353 CFTC,.TOM ]527.709 CNTC.TON 3553.6~5 T~PH.TOg 0.246 NPHI.TOH 0.249 RFOC..TOH. 0.,~77 IWRF,TOH 196.500 CI~P'TOH 192.500 IDPH.TOH 5..086 IMPH.TOg ~75.250 IIX~ TOH 20 &25 IiRM.TOH !84.950 200.125 CI],,~:TOH t95:875 ILD.TOH 4.992 189.375 SFLU.TON 5.277 GR.TOH 42.063 HTEN.TO~ 0.630 ~TE~.TO[{ ~6.625 SP.TOH -20.281 621.0o0 435.000 0.308 0.155 ~0 2.621 28.7~9 2.6~5 -337..000 28950.0 ]221500 0.093 0,250 20 I0.914 7.2]4 10.805 950.500 352.250 337.000 0.170 0.]49 ~0 5'191 ~3..648 5.102 t078.000 ~* DFPT H ---- TFNS.TOU 5360.000 LS.TON 155.625 nEF.TOW 15,773 TNRA.TO~ 3.938 N~O~.TOW 0,494 CIDP,TO~ ~9.4~8 i!RD.TON ~7.531 CILn.TO~ ~9,1P8 CSF!.,.TOU ~000.000 ~ES.TO~4 9723.000 FEET 6.094 16.656 P.125 40~.677 0.542 49.93~ 109,125 43.03! 0.500 67.750 LL.TOH S$1.TmH DRHO.TOH C~TC.TOH ~FOC,TDH !DPH.TOH II~!.TOH ILD.TOH GR.TOH SP.TOH 76.563 76.625 -0.735 1584.775 51.406 40.875 5~.094 34.563 69.~75 bU.T[IH SS2.TOH DPHI.TOH TMPH.TOH I~R~.TO~ I~P~.TON IIX~.~O~ IL~.TO~ 158,125 117.875 0.318 0.506 2O 20.0~6 35.531 23.234 1057.000 **** FILM TRAILER **** FIL~ NA~E : TON .006 SFRVICE : VERSION : 40,2 D~TF : O4/10/27 M~X REC SIZE : ~,024 FILE TYPE ~ PR LAS? FILE : **** T~PF TR~!LE~ **** $FRVICE NAM~ : LDT15 DATF : 94/10/~7 O~IGIM : CSU T~P~ NA~E : 59~555 CONTI~UAT!O~ # : O0 PREVIOUS TAPE : CP~ENT : SCNLU~BE~G~R **** REEL TRAILER **** SFRVICE NAME : LDTi5 DATE : 94/10/27 OPlCI~ : RFEI,, NA~E : 599555 CONTIMU.aTIO~, ~ : O0 PREVIOUS COM~EWT : SCMLIIa~ERGER WELL SE~¥!CFS CSU TAPE TAPE