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Home My WebLink About190-059STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________SWANSON RIV UNIT 21A-34 JBR 03/31/2022 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 3-1/2 joint. VPR NT due to no tubulars that size in SRU 21A-34. Annular 6 secs; Rams 3 secs; HCR 1 sec Test Results TEST DATA Rig Rep:Kevin ReedOperator:Hilcorp Alaska, LLC Operator Rep:Wade Hudgens Contractor/Rig No.:Hilcorp 401 PTD#:1900590 DATE:3/4/2022 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopSAM220308085231 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 3 MASP: 1349 Sundry No: 322-055 Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.NA 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 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 7-1/16 P #1 Rams 1 2-3/8x2-7/8 NT #2 Rams 1 3-1/2 P #3 Rams 1 Blinds 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 P2575 200 PSI Attained P13 Full Pressure Attained P30 Blind Switch Covers:PAll stations Nitgn. Bottles (avg):P6@2300 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 9 999 9 9 9 9 9 9 9 9VPR NT due to no tubulars that size Annular 6 secs; Rams 3 secs; HCR 1 sec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LQ KHDG 7XELQJ KHDG 9HWFR)7&,7 0 ; 0 Z0662%* ERWWRP $GDSWHU 9HWFR (63 0 URWDWLQJ IODQJH ; 0ó¶¶FRQWUROOLQH H[LWV 3UHSSHG IRU %,: .ZLN /RN DQG 9* VHDO FDUULHU 6ZDQVRQ 5LYHU 658 $ ;;ò 'ƌŽƵŶĚ>ĞǀĞů YƚǇϮ ЬĐŚĞŵŝĐĂůůŝŶĞ 7XELQJ KDQJHU )7&(63 ; 0&$ DFPH OLIW [ ò ,%7 VXVS Z ó FRQWURO OLQH H[LWV SUHSSHG IRU %,: .ZLNORN SHQHWUDWRU '' PDWHULDO ϯϭͬϴϱDdƌĞĞĂƐƐǇ EQUIPMENT HEIGHT 99.09" ADDITION FOR RING GASKETS TOTAL STACK HEIGHT 2 each @ 0.50" 99.59" OPEN AND CLOSE DATA OPEN CLOSE 2-1/16" 5M HCR 0.61 0.52 HEIGHT DATA AND WEIGHT DATA 7-1/16" 5M ANNULAR 3.21 4.57 7-1/16" 10M RAMS (PER SET) 1.3 1.3 ϳͲϭͬϭϲΗϱDEEh>Z^,&&Z ^dz> ,/',d͗ϯϬ͘ϵΗ t/',d͗ϯϬϰϮ>^ ϳͲϭͬϭϲΗϱDdzW hKW ,/',d͗ϰϰ͘ϭϵΗ t/',d͗ϲϰϬϬ>^ ϳͲϭͬϭϲΗϱDdzWh^d< ϳͲϭͬϭϲΗϱDZ/>>/E' ^WKK> ,/',d͗ϮϰΗ t/',d͗ϭϲϬϬ>^ </>>^/͗Ϯ,ϮͲϭͬϭϲΗϱDD's ,K<^/͗ϭ,ϮͲϭͬϭϲΗϱDD's Eϭ,ϮͲϭͬϭϲΗϱD,Z Swa ns o n Riv er 6:$1621 5,9(5),(/' 658B$6+/ 61: 6586583 6583 658 658$ 6583DG 6583DG $ 6HF 6HF )HHW $ODVND6WDWH3ODQH=RQH1$' /HJHQG IRRW5DGLXVDURXQG6+/ 2LODQG*DV8QLW%RXQGDU\ 0DS'DWH 6ZDQVRQ5LYHU)LHOG 658$6XUIDFH+ROH/RFDWLRQ ZLWKIRRW5DGLXV%XIIHU /RFDWLRQ0DS 2YHUYLHZ Coo k I nl et .HQDL +RPHU 7\RQHN 6HZDUG1LQLOFKLN $QFKRUDJH +$.3HWUD:HOO6\PERO 2LO 3 $'RFXPHQW3DWK2?$ODVND?*,6?FRRNBLQOHW?ZHOOV?RLOJDV?756B'LVWDQFH?P[G??2WKHU?658B$BB6+/BIW%XIIHUB'RQQD$PEUX]BYP[G Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SRU 21A-34 (PTD 190-059) Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JAN 10 2020 1. Operations Abandon Ll Plug Perforations Performed: Suspend El Perforate Ll Fracture Stimulate LJ El ❑ Pull Tubing U4LisF_ n Other Stimulate Alter Casing ❑ ee' r20 tl6' Chan ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Replace ESP ❑✓ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 190-059 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-10171-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028406 Swanson River Unit (SRU) 21A-34 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River/ Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 11,160 feet Plugs measured 10,191 (PX Plug) feet true vertical 10,859 feet Junk measured 10,191 (PX Plug) feet Effective Depth measured 11,050 feet Packer measured 9,057'; 10,169' feet true vertical 10,764 feet true vertical 9,049'; 10,034' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 33' 22" 33' 33' Surface 3,030' 11-3/4" 3,030' 3,029' 3,070 psi 1,510 psi Intermediate Production 8,575' 7" 8,575' 8,571' 6,340 psi 3,830 psi Liner 2,599' 5" 10,835' 10,578' 10,140 psi 10,490 psi Liner 883' 2-7/8" 11,159' 10,858' 10,570 psi 11,160 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 8,049' MD 8,049' TVD HES BWD; 9,057' MD 9,049' TVD Packers and SSSV (type, measured and true vertical depth) Baker DB; N/A 10,169' MD 10,034' 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: 0 0 0 165 160 Subsequent to operation: 1287 40 2509 217 218 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory❑ Development ✓ p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ✓ Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-478 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(oihilcoro com Authorized Signature:- Date: f Zo Contact Phone: 777-8420 s4 01rte Y- (. /y, zo RBDMSlfISJ JAN 1 310A Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 SO -133-10171-00 190-059 12/4/19 12/11/19 Daily Operations: 12/04/2019- Wednesday PJSM and PTW Remove rig liner and felt from WL-01RD, load all remaining equipment on trucks and move to 21A-34 Begin R/U on 21A-34. Well had 150psi of gas on tubing and annulus, bleed well to blowdown trailer. Install felt and pit liner. Transport Cruz loader from Wolf Lake. Spot base beam, carrier, accumulator, dragon heater, pits, mud pump, fuel tank, and bang board on rig liner. SDFN 12/05/2019 -Thursday PJSM and PTW @ 5:30AM. Fire up rig, heaters, generator and light plants R/U electrical, lights, heaters, tool connex, office, communication tower, and lines from the mud pump to pits Pressure test hanger void 250psi low / 3000psi high for 15min. TEST GOOD Pump 55BBL of produced water down the tubing, tubing pressure at Opsi. Set BPV in hanger, disconnect chemical injection lines. Verify 0 psi on the annulus. N/D and remove tree from the wellhead. re -terminate chemical injection lines. N/U 7-1/16" Yellowjacket BOPE stack. (Annular, 3.5" pipe rams, blinds, and mud cross) Raise derrick to half mast and pin. Secure guy lines and scope derrick to full mast, secure guy lines. R/U floor. R/U hand rails, accumulator lines, kill lines, weight indicator, derrick lights and beacon. Night watch on tour to monitor rig, heaters, and continue R/U 12/06/2019 - Friday PJSM and PTW. Verify 0 psi on the casing. R/U accumulator lines, pressurize accumulator. Complete rig containment. R/U bales and elevators R/U Kill line, jumper hose to mud pump, blow air through all lines to ensure they aren't ice plugged. Spot Summit ESP spoolers, connex and sheaves. R/U McCoy tongs and changed dies to 3.5". Set light plants. M/U BOPE test joint. Total Safety R/U and test all gas alarms. Adjust brake bands on draw works, service rig, function test BOPE valves and repair hydraulic leak on the HCR. SDFN Night watch on tour to monitor, rig, heaters and help R/U. 12/07/2019 -Saturday PJSM and PTW. Fire up rig, pressurize accumulator and verify Opsi on the casing. Set BOPE testjoint. Fluid pack and work the air out of choke manifold, choke line, kill line, test joint, TIW and dart valve. Shell test BOPE's against annular to 250psi/2,500psi. Shell test good Test 7-1/16" Yellowjacket BOPES and choke per AOGCC and Hilcorp regulations to 250psi low / 3,OOOpsi high - TEST GOOD. AOGCC witness waived by Jim Regg at 11:39AM on 12/6/2019 BPV had a little gas pressure behind it. R/U and pump SOBBL produced water down the tubing at 1.5613M. Pump 50BBL down the casing at 3.5BPM. Both tubing and casing on a slight vacuum. R/D & blow down mud pump and lines. Pull BPV, install TIW, back out lock downs and pull hanger to floor. Hanger pulled free at 65k. Disconnect ESP cable and chemical injection lines. L/D hanger and crossover subs. R/U Summit ESP sheaves. Crew change. Hold safety meeting with night shift. Start pulling 3.5" 9.2# L-80 TCII tubing stands racking back. Remove cannon clamps and spool ESP cables on Summit spools. 30 stands pulled (1,941' of tubing) Pump 20 bbls of produced water down backside of tubing for pipe displacement. Well on vac. Rig crew on lunch break. Continue tripping OOH with 3.5" tubing and ESP equipment. Lay out GLM #1 and a single. 63 stands in derrick, pump 20 bbls produced water down back side. 90 stands out of hole. Pulled 5,756'. 2,457' remaining. Shift change. Heavy rain and winds throughout the night. Roads are icy. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 190-059 12/4/19 12/11/19 Daily Operations: 12/08/2019 -Sunday PJSM and PTW, crew change with night crew. Pump 20BBL of produced water down the annulus at 1BPM for pipe displacement. Well on vac POOH with 3.5" 9.2# L-80 TC -II tubing ESP cable, & chemical injection line from 2457Ft racking back stands and laying down GLM's L/D SLB ESP assembly. Pumps turned moderately hard, AGH was locked up, VGSA turned very hard and rough, UT protector turned very easy (assume broken shaft), LT protector turned good and had clean oil, motors checked good electrically and had clean oil. All bands and cannon clamps were accounted for. Pump 20BBL down the annulus for pipe displacement. R/U Pollard and RIH with 3.75" OD rare-earth magnet to 9042Ft SLM. POOH with (2) quarter sized pieces of metal (assuming from packer milling in 2019) R/D and stage Summit equipment for install 2nd RIH with 3.75" OD rare earth magnet to 9042Ft SLM. No metal large metal returned, just metal shavings. R/U and stage Summit equipment for install RIH with 5.88" OD gauge ring to 8222Ft SLM and tagged liner top. Worked through tight spots at 6077Ft and 6120Ft. R/U and stage Summit equipment for install 3rd RIH with 3.75" OD rare earth magnet to 9,042ft SLM, magnet came back with only metal shavings. RIH with 4.5" Magnet to liner top at 8224' RKB. POOH with fine shavings. Rig down Slick line unit. Crew change. Hold pre tour safety meeting. Prep for picking up ESP components. Disconnect power to spooler. Disconnect air line, pick up boards and packing from motors and screens. Tail gate meeting. Discuss picking up screens and casing. Pick up two 40.6' Screen assemblies. Delta Elite 4 -1/2" 11.6# L-80. 4.5" 11.6# casing pup, 4x 5-1/2" 15.5# casingjoints. Land screen/shroud assembly onto work table. Pump 20 bbls down casing. Hang ESP Sheave in derrick. Start picking up ESP motors. Install anode spade with 2 x Chemical injection valves. String dual pack chemical control lines and ESP power cable through Sheave. MU 1/3" SS Chemical injection lines and pressure/Phoenix gauge line to the assemblies. Slowly trip in hole. Make up 2nd motor and 2x Seal assemblies. Service seal assemblies with oil. 12/09/2019 - Monday PJSM and PTW, change out with night crew Complete ESP completion assembly. Install (4) SF2700 pumps and discharge sub. Crossover subs back to 3.5" TC -II. Check cable and chemical injection line integrity. All checks good. RIH with 3.5" 9.2# L-80 TC -II tubing and ESP completion from 304Ft to first GLM @ 7,28Ft. Installing cannon clamps every collar. Very tight tolerance with cable and GLM, had to reorient GLM for cable clearance. Shut down for crew break and lunch. RIH with 3.5" 9.2# L-80 TC -II tubing and ESP completion from 728Ft to 2nd GLM @ 2,032Ft. Installing cannon clamps every other collar and checking cable integrity every—10,OOFt. RIH with 3.5" 9.2# L-80 TC -II tubing and ESP completion from 728Ft to 2nd GLM @ 2,032Ft. Test ESP cable and chemical injection lines - checks good RIH with 3.5" 9.2# L-80 TC -II tubing and ESP completion from 2,032Ft to 3,121'. PJSM and handover to night crew. TIH with 9.2 PPF L-80 TC -II out of the derrick from 3,121' to 4,573' MD. Test ESP wiring. Change out ESP spool. Perform splice on ESP cable at 4,573' MD Continue TIH from 4,573' MD Install GLM 4915' MD. Continue TIH to 5685' MD. Test ESP cable. 90 stands in hole or 6007' At shift change. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 190-059 12/4/19 12/11/19 Daily Operations: 12/10/2019-Tuesday PJSM and PTW. Change out with night crew and perform complete rig service. RIH with 3-1/2" 9.2# L-80 tubing, ESP completion, power cable, and chemical injection line from 6007Ft to 8215Ft Change out damaged 3-1/2" IBT to 3-1/2" TC-II crossover with new crossover from Tubo. Lower ESP cable sheaves and prep hanger for install and terminations. M/U 7" FTC-ESP tubing hanger with BPV installed. Build wellhead cable feed-thru and terminate chemical injection lines through hanger. Test ESP cable - checks good. Pump 85BBL of produced water from pits down annulus while making up hanger penetrator. RIH and land tubing hanger. S/O weight 80k, run in lock downs and test ESP cable. - checks good. Clean and clear rig floor, remove bales and elevators. R/D McCoy tongs. R/D pit hoses, mud pump, and unhook accumulator. R/D rig floor. Crew Change. PJSM with night crew. Nipple down BOPE stack and Nipple up production tree. NOS wellhead hand test hanger void 250 low 5 minutes 3,000 psi high for 15 minutes. Summit ESP rep test penetrator. Pull BPV and install tree cap. Continue to rig down. Choke house, Accumulator house, organize and load trailers. Load heaters on trailers. Prep Derrick for scoping down. Rig down and Load Gas alarms and install sensors in Koomie building. Lower pit roof, Roll up tarps/ pick up trash. Continue rigging down. Remove burm. Load summit ESP equipment. Stage magtec heaters. Load choke house on trailer. 12/11/2019- Wednesday PJSM and PTW, change out with night crew R/D 401 and load trucks. Scope and lay down derrick, tail roll accumulator, pits, dragon heater. Truck to BCU 25. Install flowline for 21A-34 Clean and clear location, hook up surface cables for 21A- 34 ESP. Complete surface electrical hook-ups and start ESP at 9:30 PM. Pump came online producing—1,800BPD. HilcorD Alaska, LLC RKe: 154' / GL IM AM6L RT -THF: 25.85' Ka 22" @ Perforation Data 33' Size Type DV Collar Top Btm 1,496' , Cement / Other 22" J 4" 2 Surface 3,030' 1-11/16" jumbo jet 111(9/10/90 Cemented 11-3/4" 3 47#, J-55 DV Collar 47#, J-55 Surface 1,496' 1,498' 4 8R / 11.000" DVCollar 7" Surface 7,087' Surface 87' BT/6.184" 6 23#, N-80 87' 4,794' BT / 6.366" 6 L8R -/6.276" 29#, N-80 6,701' 7,087' 7 DV Collar 7,087' 7,089' L8R / 6.184" 8 L8R/6.184" 29#, P-110 8,514' 8,575' L8R/6.184" s Wisdom of 7" at 8,575'8,635' (mast) 10 Possible Casing Failure @-9,112' 2a/8" pup It w/ lop chemical cut at 10,153' Perhol8 sQueezea cement from 8,551 e 6 8,60515' (6111/9") 11 12 13 14 16tel 17 X 16 19 �l x Top of PosslMe liner 2-71W links lap leak ®10,276' (....-90) OL 6" @ 10,835' H-1 H-2 . 2-7/8" 0 11,159'- TD=11,160' PBTD=11,050' Directional Data: max hole angle = 36.5° at 10,700' MD ACTUAL SCHEMATIC Swanson River Unit Well: SRU 21A-34 Completion Ran: 10/19/13 PTD: 190-059 API: 50-133-10171-01 Casing and Tubing Detail Perforation Data Size Type WU Grade Top Btm CONN / ID Cement / Other 22" Structural 10,920' Surface 33' 1-11/16" jumbo jet 111(9/10/90 Cemented 11-3/4" Surface 47#, J-55 DV Collar 47#, J-55 Surface 1,496' 1,498' 1,496' 1,498' 3,030' 8R / 11.000" 600sxs 116# (stage 1), 1250sxs 116# (stage 2) 7" Surface 29#,N-80 Surface 87' BT/6.184" 700sxs 116# (stage 1), 1150sxs 116# (stage 2) 23#, N-80 87' 4,794' BT / 6.366" 26#, N-80 4,794' 6,70V L8R -/6.276" 29#, N-80 6,701' 7,087' L8R / 6.184" DV Collar 7,087' 7,089' L8R / 6.184" 29#,N-80 7,089' 8,514' L8R/6.184" 29#, P-110 8,514' 8,575' L8R/6.184" 5" Liner 18#, N-80 8,236' 10,835' FL4S / 4.276" 90 bbl 15.8 ppg 2-7/8" Liner 6.5#, N-80 10,276' 11,159' EUE 8rd Mod / 2.441" 10 bbl 15.6 ppg Tubing 3-1/2" Prod 9.2#, L-80 Surface 8,049' TC -II / 2.992" C OD = 3.887" Production Strin Jewel Detail # Depth (RKB) Len th ID15.140" D Item 1 25.85' 0.6' 2.992"0" Tubin Hanger, 3-1/2" IBT Lift Threads 2 3,323' 6.33' 2.992"0" GLM, GLMAX-1.ORSL(Drift=2.867") 3 4,825' 6.33' 2.992"0" GLM, GLMAX-1.ORSL Drift = 2.867") 4 6,203' 6.33' 2.992"0" GLM, GLMAX-1.ORSL (Drift 5 7,525' 6.33' 2.992" GLM, GLMAX-1.ORSL (Drift=2867") 6 8,049' - - 0" Top of ESP, Discharge Head 7 8,145' 4.000" ESP Intake 8 8,231' - 4.560" Btm of ESP, 456 Motors / 400 Pumps 9 8,236' - - Liner top backer 10 9,057' 9.36' 2.555" 3.96" HES BWD Permanent Packer w/ seal bore extension 11 9,100' 1.27' 1.875" 2-3/8" Halliburton X Nipple 12 10,150' 5.86' 1.99" 3-15/16" Tristate Overshot 13 10,157' 6.27' 1.99" - 2-3/8" GLM 14 10,169' 3.07' - - Baker DB Packer w/ R Guide & millout extension 15 10,175'-10,187' 12.00' - TubingPunch w/ 4 spf 47 holes total 16 10,186'-10,188' 2.00' - - Tubin Punch w/ 4s f uns 8 holes total) 17 10,190' - FISH: PX plug 1810,191' 1.20' 1.875" OtisX Nipple 19 10,223' .58' 1.99" - Wireline Re -Ent Guide Downhole Revised: 10/19/13 Updated by STP 10/26/2013 Perforation Data ZONE TOP BTM Shot Condition H-1 10,918' 10,920' 4jspf 1-11/16" umbo jet 1 169/1 0/90 ) 10,920' 10,934' 4jspf 1-11/16" jumbo jet 111(9/10/90 10,934' 10,948' 4jspf 1-11/16" jumbo let III9/10/90 10,948' 10,960' 4s f 1-11/16" jumbo jet II9/10/90 H-2 10,966' 10,980' j 4s 1-11116" HC (2/6/91 10,980' 10,994' 4jspf /91 Downhole Revised: 10/19/13 Updated by STP 10/26/2013 THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SRU 21A-34 Permit to Drill Number: 190-059 Sundry Number: 319-478 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaslka.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Price Chair DATED thiQq day of October, 2019. M & OCT 3 0 2819 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED OCT 2 2019 Drs /0 ZCr/ 19 1 1. Type of Request: Abandon ❑ Plug Perforations Fracture Stimulate ❑ Repair Well p ❑ Operations shutdown El Suspend ❑ Perforate Other Stimulate ❑ ❑ Pull Tubing Q Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Replace ESP Ea 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 121, Stratigraphic ❑ Service ❑ 190-059 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50 -133 -10171 -Op -00 7. If perforating: 8. Well Name and Number: CJ is It 14 What Regulation or Conservation Order governs well spacing in this pool? CO 123B Will planned perforations require a spacing exception? Yes ❑ No Q , Swanson River Unit (SRU) 21A-34 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028406 Swanson River/ 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): 11,160' 10,859' 11,050' 10,764' 0 psi 10, 191 (PX Plug) 10,275 (PX Plug), X nipple, WLEG Casing Length Size MD TVD Burst Collapse Structural _ Conductor 33' 22" 33' 33' Surface 3,030' 11-3/4" 3,030' 3,029' 3,070 psi 1,510 psi Intermediate Production 8575 7" 1 8,575' 8,571' F 6,340 psi 3,830 psi Liner 2,599' 51, 10,835' 10,578' 1 10,140 psi 10,490 psi Liner 883' 2-7/8" 11,159' 10,858' 1 10,570 psi 11,160 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2# / L-80 8,049' Packers and SSSV Type: Hes BWD; Packers and SSSV MD (ft) and TVD (ft): 9,057' MD - 9,049' TVD Baker DB; N/A 10,169' MD - 10,034' TVD; NA - N/A 12. Attachments: Proposal Summary 21 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development I] Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 1, 2019 OIL✓, ' ❑ WINJ ❑ WDSPL ❑ ❑ Suspended GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: 11gLamer@hiIcorI).com Contact Phone: 777-8420 �'-�� Authorized Signature: % Date: 16 C"1'2 01 °j COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test / Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3(' d5'� Ji) 1 y I— aT ,... 61T1W� OCT 3 01019 Post Initial Injection MIT Req'd? Yes No F1 y Spacing Exception Required? Yes N0 R, Subsequent Form Required: `o •--Ll `D L APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:, L�fQ. L,t./, Submit Form and Form 10-403 Revised 4/ 017 Approvedd appli at1on 1s vaII Jor r t� f o t of approval. �s AtlachmeJ�s' Du�lic-;/f t � i(u�C 1D 24i'I RI V 1 Aelg6si to Zs -/f9 .n Hil.m Alask, LL Well Prognosis Well: SRU 21A-34 Date: 10/21/2019 Well Name: SRU 21A-34 API Number: 50-133-10171-01 Current Status: ESP Oil Well Leg: N/A Estimated Start Date: November 1, 2019 Rig: Rig 401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: joint. Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 100-148 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: No York (907) 777-8345 (0) (907) 727-9247 (C) AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP: Max. Allowable Surface Pressure: Brief Well Summary ; '1 — 1,085 psi @ 8,287' TVD — 1,085 psi @ 8,287' TVD — 0 psi r - (Flowing survey Oct 2009 mid perf of 10,956' MD) (Flowing survey Oct 2009 mid perf of 10,956 MD) (Based on actual reservoir conditions and min water cut of 90% (0.429psi/ft) will balance reservoir pressure at 4,855 ft. TVD. SRU 21A-34 was worked on in June of 2019 to replace an ESP. During this workover a plug was placed in a tubing tail to pressure test the casing. The casing tested good but the plug could not be retrieved so a milling operation ensued to remove the plug. The plug was eventually cut and dropped to the top of the 2-7/8" liner, re-establishing the flow path. An ESP was ran and hung off up in the 7" casing and the well was placed back on production. This ESP ran 129 days and failed. Diagnostics point t twisted shaft The work plan is to pull the failed ESP and run a new one. Screens ran below the intake are being considered to protect the ESP from debris in the well bore caused by the previous milling operation. Work -Over Rig Procedure 1. MIRU Rig 401 pulling unit. 2. RU and pump +/- 50 bbl Produced Water down tubing to clean pipe. Bleed casing pressure. 3. Set TWC in tubing h nger, ND tree, NU BOPE and test to 250psi low/3,OOOpsi high, annular to 250psi low/ , psi high (hold each valve and test for 5 -min). Record accumulator pre -charge pressures. a. Notify AOGCC 24hrs in advance to witness test. 1 p c �] b. Crew will be working 12hr shifts and well will be secured nightly with TIW valves and BOPE. c. Test j6W�rams on 3-1/2" test 1 ✓ joint. d. Email completed 10-424 form to all AOGCC addresses listed on the form within 5 days of BOPE test. 4. Release test pressure, pull TWC and install handling sub in hanger. 5. Back out tbg hanger hold down pins and pick up on hanger. 6. RU ESP spooling equipment. Well Prognosis HilWell: SRU 21A-34 "m nmet.' Date: 10/21/2019 7. PU pulling tubing hanger to floor. POOH with 3-1/2" TC-II production tubing from 8,049' Standing back tubing and spooling ESP cable. 8. Keep 4 GLM to re-run with new ESP completion. 9. Pickup new ESP equipment, building same in well. 10. RIH with replacement ESP with existing 3-1/2" TC -II L-80 tubing. a. Test control lines to 2,500 psi. b. RU Pollard to use bands or clamps on tubing (ensure adequate banding material). c. Set 4 re -run GLMs at +/- 7,500', +/- 6,200', +/- 4,800' and +/- 3,300'. d. Run ESP cable around Minor OD of the GLMs (will not fit across Major OD). e. Test ESP cable every 1,000' going in hole to confirm electrical integrity of the electrical system. f. Have 3-6 extra joints of 3-1/2" TC -II to replace any bad joints. 11. Set base of the Completion at (+/-) 8,231'. Land tubing hanger. 12. Set BPV, ND BOPS, NU Tree, test tree to 3,000 psi. a. Note: Do not exceed the pressure rating of the wellhead penetrator. 13. RDMO workover rig and equipment. 14. Turn well over to production. Attachments: 1. As -built Schematic (proposed Schematic is the same) 2. BOP Schematic 3. Forward Fluid Flow 4. Wellhead Diagram 5. Procedure Change Form I Cilcorp AlaAa. LLC RIIAUC/6L1a ANN. WColll� Perforation DZI-11116"HC Size Type Wt/Grade Top naa^ CONN / ID 2 ,� Structural 10,934' Surface 33 11mt1 Cemented 3 Surface 47#, J-55 DV Collar 47#, J-55 Surface 1,496' 1,498' a 8R / 11.000" w coq: 7" Surface 29#, N-80 �Toar 10,994' BT / 6.184" 700sxs 116# (stage 1), 700sxss 116# (stage 2) 23#, N-80 87' 4,794' BT/6.366" 5 1L8R 16.276" 29#, N-80 6,701' 7,087' L8R / 6.184" 6 LSR / 6.184" 29#, N-80 7,089' 8,514' L8R / 6.184" 29#, P-110 8,514' 8,575' 1-8R / 6.184" 5" Liner e 8,236' 10,835' FL4S 14.276" 90 bbl 15.8 ppq 2-7/8" Liner a rued m[ 11,159' EUE 8rd Mod / 2.441" 10 bbl 15.6 ppg Tubing arTat — ��Fleneaa gsrssals 9.2#, L-80 Surface 8,049' 181a� Production Strin Jewel Detail .• sPiceicy # De th (RKB Len th . taut han to' Item 1 sssoma 0.6' 2.992" 4.250" e,msls 2 3,323' 6.33' Crvlusol 5.140" GLM, GLMAX-1.ORSL Drift=2.867" 3 4,825' 6.33' 2.992" 11 �� 4 6,203' 12 2.992" ty6^pglt'rrF' mpwma atllgtsa , vaa4esrr �. Irpta� 11awx1 re"XIP r*1 K2 E14 Top 27Arliw 14718 7D=11,160' P13TD-11,050' SCHEMATIC Swanson River Unit Well: SRU 21A-34 Completion Ran: 10/19/13 PTD: 190-059 API: 50-133-10171-01 Casing and Tubing Detail Perforation DZI-11116"HC Size Type Wt/Grade Top Btm CONN / ID Cement / Other 22" Structural 10,934' Surface 33 11mt1 Cemented 11-3/4" Surface 47#, J-55 DV Collar 47#, J-55 Surface 1,496' 1,498' 1,496' 1,498' 3,030' 8R / 11.000" 600sxs 116# (stage 1), 1250sxs 116# (stage 2) 7" Surface 29#, N-80 Surface87' 10,994' BT / 6.184" 700sxs 116# (stage 1), 700sxss 116# (stage 2) 23#, N-80 87' 4,794' BT/6.366" 26#, N-80 4,794' 6,701' 1L8R 16.276" 29#, N-80 6,701' 7,087' L8R / 6.184" DV Collar 7,087' 7,089' LSR / 6.184" 29#, N-80 7,089' 8,514' L8R / 6.184" 29#, P-110 8,514' 8,575' 1-8R / 6.184" 5" Liner 18#, N-80 8,236' 10,835' FL4S 14.276" 90 bbl 15.8 ppq 2-7/8" Liner 6.5#, N-80 10,276' 11,159' EUE 8rd Mod / 2.441" 10 bbl 15.6 ppg Tubing 3-1/2" Prod 9.2#, L-80 Surface 8,049' TC -II 12.992" CP[q CPIOD = 3.887" Production Strin Jewel Detail # De th (RKB Len th ID OD Item 1 25.85' 0.6' 2.992" 4.250" Tubin Han er, 3-1/2" IBT Lift Threads 2 3,323' 6.33' 2.992" 5.140" GLM, GLMAX-1.ORSL Drift=2.867" 3 4,825' 6.33' 2.992" 5.140" GLM, GLMAX-1.0RS1- Drift=2.867" 4 6,203' 6.33' 2.992" 5.140" GLM, GLMAX-1.ORSL Dri4=2.867" 5 7,525' 6.33' 2.992" 5.140" GLM, GLMAX-1.ORSL Drift = 2.867" 6 8,049' - - 4.000" To of ESP, ':-Charge Head 7 8,145' 4.000" ESP Intake 8 8,231' - - 4.560" Btm of ESP, 456 Mators / 400 Pumps 9 8,236' - - - Liner top packer 10 ±9,057' 9.36' 2.555" 3.96" Seal Bore Extension 11 9,100' 1.27' 1.875" 2-3/8" Halliburton X Nipple 12 ----(1,150' 5.86' 1.99" 3-15/16" Tristate Overshot 13 10,157' 6.27' 1.99" 2-3/8" GLM 14 10,169' 3.07' - Baker DB Packer w/ R Guide & millout extension Directional Data: max hole angle = 36.5° at 10,700' MD Downhole Revised: 10/19/13 Updated by DMA 06-21-19 Perforation DZI-11116"HC ZONE TOP BTM Shot Condition H-1 10,918' 10,920/16" ' f jumbo *et IN9/10/90 10,920' 10,934' 4s f/6"'ubo'etII 9/10/90 11mt1 6"'umbo'e11 9/10/90 1,948' 0 0968 1,0' 4's f/16" umbo'etIII 9/10/90 H 10,966' 10,980' 4is f 2/210,980' 10,994' 4's f 1-11/16" HC 2/26191 Downhole Revised: 10/19/13 Updated by DMA 06-21-19 ❑a Swanson River SRU 21A-34 Current 10/21/2019 Swanson River Tubing hanger, FTC -ESP, SRU 21A-34 7 X 3.725 MCA acme lift x 11314X 7X3% 3Yz IBT susp, w/2-%4 control line exits, prepped for BIW Kwiklok penetrator, DD material 31/8 SM Tree assy - = Adapter, Velco ESP, 71/16 3M rotating flange X 31/8 5M, 2-'/4" control line exits, Prepped for BIW Kwik Lok and VG seal carrier Tubing head, Vetco-FTC-IT,''— d G. _ -` Ground Level 13 518 3M X 71/165M w/2 -21/165M SSO, BG * bottom Casing head, Shaffer KD, 13 5/8 3M X 113/4 SOW, w/ 2- Y' LPO, 7' KD slips and packoff assy in head i a R- b -7 00 O O D a IT M N m 7 d U O a` L 7 N a m O Q a 0 U) d Ol C R t U U d .O 3 N t a� 0 O aci C d .d+ w > R Q L V R R C U O y 0 Q as a -- N y 2 0- Ca C Q a dW =d m w � C a - M � 'O N ci Z4 d rn L R r U 7 d U O a` Y R d R IL v d N El N m 0 a d m Q d a d N C L L V) C D y Schwartz, Guy L (CED) From: Ted Kramer <tkramer@hilcorp.com> Sent: Monday, October 28, 2019 2:55 PM To: Schwartz, Guy L (CED) Subject: RE: [EXTERNAL] SRU 21A-34 sundry (PTD 190-059) Attachments: Yellowjacket BOPE STACK DRAWING.pdf, SRU 21A-34 Schematic 06-10-19.pdf G uy, This is a new BOPE stack. Hilcorp is in the process of switching BOP stacks away from Weatherford to Yellow Jacket. The reason for doing so is that Weatherford is in bankruptcy and there is a concern that they will not be able to maintain their fleet of Certified stacks. Yellowjacket offered brand new certified stacks so hilcorp is looking to go that direction for 7-1/16", 11", and 13-5/8" stacks. I will get the drawing corrected. As far as the SRU 21A-34 drawing it is a little misleading. The Seal bore Extension (Item #10) is actually full ID at the top and is what is holding the rest (11,12,13) in place. The packer above the seal bore was milled up the last go round. 13 should be connected to 14. 1 will have Donna correct it. Ted Kramer Sr. Operations Engineer Hilcorp-Alaska LLC Office — 907-777-8420 Cell— 985-867-0665 From: Schwartz, Guy L (CED) [mailto:guy.schwartz@alaska.gov] Sent: Monday, October 28, 2019 10:41 AM To: Ted Kramer <tkramer@hilcorp.com> Subject: [EXTERNAL] SRU 21A-34 sundry (PTD 190-059) Ted, Looking at the sundry.. are these new BOPE's?? What will be the ram configuration? The attached sheet doesn't show VBR and what is CSO ram? The schematic is a bit misleading too... the GLM at 10157 ft should be attached to the DB packer. It looks like a "fish" now. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOT/CE: 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 190-059 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED .JUN 21 2019 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull Tubing Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate Alter Casing El Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool r❑ El Repair Repair Well Re-enter Susp Well ❑ Other: Replace ESP ❑✓ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 15. Permit to Drill Number: Name: Development Q Stratigraphic❑ Exploratory ❑ Service ❑ 190-059 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-10171-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028406 Swanson River Unit (SRU) 21A-34 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 11,160 feet Plugs measured 10,191 (PX Plug) feet true vertical 10,859 feet Junk measured 10,191 (PX Plug) feet Effective Depth measured 11,050 feet Packer measured 9,057'; 10,169' feet true vertical 10,764 feet true vertical 9,049';10,034' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 33' 22" 33' 33' Surface 3,030' 11-3/4" 3,030' 3,029' 3,070 psi 1,510 psi Intermediate Production 8,575' 7" 8,575' 8,571' 6,340 psi 3,830 psi Liner 2,599' 5" 10,835' 10,578' 10,140 psi 10,490 psi Liner 883' 2-7/8" 11,159' 10,858' 10,570 psi 11,160 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 8,049' MD 8,049' TVD HES BWD; 9,057' MD 9,049' TVD Packers and SSSV (type, measured and true vertical depth) Baker DB; N/A 10,169' MD 10,034' 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: 157 115 2242 231 235 Subsequent to operation: 1169 34 2649 228 29 14. Attachments (requ!Md per 20 AAC 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory❑ Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ✓ Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-154 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: 1ramer(o3hilcoro.com Authorized Signature: 49414av'664 4(2047. Dale S%H-'C ltsl q Contact Phone: 777-84209 7, .Or r/<'ylf 9'- r -a r f RMS—IfeWJUN 2 51019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 1 190-059 3/28/19 1 6/10/19 Daily Operations: 03/28/2019 - Thursday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,500 psi high. RIH w/ 1-9/16" x 4' tubing punch and tie into schematic. Tagged top of ESP at 8,049'. Ran correlation log. Fired gun with 800 psi on tubing and 825 psi on IA from 8,000' to 8,004' (25 shots). After 15 min both had 810 psi on them. POOH. All shots fired. Rig down equipment and moved to SRU 213-15. 05/01/2019- Wednesday PJSM. Rotate Pit liner. Repair holes. Set Rig beam, back in carrier, pits, choke, accumulator unit. Gen set, Bang board, Pump, Fuel tank. Berm in location. Load fluid into pits. RU flange x 1502 on tubing. PT lines 250/3,500 psi. Pump down 3.5" tubing and take returns of gas to IA and gas buster. Pumped 260 bbls of KCL to kill well. Send rig floor Stairs to D&D equipment for repairs. Wellhead tech on location. Set BPV. Nipple down production tree. Nipple up 7" BOPE . RU rig floor, set wind walls. RU kill and choke lines. Make up 3.5" test joint, cross overs and TIW, Dart valve. Install test joint. Shell test BOPE. 250/2,500 psi. Test pump broke down. Looks like contactor in switch box. SDFN. 05/02/2019 - Thursday PJSM. Location walk around complete. Review BOPE test procedure with crew. 24 hr BOPE test witness notification sent 4/30/19 @ 13:41 . Witness waived by Jim Regg 4/30/19 @ 1907 hrs. Make up dart valve, TIW valve, x overs and test joint. Install test joint. Start BOPE test. Not able to test pipe rams or bag due to Test joint sub and hanger sub being off centric in hanger due to ESP power cable and flat pack cable. Wellhead hand depart for Nikiski for donut (larger OD x over). Spot Genset, Function test equipment. Continue with last BOPE test. Pipe rams, TIW valves and chokes. Location walk around complete. SDFN. 05/03/2019 - Friday PJSM. Remove VBR rams from 7" BOPE. Install solid body 3.5" rams. PT rams 250/2,500 psi. Good test. Remove test joint. Make up landing joint and x over to hanger. Back out hanger lock down screws. Insure tubing and IA are on a vac. 0 psi. Install Empty drums in Summit spooler. PU on hanger. Unseat at 84K. Clean PU Weight. ESP tech remove cable and control line. Remove SS clamps and pup joints. Rack back first stand leaving 3.5" IBT x 3.5" TC -II x over on top of stand. Start tripping OOH racking back stands and spooling ESP cables. 46 stands racked back. 2,814' of tubing OOH. Current depth 5,235'. RIH with stand and secure 3.5" tubing in pipe rams. Set slips. RU floor safety valve (TIW) Make up 1502. Bullhead 65 bbls of produced water down tubing. Secure well. SDFN ap� Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 190-059 1 3/28/19 1 6/10/19 Daily Operations: 05/04/2019 -Saturday PJSM. Location walk around complete. Check WHP 0 psi. Continue to trip OOH with 3.5" tubing and spool ESP cable on reels from 5,235' RKB. PU wt 60K. Remove Stainless steel bands. 921 total recovered. Tubing tally says 861 bands. Cut spliced cable at 4,100' Secure and wrap drum. Swap with Empty drum. Continue to Trip OOH . Strapping each row of stands in Derrek. Lay down 4 GLM and 3 singles. 124 stands racked back. 22 bbls pumped while OOH, POOH. SIMOPS with SLB. Pump 30 bbls produced water down 7" casing. Load pits with 120 bbls of produced water. Break down and lay out SLB ESP. Pollard Slick line on location. Pre job safety meeting and SIMOPS. RU 5.9" gauge ring and junk basket to 6 082' stackin weight. OOH, POOH to surface. Found fluid level at 5,200'. Make up 5.81" gauge ring and junk basket. RIH to 8,221' RKB. Tagging liner top (8,236') 15' difference with SL measurement. OOH, POOH to surface. Make up 4.0" junk basket RIH through liner top and tag 9,035'. Make up Selective set plug. RIH. Tagged 9,042' SLM. OOH, POOH to surface. Tagging top of sealbore assembly. Make up GS pulling tool. RIH, tag top of plug at 9,042' to retrieve plug. POOH to surface. Pump 27 bbls of produced water or 702' of fluid. Should put calculated fluid level at 4,498'. Make up 5.81" gauge ring to find fluid level. RIH and tag fluid at 4,520'. PU and wait 15 minutes. RIH tag fluid at 4,520'. PU and wait 15 minutes. Still tagging fluid at 4,520' OOH, POOH to surface to pump more fluid. OOH with SL. Close Blind rams. 50 additional bbls of produced water. Pits empty. RIH with SL to tag fluid level. Tagged at 1,700'. 5 minutes fluid level still at 1,700'. OOH, POOH with SL and lay down. Secure rig and location. Rig out of fluid. Forward plan. Fill wellbore and test casing against plug, 1,500 psi for 30 minutes. �A P ( i IT ql-� S I L'- Ic C; , Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig AN Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 1 190-059 3/28/19 1 6/10/19 Daily Operations: 05/05/2019-Sunday PJSM. Hold safety meeting. Fluid level at 1,700'. Vac trucks on location. Continue to fill casing with 65 bbls. RU pressure test charts. Pressure up 7" casing to 1,500 psi and chart for 30 minutes. Bleed down. Good PT. RU Pollard SL. RIH w/ 2- 3/8" GS to 9,040'KB WT- Overpull and friction bites. Not able to latch GS profile. POOH to surface. RIH w 2-3/8" GS with knuckle. to 9040' SLM Work tool with Friction bites cannot latch. OOH, POOH. SCALE/ASPHALTINES IN TOOL. Double Knuckle attached. RIH with 2.375" GS to 9,040'. Work spangs. cannot get over pull. POOH to surface. RIH with 1.73" LIB to 9,041' KB. POOH w LIB. Impression of seal bore or GS profile. Sharp angle. RIH with 2.375" GS with double knuckle to 9,041' KB work tools. Small 200-300 Ib overpulls. POOH to surface. Not able to latch. RIH with 2.24" LIB to 9,041'. POOH with LIB. Small dings around corner. RIH with 3.84" centralizer 10' stem GS to 9,041' KB. Work tool string. Friction bites no latch. RIH with K Kick over. Centralized. 2.375" GS to 9041' Small overpulls no latch. RIH with 1.75" x8' pump bailer to 9,041' KB. Work tools. POOH 2 cups of shavings/scale. Feels like thick grit mud. RIH w/ same to 9,040' KB. Work tool string. POOH. Bailer has 1/4 cup of metal shavings/scale. RIH with pump bailer to 9,041' KB. POOH 1/2 cup of scale/shavings. RIH with K series Kick over tool as centralizer with 2.375" GS to 9,041'. Work tool string. Small friction bites. NO latch. POOH to surface. RIH w/ 8' X 1.75" pump bailer to 9,042' KB, POOH. RIH w/ 1.5 DD Bailer to 9,043' KB, Drive down bailer empty. RIH w/ 2-1/2" RB w/ 1-3/4" Bait sub (1' long) w/ Xo w/ 5'X 1-3/4" Hyrdostatic bailer w/ 5'X 2.25" Bailer on bottom to 9,047' KB w/t 9049' KB, POOH, empty. RIH w/ 2" Gs w/ k KOT on top to 9,045'KB, w/t, POOH to surface. No latch. RIH w/ 1.75" Magnet to 9,033' KB, POOH. Empty. RIH w/ 2-3/8" Braided line brush to 9,042' KB. RIH w/ 1.75" Magnet w/ K KOT above to 9,045' KB, POOH. Magnet empty. RIH w/ 2" Gs to 9,046' KB, w/t can't latch POOH. RIH w/ 2" JUC w/ baited 1.75" Hydro bailer to 9,041'. Work tool string. Fell to 9,049'. OOH, POOH. Break down bailer. Bailer empty. 05/08/2019- Wednesday PJSM. Location walk around complete. Discuss laying down the 3.5" TC-II. Fire equipment. Verify 0 psi on well. Open pipe rams. RU to trip in hole. Swap Weatherford power pack for tongs. Lined up to take pipe displacement (fluid) from IA to pits. Trip in hole with production tubing. 3.5" TC-II. 124 total stands in Derrek. 7,757.68' in hole. Adjust draw works brakes. Rig down ESP sheave from. Trip OOH laying down 3.5" TC-II joints. Hot shot jars arrived from Carlyle. Only 3 pieces on pallet. Attempt to call NOV to verify shipment. 30 stands out of hole. 5,322' of tubing remain in hole. RU longer bails to assist in transitioning pipe from elevators. Install TIW valve. Close pipe rams. Fuel equipment. SDFN. Location walk around complete. 05/09/2019 - Thursday PJSM. Holds safety meeting. Fire equipment. Location walk around completed. Trip OOH with remaining 5,322' of TC-II tubing. All tubing OOH and placed in containment on edge of pad. Close blind rams. Break open pipe rams. Swap 3.5" fixed rams for 2-7/8" fixed rams. Make up Kelly hose. Spot and function test power swivel. Lay out 2-7/8" PH-6 tubing and strap. Change slip dies, RU Foster tongs and dress for 2-7/8" tubing. Make up Test plug, test joint FSV, and IBOP/Dart valve. Fluid pack and shell test ROPE. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig AN Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 1 190-059 3/28/19 6/10/19 Daily Operations: 05/10/2019 - Friday PJSM. Location walk around complete. Fire equipment. Verify 0 psi on well. Open blind rams. Test BOPE on 2 7/8" tubulars. 250/2,500 psi on all rams and valves. Chart each test. 24 hr BOPE test witness notification sent 5/9/19 @ 0745 hrs. Witness waived by Jim Regg 5/9/19 @ 14:57 hrs. Test gas alarms with Total Safety. Call Weatherford BOPE tech to location at 12:30 pm. Pipe ram door hinge pin seals leaking hydraulic fluid. Install Kelly hose. Measure length for new hose. Weatherford Wellhead tech on location 16:30 hrs. Rig crew assist Weatherford tech on repairing seals on Pipe ram door hinge. Remove annular bag to access bolts. Change out seals. Nipple up annular bag. Mu test joint and test plug. Fluid pack lines and shell test 250/3,500 psi charted. Good pressure test. 05/11/2019 -Saturday PJSM. Fire equipment. Verify 0 psi on well. Open blind rams. Make up Kelly hose extension. Ru handling equipment to pick up BHA. Rebuild stripper head. RU Foster tongs. PJSM with Weatherford tool hand and rig crews about making up BHA. Discuss and verify torque specs. Troubleshoot foster tongs. Change out for back up fosters and function test. Continue to make up burn shoe BHA. Pick up singles of 2-7/8" PH6 work string from 146' to 2,213' . Slack off weigh 20K. Drift each joint while picking up. Draw works brakes not stopping blocks. Troubleshoot issues with brakes. Brakes are stopping as required. Continue to RIH from 2,213' to 4,558' Slack off weight 35k. Make up and close FOSV and close pipe rams. Well secure. Location walk around complete. Shut down for night. 05/12/2019 -Sunday PJSM. Verify zero psi on well. Open blind rams. Start up rig. Service rig. Grease crown, blocks, carrier and tongs. RIH with 2-7/8" work string and milling assembly (4.06 " crown shoe) f/4,558'to 5,015". Observed leak on Foster power tongs. R/D Fosters and R/U Mccoy power tongs. Swap fittings to use rig lift cylinder. Dress to 2-7/8". Attempt to RIH. Mccoy make up jaws would not bite pipe. Attempt to adjust w/o success. R/D McCoy tongs and pick up original set of Fosters. Hang from ODS tugger and tie tugger back to derrick to prevent snagging on blocks. Good function test on foster tongs. Continue RIH F/5,015' to liner top @ 8,266'. 49.5 slack off weight. Tag liner. Set down 1K. Use Fosters to rotate string and roll off liner top. Continue in hole at reduced speed to liner packer @ 9,048'. Set 4k Confirm tag up. PUW 64K. Lay down 2 jts to 9,006'. PJSM with rig crew and Cruz loader operator. M/U kelly valve and X/O to power swivel. Pick up power swivel. Modify rig floor for static lines. Secure static lines to BOP stack. M/U FOSV and close same. Close UPR's secure well. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 1 190-059 1 3/28/19 1 6/10/19 Daily Operations: 05/13/2019 - Monday PJSM. Verify 0 psi. Open well. Start up rig. Location walk around complete. Continue to RU power swivel. Troubleshoot issues with swivel power pack motor not starting. ESD switch on remote panel had broken wire. Rewired switch and function test. Adjust and re -rig torque arrest lines. Add back up slings to each line and tie back to fingers on board so lines don't twist. Remove Off driller side wind wall to allow 80'3" Kelly hose to articulate. Fix issues with setting torque on power swivel. RIH with jt# 292 to 9,036'. Break out power swivel and Kelly up on joint 293. Make up to string. Pick out of slips. Break circulation @ 1 BPM. Stripping head rubber leaking. Rig up 3" trash pump to assist returns to pits. Stripper rubber leaking less. Walk pump up to 3 bbls/min. @ 650 psi. Wash down to top of packer. SOW 50K. Tag with 2k down at 9,047' RKB. Adjust brakes on rig. Pick up 8' @ SOK . Begin rotating @ 120 RPM and 800 ft/lbs of torque off bottom. Slack off at top of packer @ 9,047'. Begin burning over HES BWD packer. Length from top of packer to bottom of slips 30". Cut 40" over packer. Made it to 9,050.5'. Burp of gas at surface . Swap to gas buster. low level LEL alarm at pits. Picked up to 9,040' Circulate bottoms up at 3 bbls/min 1,800 psi. Magnet shows metal returns at pits. 9,722 strokes. 292 bbls pumped. Break Kelly hose. Lay down power swivel. Trip OOH with 2-7/8" PH6. Rack back 15 stands. 8,153' of pipe in hole. 83' above liner top. Install TIW valve set slips and lock. Close pipe rams and secure well. Location walk around complete. SDFN. BHA details. 2-7/8" PH6 x 2-3/8" SL H90 3.38" OD x 1.04': 4 x slick drill collars 3.13" OD x 117.66': 2-3/8" SLH 90 x 2-3/8" Reg 3.06" OD x 1.15': 3-1/8" Bowen Jar 3.13" OD x 8.48': 2-3/8" x 3-3/4" FJWP 3.75" ODx1.73' : 3-3/4" wash pip pup 3.75" OD x 4.56': 4-1/16" Crown shoe 4.06" OD x 2.15'. Weatherford BHA. 05/14/2019 -Tuesday PJSM. Verify zero psi on well. Open blind rams. Start up rig. Pull out of hole from 8,153' to 6,751', PUW= 50K, Develop leak on carrier water pump. PJSM, Drain radiator on carrier in preparation to change out defective expansion boot on water pump. Fill Radiator with gycol. PJSM, Cont pulling out of hole from 6,751' to surface, repair strong arm for fosters tongs, PUW=40K, Joint 286 is cut in half leaving 7 joints and BHA in hole. 376' of fish, Top of fish at 8,673' MD. Wait on overshot from Weatherford, put away rig 404's kelly hose, fuel rig and clean up location. PJSM, change out broken grapple in overshot, make up overshot as per fishing rep and secure well. 05/15/2019- Wednesday PJSM, Start up rig, Verify zero psi on well. Open blind rams. RIH from surface to 2,130' MD with overshot, monitor displacement with trip sheet, SOW= 25K Flush brake cooling water tank with clean water and refill RIH from 2,130' MD to 3,535' MD with overshot, monitor displacement with trip sheet SOW= 30K Adjust breaks and buff. Drawworks drum, change out transmission selector and change out control for break assist. RIH from 3,535' MD to 4,630' MD with overshot, monitor displacement with trip sheet SOW= 40K Troubleshoot drawworks cooling system, adjust nozzles for cooling water, attempt to adjust brakes to warm up ODS brakes. Call mechanics out with new brake pads. RIH from 4,630' MD to 5,480' MD with overshot, monitor displacement with trip sheet SOW= 40K. Shut down rig. Install TIW valve. Close rams. Hang blocks with tugger line. Begin to disassemble brakes. Prep for new brakes. Remove brake bands and pads. Mechanic cleaning up braking surface on draw work drums with fapper wheel. Install new brake banks and pads. Location secure. SDFN. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig AN Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 1 190-059 3/28/19 1 6/10/19 Daily Operations: 05/16/2019 - Thursday PJSM, Start up rig, Verify zero psi on well. Open pipe rams. RIH from 5,480' to top of fish at 8,673" MD with overshot, monitor displacement with trip sheet, SOW= SOK Swallow fish as per WTF fishing rep, PUW=52K SOW=50K, set 10K on fish, pick and observe 4K overpull indicating a good latch on fish. PJSM, Pull out of hole with fishing BHA from 8,673' to surface, no fish in overshot, broken grapple and scarred up guide shoe. Call out Pollard Slick line. Discuss plan forward with town. Rig up Pollard slickline with weight bar, spangs and 4" OD LIB. RIH to top of fish at 8,763' with 4" OD LIB and pull out of hole. Half moon mark looks like edge of 2-7/8" tubing with small debris. Side of LIB had marks from hitting liner top. RIH with 3.5" OD pump bailer to top of fish and attempt to clean off top of fish, pull out of hole. Pump bailer empty. Secure well by closing blinds. RDMO slick line. 05/17/2019 - Friday PJSM, Start up rig, Verify zero psi on well. Open Blind Rams. Location walk around complete. PJSM, Pick up and make up 2-7/8" test joint with TIW and Dart valve, grease all choke and kill line valves, fill stack PJSM, Test BOPE 250/2,500 PSI High for 5 Min each, Chart all tests. 24 hr test witness notification sent 5/16/19 @ 8:09 AM. Witness wiaved via email by Jim Regg 5/17/19 @ 2:09 PM. BOPE test for sent to state. PJSM, Prep rig floor to RIH, Make up Fishing/Burn BHA, Discover first few joints have grooves cut in tube section, Laydown bad drill pipe, decision made to add boot basket to clean out liner on trip in the hole. PJSM, RIH with 2-7/8" DP inspecting pipe on the way in the hole for cuts or grooves out of the norm. RIH from surface to 8030' MD, SOW= 55K. Stab TIW valve. Shut pipe rams. Wellsite secure. SDFN. 05/18/2019-Saturday PJSM, Start up rig, Verify zero psi on well. Open Blind Rams PJSM, RIH with 2-7/8" DP inspecting pipe on the way in the hole for cuts or grooves out of the norm. RIH from 8030' to top of fish at 8763' MD, SOW= 55K. PUW= 56K, SOW=52K, Work of fish as directed by WTF fishing, PUW=56K, SOW=52K, Observe overpull of 5-6K indicating good latch, fish hanging up in liner pull up to 80K Rig up stripping head and head pin, circulate in an attempt to clear debris from around fish, 100 spm=2,200 PSI PJSM, pull out of hole from 8,763' to surface with fish, observe overpulls up to 80K as pulling through liner, no over pull inside 7" casing PJSM, Lay down fishing BHA as per WTF fishing, release grapple and lay down fish, everything left in the hole was accounted for. Secure well and shut down rig Plan forward E line will be out in the AM to see if we can get a cutter below packer. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 1 190-059 3/28/19 6/10/19 Daily Operations: 05/19/2019 -Sunday PJSM, Start up rig, Verify zero psi on well. Open Blind Rams PJSM, RIH on E -line with CCL, Weight bar and jars, CCL failed, pull out of hole and repair, RIH to 1,500' comms failed again pull out of hole and remove jars from tool string, log packer at 9,057' and tag at 9,066', POOH. Call out Slick line crew. Make up 1.75" LIB on E -line. RIH and tag LIB at 9,066' and POOH. Half moon shape on edge with debris on top. Bring Slick line truck to location. Wait on slick line crews. Rig up slick line with .125" wire. RIH w 1.75" pump bailer to 9,062' KB work tools fall to 9,073' KB work tools. sit down again at 9,062' cannot pass packer top. POOH. Bailer full of oil. RIH w 2-3/8" PR baited with 2-3/8" GS to 9,063' KB . Work tools to 9,065' KB. Get 600 # overpull. POOH. Pin sheared on GS. RIH with 2-3/8" GS to 9,060' KB, work tool . POOH with bait sub and PR. RIH with 2-3/8" PR with bow spring and bait sub and 2-3/8" GS to ,9063' KB. Work tools. Get 600 # overpull. Cannot pass packer top. POOH. RIH with 1.80" Magnet and bow spring centralizer to 9,063' KB. Work tools. Get 600# overpull POOH. Magnet full of small shavings. Rig down Slick line. Close blind rams. Wellsite secure. SDFN. 05/20/2019 - Monday PJSM, Start up rig, Verify zero psi on well. Open Blind Rams. Make up Burn shoe as per WTF fishing rep. Pick up 24 joints and RIH to top of fish at "'9,050', SOW= 51K. Pick up Power Swivel, make up hyd hoses, make up Kelly hose, install strong arms and static lines, install stripper head rubber. Mill Packer as per WTF fishing rep, 97 SPM= 1,850 PSI, 120 RPM= 2- 2.8K on, 2K off, PUW=62K, SOW=51K ROT=57K. Lay down power swivel. Pull 15 stands to top of liner PUW=62K, Observe overpull up to 80K at 8,885' MD, work through obsructions every —40' to top of liner. 05/22/2019- Wednesday Hold PJSM w/ crew Start up Rig Warm up gen sets. POOH and stand back 3-1/2" Work string and L/D Weatherford Spear. R/U Pollard slickline and RIH # 1 w/ LIB 3.9" OD t/ 9,046' POOH and No unusual marks. Run # 2 w/ 1.81" LIB. RIH and Tag up @ 9,050'. POOH 2 Marks on Side face of LIB. R/D LIB and M/U slickline w/ 1.75" OD Junk pump bailer. Run #19,053'. POOH and Empty 3" Fill rerun # 2 t/ 9,057'. POOH and Empty Run #2 4" of fill Rerun # 3. Continue RIH w/ pump bailer # 3 tag up @ 9,053'. POOH w/ Empty run # 3 8" fill. RIH w/ # 4. POOH with 2" fill made very little process discuss with town for forward plan. 05/23/2019 - Thursday Hold P1SM w/ crew and service 401 rig and Weatherford tool hand Building mule shoe with 1-1/2" WTS joint and ship to drill site. M/U 1-1/2" WTS-8 Mule shoe joint, 3 -XO, 2 2-3/8" Boot Basket and XO. Continue RIH w/ 2-7/8" PH 6 Work string and checking each Connections for correct toque RIH T/8178'. Stab TIW valve and secure rig resume at AM tomorrow. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 1 190-059 3/28/19 6/10/19 Daily Operations: 05/24/2019 - Friday PJSM w/ crew Start up Rig. Continue RIH F/ 8,178'T/9,032'. M/U circulating hose and brake circ @ 1.5 bbls min w/ 400 psi,2 bbls min w/ 700 psi wash down slow and tag up 9,057 'wash down t/ 9,058'' w/ DPM and pump long way for 15 mins & Reverse Circ 2X BU. POOH and Stand Back 2 7/8" PH 6 work string. L/D Boot Basket, and clean out 1/4 of a 5-gal bucket fine scale, L/D Mule shoe. R/U to Test BOP. AOGCC witness waived by Jim Regg send @ 5/24/19 8:52 by E-mail. Total Safety tested. All Gas detection system. All good. Test Choke Manifold. All Valves T/ 250/ 2,500 PST 5 mins each, Blind Rams, Pipe Rams, All floor safety valves, Dart. R/D All test equipment and Secure well. 05/25/2019-Saturday PJSM w/ Crew, Discuss forward-plan and Start up Rig. M/U 2-3/8" Mule shoe joint and XO t/ 2-7/8" PH 6 Work -string. Continue RIH w/ 2-7/8" Work-string F/ Derrick t/ 6,500'. Work on Draw works breaks, saturated with water. RIH with 2- 7/8" out of derrick from 6,500' to 9,058'W/ DPM. Space out pipe on wireline plug, rig up to circulate, mix high vis pill in vac truck. Pump high vis pill, 87 SPM= 1,650 psi, repair mud pump lube chain issues. PJSM, Rig up slickline with plug retrieval tool, continue circulating 43 SPM= 700 psi RIH with plug retrieval tool, no success. RIH with Magnet X2 runs, 2" piece of metal on first run, clean on second. RIH with plug retrieval tool, no success POOH and R/D Pollard slickline unit. 05/26/2019-Sunday PJSM, Start up rig, Verify zero psi on well. Open Pipe Rams. Pick up joint and make up circulating hose. Reverse circulate on top of plug, 75 SPM= 1,100psi, work pipe up and down to seal bore XO to wash off plug face, total of 7.5 bottoms up. PJSM with Pollard E-line, rig down circ hoses, rig up Pollard E-Line. RIH with CCL to obtain exact depth off logs, tag junk in drill pipe at 8,672' and push down to 2-3/8" XO to 9,040'. POOH with E-line. Mu 1.75" magnet to bottom of E-line BHA. RIH. 4 small chunks of metal recovered. PJSM, Rig up circulating hose and reverse circulate 100 SPM= 1,700 psi. Rig down circ hose and lay down one joint. More metal chunks recovered. RIH with CCL and Magnet to 9,051'. POOH with E line. CCL log showing we are sitting down at sealbore assembly x 2.375" x over. Good 1" long metal chunk recovered. Call out pollard slickline for morning. Call MI SWACO for some gel. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 190-059 3/28/19 1 6/10/19 Daily Operations: 05/27/2019 - Monday PJSM. Location walk around complete. Rig crews empty pits and clean. Add new produced water to pits. Mix 2x 30 bbl high vis N-vis pills. SIMOPS PJSM with rig crews and pollard slickline. RIH w/ 1.75" magnet to 8,680' RKB, work lightly, fall to 9,063' KB, POOH. OOH w/ small chunk of metal and metal shavings. RIH w/ same to 9,063' KB (bobbled through spot at 8,680'), POOH slowly. OOH w/ 2 large chunks of metal and shavings. RIH w/ same to 9,062' KB, POOH slowly. OOH w/ metal shavings, and brass ring off of packer. OOH with slickline. Insall night cap on SL head. Reverse circulate at 4.6 BPM. 1,580 psi pump pressure. Pump 2x 30 bbl gel sweeps. Metal chunks in Rig pit possum belly. RIH 1.75" magnet to 9,062' KB, POOH slowly, tight spot around 8,700' KB, OOH w/ large chunk of metal and shavings. RIH w/ same to 9,066' KB, POOH slowly, tight spot around 8,700' KB, OOH w/ large chunk of metal and shavings. RIH w/ same to 9,067' KB, POOH slowly. OOH w/ 2 small chunks of metal. Possibly scale on tools. RIH w/ 1.75 pump bailer to 9,067' KB, w/t appear to lose pump action, POOH. OOH empty, bailer bottom has large flat spot on edge. RIH w/ 1.73" LIB to 9,067' KB, tap down twice, POOH. OOH w/ metal marks in center of LIB. RIH w/ 1.75" magnet to 9,068' KB, POOH. OOH w/ small chunks of metal. SL OOH. Secure wellsite. SDFN. Plan forward. Continue magnet runs in AM with slickline. 05/28/2019-Tuesday PJSM with Pollard slickline. Fire up rig. Check well for zero psi. Open pipe rams. RU on well with Pollard slickline. Tighten tool string. Make up 1.75" magnet. RIH w/ 1.75" Magnet to 9,069' KB, POOH slowly. OOH w/ ground up black metal. Possibly scale. RIH w/ same to 9,069' KB, POOH slowly. OOH w/ small bit of ground up black metal. RIH w/ 1.75" hydrostatic bailer to 9,071' KB, w/t 9,074' KB, POOH. OOH w/ 2" of same black material. RIH w/ same w/ ball bottom to 9,073' KB, w/t 9,075' KB, POOH. OOH w/ 3" same black material and metal shavings. RIH w/ 1.75" Magnet to 9,071' KB, POOH slowly. OOH w/ 1-1/2" long sliver of metal. Black material and metal shavings. RIH w/ same to 9,071' KB, POOH slowly. OOH no metal, covered in same black scale like material. RIH w/ 1.75" Hydrostatic bailer w/ flapper bottom to 9,073' w/t 9,074' KB. POOH, OOH empty. RIH w/ 1.75" magnet to 9,072' KB, POOH slowly. OOH w/ same black material. RIH w/ same to 9,072' KB, POOH slowly. OOH w/ very small amount of black, scale like material. 1600 hrs E-line on location. PJSM. Spot unit. OOH w/ tools, rig down for a-line. Rig up E-line. RIH with 1.75" CCL. Rope socket, 2x weight bars, Bow spring centralizer and CCL with bull plug. Not able to pass 9,066'. Tagging on the seal bore assembly cross over. Multiple attempts to make hole. POOH to surface. Move bow spring centralizer from above the CCL to above the first weight bar. RIH. Not able to pass 9,066' at seal bore extension x over by 2.375" tubing . POOH to surface. Lay down E-line top chive. Pick up joint of 2-7/8" PH-06. RIH and stab into seal bore assembly with 2.375" stinger/mule shoe joint on end of PH-6 work string. Remove bow spring centralizer and run CCL slim. RIH with E-line. Work tool string. Not able to pass 9,066', slickline measurements off and no 5' rat hole was made or debris/mechanical damage of seal bore x over preventing E-line from entering 2.375" tub. At surface. Rig down E-line. Lay down 1 joint of 2.375" PH-6. Install x over and TIW valve. Close pipe rams and close choke valves. Location walk around complete. well secured. SDFN. Plan forward: Trip OOH with tubing and pick up 1-11/16" motor and mill assembly. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 1 190-059 3/28/19 1 6/10/19 Daily Operations: 05/29/2019- Wednesday PJSM, Check well for zero pressure. Open pipe rams. Location walk around complete. Trip OOH with 2-7/8" PH -6 tubing and 2.375" mule shoe joint. Lay down mule shoe joint and x over. MU Weatherford 1-11/16" motor and mill, jars, 2x weight bars. BHA length 37.01'. RIH with motor mill BHA and 2-7/8" PH -6 tubing to 8,876'. 2 stands out from tagging fill. Install TIW valve. Secure well. Hang blocks. Adjust draw works brakes. Grease and lube rig. Fuel equipment. Location secure. SDFN. 8 buckets of Flovisc ordered for AM. 05/30/2019 - Thursday PJSM with rig crew. Discuss plan for mixing Flo Visc gel. Check fluids and fire up equipment. Verify 0 psi on well. Peak vac truck loading produced water from pits and mixing Flo Visc pill. Rig down TIW valve and open pipe rams. Run out of Derrek with 2 stands. Attempt to stab into seal bore assembly with 1.75" 3 blade junk mill. Setting down on seal bore assembly at 9,049'. Not able to enter. Ru x over and 1502 swedge. Online 1 bbl//min. Lube pump chain drive gear worked off shaft. Shut down triplex pump. Install sprocket and chain. Function test triplex. Back up and running. Pumping down 2-7/8" tubing and returning up 7" to return pits. Confirm 1:1 rate. 670 psi to 700 psi free spin pressure. Jump in seal bore and wash down to 9,057'. Tagged. Motor stalled 1,300 psi. PU establish free spin and continue to attempt milling. Stalled motor 17 times. Send gel sweep 20 bbls. While working from 9,057' to 9,058'. Worked down on fish at seal bore x over to 2.375" tubing, saw 200 psi motor work and then lost returns for 30 seconds. Pump pressure dropped from 800 psi to 400 psi. Pressure and returns back to normal. Made it past 9,058'. Cleaned up debris on top of slick line test plug stuck in x over. Plug came free and dropped and seated in x nipple and 9,100'. Pump 20 bbl gel sweep. Continue washing down to 9,075'. NO increase in pressure or weight stacks. Pump gel sweep 20 bbls. Circulate bottoms up while working pipe in seal bore assembly from 9,057' to 9,075'. Shut down pump. Rig down pump line from 2-7/8" tubing. Trip OOH with 14 stands to clear 5" liner top. Pressure test casing from top of packer at 10,169'. PT 1,500 psi for 30 minutes and chart. Good pressure test. Continue to trip OOH. Work string joints partially wet when breaking connections due to stator and rotor on mill. Shut in pipe rams. Secure well. E -line will be out in AM for tubing punch and tubing cut. Continue to trip OOH and BOPE test. 05/31/2019 - Friday PJSM. Verify zero psi. Open pipe rams. RU AK E -line into 2-7/8" PH -6 work string. Top of milling BHA parked at 7,549.61'. Trip in hole with tubing punches. Tag top of BHA at 7,554' E -line depth. PU and log strip. Shoot 4 shots in middle of joint from 7,540'-7,546'. POOH with E -line. Break out head pin. Rig up elevators. Trip OOH with 2-7/8" work string. Lay down BHA. Mill was chewed up and no carbide tips left indicating we were trying to mill loose chunks of metal. One decent sized metal chunk in boot baskets. RU E -line. Run in hole with CCL centralized. Tagging up again at 9,066' at top of seal bore x 2.375" tubing x over. Attempt to work in hole. E -line stuck in x over. Work for an hour. E -line free. POOH to surface and rig down E -line. Total safety on location testing and calibrating 1-12S and LEL monitors. Close blind rams. Open pipe rams and remove solid body rams for 2-7/8" tubing. Replace with VBR rams for 2-3/8" - 3-1/2" pipe rams. Make up blanking test sub and test joint. Stab IBOP. Fluid pack BOPE. Grease all valves. Shell test BOPE stack 250/3,000 psi. SDFN. Will continue to test in AM. 24 hr BOPE test witness notification sent 5/30/19 @ 14:07. Witness waived by Jim Regg 5/31/19 @ 17:38 hrs. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 1 190-059 3/28/19 6/10/19 Daily Operations: 06/01/2019 -Saturday PJSM. Location walk around complete. Check zero psi. Fire equipment. Generator coolant temperature pegged out at 220°F. Shut down genset. Ru production Natural Gas genset. Wire in load bank. Continue to Test BOPE. Test all rams and valves 250/3,000 psi. No failures to report. Wait on slick line. Prep rig floor. RU pollard slick line. RIH w/ 7" collapsible bow spring centralizer (will fit in 2-3/8") w/ 2.1 fluted cent w/ 2.25" rare earth magnet to 9,056' KB, POOH slowly. OOH w/ 3 bits of metal, 1 piece of flat and long. RIH w/ same to 9,066' KB, POOH slowly. OOH w/ 2 small pieces of metal. Covered in metal shavings. RIH w/ same to 9,066' KB, POOH slowly. OOH 3 chunks of metal. One piece is aprox. 2" long and 1/2" wide. RIH w/ same to 9,067' KB, POOH slowly. OOH covered in metal shavings. No metal chunks. RIH w/ 1.75" Magnet w/ retractable bow -spring centralizer on top to 9,073' KB. Tap down lightly to 9,074' KB. Have to spang up. RIH w/ bow springs cent. w/ 1.75" DD Bailer w/ mule shoe flapper on bottom to 9,065' KB, w/t fall to 9,088' KB w/t 9,099' KB. Lose spangs, POOH. OOH w/ marks on bottom of bailer. Empty. RIH w/ 1.75" LIB w/ Bow spring. Cent On top to 9,100' KB w/t 9,103' KB, POOH. OOH w/ impression of several metal marks. Lay down slick line unit. Shut blind rams. Location secure.SDFN. 06/02/2019 -Sunday PJSM. Location walk around complete. Assist electricians. Rig up new rental generator from Magtech. Slick line on location. Spot up /rig up. RIH w/ 1.75" Magnet w/ 5" retractable bow spring cent (will fit in 2-3/8" tubing). Set down @ 9,066' KB. Tap down lightly. Fall to 9,107' KB, POOH slowly. OOH w/ 3 small chunks of metal. RIH w/ same to 9,107' KB, POOH slowly. OOH w/ shavings, no metal chunks. RIH w/ 1.75" Hyrdo- Bailer w/ mule shoe flapper bottom to 9,108' KB, w/t 9,109' KB, POOH. OOH w/ 2 very small pieces of metal. Sludge. RIH w/ 1.73" LIB w/ Cent on top to 9,107, w/t POOH. OOH w/ several impressions of metal. Large chunk taken out of side. RIH w/ 1.55" Magnet on Cent to 9,107' KB, POOH slowly. OOH w/ small chunk of stainless metal and brass. RIH w/ same to 9,107' KB, POOH slowly. OOH w/ shavings. No metal chunks. RIH w/ 2-3/8" GR to 9,109' KB, w/t for 10 min, pull up too 500 lbs over pick up weight. Slip out, w/t again cannot get another friction bite. POOH. OOH tools not sheared. RIH w/ 1.75" Hydro bailer w/ cent on top to 9,109' KB w/t, have to spang out after working down. POOH, OOH w/ very small amount of metal. RIH / 1.55" Magnet w/ cent on top to 9,108' KB, POOH slowly. OOH w/ 1/2 " piece of stainless band, covered in same metallic goop. RIH w/ same to 9,105' KB, POOH slowly, OOH w/ goop/ metal shavings. AK E -line on location. Spot up and make up BHA. RIH w/ GR under bowspring cent. To 9,107' KB w/t, get friction bites, beat down, fall to 9,137' KB, w/t fall to 9,200' KB, w/t 9,291'KB cant tell if we have plug or not, still making hole, decide to POOH and check tool. Add 5' of stem, RIH w/ 2-3/8" Serrated edge PR -GS to 9,296' KB, w/t 9,856' KB, fall to 10,017' KB, w/t 10,184' KB have to jar free, POOH. Well has not gone on vacuum. OOH sheared. RIH w/ PR -GS w/ serrated dogs w/ Bow spring Cent. On top. RIH to 10,181' KB. w/t 10,183' KB, POOH. OOH no plug, not sheared. Secure slick line. Close Blind rams and lock in Accumulator. Choke and kill lines valves confirmed closed. Well is secure. Location walk around complete. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 1 50-133-10171-00 1 190-059 3/28/19 1 6/10/19 Daily Operations: 06/03/2019 - Monday Pollard Slick line on location. PJSM. RU SL unit. RIH W/ 1.75" MAGNET TO 9,069'KB W/ TOOL WOULD NOT FALL POOH W/ 1 PIECE OF METAL 1" X 1/2". RIH W/ SAME ADD BOW SPRING CENT TO 10,188'KB W/ TOOL POOH W/ METAL SHAVINGS ONLY. RIH W/ 2-3/8" GR TO 10,186'KB W/ TOOL PULL UP 200# OVER PULL SLIPS OFF - BEAT DOWN ONE TIME PULL UP SEE SPANGS @ 10,169'KB, CAN NOT LATCH, POOH, PIN NOT SHEARED - NO COMMUNICATION. RIH W/ SAME TO 10,169'KB W/ TOOL DOWN TO 10,186'KB, CAN NOT LATCH, POOH. RIH W/ 2-3/8" PR W/SLIPS TO 10,186'KB W/ TOOL LATCH PULL UP TO 10,169'KB 200# OVER PULL SLIPS OFF PUSH BACK TO 10,188' W/ TOOL, SAME RESULTS, POOH W/ MARKS ON SLIPS. Rig down pollard Slick line. Move in and rig up Pollard E-line. Make up 1.5" tool string and CCL RIH 10,177'. Log strip. Good picture of Baker DB packer, GLM, and overshot. POOH to surface. Make up 1.713" OD Jet cutter. RIH Set down at 10,173.7' CCL depth. Log strip. CCL to cutter 2.6'. Fire cutter at 10,176.6'. Wellbore went on vac. Could visually see fluid dropping inside BOPE. PU 200. RIH and stack out at 10,176.6'. Tail pipe did not drop. POOH to surface. Line up to pump down well. Online down wellbore, caught fluid at 15 bbls pumped. Pressure increased to 1,500 psi at .87 bbls/min. Drop rate to .75 bbls/min. Injection pressure 1,200-1,300 psi. 1,150 bbls/day. RIH with 1.713" Jet cutter to 10,176.3'. Attempt 2nd cut. PU attempt to RIH. Tagging at tail pipe cut at 10,176.3'. Make 4 runs to knock tail pipe loose. POOH to surface. Make up 1.813" OD jet cutter. Talk with town about making 3rd cut at tail pipe. RIH . Cut tail pipe at 10,176.6'. Attempt to pass cut with E-line. Not able to pass. POOH to surface. Rig back E-line. Close Blind rams and Perform injection test. Pump 25 bbls to catch fluid. Pressure increased to 1,400 psi @ .86 bbls/min. Not much change on injection tests. Shut down pump. Bleed well to 0 psi. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 1 190-059 1 3/28/19 1 6/10/19 Daily Operations: 06/04/2019-Tuesday PJSM with rig crew. Location walk around complete. Fuel equipment. Check oils. Pick up AK-Eline. Make up 1.687" OD x 5' gun. Loaded with 453 Owen charges 6 spf 0 degree phasing. Total of 14 shots with .41" holes. CCL to top shot 6.2'. RIH Log strip and get on depth. Park CCL at 10,166.3'. Shoot tubing punches from 10,172.5'-10,176.2'. Holes made below packer in the mill out extension. POOH to surface. Close Blind rams. Line up down IA with fluid pump. Add two 60 bbl vac truck loads to pits. Online down 7" casing at 3.5 bbls/min. 150 bbls pumped. Never caught fluid level. Shut down pump. Verify zero psi. Open blind rams. RIH with E-line jet cutter. 1.718" OD cutter. Log strip and correlate depth. 4.8' from CCL to jet charge. Park CCL at 10,160.2'. Perform jet cut at 10,165' in the 2.375" EUE pup joint between seat nipple and GLM. Leaving a 4' stub of 2.375" EUE sticking up from Baker DB packer. Log OOH . Collars are showing 4' higher after cut. Previous fishing attempts we overpulled and jared tubing at 120k. RIH to check for tail pipe. Tail pipe cut was at 10,176.6'. Made it past tail pipe cut and tagged top of tail pipe at 10,226.8'top of fish. Bottom of fish sitting at 10,272.68'. Fish is sitting on top of 2.875" liner top 10,276'KB. POOH with E-line. Rig down E-line. Make up Weatherford fishing BHA. ITCO Spear. 3 crossovers, Drain sub, Bowen Bumper Sub, Bowen oil jars, 4 spiral drill collars, Bowen intensifier. 156.09' BHA length. Run in hole from Derrek with stands of 2.875" PH-6. Ran 147 stands to 9,060'. Stab spear into seal bore assembly. Get weight parameters prior to latching into seal bore assembly. Clean pick up weight 64-65K. Slack off weight 48-51K. RIH latch up spear to seal bore assembly. 2' in on stand 147. PU 80K Fire jars. Pipe and fish traveling 15'. Continue to work up and down while jarring. PU 100k and jar. Co Rep and crew change. Safety meeting with night crew. Continue jarring at 100k. Attempt to free fish, jarring at 100k. Adjust rig brake linkage. Attempting to free fish, jarring at 100k, slack off weight 48k-51k to 9,060' setting down with additional 3-6k in attempt to free fish. Working pipe as per Weatherford fishing hand, possibly gaining 4-8" of pipe movement. Attempt to shear off fish with 12 turns to the right holding 75k so the spear wouldn't release. Tried again with 10 turns to the right & 75k. Attempt to work fish free. Set down with spear on top of fish at 35k in attempt to isolate seal bore so all fluid would pass by fish. Pumped 10BBL, the well went on a vacuum indicating fluid was passing by the fish. Continue jarring at 100k. Contacted wireline to make additional cut at 7AM. Release ITCO spear, it took several attempts to release spear. Swap out tong dies. Trip out of hole with work string to 3,176' in hole. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 190-059 3/28/19 1 6/10/19 Daily Operations: 06/05/2019- Wednesday PJSM. Fire rig. Location walk around complete. Continue to Trip OOH with BHA and PH-6 2-7/8" from stand 114 or 2,163'. Lay down Weatherford BHA. Slip and Cut 100' of drill line. RU Pollard E-line. Make up 1.68" OD jet cutter. Owen Titan Spectra II. RIH. Log strip. 2.8' from CCL to cut charge. Park CCL at 9,077.2'. Perform cut at 9,080'. Log up through seal bore no change in depth. Log down and pass tubing cut by 3'. 2.375" tubing from 9,080' to 10,176' traveled down 3'. Fish is free. Seal bore assembly stuck. Rig down E-line. Close blind rams. Online down 7" casing at 4.5 bbls/min 165 psi. Pumped 260 bbls. Did not catch fluid level. Well is on a vac. Break and lay out drill collars. PU and RIH from Derrek with 2 7/8" PH-6 in order to lay out sideways. x over and mule shoe on bottom of work string to protect threads. 7,142' of PH-6 in well 1,842' left to run in hole. Co Rep and Crew change out. PJSM with night crew, trip in hole with 2.875" PH-6 from 7,142' to 8,970'. Trip out of hole from 8,970' laying down 2.875" PH-6 singles, repair airline on tongs. Test BOPE's 250psi low, 2,500psi high per sundry. 06/06/2019 - Thursday Tested BOPE per AOGCC regs as follows. Gas Detection, Pressure Tested Annular 250-2,500psi, Rams 250-2,500psi, Valves 250-2,500psi. Used 3-1/2" test Jt. Performed Koomey Drawdown Test. No failures recorded. Test waived by Jim Regg on 6-6-2019 at 9:23AM. PREPARE RIG TO RIH WITH 3-1/2' TC-11 PRODUCTION TBG. 3-1/2" BACKUP DIE KIT WOULD NOT FIT THE OPEN FACE MCCOY 85 TONGS. WAITED ON DIES FROM THE RIG YARD TO ARRIVE. RACKED AND TALLY PIPE WILL WAITING. RIH w/30 jts of 3-1/2' L-80 9.2# TC-II tgb. SD ops due to the 6' bales sliding against the ear latches on the elevators when RIH with pipe. Contacted Weatherford waiting on 11' bails to arrive. Changed out dies in back-up TY elevators to 3.5", rigged up back-up elevators and they don't rub the bails. Continue to RIH picking up 3-1/2' L-80 9.2# TC-II singles to 4,746'. Tallying and rabbiting pipe with 2.35" OD rabbit. Adjust brake band on McCoy tongs. 06/07/2019 - Friday Held PJSM and discussed daily activities to be preformed. Continued SIH w/ 3-1/2" L-80 9.2# TC-II production tbg f/ 4,746't/ 7,872'. Total of 246 jts RIH. Prep Rig floor to TOH with production string. TOH w/ 123 stands of 3-1/2" L-80 9.2# TC-II production tbg f/ 7,872' t/surface. R/D beaver slide and catwalk. Prep wellsiteWpick-up Schlumberger ESP completion. Secure well with BOPE, suspend rig operations till 6AM. 06/08/2019-Saturday Held PJSM and discussed daily activities with crews. Staged ESP equipment and handling tools. PU/MU and serviced new ESP assembly, String new cable and dual cap string over sheave. Tie in motor and chemical injection lines. Tested chemical injection to 2,500psi, and cable to 2.5 Gohms, RIH w/ new ESP on 3-1/2" L-80 9.2# TC-II tbg with 4 GLM's as per tally. Testing chemical injection and cable every 1,000'. Clamping cable with cannon clamps. Swap out cable reels, splice cable at 6,077', Test cable after splice. /2J t4 tJ(/;V_ Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 21A-34 401 50-133-10171-00 1 190-059 3/28/19 1 6/10/19 Daily Operations: 06/09/2019 -Sunday Held PJSM and discussed daily ops with crews. Continued TIH w/ESP completion as Following depths: Hanger, 'PUP JT 3- 1/2" IBT, PUP JT 3-1/2" IBT X 3-1/2" TC -11, 101 JTS, #1 GLM @3,290', 46 JTS, #2 GLM @4,750', 46 JTS, #3 GLM @ 6,119', 42 JTS, #4 GLM @ 7,482', 17 JTS, XO 3-1/2' TC -11 X 2-7/8 EUE 8RD, HEAD @8,032', PUMP @8,055', GAS SEPARATOR @ 8,120', INTAKE @ 8,127', TANDEM SEALS @ 8,130', MOTOR @ 8,146', EOT CENTRALIZER/ANODE @8,213'. Cannon Clamps 169: SS 1-1/4". 2. PU landing joint. Installed Hanger and penetrators, Test cable and cap lines. Cut and spliced cable connector and cap strings, installed same. Meg checked connector. PU 84K/SO 74K. Land completion, weight on Hanger 75K, Ran in locked down screws. Installed BPV and LD Test Jt. ESP cable tested good with umbilical after landing hanger. RD Summit and SLB. Cleared Rig Floor and RD Handrails and Stairs. ND BOP and NU Production Tree. Tested same 250-3,000psi-good test. RD 401 and associated equipment, prep and load trailers for rig move. Suspend rig operations to back on daylight only operations. 06/10/2019 - Monday Held PJSM and discussed daily activities to be performed. RD 401 and associated equipment. Hileore Alaska, LLC RKB: 161' / GL 134' AMSL RT -THF: 26.86' K8 22"� ;. 3a' DV Collar } @ 1,496' 11-314" 2 X3,030' 3 4 DV Collar @7,087' Milled out of T' at 8,676'-0,636' (6/14/90) 10 2x16" pup 9 M top cheMeal W910,163' S B 9 Perfed 8 squeezed rsment fmn 8 55D6D 8 a 60515' 16/11190) I ;.i 11 -� 12 ' 13 :ye N 14 �, Perforation Data Top of Possible liner Wt/ Grade Top Btm 24/0'Ikler lap leak 22" Structural 10,934' 010,778' (10/1Y90) , 10,934' Cemented 11-3/4" Surface 6" @ 10,635' Surface 1,496' 1,498' 1,496' 1,498' 3,030' H-0 Est 600sxs 116# (stage 1), 1250sxs 116# (stage 2) 2' H-2 2.7W@11,169 4• TD=11,160' PBTD=11,050' SCHEMATIC Swanson River Unit Well: SRU 21A-34 Completion Ran: 10/19/13 PTD: 190-059 API: 50-133-10171-01 Casing and Tubing Detail Perforation Data Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22" Structural 10,934' Surface 33' 10,934' Cemented 11-3/4" Surface 47#, J-55 DV Collar 47#, J-55 Surface 1,496' 1,498' 1,496' 1,498' 3,030' 8R / 11.000" 600sxs 116# (stage 1), 1250sxs 116# (stage 2) 7" Surface 29#,N-80 Surface 87' BT/6.184" 700sxs 116# (stage 1), 1150sxs 116# (stage 2) 23#, N-80 87' 4,794' BT / 6.366" 26#, N-80 4,794' 6,701' L8R / 6.276" 29#, N-80 6,701' 7,087' L8R / 6.184" DV Collar 7,087' 7,089' 1-813 / 6.184" 29#, N-80 1 7,089' 8,514' L8R/6.184" 29#, P-110 1 8,514' 8,575' L8R / 6.184" 5" Liner 18#, N-80 8,236' 10,835' FL4S / 4.276" 90 bbl 15.8 ppg 2-7/8" Liner 6.5#, N-80 10,276' 11,159' EUE 8rd Mod / 2.441" 10 bbl 15.6 ppg Tubing 3-1/2" Prod 1 9.2#, L-80 Surface 8,049' TC -ll / 2.992" Cplg OD = 3.887" Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 25.85' 0.6' 2.992" 4.250" Tubing Hanger, 3-1/2" IBT Lift Threads 2 3,323' 6.33' 2.992" 5.140" GLM, GLMAX-1.ORSL(Drift =2.867" 3 4,825' 6.33' 2.992" 5.140" GLM, GLMAX-1.ORSL (Drift = 2.867") 4 6,203' 6.33' 2.992" 5.140" GLM, GLMAX-1.ORSL(Drift =2.867") 5 7,525' 6.33' 2.992" 5.140" GLM, GLMAX-1.ORSL (Drift = 2.867") 6 8,049' - - 4.000" Top of ESP, Discharge Head 7 8,145' 4.000" ESP Intake 8 8,231' 4.560" Stm of ESP, 456 Motors / 400 Pumps Liner top packer 10 19,057' 9.36' 2.555" 3.96" Seal Bore Extension 11 9,100' 1.27' 1.875" 2-3/8" Halliburton X Nipple 12 10,750' 5.86' 1.99" 3-15/16" Tristate Overshot 13 10,157' 6.27' 1.99" 2-3/8" GLM 14 10,169' 3.07' - Baker DB Packer w/ R Guide & millout extension Directional Data: max hole angle = 36.5' at IQ,700' MD Downhole Revised: 10/19/13 Updated by DMA 06-21-19 Perforation Data ZONE TOP BTM Shot Condition H-1 10,918' 10,920' 4js f 1-11/16" jumbo jet III (9/10/90 10,920' 10,934' 4jspf 1-11/16" jumbo jet III (9/10/90) 10,934' 10,948' 4's f 1-11/16" jumbo jet III 9/10/90 10,948' 10,960' 4's f 1-11/16" jumbo jet III 9/10/90 H-2 10,966' 10,980' 4's f 1-11/16" HC 2/26/91 10,980' 10,994' 4's f 1-11/16" HC 2/26/91 Downhole Revised: 10/19/13 Updated by DMA 06-21-19 SP -o ZI A--34 P -1-b 1900; to Regg, James B (CED) From: Regg, James B (CED) Sent: Monday, June 10, 2019 2:00 PM To: Karson Kozub - (C) Cc: cbartlweski@hilcorp.com; ahudgens@hilcorp.com Subject: RE: [EXTERNAL] AOGCC Inspection Form Confirmation Email 9hr test and no failures? I don't see too many of those. It is hard to read the test charts and the line is very faint, but it does look like there were several attempts before obtaining passing low pressure tests. I also want you to be aware that it was not clear to me that you had started the BOPE test at tam on 6/6 —the email sent at 539pm (6/5/19) made no mention of a revised start time. Since the previous test was performed on 6/1/19, 1 understood you to be clarifying why the test was scheduled to start at Spm on 6/6 as indicated in the formal test notice (sent at Spm on 6/5/2019). That is why I waited until the morning of 6/6 to respond. Let's try to be more clear in the future with the communications, and if you have not received feedback from an email pick up the phone and call me at 793-1236. R304,t. Jim Regg "CGdee,� Yo.,, -k4lr>p. Supervisor, Inspections Aoccc a�vt Cf-O�i.(�vufier � 3�- wLSkeP of rela�+t,. 333 W.7th Ave, Suite 100 d 0 Anchorage, AK 99501 �n5zt1-ts . 907-793-1236 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 forth e 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 a -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 Jim Regg at 907- 793-1236 or iim reee@alaska.aov. From: Karson Kozub - (C) <kkozub@hilcorp.com> Sent: Thursday, June 6, 2019 11:03 PM To: Regg, James B (CED) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov> Cc: Cole Bartlewski - (C) <cbartlewski@hilcorp.com>; Anthony Hudgens - (C) <ahudgens@hilcorp.com> Subject: RE: [EXTERNAL] AOGCC Inspection Form Confirmation Email Jim, Thank you for the quick response. We tested BOPE's this morning per AOGCC regulations. The test was complete at 11:00AM. Attached is the BOPE test report, test charts, and the gas detection system test. Please let me know if you have any questions. Regards, Karson Kozub Hilcorp Alaska LLC (907) 570-1801 Mobile (907) 283-2505 Rig phone From: Regg, James B (CED) [mailtojim.reeg@alaska.eov] Sent: Thursday, June 6, 2019 9:14 AM To: Karson Kozub - (C) <kkozub@hilcorp.com> Cc: Cole Bartlewski - (C) <cbartlewski@hilcorp.com> Subject: RE: [EXTERNAL] AOGCC Inspection Form Confirmation Email Thank you for the call this morning — AOGCC witness is waived. As discussed please send test charts with the BOPE test report when finished. Jim Regg Supervisor, Inspections AOGCC 333 W.71h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Karson Kozub - (C) <kkozub@hilcorg.com> Sent: Wednesday, June 5, 2019 5:39 PM To: Regg, James B (CED) <iim.reea alaska.eov> Cc: Cole Bartlewski - (C) <cbartlewski@hilcorp.com> Subject: FW: [EXTERNAL] AOGCC Inspection Form Confirmation Email Jim, I wanted to give you a little more information on this BOPE test. We are going to test BOPE's one day early on SRU 21A-34 in preparation to run the ESP completion. The ESP completion will take roughly 36hrs and we didn't want to have the ESP power cable across the BOPE when the test is required. Another reason for the early test is we will be running 3.5" TC -II for completion tubing, the previous BOPE test was only for 2.875" PH -6 work string. Regards, Karson Kozub Hilcorp Alaska LLC (907) 570-1801 Mobile (907) 283-2505 Rig phone From: AOGCC Inspections [mailto:noreply@iotform.com] Sent: Wednesday, lune 5, 2019 5:00 PM To: Karson Kozub - (C) <kkozub hilcorp.com> Subject: [EXTERNAL] AOGCC Inspection Form Confirmation Email This email confirms your request for an inspection with the following information: Type of Test Requested: BOPE Requested Time for Inspection: 06-06-2019 5:00 PM Location: HAK 401, SRU 21A-34, Swanson River Name: Karson Kozub E-mail: kkozubPhilcorp.com Phone Number: (907) 2832505 Company: Hilcorp Alaska Other Information: Weekly BOPE test If you are not contacted within 12 hours, please notify Jim Regg at 907-793-1236. Thank you! Alaska Oil and Gas Conservation Commission The information contained in this e-mail message is confidential information intended only for the use have ftheecei pie thss named e-mail above. In rror and anion, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, y lease notify the sender immediately by return e-mail and dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, p fY permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report *All BOPE reports are due to the agency within 5 days of testing* Submit to: iim regggalaska oovv AOGCC Inspectors(a)alaska gov phoebe brooksnx.alaska.gov Contractor: Hilcorp - Rig No.: 401 1DATE: Test Result 6/6/19 " 0 Rig Rep.: Rusty Wilson Rig Phone: 907-776-6616 1 - 7 1/16" 5M P " Operator: Hilcorp Alaska Op. Phone: 907-238-2505 - P - #2 Rams I Rep.: Karson Kozub E -Mail kkozub(rDhilcorp.com , 0 Well Name: SRU 21A-34 PTD # 1'QDW/��r��] Sundry # 319-154 NA #5 Rams 0 Ig0091Q NA #6 Rams 0 Operation: Drilling: Workover: X Explor.: 21/16 " P Test: Initial: Weekly: X Bi -Weekly: Kill Line Valves , at Pressure ( si): Rams: 250/2500 - Annular: 250/2500 - Valves: 250/2500 MASP: 0 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: NA Test Result Test Result Quantity Test Result Location Gen. P Well Sign P - Upper Kelly 0 NA Housekeeping P Rig P - Lower Kelly 0 - NA PTD On Location P Hazard Sec. P Ball Type 1 - P ling Order Posted P Misc. NA Inside BOP I P FSV Misc 0 NA BOP STACK: Quantity Sizerrype Test Result Stripper 0 Pit Level Indicators NA Annular Preventer 1 - 7 1/16" 5M P " #1 Rams I - 2 3/8"x 3.5" VBR - P - #2 Rams I Blind P " #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 21/16 " P HCR Valves 1 21/16 - P Kill Line Valves 3 21/16 P - Check Valve 0 NA BOP Misc 0 NA CHOKE MANIFOLD Quantity Test Result No. Valves 8 - P ' Manual Chokes 2 P - Hydraulic Chokes 0 NA CH Misc 0 NA MUD SYSTEM: Visual Alarm Trip Tank NA - NA Pit Level Indicators P P ' Flow Indicator NA NA Meth Gas Detector P - P - H2S Gas Detector P - P - MS Misc 0 NA Quantity Test Result Inside Reel valves 0 NA ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure (psi) 3000 P - Pressure After Closure (psi) 2400 - P - 200 psi Attained (sec) 38 P - Full Pressure Attained (sec) 94 P Blind Switch Covers: All stations Yes Nitgn. Bottles # & psi (Avg.): 6(x)1500 - P " ACC Misc 0 NA Test Results Number of Failures: 0 ' Test Time: 9_0 ' Hours Repair or replacement of equipment will be made within_ N/A Remarks: Tested BOPS per AOGCC regs as follows: pressure tested annular 250-2,500psi,rams 250-2,500psi, valves 250- 2,500psi. Used 3-1/2" test Jt. Preformed Koomey drawdown lest. No failures recorded. Tested PVT. All gas alarms tested with Total Safety Rep. Tested on 6/6/19 from 0200-1100. Witness waived by Jim Regg on 6/6/2019 at 9:36AM 24 hr Notice Yes Date/Time 615119017.00 Waived By Start Date/Time: 6/6/2019 2:uu:uu AM (date) (time) Witness Finish Daterrime: 6/6/2019 11:00:00 AM Form 10-424 (Revised 04/2018) Hilcorp 401 06-06-19 BOPE Test 60 0 Anoo 35oo h Q o ; CotKn HAK 401 �XCHART N0. MC MP -5000 -IHR II I + NETER 3UI�2. i t. pNART PUT ON TAKEN OFF -- . IDCATiON 5�zy 3�— r: \ lo } r, _ �US- 'otai Safety U -S., Inc. '09 E. 51st Avenue --3. anchorage, AK 99503 TOTAL SAFETY ��. 'hone: j907)743-9871 ax; (907) 743-9872 GAS DETECTION SYSTEM TEST SHEET rt Date: [ Time: Z . W AFE/Job#: --f-15 j 9f y ocation: / (,( (� _ 7I/ Drilling Company: Zany Representitive: J J,;; Telephone Number: Safety Technician: Current fi .f - Current Site Activity:;` of System: �tti/ , , Type of Test: Calibration 6 Bump Test Sensor # 1 Sensor # 2 Sensor # 3 Type of Sensor: Type of Sensor; Type of Sensor: s_: -- Location: Location: j d Location, i •- " Calibrated from: Calibrated from: Calibrated from: Bumped at: Bumped at: Bumped at: ' Low alarm < 30 seconds: Low alarm < 30 seconds: ti-' r Low alarm < 30 seconds:= = Battery Voltage: Battery Voltage: y Battery Voltage: Comments: Comments: Comments: Sensor # 4 Sensor # 5 Sensor # 6 Type of Sensor: Type of Sensor' Type of Sensor:.. - Location; Location: n. Location: Calibrated from: Calibrated from: Calibrated from: Bumped at: L' Bumped at: -- Bumped at: — — Low alarm < 30 seconds: low alarm < 30 seconds: -` Low alarm < 30 seconds: Battery Voltage: Battery Voltage: - Battery Voltage: Comments: Comments: Comments: Sensor # 7 Sensor # $ Sensor # 9 Type of Sensor: Type of Sensor: Type of Sensor: Location: Location: Calibrated from: Location: Calibrated from: Calibrated from: Bumped at: Bumped at: Bumped at: Low alarm < 30 seconds: Low alarm < 30 seconds: Low alarm < 30 seconds: Battery Voltage: Battery Voltage: Battery Voltage: Comments: Comments: Comments: Sensor # 11 Sensor # 12 Sensor # 10 Type of Sensor: Type of Sensor: yp Type of Sensor: Location: Location: Location: Calibrated from: Calibrated from: Calibrated from: Bumped at: Bumped at: Bumped at: Low alarm < 30 seconds: Low alarm < 30 seconds: Low alarm < 30 seconds: Battery Voltage: Battery Voltage: Battery Voltage: Comments: Comments: Comments: Compa"RepreseniNve rf Total Safety Technician Date: White - Office Canary -Customer Dlnk - File Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Tuesday, May 7, 2019 10:20 AM To: Schwartz, Guy L (DOA) Cc: Donna Ambruz ' Subject: SRU 21A-34 WO - PTD'8, Sundry # 319-154 - Revised Proced 5-7-2019 Attachments: SRU 21A-34 WO Reg Revised Proced 5-7-2019.docx Follow Up Flag: Follow up Flag Status: Flagged tl Guy, ��> Pr ti'c'„�/ ,�� We have run into a problem with the work over on the above well. We did manage to get the casing pressure tested on this well by setting a plug in the X nipple @ 9,100'. Unfortunately, we have not been able to recover the plug from the well. The plan forward is that we wish to burn over the packer at 9,057' and pull the packer down to and including the overshot at 10,150'. We will then run a new overshot and packer in its place. Attached is the revised procedure for performing this work. The changes are in red, what was in the or9oiginal procedure is in black. Hilcorp is asking for AOGCC approval to make this change and continue with well work operations on this well. The rig is on the well. We have shut down today in order to obtain approval from AOGCC and to collect necessary tools and equipment. Please let me know if AOGCC approves of this change so we can continue this operation. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp-Alaska LLC Office — 907-777-8420 Cell — 985-867-0665 The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable rare 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. U Well Prognosis - Revised Well: SRU 21A-34 Date: 5/7/2019 5. Back out tbg hanger hold down pins and pickup on hanger. 6. RU to pull tubing hanger and unseat ESP. POOH with 3-1/2" TC -II production tubing from 8,049'. Jar tubing hanger and ESP loose if necessary. a. If unable to unseat ESP (due to tight clearance), RIH with E -line and use radial cutting torch (RCT) to cut 3-1/2" tubing at +/- 8,035' (first full joint above ESP). PU 4' and fire a second RCT in the same location to cut the ESP cable. b. POOH and stand back tubing and reeling up cable. PU, RIH with overshot and jars and pull ESP. k 7. POOH w/ all tubing standing back same. a. Keep 4 GLM to re -run with ESP completion. 8. PU Burn ovewr shoe and mud motor on 2-7/8" work string. 9. RIH W/ same to top of packer at 9,057'. Burn over top straddle packer, circ. Clean, POOH. 10. PU, RIH W/spear. Spear packer and POOH W/pkr, tail pipe and overshot. 11. PU RIH W/ new overshot, tail pipe, and top straddle packer to depth. 12. Stab overshot over 2-3/8" stub looking up. Space out same and set Packer according to manufactures setting procedure. POOH laying down 2-7/8" work string. 13. RU ESP running equipment. 14. Pick up ESP equipment, building same in well. 15. RIH with replacement ESP with existing 3-1/2" TC -II L-80 tubing. a. Test control lines to 2,500 psi. b. RU Pollard to use bands or clamps on tubing (ensure adequate banding material). c. Set 4 re -run GLMs at +/- 7,500', +/- 6,200', +/-4,800' and +/- 3,300'. d. Run ESP cable around Minor OD of the GLMs (will not fit across Major OD). e. Test ESP cable every 1,000' going in hole to confirm electrical integrity of the electrical system. f. Have 3-6 joints of 3-1/2" TC -II to reach a planned ESP set depth of +/- 8,220'. 16. Set base of ESP at +/-8,220' (Pump intake around +/- 8,130'). Land tubing hanger. 17. Set BPV, ND BOPS, NU Tree, test tree to 3,000 psi. a. Note: Do not exceed the pressure rating of the wellhead penetrator. 18. RDMO workover rig and equipment. 19. Turn well over to production. Attachments: 1. As -built Schematic (proposed Schematic is the same) 2. BOP Schematic 3. Forward Fluid Flow 4. Wellhead Diagram S. Procedure Change Form THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SRU 21A-34 Permit to Drill Number: 190-059 Sundry Number: 319-154 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner rd DATED this 3 day of April, 2019. S13DMSLf"j APR o 4 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED MAR 2 7 2019 AOGCC 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: Replace ESP ❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ • Stratigraphic ❑ Service ❑ 190-059 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-10171-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Swanson River Unit (SRU) 21A-34 ' No Will planned perforations require a spacing exception? Yes El No 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028406 Swanson River/ Hemlock Oil " it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,160' 10,859' 11,050' 10,764' 0psi 10,191 (PX Plug) 10, 191 (PX Plug) Casing Length Size MD TVD Burst Collapse Structural Conductor 33' 22" 33' 33' Surface 3,030' 11-3/4" 3,030' 3,029' 3,070 psi 1,510 psi Intermediate Production 8,575' 7" 8,575' 8,571' 6,340 psi 3,830 psi Liner 2,599' S" 10,835' 10,578' 1 10,140 psi 10,490 psi Liner 883' 2-7/8" 11,159' 10,858' 1 10,570 psi 11,160 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2# / L-80 8,049' Packers and SSSV Type: Hes BWD; Packers and SSSV MD (ft) and TVD (ft): 9,057' MD - 9,049' TVD Baker DB; N/A 10,169' MD - 10,034' TVD; NA - 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: April 9, 2019 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: So York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkMM9[@hilc02.com Phone: 777-8420 �-1Contact Authorized Signature: Date: �� ) r A,16- 14 t COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: L -I / Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: i �SDD 7Q5. SOP �� r r -7�t .� , SvD P Post Initial Injection MIT Req'd? Yes ❑ No ❑ trL+ APR 0 4 2019 ^ O Spacing Exception Required? Yes [:]No ,� Subsequent Form Required: 10 l ggpMS APPROVED BYzz-/�/� p Approved by: COMMISSIONER THE COMMISSION Date: / Forrn 10 sk�6�� A oved A IicaQ i1 `al� V IItfJre�n tthe date of a Submit Form and pp pp V �.V/ 1 /� pproval.�/��chments in uplicate 2'6/Q U Hilco p Alaska. M Well Prognosis Well: SRU 21A-34 Date:3/25/2019 Well Name: SRU 21A-34 API Number: 50-133-10171-01 Current Status: ESP Oil Well Leg: N/A Estimated Start Date: April 9`h, 2019 Rig: Rig 401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: '^.�48 j 9 o—USg First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (C) AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP: Max. Allowable Surface Pressure: Brief Well Summary — 1,085 psi @ 8,287' TVD -- 1,085 psi @ 8,287' TVD — 0 psi (Flowing survey Oct 2009 mid perf of 10,956' MD) (Flowing survey Oct 2009 mid perf of 10,956' MD) (Based on actual reservoir conditions and min water cut of 90% (0.429psi/ft) will balance reservoir pressure at 4,855 ft. TVD. This well was drilled and completed as an oil well in Hemlock in 1963 as SRU 21-34. This well was sidetracked in 1990 and perforated in the H-1 zone. The well was cleaned out with coil tubing in October 1990. The Hemlock H-2 was added in February 1991. A workover performed in 1994 to isolate damaged casing. A workover performed in 2009 was done to install a new gaslift string. A workover performed in 2010 was performed to pull the gaslift completion and convert to ESP completion. Two ESP's have been ran since the well was converted to this form of artificial lift. The first pump ran for 3 years before having a down hole failure, the second system (Current) ran forjust short of 5 years. The work plan is to pull the failed ESP and run a new one. Notes Regarding Wellbore Condition M j �/ • Well currently on gaslift. Surface facilities installed for ESP back in 2010. Work -Over Rig Procedure 1. MIRU Rig 401 pulling unit. 2. RU and pump +/- 50 bbl Produced Water down tubing to clean pipe. Bleed casing pressure. 3. Set TWC in tubing han er, ND tree, NU 7-1/16" BOPE and test to 250psi low/iii high, annular to 250psi low/1,55011psi high (hold each valve and test for 5 -min). Record accum? for pre -charge pressures. XM a. Notify AOGCC 24hrs in advance to witness test. b. Crew will be working 12hr shifts and well will be secured nightly with TIW valves and BOPE. c. Test VBR rams on 3-1/2" test joint. d. Email completed 10-424 form to all AOGCC addresses listed on the form within 5 days of BOPE test. 4. Release test pressure, pull TWC and install handling sub in hanger. U 11fl.y M.A.. LG Well Prognosis Well: SRU 21A-34 Date: 3/25/2019 5. Back out tbg hanger hold down pins and pick up on hanger. 6. RU to pull tubing hanger and unseat ESP. POOH with 3-1/2" TC -II production tubing from 8,049'. Jar tubing hanger and ESP loose if necessary. a. If unable to unseat ESP (due to tight clearance), RIH with E -line and use radial cutting torch (RCT) to cut 3-1/2" tubing at +/- 8,035' (first full joint above ESP). PU 4' and fire a second RCT in the same location to cut the ESP cable. w' -*V b. POOH and stand back tubing and reeling up cable. PU, RIH with overshot and jars and pull ESP. 7. POOH w/ all tubing standing back same. a. Keep 4 GLM to re -run with ESP completion. . RIH with replacement ESP with existing 3-1/2" TC -II L-80 tubing. a. Test control lines to 2,500 psi. b. RU Pollard to use bands or clamps on tubing (ensure adequate banding material). c. Set 4 re -run GLMs at +/- 7,500', +/- 6,200', +/- 4,800' and +/- 3,300'. d. Run ESP cable around Minor OD of the GLMs (will not fit across Major OD). e. Test ESP cable every 1,000' going in hole to confirm electrical integrity of the electrical system. f. Have 3-6 joints of 3-1/2" TC -II to reach a planned ESP set depth of+/- 8,220'. 9. Set base of ESP at +/-8,220' (Pump intake around +/- 8,130'). Land tubing hanger. 10. Set BPV, ND BOPS, NU Tree, test tree to 3,000 psi. a. Note: Do not exceed the pressure rating of the wellhead penetrator. 11. RDMO workover rig and equipment. 12. Turn well over to production. Attachments: 1. As -built Schematic (proposed Schematic is the same) 2. BOP Schematic 3. Forward Fluid Flow 4. Wellhead Diagram 5. Procedure Change Form Hilcoru Alaska, LLC RKB: 154' 1 GL 134' AMSL RT -THF: 25.8V KB 2r'@ ;t 1s 33' Size Type )V collar I'. 18 Btm CONN / ID Cement / Other 22" Structural 10,934' 11314" �' �� 2 @3,038' Cemented 11-3/4" 3 r Surface 1,496' 1,498' 1,496' 1,498' 3,030' 4 D1/ Collar 7" _ @7,WT 29#, N-80 Surface 5 Perfed 8 squeezed cement from 8,55068' 8 8,60515' (6/11190) ^ 11 Possible Casing Failure @-9,112'. 1z 2318" pup It wl 13 top chemical cut at 10,153' j 14 ACTUAL SCHEMATIC Swanson River Unit Well: SRU 21A-34 Completion Ran: 10/19/13 PTD: 190-059 API: 50-133-10171-01 Casing and Tubing Detail 1s n Size Type WillGradeTop 18 Btm CONN / ID Cement / Other 22" Structural 10,934' Surface 33' 10,934' Cemented 11-3/4" Surface 47#, J-55 DV Collar 47#, J-55 Surface 1,496' 1,498' 1,496' 1,498' 3,030' 8R / 11.000" 600sxs 116# (stage 1), 1250sxs 116# (stage 2) 7" Surface 29#, N-80 Surface 87' BT 6.184" 700sxs 116# (stage 1), 1150sxs 116# (stage 2) 23#, N-80 87' 4,794' BT / 6.366" 26#, N-80 4,794' 6,701' L8R / 6.276" 29#, N-80 6,701' 7,087' L8R / 6.184" DV Collar 7,087' 7,089' L8R / 6.184" 29#, N-80 7,089' 8,514' L8R / 6.184" 29#, P-110 8,514' 8,575' L8R/6.184" 5" Liner 18#, N-80 8,236' 10,835' FL4S / 4.276" 90 bbl 15.8 ppq 2-7/8" Liner 6.5#, N-80 10,276' 11,159' EUE 8rd Mod / 2.441" 10 bbl 15.6 ppg Tubing max hole angle = 36.50 at 10,700' MD 3-1/2" Prod 9.2#, L-80 Surface 8,049' TC -11 / 2.992" C I OD = 3.887" Production StringJewel Detail # Depth RKB Length ID OD Item 1 25.85' 0.6' 2.992" 4.250" TubingHanger, 3-1/2" IBT Lit Threads 2 3,323' 6.33' 2.992" 5.140" GLM, GLMAX-1.ORSL Drift=2.867" 3 4,825' 6.33' 2.992" 5.140" GLM, GLMAX-1.0RS1- Drift=2.867") 4 6,203' 6.33' 2.992" 5.140" GLM, GLMAX-1.0RSL Drift=2.867" 5 7,525' 6.33' 2.992" 5.140" GLM, GLMAX-1.ORSL Drift=2.867" 6 8,049' 4.000" To of ESP, Discharge Head 7 8,145' - 4.000" ESP Intake 8 8,231' 4.560" Ban of ESP, 456 Motors / 400 Pumps 9 8,236' Liner to packer 10 9,057' 9.36' 2.555" 3.96" HES BWD Permanent Packer w/ seal bore extension 11 9,100' 1.27' 1.875" 2-3/8" Halliburton X Nipple 12 10,150' 5.86' 1.99" 3-15/16" Tristate Overshot 13 10,157' 6.27' 1.99" 2-3/8" GLM 14 10,169' 3.07' Baker DB Packer w/ R Guide & millout extension 15 10,175'-10,187' 12.00' TubingPunch w/ 4 s f 47 holes total 16 10,186'-10,188' 2.00' TubingPunch w/ 4s f guns 8 holes total 17 10,190' FISH: PX plug 18 10,191' 1.20' 1.875" Otis X Nipple 19 10,223' .58' 1 1.99" 1 Wireline Re -Entry Guide Downhole Revised: 10/19/13 Updated by STP 10/26/2013 1s n ZONE TOP BTM X 18 H-1 10,918' 10,920' 4's f 1-11/16" jumbo jet III (9/10/90 10,920' 10,934' 4s f •I rood 10,934' Possible liner 4's f 1-11/16" jumbo let III 9/10/90 '. 2-7/8'Iurer 10,960' lap leak 1-11/16" umbo jet III 9/10/90 H-2 10,966' 10,980' 4"s f 1a1a9o1 10,980' 10,994' 4's f 1-11/16" HC 2/26/91 5" @ 10,835 H-1 I 'i p. D t H2 A' 2-718" @ 11,15Tr- TD=11,160' PBTD=11,050' Directional Data: max hole angle = 36.50 at 10,700' MD Downhole Revised: 10/19/13 Updated by STP 10/26/2013 Perforation Data ZONE TOP BTM Shot Condition H-1 10,918' 10,920' 4's f 1-11/16" jumbo jet III (9/10/90 10,920' 10,934' 4s f 1-11116" jumbo jet III 9/10/90 10,934' 10,948' 4's f 1-11/16" jumbo let III 9/10/90 10,948' 10,960' 4's f 1-11/16" umbo jet III 9/10/90 H-2 10,966' 10,980' 4"s f 1-11/16" HC 2/26/91 10,980' 10,994' 4's f 1-11/16" HC 2/26/91 Downhole Revised: 10/19/13 Updated by STP 10/26/2013 HILCORP ALASKA 7-1/16" 5M BOPE 7-1/16`5M HYDRIL GK ANNULAR 32" TALL, FLANGE TO FLANGE 7-1/16" 5M LWS DBL GATE BOP DRESSED W/VARIABLE RAMS IN TOP DRESSED W/BLIND RAMS IN BOTTOM 26-3/4" TALL, FLANGE TO FLANGE 7-1/16" SM DRILLING SPOOL W/2 -1/16"5M OUTLETS 18" TALL, FLANGE TO FLANGE —77" TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: - 3.30 gallon open chamber volume - 3.86 gallon close chamber volume GATE STYLE BOP SPECS: -1.45 gallons to close per gate -1.18 gallons to open per gate 5.45:1 closing ratio 1.93:1 opening ratio H Itil-rp AI.d.. UJ: Swanson River SRU 21A-34 Current 03/26/2019 Swanson River Tubing hanger, FTC -ESP, SRU 21A-34 7 X 3.725 MCA acme lift x 11314X7X3% 37: IBT susp, w/2 -V4 control line exits, prepped for BIW Kwiklok penetrator, DD material 31/8 SM Tree any Adapter, Vetco ESP, 7 1/18 3M rotating flange X 3 1/8 5M, 2-1/." control line .,.912L exits, Prepped for BIW Kwik 1Lok and VG seal carder Tubing head, Vetco-FT Ground Level 13 5/8 3M: 71/16 SM bottom w/2 -21/165M SSO, BG - STB BTB Casing head, Shaffer KD, 13 5/8 3M X 113/4 SOW, w/ 2- T LPO, 7" KD slips and packoff assy in head H HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SRU 21A-34 (PTD 100-148) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date 10,000,000 1,000,000 t C O CL 100,000 10 1 Jan -1990 HILCORP ALASKA LLC, SWANSON RIV UNIT 21A-34 (190-059) SWANSON RIVER, HEMLOCK OIL Monthly Production Rates Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 e Produced Gas (MCFM) a GOR — Produced Water (BOPM) � Produced Oil (BOPM) 10,000,000 to d 1,000,000 rD O_ O 100,000 0m 0 _ 10,000 O 1 d 1,000 O m 100 fD 3 0 _ 10 s 1 Jan -2020 SPREADSHEET_ Prod -Inject Curves_W ell_V119_1900590_SRU_21A-34_20190328.xlsx 3/28/2019 i ��L•ttlL��fL ( N ��aaaal�aaaal aaa�aaa�aaa�a�% ii Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 e Produced Gas (MCFM) a GOR — Produced Water (BOPM) � Produced Oil (BOPM) 10,000,000 to d 1,000,000 rD O_ O 100,000 0m 0 _ 10,000 O 1 d 1,000 O m 100 fD 3 0 _ 10 s 1 Jan -2020 SPREADSHEET_ Prod -Inject Curves_W ell_V119_1900590_SRU_21A-34_20190328.xlsx 3/28/2019 • STATE OF ALASKA � RECEIVED ALA A OIL AND GAS CONSERVATION COMMISSION OP 28 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 11 Repair Well U Plug Perforations U Perforate U OA. ther IS Re-run ESP 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: Name: Hilcorp Alaska,LLC Development el Exploratory ❑ 190-059 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-10171-01 • 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028406 SRU 21A-34 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Hemlock Oil ' 11.Present Well Condition Summary: Total Depth measured 11,160 feet Plugs measured 10,191 (PX Plug) feet true vertical 10,859 feet Junk measured 10,191 (PX Plug) feet Effective Depth measured 11,050 feet Packer measured 9,057'; 10,169' feet true vertical 10,764 feet true vertical 9,049';10,034' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 33' 22" 33' 33' Surface 3,030' 11-3/4" 3,030' 3,029' 3,070 psi 1,510 psi Intermediate Production 8,575' 7" 8,575' 8,571' 6,340 psi 3,830 psi Liner 2,599' 5" 10,835' 10,578' 10,140 psi 10,490 psi Liner 883' 2-7/8" 11,159' 10,858' 10,570 psi 11,160 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNED Z\i 6 4 j L U l" Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 8,049'MD 8,049'ND . HES BWD; 9,057 MD 9,049'ND Packers and SSSV(type,measured and true vertical depth) Baker DB;N/A 10,169'MD 10,034'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: 32 0 598 934 230 Subsequent to operation: 190 152 2976 305 230 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 Q ' 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: 313-520 V Contact Stan Porhola Email sporholac hilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date 3 Form 10-404 Revised 10/2012 17-162"/S ,1 `1∎lIi NISinTl94$y_ 1 1 . • • Swanson River Unit • Well: SRU 21A-34 ACTUAL SCHEMATIC Completion Ran: 10/19/13 PTD: 190-059 Hilcorp Alaska,LLC API: 50-133-10171-01 RKB:154'/GL 134'AMSL RT-THF:25.85'KB Casing and Tubing Detail i — Size Type Wt/Grade Top Btm CONN/ID Cement/Other 22"@ 33' 22" Structural Surface 33' Cemented 47#,J-55 Surface 1,496' 600sxs 116#(stage 1), )V Collar 11-3/4" Surface DV Collar 1,496' 1,498' 8R/11.000" 1250sxs 116#(stage 2) a 1,496' L 47#,J-55 1,498' 3,030' 29#, N-80 Surface 87' BT/6.184" 23#, N-80 87' 4,794' BT/6.366" 11 3/a"Q , 26#, N-80 4,794' 6,701' L8R/6.276"I @3,030' 2 7" Surface 29#, N-80 6,701' 7,087' L8R/6.184" 700sxs 116#(stage 1), I '3 , DV Collar 7,087' 7,089' L8R/6.184" 1150sxs 116#(stage 2) 29#, N-80 7,089' 8,514' L8R/6.184" l 4 29#, P-110 8,514' 8,575' L8R/6.184" 1 DV Collar [ ] 5" Liner 18#, N-80 8,236' 10,835' FL4S/4.276" 90 bbl 15.8 ppg @ 7087' 1 1 rn5 2-7/8" Liner 6.5#, N-80 10,276' 11,159' EUE 8rd Mod/ 10 bbl 15.6 ppg 2.441" Tubing 6 3-1/2" I Prod I 9.2#, L-80 I Surface I 8,049' I TC-II/2.992" I Cplg OD=3.887" 0.. a Production String Jewelry Detail la 7 # Depth(RKB) Length ID OD Item 8 1 25.85' 0.6' 2.992" 4.250" Tubing Hanger, 3-1/2"IBT Lift Threads 9 2 3,323' 6.33' 2.992" 5.140" GLM,GLMAX-1.ORSL(Drift=2.867") Milled out 3 4,825' 6.33' 2.992" 5.140" GLM,GLMAX-1.ORSL(Drift=2.867") of led ou -= 4 6,203' 6.33' 2.992" 5.140" GLM,GLMAX-1.ORSL(Drift=2.867")at 8,575-8,635' W Perfed& 5 7,525' 6.33' 2.992" 5.140" GLM, GLMAX-1.ORSL(Drift=2.867") (6/14/90) cement from 6 8,049' - - 4.000" Top of ESP, Discharge Head 10 .. 8,550-60'& 7 8,145' - - 4.000" ESP Intake 8,605-15'(6/1 vso) 8 8,231' - 4.560" Btm of ESP,456 Motors/400 Pumps � 9 8,236' - Liner top packer 10 9,057' 9.36' 2.555" 3.96" HES BWD Permanent Packer w/seal bore C extension © 11 11 9,100' 1.27' 1.875" - 2-3/8"Halliburton X Nipple 4 Possible Casing 12 10,150' 5.86' 1.99" 3-15/16" Tristate Overshot =allure @-9,112' 13 10,157' 6.27' 1.99" - 2-3/8"GLM 12 14 10,169' 3.07' - - Baker DB Packer w/R Guide&millout extension 2-3/8"pup jtw/ 15 10,175'-10,187' 12.00' - - Tubing Punch w/4 spf(47 holes total) top chemical �� 13 16 10,186'-10,188' 2.00' - - Tubing Punch w/4spf guns(8 holes total) cut at10,153' '' 14 17 10,190' - - - FISH: PX plug a_.•:_ii 15 z 18 10,191' 1.20' 1.875" - Otis X Nipple 16 I 17 19 10,223' .58' 1.99" - Wireline Re-Entry Guide X 18 19 Top of Perforation Data Possible liner 2-7/8"liner ZONE TOP BTM Shot Condition lap leak @ 10,276 H-1 10,918' 10,920' 4jspf 1-11/16"jumbo jet III(9/10/90) 110/15/90) , 10,920' 10,934' 4jspf 1-11/16"jumbo jet III(9/10/90) 5"@10,835' 10,934' 10,948' 4jspf 1-11/16"jumbo jet III (9/10/90) 10,948' 10,960' 4jspf 1-11/16"jumbo jet III(9/10/90) H-2 10,966' 10,980' 4jspf 1-11/16"HC(2/26/91) 10,980' 10,994' 4jspf 1-11/16"HC(2/26/91) H-1 I H-2 2-7/8"@ 11,159' I TD=11,160' PBTD=11,050' Directional Data: max hole angle=36.5°at 10,700'MD Downhole Revised: 10/19/13 Updated by STP 10/26/2013 • • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 21A-34 50-133-10171-00 190-059 10/14/13 10/18/13 10/14/2641-1\11,944 MIRU Moncla WOR and associated equipment. Bled well pressure to rig tank. Set BPV and ND PT/NU BOP stack. Hookup Koomey, kill and choke lines. SDFN. 1Q/15/2°13-Tue y ti' 41„,,, aPlb'P19 Prep to test BOPE and finished RU. Pulled BPV. Pumped 25 bbls down csg and 25 bbls down tbg. Set TWC and Tested BOPE, Values 250psi/3,000psi, Rams 250psi/3,000psi,Annular 250psi/3,000psi. Held test pressures for 5 mins. Tested Koomey and Gas Detection,Test ok. Witness waived by Jim Regg,AOGCC. Pulled TWC. Prep rig to pull completion. M.0 lifting sub and backed out lock down pins. PU to 88k and pipe started moving. L/D tbg hanger and lifting sub. Set slips. MIRU SLB equipment. TOOH w/ESP cable, control line and 60 stands of 3-1/2”tbg. Encountered tight spot at 6,300' (38 stands). Pumped 10 bbls down the csg and worked thru tight spot. TLTR:45bbls. TOOH w/ESP cable, control line and 22 stands of 3- 1/2" tbg. liyi 10/16/id13-wedrieday Continued OOH with ESP equipment. 125 stands and 1 single of 3-1/2"TC-II 9.2#tbg,4 GLV,XA Sliding Sleeve and X-nipple. LD tools and ESP equipment. Waited on new ESP equipment to arrive from SLB yard. PU new ESP equipment, ESP cable and a dual encapsulated control line. TIH w/ESP and 38 stands of 3-1/2"TC-II 9.2#tbg and 4 GLM. Secured ESP cable with 3 bands per joint and the control line 1 band ever other joint. Continued TIH at report time. 10/17/20138,, hurSday $ 'NM F' £ s'rc h 1,1HI1ilh toll;111 t qy Continued RIH with ESP equipment/GL completion. Made the cable slice at 4,900'. Continued RIH with ESP/GL completion. PU tbg hanger and measured cable to make cut. Connect the cable penetrator and control lines into tbg hanger. Landed hanger with 83k. ESP landed at 8,231'. Secure lock down pins. Set BPV and ND BOP's/NU PT. Tested the hanger to 3000psi. Pulled BPV. /2013-Frida y , 'a rc' �- •. i tl i l(,i ilt(y - i RD WOR and equipment,Stand-by for ESP start-up. 000 0 00 10/19/2013 Saturda Hooked up flowline from the tree to sales. 10/20/2013-Sunda,Y �'Ily t t. v �I �, Standby for ESP start up. . • • 001"��I I/7:s THE STATE Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue C4'41,LAS A*s v ' Anchorage, Alaska 99501-3572 A Main: 907.279.1 433 SCANNED NOV a 32013 Fax: 907.276.7542 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 21A-34 Sundry Number: 313-520 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, Cathy P. oerster ,.�� Chair, Commissioner DATED this 7 r d of October, 2013. Encl. III b STATE OF ALASKA 11 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair WOE] Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing El ° Ti,eExtension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing Other. Run ESP 0 • 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to MI Number. Exploratory ❑ Development is . 190-059 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-10171-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 1238 Swanson River Unit(SRU)21A-34 . Will planned perforations require a spacing exception? Yes ❑ No In 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028406 '1 Swanson River/Hemlock Oil . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,160 10,859 • 11,050 10,764 10,191(PXPIug) 10,191(PXPIu9) Casing Length Size I ND D Burst Collapse • Structural l Conductor 33' 22" 33' 33' Surface 3,030' 11-3/4" 3,030' 3,029' 3,070 psi 1,510 psi Intermediate Production 8,575' 7" 8,575' 8,571' 6,340 psi 3,830 psi Liner 2,599' 5" 10,835' 10,578' 10,140 psi 10,490 psi Liner 883' 2-7/8" 11,159' 10,858' 10,570 psi 11,160 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2#/L-80 8,044' Packers and SSSV Type: Hes BIND; Packers and SSSV MD(t)and ND(ft): 9,057'MD-9,049'ND Baker DB;N/A 10,169'MD-10,034'ND;NA-N/A 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program Li BOP Sketch U Exploratory U Stratigraphic Li Development U Service U 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/13/13 Oil EI . Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porttola Phone: 907-777-8412 . Email sporholaahilcorp.com Printed Name tan Porhola Title Operations Engineer z Signature �UZ Phone 907-777-8412 Date 1 e/o 3 ( 7? COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\3 - 520 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: Y`3 00 0 DSc t5 d M ( ,5 RBDt'4S OCT 10 20'h Spacing Exception Required? Yes ❑ No a Subsequent Form Required: / 6--`1'CY"( APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: f '-4- 13 t Submit Form and 0 Form 10-403(Revi d 10/2012) 16- pproved apps a o h from the date of approval. A chments in Duplicate ri„, • • Well Prognosis Well: SRU 21A-34 Hilcorp Alaska,LL Date:10/03/2013 Well Name: SRU 21A-34 API Number: 50-133-10171-01 Current Status: ESP Oil Well Leg: N/A Estimated Start Date: October 13th, 2013 Rig: Moncla#405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 1598- I°lo- 655 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 @ 10,682' TVD (Flowing survey Oct 2009 mid perf of 10,956' MD) Maximum Expected BHP: —2,500 psi @ 10,682' TVD (Flowing survey Oct 2009 mid perf of 10,956' MD) Max.Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 90% (0.429psi/ft) will balance reservoir pressure at 4,855 ft. TVD. Brief Well Summary This well was drilled and completed as an oil well in Hemlock in 1963 as SRU 21-34.This well was sidetracked in 1990 and perforated in the H-1 zone.The well was cleaned out with coil tubing in October 1990.The Hemlock H-2 was added in February 1991.A workover performed in 1994 to isolate damaged casing.A workover performed in 2009 was done to install a new gaslift string.A workover performed in 2010 was performed to pull the gaslift completion and convert to ESP completion.Just recently, a downhole failMre occurred after the ESP had ran for just over 3 years. Plan is to pull the failed ESP and run a new ESP. Notes Regarding Wellbore Condition • Well currently on gaslift.Surface facilities installed for ESP back in 2010. Work-Over Rig Procedure 1. MIRU Moncla#405 pulling unit. (''" 2. RU and pump+/-50 bbl Produced Water down tubing o clean pipe. Bleed casing pressure. (/y_"_',--e/J 3. Set TWC in tubing hanger, ND tree, NU 7-1/16" BOPE and test to 250psi low/3,000psi high, annular to 250psi low/1,500psi high (hold each valve and test for 5-min). Record accumulator pre-charge pressures. a. Notify AOGCC 24hrs in advance to witness test. b. Crew will be working 12hr shifts and well will be secured nightly with TIW valves and BOPE. 4. Release test pressure, pull TWC and install handling sub in hanger. 5. Back out tbg hanger hold down pins and pick up on hanger. 6. RU to pull tubing hanger and unseat ESP at 8,233' and SOOH with 3-1/2"TC-II production tubing from 8,044'.Jar tubing hanger and ESP loose if necessary. a. If unable to unseat ESP(due to tight clearance), RIH with E-line and use radial cutting torch to cut 3-1/2"tubing at+/-8,015' (first full joint above ESP). b. SOOH with tubing and RIH with overshot and jars and pull ESP. 7. SOOH w/all tubing. • • Well o Well:Pr SRU gnosis 21A-34 Hilcorp Alaska,LL Date:10/03/2013 a. Keep 4 GLM to re-run with ESP completion. 8. RIH with replacement ESP with existing 3-1/2"TC-II L-80 tubing. a. Test control lines to 2,500 psi. b. RU Pollard to use bands or clamps on tubing(ensure adequate banding material). c. Set 4 re-run GLMs at+/-7,500',+/-6,200', +/-4,800'and+/-3,300'. d. Run ESP cable around Minor OD of the GLMs(will not fit across Major OD). e. Have 3-6 joints of 3-1/2"TC-II to reach a planned ESP set depth of+/-8,220'. 9. Set base of ESP at+/-8,220' (Pump intake around +/-8,130'). Land tubing hanger. 10. Set BPV, ND BOPs, NU Tree,test tree to 3,000 psi. a. Note: Rated pressure of BIW penetrator(wellhead to cable connection) is 3,000 psi. 11. RDMO workover rig and equipment. 12. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic H, • Swanson River Unit• Well: SRU 21A-34 ` ' ACTUAL SCHEMATIC Completion Ran:9/02/2010 PTD: 190-059 API: 50-133-10171-01 Hilcorp Alaska,LLC RKB:154'/GL 134'AMSL RT-THF:25.85'KB Casing and Tubing Detail Je 1 Size Type Wt/Grade Top Btm CONN/ID Cement/Other 22"@ 33' 22" Structural Surface 33' Cemented 47#, J-55 Surface 1,496' 600sxs 116#(stage 1), >vcollar 11-3/4" Surface DV Collar 1,496' 1,498' 8R/11.000" 1250sxs 116#(stage 2) g 1,496' I 47#,J-55 1,498' 3,030' 29#, N-80 Surface 87' BT/6.184" 4 • 23#, N-80 87' 4,794' BT/6.366" 26#, N-80 4,794' 6,701' L8R/6.276" 11-3/4" I , 2 700sxs 116#(stage 1), @3,030' 7" Surface 29#, N-80 6,701' 7,087' L8R/6.184" 1150sxs 116#(stage 2) c:.3 DV Collar 7,087' 7,089' L8R/6.184" t.a 29#, N-80 7,089' 8,514' L8R/6.184" 29#, P-110 8,514' 8,575' L8R/6.184" DV Collar [ 5 1 5" Liner 18#, N-80 8,236' 10,835' FL4S/4.276" 90 bbl 15.8 ppg @7'°87 EUE 8rd Mod/ R-. t s 2 2-7/8" Liner 6.5#, N-80 10,276' 11,159' 2.441" 10 bbl 15.6 ppg 7 Tubing 8 3 1/2" Prod 9.2#, L-80 Surface 8,044' TC-ll/2.992" I Cplg OD=3.887" Production String Jewelry Detail # Depth(RKB) Length ID OD Item - 9 1 25.85' 0.6' 2.992" 4.250" Tubing Hanger, 3-1/2"IBT Lift Threads S' gis 10 2 3,323' 6.33' 2.992" 5.140" GLM,GLMAX-1.ORSL(Drift=2.867") Milled out 3 4,825' 6.33' 2.992" 5.140" GLM,GLMAX-1.ORSL(Drift=2.867") of 7"at µ 4 6,203' 6.33' 2.992" 5.140" GLM,GLMAX-1.ORSL(Drift=2.867") 8,575'-8,635' , Perfed& 5 7,525' 6.33' 2.992" 5.140" GLM, GLMAX-1.ORSL(Drift=2.867") (6/14/90) squeezed •cement from 6 7,936' 4.15' 2.813" 4.250" XD Sliding Sleeve,2.813"Min ID 11 ' r, 8,550-60'& 7 7,985' 1.83' 2.720" 4.250" XN-Profile,2.720"No-Go ID 11/90' 16/11/90) 8 8,044' - - 5.130" Top of ESP, Discharge Head (6/ 9 8,233' 5.625" Btm of ESP, 562 Motors/513 Pumps 10 8,236' Liner top packer 11 9,057' 9.36' 2.555" 3.96" HES BWD Permanent Packer w/seal bore X 12 extension Possible Casing 12 9,100' 1.27' 1.875" - 2-3/8"Halliburton X Nipple =allure @—9,112' 13 10,150' 5.86' 1.99" 3-15/16" Tristate Overshot 13 14 10,157' 6.27' 1.99" - 2-3/8"GLM 2-3/8"pup jtw/ 15 10,169' 3.07' - - Baker DB Packer w/R Guide&millout extension top chemical 1a 16 10,175'-10,187' 12.00' - - Tubing Punch w/4 spf(47 holes total) cut at 10,153' '''#'11111i` 15 17 10,186'-10,188' 2.00' - - Tubing Punch w/4spf guns(8 holes total) : :.a 16 : 18 10,190' - - - FISH: PX plug 17 : 18 19 10,191' 1.20' 1.875" OtisX Nipple 19 20 10,223' 58' 1.99" Wireline Re Entry Guide 1111 +zo + Top of Possible liner '{ 2-7/8"liner Perforation Data lap leak L/j @ 10,276' (11/10/91) ZONE TOP BTM Shot Condition H-1 10,918' 10,920' 4jspf 1-11/16"jumbo jet III(9/10/90) 5"@10,835' 10,920' 10,934' 4jspf 1-11/16"jumbo jet III(9/10/90) 10,934' 10,948' 4jspf 1-11/16"jumbo jet III (9/10/90) 10,948' 10,960' 4jspf 1-11/16"jumbo jet III (9/10/90) H-2 10,966' 10,980' 4jspf 1-11/16"HC(2/26/91) H-1 10,980' 10,994' 4jspf 1-11/16"HC(2/26/91) H-2 2-7/8"@11,159'.I.: •`. TD=11,160' PBTD=11,050' Directional Data: max hole angle=36.5°at 10,700'MD Downhole Revised:9/02/2010 Updated by STP 10/03/2013 • Swanson River Unit • • • Well: SRU 21A-34 - PROPOSED SCHEMATIC Completion PTD:Proposed 190-059 API: 50-133-10171-01 Hilcorp Alaska,LLC RKB:154'/GL 134'AMSL RT-THF:25.85'KB Casing and Tubing Detail J1 Size Type Wt/Grade Top Btm CONN/ID Cement/Other 22"@ 33' 22" Structural Surface 33' Cemented 47#,J-55 Surface 1,496' 600sxs 116#(stage 1), AlCdlar 11-3/4" Surface DV Collar 1,496' 1,498' 8R/11.000" 1250sxs 116#(stage 2) a 1,496' I 47#, J-55 1,498' 3,030' 29#, N-80 Surface 87' BT/6.184" 4 23#, N-80 87' 4,794' BT/6.366" 11-3/4" 26#, N-80 4,794' 6,701' L8R/6.276" 700sxs 116#(stage 1),I @3,030' ^iz 7" Surface 29#, N-80 6,701' 7,087' L8R/6.184" 1150sxs 116#(stage 2) rs DV Collar 7,087' 7,089' L8R/6.184" 29#, N-80 7,089' 8,514' L8R/6.184" i , ,4 29#, P-110 8,514' 8,575' L8R/6.184" DV Collar [ ] 5" Liner 18#, N-80 8,236' 10,835' FL4S/4.276" 90 bbl 15.8 ppg @ 7,087' I :,>5 2-7/8" Liner 6.5#, N-80 10,276' 11,159' EUE 8rd Mod/ 10 bbl 15.6 ppg 2.441" Tubing 6 3-1/2" Prod I 9.2#, L-80 Surface 8,016' I TC-II/2.992" [ Cplg OD=3.887" Production String Jewelry Detail # Depth(RKB) Length ID OD Item 7 1 25.85' 0.6' 2.992" 4.250" Tubing Hanger, 3-1/2"IBT Lift Threads 0 �- 8 2 3,323' 6.33' 2.992" 5.140" GLM,GLMAX-1.ORSL(Drift=2.867") Milled out 3 4,825' 6.33' 2.992" 5.140" GLM, GLMAX-1.ORSL(Drift=2.867") of 7"at 4 6,203' 6.33' 2.992" 5.140" GLM,GLMAX-1.ORSL(Drift=2.867") 8,575'-8,635' , Perfed& 5 7,525' 6.33' 2.992" 5.140" GLM,GLMAX-1.ORSL(Drift=2.867") (6/14/90) squeezed cement from 6 8,016' 4.000" Top of ESP,Discharge Head 9 Ma .1 8,550-60'& 7 8,220' 5.520" Btm of ESP,456 Motors/400 Pumps 8,605-15'(6/11/90) .I I `' 8 8,236' Liner top packer 9 9,057' 9.36' 2.555" 3.96" HES BWD Permanent Packer w/seal bore extension 10 9,100' 1.27' 1.875" - 2-3/8"Halliburton X Nipple 10 11 10,150' 5.86' 1.99" 3-15/16" Tristate Overshot Possible Casing 12 10,157' 6.27' 1.99" - 2-3/8"GLM =allure @-9,112' 13 10,169' 3.07' - - Baker DB Packer w/R Guide&millout extension I.11 14 10,175'-10,187' 12.00' - - Tubing Punch w/4 spf(47 holes total) 2-3/8"pup jtw/ 15 10,186'-10,188' 2.00' - - Tubing Punch w/4spf guns(8 holes total) �" 12 top chemical = 16 10,190' - - - FISH: PX plug cut at10,153' r-' '1-'N. 13 17 10,191' 1.20' 1.875" - OtisX Nipple s__a a_c. 14 ; 18 10,223' .58' 1.99" - Wireline Re-Entry Guide 15 16 © 17 18 Perforation Data Top of ZONE TOP BTM Shot Condition Possible liner 2-7/6'liner H-1 10,918' 10,920' 4jspf 1-11/16"jumbo jet III(9/10/90) lap leak $ @ 10,276 (10/15/90) 10,920' 10,934' 4jspf 1-11/16"jumbo jet III(9/10/90) 4. lb. 10,934' 10,948' 4jspf 1-11/16"jumbo jet III (9/10/90) 5"@ 10,835' 10,948' 10,960' 4jspf 1-11/16"jumbo jet III(9/10/90) •. H-2 10,966' 10,980' 4jspf 1-11/16"HC(2/26/91) 10,980' 10,994' 4jspf 1-11/16"HC(2/26/91) H-1 '1y I H-2 2-7/8"@ 11,159' I „p TD=11,160' PBTD=11,050' Directional Data: max hole angle=36.5°at 10,700'MD Downhole Proposed Updated by STP 10/03/2013 • � Swanson River 2013 Moncla Rig#405 Knight Oil Tools BOP Hilrnrr Uarksn.l.l.(. 0 i 1 lii lil lil I i l l ti 2.57' Shaffer 7 1/16 5009, 1111 111-111 111 1 1. III 111 111 IF EU _ 2 3/8-31/2 variable y+ CAMERON 3.681 , �'I .m: Blind 6-.47 1/16 5000 Ii_ y1� lil Itl 1111111 lil Choke and Kill valves are 2 1/16 10M _ 111 111 111.111 III r:: .:1 ! - a ' ' 1!( ' 1P 1.56' i 7 1/16 500 • _ • -a It • �_ 111 111 111 111 111 • • ~~~~C~ 0~ I~~Q~~a /,E..~a~,~w.E~~ Timothy C. Brandenburg Drilling Manager Union Oil Company of California ~~~ ~`~~~~..~ `~'~'r _"~ `~' O~ P.O. Box 196247 O Anchorage, AK 99519 1~ Re: Swanson River Field, Hemlock Oil Pool, SRU 21A-34 Sundry Number: 310-245 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. 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. Chair DATED this l ~ day of August, 2010. Encl. ,t~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 F~~J~D /o-~o au~ a ~ ~o~ww~-- °~~ [0~4° ~1~~sk~ ~ Gas ~~ti ~~CIiJI'2g~ 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Pertorations ^ Perforate ^ Pull Tubing ^~ - Time Extension ^ Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ^ Alter Casing ^ ESP Conversion ^~ - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^~ Exploratory ^ 190-059 - 3. Address: ^ Stratigraphic ^ Service 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-10171-01 - 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^' Swanson Riv Unit (SRU) 21A-34- 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028406 [Swanson River Unit] - Swanson River Field /Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11,160 10,859 11,050 10,764 10,191 (PX Plug) 10,191 (PX Plug) Casing Length Size MD ND Burst Collapse Structural Conductor 33' 22" 33' 33' Surface 3,030' 13-3/8" 3,030' 3,029' 3,070 psi 1,510 psi Intermediate Production 8,575' 7" 8,575' 8,571' 6,340 psi 3,830 psi Liner 2,599' S" 10,835' 10,578' 10,140 psi 10,490 psi Liner gg3' 2-7/8" 11,159' 10,858' 10,570 psi 11,160 psi Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,918'-10,960', 10,966' j 10,650'-10,686', 10,691'- 3-1 /2" x 2-3/8" ~ 9.2# L-80 x 4.6# L-80 Surt-8,173' x 8,173'-9,054' 10,994' 10,715' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): HE BWD Permanent Packer 8~ Baker DB Packer / N/A 9,057'MD (9,049'ND) & 10,169'MD (10,034'ND) / N/A 12. Attachments: Description Summary of Proposal ^~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development ^~ - Service ^ 14. Estimated Date for 8/22/2010 15. Well Status after proposed work: Commencing Operations: Oil ^~ - Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: N/A WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola 263-7640 Printed Name Timothy C. Brandenburg Title Drilling Manager Si nature ~7 Phone 276-7600 Date 8/4/2010 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test [~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ .g~-~ ~~ ~~' l'O 000 r0 S.t. - Subsequent Form Required: ~O _ ~O ~, APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ` ~ ~ l -- ~~S A~1~2 ~oRi~iNA~ Form 10-403 Revised 12/2009 Submit in Duplicate Chevron • OBJECTIVE: i Swanson River Unit Well #SRU 21A-34 8/04/10 • Pull existing gaslift completion, add additional tubing punches in 2-3/8" tubing, cleanout 7" casing, remove old and install new tubing spool, and run new ESP completion. PROCEDURE SUMMARY: 1. MIRU Key Energy Rig #3. 2. Install BPV, ND tree, NU BOPE & test same 250psi low/ OO~i high, pull BPV. 3. Pum~%1KCI down tubing and annulus. Pull 3-1/2" x 2-3%8" production tubing from packer at 9,054'. 4. Change out 2-3/8" pipe rams and install 2-7/8" pipe rams. Test same 250psi low/ 3,000 psi high. ~ 5. Tubing punch 12' section of 2-3/8" tubing above PX plug at 10,174' - 10,186' (+/-). 6. Set 5" retrievable bridge plug at 8,500'(+/-). Test plug to 1,500 psi. 7. Scrape 7" casing to 5" liner top depth of 8,236'. 8. ND BOPE and ND tubing spool. NU new tubing spool. NU BOPE. Shell test to 250psi low/3000psi high. ~ 9. Pull 5" retrievable bridge plug. Spot 20 bbl sized-salt pill to create a debris barrier from plugging tubing. 10. Run 3-1/2" tubing ESP completion to 8,200' (+/-). ~ 11. Set BPV, ND BOPE, NU Tree. 12. Release Key Energy Rig #3. 13. Return the well to production. Current BHP: 2,975 psi @ 10,654' TVD Max Downhole Pressure: 2,975 psi @ 10,654' TVD (Based on SITP =1,060 psi, fluid level at 6,247' and a produced water gradient) MASP: 1,910 psi (Based on a pressure gradient of 0.1 psi per foot of true vertical depth) ~ SRU 21A-34 Operation Summary 8-04-10.doc REVISED BY: STP 8/04/10 RKB: 154' / GL: 134' AMSL RT-THF: 25.85 I~ 2r' @ • 33' NV Cdlar ; ' a 1,a95 ti, 11314" ~ 3,030' ~~~• DV Collar ~. 1 ~~ ~ .' ~ 7,OBT 2 Milled out I of T' at 8,575-8,635' , (8/14190) s i g.. Possible Casing =aiure 1~ii-9,117, 2.318" pup 1< wl top chemical cut at 10,153' 11 3 a =~ 5 Pe Red & squeezed ~: cementfram e, s5oso' a 8,605-15' (fi~11/90) 7 a 1 9 •~ +`. ''~ 10 •:t. 12 ..+ 13 ;~.~ 14 '• Possible liner lap leak (10115190) 5' 010.835' H-1 H-2 Top of I -, 2-7/8" Iner 10, 276' Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement /Other 22" Structural Surface 33' Cemented 47#, J-55 Surface 1,496' 1 600 116# t 11-3/4" Surface DV Collar 1,496' 1,498' 8R / 11.000" ), sxs (s age 1250sxs 116# (sta e 2) 47#, J-55 1,498' 3,030' g 29#, N-80 Surface 87' BT 16.184" 23#, N-80 87' 4,794' BT / 6.366" 26#, N-80 4,794' 6,701' L8R / 6.276" 1 116# t 700 7" Surface 29#, N-80 6,701' 7,087' L8R / 6.184" ), sxs (s age 1150sxs 116# (sta e 2) DV Collar 7,087' 7,089' L8R / 6.184" g 29#, N-80 7,089' 8,514' L8R / 6.184" 29#, P-110 8,514' 8,575' L8R / 6.184" 5" Liner 18#, N-80 8,236' 10,835' FL4S / 4.276" 90 bbl 15.8 2-7/8" Liner 6.5#, N-80 10,276' 11,159' EUE 8rd Mod / 2.441 " 10 bbl 15.6 ppg Tubing 3-1/2" Prod 9.2#, L-80 Surface 8,173' TC-II / 2.992" C I OD = 3.887" 2-3/8" Prod 4.6#, L-80 8,173' 9,054' TC-II /1.995" C I OD = 2.675" Production Strin Jewel Det ail # Depth (RKB) Len th ID OD Item 1 3 545', 5,328', 6,711', 8,124' 6.80' 2.992" 5.313" 3-1/2" SFO-1 GLMs (Drift = 2.867") [Gaslift valves installed on 8/28/09 2 8,173' 1.56' 1.990" 3.887" X-Over 3-1 /2" TC-II B x 2-3/8" TC-II P 3 8,236' - - - Liner to acker 4 8,638' 7.10' 1.995" 3.875" 2-3/8" BST GLMAX-1(SC) GLM (Drift = 1.901") Dumm valve installed on 8/26/09 5 9,054' 9.80' 1.920" 2.550" HES Seal Assembly w/ straight slot locator bottom of locator 2.0' above acker 6 9,057' 9.36' 2.555" 3.96" HES BWD Permanent Packer w! seal bore extension 7 9,100' 1.27' 1.875" - 2-3/8" Halliburton X Ni le 8 10,150' 5.86' 1.99" 3-15/16" Tristate Overshot 9 10,157' 6.27' 1.99" - 2-3/8" GLM 10 10,169' 3.07' - - Baker DB Packer w/ R Guide & millout extension 11 10,188'-10,186' - - - Tubin Punch w/ 4s f uns 8 holes total 12 10,190' - - - FISH: PX lu 13 10,191' 1.20' 1.875" - Otis X Ni le 14 10,223' 58' 1.99" - Wireline Re-Ent Guide Perforation Data ZONE TOP BTM Shot Condition H-1 10,918' 10,920' 4's f 1-11/16" umbo'etIII 9/10/90 10,920' 10,934' 4's f 1-11/16" ~umbo 'et III 9/10/90 10,934' 10,948' 4's f 1-11/16"'umbo'et III 9/10/90 10,948' 10,960' 4 s f 1-11/16" ~umbo ~et III 9/10/90 H-2 10,966' 10,980' 4's f 1-11/16" HC 2/26/91 10,980' 10,994' 4's f 1-11/16" HC 2/26/91 2-718" ~ 11,159`• L', l:~'^ D' TD=11160' PBTD=11050' Directional Data: max hole angle = 36.5° at 10,700' MD SRU 21A-34 Actual WBD 8-28-09 doc Updated by STP 8-07-10 RK@ 154' I GL 134' AMSL RT-THF: 25.85 KB 1 2r' ~ 33' ~NCdlar . ' a 1,ass' 1131a" 2 {~ 3,030' 3 a DV Collar ~ 5 ~ 7,OBT _ s XN 7 Q $ s Milled out of T' at 8,578-8,635' Pe Red & (6114190) squeezed -cement from 11) a, 55osa a 8,606-15' ~_, (&11/90) . 11 . Possible Casing =atlure~ID-9,117. 12 ~ ~. 2-3!8" pup jt w/ top chemical cut at 10,153' 17 18 19 Possible liner lap leak (1alysoj 5" (~ 10,835' H-1 H-2 Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement /Other 22" Structural Surface 33' Cemented 47#, J-55 Surface 1,496' 11-3/4" Surface DV Collar 1,496' 1,498' 8R / 11.000" 600sxs 116# (stage 1), 1250 116# 2 t 47#, J-55 1,498' 3,030' ) sxs (s age 29#, N-80 Surface 87' BT / 6.184" 23#, N-80 87' 4,794' BT / 6.366" 26#, N-80 4,794' 6,701' L8R / 6.276" 7" Surface 29#, N-80 6,701' 7,087' L8R / 6.184" 700sxs 116# (stage 1), 1150 116# 2 t DV Collar 7,087' 7,089' L8R 16.184" sxs (s ) age 29#, N-80 7,089' 8,514' L8R / 6.184" 29#, P-110 8,514' 8,575' L8R / 6.184" 5" Liner 18#, N-80 8,236' 10,835' FL4S / 4.276" 90 bbl 15.8 2-7/8" Liner 6.5#, N-80 10,276' 11,159' EUE 8rd Mod / 2.441 " 10 bbl 15.6 ppg Tubing 3-1 /2" Prod 9.2#, L-80 Surface +/- 8,010' TC-II / 2.992" Cpl OD = 3.887" Production Strin Jewel Det ail # De th RKB Len th ID OD Item 1 25.85' 0.6' 2.992" 4.250" Tubin Han er, 3-1/2" IBT Lift Threads 2 +/- 3,600' +/- 6.0' 2.992" 5.140" GLM, GLMAX-1.ORSL Drift = 2.867" 3 +/- 5,000' +/- 6.0' 2.992" 5.140" GLM, GLMAX-1.ORSL Drift = 2.867") 4 +/- 6,400' +/- 6.0' 2.992" 5.140" GLM, GLMAX-1.ORSL Drift = 2.867" 5 +/- 7,800' +/- 6.0' 2.992" 5.140" GLM, GLMAX-1.ORSL Drift = 2.867" 6 +/- 7,920' +/- 6.0' 2.813" 4.250" XD Slidin Sleeve, 2.813" Min ID 7 +/- 7,970' +/- 1.0' 2.720" 4.250" XN-Profile, 2.720" No-Go ID 8 +/- 8,010' +/- 190' - 5.625" ESP, 562 series Motors and 513 series Pum s 9 8,236' - - - Liner to acker 10 9,057' 9.36' 2.555" 3.96" HES BWD Permanent Packer w/ seal bore extension 11 9,100' 1.27' 1.875" - 2-3/8" Halliburton X Ni le 12 10,150' 5.86' 1.99" 3-15/16" Tristate Overshot 13 10,157' 6.27' 1.99" - 2-3/8" GLM 14 10,169' 3.07' - - Baker DB Packer w/ R Guide & millout extension 15 +/- 10,174'- +/-10,186' 12.00' - - Tubing Punch w/ 4 spf (48 holes total) 16 10,186'-10,188' 2.00' - - Tubin Punch w/ 4s f uns 8 holes total 17 10,190' - - - FISH: PX lu 18 10,191' 1.20' 1.875" - OtisX Ni le 19 10,223' .58' 1.99" - Wireline Re-Ent Guide 1a Perforation Data ZONE TOP BTM Shot Condition H-1 10,918' 10,920' 4's f 1-11/16" ~umbo'et III 9/10/90 10,920' 10,934' 4's f 1-11/16"'umbo'et III 9/10/90 10,934' 10,948' 4's f 1-11/16" ~umbo'et III 9/10/90 10,948' 10,960' 4's f 1-11/16" ~umbo ~et III 9/10!90 H-2 10,966' 10,980' 4's f 1-11/16" HC 2/26/91 10,980' 10,994' 4's f 1-11/16" HC 2/26/91 op of 78" Iner 10, 276' 2-718"~11,159'•d;,' D' TD=11,160' PBTD=11,050' Directional Data: max hole angle = 36.5° at 10,700' MD SRU 21A-34 Proposed WBD 8-03-10 ESP.doc Updated by STP 8-03-10 Chevron • • Summary of Key Energy Rig #3 Specifics SRU 21A-34 Convert to ESP The SRU 21A-34 workover is to pull the existing gaslift completion, cleanout the 7" casing, isolate the well and replace the existing tubing spool, and run a new ESP completion. The rig specifics are for the planned rig up on this well and are likely to change from well to well. Proposed Configuration Rig Model The rig model is a Hopper Hydra-hoist, Back-model GXXTA. Drawworks The drawworks are GXXTA-MD 10x42; w/ Sand Drum 15,000 ft - 9/16" sand line. Derrick The derrick is a telescoping double, with 260,000 Ib capacity, 30" crown sheaves and McKissick 30" 150 ton 73A traveling block. Pipe Handling The pipe handling system is a HydraWalk-hydraulic catwalk, 38' long, 5' wide, 5' high. The base beam is internally guided and load bearing. The beam is load rated with 102' derrick and 10,000 of 2- 7/8" tubing to 58 mph winds. BOP Specifications Annular, 5M 7-1/16" Hydril Single gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram (2-3/8", 2-7/8", or 3-1/2" rams) Double gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram (2-3/8", 2-7/8", or 3-1/2" rams) and blind ram Mud Cross, 5M, 7-1/16" BOP Diagram See attached. Accumulator 120 gallon KOOMEY Accumulator System. Includes 5 functions with manual bypass and remote panel. Eight 15 gallon accumulator bottles. 200 gallon hydraulic tank with air operated hydraulic pump. Pits The pit consists of a 200 bbl tank partitioned into three isolatable compartments. An optional shale shaker is also available that is a 3'x4' Jr. Standard-hydraulic driven. Pump The pump is a National JWS-400 7"x4.5" Triplex rated to 5,000 psi on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Key Energy Rig #3 Specs (SRU 21A 34) rev0.doc 8/03/10 Chevron ~ , Kill Line Valves The kill line valves consist of 2 ea. manually operated, 2-1/16", 5M valves attached to the mud cross with co-flex hose with aUnibolt/Hub-flanged connectors. Choke Line The choke line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Choke Line Valves The choke line valves consist of 1 ea. manually operated, 2-1/16" 5M valve and 1 ea. automatically operated HCR valve that is attached to the mud cross with co-flex hose with aUnibolt/Hub-flanged connectors. Choke Manifold See attached. Choke Return Line/Diffuser Line The diffuser line will consist of 2", 5,000 psi hose with Unibolt connections. The line will run from the choke manifold to the diffuser tank. Diffuser Tank A diffuser tank will be placed adjacent to the mud pits with the capability of fluid transfer to the circulating system. Gas Detection There is a single gas LEL monitor and a single H2S monitor be placed at the work platform;~nd a single gas LEL monitor and a single H2S monitor at the shale shaker if used. PVT There is no PVT system for the circulation system on this workover rig, as is standard practice in this type of well service work. Key Energy Rig #3 Specs (SRU 21A 34) rev0.doc 8/03/10 r Ch_ evron BOPE Diagram SRU 21A-34 Workover 8/03/2010 3.08' 0.94' 1.04' 227' Kill line 2 1/16 Annular preventer, H} 7 1/16 5M Flange< ing a gate, 7affer Chasovoy 7 1/1 stdd X 7 1/16 5M stc ffer Chasovoy 7 1/1 ~tdd X 7 1~ 5M stc O• (•_C )~) Pipe Ram ~ 9.00' Pipe Ram 1.6T o 0 00 00 Unibolt Blind Ram Mud Cross, 7 1/16 5M FE X 7 1/16 5M FE w/ 2 1/16 5M X 2 1/16 5M EFO Choke line 2 1/16 5M HCR Unibolt Che1-ro11 ~ Swanson River 2010 Choke Manifold 08/03/2010 Blooey Line To Gas Buster Unibolt Connection O 9 0 O ~' K1Cs 14- STATE OF ALASKA ' 't jL3 ~z-oot ALAS~IL AND GAS CONSERVATION COMMIS~ REPORT OF SUNDRY WELL OPERATI~NS 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Run 3-1/2" x 2-3/8" Performed: Alter Casing ^ Pull Tubing ^~ Perforate New Pool ^ Waiver ^ Time Extension ^ completion Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of Califomia 4. Well Class Before Work: 5. Permit to Drill Number : Name: Development ^~ F~cploratory ^ 190-059 / 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic^ Service ^ 6. API Number: 50-133-10171-01 --~p ~ 8. Property Designation (Lease Number): 9. Weil Name and Number: FEDA028406 (Swanson River Unit] ~ Swanson River Unit 21A-34 ~ 10. Field/Pool(s): ~ Swanson River Field / Hemlock Oil Pool 11. Present Well Condition Summary: Total Depth measured 11,160 ~ feet Plugs (measured) 10,191 {PX plug) feet true vertical 10,859~~ ~~ f~/ ~ ~ Junk (measured) N/A feet Effective Depth measured 11,050 feet Packer (measured) 9,057 & 10,169 feet true vertical 10,764 feet (true vertical) 9,049 & 10,034 feet Casing Length Size j MD j ND Burst Collapse Structural Conductor 33' 22" 33' 33' Surface 3,030' 11-3/4" 3,030' 3,029' 3,070 psi 1,510 psi Intermediate 8,575' 7" 8,575' 8,571' 6,340 psi 3,830 psi Production 2,599' 5" 10,835' 10,578' 10,140 psi 10,490 psi Liner 883' 2-7/8" 11,159' 10,858' 10,570 psi 11,160 psi Perforation depth: Measured depth: 10,918'-10,960' & 10,966'-10,994' a,;h - ~ F,~,s• ~ J ~ , >. ~ ~ , . . ,,. . True Vertical depth: 10,650'-10,686' & 10,691'-10,715' Tubing (size, grade, measured and true vertical depth): 3-1/2" x 2-3/8" 9.2# L-80 x 4.6# L-80 8,173' x 9,054' MD 8,169' x 9,046' ND Packers and SSSV (type, measured and true vertical depth): HES BWD Perm & Baker DB Packer / N/A 9,057' & 10,169' / N/A 9,049' & 10,034' / N/A -' ILv g~SZ~ MD ND 12. Stimulation or cement squeeze summary: 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: 35 150 600 1260 psi (gaslift) 1240 psi Subsequent to operation: 68 537 1634 1600 psi (gaslift) 400 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ~^ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ 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: 309-248 / Contact Stan Porhola 263-7640 Printed Name Timothy C. Brandenburg -, Title Drilling Manager , t- Signature ' '~ ~ Phone 276-7600 Date 9/22/09 ~~~~~~~~ ~~~ ~~~ ~ `~ tii0~+ Form 10-404 Revised 7/2009 Submit Original Only ~ ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 21A-34 SWANSON RIV UNIT 21A-34 FEDA028406 5013310171 QA5347 26.00 ~ , ~+, s ~ +k~.:. `*J ~ ~ ,;gt ~ ^~?' ~ ~~.:a',~ C. ~~?;~ s~ ~ Y ~*'~..;• ~~: ~ :. Y ~' ~ „ ~E^ . ~c r ~' ~ Primary JobType Job Category Objective Actual Start Date Actual End Date Tubing Repair Major Rig 8/22/2009 8/29/2009 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number SRU 21A-34 5013310171-01 1900590 Dai f~~' ~ r~tfoi~~ x~ ~ ~ , ._ :.,-. J _ ~ ,~ :. ~. . . . . 8/22/2009 00:00 - $/23/2009 0~~0{~ ' . , Operations Summary R/U to circ. Test lines to 3000 psi - test OK. Pump 3% KCI down tubing and annulus. Monitor weli, 0 psi. Set BPV. N/D tree. N/U BOPE and test to 250/3000 psi - test OK. Witness waived by BLM & AOGCC Jim Regg. R/U to pull tubing. P/U to 117k, tubing parted downhole. POOH. UD tubing. ~ ~23l2009 00:00 - 8/24/2009 00:00 ° `" Operations Summary UD tubing. Recovered 6385', parted 7.43' down 1st full joint below GLM #7. Change pipe rams from 2-3/8" to 3-1/2" and test to 250/3000 psi - test OK. P/U fishing overshot. RIH and tag fish at 6401'. Attempt to latch fish. srzat~ot~~ a~.a~ ~ sra~~aaa oo:oo Operations Summary Work over top of fish at 6401'. Overpull up to 87k. Working tubing and seal assembly up hole. POOH. UD tubing and seal assembly (full recovery). UD workstring. 8/25/2009 00:00 - 8/26/2009-04:00 Operations Summary Cont. UD work string. Change pipe rams from 2-7/8" to 2-3/8", Test BOPE 250 low/ 3000 high - test OK. Test witness waived by BLM & AOGCC J~ Regg. RIH with 2-3/8" x 3-1/2" Completion. s~ss~2oo~ oo:oo - s~2~izoos oo:oa Operations Summary Cont. RIH with 2-3/8" 4.6# L-80 x 3-1/2" 9.2# L-80 Completion. Sting into packer at 9057'. Space out and land tubing hanger. Test annulus to 2500 psi for 30 min - test OK. Set BPV. N/D BOPE. N/U Tree. Test tubing hanger and tree adapter to 250/5000 psi for 30 min - test OK. Pull BPV. Set TWC. Test tree to 250/5000 psi for 30 min - test OK. Pull TWC. R/D Key Energy Rig #3. Release rig at midnight. Move rig to SCU 33-33. 8t27/2009 00:00 - 8/28/2009 00:00 ~ Operations Summary R/U slickline. RIH w/ 1.84" GR and tag GLM #5 at 8651' SLM. POOH. RIH w/ 1.75" drive-down bailer, 1.5" GR, and 1.85" LIB. Unable to work passed 8651' SLM. Change out dummy valves w/ gasiift valves in GLM #3, and #4. Attempt to pull dummy valve in GLM #5. Latched valve but did not recover valve. POOH. Rest crews. $l28/2009 00:00 - 8/29/2009 00:00 Operations Summary R/U slickline. Test lubricator to 250/2500 psi - test OK. RIH w/ 1.75" overshot to 8651' RKB. Attempt to pull dummy valve in GLM #5 - no joy. POOH. RIH w/ 1.50" pulling tool to 8651' RKB. Attempt to pull dummy valve in GLM #5 - no joy. POOH. RIH w/ 1.50" LIB to 8655' RKB. POOH. Found deep groove on one side. Pull dummy vavles in GLM #1 and #2. R/D slickline. evro SRU 21A-34 - • ' ~ . _ ..~ ,_ _ ~ - ' ~ `~ - ~ Actual Wellbore Schematic • Rr-niF: zs.as ~ ', zr~~ . 33' , ~IV Cdlar D 1,496' 11314" ~ 3,OJ0' 1 DV Collar ~~.~T ~ 2 3 Mllled out -~ Peded & of T' at 4 ~ squeezed 8,578-8,635 ' •' cement fram (6174190) , '• e,ssosas : 5 .. 8,605-15' ~ (6/11/90) 6 .~ ~ . ,~ ,~ : : x ~ .. Possible Casing 'aYure~-9,11z Casing and Tubing Detail Size Type WU Grade Top Btm CONN / ID Cement / Other 22" Structural Surface 33' Cemented 47#, J-55 Surface 1,496' 11-3/4" Surface DV Collar 1,496' 1,498' 8R / 11.000" 600sxs 116# (stage 1), 1250s s 116# (sta e 2) 47#, J-55 1,498' 3,030' x g 29#, N-80 Surface 87' BT / 6.184" 23#, N-80 87' 4,794' BT / 6.366" 26#, N-80 4,794' 6,701' L8R / 6.276" 7" Surface 29#, N-80 6,701' 7,087' L8R / 6.184" 700sxs 116# (stage 1), 1150 116# 2 t DV Collar 7,087' 7,089' L8R / 6.184" (s ) sxs age 29#, N-80 7,089' 8,514' L8R ! 6.184" 29#, P-110 8,514' 8,575' L8R / 6.184" 5" Liner 18#, N-80 8,236' 10,835' FL4S / 4.276" 90 bbl 15.8 2-7/8" Liner 6.5#, N-80 10,276' 11,159' EUE 8rd Mod / 2.441 " ~0 bbl 15.6 ppg Tubing 3-1/2" Prod 9.2#, L-80 Surface 8,173' TC-II / 2.992" C I OD = 3.887" 2-3/8" Prod 4.6#, L-80 8,173' 9,054' TC-II /1.995" C I OD = 2.675" Production Strin Jewel Det ail # De th RKB Len th ID OD Item ~ 3,545', 5,328', 6,711', 8,124' 6.80' 2.992" 5.313" 3-1/2" SFO-1 GLMs (Drift = 2.867") [Gaslift valves installed on 8/28/09 2 8,173' 1.56' 1.990" 3.887" X-Over 3-1/2" TC-II B x 2-3/8" TC-II P 3 8,236' Liner to acker 4 8,638' 7.10' 1.995" 3.875" 2"3/8" BST GLMAX-1(SC) GLM (Drift = 1.901 ") Dumm valve installed on 8/26/09 5 9,054' 9.80' 1.920" 2.550" HES Seal Assembly w/ straight slot locator bottom of locator 2.0' above acker 6 9,057' 9.36' 2.555" 3.96" HES BWD Permanent Packer w/ seal bore extension 7 9,100' 1.27' 1.875" 2-3/8" Halliburton X Ni le 8 10,150' 5.86' 1.99" 3-15/16" Tristate Overshot 9 10,157' 6.27' 1.99" 2-3/8" GLM 10 10,169' 3.07' Baker DB Packer w/ R Guide & millout extension 11 10,188'-10,186' Tubin Punch w/ 4s f uns 8 holes total 12 10,190' FISH: PX lu 13 10,191' 1.20' 1.875" OtisX Ni le 14 10,223' .58' 1.99" Wireline Re-Ent Guide PerForation Data ZONE TOP BTM Shot Condition H-1 10,918' 10,920' 4's f 1-11/16" ~umbo 'et III 9/10/90 10,920' 10,934' 4's f 1-11/16" umbo ~et III 9/10/90 10,934' 10,948' 4~s f 1-11/16" 'umbo ~et III 9110/90 10,948' 10,960' 4~s f 1-11/16" umbo et III 9/10/90 H-2 10,966' 10,980' 4~s f 1-11/16" HC 2/26/91 10,980' 10,994' 4's f 1-11/16" HC 2/26/91 H-1 H-2 2-7/8" ~ 11,159' , . Ma~c angle = 36.49° ~ 10,70V ND TD=11,160' PBTD=11,050' SRU 21A-34 Actual WBD 8-28-09.doc Updated by STP 9-11-09 ! ~'O ° O5~ Page 1 of ~ ~ ~ Aubert, Winton G (DOA) From: Aubert, Winton G (DOA) Sent; Thursday, September 10, 2009 9:d8 AM Ta: 'P~RHOLA, STAN T Cc: Maunder, Thomas E (DOA) Subject: RE: SRU 21A-34 (Sundry 309-248) Re-pull tubing , :, .. ~ _ ~ _ ,_ .. F:,~ra~ ~~~ .. . n .. , ~...:~~r , .~. ~.;.:.,~., _. . _ ~,_F. ,_ }~ . ~ . ,. `~ - - ~~ ~~:. ; ~`~ ~; "~ .~ ,. From: PORHOLA, STAN T [maitto:stan.portrola~chevron.com] ~~~: ~ltu~ay, Septerrtb2r 10, 200g 8:~2 AM To: Aubert, Winton G (DOA) Cc: Kanyer, Chris~topher V; Maunder, Thomas E(DOA) p Subject: SRU 21A-34 (Sundry 309-248) Re-pull tubing ~- l) ~-1 Winton, ~~ The pulling unit operations for SRU 21A-34 (Sundry 309-248) were completed on 8/26/09. Follow-up slickline work has indicated an obstruction in the tubing near the bottom gaslift mandrel in the 2-3/8" tubing. Diagnostics have been inconclusive but it is believed to be an over-torqued connection, bent tubing, or an issue with the gaslift mandrel and/or the dummy valve currently installed in the mandrel. The well is currently being gaslifted and flowing +/-1700 bbl/d w/ 96% water cut. Our proposal is to rig-up with the Key Energy pulling unit again and perform the same operations as steps #5 -#11 in the approved sundry (309-248) to replace the tubing/jewelry that is causing the obstruction. Removing the obstruction would allow future access to the gaslift mandrel and the tubing below, and likely increase production with active gaslift lower in the well. We would like to utilize the same sundry approval and include these operations in the report of sundry well operations farm 1d-40,4. Please let us know if you are agreeable to utilizing the same sundry for these operations. Stan Porholag Drilling Engineer MidContinerit/Alaska Business Unit Chevron North America E~loration and Production 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tel 907 263 7640 Fax 907 263 7884 Cell 907 2291769 stan.porhola~chevron.com 9/10/2009 • • ....~ ,~ _~ .~ 0..... „~~ ~_ .~ ...~. ..LL, . ~ ~~~ ~ ~ ~ "~ ' ~,~~ ~ r ~ ~' : ~ ~~" ~e~~~ ~ ~ ~ SEAN PARNELL, GOVERNOR ~ ~1 ~-r-7~~ ~~ tu~i~ Vrn--7 ~ 333 W. 7th AVENUE, SUITE 100 C0~5'iti RQAii~l` COr~IIS'~7'I~~ ANCHORAGE, ALASKA 9950135 , PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. Timothy C. Brandenburg Drilling Manager Union Oil company of California ,;~~ P.O. Box 196247 h~ '(~~ Anchorage, AK 99516 (~ V ~ ~ Re: Swanson River Field, Hemlock Oil, Swanson R'rver Unit 21A-34 Sundry Number: 309-248 F r~~, x~"'~~~~-~'` ~~ ,i; `.' '°~ ~l~u ~ DearMr. Brandenburg: ~~~'`~`°"'" `~~~` ~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this Ietter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair ~ DATED this 2~ day of July, 2009 Encl. yo~ 1~ ~~ti STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI~ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~~~~I~~~~~~~ ~UL. ~ ~, ?Q09 ~~~~f 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ~ Other ~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ` ~~~~~~~ Run 3-1/2" x ~ Change approved program ^ Pull Tubing ~^ - Perforate New Pool ^ Re-enter Suspended Weil ^ 2-3/8" completion 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development Q_ Exploratory ~ 190-059 ~ 3. Address: Stratigraphic ~ Service ~ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-10171-01 - 7. If perforati~g, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Swanson River Unit 21A-34 ' 9. Property Designation: 10. KB Etevation (ft): 11. Field/Pool(s): FEDA028406 [Swanson River Unit] 25.85' Swanson River / Hemlock Oil 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11,160 10,859 11,050 10,764 10,191 (PX plug) N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 33' 22" 33' 33' Surface 3,030' 11-3/4" 3,030' 3,029' 3,070 psi 1,510 psi Intermediate 8,575' 7" 8,575' 8,571' 6,340 psi 3,830 psi Production 2,599' 5" 10,835' 10,578' 10,140 psi 10,490 psi Liner 883' 2-7/8" 11,159' 10,858' 10,570 psi 11,160 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,918'-10,960' & 10,966'-10,994' 10,918'-10,960' & 10,966'-10,994' 2-7/8" x 2-3/8" 6.5# N-80 & 4.7# N-80 10,223 Packers and SSSV Type: Packers and SSSV MD (ft): HES BWD Permanent Packer & Baker DB Packer / N/A 9,057' & 10,169' / N/A 13. Attachments: Description Summary of Proposal Q 14. Weli Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development Q- Service ^ 15. Estimated Date for 8/1/2009 16. Well Status after proposed work: Commencing Operations: Oil ^~ - Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola 263-7640 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~ ~ e 276-7600 Date 7/20/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: V~~ ~-1/ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Ciearance ^ Other: ~ g S{ ~Q P~ '{'O ;00 O~ 5,,, • ~er Zo ~414C. ZS. 2Q5 Ck~ ~ a~"~~~c ~o j~~ i5 a.~proYr~ . Subsequent Form Required: ~ ~" 40 ~... APPROVED BY Approved COMMISSIONER THE COMMISSION Date: ~ l Z~ f 1 Form 10-403 Revised 06/2006 O R~~„7 ~ N~ E„~ ,. ~ ~ !;J ~~ (j ~~~g Submit in Duplicate Chevron ~ ~ Swanson River Unit ~ Well # SRU 21A-34 ~ 7/17/09 OBJECTIVE: • Pu112-3/8" x 2-7/8" tubing & rerun 2-3/8" x 3-1/2" completion. PROCEDURE SUMMARY: 1 R/U Slickline. Pressure test lubricator 250psi low/2,SOOpsi high. 2 Pull tubing patch at 6,350'. 3 Attempt to fish PX plug at 10,190'. 4 Shift XA Sliding Sleeve open at 8,989'. R/D Slickline. 5 MI/RU Key Energy Rig #3. 6 N/D Tree. N/U and Test BOPE 250/3,000 psi. ~ 7 Circulate fresh water down tubing and annulus for well kill. Flow check well. 8 R/t1 and pull 2-3/8" x 2-7/8" tubing and seal assembly above packer at 9,057'. 9 RIH w/ seal assembly, 2-3/8" 4.6# L-80 x 3-1/2" 9.2# L-80 tubing, with GLM's. 10 Land out, N/D BOP, N/U Tree. 11 R/D and Demobe rig. Turn well over to production. SRU 21A-34 REVISED BY: CVK 7-17-09 zz~ t 33' 1 ~isa~• , ~ ~ ~ @ ~,a3a z 3 Bottom GLM ~ ~ ~ 4 suspeded Upsidedown Mi~edout ` s: Perfed & of T~ at ~ 5 t: squeead 8,575~,639 ~ ;+' celnent frarr ' (6/7N90) 6 & :;,j B,SSOfiO r 6,60.r15 ~ ~ , _ '. (c~i vso~ a s Possibk Casing Falure ~ -9,11 T ~ o "- 2J~8" P~P 1~ N'~ 11 . topcnemical , cut at 10,153' v-- 12 14 Top d Possible liner ~ 2-7/8" liner Iapleak ~ 10,275 ~~a~s~so~ s^ ~ ~o,a~s' ~i t+z 2-~ig~ ~ ~t, TD =11,160' PBTD =11,050' Casing and Tubing ~etail Size Type WU Grade Top Btm CONN / ID Cement / Other 22" Structural Surface 33' Cemented 11-3/4" Surface 47#, J-55 Surface 3,030' 8R / 11.000" 600sxs 116# (stage 1), 1250sxs 116# sta e 2 29#, N-80 Surface 87' BT / 6.184" 23#, N-80 87' 4,794' BT / 6.366" O 16# 1 7" Surface 26#, N-80 4,794' 6,701' L8R / 6.276" sxs 1 (stage ), ~O 116# e 2 1150 t 29#, N-80 6,701' 8,514' L8R / 6.184" sxs (s ) ag 29#, P-110 8,514' 8,575' L8R / 6.184" 5" Liner 18#, N-80 8,236' 10,835' FL4S / 4.276" 90 bbl 15.8 2-7/8" Liner 6.5#, N-80 10,276' 11,159' EUE 8rd Mod / 2.441 " 10 bbl 15.6 ppg Tubing 2-7/8" Production 6.5#, N-80 Surface 9,023' Butt / 2.441" 2-3/8" Production 4.7#, N-80 9,023' 10,223' Butt /1.995" Production Strin Jewel Det ail # De th (RKB) Len th ID OD Item ~ 1,763', 2,897', 3,799', 4,546', 5,206', 5,795', 6,386' _~ 0.23' 2.44" 2-7l8" Camco GLMs 2 6,350' 60' ~.4~ ~~ AD-2 stop, 10' lower pack off, 22' spacer, 23' u er ack offs, & A-sto 3 6,949', 7,601', 8,190' ~Q z3' 2.44" 2-7/8" Camco GLMs (Bottom GLM upside-down) 4 8,236' Liner to acker 5 8,989' 2.74' 2.313" 3.75" Halliburton XA SSD 6 9,023' 1.04' 1.99" 3.25" X-Over 2-7/8" EUE B x 2-3/8" Butt 7 9,055' 9.79' 1.99" 3.25" HES Seal Assembl w/ strai ht slot locator 8 9,057' 9.36' 2.555" 3.25" HES BWD Permanent Packer w/ seal bore extension 9 9,100' 1.27' 1.875" 2-3/8" Halliburton X Ni le 10 10,150' 5.86' 1.99" 3-15/16" Tristate Overshot rotate to en a ed 11 10,157' 6.27' 1.99" 3.875" 2-3/8" GLM MERLA TMPDX S ec. Clearance 12 10,169' 3.07' Baker DB Packer w/ R Guide 8~ millout extension 13 10,188'-10,186' Tubin Punch w/ 4s f uns 8 holes total 14 10,190' FISH: PX lu 15 10,191' 1.20' 1.875" Otis X Ni le 16 10,223' .58' 1.99" Wireline Re-Ent Guide Perforation Data ZONE TOP BTM Shot Condition H-1 10,918' 10,920' 4"s f 1-11/16"'umbo ~et III 9/10/90 10,920' 10,934' 4~s f 1-11/16" ~umbo'et III 9/10/90 10,934' 10,948' 4's f 1-11/16"'umbo'et III 9/10/90 10,948' 10,960' 4 s f 1-11/16" ~umbo'et III 9/10/90 H-2 10,966' 10,980' 4~s f 1-11/16" HC 2/26/91 10,980' 10,994' 4~s f 1-11/16" HC 2/26/91 SRU 21A-34 Actual Well Schematic 1-19-94.doc Updated bv STP 7-16-09 Milled out ~ i ~ PeAed 8 - s ueezed 8,575 8,635 ~ 4 '' ~ent hm ~ ` ~sna~so~ ~ s, ~osa a • ; X 5 .i 8,605-15 r .. '. (c~iiiso~ s ~ PossibleCating ! Fail ure ~ -9, N 2 ~ Top of Possible liner ' ~~ 2-7/8" iner iap leak a 10,275 (7 d7 590) Y' ~ID 10. 835' H-1 H-2 2-7/8" ~ 17 ,159'• ~~'"" .'~~-. TD=11,160' PBTD=11,050' Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22" Structural Surface 33' Cemented 11-3/4" Surface 47#, J-55 Surface 3030' 8R / 11.000" 600sxs 116# (stage 1), 1250sxs 116# sta e 2 29#, N-80 Surface 87' BT / 6.184" 23#, N-80 87' 4,794' BT / 6.366" O 116# 1 7" Surface 26#, N-80 4,794' 6,701' L8R / 6.276" sxs (stage ), ~O e 2) 1150s s 116# (sta 29#, N-80 6,701' 8,514' L8R / 6.184" x g 29#, P-110 8,514' 8,575' L8R / 6.184" 5" Liner 18#, N-80 8,236' 10,835' FL4S / 4.276" 90 bbl 15.8 2-7/8" Liner 6.5#, N-80 10,276' 11,159' EUE 8rd Mod / 2.441 " 10 bbl 15.6 ppg Tubing 3-1/2" Prod 9.2#, L-80 Surface 8,000' TC-II / 2.992" 2-3/8" Prod 4.6#, L-80 8,000' 9,057' TC-II /1.995" Production Strin Jewel Det ail # De th RKB Len th ID OD Item ~ 3,550', 5,200', 6,700', 7,900' 10.00' 2.44" 3-1/2" SFO-1 GLMs 2 8,000' 2.00' 1.99" 3.25" X-Over 3-1/2° TC-II B x 2-3/8" TC-II P 3 8,236' Liner to acker 4 9,030' 10.00' 2.44" 2-3/8" BST GLMAX-1 SC GLMs 5 9,050' 2.00' 2.313" 2-3/8" Halliburton X Ni le 6 9,057' 2.01' 2.555" 3.96" HES BWD Permanent Packer 7 9,100' 1.27' 1.875" 2-3/8" Halliburton X Ni le 8 10,150' S.86' 1.99" 3-15/16" Tristate Overshot 9 10,157' 6.27' 1.99" 2-3/8" GLM 10 10,169' 3.07' Baker DB Packer w/ R Guide & millout extension 11 10,188'-10,186' Tubin Punch w/ 4s f uns 8 holes total 12 10,191' 1.20' 1.875" Otis X Ni le 13 10,223' .58' 1.99" Wireline Re-Ent Guide Pertoration Data ZONE TOP BTM Shot Condition H-1 10,918' 10,920' 4's f 1-11/16" 'umbo ~et III 9/10/90 10,920' 10,934' 4~s f 1-11/16" umbo et III 9/10/90 10,934' 10,948' 4~s f 1-11/16" umbo et III 9/10/90 10,948' 10,960' 4~s f 1-11/16" umbo ~et III 9/10/90 H-2 10,966' 10,980' 4~s f 1-11/16" HC 2/26/91 10,980' 10,994' 4~s f 1-11/16" HC 2/26/91 SRU 21A-34 Proaosed Well Schematic 7-20-09 doc Updated bv STP 7-20-09 Chevron • BOPE Diagram ~ SRU 21A-34 Workover - ~ 07/20/2009 nular preventer, Sha 7 1/16 5M Flanged 2.58' I haffer Chasovoy 7 1l16 5 Pipe Ram 7.16' 1.00~ stdd X 7 115M stdd ~ O Mud Cross, 7 1/16 5M FE X 7 1/16 5M FE w! 2 1/16 5M -- X 3 1/8 5M EFO Kill line 2 1/16 5M Choke line 2 1/16 5M 1.83' ~ ' `~ 00 00 Unibolt I ~ DSA Unibolt 3 1/8 5M X 2 1/1 ~ • S R U 21 A-34 rrom ~noKe 1", 5M, Unibolt, Nose rrom LnoKe Line Line Side of Drilling Spool ~ ~ ~?~ d~r~~ • . Chevron Timothy C Brandenburg Union Oil Company of California ~ Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 ~ Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com ~uiy 2~, 2oos ~~~~I~~~ ~u~ ~ ~ z~o~ Commissioner ~Iaska (lil & Cas C~ns. Cummis~i~r~ Alaska Oil & Gas Conservation Commission An~hara~c~ 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Swanson River Workover Program Variance Request for SRU 21A-34 Dear Commissioner, UOCC is requesting a variance of 20 AAC 25.285 (c) (9) and (10) for well service work in the Swanson River Field, for SRU 21A-34. UOCC is currently performing well intervention work with a"well servicing unit" provided by Key Energy. Key Energy mobilized the workover unit here from the Rocky Mountain area. After reviewing the BOPE rig up and equipment as used in UOCC's last Swanson River workover campaign in 2004, we feel that the proposed system is fit for purpose in well control capabilities and mobility to other BOPE configurations for this well service work. This variance request was granted for the KGSF #1 workover on Sundry Number 309-221, and was successfully utilized on this well intervention. As in this same configuration successfully used in 2004, UOCC is asking for a variance of the kill line and choke line configuration and the choke manifold equipment requirements. We consider the application of this and all BOP configurations to be a well bore specific concern and do not intend or desire to consider this as an area wide or unilaterally applied configuration. UOCC appreciates your consideration of this proposal and looks forward to discussing any questions with the proposed configuration as needed. Attached is a brief description of the well to be worked on, and the proposed BOP configuration and schematic. Please let us know if we can provide any further information by contacting myself at 263- 7657 or Evan Harness at 263-7932. Sincerely, .. ~ ~c. Timothy . randenburg Drilling Manager Attachments: Summary of Swanson River Workover Program, BOP diagram, Choke diagram Union Oil Company of California / A Chevron Company Chevron ~ • ~ ~ Summarv of Kev Enerqv Riq #3 Specifics SRU 21A-34 Workover The SRU 21A-34 workover is to pull the existing tubing string above the upper packer and run a new tubing string. The rig specifics are for the planned rig up on this well and are likely to change from well to welL Proposed Confipuration Rig Model The rig model is a Hopper Hydra-hoist, Back-model GXXTA. Drawworks The drawworks are GXXTA-MD 10x42; w/ Sand Drum 15,000 ft- 9/16" sand line. Derrick The derrick is a telescoping double, with 260,000 Ib capacity, 30" crown sheaves and McKissick 30" 150 ton 73A traveling block. Pipe Handling The pipe handling system is a HydraWalk-hydraulic catwalk, 38' long, 5' wide, 5' high. The base beam is internally guided and load bearing. The beam is load rated with 102' derrick and 10,000 of 2- 7/8" tubing to 58 mph winds. BOP Specifications Annular, 5M 7-1/16" Shaffer Single gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram Double gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram and blind ram Mud Cross, 5M, 7-1/16" BOP Diagram See attached. Accumulator 140 gallon KOOMEY Accumulator System. Includes 5 functions with manual bypass and remote panel. Fourteen 11 gallon accumulators with four 11 Gallon Nitrogen Bottles for backup. 210 gallon hydraulic tank with air operated hydraulic pump. Pits The pit consists of a 200 bbl tank partitioned into three isolatable compartments. An optional shale shaker is also available that is a 3'x4' Jr. Standard-hydraulic driven. Pump The pump is a National JWS-400 7"x4.5" Triplex rated to 5,000 psi on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line '~ ~ - ~ The Kill Line/Circulating Line consists of 2", 5,000 psi hose with Unibolt/Hub-~trange nnectors. ~ Key Energy Rig #3 Specs (SRU 21A 34).doc 7/27/09 Chevron ~ • ~ ~ Kill Line Valves The kill line valves consist of 2 ea. manually operated, 2-1/16", 5M valves attached to the mud cross with co-flex hose with a Unibolt/Hub-flanged connectors. Choke Line The choke line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. ~l Choke Line Valves The choke line valves consist of 1 ea. manually operated, 2-1/16" 5M valve and 1 ea. automatically operated HCR valve that is attached to the mud cross with co-flex hose with a Unibolt/Hub-flanged connectors. Choke Manifold See attached. Choke Return Line/Diffuser Line The diffuser line will consist of 2", 5,000 psi hose with Unibolt connections. The line will run from the choke manifold to the diffuser tank. Diffuser Tank A diffuser tank will be placed adjacent to the mud pits with the capability of fluid transfer to the circulating system. Gas Detection There is a single gas LEL monitor and a single H2S monitor be placed at the work platform; and a single gas LEL monitor and a single H2S monitor at the shale shaker if used. PVT There is no PVT system for the circulation system on this workover rig, as is standard practice in this type of well service work. Key Energy Rig #3 Specs (SRU 21A 34).doc 7/27/09 ~ • thevron ~ ~ Summarv of Swanson River Workover Pros~ram Weil Work Inventorv 1 ea. Gas Re-completions (Tyonek) Plan is to change the tubing string in a gas storage well from 2- 3/8H ta 3-1/2" tubing to increase deliverability. (KGSF #1) 3 ea. Oil Re-completions (Hemlock Oil) Plan is to recomplete Hemlock with optimized gas lift designs. (SCU 12A-04, SRU 21A-34, SRU 21-27) 1 ea. Rod Pump Repair / Re-completion (Hemlock Oil) Plan to retrieve rods, pull and replace tubing and change out pump. (SCU 33-33) Additional potential for several wells to P8A Hemlock horizons. Reservoir The planned recompletion of the gas storage well will be after the storage well is "full", with a maximum BHP of 3300 psi Qa 6,388' ND (Tyonek}. Fully evacuated, the MASP would be as fo[lows: 330U psi BHP -(6,388' ND x.1psi/ft Gas Gradient) = 2,661psi MASP. ~ The highest BHP of the oil wells to be worked on at this time is 3120 psi ~ 10,9s4' ND (Hemlock) which is equivalent to a.272 psifft gradient. Fully evacuated, the MASP would be as follows: 3120 psi BHP -(10,994' TVD x.1psi/ft Gas Gradient) ~ 2,020pai MASP. i A 3,000 psi BOPE configuration is sufficient for all planned well work. ~ Proaosed Conftuuration BOP's ~ Annular, 5M 7-1/'!6" Hydril or 11" Shaffer Double gate, 5M, 7-1/16" Hydril or 11" Shaffer Mud Cross, 7-1/16" and 11a (optional based on BOP height) Accumulator 140 gallon KOOMEY Accumulator System. 5 functions with manual bypass and remote panel. Fourteen 11 gallan accumulators with four 11 Gallon Nitrogen Bottles for backup. 210 gallon hydraulic tank with air operated hydraulic pump. Pits The pi# consists of a 200 bbl tank partitioned into three isolatable compartments. Pump The pump is a National JWS-400 Triplex on an independent skid. The pump will pull fluid directly from the pit. The discharge will !~ plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line will cansist of 2", 5~0 psi Iron or 2", 5000 psi hoses with integral Fig 1502 Unions. ~ Chevron ~ ~ ~ Kil{ line Valves The kill line valves will consist of, at a minimum, 2 ea. manuaily operated, 2-1/16", 5M valves attached to either the mud cross or the tubing spool annulus valve. Choke Line Valves The choke line valves will consist of, at a minimum, 2 ea. r1~5nu operated, 2-1/16" 5M valves that will be attached to either the outlet below the lower rams on t ouble gate or the mud cross. Choke Line The choke line will consist of 5,000 psi hoses with integral Fig 1502 Unions. ~ Choke Manifold --, ~ The choke manifold is 3-1/8", 5M witl~twg manua~ chokes and five valves. There are two valves upstream of each choke. Choke Retum Line/Gas Buster Line The gas buster line will consist of 2", 5000 psi hose with integral Fig 1502 Unions: The line will run from the choke manifold to the gas buster. Gas Buster A free standing gas buster will be placed adjaoent to the mud pits. Gas Detection We are proposing that a single gas LEI. monitor and a single H2S monitor be placed at the work , platform; and a single gas LEL monitor and a single H2S monitor be placed at the shale shaker (if s): PVT We are p~opasing to work with-out a PVT system as the circulation system on this workover rig, as is standard practice in this type of well service work. THE MATER/AL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27 2000 E P M C:LORIkMFILM.~ L A T T E R IA L HIS MA R E W UNDER K E R ,, STATE OF ALASKA ~ ALA,' . OIL AND GAS CONSERVATION COMM. ON REPORT OF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown __ Stimulate Pull tubing X_ 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 655' FNL, 1977' FWL, Sec. 34, T8N, R9W, SM At top of productive interval 1057' West and 440' Southof surface At effective depth 1172' West and 456' South of surface At total depth 1172' West and 456' South of surface __ Plugging _ _ Perforate ~ Repair well Pull tubing Other 5. Type of Well: Development X Exploratory __ Stratigraphic__ Service ---- 6. Datum elevation (DF or KB) 154' KB 134' GL 7. Unit or Property name Swanson River Unit feet 8. Well number SRU 21A-34 9. Permit number/approval number 90 -59/93 -320 10. APl number 50-133-10171-01 11. Field/Pool Swanson River-Hemlock 12. Present well condition summary Total depth: measured true vertical 11,160' 10,860' feet feet Plugs (measured) Effective depth: measured 11,094' true vertical 10,801' Casing Length Size Structural Conductor 33' 22" Surface 3030' 11-3/4" Intermediate 8583' 7" Production 2599' 5" Liner 883' 2-7/8" feet feet Junk(measured)ORIGINAL Cemented Measured depth True vertical depth 33' 33' 1850 sx class "G" 3030' 3030' 1850 sx Class "G" 8583' 8583' 500 sx class "G" 8236'-10835' 8236'-10582' 48 sx class "G" 10276'- 11159' 10125'- 10862' Perforation depth: measured 10918'-10960'; 1 o966'-10994' true vertical 10649'- 10685'; 10691 '- 10715' Tubing (size, grade, and measured depth) See Schematic Packers and SSSV (type and measured depth) See Schematic 13. Stimulation or cement squeeze summary Intervals teated (measured) None Treatment description including volumes used and final pressure None Gas Cons. commission Anchorage 14, Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water- Bbl Casing Pressure Tubing Pressure Prior to well operation 231 443 1416 1650 Subsequent to operation 320 182 1960 2250 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations x_ 78O 57O 16. Status of well classification as: Oil x__ Gas __ Suspended _ _ Service 17. I here~ c~)tify, t,_l~he{~r~o~~tr~e and correct to the best of my knowledge. Signed G. Russell Schmidt Title Drillinq Manager Form 10-404 Rev 06/15/88 Date 04/04/94 SUBMIT IN DUPLICATE~., SWANSON RIVER FIELD SRU 2fA-$4 ACTUAL 3/10/94 GAS LIFT MANDRELS AS DETAILED TOP OF LINER @8236' 6.5# N-80 BT TBG (290 JTS) ?" @8583' TBG PUNCHED {s HOL S) TBG FISH: "PX" PLUG IN "X" NIPPL~ @10,191' 2 7/8" TOP OF LINER ~10,~76' 5" ~18 N-80 LINER ~10,835' PERFS FROM PERFS FROM 10,966-10,994' 8 O 10 11 12 13 14 1§ 16 17 1) HES "XA" SSD @8989' 2) 2 7IS" 6.5# N-80 BT @8992' (1 JT) 3) 2 3/8" 4.7# N-80 BT @9023' (1 JT) 4) HES "BWD" PERM. PER W/SEALBORE EXT @9057' 5) 2 3/8" 4.7# N-80 BT @9067' 6) HES "X" NIPPLE @9100' 7) 2 3/8" 4.7# N-80 BT TBG (34 JTS) 8) TRISTATE OVERSHOT W/PACKOFF 0 10,150-155' 9) 2 3/8" 4.7# N-SO CHEMICAL CUT PUP 010,153" 10) GLM @ 10,157' 11) 6'2 3/8" 4.7// PUP @10,163' 12) BAKER "DB" PKR @10,169' W/MILLOUT EXT. 13) 6'2 3/8" 4.7// PUP @10,179' 14) 6'2 3/8' 4.7~ PUP 010,185' 15) OTIS "~' NIPPLE ~10,191' 16) 2 3/~ 4.7~ EUE A.B. MOD TBU ~10,192' (1 JT) 17) WIREUNE RE-ENTRY GUIDE RECEIVED Afaska Oil & Gas Cons. Commission Anchorage ETD @ 11,094' 2 7/8" 6.6# N-80 LINER @ 11,159' TD @ 11,160' SCU 21A-34 DAY 1 (12/28/93) RIH W/"PX" PLUG ON SLICKLINE & SET IN "X" NIPPLE @ 10,191'. RIG UP NORDIC RIG 5 ON WELL. FILTER LEASE WATER AND MIX 3% KCL. CIRCULATE WELL TO 3% KCL @ 8.7 PPG. REMOVE X-MAS TREE AND INSTALL BOPE. DAY 3-6 (12/30-01/02/94) RAN 1-11/16" CHEM CU1-FER. UNABLE TO PASS 8708'. RAN 1-11/16" SWEDGE-UNABLE TO PASS 8708'. SLICKLINE MADE REPEATED RUNS: 1-3/4" LIB AND 1.8" GAUGE RING BOTH PASSED 8708' OK. RAN IN TO 10208'. RAN 1.75" BROACH TOOL AND WORKED TIGHT SPOT AT 8708'. ATTEMPED TO RE- RUN CHEM CUTTER. UNABLE TO PASS 8708'. CUT 2-3/8" TBG AT 8693'. POOH. CHECK FOR NORMS-OK. P/U 4-1/8" OVERSHOT ON 17 JTS, 2-7/8" TBG AND RIH ON 3-1/2" DRILLPIPE. ENGAGED TOP OF 2-3/8" TBG @ 8693'. SLICKLINE RESET 1" GLV IN MANDREL @ 8993'-3 RUNS. PERFORATE 2-3/8" TBG W/4 SHOTS @ 10,063'. A~-FEMPT TO CIRCULATE TO CLEAR 2-3/8" X 5" ANNULUS. NO SUCCESS. RAN FREE-PT LOG-INDICATED 2-3/8" STUCK BELOW 9510'. RAN 1-13/16" JET CUTTER AND CUT 2-3/8" TBG @ 9484'. CIRCULATE OUT OLD DRILLING MUD AND SAND PLUS GAS. POH AND LAYED DOWN FISH. RIH W/OVERSHOT. DAY 7 (01/03/94) RIH W/4-1/8" OVERSHOT. AND 8980'. COULD NOT OVERSHOT BENT INWARD. MILL. WORK THROUGH TIGHT SPOTS AT 8747', 8762' PASS 9112'. POOH FOUND LIP GUIDE ON M/U 3-3/4" FLAT BOTTOM MILL & 4-1/8" STRING DAY 8 (01/04/94) RIH 3-3/4" FLAT BOTTOM MILL & 4-1/8" STRING MILL. WORK TIGHT SPOTS FROM 8719' TO 9160'. RIH TO TOF AT 9467'. CBU. POOH. DAY 9 (01/05/94) POOH. RIH AND DRESSED FISH AT 9467'. ATTEMPT TO CIRC THROUGH PERFS AT 10,063', NEG. RIH AND CHEMICAL CUT TBG AT 9859'. POOH W/FISH. RECEIVED & Gas Cons. Commission Anchorage DAY 10 (01/06/94) POOH. RECOVERED 373' OF TUBING. RIH W/OVERSHOT LATCH FISH AT 9859'. R/U COIL TUBING UNIT TO WASH FILL FROM INSIDE TUBING STRING. DISPLACE COIL TUBING W/HOT BRINE. COIL TUBING FROZE 2 BBLS SHORT OF DISPLACEMENT. (NOTE NEW REEL OF PIPE W/O FLUID IN IT). TEMP -5° AND WINDY. DAY 11-13 (01/07-09/94) THAW COIL TUBING UNIT. WASH FILL FROM 9945' TO 10047', COULD NOT PASS JUNK AT THIS POINT. POOH W/COIL TUBING. R/U SLICKLINE FISH SMALL PIECES OF METAL FROM WELL. RIH W/1-1/2" COIL TUBING WASH, 10057' TO 10100' CIRCULATE THROUGH PERFS AT 10063'. CONTINUE WASHING W/COIL TUBING 10180' (CTD). POOH. RIH W/CHEM CUTTER COULD NOT PASS GL MANDREL AT 10174'. CUT TUBING AT 10170'. CIRCULATE OUT SAND. DAY 14 (01/10/94) POOH W/FISH. RECOVER 314" TUBING TO CUT AT 10174'. TEST BOP'S. RIH W/3-3/8". OVERSHOT DRESSED W/2-3/8" GRAPPLE. DAY 15 (01/11/94) RIG SHUT DOWN FOR REPAIRS, REPAIRING BRAKE COOLING SYSTEM. DAY 16 (01/12/94) RIG SHUT DOWN FOR REPAIRS, REPAIRING BRAKE COOLING SYSTEM FOR 19 HRS. CONT. RIH W/OVERSHOT. DAY 17 (01/13/94) RIH W/O.S. LATCH FISH AT 10151' DPM A~-TEMPT TO ROTATE FREE W/O SUCCESS. RELEASE O.S. POOH. RIH W/MILL SCRAPPER ASSY. DAY 18-20 (01/14-16/94) SET DOWN AT 9112'. REAM BAD SPOT IN CASING. RIH TO TOF AT 10,172'. CBU. TEST CASING TO 2500 PSI. POOH. TIGHT AT 9112' (40-50 K OVER). POOH. RIH W/OVERSHOT/PACK OFF ON 5" OTIS PACKER. LATCH TUBING STUB SET PACKER AT 9057' TEST TO 2500 PSI. RECEIVED At:;!R 1 1 t97,'~. Anchorage DAY 21 (01/17/94) POOH W/SETTING TOOL. RIH W/COMPLETION. COULD NOT PASS 8325'. POOH W/TUBING. DAY 22 (01/18/94) POOH FOUND 2-3/8" GAS LIFT MANDREL MARKED, TOO CLOSE OF TOLERANCE FOR 5" LINER. WAIT 7 HRS OBTAIN 2-7/8" X A SLEEVE TO RUN IN PLACE OF MANDREL. RIH W/COMPLETION. DAY 23 (01/19/94) PIN. SPACE OUT & LAND COMPLETION. LANDED SEALS. TESTED TBG TO 500 PSI. SPACED OUT TBG. LANDED HANGER. LOCKED DOWN HANGER. P TESTED TBG TO 1500 PSI AND ANNULUS FOR 1000 PSI, OK. NIPPLED DOWN BOPS. NU WELLHEAD. RIG OUT RIG. DAY 24-25 (01/01/94-02/01/94) R/U COIL TUBING CLEAN OUT WELL TO PLUG AT 10192'. RIH W/WL ATTEMPT TO RETRIEVE PRONG IN PLUG AT X PROFILE AT 10192' OBSTRUCTION/FILL IN MILL OUT EXTENSTION. DAY 27 (02/02/94) WITH SLICKLINE MADE SEVERAL BAILER RUNS. CLEAN OUT WELL FROM 10151' TO 10158'. DAY 28 (02/03/94) RU CTU. CLEANOUT FILL F/10,167'-10,190'. RD CTU. RU SLICKLINE & RIH W/LIB. SET DOWN @ 10,165' 0NLM). APPEARS TO BE LARGE PIECE OF METAL ON "PX" PLUG. DAY 29 (02/04/94) RIH W/1.75" SAMPLE BAILER TO 10,165'. RD SLICKLINE. DAY 30 (02/05/94) RIH W/PERF GUNS & PUNCH TBG F/10,188'-10,186' @ 4 SPF (8 HOLES). RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon __ Suspend __ Operations shutdown__ Re-enter suspended well__ Alter casing__ Repair well __ Plugging Time extension Stimulate Change approved program __ Pull tubing X variance__ Perforate_ Other__ ,~/~', 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) , 4o Union Oil Company of Califomia- dba Unocal Address P.O. Box 196247 Anchorage, Alaska 99519-6247 Location of well at surface 655' FNL, 1,977' FWL, Section 34, T8N, R9W, SM At top of productive interval 1,057' West and 440' South of Surface At effective depth 1,172' West and 456' South of Surface At total depth 1,172' West and 456' South of Surface Development X Exploratory __ Stratigraphic __ Service 154' K.B. 134' G.L. feet 7. Unit or Property name Swanson River Unit 8. Well number SRU 21A-34 9. Permit number 10. APl number 50-133-10171-01 11. Reid/Pool Swanson River-Hemlock 12. Present well condition summary Total depth: measured true vertical 11,160' 10,860' feet Plugs (measured) feet Effective depth: measured 11,094' true vertical 10,801 feet Junk (measured) feet Casing Length Structural Conductor 33' Surface 3,030' Intermediate 8,583' Production 2,599' Uner 883' Perforation depth: measured true vertical Size Cemented 22' Cemented 11-3/4' 1,850 SX ClassG 7' 1,850 SX Class G 5' 500 SX Class G 2-7/8' 48 SX Class G 10,918'-10,960'& 10,966'-10,994' 10,649'-10,685'& 10,691'-10,715' Tubing (size, grade, and measured depth) See Schematic Packers and SSSV (type and measured depth) See Schematic Measured depth True vertical depth 3,030' 3,030' 8,583' 8,583' 8,236'-10,835' 8,236'- 10,582' 10,276'-11,159' 10,125'-10,862' RECEIVED [.~OV 1 8 133~ Oil & G-~s Cons. Commission Anchorage 13. Attachments Description summary of proposal X__ Detailed operations program__ BOP sketch X__ 14. Estimated date for commencing operation 115. December 20, 1993 16. If proposal was verbally approved Oil X__ Gas __ Name of approver Date approved Service 7. I her(~ ce~fy that/t~for~goi/ing it.!/ru,)?~md correct to_the best of my knowledge. FOR COMMISSION USE ONLY Status of well classification as: Suspended__ Conditions of approval: Notify 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 Original Signed By David W. Johnston I Appr°~,~ .-- ,~' ~_.~ .r~pproved Copy Returned Commissioner Date '~//"~- ~/~' ~' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ® e ® e ® ® e ® ® Swanson River Field SRU 21A-34 Workover Procedure IIII-'11 Rig up electric line, perforate at 10,150' In,aH BPV. Move in and rig up workover rig. Kill well. Nipple down tree and nipple up B.O.P. Test B.O.P. to 5,000 psi. Release snap latch and POOH with tubing. RIH with completion string Pressure test tubing/casing annulus to 1,500 psi. ln~all BPV; nipple down B.O.P. Nipple up tree; pressure test to 5,000 psi. Release Rig. RECEIVED & Gas Cons. Commission Anchorage 11-3/4" @ 3030' TOP OF 5" LINER @ 8236' 7" #23/26/29 N-80 @ 8583' SWANSON RIVER FIELD WELL # 21A-34 PROPOSED 11/16/93 II I II 2-7/8" 6.4# TUBING TO 8200' GAS LIFT MANDRELS AS SPECIFIED CROSSOVER 2-7/8" x 2-3/8" AT 8200' GAS LIFT MANDRELS AS SPECIFIED BAKER 2 3/8" SEAL ASSEMBLY BAKER 10' PBR Anchored to DB PACKER BAKER DB PACKER AT 10,172' 2-7/8" UNER TOP AT 10,276' OTIS "X" NIPPLE AT 10,192' 2-3/8" TUBING TAIL AT 10,225' 5" # 18 N-80 LINER @ 10,835' ETD AT 11,094' 2'7/8" 6.5# N,80 UNER AT 11,159' PERFORATIONS FROM 10, g 18'- 10,960' PERFORATIONS FROM 10,966'- 10,994' RECEIVED TD AT 11,160' 0il & Gas Cons. Commission Anchorage Arc Alaska Inc.- Swanson Riv Well- SRU 21A-34 APl#: 50-133-10171-01 Spud Date' 3/63 ST 8/90 Completion Date: 9/90 Original RKB' 26' Hanger Type: Schaffer Top of Hemlock:lO918' MD Max. Hole Angle' 36° 'Field Well Type: Producer Last Workover- 8/90 Hanger: Schaffer Angle @ Hemlock' 30° All Depths are RKB MD to Top of Equipment. Jewelry I 28.53' 2 3975' 3 7005' 4 8194' 5 8993' 6 10,163' 7 10,169' 8 10,172' 10,178' 10,179' 9 10,192' 10 10,224' 11 10,225' 2-7/8" Extended Neck TBG Hanger GLM 2 7/8"X1" Merla TPD w/DV & Type BK-2 Latch GLM 2 7/8"X1" Merla TPD w/Mod. DV & BK-2 Latch (leaking) X-Over 2-7/8" X 2-3/8" GLM 2-3/8" X 1" Merla TMPDX w/1/4" Orifice GLM 2-3/8" X 1" Merla TMPDX w/DV (GLM is upside down) Baker "E" Seal Nipple W/Anchor (74,0008) & X-O 2-7/8" X 2-3/8" Baker "DB" Packer W/Type "B" Guide 3-1/2" NU Millout extention W/3-1/2" NU 10 Rd Pin X Pin 3.50" X 2.992" ID X-Over 3-1/2" NU 10 Rd Box X 2-3/8" Otis "X" Nipple 2-3/8" 1.875" ID 2-3/8" Wireline Re-Entry Guide (2.00"I.D.) Tubing Tail Minimum ID: 1.875"(~ 10.192' ~ Otis "X" NiDole 2 3/8"1 _ . 7,8 9 10,11 Casing and Tubing Size Weight Grade ~ Bottom Descriotion 22" 13 -3/4" 7" # 2-7/8" 0 33' Conductor Pipe 0 3030' Suface Casing 29# N-80 0 47' Production Casing 23# N-80 47' 4794' 26# N-80 4794' 6701' 29# N-80 6701' 8513' 29# N-80 8513' 8583' 18# N-80 8236' 10,835' Liner (FL4S) 6.5# N-80 10,276' 11,159' Liner 2-7/8" 6.5# N-80 0 8194' Tubing 2-3/8" 4.7# N-80 8194' 10,224' Tubing H1 H2 Perforation Data Interval Zone FT SPF 10,918'-10,960' H1 42' 4 10,966'-10,994' H2 28' 4/5 PBTD = 11,094' TD -- 11,160' 9/10/90 , ,,RECEIVED ;,": !.:.r~ (iii & G~:t$ Cons. Commission Anchorage Well SRU 21A-34 By: JLB 1/24/92 Rev. Con[fao[ Exhibi[ E OPTION I FILL-UP KILL LINE ANNULAR BOP 10" 3000 psi PIPE RAMS 10" 5000 psi BLIND RAMS 10" 5000 psi FLOW t ~ / DRILLING ] []~ SPOOL ~ h[~'~~O'' $000 5000 psi I II 3" 5000 psi PIPE RAMS ] 10" 5000 psi 1 CHOKE LINE ==~ BOP STACK 10" 5000 psi 6,:~s Cons. C3mmission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering July 28, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Subsequent Report for SRU 21A-34. Dear Mr. Smith: In March of 1992 ARCO Alaska, Inc. proposed to reperforate the HI sands (10918'-10960), on SRU 21A-34 (approval No. 92-051) at our Swanson River Field. This is to notify you that the job was canceled. Due to tubing restrictions the desired interval could not be reached. If you require any further information in this regard, please call Jim Zernell at 263-4107. Sincerely, Acting Regional Engineer JCW:DRH:jlg: 0168 Attachment CC: Mr. L. R. Dartez Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED JUL 2 9 ~,~92 Alaska Oil & Gas CoIls. commission Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS OR GINAL 1. Type of Request: Operation Shutdown ~ Stimulate Plugging ~ Perforate X Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 655' FNL, 1977' FWL, Sec. 34, T8N, Rgw, SM At top of productive interval 931' FNL, 963' FWL, Sec. 34, T8N, Rgw, SM At effective depth At total depth 947' FNL, 840' FWL~ Sec. 34, T8N~ Rgw~ SM 12. Present well condition summary Total Depth: measured 11,160' true vertical 10,861' 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB = 26', GL = 134' 7. Unit or Property name Soldotna Creek Unit 8. Well number SRU 21 A-34 9. Permit number/approval number -92-051/,~,.'~ ~,~.~'-~ 10. APl nurnlber 50-133-10171-01 11. Field/Pool Swanson River-Hemlock feet feet Plugs (measured) 13. Effective depth: measured 11,094' true vertical 10,805' Casing Structural Conductor 33' Surface 3030' Intermediate 8583' Production 2599' Liner 883' Perforation depth: measured Length Size feet feet Junk (measured) Cemented Measured depth 22" Driven 33' MD 11-3/4" 1850 sx Class G 3030' MD 7" 1850 sx Class G 8583' MD 5" 500 sx Class G 8236'-10835' MD 2-7/8" 48 sx Class G 10276'-11159' MD 1091 8'-10960', 10966'-10994' MD true vertical 10654'-10690', 10695'-1071 9' TVD Tubing (size, grade, and measured depth) 2-7/8" @ 81 94' MD; 2-3/8" from 8194'-10224' MD Packers and SSSV (type and measured depth) Packers: Baker 'DB' Model Packer @ 101 77' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A True vertical depth 33' TVD 3030' TVD 8583' TVD 8236'-10582' TVD 10125'-10862' TVD Alaska, Oil & Gas C0rls. ub~'~'''''~ ' 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data ........... Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure JOB CANCELED due to tubing restrictions Tubing Pressure 1 $. 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 certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Cook Inlet Regional Engineer Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering March 13, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Application for Sundry Approval SRU 21A-34 Dear Mr. Smith: ARCO Alaska, Inc. proposes to reperforate the H1 sands (10918'- 10960), on SRU 21A-34 at our Swanson River Field. Please refer to the attached submittal of the Application for Sundry Approval and the Perforating Procedures for details of this operation. If you require any further information in this regard, please do not hesitate to call Jim Zernell at 263-4107. Sincerely, Acting Regional Engineer JCW:DRH:czm:0123 Attachment CC: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED MAR 1 7' 1992 Alaska Oil & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Sub~r~ of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ORIGINAL 1. Type of Request: Abandon Alter casing _ 2. N~me of Operator Suspend_ Operation Shutdown _ Re-enter suspended well_ Repair well _ Plugging _ Time extension _ Stimulate . Change approved program _ Pull tubing _ Variance _ Perforate X Other _ 6. Datum elevation (DF or KB) 99510 ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 655' FNL, 1977' FWL, Sec. 34, T8N, Rgw SM At top of productive interval 931' FNL, 963' FWL, Sec. 34, T8N, R9W SM At effective depth 5. Type of Well: Development Exploratory Stratigraphic Alaska 0il & Gas Cons. Comr~ Anchorage At total depth 947' FNL, 840' FWL, Sec. 34, T8N, Rgw SM RKB 26'. GL 134' 7. Unit or Property name Swanson River Unit feet 8. Well number SRU 21A-34 9. Permit number 9{)-59 1{). _APl number SSi~. 1 3 3-1 01 71-01 11. Field/Pool Swanson River/Hemlock 12. Present well condition summary Total Depth: measured true vertical 11,160' feet Plugs (measured) 1 0,861' feet 13. Effective depth: measured 11,094' feet Junk (measured) true vertical 1 0,805' feet Casing Length Size Cemented Structural Conductor 3 3' 2 2" D rive n Surface 3030' 1 1-3/4" 1850 sx Class G Intermediate 8583' 7" 1850 sx Class G Production 2599' 5" 500 sx Class G Liner 883' 2-7/8" 48 sx Class G Perforation depth: measured Current: 10918'-10960' MD, 10966'-10994' MD, reperforate : 10918'-10960' true vertical Measured depth True vertical depth 33' MD 3030' MD 8583' MD 8236'-10835' MD 10276'-11159' MD 33' TVD 3030' TVD 8583' TVD 8236'-10582' TVD 10125'-10862' TVD Current: 10654'-10690' TVD, 10695'-10719' TVD, reperforate : 10654'-10690' TVD, Tubing (size, grade, and measured depth 2-7/8" @ 8194' MD; 2-3/8" from 8194'-10224' MD Packers and SSSV (type and measured depth) Packers: Baker 'DB' Model Packer ~ 10177' Attachments Description summary of proposal X Detailed operation program _ BOP sketch 14. Estimated date for commencing operation March 30. 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas _ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~-'C /,~,' ,,~ ~1. ~'."] '~LCf. C~ ~e Cook Inlet Regional En~r. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance m Mechanical Integrity Test _ Subsequent form require IApproval No. I d/~-~)-y~/ Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGli',]AL SIGNED LONI',ilE O. CF~ITI,,I Commissioner Date ~ -i ~- ? ~ SUBMIT IN TRIPLICATE Re-perf Procedure: Hold safety meeting with all personnel involved. Obtain a schematic from the wireline company of ali tools that will be run into the wellbore. . . MIRU E-line unit. Test lubricator. With well shut-in RIH with 1-11/16" hollow carrier guns and CCL and re-perforate the H- 1 from 10,918' - 10,960' with 4 SPF, 0° Phasing, oriented 60° from low side of hole Note: Because of a dogleg at ~10,920-70' tool string length must be minimized. Make multiple runs as required to perforate the desired interval. A 38' tool string was successfully run in Feb. '91. The well should be perforated on depth with the IEL-GR log dated 8/9/90 and tie in Performed via CCL-GR log dated 8/16/90. IEL {8/9/90) Footaae Zone SPF -- 10,918-960' 42' H-1 4 Berea Sandstone Perf Data for 1-11 / 16" Hollow Carrier Charges. Hole Hole Company Gun _Type Depth Dia, Schlumberger Hyperdome 4.63" 0.28" Western Arias Jumbo-Jet III 5.84" 0.24" . . . . POOH with guns and verify all shots fired. Repeat runs as necessary to complete perforating. On the last trip out of the hole run a CCL strip across the 2nd GLM at 7,005'. The strip should show several collars both above and below the GLM. This information will be used for ensuring the proper sPaceout for the tubing patch. RDMO E-line unit. Obtain post-peri well test. Well- SRU 21A-34 Spud Date- 3/63 ST 8/90 Original RKB: 26' Top of Hemlock:lO918' MD ,~ Alaska Inc.- Swanson R APl#: 50-133-10171-01 Completion Date' 9/90 Hanger Type' Schaffer Max. Hole Angle: 36° Field Well Type: Proclucer Last Workover.' 8/90 Hanger: Schaffer Angle @ Hemlock: 30° All Depths are RKB MD to Top of Equipment. Jewelry 1 28.53' 2 3975' 3 70O5' 4 8194' 5 8993' 6 10,163' 7 10,169' 8 10,172' 10,178' 10,179' 9 10,192' 10 10,224' 11 10,225' 2-7/8" Extended Neck TBG Hanger GLM 2 7/8"Xl" Merta TPD w/DV & Type BK-2 Latch GLM 2 7/8"Xl" Merla TPD w/Mod. DV & BK-2 Latch (leaking) X-Over 2-7/8" X 2-3/8" GLM 2-3/8" X 1" Merla TMPDX w/1/4" Orifice GLM 2-3/8" X 1" Merla TMPDX w/DY (GLM is upside down) Baker "E" Seal Nipple W/Anchor (74,000#) & X-O 2-7/8" X 2-3/8' Baker "DB" Packer W/Type "B" Guide 3-1/2" NU Millout extention W/3-1/2" NU 10 Rd Pin X Pin 3.50" X 2.992" ID X-Over 3-1/2" NU 10 Rd Box X 2-3/8" Otis "X" Nipple 2-3/8" 1.875" ID 2-3/8" Wireline Re-Entry Guide (2.0p;I Tubing Tail J~ IV E D 7,8 9 10,11 MAR 1 ? 1992 Minimum ID: 1.875" (~ 10.192' ( Otis "X" Ni001e 2. ,3~.,~,;a 0JJ & Gas Cons. Commission Anchorage Casing and Tubing .Size Weioht Grade ~ Bottom Deaerl~tlon 22" 13 -3/4" 7" # 2-7/8" 0 33' Conductor Pipe 0 3030' Suface Casing 29# N-80 0 47' Production Casing 23# N-80 47' 4794' 26# N-80 4794' 6701' 29# N-80 6701' 8513' 29# N-80 8513' 8583' 18# N-80 8236' 10.835' Liner (FL4S) 6.5# N-80 10,276' 11,159' Liner 2-7/8" 6.5# N-80 0 8194' Tubing 2-3/8" 4.7# N-80 8194' 10,224' Tubing H1 H2 Perforation Data Interval Zone FT SPf Date 10,918'- 10,960' H 1 42' 4 9/10/90 10,966'-10,994' H2 28' 4/5 2/26/91 PBTD = 11,094' TD = 11,160' Well SRU 21A-34 By: JLB 1/24/92 Rev. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Torn Wellrnan Regional Engineer Cook inlet Engineering March 4, 1991 Mr. L. Smith Alaska 0il and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is a subsequent report of operations for the perforating of SRU 21A-34. SRU 21A-34 was perforated in the H2 interval from 10,966' to 10,994' MD on February 26, 1990. The well is currently producing approximately 759 BOPD, 452 MCFPD and 855 BWPD. Sincerely, T. Wellman Regional Engineer TW:jkw: 0016 Attachment cc: Mr. A. R. Kukla Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED MAR - 7' 1991 AIaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown~ Stimulate Pull tubing ~ Alter casing ~ Repair well . 2. Name of Operator AR~g Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 655' FNL, 1977' FWL, Sec. 34, T8N, RgW, SM At top of productive interval 931' FNL, 963' FWL, Sec. 34, T8N, Rgw, SM At effective depth 5. Type of Well: Development ..~ Exploratory . Stratigraphic Service At total depth 947' FNL~ 840' FWL~ Sec. 34~ TSN~ R9W~ SM 12. Present well condition summary Total Depth: measured 11,160' true vertical 10,861' feet feet Plugs (measured) Plugging .~ Perforate X Pull tubing ~ Other 6. Datum elevation (DF or KB) RKB = 26'. GL = 134' feet 7. Unit or Property name Soldotna Creek Unit 8. Well number SRU 21A-~4 9. Permit number/approval number 90-5g 10. APl number so-133-10171-01 11. Field/Pool Swanson River-Hem lock Effective depth: measured 11,094' true vertical 10,805' feet feet Junk (measured) 13. Casing Structural Conductor 33' Surface 3030' Intermediate 8583' Production 2599' Liner 883' Perforation depth: measured Length Size Cemented 22" Driven 11-3/4" 1850 sx Class G 7" 1850 sx Class G 5" 500 sx Class G 2-7/8" 48 sx Class G 10918'-10960', 10966'-10994'MD truevertical 10654'-10690', 10695'-10719'TVD Tubing (size, grade, and measured depth) 2-7/8" @ 8194' MD; 2-3/8" from 8194'- 10224' MD Packers and SSSV (type and measured depth) Packers: Baker 'DB' Model Packer @ 10177' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Measured depth 33'MD 3030'MD 8583'MD 8236'-10835'MD 10276'-II159'MD True vertical depth 33'TVD 3030'TVD 8583'TVD 8236'-10582'TVD lOI25'-10862'TVD N/A RECEIVED MAR - ? t991 Alaska Oil & Gas Cons. i ommisSion ;Anchorage 14. ReDresentative Daily Averaae Production or In iection Data Oil-Bbl Gas-Mcf Water-§bi Casing Pressure Tubing Pressure Prior to well operation 331 1645 156 500 240 Subsequent to operation 759 452 855 1000 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 7OO Signed Form 10-404 Rev 06/15/88 Title Cook Inlet Regional Engineer Date m/~/~ I SUBMIT IN DUPLICATE .... FEB-2?-~91 0?:02 ID:~NSON RIUER TEL NO:~BS1 WELL ARCO Alaska, Inc. S(Jbstcll&~ of Atlantic Richfield Company i/t/ELL SERVICE REPORT DATE IDAYS PBDT FIELD. DISTRICT- STATE OPERATION AT REPORT...T~.JI.TIME /Z: zo -/~'...$0 /~: $13 - · I& :tlO- 17.', ~0 /9.'$0 .- R E C E IV E D ~*~ MAR - ? 199~ .... ,... rAnohorago [] C"ECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~-~-aiher,.,,.,,~ ITem,. . ]Chill .Factor t VIsibility I WInd Vel. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering March 4, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is an Application for Sundry Approval to perforate the H2 interval in Well SRU 21A-34. We propose to perforate 28' of the H2 sand (10,966'-10,994' MD) using 1 11 / 16" hollow carrier perforating guns @ 4 spf. The work was completed on February 26, 1991 per verbal approval from Mike Minder to Carol Baker on February 22, 1991. If you have any questions please contact Carol M. Baker at 263-4643. Sincerely, T. Wellman Regional Engineer TW:jkw:0002 Attachment cc' Mr. A. R. Kukla Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED k, AR - ? 199t Alaska 0il & Gas Cons. CommiSSiOn Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator _ Suspend_ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well Plugging_ Time extension _ Stimulate_ Change approved program __ _ Perforate X Other ._ 6. Datum elevation (DF or KB) ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 Pull tubing __ Variance 5. Type of Well: Development X_ Exploratory _ Stratigraphic _ Service _ RKB 26'. GL 1,34' 7. Unit or Property name Swanson River Unit feet 4. Location of well at surface 655' FNL, 1977' FWL, Sec. 34, T8N, Rgw SM At top of productive interval 931' FNL, 963' FWL, Sec. 34, T8N, R9W SM At effective depth At total depth 947' FNL~ 840' FWLt Sec. 34r T8N~ Rgw SM 12. Present well condition summery Total Depth: measured 11,160' true vertical 10,8 61' feet Plugs (measured) feet 8. Well number SRU 21A-34 9. Permit number 90-59 10. APl number 50-133-1 01 71-01 11. Field/Pool Swanson River/Hemlock Effective depth: measured 11,094' feet Junk (measured) true vertical 1 0,805' feet 13. Casing Length Size Structural Conductor 3 3' 2 2" Surface 3030' 1 1-3/4" Intermediate 8583' 7" Production 2599' 5" Uner 883' 2- 7/8" Perforation depth: measured Driven 1850 sx Class G 1850 sx Class G 500 sx Class G 48 sx Class G Current: 10918'-10960' MD Proposed: 10966'-10994' MD true vertical Current: 10654'-10690' TVD Proposed: 10695'-10719' TVD Tubing (size, grade, and measured depth 2-7/8" @ 8194' MD; 2-3/8" from 8194'-10224' MD Packers and SSSV (type and measured depth) Packers: Baker 'DB' Model Packer ~ 10177' Attachments ~ Measured depth 33' MD 3030' MD 8583' MD 8236'-10835' MD 10276'-11159' MD Description summary of proposal True vertical depth 33' TVD 303O' I'VD 8583' TVD 8236'-10582' TVD 10125'- 10862' TVD RECEIVED k iAR - ? t991 Alaska 0il & Gas Cons. CommJssiOtl Anchornge Detailed operation program _ BOP sketch 16. 17. Estimated date for commencing operation 15. Status of well classification as: February 26. 1991 Oil ~ Gas If proposal was verbally approved Name of approver Date approved Service __ I hereby certify that the foregoing is true and correct to the best of my knowledge. Suspended Title Cook Inlet Regional Engr. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative mey witness Plug integrity BOP Test _ Location clearance Mechanical Integrity Test _ Subsequent form require 10- ORIGINAL SIGNED BY Approved Copy Returned LONNIE O. SMITH .~_l~-..d~lo.~__, the order of the Commission Form 10-403 Rev 5/03/89 Commissioner JApproval No~_ (DT~,... I Date c:~ --'1 ~) --Ct I SUBMIT IN TRIPLICATE E-Line BOPE's Grease Head/ Hydraulic Packoff ~[a$~a .OJj.& Gas Cons. Oommission ~chorage ~ Lubdcator Extension Manual Rams Swab Valve Double Maste~ Valves -Wellhead SRU 21A-34 PERFO~TION SR ?? Objective: To add H2 perforations. Well Data: Completion: Min. Restriction: 2-7/8", 6.5#, N-80 tbg to 8193' MD, 2-3/8", 4.7#, N- 80 tbg to 10,224' MD 2-7/8"-liner from 10276' MD to 11,160' MD. 1.875" Otis 'X' Nipple at 10,192' MD NOTE: Assure that testing has been performed to assure that the current H2 perfs produce a low watercut prior to performing this work. Procedure.: Xe RIH with a 1.8" gauge ring to bottom, verify exposure of desired perf intervals. 2. SI well ~24 hours prior to perforating. 3. MIRU conductor line. Pressure test lubricator {o 4000 psi. SI well. . RIH with a perf gun and CCL. Tie-in to perf interval, starting from the bottom. (Note: Two gun runs will be needed to allow the guns to pass through the dog leg at ~ 10970'. Gun length~ should be minimized.): IEL [8/9/90) ~ Sand SPF 10966-10994' 28' MD H2 4 Hole Hole Company Gun _Type Gun Slz~ Depth* Diameter* Schlumberger Hyperdome Arias Jumbo Jet III *APl test data in Berea sandstone. 1-11/16" 4.63" .28" 1-11/16" 5.84" .24" NOTE: Gun orientation should be 60 deg off hole bottom. 5. Perforate interval. . . 8. .Repeat steps 3-6 to complete perforating. 9. RDMO. Bring well on line. POOH (going slowly until through tubing t_n!l). Check gun to confirm that all shots have fired. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering February 15, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is an Application for Sundry Approval to perforate the H2 interval in Well SRU 21A-34. We propose to perforate 18' of the H2 sand (10,966'-10,974', 10,980'- 10,986' and 10,990'- 10,994' MD) using I 11/16" hollow carrier perforating guns @ i spf. With your approval, we would like to begin this work as soon as possible. If you have any questions please contact Carol M. Baker at 263-4643. Sincerely, T. Wellman Regional Engineer TW:jkw:0044 Attachment cc: Mr. A. R. Kukla Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend__ Alter casing __ Repair well Change approved program __ Operation Shutdown __ Re-enter suspended well __ _ Plugging_ Time extension _ Stimulate_ Pull tubing __ Variance _ Perforate X Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 655' FNL, 1977' FWL, Sec. 34, T8N, Rgw SM At top of productive interval 931' FNL, 963' FWL, Sec. 34, T8N, Rgw SM At effective depth At total depth 947' FNL, 840' FWL, Sec. 34, T8N, Rgw SM 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 6. Datum elevation (DF or KB) RKB 26'. GL 134' 7. Unit or Property name Swanson River Unit 8. Well number SRU 21A-34 9. Permit number 90-59 10. APl number 50-133-10171-01 11. Field/Pool Swanson River/Hemlock feet 12. Present well condition summary Total Depth: measured true vertical 11,160' 10,861' feet Plugs (measured) feet oECEiVED 13. Effective depth: measured 11,094' feet Junk (measured) true vertical 1 0,8 0 5' feet Casing Length Size Structural Conductor 3 3' Surface 3030' Intermediate 8 5 8 3' Production 2 5 9 9' Liner 8 8 3' Perforation depth: measured Current: 10918'-10960' MD Proposed: true vertical Cemented 22" 1 1-3/4" 7" 5" 2-7/8" Driven 1850 sx Class G 1850 sx Class G 500 sx Class G 48 sx Class G 33' MD 33' MD 3030' MD 3030' TVD 8583' MD 8583' TVD 8236'-10835' MD 8236'-10582' TVD 10276'-11159' MD 10125'-10862' TVD 10966'-10974', 10980'-10986', 10990'-10994' MD Current: 10654'-10690' TVD Proposed: 10695'-10702', 10707'-10712', 10716'-10719' TVD Tubing (size, grade, and measured depth 2-7/8" @ 8194' MD; 2-3/8" from 8194'-10224' MD Packers and SSSV (type and measured depth) Packers: Baker 'DB' Model Packer @ 10177' Attachments Description summary of proposal , Detailed operation program _ BOP sketch X 14. Estimated date for commencing operation Februarv 21. 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: O, .Z.- Gas Suspended . 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Cook Inlet Regional En~r. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance __ Mechanical Integrity Test _ Subsequent form require 10- ORIGINAL SIGNED BY ~ n~F C. SMITH Approved by the order of the Commission Form 10-403 Rev 5/03/89 Date IApprov. al ~No. SUBMIT IN TRIPLICATE SRU 21A-34 PERFORATION SR 219 Objective: To add H2 perforations. Well Data: Completion: Min. Restriction: 2-7/8", 6.5#, N-80 tbg to 8193' MD, 2-3/8", 4.7#, N-80 tbg to 10,224' MD 2-7/8" liner from 10276' MD to 11,160' MD. 1.875" Otis 'X' Nipple at 10,192' MD Procedure: . RIH with a 1.8" gauge ring to bottom, verify exposure of desired perf intervals. . MIRU conductor line. Pressure test lubricator to 4000 psi. SI well. . RIH with a perf gun and CCL. Tie-in to perf interval, starting from the bottom. (Note: Two gun runs will be needed to allow the guns to pass through the dog leg at - 10970'. Gun lengths should be minimized.): IEL (8/9/90) Footage Sand SPF 10966-10974' 10980-10986' 10990-10994' 8'MD H2 1 6'MD H2 1 4'MD H2 1 Company Gun _Type Hole Hole Gun Size Depth* Diameter* Schlumberger Hyperdome Arias Jumbo Jet III 1-11/16" 4.63" 1-11/16" 5.84" .28" .24" *API test data in Berea sandstone. NOTE: Gun orientation should be 60 deg off hole bottom. 4. Perforate interval. 5. POOH (going slowly until through tubing tail). 6. Check gun to confirm that all shots have fired. 7. Repeat steps 3-6 to complete perforating. 8. RDMO. Bring well on line. E-Line BOPE's Grease Head/ Hydraulic Packoff , Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead STATE OF ALASKA AI_A'-.,A OIL AND GAS CONSERVATION COM,~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~ GAS r-~ SUSPENDED r'~ ABANDONED r-] SERVICE F'"'] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-59 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~~_ 50-133-10171-01 4 Location of well at surface~ ~ 9 Unit or Lease Name AtTop Producing Interval ~ ,,...,,~. ..... t V~,~FJc~' [ 10 Well Number 931' FNL,963' FWL,SEC 34, T8N, Rgw SM ~C~._. .............. j 5u,, SRU 21A-34 At Total Depth .................. ~-~ I~S.~ 11 Field and Pool 947' FNL, 840' FWL, SEC 34, TSN, R9W SM SWANSON RIVER FIELD , 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. HEMLOCK OIL POOL RKB 26'~ GL 134' A-028406 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Deplh, if offshore 116 No. of Completions 6/20/90. 8/9/90. 9/10/90. NA feet MSLI 1 "i7 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 11160' MD & 10861'TVD 11094' MD & 10805'TVD YES IXI NO II NONE feetUD 0' APPROX '22 Type Electric or Other Logs Run D IL/CNL/SP/GR/BHC-AL/CAL/GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22" SURF 33' 11-3/4" 47# J-55 SURF 3030' 16" 1850 SX CLASS G .... 7" 29,23,26~ N80, P110 SURF 8583' 9-5/8" 1850 SX CLASS G 5" 18# N80 8236' 10835' 6" 500 SX CLASS G 2-7/8" 6.5~ NS0 10276' 11159' 4-1/8" 48 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" X 2-3/8" 10,224' 10~177' 10,918'-10,960' MD W/1-11/16" @ 4 SPF 10654'-10690' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST , Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~- Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .RECEIVED NOV o 1990 RR 8/20/90 PERF'D 9/10/90 ,. Form 10-407 Submit in duplicate Rev. 7-1-80 C,(~TINUED ON REVERSE SIDE 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. HEMLOCK 10918" 10654' 31. LIST OF ATTACHMENTS GYRO, SUMMARY OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge { INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil a,,. Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "llflffal tl~T' On the first Wednesday after a well is spudded or workover operations are started. Daily work prtor to spuddlt~r~Should be ~mmaHzed on the form giving inclusive dates only. District ~.;~; Count. parish or b .... ARCQ A~$~ ZNQ, KENAI Field ~Lea~ or Unit I S~SO~ ~[~ ~Title A-~28406 Auth. or W.O. no. I ~6803 I DRILLING ~ CO~LETION IState AK I Well no. .~RH 211~-34 Operator IARCO W.I. ARCO ] ~_~900 SpuddedorW.O. begun IDate ]Hour Priorstai~ifaW.O. SPUD 06/20/90 11:00 Date and depth as of 8:00 a.m. 06/10/90 (1) TD: 8708' (8708) SUPV:WH 06/11/90 (2) TD: 8708' ( 0) SUPV:WH 06/12/90 (3) TD: 8708' ( 0) SUPV:WH/EB 06/13/90 ( TD: 8708'( SUPV:WH/EB 06/14/90 (5) TD: 8708'( 0) SUPV:EB 06/15/90 (6) TD: 8708'( 0) SUPV:EB Complete record for each day re~ed GRACE 154 ATT TO TEST BOPE MW: 9.2 VIS: 0 HAD GYRO'D WELL AND SET BRIDE PLUG W/ ELECTRIC LINE 6-2-90. ACCEPT RIG @ 0600 6-9-90. NU BOP STACK AND ATT TO TEST. RAM DOORS LEAKING BADLY. DAILY:S36,847 CUM:$36,847 ETD:S36,847 EFC:$1,690,000 CIRCULATE 9.2 BRINE MW: 9.2 VIS: 0 CLEAN SEAL ~%3~EA AND REPLACE SEALS ON RAM DOORS. TEST BOPE TO 250 AND 4500 PSI PU 2-7/8" TBG AND 3-1/2" DP. GIH AND TAGGED BP @ 8708' SI/ff. CIRCULATE 9.2 PPG BRINE. DAILY:S16,485 CUM:$53,332 ETD:S53,332 EFC:$1,690,000 CIRCULATING MW: 9.4 VIS: 0 CIRC WELL TO 9.2 PPG BRINE. POH. RU AWL AND ATT TO TEST PO. WO .GREASE HEAD. PERF WELL F/ 8615'-8605' AND 8560'-8550'. WELL STARTED TO PLOW. GIH W/ 10 STDS DP. BULLHEAD IN 7 BBLS. PRESSURED UP TO 3000 PSI. LET BLEED TO FORMATION AND BULLHEAD 6 ADD'L BBLS AND PRESSURE UP TO 3000 PSI. FGIH TO. 8708' CIRC AND RAISE BRINE TO 9.4 PPG. SD & MONITOR WELL 1/2 HR. NO FLOW. CIRC. DAILY:S23,318 CUM:$76,650 ETD:S76,650 EFC:$1,690,000 ~;~~~NG MW: 9.4 VIS: 0 ~ "!MZX 77 SX CMT. SPOT BAU,-WCED PLUG ACROSS ~'~~:.PF, RFS.~~ POH 6 STDS. SQUEEZED AWAY 3 BBLS CMT AT ~..~-~'woc. CIRC. POH. PU S.~. GIH TO 7058'. CIRC ~W~%~ TAGGED CMT AT 8363. DRILLED FIRM CMT TO 8709' DPM. CIRC HOLE CLEAN. DAILY:S23,954 CUM:$100,604 ETD:S100,604 EFC:$1,690,000 POH W/ SECTION MILL MW: 9.5 VIS: 82 CLEAN TANKS AND TRANSFER BRINE TO STORAGE. MIX MUD FOR SECTION MILLING. DISPLACE WELL WITH MUD. POH. PU SECTION MILL AND BHA. GIH TO 8575'. INITIATE CUT AT 8575'. MONITOR WELL. STABLE. MILL TO 8578'. MILL QUIT CUTTING. SD. HOLE FLOWING SLIGHTLY. CBU. POH W/ CORRECT FILLUP. DAILY:S26,698 CUM:$127,302 ETD:S127,302 EFC:$1,690,000 CLEANING OUT 7" CSG MW: 9.5 VIS: 84 FPOH WET. CO'SECTION MILL AND GIH. CUT SECTION F/ 8578'-8597'. MILL QUIT CUTTING. (22' TOTAL CUT.) POH. LD MILL AND PU BIT. GIH AND ATT TO CLEAN METAL CUTTINGS OUT OF 7" CSG. DAILY:S90,609 CUM:$217,911 ETD:S217,911 EFC:$1,690,000 The above is.cFqirrect Signature~ For form preparation ~ d~stribution, see Procedures Man~ection 10, Orilling, Pages 86 an~.-&~, AR3B-459-1-D It! NOV o 91990 JNumber aH daily~M~ las they are prepared for ~ach ~ell. '. ~~.~ iPage no. ARCO Oil a~,,. Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "interim" sheets until linaJ completion· Report oflicial or representative test on "Final" form. !) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string un[il completion. District ICounty or Parish I ARCO ~T.~ zw~ T 'k?,'"' I Field ............. Lease o r' b~'l't I 02 Date and dept~ ......... Complete record for each day while drdhng orW~ progress IState as of 8:00 a.m. 06/16/90 ( 7) TD: 8708' ( 0) SUPV:EB 06/17/90 ( 8) TD: 8708' ( 0) SUPV:EB 06/18/90 ( 9) TD: 8355'( 0) SUPV:EB 06/19/90 (10) TD: 8630' ( 275 SUPV:EB 06/20/90 (11) TD: 8583'( SUPV:EB 06/21/90 (12) TD: 8631' ( 48) SUPV:EB ~K Well no. Sku 2i~-3~ CUTTING 7" SECTION MW: 9.7 VIS:120 REAM TO 8708'. CIRCULATE OUT 5' FILL (METAL CUTTINGS.) POH. PU NEW MILL AND GIH. CUT SECTION TO 8601'.MUD CONTAMINATED W/ OLD DRILLING MUD AND GAS. RAISED MW TO 9.7. CONTINUE TO MILL SECTION TO 8634' DAILY:S17,982 CUM:$235,893 ETD:S235,893 EFC:$1,690,000 LD SECTION MILL MW:10.1 VIS: 54 FINISHED CUTTING SECTION TO 8635'. CIRCULATE. HOLE NOT FILLING PROPERLY ATT TO POH. CIRCULATE BU. ATT TO POH. WELL TRYING TO FLOW. CIRCULATE AND RAISED MW TO 9.9 PPG. STILL COULD NOT POH. RAISE MW TO 10.1 PPG. POH AND LD TRISTATE TOOLS. DAILY:S19,090 CUM:$254,983 ETD:S254,983 EFC:$1,690,000 DRILLING CMT MW:10.2 VIS: 60 LD SECTION MILL. PU 2-7/8" STINGER AND GIH TO 8635' WASH AND CIRCULATE OUT GAS AND OLD MUD TO 8708' RU HALLIBURTON AND SPOT 98 SX OF 'G' CMT AS KO PLUG. POH 7 STDS AND SQZ AWAY 4.5 BBLS CMT. WOC AND CLEAN OUT FLOWLINE. REV OUT. POH AND TEST BOPE. GIH W/ BIT AND TAG TOC @ 8340' DRILL INTO FIRM CMT @ 8355'. DAILY:S42,683 CUM:$297,666 ETD:S297,666 EFC:$1,690,000 GIH MW:10.1 VIS: 44 CIRC OUT CONTAMINATED MUD. DRILLED FIRM CMT F/ 8390'-8526'. DRILLED POOR CMT F/ 8526'-8585' DRILLED FIRM AND HARD CMT F/ 8585'-8629' CIRCULATE. POH. STD BACK BHA AND GIH OE. CIRCULATE. RU HALLIBURTON AND BATCH MIX 75 SX 'G' CMT @ 16.6 PPG. SPOT BALANCED PLUG FROM 8629' POH 7 STDS. SIW AND PRESSURE UP ON PLUG TO 3000 PSI. SQZ'D IN 1 BBL. HOLD PRESSURE WHILE WOC. REV CIRCU- LATE. POH AND PU 6" BIT. GIH. DAILY:S68,880 CUM:$366,546 ETD:S366,546 EFC:$1,690,000 ORIENTING FOR KICKOFF GIH AND WOC. TAG CMT @ 8329'. CBU. POH. PU KO ASS'Y. GIH. GYRO. DAILY:S28,102 CUM:$394,648 MW:10.1 VIS: 40 DRILLED FIRM CMT TO 8583'. CIRC AND ORIENT W/ MULTISHOT ETD:S394,648 EFC:$1,690,000 DRILLING MW:10.1 VIS: 42 CONFIRM ORIENTATION. SIDETRACK OFF OF PLUG AND DRILL TO 8631' DAILY:S52,164 CUM:$446,812 ETD:S446,812 EFC:$1,690,000 The aboveJs correct rm prepa ati~'-~ · ~=> For form preparah nd d~stribution see pr°Ce~esr"a'~' ~ect,on ~0, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. Page r~o. ARCO Oil an~, Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number a~l drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string iS set. Submit weekly for workovers and following setting of oil strin~ until completion. District FieJd ARCO ALASKA INC. County OrKENAiParish I State Lease or Unit A-0~8406 SWANSON RIVER AK J Well no. $~U u_!A-3~. Date and depth as of 8:00 a.m. 06/22/90 (13) TD: 8645'( 14 SUPV:EB 06/23/90 (14) TD: 8788' ( 143 SUPV:EB 06/24/90 (15) TD: 8866'( 78 SUPV:EB 06/25/90 (16) TD: 8944'( 78 SUPV:EB 06/26/90 (17) TD: 9026' ( 82 SUPV:EB 06/27/90 (18) TD: 9091' ( 65 SUPV:EB 06/28/90 (19) TD: 9202'( 111 SUPV:WH 06/29/90 (20) TD: 9316'( 114 SUPV:WH 06/30/90 (21) TD: 9389'( 73 SUPV:WH The above is correct Complete record for each day while drilling or workover in progress GRACE 154 PU DRILLING ASSEMBLY MW:10.1 VIS: 40 DRILLED TO 8645'. POH AND PU 6" HO. GIH AND WIPE OUT KICK-OFF. DISPLACE HOLE NEW MUD SYSTEM. PERFORM PIT=14.6 PPG EMW. POH. PU DRILLING ASS'Y. DAILY:S34,539 CUM:$481,351 ETD:S481,351 EFC:$1,690,000 DRILLING MW:10.0 VIS: 39 GIH. DRILLED WITH ANGLE BUILDING ASS'Y. DAILY:S47,693 CUM:$529,044 ETD:S529,044 EFC:$1,690,000 DRILLING MW:10.0 VIS: 41 DRILLED TO 8837'. POH. CHG BHA. GIH. DRILLED TO 8866' DAILY:S31,289 CUM:$560,333 ETD:S560,333 EFC:$1,690,000 DRILLING DRILLING AND BUILDING ANGLE. GIH. DRILLED TO 8944'. DAILY:S30,393 CUM:$590,726 MW: 9.9 VIS: 42 POH FOR NEW BIT. TEST BOPE. ETD:S590,726 EFC:$1,690,000 TIH MW: 9.9 VIS: 41 DRLG 9026,SURVEY, CHAIN OUT OF HOLE,CHANGE BIT, TIH W/BIT #6. DAILY:S33,075 CUM:$623,801 ETD:S623,801 EFC:$1,690,000 DRLG AHEAD W/MOTOR MW: 9.8 VIS: 41 TIH,FILL DP @ 5100',CONT. TIH TO 8950',ORIENT/WASH TO BTM, 4' FILL, DRLG AHEAD W/MTR AND BUILD ANGLE 9026'-9091' DAILY:S30,780 CUM:$654,581 ETD:S654,581 EFC:$1,690,000 CHANGE OUT MUD MOTOR MW: 9.8 VIS: 40 DRLG TO 9096,POOH,CHANGE OUT MUD MOTOR & MWD,TIH, SLIP DRLG LINE & SERV. RIG, FIN TIH,WASH 9088 TO 9096,ORIENT,DRLG TO 9202,MUD MOTOR FAILED,POOH, CHANGE OUT BIT AND MUD MOTOR DAILY:S19,418 CUM:$673,999 ETD:S673,999 EFC:$1,690,000 DRLG MW: 9.8 VIS: 39 TIH,ORIENT,DRLG FROM 9202-9218,POOH LD DYNA-DRIL, PU MUD MOTOR 1-3/4" BENT SUB TIH TO 5000',CUT DRLG LINE, FIN TIH DRLG DAILY:S27,639 CUM:$701,638 ETD:S701,638 EFC:$1,690,000 DRILLING MW: 9.8 VIS: 41 DRILLED TO 9321'. POH & LD MOTOR. GIH AND REAM TIGHT HOLE. TFBHA. DRILLED TO 9389' DAILY:S27,164 CUM;$728.802 ETD:$728~802 For form preparation afr~ disfribution ~ see Procedures Manu~'~ection 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms consecutively as hey are prepared for each well. Page no ARCO Oil ar._ ~as Company Daily Well History--Interim Instructions: This form is used during dril.ling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until tinal completion. Report official or representative test on "Final" torm. 1) Submit "Interim" sheets when tilled out but not less frequently Ihan every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish ARCO ALASKA INC. I KENAT Fietd ILease or Unit I A-0~406 Date and depth Complete record for each day while drilling or workover in prOgress as of 8:00 a.m. JState AJ{ ]Well no. 07/01/90 (22) TD: 9417' ( 28 SUPV:WH 07/02/90 (23) TD: 9500' ( 83 SUPV:WH 07/03/90 (24) TD: 9623' ( 123 SUPV:WH 07/04/90 (25) TD: 9674' ( 51 SUPV:WH 07/05/90 (26) TD: 9747' ( 73 SUPV:WH 07/06/90 (27) TD: 9818'( 71 SUPV:WH 07/07/90 (28) TD: 10059' ( 241] SUPV: WH 07/08/90 (29) TD:10153' ( 94 SUPV:WH DRILLING MW:10.3 VIS: 40 DRILLED TO 9406'. ATT TO POH-. HOLE NOT FILLING PROPERLY. GIH AND CIRC OUT. MW CUT TO 8.4 PPG. CIRC AND RAISE MW TO 10.3 PPG. TFNB. DRILLED TO 9417'. DAILY:S30,654 CUM:$759,456 CIRC AND RAISE MW TO 10.7 PPG DRILLED TO 9500'. ATT TO POH. GIH. CBU. MW CUT TO 9.5 PPG. 10.7 PPG. DAILY:S31,882 CUM:$791,338 DRLG ETD:S759,456 EFC:$1,690,000 MW:10.5 VIS: 40 HOLE NOT FILLING PROPERLY. CIRCULATE AND RAISE MW TO ETD:S791,338 EFC:$1,690,000 MW:ll.0 VIS: 43 CIRC, RAISE MUD WT TO 10.8, POH, LD MUD MOTOR AND BENT SUB. PU ROTARY ASSEMBLY TIH TO 9300, REAM FROM 9300 TO 9500, BOTTOMS UP, WT CUT TO 10 LB VIS 32, DRLG TO 9623. DAILY:S34,498 CUM:$825,836 ETD:S825,836 EFC:$1,690,000 POH MW:ll.0 VIS: 43 DRILLED TO 9625'. TFNB. CBU. MW CUT TO 9.9 PPG. DUMP 35 BBLS WATER CUT MUD. DRILLED TO 9674' TFNB. DAILY:S42,811 CUM:$868,647 ETD:S868,647 EFC:$1,690,000 DRILLING MW:ll.0 VIS: 41 FTFNB. CBU. MW CUT TO 9.7 PPG W/ FRESH WATER. DUMPED 33 BBLS. DRILLED TO 9747'. DAILY:S31,454 CUM:S900,101 ETD:S900,101 EFC:$1,690,000 DRILLING MW:ll.3 VIS: 43 D~ILLED TO 9768' POH. TESTED BOPE. GIH W/ ROTARY ASS'Y AND MOSAIC BIT. DRILLED TO 9818' DAILY:S25,115 CUM:$925,216 ETD:S925,216 EFC:$1,690,000 DRILLING MW:ll.2 VIS: 43 DRILLED TO 10059'. DAILY:S22,105 CUM:$947,321 ETD:S947,321 EFC:$1,690,000 GIH MW:ll.5 VIS: 39 DRILLED TO 10117' MADE ST. DRILLED TO 10153'. MWD FAILURE. ATT TO POH. HOLE NOT FILLING PROPERLY. GIH AND RAISE MW F/ 11.2 TO 11.5 PPG. POH. CHANGE BHA AND GIH. DAILY:S27,799 CUM:$975,120 ETD:S975,120 EFC:$1,690,000 The above is correct Signature ~ ~ For form preparation and ~ri6ution ~ see Procedures Manual S(~113n 10, Drilling, Pages 86 and 87 AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. Page ne ARCO Oil arm ,.~as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring1 or perforating, show formation name in describing work performed. Number a;I drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until linal completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO ALASKA INC. County or Parish ] State I KENAI JLease or Unit A-028406 SWANSON RIVER Date and depth as of 8:00 a.m. 07/09/90 (30) TD:10333' ( 180 SUPV:WH 07/10/90 (31) TD:10399' ( 66 SUPV:WH 07/11/90 (32) TD:10570' ( 171 SUPV:WH 07/12/90 (33) TD:10706' ( 136 SUPV:EB 07/13/90 (34) TD:10816' ( 110 SUPV:EB 07/14/90 (35) TD:10980' ( 164 SUPV:EB 07/15/90 (36) TD:l1084' ( 104] SUPV:EB 07/16/90 ( 37)0) TD:l1084' ( SUPV:EB 07/17/90 (38) TD:10365'( SUPV:EB Complete record for each day while drilling or workover in progress AK J Well no. SP.U 2 !A- 3"'. GRACE 154 DRILLING FGIH. DRILLED TO 10333'. MW:ll.5 VIS: 40 DAILY:S24,103 CUM:$999,223 ETD:S999,223 EFC:$1,690,000 DRILLING MW:ll.9 VIS: 39 DRILLED TO 10399' ATT TO POH. HOLE NOT FILLING PROPERLY. GIH AND CBU. MW CUT TO 8.7 PPG. CIRC AND WT UP TO 11.9 PPG. TFNB. DAILY:S31,043 CUM:$1,030,266 ETD:S1,030,266 EFC:$1,690,000 DRILLING MW:12.0 VIS: 42 DRILLED TO 10570' DAILY:S25,931 CUM:$1,056,197 ETD:S1,056,197 EFC:$1,690,000 CHANGING BHA MW:12.0 VIS: 41 DRILLED TO 10706'. CBU. POH. DAILY:S25,444 DRILLING TEST BOPE. GIH. CUM:$1,081,641 ETD:S1,081,641 EFC:$1,690,000 MW:12.0 VIS: 42 DRILLED TO 10816'. DAILY:S28,751 CUM:$1,110,392 ETD:SI,ii0,392 EFC:$1,690,000 DRILLING MW:12.0 VIS: 42 DRILLED TO 10,838'. TFNB. DRILLED TO 10980'. DAILY:S36,948 CUM:$1,147,340 ETD:S1,147,340 EFC:$1,690,000 WORK STUCK PIPE MW:12.0 VIS: 43 DRILLED TO 11084'. JAR ON STUCK PIPE. SPOT EZ SPOT PILL AND CONTINUE TO JAR ON STUCK PIPE. DAILY:S26,784 CUM:$1,174,124 ETD:S1,174,124 EFC:$1,690,000 JAR ON STUCK PIPE MW:12.0 VIS: 42 JAR ON STUCK PIPE. RU AND RAN FP. FREE 4 JTS ABOVE JARS. BACKED OFF PIPE @ 10741'. POH AND PU JARRING ASS'Y. GIH AND SCREW INTO FISH. JAR ON STUCK PIPE. DAILY:S25,831 CUM:$1,199,955 ETD:S1,199,955 EFC:$1,690,000 WOC MW:12.0 VIS: 41 JAR ON FISH. RAN FP AND BACKED OFF AT SCREW-IN SUB. CBU. MW CUT TO 10.8 PPG. POH AND LD FISHING TOOLS. PU STINGER OF TBG AND GIH TO TOF=10741'. CBU. MW CUT TO 11.2 PPG. SPOT CMT PLUG F/10741'-10365'. POH TO 7" CSG. REV The is correct above HOT,T) 300 PSI WHILE WOC. ForSignatureform~di~I'~ LY: $42,494 JDate CUM: $1,242,44~it'~TD: $1,242,449 EFC: $1,690,000 seeP .... d .... M anus%,.,~ection 10, /// ~'~ / ~' ("~ I~,Q~ ~ Drilling, Pages 86 and 87 AR3B-459-2-B JNumber all daily well history forms consecutively JPage no. as they are prepared for each well. ARCO Oil an.~ .~as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number a;I drill stem tests sequentially. Attach description of all ceres. Work performed by Producing Seclion will be reported on "Interim" sheets unlil final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and tollowing setting of oil string until completion. District IState ARCO ALASKA INC. Field SWANSON RIVE! Date and depth as of 8:00 a.m. 07/18/90 (39) TD:10657'( 29; SUPV:EB 07/19/90 (40) TD:10732' ( 75 SUPV:EB 07/20/90 (41) TD:10795'( 63 SUPV:EB 07/21/90 (42) TD:10834' ( 39 SUPV:EB 07/22/90 (43) TD:l1052' ( 218 SUPV:EB 07/23/90 (44) TD:11136' ( 84 SUPV:EB 07/24/90 (45) TD:ll160' ( 24 SUPV:EB County or Parish KV. lgA T Lease or Unit A-028406 Complete record for each day while drilling or workover in progress GRACE I _54 A~ LWell no. SRU ~iA-34 GIH W/SIDETRACK ASS'Y MW:12.0 VIS: 50 WOC. ATT TO POH. WELL SWABBING. CIRC OUT AND TREAT CONTAMINATED MUD. POH. PU BIT AND GIH. DRILL CMT STRINGERS F/8295'=8652' GIH TO 10584'. DRILLED CMT TO 10657'. C&C MUD. POH AND PU ST ASS'Y. DAILY:S28,009 CUM:$1,270,458 ETD:S1,270,458 EFC:$1,690,000 SIDETRACKING WELL MW:12.0 VIS: 42 FGIH W/ ST ASS'Y. SIDETRACK WELL OFF OF PLUG F/10,657'-10 732' DAILY:S136,362 CUM:$1,406,820 ETD:S1,406,820 EFC:$1,690,000 DRLG MW:12.0 VIS: 42 SIDETRACK OFF CMT PLUG 10,732'-10,738',PUMP DRY JOB, POH TIGHT @ 9567',WORK TIGHT HOLE FROM 9567'-9552',ROT, CIRC. AND CLEAN UP,CONT. POH,LD MUD MTR, CHANGE BHA, CK MWD,CHANGE OUT JARS,TIH TO 10,654',SMALL BRIDGE @ 9567',REAM MTR RUN, 10.654'-10,738',DRLG TO 10,795',BTMS UP WT CUT TO 11.2 PPG W/13 BBLS TOTAL INFLUX FROM FORMATION DAILY:S36,653 CUM:$1,443,473 ETD:S1,443,473 EFC:$1,690,000 DRILLING MW:ll.9 VIS: 41 DRILLED TO 10802' TRIP FOR BHA CHANGE. DRILLED TO 10834' DAILY:S34,075 CUM:$1,477,548 ETD:S1,477,548 EFC:$1,690,000 DRILLING MW:ll.9 VIS: 43 DRILLED TO 10921' MADE 15 STD ST. DRILLED TO 11052'. DAILY:S22,996 CUM:$1,500,544 ETD:S1,500,544 EFC:$1,690,000 DRILLING MW:ll.9 VIS: 42 DROP SURVEY AND TFNB. DRILLED TO 11136' DAILY:S28,060 CUM:$1,528,604 ETD:S1,528,604 EFC:$1,690,000 SPOTTING EZ-SPOT PILL MW:ll.9 VIS: 41 DRILLED TO 11160'. MADE ST TO 7" CASING. PIPE STUCK WHILE DROPPING SURVEY. JAR ON STUCK PIPE WHILE MIXING EZ SPOT PILL. CIRC AND CUT MW TO 11.5 PPG. WELL FLOWING SLIGHTLY. SPOT PILL AND WELL BEGAN STRONG FLOW. CIRC IN 11.9 PPG MUD TO KILL WELL AND RESPOT NEW PILL. DAILY:S29,731 CUM:$1,558,335 ETD:S1,558,335 EFC:$1,690,000 The above is correct Signatur~~ ~_ For form preparation ~i~ distribution see Procedures Manu~,,~Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Date '" E( i iVED .NOV o 1990 Gas Cons. Number all daily well history forms consecutively as Ihey are prepared for each well. Page no. ARCO Oil ar~- ,~as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work pertormed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. County or Parish ' IState District I ~t~[:~CO A~.SKA INC ~..h]'A, AK h,,eH Field Lease or Unit ~i no. SW~SON RIVER ~-~R406 SPJJ ~A 3~ Date and dept~ Complete record for each day while drilling or workover in progress as of 8:~ a.m. 07/25/90 (46) TD:lll60' ( SUPV:EB 07/26/90 (47) TD:lll60' ( SUPV:WH 07/27/90 (48) TD:10710' ( 0 SUPV:WH 07/28/90 (49) TD:10740' ( 30 SUPV:WH 07/29/90 (50) TD:10811' ( 71 SUPV:WH 07/30/90 (51) TD:10835' ( 241 SUPV:WH 07/31/90 (52) TD:10835' ( SUPV:WH 08/01/90 (53) TD:10835' ( SUPV:WH POH MW:ll.9 VIS: 42 SPOT PILL. JAR ON STUCK PIPE. RU AND RUN FP. TOP OF JARS FREE. RETRIEVE SURVEYS. ATT TO BO ON TOP OF JARS. RUN FP AND BO 1 JT ABOVE JARS. CIRC OUT PILL AND WATER CUT MUD. MW CUT TO 10.0 .PPG. POH. DAILY:S45,544 CUM:$1,603,879 ETD:S1,603,879 EFC:$1,690,000 GIH MW:ll.9 VIS: 41 FPOH. PU JARRING ASS'Y AND GIH. JAR ON FISH W/O SUCCESS. BO OF FISH AND POH. LD FISHING TOOLS AND PU 2-7/8" TUBING STINGER. GIH TO SET CMT PLUG. DAILY:S23,644 CUM:$1,627,523 ETD:S1,627,523 EFC:$1,690,000 POH MW:ll.9 VIS: 42 GIH AND TAG TOF @ 10946' SPOT 100 SK BALANCED CMT PLUG. POH 16 STDS AND REV OUT. POH AND LD 2-7/8" TBG. PU BIT AND GIH. TAG TOC @ 10636'. DRLD CMT TO 10710' CBU AND POH FOR ST ASS'Y. DAILY:S38,936 CUM:$1,666,459 ETD:S1,666,459 EFC:$1,690,000 SIDETRACKING W/ MOTOR MW:ll.9 VIS: 42 FPOH. TEST BOPE. PU ST ASS'Y AND GIH. HOLE TIGHT @ 9714' REAM TO TD. ST W/ MUD MOTOR. DAILY:S28,019 CUM:$1,694,478 ETD:S1,694,478 EFC:$1,690,000 REAMING TO BOTTOM MW:ll.9 VIS: 43 DRILL TO 10811' W/ ST ASS'Y. TFNB AND BHA. REAM NEW HOLE TO TD. DAILY:S28,282 CUM:$1,722,760 ETD:S1,722,760 EFC:$1,690,000 RU TO RUN 5" LINER MW:ll.9 VIS: 44 FIN REA/4ING TO TD. DRILLED TO 10835'. ST. HOLE TIGHT. CIRC. ST. HOLE TIGHT. CIRC. POH FOR LINER. HOLE IN GOOD SHAPE. LD BHA. RU TO RUN 5" FL4S LINER. DAILY:S22,919 CUM:$1,745,679 ETD:S1,745,679 EFC:$1,690,000 GIH W/ BIT MW:ll.9 VIS: 43 PU 5" LINER. RUN LINER IN HOLE ON DP. HIT BRIDGE @ 10043'. WORK LINER. COULD NOT GET THROUGH BRIDGE. POH AND LD 5" LINER. PU BIT, BHA AND GIH. DAILY:S18,939 CUM:$1,764,618 ETD:S1,764,618 EFC:$1,690,000 The above is correct DAILY: S24; :303 Signature ~ For form preparation an~'-~lstril~ution see Procedures Manual ~,~:tion 10, Drilling, Pages 86 and 87' GIH W/5" LINER MW:12.0 VIS: 45 FGIH. 5' FILL ON BOTTOM. CIRC. ST TO WINDOW. CBU. ST TO WINDOW. SPOT BARATROL PILL IN 6" HOLE. POH. RU AND RUN 65 JTS 5" 18# FL4S N-80 LINER AND LINER EQUIPMENT. GIH W/ LINER ON 3-1/2" DP. Date __ - ' ;' i - ' ,,~-' ........ - ' -- - ' - - - AR38-459-2-B Number all daily well history forms consecutively as they are prepared for each well. JPage no ,. ARCO Oil ar~_ ,.~as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing1 coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach descr pt on of all cores. Work performed by Producing Section will be reported on "Interim" sheets undl final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string unlil completion. District Field SWANSON RIVRR Date and depth as of 8:~ a.m. GRACR 1 54 08/02/90 (54) TD:10835' ( SUPV:WH 08/03/90 (55) TD:10835' ( 0 SUPV:WH 08/04/90 (56) TD:10840' ( SUPV:WH 08/05/90 (57) TD:l1056' ( 216 SUPV:WH 08/06/90 ( 58) TD:l1073' ( 17 SUPV:WH 08/07/90 (59) TD:11073' ( SUPV:WH 08/08/90 ( 60) TD:l1077' ( 4) SUPV:WH 08/09/90 (61) TD:ll127'( 50) SUPV:EB DAIL¥:S2~:SqR The above is c2ect For form preparation ~ di~ribution see Procedures Manu I~ection 10, Drilling, Pages 86 and~7 County or Parish ARCO ALASKA INC. KP. NAI Lease or Unit ~-028406 Complete record [or each day while drilling or workover in progress Stale A~ ~Well no. SRU ~IA-34 POH MW:ll.9 VIS: 44 GIH W/ LINER TO 8570' CIRC. FGIH AND TAG BOTTOM @ 10835' CIRC AND RECIPROCATE LINER. BATCH MIX 90 BBLS CMT @ 15.8 PPG. PUMP AND DISPLACE CMT. BUMP PLUG W/ 2000 PSI. FLOATS HELD. HANG LINER. POH 10 STDS. CIRC. TRIP FOR BIT. NO CMT ON TOL. WO TOL PACKER. POH. DAILY:S82,458 CUM:$1,871,379 ETD:S1,871,379 EFC:$1,690,000 DRILLING OUT 5" LINER MW:ll.3 VIS: 42 FPOH. LD 3-1/2 HWDP. PU TOL PKR. GIH. SET PKR AND TEST TOL TO 3000 PSI. NEW TOL = 8236'. POH. PU BHA AND GIH W/CMT MILL. TAG CMT @ 10728'. DRILLED SOFT CMT TO LANDING COLLAR @ 10752'. DRILLED LC AND CMT. DAILY:S53,377 CUM:$1,924,756 ETD:S1,924,756 EFC:$1,690,000 PU BHA MW: 9.6 VIS: 39 DRILLED ON FC. POH. CO MILL. GIH. DRILLED FC, CMT, FS, AND 5' OF NEW FORMATION. PERFORM PIT = 12.5 PPG EMW. POH. PU BHA. DAILY:S37,808 CUM:$1,962,564 ETD:S1,962,564 EFC:$1,690,000 POH MW: 9.7 VIS: 39 GIH. DRILLED TO 11056'. POH. DAILY:S32,283 CUM:$1,994,847 ETD:S1,994,847 EFC:$1,690,000 RIG REPAIR MW: 9.7 VIS: 41 FPOH. TESTED BOPE. GIH. DRILLED TO 11073' WORK ON ROTARY TABLE. POH TO CSG AND REPAIR ROTARY TABLE. DAILY:S26,005 CUM:$2,020,852 ETD:S2,020,852 EFC:$1,690,000 CO ROTARY TABLE MW:10.2 VIS: 40 CIRCULATED AND RAISED MW TO 10.2 PPG. POH & PU RETRIEVABLE BP. GIH & SET BP @ 10817'. SET 7" STORM PKR @ 35' CHANGE OUT ROTARY TABLE. DAILY:S25,226 CUM:$2,046,078 ETD:S2,046,078 EFC:$1,690,000 POH MW:10.2 VIS: 39 CHANGE OUT ROTARY TABLE. RELEASE STORM PKR AND RELEASE BP. CIRC & POH. PU BHA. GIH. DRILLED TO 11077'. BIT NOT DRILLING. POH. DAILY:S19,884 CUM:$2,065,962 ETD:S2,065,962 EFC:$1,690,000 DRILLING MW:10.2 VIS: 42 FPOH. CO MOTOR AND BIT AND GIH. DRILLED TO 11,127' CEIVED AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. IPage no ARCO Oil anu Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or pen'orating, show formation name in describing work pertormed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative.teSt on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish State ARCO ALASKA INC. KENAI AK Field Lease or Unit ~'"lwell no. SWANSON RIVER ;%-028406 $~T3 ~_1_~_-34 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. 08/10/90 (62) TD:11160' ( 33 SUPV:EB 08/11/90 (63) TD:lll60' ( SUPV:EB 08/12/90 (64) TD:11160' ( SUPV:EB 08/13/90 (65) TD:11160' ( SUPV:EB GRACE 154 The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 an/~ ~ GIH W/ FISHING ASS'Y MW:10.2 VIS: 43 DRILLED TO 11134' ST. DRILLED TO 11160'. CIRC. POH TO LOG. RU ATLAS. LOG OPEN HOLE W/IEL-CNL-SP, RUN 1, GR-BHCS-CAL-SP, RUN 2. STUCK ON REPEAT. WORK TOOL WHILE WO FISHING TOOLS. PULL OFF WEAK POINT AND POH W/ WL. PU FISHING TOOLS AND GIH. DAILY:S24,492 CUM:$2,117,052 ETD:S2,117,052 EFC:$1,690,000 TRIPPING IN HOLE MW:10.2 VIS: 45 TIH W/FISHING TOOLS TO 10820',CBU, GAS CUT TO 9.9 PPG CONT.TIH,WORK OVERSHOT ON FISH @ 10,944',JAR ON FISH, POH TO SHOE AND CONFIRM FISH IN OVERSHOT, POH WET RETRIEVE 22' OF ATLAS TOOLS,REDRESS O.S. AND TIH TO 5" SHOE @ 10,835',CIRC OUT GAS CUT MUD TO 9.0 PPG WHILE CUT DRLG LINE, CONT TIH, WORK OVERSHOT ON FISH @ 10,966',PULL LOOSE 30K, POOH TO SHOE NO INCREASE IN PUMP PRESSURE,POSSIBLE FISH LOOSE AND MOVED DOWN HOLE,MIX & PUMP PILL, POOH, RECOVER REMAINDER OF ATLAS TOOL STRING, LD FISH AND TSA FISHING TOOLS,PU BIT AND 4-1/8" STABS, TIH DAILY:S64,983 CUM:$2,182,035 ETD:S2,182,035 EFC:$1,690,000 RUN 2-7/8" LINER MW:10.2 VIS: 45 CONT TIH,BREAK CIRC. @ lll30',WASH 11130' TO 11150',10' OF FILL, HOLE STICKY ON BTM, CIRC. MUD, COND HOLE,DID NOT ATTEMPT TO C/O FILL DUE TO DRAG ON BTM, BTMS UP GAS CUT TO 9.9 PPG POOH TO 5" SHOE,NORMAL DRAG, NO TIGHT SPOTS,MONITOR HOLE (STABLE),RU/POOH/LDDP,CLEAR FLOOR OF ALL SMALL HANDLING TOOLS,PULL WEAR BUSH., CHANGE RAMS TO 2-7/8" AND TEST TO -4500PSI,RESET WEAR BUSH.,RU GBR AND RIH WITH 2-7/8" LINER ~LY:$24,719 CUM:$2,206,754 ETD:S2,206,754 EFC:$1,690,000 RUN 2-7/8" LINER MW:10.2 VIS: 40 CONT TIH TO 5" SHOE W/2-7/8" LINER, CIRC OUT GAS CUT MUD TO 9.0 PPG, PU 9 JTS 2-7/8" & STAND BACK,MU CMT PLUG HEAD,CONT TIH TO 11130' (NORMAL) WASH 11130'TO 11160',SPACE OUT W/PUPS FOR CMT HEAD,CIRC AND RECIP. TBG, BTMS UP GAS CUT MUD TO 9.9 PPG,MIX UP SPACERS AND BATCH MIX CMT.,TEST CMT LINES TO 3000 PSI,PUMP 10 BBLS 11.5 PPG DUAL SPACER, DROP BTM PLUG, PUMP 10 BBLS CLASS G CMT @ 15.6 PPG BLENDED PER PROGRAM, DROP TOP PLUG & FLUSH 2" CMT LINE W/BRINE,DISPLACE CMT W/ 5BBLS 10.2 BRINE/20BBLS 10.2 POLY SPACER/28BBLS BRINE @ 4 BPM/1450 PSI 53 BBLS BEHIND PLUG, PRESS. LOCKED UP AT 3000 PSI,RELEASE PRESS. AND CHECK SURFACE EQUIP.,FOUND 2" HP CMT HOSE GAVE UP INTERNALLY, RD HOWCO AND POOH TO 5" SHOE CMT IN TBG 9156' TO 10886',POOH AND STD BACK ALL UNCEMENTED TBG. (97 STDS),RU AND CONT POOH,I/) 2-7/8" TBG, LOST 63 JTS TO CMT, CLEAN& INSPECT FLOAT EOUIP.. FOUND HOWCO BTM PLUG DID NOT LAND ON SHQ~LDER, NOT COMPATIBLE TO BAKER FLOAT i~ESULTIN~ TN OF FLOAT COLL~t~REMOVE DAMAGE~it~LUG F/FLOAT C~LLAR AND AR3B-459-2-B INumber all daily well history forms conseculively as they are prepared Ior each well. Page no. ARCO Oila~. .~asCompany Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative te'~ton "Fh~el" form. 1) Submit "Interim" sheets when filled out bul not less frequently than every 30 days, or {2) on Wednesday of the week in which oil stiit~g' Is set. Submit weekly for workovers and following setting of oil strin§ until completion. District 'Field SWANSON RIVER 'Date and depth as of 8:00 a.m. I County or Parish ARCO ALASKA INC. ! I Lease or Unit A-O?R4Q6; Complete record for each day while drilling or workover in progress 08/14/90 (66) TD:l1094' ( 0 SUPV:EB 08/15/90 (67) TD:11094' ( SUPV:EB 08/16/90 (68) TD:11094' ( SUPV:EB 08/17/90 (69) TD:11094' ( 0 SUPV:EB 08/18/90 (70) TD:11094' ( SUPV:EB GRAC~ ~54 IState A~ iWelI no. .... 21A-34 STABLE,MU FLOAT EQUIP. CIRC AND CHECK SA24E, TIH W/2-7/8" TBG BAKER LOCK BTM OF ALL 2-7/8" COLLARS IN EXPECTED CMT TOP AREA FOR BACKOFF,RABBIT ALL TBG, FILL TBG EVERY 1000' DAILY:S30,021 CUM:$2,236,775 ETD:S2,236,775 EFC:$1,690,000 WOC MW:10.2 VIS: 41 CONT TIH W/2-7/8" TBG, RABBIT ALL STANDS FROM DERRICK TO 5" SHOE,PU AND STD BACK OPEN HOLE TBG IN DERRICK, RU CMT HEAD CONT TIH, BRK CIRC @ ll,130',WASH TO FILL @ ll,150',CIRC AND COND HOLE,WASH FILL ll,150-11,160',BTMS UP GAS CUT TO 9.1 PPG, CIRC WELL TO 10.2 PPG WHILE MIXING SPACERS,BATCH MIX CMT, TEST LINES TO 3000 PSI,PUMP 10BBLS DUAL PURPOSE SPACER @ 15.6 PPG, FOLLOW W/10BBLS CLASS G CMT BLENDED PER PROGRAM @ 15.6 PPG, DROP TOP PLUG AND FLUSH CMT LINE,DISPLACE W/5 BBLS 10.2 PPG BRINE,FOLLOW W/20 BBLS POLYMER SPACER @ 10.2 PPG AND 39.2 BBLS OF 10.2 PPG BRINE @ 4 BPM AND 1800 PSI WHILE RECIPROCATING TBG, SLOW RATE TO 3 BPM AND 1000 PSI FOR LAST 5 BBLS DISPLACEMENT, BUMP PLUG W/2000 PSI,CHECK FLOATS, POSITION STRING 1' OFF BTM, CIP @ 2100 HRS, SHUT IN TBG W/0 PRESSURE WOC AND MONITOR ANNULUS,CLEAN MUD PITS DAILY:S39,801 CUM:$2,276,576 ETD:S2,276,576 EFC:$1,690,000 POH W/2-7/8" TUBING MW: 9.0 VIS: 0 WOC AND CLEAN MUD TANKS. RU AND RUN FP AND SS. TAG UP @ 10982'. ATT BO @ 10274'. BACKED-OFF HIGH. SCREW IN AND MAKE JET CUT @ 10,276'. DISPLACE WELL TO BRINE. POH WITH · Z~7tS"TUBING. '.~W/%.:;~41,306 CUM:$2,317,882 ETD:S2 317,882 EFC:$1,690,000 i~~i:: MW: 9.0 VIS: 0 ~,.' RU SLICKLINE AND BAIL OUT FILL TO 11038' WLM. MADE GAGE~ING RUN IN 5" LINER AND IN 2-7/8" LINER. LOG CCL-GR FOR CORRELATION. DAILY:S28,040 CUM:$2,345,922 ETD:S2,345,922 EFC:$1,690,000 CIRCULATE AND FILTER BRINE MW: 9.0 VIS: 0 RAN GR-CCL AND GYRO SURVEY. GIH W/ 2-7/8" TUBING. CIRCULATE AND FILTER BRINE. DAILY:S36,844 CUM:$2,382,766 ETD:S2,382,766 EFC:$1,690,000 BAILING OUT 2-7/8" LINER MW: 9.0 VIS: 0 CIRCULATE AND FILTER BRINE. RU SLICKLINE AND TAG FILL @ 10895'. BAIL FILL OUT OF LINER TO 11000'. DAILY:S25,811 CUM:$2,408,577 ETD:S2,408,577 EFC:$1,690,000 The above is correct For form d~stri see Procedures Manqf~l]Section 10, Drilling, Pages 86 an(~87 AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil an. Nas Company Daily Well History--Interim Instructions: This form is used during drilling or work, over operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. A .t-~llb. h description of all cores. Work .p. erfo.rm,e,d by Prod. ucin.~,.S,ection will be rep.dried on "Interim" sheets until completion. Report official or representa~_...-test, on ".FJ~'..' form. 1) Submit "lnlerlm shee. ts wne~ i,~ee ~ut b.ut not !ess frequently than every 30 days, or on Wednesday of the week in which oil st~ ~set. Submit weekly for workovers and following setting of oil siring until completion. -.; District Field SWAN.~ O~ R IVP. R Date and depth as of 8:00 a.m. I County or Parish ARCO ALA~[(A INC. I WF. NAT I Lease or Unit - - I A-028405 Complete record for each day while drilling or workover in progress 08/19/90 (71) TD:l1094' ( 0 SUPV:EB lState ~'~ ]Well no. 3RU 21A-34 GIB W/ PACKER MW: 9.0 VIS: 0 WORK 2.2" GAGE RING TO 11039'. RU AWS AND ATT TO PERFORATE W/ 2-1/8" GUNS. GUNS WOULD NOT GO BELOW 10920'. MADE 1-11/16" GAGE RING RUN TO 11035'. RD AWS. PO~ W/ TBG. RUN MODEL 'DB' PKR ON WIRELINE. WOULD NOT SET. HEAD WET. DAILY:S29,843 CUM:$2,438,420 ETD:S2,438,420 EFC:$1,690,000 The above is correct Signatu re~.~,.~ ~ For form preparation ai)~:Jis'~bution ~, see Procedures Manuatl' S~)~ction 10, Drilling, Pages 86 and'~P' Date AR3B-459-2-B Number all daily well history forms consecutively IPage no. as they are prepared for each well. ARCO O,..4nd Gas Company Daily Well History-Final Report Instructions: Prepare ~~':~Wednesday after allowable has been assigned or well Is Plugged, Abandoned, or Sold. "Ftnll Report" should "='~ .... _ nded for an indefinite or appreciable length of time. On workovera when an official test is not required upon complet.'"~...' --~ ~_~l_est data in blocks provided. The "Final I=lep~rl" form may be used for reporting the entire operation if space is a~~' - ~ ' '~'~--'~ .... ~ ~'" :-: "'~- I State District : ~..r%:~_~T~-'.~:'..~ ~? ~: --~ ~ County or Par sh ARCO ALASKA INC. KENAI Field Lease or Unit Wall no. SWANSON RIVER Title A-028406 SRu ,qlA-~4 Auth. or W.O. no. AD6803 I DRILLING & COMPLETIONS Operator A.R.Co. W.I. ~Total number of wells (active or inactive) on thisI Icost center prior to plugging and I ARCO 48.4900 labandonment of this well Spudded or W.O. begun Date iHour IPrior status if a W.O, / I SPUD 06/20/90 / 11:00 Date and depth as of 8:00 a.m. 08/20/90 (72) TD:l1094' ( SUPV:EB Complete record for each day reported GRACE 154 RR AND RIGGING DOWN MW: 9.0 VIS: 0 SET PKR @ 10171' WLM. RD AWS. GIH W/ 2-7/8" X 2-3/8" COMPLETION ASS'Y. SPACE OUT AND LATCH SEALS INTO PKR. TUBING WOULD CIRCULATE. INSTALL PRODUC- TION TREE AND TEST TO 250 AND 5000 PSI. RU SLICKLINE AND INSTALL DV'S IN TOP 2 2-7/8" GLM'S. TEST TBG AND ANNULUS. OK. SET BPV. RR @ 0600 20-AUG-90. DAILY:S187,366 CUM:$2,625,786 ETD:S2,625,786 EFC:$1,690,000 O[d TO ! New TD PB Depth I Released rig I Date I K nd ofr g I I Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data ~ Well no. Date Reservoir Producing Interval OII or gu Teat time Production Oil on teat Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above ia correct ~-~ For form prepa~t_io~j~ di'~tribut--'ion, ~ Pmcedur~ Ma~ Section Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively aa they are prepared for each well. iPage no. Olvll~on of AIlantlcRIchfleldCo~patty 0 I~! I L_I_ I N 1:3 SEFIVICES August 20, 1990 Mr. Lowell Crane ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Level Rotor Gyroscopic Survey Job No. AK-LB-00095 Well: 21A-34 Field: Swanson River Survey Date: 8/16/90 Operator: T. McGuire Dear Mr. Crane: Please find enclosed the "Original" and one (1) copy of our tie-in Lever Rotor Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard Region Manager Enclosure 5631 SilveradoWay, Suite G · Anchorage, Alaska99518 ° (907)563-3256 · Fax (907)563-7252 A Baroid Company SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, INC. 21A-34 SWANSON RIVER ALASKA COMPUTATION DATE: 8/20/90 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN DATE OF SURVEY: 08-16-90 LEVEL ROTOR GYROSCOPIC SURVEY JOB NUMBER: AK-LB-00095 KELLY BUSHING ELEV. = 156.00 FT. OPERATOR: T. MCGUIRE COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8500 8499.29 8343. 8600 8599.22 8443. 8700 8699.05 8543. 8800 8798.79 8642. 8900 8898.27 8742. 29 I 2 S 35.00 W .00 27.24S 74.89W 22 2 49 S 30.99 W 1.80 30.10S 76.68W 05 3 45 S 30.85 W .92 35.03S 79.63W 79 4 34 S 47.27 W 1.45 40.55S 84.24W 27 .7 4 S 63.77 W 2.99 45.98S 92.71W 79.43 81.91 86.06 91.96 101.57 9000 8997.15 8841. 9100 9095.03 8939. 9200 9191.29 9035. 9300 9285.81 9129. 9400 9378.69 9222. 9500 9469.30 9600 9558.34 9700 9646.20 9800 9731.97 9900 9816.07 15 10 0 S 69.19 W 3.02 51.79S 106.36W 03 13 34 S 75.20 W 3.78 57.88S 125.84W 29 17 45 S 79.05 W 4.29 63.78S 152.17W 81 20 19 S 80.88 W 2.65 69.43S 184.29W 69 23 10 S 79.78 W 2.86 75.67S 220.81W 9313.30 26 49 S 76.65 W 3.90 84.38S 262.15W 9402.34 27 19 S 75.80 W .63 95.22S 306.36W 9490.20 29 40 S 75.03 W 2.36 107.25S 352.53W 9575.97 32 10 S 74.42 W 2.52 120.79S 402.08W 9660.07 33 19 S 74.62 W 1.17 135.22S 454.21W 116.27 136.66 163.61 196.09 232.96 275.13 320.64 368.34 419.70 473.80 10000 9899.22 10100 9981.42 10200 10062.88 10300 10144.37 10400 10226.37 9743.22 34 10 S 75.65 W 1.01 149.47S 507.90W 9825.42 35 15 S 74.67 W 1.22 164.06S 562.94W 9906.88 35 40 S 73.34 W .88 180.05S 618.70W 9988.37 35 10 S 74.09 W .66 196.30S 674.32W 10070.37 34 40 S 74.25 W .51 211.91S 729.39W 529.35 586.28 644.28 702.23 759.46 10500 10308.07 10600 10389.06 10700 10469.48 10800 10552.21 10900 10638.10 10152.07 35 45 S 74.56 W 1.10 227.41S 784.92W 10233.06 36 4 S 74.98 W .41 242.82S 841.52W 10313.48 36 49 S 74.76 W .76 258.33S 898.88W 10396.21 31 34 S 83.74 W 7.27 269.08S 953.91W 10482.10 30 0 S 82.21 W 1.77 275.32S 1004.71W 817.11 875.77 935.19 991.10 1041.75 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1041.75 FEET AT SOUTH 74 DEG. 40 MIN. WEST AT MD = 10900 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 254.68 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. 21A-34 SWANSON RIVER ALASKA COMPUTATION DATE: 8/20/90 DATE OF SURVEY: 08-16-90 JOB NUMBER: AK-LB-00095 KELLY BUSHING ELEV. = 156.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8500 8499.29 8343.29 9500 9469.30 9313.30 10500 10308.07 10152.07 10900 10638.10 10482.10 27.24 S 74.89 W .71 84.38 S 262.15 W 30.70 29.99 227.41 S 784.92 W 191.93 161.24 275.32 S 1004.71 W 261.90 69.96 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVIC~.o ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. 21A-34 SWANSON RIVER ALASKA COMPUTATION DATE: 8/20/90 DATE OF SURVEY: 08-16-90 JOB NUMBER: AK-LB-00095 KELLY BUSHING ELEV. = 156.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA HEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 8500 8499.29 8343.29 8556 8556.00 8400.00 8656 8656.00 8500.00 8757 8756.00 8600.00 8857 8856.00 8700.00 8958 8956.00 8800.00 9059 9056.00 8900.00 9163 9156.00 9000.00 9268 9256.00 9100.00 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 27.24 S 74.89 W .71 28.31 S 75.61 W .73 .02 32.63 S 78.20 W .86 .13 38.22 S 81.76 W 1.08 .22 43.67 S 88.49 W 1.46 .38 49.28 S 100.05 W 2.29 .83 55.47 S 117.26 W 3.97 1.68 61.63 S 141.63 W 7.10 3.13 67.67 S 173.66 W 12.30 5.19 9375 9356.00 9200.00 9485 9456.00 9300.00 9597 9556.00 9400.00 9711 9656.00 9500.00 9828 9756.00 9600.00 74.01 S 211.44 W 19.40 7.10 82.88 S 255.70 W 29.14 9.74 94.93 S 305.19 W 41.37 12.23 108.69 S 357.92 W 55.28 13.91 124.85 S 416.63 W 72.38 17.11 9947 9856.00 9700.00 10068 9956.00 9800.00 10191 10056.00 9900.00 10314 10156.00 10000.00 10436 10256.00 10100.00 142.17 S 479.60 W 91.83 19.44 159.31 S 545.61 W 112.87 21.04 178.63 S 613.97 W 135.53 22.66 198.55 S 682.20 W 158.23 22.69 217.48 S 749.11 W 180.02 21.80 10559 10356.00 10200.00 10683 10456.00 10300.00 10804 10556.00 10400.00 10900 10638.10 10482.10 236.58 S 818.26 W 203.10 23.07 255.67 S 889.14 W 227.15 24.05 269.33 S 956.22 W 248.45 21.30 275.32 S 1004.71 W 261.90 13.45 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS // AOGCC GEOLOGICAL MATERIALS iNVENTORY' LiST PERMIT # ,~o - ~-~ WELL NAME ..~/~y' .~//,~'- COmPLETiON DATE ~ ! /~ j ~o CO, CONTACT ~~ check off or list data as it is received.*list received date for 407. if not 're.uired list as NR .u drilling history' sur~ev well '~es~s' core descri cored intervals core I/v~ drv ditch intervals ital data Ri 12.1 13l I I RUN NO. INTERVALS , [to thc nearest foot~ ,, [inchll ...... ~ ~ ~?- ///_r-.~- .~ v- .r- ............ I i, ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSMISSION TO:. Commissioner FROM: Scott Jepsen COMPANY: AOGCC COMPANY: ARCO Alaska, Inc DATE: 10/8/90 WELL NAME: Listed below Transmitted herewith are the following Blue Sepia Sepia rape & Line Folded Rolled Mylar listin~ BRU 214-26 DUAL INDUCT FOC 1 1 DUAL LATERAL 1 1 ACOUSTIC CE~NT BOND 1 1 MINILOG GR 1 1 GAMMA RAY 9/24 1 1 GAMMA RAY 9/23 1 1 Z-DENS, COMP NEU 1 1 ACOUSTIC CEMENT BOND 1 1 SCU 32g-9 SEG BOND GR 1 1 Z-DENS CA~MP NEU 1 1 DUAL IND FOCUSED 1 1 S'RU 21A-34 NEUTRON GR 1 1 INDUCT GR 1 1 GR 1 1 ! , , Return reciept to ARCO ALASKA, Inc. ATrN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' Gas Corn C0mml~sl0a ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSM1TrAL g423 TO:. Commissioner FROM: Scott Jepsen COMPANY: AOGCC DATE: 8/28/1990 COMPANY: ARCO Alaska, Inc WELL NAME: Listed below Transmitted herewith are the following Blue Sepia Sepia A ¢.~ - 5-0 - i 7~ $ _.-- / O / ? /.- 0 1 IJne Folded Rolled M~,lar Tape SRU 21A-34 Tape and listing 1 BHC Acoustilog 1 1 Compensated Neutron GR 1 1 Induction Elec GR 1 1 Collar Log 1 1 Acknowledgement Receipt ~.~7~.~. {(/, c..,, Remm reciept to ARCO ALASKA, Inc. ATTN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' May 10, 1990 Telecopy.. (907)276-7542 P. J. Archey Area Drilling Engineer ARCO Alaska, !nc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Swanson River Unit 2IA- 34 ARCO Alaska, -!nc. Permit No. 90-59 Sur. Loc. 655'FNL, !977'~.~L, Sec. 34, TSN, R9W, SM. Btmho!e Loc. 990'F~, 861'~,P~, Sec. 34, TSN, R9W, SM. Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The parmit to drill does not e×~mpt you from obtaining additional oerm~.ts required by law from other governmental agencies, and does not authorize conductzng dr~.llzng operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. BY O~ER OF THE CO~-~%SSIOlq dlf Enclosure cc: DeDartment of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASr~, OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 ! la. Type of Work Drill __ Redrill X I lb. Type of Well Exploratory. Stratigraphic Test Re-Entry ~ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 154', Pad 134' GL feet Swanson River Unit 3. Address 6. Property Designation Hemlock P. O. Box 100360, Anchorage, AK 99510-0360 A-028406 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 655' FNL, 1977' FWL, Sec. 34, TSN, Rgw, SM Swanson River Unit Statewide Al top of productive interval 8. Well number Number 955' FNL, 977' FWL, Sec. 34, T8N, R9W, SM 21A-34 #UG30610 At total depth 9. Approximate spud date Amount 990' FNL, 861' FWL, Sec 34, TSN, R9W, SM 6-9-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) properly line (SCU) SRU 12-34 @ TD 11182' MD @TD 1697' 1005 Feet 7900 Acres 10850' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 8575 feet Maximum hole an~le 35.5 Maximum sudace 3415 psis] At total depth (TVD) 4500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD TVD IVD TVD (include stac~e data) 7" mixe¢ mixed* BTC 0 0 8575 8575 Existing 6" 5" 18.0# N-80 FL4S 2888' 8300' 8300 11,182' 10,850' 300 sx Class G + additives 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11065 ' MD feet Plugs(measured) Plug @ 10309' w/150 sx Class G true vertical 11065' TVD feet (Pkr @ 10579', 100 sx below, 50 sx above) Effective depth: measured 10309' MD feet Junk(measured) None true vertical 10309' TVD feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 11' 22" Cemented 33' MD 33' TVD . Surface 3308' 1 1-3/4 1850 sx Class G 3030' MD 3030' TVD Production 11034' 7"* 1850 SX Class G 11056' MD 11056' TVD * see attached shematic for weights and grades for 7" production casing. Perforation depth: measured None open to production true vertical None open to production 20. Attachments Filing fee ~ Property plat X BOP Sketch ~ Diverter Sketch ~ Drilling program Drilling fluid program X Time vs depth plot ~ Refraction analysis __ Seabed repeal _ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~,~ .,._~, ~...~..~.-,,?/ Title Area Drilling Engineer Date .~/"~---//~-.~ ~ Commission Use Only Permit Number APl number Approval date 0 5 / 1 0 / 9 0 ~'('~-- 5.~ 50-/,.,~ ~' -/O l 7 / --O 1 other requirements Conditions of approval Samples required __Y e s ~ N o Mud log required ~ Ye s ~N o Hydrogen sulfide measures~ Yes ,~ N o Directional survey required ,z~_Yes ~ N o Required working pres..s,u~ for B(j;;~E ~-------~M; _ ~ 3 M; ..~ 5 M' ~ 1 0 M' ~ 1 5 M ~ / /, ~ '~. ~-- " by order of Approved by ,,- Commissioner the commission Date Form 10-401 Rev. 7-24-89 ! q triplicate SRU 21A-34 SIDETRACK AOGCC SUMMARY' The following procedure outlines the planned work to sidetrack the SRU 21-34 well (which has been temporarily abandoned) as SRU 21A-34 and complete the well in the Hemlock formation. The procedure includes cutting a 60 foot section in the existing 7" casing at 8575'+ and then sidetracking from the original wellbore using conventional methods. The well will be drilled to a total measured depth of approximately 11,182'. The new wellbore is planned to step out 1165' (horizontal departure) in the W-SW direction in an angle build and hold type trajectory with a maximum inclination angle of .+,. 35-1/2 degrees. Following the sidetrack, a 5" liner will be run and cemented in place. Actual completion procedures will be determined after well logs are evaluated. Anch0ra,(F¢ SRU 21A-34 SIDETRACK General Procedure o . Move in rig and rig up. Ensure well is dead, ND tree, NU BOPE, and test same. Build hi-vis mud system suitable for section milling. . PU 3-1/2" drill pipe and GIH w/ 6" bit and 7" 29# casing scraper to PBD = 9,000'+. Test casing to 3,000 psi. Displace casing w/ hi-vis mud system suitable for section milling and POH. 4. RU electric line and set EZSV @ 8,800% wlm. 5. GIH w/ Tri-State Metal Muncher section mill for 29# 7" casing. 6. Cut 60' section f/+ 8,575' - 8,635'. POH. . GIH open ended and spot cement plug f/ PBD - 8,325'+. PU above TOC, close rams, and squeeze 3 + bbls cmt into formation if possible. Open preventers and POH. . GIH w/ 6" bit and dress off kick-off plug to 10' below top of casing section. POH. . Sidetrack the well out of the casing, section building angle @ 3 degrees / 100' per the attached directional plat. TD=10,850' TVD, 11,182' MD. Ramp angle = 35-1/2 + degrees. 10. Log open hole and make any additional necessary rat hole on the conditioning trip prior to running casing. 11. Run 5" production liner and cement same. 12. Clean out to TOL and test same to 3,000 psi. 13. Clean out inside of liner and retest to 3,000 psi. 14. Run cased hole log, GR-CCL-CET. SRU 21A-34 SIDETRACK General Procedure (Continued) 15. Perforate w/ TCP. POH and LD drill pipe. 16. Run completion assembly. 17. ND BOP's, NU tree, and test same. 1 8. RD and MO rig. 19. Displace annulus w/ packer fluid and turn well over to Production Supervisor. SRU 21A-34 SIDETRACK Drillinq Information DRILLING FLUIDS PROGRAM From sidetrack point tO Total Depth Density PV YP Viscosity Initial gels 10 minute gels Filtrate APl pH % Solids 9.5 - 11.0 15 - 18 10- 15 40 - 55 5-10 10- 15 4-8 9-10 10 - 20 DRILLING FLUID SYSTEM As per attached Schematic of the Grace 154 drilling fluid system -Dual tandem shale shakers -Mud Cleaner -Centrifuge -Degasser -Pit level indicators (visual and audio alarm) -Trip tank -Fluid flow sensor -Fluid agitators Drillng practces will be in accordance with the appropriate regulations stated in 20AAC25.033. CASING PROGRAM As per current and proposed schematics which are attached. Casing Size Weight Grade Connections Status Production 7" Mixed * Mixed * Liner 5" 1 8# N-80 FL4S In place New * See schematics CEMENT SLURRIES 5" Liner - Calculated for cement from 8300' MD to 11,1182' MD.. 300 sx Class "G" with additives mixed at 15.8 ppg. Yield = 1.15 cu ft/sk. Volume above based on 100% excess in open hole section and 80' of plug back. GEOLOGIC INFORMATION b. Geologic Surface Location - Pleistocene gravel. Markers (Will not be encountered on this Name TOp 'E' Marker 8,650' TVD 'H' Marker 10,328' TVD sidetrack.) Co Tops and bottoms of anticipated formation (since this is a sidetrack from 8575' MD no surface formations will be encountered) Name Content TOp TVD Bottom TVD Pressure 'G' Sands Water 10,510' 10,600' 9.0 ppg EMW Hemlock Oil,gas 10,650' 10,850' 8.12 ppg EMW MAXIMUM ANTICIPATED SURFACE PRESSURE Maximum anticipated surface pressure is estimated by a very conservative approach of assuming bottom hole pressure (minus a gas gradient) at surface during production. Anticipated bottom hole pressure is 4500 psi (@ 10,850' TVD). Subtracting a 0.1 psi/ft gas gradient gives 3415 psi at surface. In the worse case scenario, this pressure would be applied on top of a full annulus of 9.5 ppg packer fluid during a tubing leak after the will is put on production (assuming the well is not being gas lifted.) The 7" production casing burst specifications exceed this worse case scenario at all depths. (See attached well schematic showing casing grades and setting depths.) ARCO Alaska Inc. is proposing BOP tests to 4500 psi to cover the conservative approach of assuming bottom hole pressure at surface. PRESSURE CONTROL EQUIPMENT The pressure control equipment will be as per the attached schematics. Also, the following should be noted: a. The tubing spool top connection will be a 7-1/16" 5000 psi flange. There will be hand wheels provided on the BOPE as a backup for closing them. The accumulator system is a Valvcon, 90 gallon, 4 station system. IT has one set of remote controls in the rig floor doghouse and one set of controls in the accumulator/generator house. PROJECT DURATION Work on the project is expected to commence on or about June 11, 1990 and should be completed on or about July 16,1990. Bottom Hole Location __ 990' ~86i ' .~~._ FNL FWL 1977' { ,s~ u- ~,- ~4 "l i 1 1 TSN e- TTN 7 8 9 I0 18 { 17 16 15 ! I I I I I I 14 I m SCALE: I"= I MILE 24 CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered and licensed to practice land surveying in the State of Alaska and that this plot represents o proposed drilling location. Dimensions and other details furnished by Arco-Alaska Inc. ' Date Surveyor PROPOSED SIDETRACK S~U - 2 I-A34 Located in Sec. 54, T. 8 N., R. 9 W., S.M., Alaska for ARCO ALASKA INC. P.O. BOX 100560 ANCHORAGE, AK. 99510-0560 by R.C. DAVIS ~ ASSOC. LAND & MINERAL SURVEYORS 14870 SNOWSHOE LANE ANCH.,AK. 99516 SCALE ! ', 200FT. #OTE, COORDI,#ATE9 RELATIVE TO SLOT 2O00 TYD e57~~8575. 0'0' 0.00 ~C. 9?05 LHO~9779. 35'22' 352.33 ~C. 1~~~~ 3 · ' 0 20OO V.gECTZON PLANE~ 373' 18'1~ PROPOSAL ~ P00834. OAR ARCO ALASKA, SRU 21-34 SCALE I't2OOOFT. k~q.L, 21'34 ~I. OT, ! CURRENT WELLBORE ~¢HEMATI(;:: SRU 21-34 All Depths Measured Cement ~, 22" @ 33' 11-3/4' @ 3030' 7" Detail 29# N-80 23# N-80 26# N-80 29# N-80 29# P-110 TOC @ 10,309' 50 sx Class G PACKER @ 10,579' 100 sx Class G PBTD -- 10,966' 7" @ 11,056' TD = 11,065" 0'- 47' 47'- 4,794' 4,794' - 6,701' 6,701' - 8,513' 8,513' - 11,056' PROPOSED WELLBORE SCHEMATIC SRU 21A-34 All Depths Measured cement 22' @ 33' 11-3/4" @ 3030' 7" Detail 29# N-80 23# N-80 26# N-80 29# N-80 29# P-110 0' - 47' 47' - 4,794' 4,794' - 6,701' 6,701' - 8,513' 8,513' ~ 11,056' Top of 5" liner = +/- 8300' Top of 7" Section @ 8575' PBD = +/- 11,100' 5" liner @ 11,182' 3-518" 5000 PSI BOP STACK DIAGRAM ACCUMULATOR CAPACITY TEST ! I REYENTER~ I PI PE RAHS BLI ND RAHS DRILLING SPOOL PIPE RAMS I TBG SPOOL 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. o . 10. 11. 12. STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN LOCK-DOWN SCREWS IN HEAD. 3. OPEN CASING VALVE(S) ON TUBING HEAD. (MONITOR CASING VALVE FOR FLOW THROUGH OUT BOP STACK TEST). 4. CLOSE ANNULAR PREVENTER AND TEST TO 250 AND 4,500 PSI FOR 10 MINUTES. BLEED TO ZERO. 5. OPEN ANNULAR AND CLOSE TOP PIPE RAMS. TEST TOP PIPE RAMS, CHOKE MANIFOLD VALVES, AND STACK VALVES TO 250 AND 4,500 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN TOP PIPE RAMS AND CLOSE BO'FrOM PIPE RAMS. TEST TO 250 AND 4,500 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 7. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 250 AND 4,500 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN PIPE RAMS. CLOSE CASING VALVE(S) AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF A NON-FREEZING LIQUID AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 250 AND 4,500 PSI. TEST KELLY COCKS AND INSIDE BOP TO 250 AND 4,500 PSI. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. FUNCTION TEST BLIND RAMS EACH TIME OUT OF THE HOLE. ALL BOP EQUIPMENT 5000 PSI RATED GRAC~,q~ILLING ~OMPANY - RIG #I54 10,000# CHOKE MANIFOLD IN SKIDDED HOUSE TO PITS/GAS BUSTER TO RESERVE PIT {1)' !0,000# LINE. FROM BoPs (2) 10,000# CROSS (3) 4" 10,000# VALVES (4) 3" 10,000# VALVES (5) 10,000~ HYDRAULIC CHOKES (6) 3" 50005 VALVES (7) 3" x 5000# CROSS (B) 3" x 5000# LINES (9) 4" x 5000# LINES Grace 154 Drilling Fluids System I I n I ! t I I I I t~ , ' I i I I · i i m i i i i · il II ! · 11 . .. i I I I I CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) ~ee ~./C (2) Loc _ :/~hru 8) (8) ('9 -thr'~ "13 (10 and 13) (4) Casg '~~.-~. ~- 7-~o (14 thru 22) 1. IS 2. Is 3. Is 4. Is 5. Is 6. Is 7. 8. . 10. 11. 12. 13 14. 15. (5) BOPE (23 thru 28) 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company ~.ease & Well YES NO the permit fee attached .......................................... well tG be located in a defined pool ............................. well located proper distance from property line .................. well located proper distance from other wells .................... sufficient undedicated acreage available in this pool ............ well to be deviated and is wellbore plat included ................ Is operator the only affected party ..... ............................ Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... _~ Does the well have a unique name and number . Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~'0~ psig .. ~ ' , Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) thru- 3'1) .Geology: Engi. n.eering: -:~-.;"( BEW rev: 01/30/89 6.011 For 29. ~0. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. .,×//. :f, / / INITIAL GEO. UNIT I ON/OFF POOL CLASS STATUS AREA NO.t SHORE Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIx. .. No special'effort has been made to chronologically organize this category of information. -.. · .. PROGRAM: LIS ' REVISION: 4.1 PART NUMBER: W5550-MICRO Start of execution: Thu 16 AUG 90 4:51pm WELL DATA FILE: C:\CLIFF\W04505.WDF ECC: 4505.00 COMPANY NAME: WELL NAME: FIELD: LOCATION: ARCO ALASKA INC. SRU ~ Top of Well: Bottom of Well: Level Spacing: 10700.000 11190.000 0.500 NUMBER OF CURVES: 19 DEPTH A1R1 A1R2 A2R1 C24 CAL GR SP T2R2 TEN TTEN A2R2 SPD AC TlR1 ACQ TlR2 C13 T2R1 COMPANY:ARCO ALASKA INC. WELL:SRU 21-34 FIELD:SWANSON RIVER COUNTY:KENAI STATE:ALASKA TAPE INFORMATION FILE:MAIN .001 FILE INTERVAL: START= 11190.000 END= 10700.000 DEPT 11190. 000 GR SPD SP CAL -999.250 -999.250 -999.250 -999.250 TTEN -999.250 C13 -999.250 C24 -999.250 AC -999.250 11165.000 0.000 29.997 3.731 0.000 3093.956 3.948 3.514 50.000 11140.000 142.913 27.107 3.996 0.000 3656.896 4.028 3.963 83.267 11115.000 99.065 26.997 4.179 0.928 3625.981 4.176 4.181 69.420 11090.000 52.229 27.888 4.073 1.209 3614.833 4. 075 4.071 78.660 11065.000 68.160 27.997 4.089 1.030 3629.768 4. 113 4.064 80.738 11040.000 82.900 27.997 4.180 1.189 3579.506 4. 188 4.171 80.018 11015.000 81.803 27.997 4.086 1.038 3585.450 4.138 4.035 88.351 10990.000 71.999 27.997 4.018 1.319 3616.999 4.098 3.938 83.491 10965.000 10940.000 123.307 27.107 4.124 70.529 27.342 4.072 1.303 3755.090 1.077 3606.019 4. 195 4.101 4. 052 4.044 85.087 88.431 10915.000 147. 667 27. 761 4.458 1.168 3785.185 4.490 4.425 67.103 10890.000 62.145 27.997 4.477 1.005 3603.020 4.284 4. 670 249.975 10865.000 57.858 27.997 4.422 1.085 3555.144 4.252 4.593 241.966 10840.000 64.444 27.342 4.561 1.039 3567.973 4.333 4.790 83.907 10815.000 53.692 27.997 4.255 1.127 3556.736 4.275 4.235 83.502 10790.000 59.268 27.997 4.239 0.929 3504.814 4.237 4.241 151.233 10765.000 67.486 27.997 4.263 0.987 3492.475 4.279 4.248 134.606 10740.000 38.980 0.000 1.100 0.000 2.000 2.000 98.258 2.000 10715.000 0.000 0.000 1.384 0.000 2.000 2.000 50.000 2.000 10700.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 WELL DATA FILE: ECC: C: \CLIFF\W04506.WDF 4506.00 COMPANY NAME: WELL NAME: FIELD: LOCATION: Top of Well: Bottom of Well: Level Spacing: ARCO ALASKA INC. SRU 21-34 10970. 000 11170. 000 0.500 NUMBER OF CURVES: 19 DEPTH A1R1 A1R2 A2R1 A2R2 C24 CAL GR SP SPD T2R2 TEN TTEN AC ACQ C13 TlR1 TlR2 T2R1 FILE:REPEAT.002 FILE INTERVAL: START= 11170.000 END= 10970.000 DEPT GR SPD SP CAL TTEN C13 C24 AC 11170.000 0.000 0.000 2.000 0.000 0.000 2.000 2.000 50.000 11145.000 0.000 30.356 4.068 0.000 3652.988 4.035 4.100 72.305 11120.000 113.728 27.094 4.149 11095.000 53.171 3.975 29.997 2.090 3631.678 4.147 3648.779 4.125 4.173 79.615 4.070 3.881 84.095 11070.000 57.904 29.567 4.127 2.733 3674.810 4. 130 4. 124 78. 710 11045.000 72.650 26.549 4.156 -0.633 3616.725 4.169 4.143 86.374 11020.000 97.310 25.081 4.826 3598.241 4.181 4.122 80.792 4. 151 10995.000 66.275 4.157 10970.000 -999.250 -999.250 10970.000 -999.250 -999.250 WELL DATA FILE: ECC: COMPANY NAME: WELL NAME: FIELD: LOCATION: Top of Well: Bottom of Well: Level Spacing: 26.991 3.258 3611.346 4.156 4.157 84.242 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 C:\CLIFF\W04507.WDF 4507.00 ARCO ALASKA INC. SRU 21-34 10780.000 11190.000 0.500 NUMBER OF CURVES: 14 DEPTH CN CNC SN SP SPD CNRA COND GR SSN TEN TTEN LSN RT FILE:MAIN .003 FILE INTERVAL: START= 11190.000 END= 10780.000 DEPT GR TTEN 11190.000 -999.250 -999.250 11165.000 0.000 2797.619 11140. 000 142.913 _3339.741 11115.000 99.065 3325.360 11090.000 52.229 3327.731 11065.000 68.160 3308.626 SPD -999.250 35.743 30.997 30.997 30.997 30.997 CN -999.250 0.000 16.270 16.219 10.845 14.597 CNC -999.250 0.000 26.049 25.987 19.428 24.027 SP -999.250 1.814 1.527 1.441 1.432 1.623 SN -999.250 9.900 12.141 13.110 28.480 25.784 RT -999.250 7.044 5.099 9.494 4.957 5.280 11040.000 82.960 3294.144 30. 997 16. 910 26. 817 1. 564 26. 469 8. 546 11015. 000 81. 803 30. 997 18. 447 3276.667 10990.000 71.999 30.997 14.436 3276.302 10965.000 123.307 30.997 19.308 3247.588 10940.000 70.529 30.761 15.056 3234.207 10915.000 147.667 30.342 18.746 3254.613 10890.000 62.145 30.997 20.368 3244.718 10865.000 57.858 30.997 20.968 3259.513 10840.000 64.444 30.997 20.695 3206.449 10815.000 53.692 30.997 31.525 3211.325 10790.000 59.268 0.000 .0.000 0.000 10780.000 -999.250 -999.250 -999.250 -999.250 WELL DATA FILE: C:\CLIFF\W04508.WDF ECC: 4508.00 COMPANY NAME: WELL NAME: FIELD: LOCATION: ARCO ALASKA INC. SRU 21-34 Top of Well: Bottom of Well: Level Spacing: 10800.000 11190.000 0.500 28.652 23.832 29.672 24.583 29.007 30.922 31.627 31.306 43.640 0.000 -999.250 1.537 1.420 1.567 1.510 1.595 1.440 1.398 1.472 1.538 0.000 -999.250 28.587 42.486 12. 691 39.077 8.893 8. 181 8.582 7.257 0.085 0.000 -999.250 7.198 18.215 9.075 41.182 7.070 7.735 7.560 6.217 36.496 0.000 -999.250 NUMBER OF CURVES: 14 DEPTH CN CNC CNRA SN SP SPD SSN COND TEN GR TTEN LSN RT FILE:REPEAT.004 FILE INTERVAL: START= 11190.000 END= 10800.000 DEPT GR TTEN 11190.000 -999.250 -999.250 11165.000 0.000 2847.506 11140.000 142.913 3359.053 11115.000 99.065 3344.172 11090.000 52.229 3338.708 11065.000 68.160 3317.004 11040.000 82.900 3312.482 11015.000 81.803 3305.364 1099o. O00 71.999 3296.878 10965.000 123.307 3264.707 10940.000 70.529 3259.964 10915.000 147.667 3275.447 10890.000 62.145 3258.779 10865.000 57.858 3244.875 10840.000 64.444 3225.636 10815.000 53.692 0.000 10800.000 -999.250 -999.250' SPD CN CNC SP SN RT -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 31. 409 14. 715 24. 170 1. 259 9. 956 6. 848 30.997 16.287 26.068 1.165 11.965 4.968 30. 997 16. 265 26. 043 1. 307 13 . 129 9 . 131 3'1.997 10.583 19.103 1.164 27.285 5.294 30.997 15.074 24.605 1.320 25.173 5.244 30.997 17.095 27.039 1.204 26.381 8.712 30.997 18.000 28.119 1.315 28.302 7.959 30.997 15.217 24.778 1.232 42.162 16.258 30.997 18.363 28.552 1.270 13.531 10.629 30.997 14.402 23.791 1.162 39.299 40.523 30.997 19.947 30.426 1.144 8.896 7.581 30.997 19.846 30.307 1.297 8.075 8.258 30. 997 20. 620 31. 218 1. 332 8. 514 7. 713 30.997 22.572 33.498 1.162 7.330 6.380 0.000 0.000 0.000 0.000 0.000 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 End of execution: Thu 16 AUG 90 4:51pm