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185-311
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: G/L Completion Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,250 feet 11,166 feet true vertical 10,083 feet N/A feet Effective Depth measured 11,003 feet 9,894 feet true vertical 9,867 feet 8,921 feet Perforation depth Measured depth 10,024 - 10,900 feet True Vertical depth 9,033 - 9,777 feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5 / L-80 9,972 MD 8,988 TVD 9,894 (MD) 348 (MD) Packers and SSSV (type, measured and true vertical depth)DLH Pkr 8,921 (TVD) NE TRSV SSSV 348 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD measured true vertical Packer 9-5/8" 7" 9,841 MD 3,069 11,250 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 400 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-311 50-733-20373-01-00 Plugs ADL0017594 Trading Bay Unit D-43RD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-074 160 Authorized Signature with date: Authorized Name: 520 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 76 Gas-Mcf 40 N/A Oil-Bbl 0 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 59 McArthur River Field / Middle Kenai G and Hemlock Oil PoolsN/A measured 9,841 Size 976 Production Casing Structural Liner 1,707 Length 3,069 Conductor Surface 7,020psi 4,760psi 13-3/8" 907 777-8384 6,870psi 2,907 8,887 10,083 Collapse Karson Kozub kkozub@hilcorp.com Tubing Pressure 1,950psi3,450psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,160psi Daniel E. Marlowe Operations Manager Burst PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:57 pm, Aug 25, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.08.25 10:04:37 -08'00' Dan Marlowe (1267) RBDMS HEW 8/27/2020 DSR-8/27/2020 (pull ESP run G/L) SFD 8/28/2020 mbell gls 10/23/20 Oil G/L Completion Updated 08/25/20 by JLL SCHEMATIC McArthur River Field, TBU Well: D-43RD Completed: 08/09/2020 API: 50-733-20373-01 PTD: 185-311 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 68 K-55 Butt 12.415” Surf 3,069' 9-5/8" 47 N-80 Butt 8.681” Surf 9,409’ P-110 8 round 8.681” 9,409’ 9,841’ 7" 29 N-80 Butt 6.184” 9,543' 11,250' TUBING DETAIL 2-7/8” 6.5 L-80 8 round EUE 2.441” Surf 9,972’ TD = 11,250’ PBTD = 11,166’ 1 2-10 11 G-4 12 HK-3 13 C/O to 11,003’ on 5/4/17 G-4A Devi = 31° (10,600’) G-2 G-4 HK-1 HK-2 HK-4 X HK-2A HK-5 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 348’ 348’ 2.313 4.625 NE TRSV SSSV 2 2,818’ 2,703’ 2.441 4.500 GLM #1 –PSPO 1-0 w/1” valves, BK Latch 3 4,811’ 4,412’ 2.441 4.500 GLM #2 –PSPO 1-0 w/1” valves, BK Latch 4 6,064’ 5,502’ 2.441 4.500 GLM #3 –PSPO 1-0 w/1” valves, BK Latch 5 6,740’ 6,091’ 2.441 4.500 GLM #4 –PSPO 1-0 w/1” valves, BK Latch 6 7,357’ 6,637’ 2.441 4.500 GLM #5 –PSPO 1-0 w/1” valves, BK Latch 7 7,971’ 7,184’ 2.441 4.500 GLM #6 –PSPO 1-0 w/1” valves, BK Latch 8 8,582’ 7,742’ 2.441 4.500 GLM #7 –PSPO 1-0 w/1” valves, BK Latch 9 9,257’ 8,368’ 2.441 4.500 GLM #8 –PSPO 1-0 w/1” valves, BK Latch 10 9,840’ 8,875’ 2.441 4.500 GLM #9 –PSPO 1-0 w/1” valves, BK Latch 11 9,894’ 8,921’ 3.000 2.875 Packer –DLH pinned 46k shear release 12 9,938’ 8,959’ 2.313 2.875 X-Nipple 13 9,972’ 8,988’ 2.441 3.000 WLEG PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amount SPF Date Comments G-2 10,024' 10,048' 9,033' 9,053' 20' G-4A 10,272' 10,282' 9,242' 9,250' 10' G-4A 10,192' 10,206' 9,175' 9,186' 14' G-4A 10,149' 10,169' 9,138' 9,155' 20' HK-1 10,460' 10,492' 9,400' 9,427' 32' HK-2A 10,455’ 10,487’ 9,396’ 9,423’ 32’ 5 05/08/17 HK-2 10,515’ 10,590’ 9,477’ 9,511’ 75’ 04/02/17 HK-2 10,516 10,587’ 9,448’ 9,508’ 71’ 05/08/17 HK-2 10,522 10,530 9,453 9,460 8’ 6 10/17/15 Open HK-3 10,604’ 10,687’ 9,523’ 9,593’ 83’ 5 05/08/17 HK-3 10,604' 10,696' 9,523' 9,601' 92' HK-4 10,698 10,718 9,603 9,620 20’ 6 10/17/15 Open HK-3 & HK-4 10705’ 10,837’ 9,609’ 9,722’ 132’ 5 05/08/17 HK-4 10,711’ 10,727’ 9,614’ 9,628’ 16’ 04/02/17 HK-5 10,875’ 10,900’ 9,755’ 9,777’ 25’ 5 05/08/17 SSSV Rig Start Date End Date HAK 404 7/31/20 8/9/20 07/31/20 - Friday Daily Operations: Hilcorp Alaska, LLC Well Op erations Summary API Number Well Permit Number 50-733-20373-01 185-311 Well Name D-43RD 08/01/20 - Saturday PTSM. Cont. organize decks, & circ well. S/d after circulating 2 hole volumes. Mobe AAO crews to platform, orientate same. Unload boat w/draworks, BOPE & misc. overpacks w/ eq. Cont. moving eq. on deck. Put mast & carrier on boat & prep rig beam package for dismantling & spotting over well center D-43rd. Remove landing & stairs to east side crane. Assemble beam package over D-43rd. Prep deck to offload boat. Offload from the boat & install carrier, drawworks, & derrick. Off load misc. equipment from boat. Prep mast to raise. 08/03/20 - Monday Finish wiring up test pump, shell test BOPE w/ 2 7/8" TJ 250/2500 on annular, 250/3500 on rams. Cont. rigging up gas detection system & trouble shoot alarm lights, tie into platform system, continue work on rig punch list & housekeeping. Test BOPE as per Hilcorp & AOGCC requirements, test was witnessed by AOGCC inspector Adam Earl, tested with 2 7/8" & 3 1/2" TJ, 250/2500 annular, 250/3500 on all other eq. Rig down test equipment, blow down lines, & align valves. Pump down tubing to fill w/ 55 bbls at 1.5-3 bpm to catch pressure. Rig up & pull BPV. Line up to pump down the tubing to circulate IA clean. Pump 223 bbls to see returns at 1.5-4 bpm 0-800 psi. Shut down for 5 minutes & re-establish circulation to determine loss rate at 82 bph. Continue to circulate IA clean at 3.5-4 bpm, 800 psi, pumped total of 540 bbls. Make up landing joint to hanger & BOLDS. Pull hanger off seat with PU 80K. Packer pull free with PU 160K. Pull hanger to the rig floor w/ PU 120K. Rig up Summit & prep hanger to lay down. Lay down hanger & landing joint. Continue pulling from 9000' - 8647' MD, PU 115K. Cont. Prep mast & raise, spool up drill line, string out guy lines, adjust "A" leg. L/d mast, unload mud pit & spot same. String out circ. lines, circulate well to well clean tank, shut down & monitor tubing & annulus. Went on vac. test void t/3600 good, monitor well good. Install BPV. N/D SSV, flow line & tree. Prep Hanger & install blanking sub. Unload boat and stage equipment. Nipple up stack, work the boat, dress mud pump, torque up stack flanges. Continue torque up of stack flanges, set Driller's dog house, raise mast & scope, secure lines. 08/02/20 - Sunday Center blocks, secure mast, r/u floor. R/u FIW t/ pump & pits. Install hand rails over base beams. Install kill line t/ mud manifold. Finish r/u choke & kill lines, install stairs & hand rails on rig floor. R/u weight indicator, spot remote panel in driller dog house, install fittings on BOPE stack, install beaver slide, r/u super choke panel. Run and connect accumulator lines, function test BOPE. RU air to the Super Choke, rig up floor tools, function test mud pump, mobilize XOs for test joints, perform derrick inspection, rig up test pump & chart. Make up t est joints & function test Super Choke. Continue rigging up test equipment & lines. Flood lines & purge. shell test BOPE w/ 2 7/8" TJ 250/2500 on annular, 250/3500 on rams. Install BPV. N/D SSV, flow line & tree. Line up to pump down the tubing to circulate IA clean. Pump 223 bbls to see returns at 1.5-4 bpm 0-800 t BOPE as per Hilcorp & AOGCC requirements, test was witnessed by AOGCC inspector Adam Earl, Pull hanger off seat with PU 80K. Packer pull free with PU 160K. Rig Start Date End Date HAK 404 7/31/20 8/9/20 Daily Operations: Hilcorp Alaska, LLC Well Op erations Summary API Number Well Permit Number 50-733-20373-01 185-311 Well Name D-43RD 08/05/20 - Wednesday Prep floor t/ l/d ESP assy. POOH lo/d last joint w/xo, ported sub & discharge head, 3- ea pump assy, intake & 2-ea seal assy, 2- mtrs, Guage & cent/Anode, observed no abnormalities in assy. Clean & clear floor, l/d ESP handling tools, c/o handling tools. P/U, BHA - 6" bit, 7" casing scraper, Bit sub= 5.89'. TIH p/u 2 7/8" 6.5# l-80 eue 8rd tubing from surface to 1260' MD, SO 12K. TIH p/u 2 7/8" 6.5# l-80 eue 8rd tubing from 1260' - 4907' MD, PU 29K, SO 25K. Service drawworks, motor / transmission, & handling equipment. TIH p/u 2 7/8" 6.5# l-80 eue 8rd tubing from 4907' - 7835' MD, PU 45K, SO 35K. 08/06/20 - Thursday TIH p/u 2 7/8" 6.5# l-80 eue 8rd tubing f/7835' t/10,031', PU 54K, SO 42K. Wipe from 9800-10031' 4x, drifted clean through liner top. POOH standing back 2 7/8" completion tubing, t/8354, up wt 47k, dn wt 37k,Cont. POOH standing back 2 7/8" completion tubing, l/d BHA. Clear & clean rig floor. Pick up 2-7/8" EUE gas lift completion jewelry; WLEG, 1 joint tubing, X- nipple, 1 joint tubing, 7" packer, 1 joint tubing, & GLM to 133' MD. Run 2-7/8", 6.5#, L-80, EUE 8RD tubing f/ 133' - 1963' MD, SO 14K, as per tally. Service drawworks, motor / transmission, & handling equipment. Run 2-7/8", 6.5#, L-80, EUE 8RD tubing f/ 1963' - 3826' MD, PU 24K, SO 22K, as per tally. Run 2-7/8", 6.5#, L-80, EUE 8RD tubing f/ 3826' - 9047' MD, PU 48K, SO 38K, as per tally. 08/04/20 - Tuesday Cont. POOH from 8647' t/7276' w/3 1/2" 9.2#, L-80 supermax completion, removing clamps & looking for any abnormality in cable while pulling. up wt 80k, l/d 49 jts total. Cont. POOH from 7276' t/5490' w/3 1/2" 9.2#, L-80 supermax completion, removing clamps & looking for any abnormality in cable while pulling. up wt 60k, l/d 101 jts total. Cont. POOH from 5490' t/3860' w/3 1/2" 9.2#, L-80 supermax completion, removing clamps & looking for any abnormality in cable while pulling. up wt 46k, l/d 149 jts total. Service rig. Cont. POOH from 3860' t/2982' w/3 1/2" 9.2#, L-80 supermax completion, removing clamps & looking for any abnormality in cable while pulling. up wt 38k, l/d 174 jts total. Cont. POOH from 2982' t/231'' w/3 1/2" 9.2#, L-80 supermax completion, removing clamps & looking for any abnormality in cable while pulling. up wt 13k, l/d 256 jts total. . POOH from 8647' t/7276' w/3 1/2" 9.2#, L-80 supermax completion, POOH standing back 2 7/8" completion tubing, Prep floor t/ l/d ESP assy. POOH Rig Start Date End Date HAK 404 7/31/20 8/9/20 Daily Operations: Hilcorp Alaska, LLC Well Op erations Summary API Number Well Permit Number 50-733-20373-01 185-311 Well Name D-43RD Cont. RIH w/ 2 7/8" 6.5# l-80 eue 8rd G/L completion. M/u landing jt & hanger, m/u control line penetration for SSSV, land hanger, up wt 53k, dn wt 48k placing tail @ 9930'. Run in l/d pins, & pak off hanger. Drop prong & pressure up to set packer t/3450 psi, hold 30 min on chart good, setting packer @ 9863'. R/U & fill annulus & r/u, t/ test t/ 2100 psi f/ 30 min good. R ig down test equipment. R/U w/l, RIH retrieve Prong @ 9897', pull out and lay down Prong. Rig up GS tool to retrieve plug. RIH to 5668' WLM, unable to drift past, make several attempts t o get by with no success. POOH. RIH with a 2.25" LIB to 5668' WLM, POOH. RIH w/ a 2.3" guage ring to 5668' WLM, nogo, POOH. Discuss options with engineering, decision made to pull completion, find compromised tubing replace packer & re-complete. RIH w/ a 2.1" gauge ring to 6687' WLM, nogo, POOH. Rig down slick line. Nipple down flange to raise stack & riser to cut SSSV control line for shell test. Unable to lift riser due to clearance issues in well bay. Torque up flanges & secure stack. Push control line down past annular for closure. Perform shell test with annular to 250 / 3500 psi for 5 minutes each, charted. Rig up handling equipment & prep to pull 2- 7/8" completion. Pull hanger of seat at 40K & packer free at 88K. Pull hanger to rig floor w/ 60K. Lay down hanger, landing joint & FOSV. TOH w/ 2-7/8", 6.5#, L-80, 8RD EUE tubing from 9886' - 4875' MD. PU 29 K, racking back stands & laying out jewelry as per tally. Total of 280 bbls to fill IA for returns. 72 bph losses while TOH. 08/08/20 - Saturday Cont. POOH w/ 2-7/8", 6.5#, L-80, 8RD EUE tubing from 4875' t/4249', racking back stands & laying out jewelry as per tally. Found over torqued connection, l/d 2- singles & p/u replacement joints. R/U w/l rih with 2.3" drift, made 962' tagged up. R/d W/L. Cont. POOH w/ 2-7/8", 6.5#, L-80, 8RD EUE tubing from 4249't/3262', racking back stands & laying out jewelry as per tally. Found a damaged joint, changed it out. R/U w/l, RIH with 2.3 drift t/tubing to plug @ 3228', good. R/d wireline. Cont. POOH w/ 2-7/8", 6.5#, L-80, 8RD EUE tubing from 3262', racking back stands & laying out jewelry as per tally. L/d packer, inspected RHCP plug, good. C/O WLEG. RIH w/ 2 7/8", 6.5#, L-80, 8RD EUE, G/L completion, drifting from derrick w/2.347 drift from surface to 2382' MD, PU 15K, SO 15K. Service drawworks / transmission, blocks & handling equipment. Level rig over hole. RIH w/ 2 7/8", 6.5#, L-80, 8RD EUE, G/L completion, drifting from derrick w/2.347 drift from 2382' - 6137' MD, PU 34K, SO 28K. Loss rate ~ 60 bph. RIH w/ 2 7/8", 6.5#, L-80, 8RD EUE, G/L completion, drifting from derrick w/2.347 drift from 6137' - 9929' MD, PU 54K, SO 39K. Loss rate ~44 bph. Rig up & wire line w/ 2.30" gauge ring to 9928' WLM, POOH & rig down wire line. 08/07/20 - Friday (CMIT) 2nd run on completion.... Found a damaged joint, changed it out. Cont. RIH w/ 2 7/8" 6.5# l-80 eue 8rd G/L completion. Pull completion due to tubing restriction at 5668 ft fill annulus & r/u, t/ test t/ 2100 psi f/ 30 min good. Pull hanger of seat at 40K & packer free at 88K. find compromised tubing replace packer & re-complete. MIT-IA to 2100 psi C/O WLEG. RIH w/ 2 7/8", 6.5#, L-80, 8RD EUE, G/L completion, drifting from derrick w/2.347 drift from surface to 2382' MD, PU 15K, SO 15K. Service drawworks / transmission, blocks & handling equipment. Level rig over hole. RIH w/ 2 7/8", 6.5#, L-80, 8RD EUE, G/L completion, drifting from derrick w/2.347 drift from 2382' - 6137' MD, Drop prong & pressure up to set packer t/3450 psi, hold 30 min on chart good, setting packer @ 9863'. Rig Start Date End Date HAK 404 7/31/20 8/9/20 Daily Operations: Hilcorp Alaska, LLC Well Op erations Summary API Number Well Permit Number 50-733-20373-01 185-311 Well Name D-43RD 08/09/20 - Sunday M/U hanger & landing joint, make hanger penetrations w/ SSSV control line. Drain stack. Land hanger Up weight 53k, dn weight 48k, placing tubing tail @ 9973'. RILD pins & pack off hanger. Drop Prong, pressure up t/ 3470psi hold for 30 min, pressure dropped to 3000psi, set packer @ 9894'. R/U on Annulus, fill & pressure up to 2250 psi for 30 min. R/U t/ tubing & test t/2250 f/30 min good. R/U w/l, RIH retrieve prong @ 9938'. RIH & retrieve RHCP plug, r/d w/l. R/D landing joint, install BPV. Clear floor, prep & r/d floor. Prep mast and scope down. Prep t/ n/d BOPE. Unhook guide lines, unspool tuggers & drilling line, prep & lay over derrick. Nipple down BOPE and st age for move. Prep wellhead & nipple up tree. SIMOPS prep derrick for removal. Continue to nipple up tree. Test neck seals to 500 / 5000 psi for 5 minutes each, good. Test void to 500 psi for 5 minutes & 5000 psi for 15 minutes, good. Test tree to 5000 psi for 5 minutes, good. SIMOPS prep derrick for removal. Remove derrick, drawworks, A-leg, & carrier staging on boat. Prep carrier beams to move over to D-12RD. Drop Prong, pressure up t/ 3470psi hold for 30 min, pressure dropped to 3000psi, set packer @ 9894'. R/U on Annulus, fill & pressure up to 2250 psi for 30 min. Test tree to 5000 psi for 5 minutes, good. STATE OF ALASKA Reviewed By: JGr— OIL AND GAS CONSERVATION COMMISSION P.I. Supry —914 4�20 BOPE Test Report for: TRADING BAY UNIT D -43RD Comm Contractor/Rig No.: Hilcorp 404 - PTD#: 1853110 DATE: 8/3/2020 Inspector Adam Earl Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Soule/Lundale Rig Rep: Steiner/ Castine Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopAGE200811065142 Rams: Annular: Valves: MASP: 320-074 - - Type Test: [NIT 250/3500 - 250/2500 250/3500 2696. Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Upper Kelly - 0 P/F Lower Kelly Visual Alarm Time/Pressure P/F Location Gen.: P _ Trip Tank NA NA System Pressure 3050 _ _P_ Housekeeping: P Pit Level Indicators P P Pressure After Closure 1850 P PTD On Location P Flow Indicator NA - NA 200 PSI Attained 19 P Standing Order Posted _P _ Meth Gas Detector - P P._ Full Pressure Attained -__83 _ P Well Sign P H2S Gas Detector _P- - P _ Blind Switch Covers: All Stations - P DO. Rig P MS Mise 0 NA Nitgn. Bottles (avg): 4 (d,) 2300 P Hazard Sec. P _ (Valid for Coil Rigs Only) Choke Ln. Valves ACC Mise 0 NA Misc NA P/F HCR Valves 2 21/16 P FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly - 0 NA - Lower Kelly 0 ---NA Stripper Ball Type - 2 - P - Inside BOP 2 P FSV Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 NA No. Valves 10 FP Annular Preventer 1 135/8 - P Manual Chokes 1 _ P #1 Rams 1 2 7/8 x 5 1/2 - P Hydraulic Chokes 1 P_. #2 Rams I - blind P CH Misc 0 NA #3 Rams 0 NA_ #4 Rams 0 NA #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 , 21/16 P Quantity P/F HCR Valves 2 21/16 P Inside Reel Valves 0 -__ NA Kill Line Valves 2 2 1/16 P Check Valve 0 NA BOP Misc 0 NA Number of Failures: I' Test Results Remarks: CMV number 4 needed serviced, passed retest , Test Time 5 THE STATE '.ALASKA GOVERNOR MIKE DUNLEAVX Dan E. Marlowe Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Re: McArthur River Field, Middle Kenai G and Hemlock Oil Pool, TBU D -43RD Permit to Drill Number: 185-311 Sundry Number: 320-074 Dear Mr. Marlowe: 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, r WJePrice DATED this l J day of February, 2020. R13DMA P"/ FEB 14 292D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED FEB 11 020 2 % O 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑r Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: G/L Completion ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ • 185-311 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20373-01-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NIA Will planned perforations require a spacing exception? Yes ❑ No ❑✓ Trading Bay Unit D -43RD 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0017594 McArthur River Field 1 Middle Kenai G and Hemlock Oil Pools 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): 11,250 10,083 11,003 9,867 2,696 psi 11,166 NIA Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3,069 13-318" 3,069 2,907 3,450 psi 1,950 psi Intermediate Production 9,841 9-5181, 9,841 8,887 6,870 psi 4,760 psi Liner 1,707 7" 1 11,250 10,083 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,024 -10,900 9,033 - 9,777 3-112" 9.2# 1 L-80 8,843 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): D&L Oil Tools Hydroset Il Packer 1 Haliburton NE TRSV 412 (MD) 412 (TVD) & 353 (MD) 353 (TVD) 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/28/2020 OIL Q 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: Dan E. Marlowe Contact Name: Mark McKinley Authorized Title: Operations ManNgr Contact Email: minrickinley0hilcoro.com Contact PhDne: 907 777-8387 �z/p ( Z Authorized Signature Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: *4 Plug Integrity ❑ SOP Test Mechanical Integrity Test ❑ Location Clearance ❑ p� �+ tr�r f�// Other: 'qBDMSf E FED 14 2020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Rf Subsequent Form Required: 10 - '�o L_J(�k APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1 a ; �^ r _ I��18 Subml! Form and Form 10 4CCC���777###��-��_evised a!z((ihhh7 ApprfafafahNNl ed application i I�J� 1�D�t he date of approval. Attachments' Duplicate Well Prognosis Hilaoep Alaska, LLC Well Name: D -43rd API Number: 50-733-20373-01 Current Status: SI ESP Producer Leg: Leg #A-1 NE corner Estimated Start Date: February 28, 2020 Rig: HAK 404 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 185-311 First Call Engineer: Mark McKinley (907) 777-8387(0) (907) 953-2685 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 3,599 psi @ 9,033' TVD 0.398 lbs/ft (7.66 ppg) based on SBHP 05/11/17 Maximum Expected BHP; 3,599 psi @ 9,033' TVD 0.398 Ibs/ft (7.66 ppg) based on SBHP 05/11/17 Maximum Potential Surface Pressure: 2,696 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) Brief Well Summary Well D -43 d is an oil well with a comingled completion in the G and Hemlock zones. D -43rd was converted to an ESP from gas -lift in May 2017. This workover will replace the ESP that failed in August 2017 with a • gas lift completion. Last Casing Test: 05/06/2017 tested lA at 9,797' to 1,600 psig on chart for 45 minutes. Procedure: PKC 1.MIRU HAK-404. r5,0 2. Circulate hydrocarbon off of well. Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/3,500psi high/2,500 psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow the orlli io itness test). 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with completion. 6. R1H with bit and scraper to ±10,000', circulate clean, POOH. 7. PU and RIH with gas -lift assembly. 8. Set Packer/ Pressure test completion: a. Pressure up and set packer b. Test tubing against plug in X nipple to 2500# and chart for 30 minutes. c. Test IA to 2,000 psi and chart for 30 minutes (This will pressure up tubing also). d. Pull prong and plug in X -Nipple. 9. Set BPV, ND BOP, NU wellhead and test. 10. Turn well over to production. 11. Conduct SVS testing per AOGCC regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. Wellhead Schematic Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form TD =11,250' PBTD =11,166' Devi = 31' (10,600') P, -,V McArthur River Field, TBU SCHEMATICWell: D -43D CompledR t05/11/2017 API: 50-733-20373-01 PTD: 185-311 JEWELRY DETAIL No Depth (MD) Depth (TVD) CASING DETAIL OD Item 1 SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 68 K-55 Butt 12.415" Surf 3,069' 9-5/8" 47 N-80 Butt 8.681" Surf 9,409' P-110 8 round 8.681" 9,409' 9,841' 7" 29 N-80 Butt 6.184" 9,543' 11,250' 5,841' 5,308' 2.992" TUBING DETAIL GLM #4 w/ dummy valve 7 6,522' 3-1/2" 9.2 L-80 Supermax 2.992" Surf 8,843' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 1 353' 353' 2.813" 5.620" SSSV -- Halihurton NE TRSV 2 412' 412' 3.000" 8.500" Packer - D&L Oil Tools Hydroset Il w/ WFT Vent valve 3 2,464' 2,407' 2.992" 5.750" GLM #1 w/ 24 Port valve 4 3,980' 3,692' 2.992" 5.750" GLM#2w/dummy valve 5 5,028' 4,601' 2.992" 5.750" 1 GLM #3 w/ 24 Port valve 6 5,841' 5,308' 2.992" 5.750" GLM #4 w/ dummy valve 7 6,522' 5,900' 2.992" 5.750" GLM #5 w/ 24 Port valve 8 7,073' 6,387' 2.992" 5.750" GLM #6 w/ dummy valve 9 7,656' 6,903' 2.992" 5.750" GLM #7 w/ Orifice valve 10 8,208' 7,398' 2.992" 5.750" GLM #8 w/ dummy valve 11 8,756' 7,903' 2.992" 5.750" GLM #9 w/ dummy valve 12 8,804' 7,948' 2.813" 4.450" X Nipple 8,843' 7,984' N/A 5.130" Balton Discharge Head 9,453 8,844' 7,985' N/A 5.130" Triple Pump section, Summit 198 stage S.110000AR HK -3 8'915' 8,052' N/A 5.130" Intake 13 8,916' 8,053' N/A 5.130" TandemSeals -BPBSL 9,523' 8,934' 8,069' N/A 5.620" Tandem Motors --KMS 1000HP/3600V/165.5A HK -4 9,000' 8,131' N/A 5.620" Gauge (Zenith) /Centralizer/ Anode 6 10/17/15 Open HK -3 & HK -4 10705' 10,837' PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amount SPF Date Comments G-2 10,024' 10,048' 9,033' 9,053' 20' G -4A 10,272' 10,282' 9,242' 9,250' 10' G -4A 10,192' 10,206' 1 9,175' 9,186' 14' G -4A 10,149' 10,169' 9,138' 9,155' 20' HK -1 10,460' 10,492' 9,400' 9,427' 32' HK -2A 10,455' 10,487' 9,396' 9,423' 32' 5 05/08/17 HK -2 10,515' 10,590' 9,477' 9,511' 75' 04/02/17 HK -2 10,516 10,587' 9,448' 9,508' 71' 05/08/17 HK -2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open HK -3 10,604' 10,687' 9,523' 9,593' 83' 5 05/08/17 HK -3 10,604' 10,696' 9,523' 91601' 92' HK -4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open HK -3 & HK -4 10705' 10,837' 9,609' 9,722' 132' 5 05/08/17 HK -4 10,711' 10,727' 9,614' 9,628' 16' 04/02/17 HK -5 10,875' 10,900' 9,755' 9,777' 25' 5 05/08/17 Updated: 09/07/2017 by DENT McArthur River Field, TBU Well: D -43RD PROPOSED Corripieted: FUTURE API: 50-733-20373-01 -If- Hileoro Alaska. LLC PTs: 185-311 TD =11,250' PBTD =11,166' Devi =31' (10,600') JEWEL i�Y DETAIL No Depth (MD) Depth ID (TVD) CASING DETAIL 1 ±350' *350' 2.313" SIZE WT GRADE CONN 1D TOP BTM. 13-3/8" 68 K-55 Butt 12.415" Surf 3,069- 9-5/811 47 N-80 Butt 8.681" Surf 9,409' P-110 8 round 8.681" 9,409' 9,841' 7" 29 N-80 Butt 6.184" 9,543' 11,250' ±9,237' ±8,350' GLM #8 TUBING DETAIL ±9,886' ±8,915' GLM #9 2-7/8" 6.5 L-80 1 8 round 1 2.441" Surf ±9,975' JEWEL i�Y DETAIL No Depth (MD) Depth ID (TVD) OD Item 1 ±350' *350' 2.313" SSSV 2 12,814' ±2,700' GLM #1 3 ±4,798' ±4,400' GLM #2 4 ±6,061' ±5,500' GLM #3 5 1 ±6,750' ±6,100' GLM #4 6 ±7,371' ±6,650' GLM #5 7 17,988' ±7,200' GLM #6 8 ±8,591' ±7,750' GLM #7 9 ±9,237' ±8,350' GLM #8 10 ±9,886' ±8,915' GLM #9 11 ±9,915' ±8,940' Packer 12 ±9,945' ±8,965' 2.313" X -Nipple 13 ±9,975' ±8,991' WLEG PERFORATION DETAIL Lone Top (MD) Btrn (MD) Top (TVD) Btrn (TVD)Amount SPF Date Comment G-2 10,024' 10,048' 9,033' 9,053' 20' G -4A 10,272' 10,282' 9,242' 9,250' 10' G -4A 10,192' 10,206' 9,175' 91186' 14' G -4A 10,149' 10,169' 9,138' 9,155' 20' HK -1 10,460' 10,492' 9,400' 9,427' 32' HK -2A 10,455' 10,487' 9,396' 9,423' 32' 5 05/08/17 HK -2 10,515' 10,590' 9,477' 9,511' 75' 04/02/17 HK -2 10,516 10,587' 9,448' 9,508' 71' 05/08/17 HK -2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open HK -3 10,604' 10,68T 9,523' 9,593' 83' 5 05/08/17 HK -3 10,604' 10,696' 9,523' 9,601' 92' HK -4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open HK -3 & HK -4 10705' 10,837' 9,609' 9,722' 132' 5 05/08/17 HK -4 10,711' 10,727' 9,614' 9,628' 16' 04/02/17 HK -5 10,875' 10,900' 9,755' 9,777' 25' 5 05/08/17 Updated 01/30/20 byJLL Rilsm? Alwkw, TJX. Dolly Varden D -43RD 133/8X95/8X31/2 BHTA, Bowen, 3 1/8 5M FE X 3" Bowen top Dolly Varden Platform D43RD Current 05/29/2017 Tubing hanger, CIW-DCB-ESP, 11 X 3 % eue lift and susp, w/ 3" type H BPV profile, 5 X EN, 2- 3/8 continuous control line ports, prepped for BIW penetrator Valve, swab, WKM-M, 31/85M FE, HWO, T-24 Valve, Wing, WKM-M, ' 31/8 5M FE, w/ 15" OMNI operator, DD �. trim Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 C Valve, lower master, WKM-M, 31/8 5M FE, HWO, T-24 Adapter, CIW-Toadstool, 11 5M Stdd X 3 1/8 5M FE, prepped for 5 % ESP neck, 2- % npt continuous -tl control line ports Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M 550, X bottom j Valve, WKM-M, 21/16 5M FE, tf ^� f HWC, DD ID, I�A City 2 Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing Valve, CIW-F, 21/16 5M FE, thread bottom, w/ 2- HWO, AA trim 21/16 5M EFO, CA slips F installed in head MMi- Q H Hilrowl, AWWO, LII Dolly Varden Platform D -43RD 133/8X95/8X27/8 Dolly Varden Platform D -43RD Proposed 01/24/2020 Tubing hanger, CIW-DCB- FBB-CCL, 11 X 31/2 EUE lift and susp, w/ 3" type H BPV profile, 6 Y4 EN, 2- % npt CCL ports BHTA, Bowen, 31/8 5M FE X 3" Bowen Quick Union Valve, Swab, ClW-FC, 3 1/8 5M FE, HWO, EE trim Valve, Upper Master, CIW-FC, 3 1/85M FE, HWO, EE trim Valve, Master, CIW-FC, 3 1/85M FE, HWO, EE trim Tubing head, CIW-DCB-S, 13 5/8 3M X 115 M, w/ 2- 21/16 5M SSO, X -bottom prep Casing head, CIW-WF, 13 5/8 3M X 13 3/8" threaded bottom, w/ 2- 21/16 5M EFO Valve, SSV, FC, 3 1/8 5M FE, W/ 15" Safeco oper-air operated Adapter, CIW-EN-CCL, 115M Stdd x 3 1/8 5M, prepped for 6 Y EN and 2- 34 npt CCL ports, EE material Valve, WKM-M, 2 1/16 5M FE, HWO, AA Qty 2 Valve, CIW-F, 21/165M FE, HWO, AA Hilcgrp 4.1urkv, CIA; Dolly Varden Platform 2020 BOP Stack 01/24/2020 271 -5-5 variables Blinds earl! KIII valves 21/166M ■ 0 n C c 4 a03 �D m W 0O r J 2 ; C m>,i rCrr N Ow00 zz-°*;u 00m�G� _ 'cn > Z��CD 4]]n m0 Z -j Z z C N z z 0 -a T m Cf) n� z D m r O� O Jm0 S] n 2 A mm Z rD Sc mo mM XM r� Z Z M, W U *00 � c�0 N P �y _ m - �� a a a aM. � °-' a n v o3i a d d m -3 3~ •- v' v an3i m �m00'o aa.a--aaoo '� Iooao n.a n a Q a n a�a n � a A a a a -r.+ r o '. -''.-...-...- -..� - nn n.n�n n n nn n m 3 3 3 K 3 3 3 n 5 3 3 O o n n o nn O -n o n Ona O l+ c o' o n 0.0 o EE0 Rig 404 11301) Test Procedure mtcwp Alaska, LU Attachment 91 Attachment #1. Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift -threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift -threads d) For ESP wells -Ensure that cap is on cable penetrator e) NU BOP. Test ROPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) Hileorp Alaska, LLC Rig 404 130P Test Procedure Attachment f$1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump -in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD ROPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test fine connected to pump -in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 11 valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Ciose pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross, open 1' valve of standpipe, close valves 3, 4 & 9 on choke manifold, open valves 1 & 2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two testjoints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve / open outside valve on kill side of mud cross, close valves 5 & 6 / open valves 3 & 4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke / open valves 5 & 6 on choke manifold. Pressure up to —1200 psi and bleed off 200-300 #s recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. f) Close HCR (outside valve on choke side of mud cross), open manual & super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. Rig 404 BOP Test Procedure Attachment #1 g) Close inside valve / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off- open pipe rams and pull testjoint leaving test plug / 2 -way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7 & 8 / open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre - charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. a n pt 0 m 0 co m CD m `a DD O� n 0 Q CD o. M. m (Q �o o w C CD �o � Q. ON C N Q w CD CCD tQ C1 CD 0 CD 3 D� CD - nm CL nC Mw 0"o 3 O �CD �_ flcr C CD W O O h 3 3 CD w 0 3 s co N CD 3 N (Q r -r CD O 3 CD w .fl � C 'O �• Q LZ CD C3' a CD N O C (D O CD B is CD CD O cn 3 CD C N 3 3 N ca Q CD Er ' O 3 CD N c rt 0 01 {O 0 'o m M C Q T O Q m C. c 0 m O w X v v co W 7t CL C ■o, r r n VOF Tit • • 0+1..'�\�//7 ,t THE STATE Alaska Oil and Gas " ofA TT ccKA Conservation Commission this rt: i, 333 West Seventh Avenue mo . , /- GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Oj A : �Q. Main : 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager Hilcorp Alaska, LLC �' '��� VV 201? 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G and Hemlock Oil Pool, TBU D-43RD Permit to Drill Number: 185-311 Sundry Number: 317-441 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, (EMCF-'' ______ Hollis S. French Chair DATED this Zn' day of September, 2017. RBLJMSIJI,Y - :J . ,.. • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 1 $ 2017 APPLICATION FOR SUNDRY APPROVALS �� � 20 AAC 25.280 1.Type of Request: Abandon Cl Plug Perforations❑ Fracture Stimulate El Repair Well ❑ Operations shutdown Cl Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. G/L Completion 0+; 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory El Development 0 185-311 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20373-01 , 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes Cl No 0 Trading Bay Unit D-43RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 + McArthur River Field/Middle Kenai G and Hemlock Oil Pools 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): 11,250 10,083 11,003 9,867 2,543 psi 11,166 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3,069 13-3/8" 3,069 2,907 3,450 psi 1,950 psi Intermediate Production 9,841 9-5/8" 9,841 8,887 6,870 psi 4,760 psi Liner 1,707 7" 11,250 10,083 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,024-10,900 ' 9,033-9,777 ' 3-1/2" 9.2#/L-80 8,843 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): D&L Oil Tools Hydroset II Packer/Haliburton NE TRSV 412(MD)412(TVD)&353(MD)353(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work Commencing Operations: 10/30/2017 OIL 0 WINJ ❑ WDSPL El Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG El Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hilcorp.com \ Contact Phone: (9:q..)283-1329 Authorized Signature: r �... Date: %%U `, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. �/ 3 t-7- 1-(1-( 1 Plug Integrity CI BOP Test I: Mechanical Integrity Test ❑ Location Clearance ❑ Other: .. 3 500 f c &)P 7 f_ Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS i. L Lt,t -. J Cd 9/ Spacing Exception Required? Yes o No Er Subsequent Form Required: /0_ L./®/ ��� APPROVED BY c% r• lq Approved by: r.. COMMISSIONER THE COMMISSION Date: `l \ f ?i'•4 //z1/,- ,,''Yk Icy (s . ;cc1_ 7-i7 c.1\ \ Submit Form and Form 10-403 Revised 4/2017 0 RIIp i R id for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: D-43rd 13ilcorp Alaska,LLC Date: 09/14/17 Well Name: D-43rd API Number: 50-733-20373-01 Current Status: ESP Producer Leg: Leg#A-1 NE corner Estimated Start Date: October 30, 2017 Rig: Moncla 404 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 185-311 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) Current Bottom Hole Pressure: 3,554 psi @ 9,315' TVD 0.437 psi/ft mid perf 2009 SIBHP Maximum Expected BHP: 3,5 A • i @ 9,315'TVD 0.437 psi/ft mid pert 2009 SIBHP Maximum Potential Surface Pressure: 2,543 Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Brief Well Summary Well D-43rd is an oil well with a comingled completion in the G and Hemlock zones. D-43rd was converted to an ESP from gas-lift in May 2017.This workover will replace the ESP that failed in August 2017 with a gas lift completion. / -� --�- 631a Last Casing Test: 05/06/2017 tested IA at 9,797'to 1,600 psig on chart for 45 minutes. Procedure: 1. MIRU Moncla Rig#404. 2. Circulate hydrocarbon off of well.Work over fluid will be FIS[. BOP's will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/3,500psi high/2,500 psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with completion. 6. RIH with bit and scraper to±10,000', circulate clean, POOH. 7. PU and RIH with gas-lift assembly. 8. Set Packer/Pressure test completion: a. Pressure up and set packer b. Test tubing against plug in X nipple to 2500#and chart for 30 minutes. c. Test IA to 2,000 psi and chart for 30 minutes(This will pressure up tubini also). d. Pull prong and plug in X-Nipple. 9. Set BPV, ND BOP, NU wellhead and test. 10. Turn well over to production. 11. Conduct SVS testing per AOGCC regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. Wellhead Schematic Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form McArthur River Field, TBU .sCHEMATIC • Well: D-43RD Completed: 05/11/2017 API: 50-733-20373-01 Hilcorp Alaska,LLC PTD: 185-311 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 68 K-55 Butt 12.415" Surf 3,069' 1 9-5/8" 47 N-80 Butt 8.681" Surf 9,409' 4 2 P-110 8 round 8.681" 9,409' 9,841' 7" 29 N-80 Butt 6.184" 9,543' 11,250' ini TUBING DETAIL ,csi) f ..._ 3-1/2" 9.2 L-80 Supermax 2.992" Surf 8,843' JEWELRY DETAIL V No Depth Depth ID OD Item (MD) (TVD) 3-11 1 353' 353' 2.813" 5.620" SSW-Haliburton NE TRSV 2 412' 412' 3.000" 8.500" Packer-D&L Oil Tools Hydroset II w/WFT Vent valve 3 2,464' 2,407' 2.992" 5.750" GLM#1 ill 4 3,980' 3,692' 2.992" 5.750" GLM#2 fru 5 5,028' 4,601' 2.992" 5.750" GLM#3 6 5,841' 5,308' 2.992" 5.750" GLM#4 7 6,522' 5,900' 2.992" 5.750" GLM#5 12 8 7,073' 6,387' 2.992" 5.750" GLM#6 9 7,656' 6,903' 2.992" 5.750" GLM#7 10 8,208' 7,398' 2.992" 5.750" GLM#8 U 11 8,756' 7,903' 2.992" 5.750" GLM#9 12 8,804' 7,948' 2.813" 4.450" X Nipple 13 8,843' 7,984' N/A 5.130" Bolt on Discharge Head Z Z 8,844' 7,985' N/A 5.130" Triple Pump section,Summit 198 stage SJ10000AR 13 8,915' 8,052' N/A 5.130" Intake G 8,916' 8,053' N/A 5.130" Tandem Seals-BPBSL 8,934' 8,069' N/A 5.620" Tandem Motors-KMS 1000HP/3600V/165.5A 9,000' 8,131' N/A 5.620" Gauge(Zenith)/Centralizer/Anode PERFORATION DETAIL Zone Top Btm Top Btm Amount SPF Date Comments (MD) (MD) (TVD) (TVD) G-2 10,024'' 10,048' 9,033' 9,053' 20' G-4A 10,272' 10,282' 9,242' 9,250' 10' G-4A 10,192' 10,206' 9,175' 9,186' 14' =G-2 G-4A 10,149' 10,169' 9,138' 9,155' 20' G-4A HK-1 10,460' 10,492' 9,400' 9,427' 32' G-4 - HK-2A 10,455' 10,487' 9,396' 9,423' 32' 5 05/08/17 G-4 HK-1 HK-2 10,515' 10,590' 9,477' 9,511' 75' 04/02/17 HK-2A HK-2 10,516 10,587' 9,448' 9,508' 71' 05/08/17 HK-2 - HK-2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open HK-3 c/oto - HK-3 10,604' 10,687' 9,523' 9,593' 83' 5 05/08/17 11,003'on -HK-4 5/4/17 HK-3 10,604' 10,696' 9,523' 9,601' 92' =HK-5 .st HK-4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open HK-3& TD=11250' PBTD=11,166' HK-4 10705' 10,837' 9,609' 9,722' 132' 5 05/08/17 Devi=31"(10,600') HK-4 10,711' 10,727' 9,614' 9,628' 16' 04/02/17 HK-5 10,875' 10,900'. 9,755' 9,777' 25' 5 05/08/17 Updated 06/05/17 by JLL • McArthur River Field,TBU °PROPOSED Completed: FUTURE API: 50-733-20373-01 LLCileorp Alaska, PTD: 185-311 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 68 K-55 Butt 12.415" Surf 3,069' 1N-80 Butt 8.681" Surf 9,409' 9-5/8" 47 P-110 8 round 8.681" 9,409' 9,841' 7" 29 N-80 Butt 6.184" 9,543' 11,250' TUBING DETAIL 3" 6.4 L-80 8 round 2.441" Surf ±9,975' �w� . JEWELRY DETAIL ' No Depth Depth ID OD Item (MD) (TVD) 1 ±350' ±350' SSSV 2 ±2,574' ±2,500' GLM#1 3 ±4,336' ±4,000' GLM#2 4 ±5,774' ±5,250' GLM#3 • 5 ±6,750' ±6,100' GLM#4 2 10 Po r 5-4\ 6 ±7,540' ±6,800' GLM#5 (v�"�T- 7 ±8,155' ±7,350' GLM#6 ,/ ' 8 ±8,752' ±7,900' GLM#7 9 ±9,320' ±8,425' GLM#8 10 ±9,885' ±8,914' GLM#9 S Z 11 ±9,915' ±8,940' Packer 12 ±9,945' ±8,965' X-Nipple L 13 ±9,975' ±8,991' WLEG PERFORATION DETAIL MT Zone Top Btm Top Btm Amount SPF Date Comments (MD) (MD) (TVD) (ND) ` 11 G-2 10,024' 10,048' 9,033' 9,053' 20' lilt 12 G-4A 10,272' 10,282' 9,242' 9,250' 10' air'13 G-4A 10,192' 10,206' 9,175' 9,186' 14' =--G-2 G-4A 10,149' 10,169' 9,138' 9,155' 20' G-4A HK-1 10,460' 10,492' 9,400' 9,427' 32' =G-4 r...--G-4 HK-2A 10,455' 10,487' 9,396' 9,423' 32' 5 05/08/17 =HK-1 HK-2 10,515' 10,590' 9,477' 9,511' 75' 04/02/17 HK-2A HK-2 10,516 10,587' 9,448' 9,508' 71' 05/08/17 HK-2 HK-2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open HK-3 C/0 to = HK-3 10,604' 10,687' 9,523' 9,593' 83' 5 05/08/17 11,003'on =HK-4 5/4/17 HK-3 10,604' 10,696' 9,523' 9,601' 92' s HK-5 \ HK-4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open TD=11,250' PBTD=11,166' HK-3& 10705' 10,837' 9,609' 9,722' 132' 5 05/08/17 Devi=31"(10,600') HK-4 HK-4 10,711' 10,727' 9,614' 9,628' 16' 04/02/17 HK-5 10,875' 10,900' 9,755' 9,777' 25' 5 05/08/17 Updated 09/14/17 by DEM • D Varden Platform 3 D-43RD Hiknrp Al.urku,LIA: Dolly Varden Tubing hanger,CIW-DCB-ESP, D-43RD 11 X 3'4 eue lift and susp,w/ 13 3/8 X 9 5/8 X 31/2 3"type H BPV profile,5 Y.EN, 2-3/8 continuous control line ports,prepped for 81W penetrator BHTA,Bowen,3 1/8 5M FE X 3"Bowen top III i nl MID I'" ii ,ii Valve,swab,WKM-M, ), 3 1/8 5M FE,HWO, ,) glit T-24 Valve,Wing,WKM-M, ZS/ 31/8 5M FE,w/15" •ar11.1 Y„1�1 OMNI operator,DD trim Valve,wing,WKM-M, 4: j'iFEHWQ T24 - • - 1l1 ■ Valve,lower master,WKM M, -�9j 3 1/8 5M FE,HWO,T-24 III III It III Adapter,CIW-Toadstool, 11 5M g. Stdd X 3 1/8 5M FE,prepped for 5'A ESP neck,2-%2 npt continuous control line ports Tubing head,CIW-DCB, _._ �” 13 5/8 3M X 11 5M,w/2- sill � 1 II: 2 1/16 5M SSO,X bottom 111 I I Valve,WKM-M,2 1/16 5M FE, # HWO,DD 1 Illilli millik*N_)1 I 1 Qty 2 III _ I III A! 111 Casing head,CIW-WF, RI 13 5/8 3M X 13 3/8 casing Li Valve,CIW-F,2 1/16 5M FE, thread bottom,w/2- i I I ■ III HWO,AA trim 2 1/16 5M EFO,CA slips - , installed in head ni ill IP • • II e Dy Varden Platform Y D-43RD Proposed 09/14/2017 Hiknrp:%blokes,HA: Dolly Varden Platform Tubing hanger,CIW-DCB- D-43RD FBB-CCL,11 X 3 1/2 EUE lift 13 3/8 X 9 5/8 X 2 7/8 and susp,w/3"type H BPV profile,614 EN,2-'A npt CCL ports BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union ill .■MEM. p Uj u. Valve,Swab,CIW-FC, �'.71\ 3 1/8 5M FE,HWO, el;C EE trim Valve,SSV,FC,3 1/8 5M FE, 1 1,...09� w/15"Safeco oper-air it....Tip operated i i i U I 1 11.6. 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Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT) is just above the blind rams. 4) Set slips,mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection, etc.) • • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska, [ Attachment#1 Ll f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. P g Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1st valve on standpipe manifold,close valves 1, 2, 10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint,close outside valve on kill side of mud cross,open ft valve of standpipe, close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross,close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to^'1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross),open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed (e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP,FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • • • 0 -o2 Cl)® ƒ c J el /® c 7 a / 2 Q 0 S °/ A Ek " C) c \ < n $ Cl) coca / xJ › n 2 � ® k C E - / CD R / q $ IS 0 3 0 / co 0 / 1 C / o a• Cl) 5 t \ k Q. m ƒ . � � Cl) xi ca IN /Q k CD C paf s p CD % (D 0 17 %' � 0 2 C k %] CCD 0. > f = OE 0 CD 9 / / / a co %.f i. o CD,-p- X / / -I CD < QQ. / � co J ,- m<2CD // 17 � * 3 \ ✓ C � / k CD a. § g £ 2f C.f= =1. /�� 7 / k ro 0. QC CDa •D $ /. . 2 = k7 ƒ / m0. q co ] D co § 22D 70. 0 < 0 \ 0- = A) CD a- = = X * / D CD _ « Fi) Dam STATE OF ALASKA Alit OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing I] Operations shutdown 0 Performed: Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill 0 erforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: GL/ESP CompletionE 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 0 185-311 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service El 6.API Number: AK 99503 50-733-20373-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 Trading Bay Unit/D-43RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Middle Kenai G and Hemlock Oil Pools 11.Present Well Condition Summary: Total Depth measured 11,250 feet Plugs measured 11,166fee �'CE IVED true vertical 10,083 feet Junk measured N/A feet 11��R' /� n Effective Depth measured JUN uly v 20�� p 11,003 feet Packer measured 412 feet true vertical 9,867 feet true vertical 412 feet AOGC Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3,069' 13-3/8" 3,069' 2,907' 3,450 psi 1,950 psi Intermediate Production 9,841' 9-5/8" 9,841' 8,887' 6,870 psi 4,760 psi Liner 1,707' 7" 11,250' 10,083' 8,160 psi 7,020 psi Perforation depth 'Measured depth 10,024-10,900 SCANNED .,i I)N 2 02017 True Vertical depth 9,033-9,777 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 8,843(MD) 7,984(TVD) D&L Oil Tools 412'(MD) 353'(MD) Packers and SSSV(type,measured and true vertical depth) Hydroset II Pkr 412'(TVD) Haliburton NE TRSV 353'(TVD) 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: 67 18 217 1040 316 Subsequent to operation: 127 18 690 250 124 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ DevelopmentE Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil EI Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-144 Authorized Name: Stan Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe(5 hilcorp.com treAuthorized Signature: Date: 4/0/2.01 1 Contact Phone: 907-283-1329 Form 10-404 Revised 4/2017 Ye 1 ` RBDMS !!`/�UN - 6 2017Submit Original Only9 McArthur River43RD Field,TBU C SCH C 14 • MATT C Completed: 05/11/2017 API: 50-733-20373-01 Hilcorp Alaska,LLCPTD: 185-311 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 68 K-55 Butt 12.415" Surf 3,069' 1 N-80 Butt 8.681" Surf 9,409' 9-5/8" 47 2 P-110 8 round 8.681" 9,409' 9,841' 7" 29 N-80 Butt 6.184" 9,543' 11,250' ti TUBING DETAIL s 3-1/2" 9.2 L-80 Supermax 2.992" Surf 8,843' b JEWELRY DETAIL lb No Depth Depth ID OD Item (MD) (TVD) 3-11 1 353' 353' 2.813" 5.620" SSSV-Haliburton NE TRSV 2 412' 412' 3.000" 8.500" Packer-D&L Oil Tools Hydroset II w/WFT Vent valve to 3 2,464' 2,407' 2.992" 5.750" GLM#1 to 4 3,980' 3,692' 2.992" 5.750" GLM#2 5 5,028' 4,601' 2.992" 5.750" GLM#3 ati 6 5,841' 5,308' 2.992" 5.750" GLM#4 19 7 6,522' 5,900' 2.992" 5.750" GLM#5 CI 12 8 7,073' 6,387' 2.992" 5.750" GLM#6 9 7,656' 6,903' 2.992" 5.750" GLM#7 10 8,208' 7,398' 2.992" 5.750" GLM#8 11 8,756' 7,903' 2.992" 5.750" GLM#9 12 8,804' 7,948' 2.813" 4.450" X Nipple 13 8,843' 7,984' N/A 5.130" Bolt on Discharge Head 7 Z 8,844' 7,985' N/A 5.130" Triple Pump section,Summit 198 stage SJ10000AR 13 8,915' 8,052' N/A 5.130" Intake - 8,916' 8,053' N/A 5.130" Tandem Seals-BPBSL 8,934' 8,069' N/A 5.620" Tandem Motors-KMS 1000HP/3600V/165.5A 9,000' _ 8,131' N/A 5.620" Gauge(Zenith)/Centralizer/Anode PERFORATION DETAIL Zone Top Btm Top Btm (MD) (MD) (TVD) (TVD) Amount SPF Date Comments 6-2 10,024' 10,048' 9,033' 9,053' 20' G-4A 10,272' 10,282' 9,242' 9,250' 10' G-4A 10,192' 10,206' 9,175' 9,186' 14' G-2 G-4A 10,149' 10,169' 9,138' 9,155' 20' =G-4A HK-1 10,460' 10,492' 9,400' 9,427' 32' G-4 HK-2A 10,455' 10,487' 9,396' 9,423' 32' 5 05/08/17 G-4 HK-1 HK-2 10,515' 10,590' 9,477' 9,511' 75' 04/02/17 HK-2A HK-2 10,516 10,587' 9,448' 9,508' 71' 05/08/17 HK-2 HK-2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open HK-3 got. HK-3 10,604' 10,687' 9,523' 9,593' 83' 5 05/08/17 11,003'on 5/4/17 -HK-4 HK-3 10,604' 10,696' 9,523' 9,601' 92' =HK-5 HK-4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open HK-3& TD=11,250' PBTD=11,166' HK-4 10705' 10,837' 9,609' 9,722' 132' 5 05/08/17 Devi=31"(10,600') HK-4 10,711' 10,727' 9,614' 9,628' 16' 04/02/17 HK-5 10,875' 10,900' 9,755' 9,777' 25' 5 05/08/17 Updated 06/05/17 by JLL • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig d iAPI Number Well Permit Number Start Date End Date D-43RD Moncla 404 50-733-20373-01 185-311 4/18/17 5/11/17 Daily Operations. 04/18/2017-Tuesday Working M/V Champion. Backload derrick. Remove draw works and carrier walkways and stairs. Backload carrier and rig tank to boat. B/O rig beam spreader bars. Move mud pump to south end of drill deck. 04/19/2017-Wednesday Set strongback beams in position and installed spreader bars-cleaned South deck area over well bay while waiting on M/V Champion to return from crew change. Picked rig carrier off M/V Champion and set in place on strongback beams- mounted A-frame, drawworks and pinned derrick. Offloaded walkways, stairs, landings and test pump- released M/V at 1400 hrs. Installed walkways on carrier- hooked up mud pump to tank- began positioning and hooking up koomey unit, choke house.Total Safety and Quadco setup and tested their systems. Spot SLU on drill deck. M/U lubricator and 1.75"TS (0.5' RS, 10' Stem, 0.75' KJ. 3' OJ, 7' LSSJ) and 3" GS Spear. SI well, lock SSSV open and SI chem. injection line. Begin equalizing well. Lay down lubricator and tool string and return crane to rig crew to continue R/U W/O package. Half mast derrick and spool up draw works and cat line. Lay derrick down to allow SLU access to well hatch. Well equalized,T/IA= 1000/1000. Rig SLU to WHA. PT Lubricator&WLV= 3000 psi-good test. RIH# 1 w/3" GS spear to 3056', latch and pull AA Stop. POOH. Fill rig tank w/ FIW. L/D AA Stop. RIH#2 w/3" GS Spear to 3057', latch and pull upper pack-off. POOH. L/D pack off. RIH#3 w/3" GS Spear to 3058', latch and pull isolation tube. POOH. L/D isolation pipe. RIH#4 w/3" GS Spear to 3070', latch and pull lower pack-off. POOH. L/D pack-off. RIH#5 w/3" GS Spear to 3071', latch and pull AD2 Stop . POOH. L/D AD2 Stop. RIH#6 w/OK5 kick-over tool dress w/ 1-1/2"JDS to 9,676' (WLM)- latched valve and POOH. B/0 lub- recovered valve. B/O kick-over tool. M/U 3" GS spear w/AD2 stop-TIH w/ Run #7. 04/20/2017-Thursday TIH w/3" GS w/AD-2 stop to 3,071' (WLM)-set stop- POOH. M/U 10' patch w/ lower packoff on 3" GS-TIH and set on stop at 3,071'- POOH. M/U upper packoff on 3" GS-TIH and set at 3,057' (WLM)- POOH. M/U AA stop on 3" GS-TIH and set stop at 3,056'- POOH- R/D S/L. Bled down 1000 PSI tb and casing pressure to 100 PSI thru well clean tank. Rig crew continuing R/U W/O package. Lined up to flush well w/ FIW sending returns to TB thru well clean tank. NOS rep tested, worked hold downs and repacked hanger void. Began flushing well (LW) w/ FIW at 2.25 BPM 0 PSI initial pressure.486 BBL(13,600 stks) FIW away @ 2.80 BPM) 0 PSI circulating pressure, 0 returns. Continue circulating. 853 BBL(23,893 stks, Hole Volume + 25%) FIW away,T/IA=0/0, no returns to surface. Stop pump. Line up to pump FIW to IA taking returns thru tubing to well clean tank.Tubing on vacuum. Start pumping to IA at 2.75 BPM 0 PSI. 315 BBL(8800 stks) away to IA, 2.75 BPM, 0 PSI casing and tubing, no returns to surface. Continue loading backside w/ FIW. NOS rep begins backing out one lock dock screw(LDS) to start LDS/gland nut replacement.As LDS backs out and packing relaxes pressure vents. NOS tightens LDS to engage packing.Verify IA=0 PSI. NOS rep bleeds trapped pressure in hanger void. NOS rep returns to replacing all LDS 1 at a time. Replaced 3 lock down screw sets. 601 BBL(16,832 stks) away to IA.T/IA= 0 PSI. Stop pump. Install BPV. Began N/D tree- maxed torque unit to backoff nuts. Pulled 40k against tree w/crane- no movement. Pulled BPV and installed 2-way check- pressured up to 4000#s and pulled 40,000#s w/crane- no movement. Conferred w/ Mr. Chanley, Mr. Loomis and Mr. Marlowe-decision was made to cut bolt on DSA. ! • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-43RD Moncla 404 50-733-20373-01 185-311 4/18/17 5/11/17 Daily Operations: 04/21/2017 - Friday Began cutting bolts on DSA adapter spool to N/D tree. Welder onboard to correct faults identified by Mr.Tornai. Ordered Swaco mixing tank and material to build sized salt pills. 1430 hrs lifted tree off w/assistance from jacks-threads in tb hanger in excellent condition- M/U 4 1/2" 8rd blank test sub in hanger- prepped flange and hanger for BOP N/U. Changed out all holddown pins on tb head- repacking void. N/U 13 5/8" 5M BOPE w/ 11" 5M adapter on btm- 2 7/8" x 5"VBR. Finished torqueing BOP bolts, run coflex hoses to kill line and flow cross. Stand up and scope out derrick and secured all guy lines. Mounted rig floor and wind walls and stairs on off-driller side of floor. Hang tongs, set up handling tools, 3-1/2" test jt, IBOP, pump-in sub and safety valve on floor. Run power pack lines to tongs. Connected lines to koomey and function the BOPE. M/U safety valve, IBOP and pump-in sub to 3-1/2" test jt w/ported sub on bottom, NOS rep on floor. Fill BOPE w/ FIW. Shell test BOPE (3500 psi) -good test Testing BOPE 250 low 3500 high as per Hilcorp and AOGCC requirements. 04/22/2017-Saturday Finished testing all BOPE 250 psi low 3500 psi high as directed in Sundry (annular tested 250 psi low 2500 psi high),in accordance with Hilcorp and AOGCC requirements. Performed successful koomey drawdown test. Witnessed waived by Mr Quick/AOGCC 1:40 PM 4/20/217. Pulled blanking sub from hanger- R/D test equipment and M/U 3 1/2" 8rd landing jt w/4 1/2" 8rd xover on btm. Slight blow on tb & casing-will not register on gauge. Pumped 60 bbls FIW down tb at 2 BPM 0 psi. Pulled BPV and M/U landing jt in hanger- lined up to pump down casing. Pumped down annulus at 3 bpm 0 psi- began seeing pressure at 157 bbls-shutdown pump and opened backside. NOS rep backed out holddown pins. Latched onto string and P/U to 140k before hanger pulled loose-worked pipe from 85k to 170K (hanger comes off seat at 82k). R/U Pollard S/L. M/U 1 3/4" standard tool string (10' of stem, knuckle, oil &spang jars) Run#1- 3" GS spear to 3,056'- latch and pull AA stop- POOH- B/O stop. Run#2- 3" GS Spear to 3,057'- latch and pull upper packoff- POOH. B/O upper pack off, isolation pipe and lower packoff OOH as assembly. Run #3-3" GS spear to 3,071'- latch and pull AD2 stop- B/O stop. Run #4-2.59" gauge-TIH to 9,925'- POOH- R/D S/L. R/U Pollard ELine. RIH w/CCL/Chemical cutter to 9914' tubing tail (13' CCL to cutter). Log up to correlate, correct depth.TIH and repeat log up to place cutter on depth at 9791.1 CCL (9804' corrected depth). Fire cutter at 18:15 hrs. Work wire,jar lick on PUH, free. POOH. Rig back ELU. P/U on 3-1/2" tubing working up to 175K pickup, tubing is not free. Work tubing from 85K to 175K. Pump 40 BBL, 11.4 ppg Super Saturated Salt pill and chase w/50 BBL FIW to tubing 2.90 BPM 0 PSI while working tubing. Call out for EL Free Point tools Continue working 3-1/2" tubing 85K- 175K. Work tubing alternating w/ pickups to 175K and holding. Pickup to 175K and hold, weight falls off to„ 140K. Work tubing 100K- 160K, tubing PUH. Pull hanger to floor. Pump 20 BBL FIW. Cancel Free Point tools, RD ELU. NOS rep works tubing hanger, L/D tubing hanger. Pull 3-1/2"jts. as needed to allow tie back of flatpack chemical lines to PWL spooler. Continue POOH baking down 3-1/2"jts. Initial PU weights 120-125K. Pump 10 BBL FIW every 20 jts. laid down. SSSV to floor,work and L/D valve. Continue POOH laying down 3-1/2"jts. Pump 10 BBL FIW every 20 jts. laid down. 35 of 301 jts OOH at report time. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-43RD Moncla 404 50-733-20373-01 185-311 4/18/17 5/11/17 Daily Operations: 04/23/2017-Sunday Continued POOH w/3 1/2".9.2# N:80 Buttressproduction strinLalo w/SSSV and GLMs. Laid down jt#36 then PUH stripping off damaged control line clamp which fell in hole wedging at wellhead. Rig crew fished clamp out then lined up to pump down casing. Ordered TS-100 bowl & slip from KOT. Began pumping down casing at 3.2 bpm 0 psi, monitoring returns at rig tank- began seeing pressure at 346 bbls pumped-shutdown and lined up to well clean tank. Continued pumping 3.2 bpm, pressure stabilizing at 270 psi. Shutdown pump after pumping 865 bbls FIW (1.4 hole volume @ 8,661')- both sides on vacuum. B/O hose to well clean and connected back to circ manifold. Continued POOH w/recovered production string, removing clamps on flatpack control line at every connection- pumping 6 bbls FIW every 20 jts LID. PUW = 96k. M/V Champion arrives. Work boat. Continued POOH w/ recovered production string. 140 jts racked (4425') plus GLM# 1 and 2. PUW= 58K. Continued POOH w/recovered production string, removing clamps on flatpack control line at every connection- pumping 6 bbls FIW every 20 jts L/D. 220 of 301 jts OOH at report time = 7,102'. PUW= 36k. 04/24/2017 Monday Continued POOH w/ recovered 3 1/2" 9.2# N-80 Buttress production string, removing clamps on flatpack control line at every connection- pumping 2 bbls FIW every 20 jts L/D (fluid loss rate decreasing). 0930 hrs swapped out tongs. Work M/V Champion exchanging pulled production string for workstring- changed out flatpack spool. EOT was chem cut= 9,804'. Recovered all control line flatpack & clamps. Cleared and cleaned rig floor and V-door area. Clear& clean drill deck. M/U BHA#1 (6" Varel rock bit, scraper 1/7" casing, 8 jts PH6 tb (256'), scraper f/9 5/8" casing w/xover subs = 264.33'. M/V Champion arrives. Work boat off loading and back loading. C/O tong back-up dies. RIH with BHA#1 P/U 3-1/2" 12.95# P-110 PH6 workstring-strapping, drifting and torqueing to 6000 FPT. C/O shaker screens.Joint#40 in the hole = 1,241'. Rev circulated to clean up hole 3 BPM 118 PSI. 10 BBL to fill the hole, 90 bbl hole volume. Sand and scale in leading returns, returns cleaned up with 70 BBL bottoms up. C/O tong dies and drag buttons. Hooked up choo-choo pump to pump down stack, hole standing full. Continued RIH P/U workstring to 2,480' (80 jts). Reversed 90 bbls FIW at 3.5 bpm 120 psi- minimual solids in returns. Continued RIH P/U workstring off deck- 110 jts (3,687') in hole at report time. 04/25/2017-Tuesday Continued RIH w/ KOTs BHA#1 C/O assy to 5,541' (160 jts). Reversed 200 bbls FIW at 2.5 bpm 150 psi-taking returns across shaker. Continued RIH w/C/O assy to 7,736' (240 jts) Reversed 200 bbls FIW at 2.5 bpm 150 psi-taking returns across shaker-2 bbls to get returns- minimual solids across shaker. Continued RIH w/C/O assy-tagged up @ 9,798' (316 jts) set down 1k on stub and laid down 1 single. Reversed 500 bbls FIW at 3.5 bpm 400 psi-taking returns across shaker-total solids during all circulations—5 gallons. B/O pump lines and laid down 7 jts- POH standing back 154 stands- B/D BHA#1. Cleared and cleaned rig floor- picked up running tool and installed wear ring bushing- laid down running tool. Prepped rig floor with KOT handing equip. M/U KOTs BHA#2 (5 3/4" overshot Idd w/3 1/2" basket grapple, 4 3/4" x 2 1/4" B&O jars, 6- 4 3/4" x 2 1/4" DCs,4 3/4" x 2 1/4" Acc jar,4 3/4" x 2 1/4" xover= 225.73') Started RIH w/ KOTs BHA#2 on 3 1/2" 12.95# P- 110 PH-6 workstring. 13 stands in hole at report time (1,039'). • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-43RD Moncla 404 50-733-20373-01 185-311 4/18/17 5/11/17 Daily Operations: 04/26/2017-Wednesday Continue TIH w/ KOTs BHA#2 (5 3/4" overshot Idd w/3 1/2" basket grapple, 4 3/4" x 2 1/4" B&O jars, 6-4 3/4" x 2 1/4" DCs, 4 3/4" x 2 1/4" Acc jar, 4 3/4" x 2 1/4" xover= 225.73') from 2,001' to top of liner at 9,543'- had to turn to get thru. Continued in hole to 9,788'. R/U and function tested power swivel-serviced same. Cleaned and organized platform deck while waiting on 4" FH x 3 1/2" IF xover sub and stiff arms f/swivel. M/U saver sub and install stiff arms on swivel. M/U swivel to string-attempted to latch up on fish no go set down on fill. Pick up Reverse circ B/U @ 3 bbls 375 psi- Attempted serval times, no go. Make up stripping head on hydril and attempted to wash down on top of fish the long way w/2.5 bbls min with 300 psi F/9798'T/9818' (PM), no go -seems to be something in the over shot barrel. R/D power swivel and lay down 1 single. Pulled OOH to KOTs BHA#2. 04/27/2017-Thursday Finished B/D KOTs BHA#2 (overshot w/jars & DCs)-found ball of control line and solid heavy wire in throat of ovs. M/U KOTs BHA#3 (5 3/4" x 3 1/2" WP shoe, 5 3/4" x 5 1/8" ext, 5 3/4" x 2 3/4" top bushing,4 3/4" x 2 1/4" B&O jars, 6-4 3/4" x 2 1/4" DCs, 4 3/4" x 2 1/4" Acc jar, 4 3/4" x 2 1/4" XO = 221.34').TIH w/ BHA#3 to 9,784' (154 stands). P/U single and install stripping rubber- RIH w/single to 9,808' landing rubber. P/U swivel w/2-3 1/2" PH-6 pups- M/U to string. Wash and Rot over 3 1/2" stub and junk 1/9818't/9830' and swallow 11' stub w/3 bbls min w/450-750 psi tq 2500-5000 ft/lb. Circ B/U @ 3.5 bbls min w/730 psi. Had some trouble with power swivel. R/D due to hydraulic fitting leaking, bad oring seal, continue R/D lay down 2 pup jts and 1 jt.Tot 154 stands in hole. P.O.O.H w/3 1/2" PH6 stand back in derrick. Continue stand back BHA#3 and lay down ext barrel had 2.5 feet control line stuffed in barrel. Make up BHA#4 w/ grapple. RIH w/ BHA#4, 5 3/4 x 2 3/4" over shot w/RHW grapple f/3 1/2", 5 3/4" x 2 3/4" top bushing,4 3/4" x 2 1/4" B&O jars, 6-4 3/4" x 2 1/4" DCs,4 3/4" x 2 1/4" Acc jar,4 3/4" x 2 1/4" XO = 225.73'.TIH w/ BHA#4 on 3 1/2" PH6 workstring f/derrick. 63 of 154 stands in hole at report time =4,126'. 04/28/2017- Friday Continue TIH w/ KOTs BHA#4 (5 3/4" overshot Idd w/3 1/2" basket grapple,4 3/4" x 2 1/4" B&O jars, 6-4 3/4" x 2 1/4" DCs,4 3/4" x 2 1/4" Acc jar, 4 3/4" x 2 1/4" xover= 225.73') from 2,001'to top of liner at 9,543'- had to turn 4 rounds to get thru. Continued in hole to 9,817'. PUW 132k-SOW 84k. P/U power swivel w/2- 10' pups- latched fish and torqued string to 6000 PSI while working pipe from 90k to 140k (1150 hrs to 1300 hrs). Released torque and jarred on fish from 85k to 170k (1300 to 1330 hrs). Worked pipe from 90k to 140k again while torqueing pipe to 6000 PSI (1330- 1400 hrs). L/D swivel and jarred on pipe from 85k to 180k-jarred loose on 10th hit. L/D pups. Started off btm dragging 10k over(142k) thru 7" casing. POOH pumping 5 bbls FIW every 20 stands and stand BHA in derrick. PJSM w/crew. L/D cut jt, pup jt, baker chemical inj sub, baker locator sub, PBR, anchor seal assy,tail pipe chem inj sub, 2 jts butts N-80 3 1/2" #9.2 tubing and Mule shoe. Tot length lay down 109.46'. Cleaned up floor and rigged down stripping head on hydril- pulled wear bushing and landed test plug- rigged up test equip. BOPE Test witness waived by Mr.Jim Regg/AOGCC 3:12 PM 4/28/17. Tested BOP annular 250/2500-continued testing BOPE T/250/3500 and All Choke Manifold Valves and VBR 2 7/8 X5", Blind Rams t/250/3500 and All Floor Safety Valves 250/3500 PSI. Perform accumulator System 3000 psi after closure 1900 /2100 40 sec 200 psi fill test 162 Sec 3000 PSI Avg Nitrogen 2000 PSI 6 Bottles. Pulled test plug and installed wear bushing- installed stripping head back on hydril and picked up power swivel testing safety valve to 250/3500 PSI. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date 0-43RD Moncla 404 50-733-20373-01 185-311 4/18/17 5/11/17 Daily Operations: 04/29/2017-Saturday M/U KOTs BHA#5 (6" x 4 3/4" WP shoe, 5 3/4" x 2 3/4" top bushing,4 3/4" x 2 1/4" B&O jars, 6-4 3/4" x 2 1/4" DCs,4 3/4" x 2 1/4" XO = 213.44'). TIH running BHA on 3 1/2" 12.95# P-110 PH-6 workstring to 9,807' (154 stands+ 1 single). Changed out swivel power pack- P/U power swivel and M/U single- installed stripping rubber on single and M/U to string then landed rubber in head. PUW 130k SOW 86k RotW 104k. Began circulating (rev) at 3.5 BPM 700 psi-eased down and tagged pkr at 9,855' (PM) and began milling- 20 mins in we plugged off at surface blowing rubber. Closed pipe rams- swapped direction & reestablished circ- lined up to reverse again and pumped tb volume+ @ 3.2 bpm 550 psi. Changed out blown stripping rubber- 1625 hrs turning on pkr again. Packer started moving downhole @ 9858', REV, CBU @ 3.5 bbl min w/675 psi then set back power swivel- P/U singles t/ 10641 Attempt t/ rot and push packer down hole no go-circ and clean off top of Pkr.Trace of gas on bottoms up and Sand and Rubber.Trying to clean off top of pkr string plugged up but able to free up-could have been the pkr jammed in shoe. Set Back power swivel and SOOH. 04/30/2017-Sunday Serviced rig and Hilcorp Gill 600 power tongs. Continued POOH w/ KOTs BHA#5 (6" x 4 3/4" WP shoe, 5 3/4" x 2 3/4" top bushing,4 3/4" x 2 1/4" B&O jars, 6-4 3/4" x 2 1/4" DCs, 4 3/4"x 2 1/4" XO = 213.44') pumping 5 bbls FIW every 20 stands. 23 stands OOH PUW 124k SOW 80k. B/D BHA#5-checked inside of shoe and identified milling marks 16" up from end- shoe ^ 50%worn- took 17 bbls to fill hole. M/U KOTs BHA#6 (5 7/8" x 4 3/4" SC overshot, 4 3/4" x 2 1/4" B&O jars, 6-4 3/4" x 2 1/4" DCs, 4 3/4" x 2 1/4" Acc jar, 4 3/4" x 2 1/4" xo = 224.81').TIH running BHA in on 3 1/2" 12.95# P-110 PH-6 workstring to 10641' and latched fish- PUH w/6k drag- B/O 1st stand wet- rigged up mud bucket. POOH stand back 3 1/2" PH6 slow w/fish No issues @ TOL 9543'. Continued POOH. Stand back BHA#6 and w/no fish over shot had 2' sand packed off in over shot and small piece of metal. Clean up over shot and lay down bumper sub due to sand. M/U KOTs BHA #7 (5 7/8" x 4 3/4" SC overshot, 4 3/4"x 2 1/4" Oil jars, 6-4 3/4" x 2 1/4" DCs, 4 3/4" x 2 1/4" Acc jar, 4 3/4" x 2 1/4" xo = 217.31). Continued RIH w/3 1/2" PH6 workstring. 126 of 168 stands in hole at report time = 7,864'. • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-43RD Moncla 404 50-733-20373-01 185-311 4/18/17 5/11/17 Daily Operations: 05/01/2017- Monday Serviced rig and tongs. Continued RIH w/ KOTs BHA#7 (5 7/8" x 4 3/4" SC overshot,4 3/4" x 2 1/4" B&O jars, 6-4 3/4" x 2 1/4" DCs,4 3/4" x 2 1/4" Acc jar,4 3/4" x 2 1/4" xo= 224.81') to 10,614'. P/U power swivel and M/U single#336- installed stripping rubber and M/U to string- landed rubber. PUW 142k SOW 82k. Began reversing FIW at 3.27 bpm-took 10 bbls to catch pressure which stabilized at 450 psi. Slacked off to 10,645' and pressure began to increase (to 1200 psi). P/U off btm and closed pipe rams- circ two btms up to check returns (some sand across shakers) but pressure did not drop off. Isolated all surface lines and circulated thru at 3.5 bpm 80 psi.Tied circ lines back into system- added 10' pup in string and began reversing at 3 bpm 550 psi (5 bbls to get returns). Started slacking off and pressure climbed to 800 psi-shutdown pump. Lined up and pumped LW at 3.7 bpm 715 psi-washed down to 10, 651'- (would not wash off deeper)-set 8k down- P/U w/ 15k over pull (157K).Turned fluid around and circ btms up at 3.5 bpm 750 psi-dropped 20k down on fish twice. B/O L/D swivel and 6' pup jt. POOH pumping 5 bbls FIW every 20 stands. B/D BHA#7- no recovery of pkr fish. Cleaned up floor and lay down overshot- M/U KOTs BHA#8 drifting assy (6"x 2 1/4" bladed junk mill, 4 3/4" x 2 1/4" 0 jars, 6-4 3/4" x 2 1/4" DCs, 4 3/4" x 2 1/4" xo = 202.79').TIH to 10,630' dropping rabbit thru 3 1/2" PH-6 workstring. Pick up swivel- make up single#336 and installed stripping rubber- M/U to string and land rubber. PUW 138, SOW 87, RotW 106, Tq 4500 psi- broke circ rev @ 3.25 BBLS w/475 psi- tag junk @ 10651' and began milling. 5' of new hole made at report time = 10,656'. 05/02/2017 Tuesday Continued milling/washing on pkr junk and fill from 10,656' to 10,816' 3+ bpm 700-1200 psi, changing circulation direction to prevent plugging or blowing stripping rubber and continue making hole and flushing well. Washed/milled singles down then reversed hole clean (closing pipe rams to keep pressure off stripping rubber). At 10,816' started pressuring up while reversing-attempted several times to regain rev circ rocking fluid back and forth. Continued circ long way @ 4.5 BBIs 1150 PSI while building high visc pill w/50 bbls FIW& 6 sacks of Barazan-D. Pump 50 BBLS Hi-Vis sweep down tb @ 4.5 bpm w/ 1050 PSI- Rot @ 50 RPM and worked pipe while pumping pill around (LW)- regained rev circ. Continued milling and washing from 10,816 to 10,824' tq running 6500-7500 psi- mixed 1 Drum of CFS-520 w/20 bbls FIW Pill and pump LW to btm. We'll determine if friction reducer helps once it comes around. 05/03/2017-Wednesday Serviced rig& Hilcorp tongs. After pumping CFS-520 we determined that it had little to no effect on relieving our torqueing issues. B/O L/D swivel and attempted to POOH (from 10,824') - hit jars in efforts to pull free -decision was made to P/U swivel to aid in POOH. Broke circ LW at 3.5 bpm 550 psi and began pumping workstring OOH (unable to reverse). Pulled/laid down 5 singles which put us at 10,692' (1330 hrs). Circ- rotated-worked pipe for 70 mins before pulling free. Pulled 2 more singles w/swivel- no drag. Laid down swivel. POOH to KOT BHA#8. L/D 4-4 3/4" DCs. B/O 6" bladed mill- 90%worn, heavy damage on OD due to milling on junk. M/U KOT BHA#9 (6" x 2 1/4" bladed mill, 2-4 3/4" x 2 1/4" oil jar, 2-4 3/4" x 2 1/4" DCs, 4 3/4" x 2 1/4" XO sub= 79.92').TIH w/ BHA on 3 1/2" PH-6 workstring t/TOL @ 9543'. R/U head pin and reverse circulate @ 3.5 BBLS min w/375 PSI one tubing volume. Continue RIH w/ PH6 workstring t/9953'. R/U head pin and reverse circulate btms up @ 3.5 bpm 425 PSI. Continue RIH w/ PH6 Workstring t/ 10,476. R/U head pin and reverse circulate btms up @ 3.5 bpm 400 PSI. Continued in hole and tagged at 10,651' (20' in on #341). Rigging up power swivel. • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-43RD Moncla 404 50-733-20373-01 185-311 4/18/17 5/11/17 DailyOperations: 05/04/2017-Thursday Finished P/U power swivel w/single#341 (10,6311)- installed stripping rubber and M/U to string- landed rubber in stripping head. 122k UW, 98 DW, 108 RotW, 3000 Tq, 50 RPM, 3.3 bpm 400 psi. Eased down and tagged at 10,651'- milled thru 4' tight spot (slight amount of metal and fines in returns). Ran in singles w/swivel to 10,725'- noticed minor weight loss and began rotating and reversing btms up each jt down-continued in hole to 10,817'. M/U single#347 and continued w/ cleanout reversing 3.5 bpm 450 psi to previous TD at 10,824'. Pressure began increasing-at 1350 psi, shutdown pump and began pumping LW at 4 bpm 900-1300 psi. Mixed 20 bbl Barazan-D+sweep and pumped it at the EOJ (10,848')followed by 75 bbls FIW. Mixed 60 bbls sweep-continued clean out F/ 10848 T/ 11003' pumping 20 bbl hi-vis sweeps every 30' followed by FIW @ 4.5 bpm 700-1000 psi. Mixed and pumped 25 bbls Hi-Vis sweep (vis cup 90 sec) around @ 11,003' 4.5 bpm 800-1000 psi, ROT @ 50 rpm and reciprocate pipe 20'. Shutdown pump and attempt to POOH- no go. Break circ LW and began pumping OOH laying down singles. 3 singles out at report time = 10,910'. 05/05/2017- Friday Continued POOH L/D singles using power swivel and pump-from 10,910' to 10,651'-worked twice at tight spot and popped thru- pulled to EOJ (10,631') w/o circ or turning. Set back swivel. Pulled from 10,631'to 9,518' (inside 9 5/8") with no drag (12 singles laid down and 18 stands racked back). Lined up casing valve to production header-cleaned rig tank pumping fluids away thru header to TBF. Slipped and cut 120' of 1" swaged drill line while cleaning tank. RIH f/9518't/ 10631'. Rig up to take on FIW from production and rig up return line to production header. Hold PJSM w/ rig crew and production crew. Start displacement down PH6 workstring and take returns thru production header t/TB @ 3.75 BBIs min w/800 psi. Final circ pres 800 PSI to pump 1040 BBIs. R/D monitor well 10 mins ok. POOH w/ Ph6 Worktring and stand back in derrick tot 170 stands. Lay Down BHA #9 (all KOT tools). N/D 7 1/16" stripping head and pulled wear bushing. 05/06/2017-Saturday M/U 3 1/2" test jt w/pumpin, SV, IBOP on top,test plug on btm- landed same and filled system w/ FIW. Shelled tested to 3500 psi-worked thru minor leaking issues.Tested all BOPE to 250 psi low/3500 psi high as directed by Sundry (tested annular to 250 psi low/2500 high) in accordance with AOGCC and Hilcorp requirements. Performed successful koomey draw down test. Test witness waived by Mr. Regg/AOGCC 9:31 AM 5/4/17. Cleared floor of test equipment and P/U Halb RTTS tool (5.85" OD x 2 .44" ID x 5.85' Length). M/U on 1st stand.TIH on 3 1/2" 12.95# P-110 PH-6 workstring at 100 fpm (as directed by Halb)to 9802', UW 126K DW 84K- picked up string 5' and turned pipe 2 1/2 RRHT setting 17k down on tool @ 9,797'. Lined up to test 9 5/8" x 7" casing- pumped down annulus @ 1/2 bpm t/ 1600 psi (total bbls pumped = 3.2 bbls)- charted test for 45 mins-good test. Bleed off pres t/0- unset RTTS- monitored well f/10 mins. POOH standing back 5 stds (17 stands total in derrick)- continue POOH laying down 3 1/2" PH6 workstring. 235 of 315 jts laid down at report time (depth = 2,496'). • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-43RD Moncla 404 50-733-20373-01 185-311 4/18/17 5/11/17 Daily Operations: 05/07/2017-Sunday Finished POOH f/2,496' laying down PH-6 workstring. B/0 L/D RTTS tool. Held PJSM w/rig and crane crew, production, Halb rep &WSM. Moved handling tools to rig floor and M/U 445' of 4 5/8" 5 SPF 60* phase EHC Idd w/39 grm Millennium charges+ needed hardware-total length = 525.01'. TCP assembly diagram in '0' drive.TIH w/TCP assy picking up 3 1/2" 9.2# L-80 SuperMax tb-strapping, drifting and torqueing to specs. Ran in a total of 272 jts of 3 1/2" SuperMax at report time = 9,573.56' 05/08/2017- Monday Continue RIH picking up 3 1/2" 9.2# L-80 SuperMax prod tb strapping, drifting and torqueing to specs-total of 285 jts RIH = 10,006.97'. M/U XOs f/3 1/2" PH-6 then continued RIH w/stands to 10,904' (PM) (14 1/2 stands) - M/U 6' & 10' pups. R/U Pollard EL w/pumpin, SV& lift pup- hung top sheave in derrick. RIH w/ 1.7" GR/CCL to 10,422'- pulled correlation log to 9,870' and sent las & pdf file to Geologist for verification. Depth shifted corr pass 1' uphole as per Geo (pdf in '0' drive). POOH R/D EL. S/0 below firing depth and pulled into position- pumped down tb pressuring up to 1900 psi firing guns as per perf detail. B/D L/O pups and 16 singles of 3 1/2" PH-6 workstring (10,442') to get above perfs. 1430 hrs lined up and reversed two btms up 3.4 bpm 350 psi- 20 bbls to get returns (losing 10 bph while circ). L/D power swivel. Finished L/D all PH-6 workstring- laid down 31 jts of 3 1/2" SuperMax and stood back 127 stands (8,442'). R/U and Hold PJSM w/crew laying down TCP guns total 445' guns all guns fired. Finished clean up floor and remove stripper rubber from hydril, pull wear ring, clean up and swap power tongs. R/U summit tools. Continue R/U ESP cables and hang sheave in derrick. R/U spooler. 05/09/2017-Tuesday Continue r/u spooler and cables. PJSM w/crew start to p/u Summit ESP Assy. RIH with Summit ESP/SPM assembly on 3- 1/2", 9.2# L-80 SuperMax tubing (re-used) and GLMs clamping power cable and flatpack as needed.Test insulation every 1000'. 55 BBL FIW pumped to keep hole filled 06:00- 18:00. Filling hole as needed with FIW. M/U GLM#5 at 2477'. Driller notices deformation to 3-1/2" top pup of GLM#5 assembly.Attempt to drift pup unsuccessful. B/O & L/D GLM#5. Contact HAK Ops Eng.to notify and continue RIH w/3-1/2" Supermax tubing completion using GLM#4. Slide all GLMs down one slot and continue RIH w/completion. Call PWL and order 3-1/2" pup to replace deformed pup. Will replace damaged pup and move GLM#5 uphole to GLM# 1 slot. Continue RIH with Summit ESP/SPM production assembly on 3-1/2", 9.2# SuperMax tubing from 2477' to 5092'.Test insulation every 1000'. Summit made power cable splice at 5092'. Check insulation -Good. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-43RD Moncla 404 50-733-20373-01 185-311 4/18/17 5/11/17 Daily Operations: 05/10/2017-Wednesday Continue RIH with Summit ESP/SPM production assembly on 3-1/2", 9.2#SuperMax tubing from 5092' t/8588'.Test insulation every 1000'. P/U Tripoint 9 5/8" dual hydraulic ESP packer. Summit made splice through 9 5/8" PKR. Test insulation -Good test. Cycle vent valve-Good Test. RIH w/9-5/8" Dual Hydraulic ESP packer and ESP/SPM production completion on 1 joint of 3-1/2", 9.2# EUE tubing from 8602' to 8634'. P/U SSSV, make up control line. Cycle SSSV-Good test. RIH w/ ESP/SPM production completion on 3-1/2", 9.2#SuperMax tubing. NOS rep M/U tubing hanger. M/U landing joint. Summit built penetrator splice and plumb same through tubing hanger. NOS plumbed control lines through hanger. Slacked off, landing hanger with 80K down, est. P/U 110K, end of pump at 8999.92'. Ran in hold down pins and packed off void. Clear rig floor of all Summit equipment and L/D Summit sheaves. R/U SLU. RIH with 2.80" GR to top of plug at 8820' WLM. POOH and S/B SLU. Pump FIW to fill tubing ahead of bar, drop bar, pump FIW to pressure up tubing to 3800 psi to set 9-5/8" Dual Hydraulic ESP Packer. Hold for 30 minutes and bleed off t/0 test ann t/1700 psi 30 mins all good/ bleed off. R/D test Equip. 05/11/2017-Thursday Continue R/U Wire line and RIH and latch up rod. POOH L/D rod. Makeup run#2 RIH and latch up plug. POOH L/D plug and R/D W.L. Make up BPV w/ NOS and run in hole. Set BPV and r/d running tool. Continue rigging down floor and put all tools way. Pressure wash BOP stack and rig down Moncla rig floor and remove floor. Scope derrick down and tie up all cables. Lay derrick down on carrier for crane work. Continue N/D BOP stack and riser remove with crane. Washing and cleaning drill deck. Nipple up WH tree. Plumb control lines and power cable thru tree adapter. Summit tested ESP power cable -good test. NOS rep test pack off void, 500 psi(5 min.), 5000 psi (15 min.) -Good Test. NOS Pull BPV, Set 2-way check. NOS Pressure tested tree, 5000 psi (5 min.) -Good Test. NOS Pull 2-way check.Turn over well to production at 23:00 hours. STATE OF ALASKA ' AL.OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: Pull/Reset PatchO 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 185-311 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-733-20373-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 Trading Bay Unit/D-43RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Middle Kenai G and Hemlock Oil Pools 11.Present Well Condition Summary: Total Depth measured 11,250 feet Plugs measured 11,166 E C E I V E D true vertical 10,083 feet Junk measured N/A feet APR 2 5 2017 Effective Depth measured 10,734 feet Packer measured 9,840 feet true vertical 9,634 feet true vertical 8,876 feet AOGCC Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3,069' 13-3/8" 3,069' 2,907' 3,450 psi 1,950 psi Intermediate 9,409' 9-5/8" 9,409' 8,505' 6,870 psi 4,760 psi Intermediate 432' 9-5/8" 9,841' 8,877' 9,440 psi 5,300 psi Liner 1,707' 7" 11,250' 10,083' 8,160 psi 7,020 psi Perforation depth Measured depth 10,024-10,727 Q� -- %AN E iviA.s , 1' z C True Vertical depth 9,033-9,628 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/N-80 9,914(MD) 8,939(TVD) Packers and SSSV(type,measured and true vertical depth) Baker FA-1 Packer 9,840'(MD)8,876'(TVD) TRDP-1A SCSSV 293'(MD)293'(TVD) 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: 96 10 226 1060 140 Subsequent to operation: 82 20 640 1200 200 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑., Exploratory❑ Development 0 Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-104/ 'I'-j- -144 Authorized Name: Stan Golis 777-8356 Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hilcorp.com Authorized Signature: 5L1.3 17 4 Date: 11/ZS 1-4)1 7 Contact Phone: 907-283-1329 54 5'1147 l RBDMS LUMA - 3 26`17 Form 10-404 Revised 4/2017 C'07 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-43RD E-Line/Slickline 50-733-20373-01 185-311 4/1/17 4/2/17 Daily.Operations: 04/01/17-Saturday PJSM,JSA& Permits. R/U SLU. M/U 1.75" TS: RS, 10' Weight Bar, 3' OJ, 7' LSSJ. PT LUB &WLV= 3000 psi. RIH w/2.75" GR to 3,054'. POOH. L/D GR. P/U 3" GS Spear. RIH to 3,054',top of 3-1/2" AA Stop. Latch Stop, work tools, 2 spang licks, POOH. OOH with AA Stop, L/D same, RIH w/3" GS Spear to 3,056'. Latch Upper Packoff, work tools, POOH. OOH with Upper Packoff, Stinger and Lower Packoff. L/D same. RIH w/3" GS Spear to 3,071'. Latch AD-2 Stop, work tools, POOH. OOH with AD-2 Stop, L/D same. RIH w/2.75" GR to 10,730' WLM. POOH. L/D GR. P/U 2.50" X 25' spent HSC dummy gun. RIH with dummy gun to 10,734'. POOH. RD SLU. Secure well and drill deck. SDFN.Job in Progress. 04/02/17-Sunday PJSM,JSA& Permits. RU Eline unit. PT LUB and WLV= 250 psi LO/3000 psi HI. M/U tool suite: GR/CCL+Gun# 1(2.50" X 16' GeoDynamics Razor, 6 SPF, 60 deg. phase). GR/CCL to top shot= 9.50'. Initial T/IA/OA=1100/1100/80,RIH with Gun# 1 to tag depth at 10,707' GR/CCL UNCORRECTED. PUH logging for correlation and depth correction. Shift GR/CCL= 6.0'. Send correlation logging pass to HAK Geologist for depth correction/correlation verification. Shift GR/CCL depth (-)2.0' per HAK Geo. RIH to tag depth, PUH to place shots on depth GR/CCL= 10,701.7' CORRECTED. Fire shots perfing 10,711' - 10,727'. PUH logging and POOH.T/IA/OA= 1100/1100/80, OOH with Gun# 1. L/D Gun# 1. P/U Gun#2 (2.50" X 25' GeoDynamics Razor, 6 SPF, 60 deg. phase). GR/CCL to top shot= 9.50'.T/IA/AO = 1150/1150/80. RIH with Gun#2 to 10,650'. Pull up for correlation log 10,650' - 10,260'.TIH to 10,600' Corrected. Log shots on depth, GR/CCL= 10555.5'. Fire shots. Perf 10,565' - 10,590.1,PUH logging and continue POOH. OOH with Gun#2. L/D Gun# 2, shots fired. P/U Gun#3 (2.50" X 25' GeoDynamics Razor, 6 SPF, 60 deg. phase). GR/CCL to top shot=9.50'.T/IA/OA= 1150/1150/80. RIH with Gun#3 to 10,650'. Log up to correlate/correct depth 10,650' - 10,240'. TIH to 10,578'. Log up to place shots on depth, CCL/GR= 10,530.5'. Fire shots. Perf 10,540' - 10,565'. PUH logging and continue POOH.T/IA/OA= 1160/1160/80. OOH with Gun#3. 2/ L/D Gun#3, shots fired. P/U Gun#4 (2.50" X 25' GeoDynamics Razor, 6 SPF, 60 deg. phase). GR/CCL to top shot= 9.50'. T/IA/OA= 1200/1200/80. RIH w/Gun#4 to 10,650'. Log up to correlate/correct depth 10,650' - 10,290'.TIH to 10,560'. Log } up to place shots on depth, CCL/GR = 10,505.5'. Fire shots. Perf 10,515' - 10,540'. PUH logging and continue POOH.T/IA/OA= 1200/1200/80. OOH with Gun#4, shots fired. R/D Eline unit, prep all loads for boat to beach.Turnover well to Slickline. PJSM, JSA and Permits. RU SLU. M/U 1.75" TS: RS, 10' STEM, 3' OJ, 7' LSSJ. PT LUB & WLV= 3000 psi. RIH with 3" GS+ 3-1/2" AD-2 Stop to 3,071' KB. Work tools, set AD-2 Stop, shear off and POOH. RIH with 3" GS+ 1.90" X 10' Spacer Pipe+ 3-1/2" Lower Pack Off to 3,071' KB. Work Tools, set patch, shear off and POOH. RIH with 3" GS +3-1/2" Upper Pack Off to 3,057' KB. Work tools, set Pack Off, shear off and POOH. RIH with 3" GS+AA Stop to 3,056' KB. Work Tools, set Stop, shear off and POOH. Standby for Production to test patch. Open well to production -Tubing Pressure = 500 psi, IA Pressure = 1000 psi-GOOD TEST. R/D SLU. Secure well and drill deck. Clean area and move SLU package to pipe deck. Fly crews to beach.Job Ended. •14 rthur River Field, TBU D-43RD SC I-I E MATI C Completed: 1986-02-23 API: 50-733-20373-01 Hilcorp Alaska,LLC PTD: 185-311 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 68 K-55 Butt 12.415" Surf 3,069' 1 N-80 Butt 8.681" Surf 9,409' 9-5/8" 47 P-110 8 round 8.681" 9,409' 9,841' --- 2 ' 7" 29 N-80 Butt 6.184" 9,543' 11,250' TUBING DETAIL 31/2" 9.2 N-80 Butt. 2.992" Surf. 9,914' fl Pan 1111 JEWELRY DETAIL 3,056' to No Depth Depth ID Item 3,071' (MD) (TVD) 1 41' 41' CIW'DCB'Tbg.Hgr. 2 293' 293' 2.812 Camco TRDP-1A SCSSV 2.812"profile flapper type w/CS 3 lock 2,134' 2,113' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 4,453' 4,101' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 6,074' 5,511' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch I 3 7,281' 6,571' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,204' 7,395' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,834' 7,976' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch In9,310' 8,416' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 4 9,686' 8,745' 2.880 2.88"Drift Camco'KBUG-CP'Mandrel --1"Nova installed III on 10/2/08 5 9,779' 8,824' 2.880 2.88"Drift Camco'KBUG-ELTS'Injection Mandrel.1-1/2" Z I 4 E RK Latch 6 9,828' 8,866' 2.880 Baker Locator 2.88"Drift G 5 7 9,840' 8,876' Baker'FA-1'Packer 8 9,843' 8,878' 2.990 Baker Seal Assy.2.88"Drift.3 Jts 3-1/2"Tbg tail pipe 2.99"ID 9 9,914' 8,939' 3.000 Half-cut mule shoe 3.00"ID 6 PERFORATION DETAIL Top Btm Top Btm 7 Zone Amt SPF Date Comments A . o- (MD) (MD) (TVD) (TVD) G-2 10,024' 10,048' 9,033' 9,053' 20' 8 G-4A 10,272' 10,282' 9,242' 9,250' 10' G-4A 10,192' 10,206' 9,175' 9,186' 14' III 9 G-4A 10,149' 10,169' 9,138' 9,155' 20' HK-1 10,460' 10,492' 9,400' 9,427' 32' G 2 K-2 ~ 10,515' 10,590' 9,477' 9,511' 75' 04/02/17 -G-4A (H-1(-2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open -G-4 HK-3 10,604' 10,696' 9,523' 9,601' 92' HK-4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open HK-1 ✓ HK-2 ✓ HK-4 10,711' 10,727' 9,614' 9,628' 16' 04/02/17 HK-3 HK-4✓ MIMIttt# H .. - Notes: 02/16/12 2.70 GR tag at 10,734' TD=11,250' PBTD=11,166' Devi=31'(10,600') Fish: 2 GL Valves Updated: 04/04/17 by AL 1.4 OF 7'4 • g4•e" //yA THE STATE Alaska Oil and Gas �� o Conservation Commission fALASI�:A ;zt = 333 West Seventh Avenue 1,4741170114r- GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan APP.Golis �y, Operations Manager 414�� 1 2 Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU D-43RD Permit to Drill Number: 185-311 Sundry Number: 317-144 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 1®'ay of April, 2017. RBDMS pit-APR 1 0 2017 • • • RECEIVED STATE OF ALASKA APR 00 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION ' .5,-/-76i APPLICATION FOR SUNDRY APPROVALS AOGCA7 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate El, Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. GL/ESP Completion El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ` Exploratory ❑ Development I] . 185-311 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20373-01 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A • Will planned perforations require a spacing exception? Yes 0 No 0 ✓ Trading Bay Unit D-43RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools • 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): 11,250 - 10,083 . 10,734 • 9,634 2,543 psi • 11,166 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3,069' 13-3/8" 3,069' 2,907' 3,450 psi 1,950 psi Intermediate Production 9,841' 9-5/8" 9,841' 8,887' 6,870 psi 4,760 psi Liner 1,707' 7" 11,250' 10,083' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,024-10,727 -, 9,033-9,628 3-1/2" 9.2#/N-80 9,914 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker FA-1 Pkr&TRDP-1A SCSSV 9,840'(MD)8,876'(TVD)&293'(MD)293'(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/21/2017 OIL 0 • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.IGolis Title Operations Manager ti. Signature . LJ.Jli6 Phone (907)777-8356 Date C>r"'E I Oil / G. CD 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number '1-7- ( `-f Plug Integrity ❑ BOP TestMechanical Integrity Test ❑ Location Clearance ❑ �(e Other: X3 gob '1St ,e P .T..est °'t ` ` f s- Post Initial Injection MIT Req'd? Yes ❑ No �/❑, Spacing Exception Required? Yes ❑ No Lh Subsequent Form Required: /0 ib o LI RBDMS '/APR 1 0 2017 APPROVED BY Approved by:gic+4.1(4„.____ COMMISSIONER THE COMMISSION Date: 4. _ /0 . 17 Submit Form and Form 10-403 Revised 11/2015 ORleGliNrt Ildor 12 months from the date of approval. Attachments in Duplicate • Well Prognosis Well: D-43rd Ililcarp Alaska,LLC Date: 04/04/17 Well Name: D-43rd API Number: 50-733-20373-01 Current Status: Gas-Lifted producer Leg: Leg#A-1 NE corner Estimated Start Date: April 21, 2017 Rig: Moncla 404 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 185-311 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) Current Bottom Hole Pressure: 3,554 psi @ 9,315' TVD 0.437 psi/ft mid pert 2009 SIBHP Maximum Expected BHP: 3,554 psi @ 9,315'TVD 0.437 psi/ft mid pelf 2009 SIBHP Maximum Potential Surface Pressure: 2,543 psi v Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Brief Well Summary Well D-43rd is a gas-lifted oil well with a comingled completion in the G and Hemlock zones.This project will install a combination gas-lift/ESP completion to increase productivity. Last Casing Test: 02/20/1986 tested IA at 9840'to 3,000 psig. �sr t �,�� P Procedure: 1. MIRU Moncla Rig#404. 2. Pull lowest GLV and circulate hydrocarbon off of well. Work over fluid will be FIW. SOP's will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. RU E-line and cut tubing above packer at±9,825'. 6. Unseat hanger and POOH with gas-lift completion. 7. RIH with tapered cleanout assembly to±9,825', circulate clean, POOH. 8. Mill and recover Production packer at 9,840'. 9. RIH with cleanout assembly to ±11,000', circulate clean, POOH. 10. RIH with RTTS to±9,800' and test casing to 1500 psig and chart for 30 minutes 11. Contingent- RIH with Storm packer, set same at 200' and hang off string. Pressure test to 1500 psi. Release from storm packer, POOH. Install new casing spool. Retest all BOP breaks to. ,56a psi and + chart. POOH with storm packer. 3Goo . . 12. PU TCP guns, RIH and perforate per the Perf recommendation. It!c FO �b hex 13. After detonation, circulate perf gas, confirm well is static, POOH. 14. PU and RIH with new combo gas-lift/ESP assembly. f5 3c a. A high set packer, packer vent valve, and SSSV will be ran if well indicates ability to flow to k'l P. surface. / tt° r-at.r_'"- ) 15. Set BPV, ND BOP, NU wellhead and test. 5 0 p s c' 16. Turn well over to production. I-T_s.A) 17 17. Conduct SVS testing per AOGCC regulations. 18. If applicable (packer and SSSV not installed)-Schedule no-flow with AOGCC as per regulations. S • Well Prognosis Well: D-43rd xi!carp Alaska,LLC Date: 04/04/17 Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. Wellhead Schematic Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form Arthur River Field, TBU , • SCHEMATIC Well: D-43RD Completed: 1986-02-23 API: 50-733-20373-01 naeurp Ala.ka,I,LC PTD: 185-311 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. \ 13-3/8" 68 K-55 Butt 12.415" Surf 3,069' 1 N-80 Butt 8.681" Surf 9,409' 9-5/8" 47 P-110 8 round 8.681" 9,409' 9,841' 2 / 7" 29 N-80 Butt 6.184" 9,543' 11,250' TUBING DETAIL 3-1/2" 9.2 N-80 Butt. 2.992" Item Surf. 9,914' Tubing JEWELRY DETAIL il 3,056' `� No (MD)Depth Depth 3,071' (ND) ID 1 41' 41' CIW'DCB'Tbg.Hgr. 4 2 293' 293' 2.812 Camco TRDP-1A SCSSV 2.812"profile flapper type w/CS 3 lock 2,134' 2,113' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch Iii4 4,453' 4,101' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 6,074' 5,511' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 3 7,281' 6,571' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,204' 7,395' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch ii 8,834' 7,976' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 9,310' 8,416' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 4 9,686' 8,745' 2.880 2.88"Drift Camco'KBUG-CP'Mandrel --1"Nova installed on 10/2/08 2.88"Drift Camco'KBUG-ELTS'Injection Mandrel.1-1/2" 5 9,779' 8,824' 2.880 RK Latch S 4 6 9,828' 8,866' 2.880 Baker Locator 2.88"Drift L 5 7 9,840' 8,876' Baker'FA-1'Packer 8 9,843' 8 878 2 990 Baker Seal Assy.2.88"Drift.3 its 3-1/2"Tbg tail pipe 2.99"ID 9 9,914' 8,939' 3.000 Half-cut mule shoe 3.00"ID ',6 PERFORATION DETAIL 7 Zone Top Btm Top Btm Amt SPF Date Comments XIXI-� (MD) (MD) (ND) (ND) G-2 10,024' 10,048' 9,033' 9,053' 20' 8 G-4A 10,272' 10,282' 9,242' 9,250' 10' G-4A 10,192' 10,206' 9,175' 9,186' 14' 9 G-4A 10,149' 10,169' 9,138' 9,155' 20' HK-1 10,460' 10,492' 9,400' 9,427' 32' G-2 HK-2 10,515' 10,590' 9,477' 9,511' 75' 04/02/17 -G-4A HK-2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open =G 4 HK-3 10,604' 10,696' 9,523' 9,601' 92' HK-4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open HK-1 p HK-2 HK-4 10,711' 10,727' 9,614' 9,628' 16' 04/02/17 HK-3 - HK-4 Notes: L \ 02/16/12 2.70 GR tag at 10,734' TD=11,250' PBTD=11,166' Devi=31"(10,600') Fish: 2 GL Valves Updated: 04/04/17 by JLL 4/P 0 McArthur River Field,TBU Well: D-43RD PROPOSED Completed: FUTURE API: 50-733-20373-01 PTD: 185-311 Hileorp Alaska,LL(: CASING DETAIL 1;64--- SIZE WT GRADE CONN ID TOP BTM. j 13-3/8" 68 K-55 Butt 12.415" Surf 3,069' 9,409' 1 11 9-5/8'' 47 N-80 Butt 8.681" Surf A 2 I Sb� P P-110 8 round 8.681" 9,409' 9,841' , 7" 29 N-80 Butt 6.184" 9,543' 11,250' TUBING DETAIL 3-1/2" 9.2 1-80 Supermax 2.992" Surf ±8,550' 1 JEWELRY DETAIL 11119 No Depth Depth ID OD Item 3-11 (MD) (TVD) 1 ±350' ±350' 2.813" Contingent-SSSV a 2 ±400' ±400' Contingent-Packer w/Vent valve 1 3 ±2,230' ±2,200' GLM#1 4 ±3,181' ±3,000' GLM#2 5 ±3,874' ±3,600' GLM#3 6 ±4,625' ±4,250' GLM#4 cal12 7 ±5,199' ±4,750' GLM#5 8 ±5,774' ±5,250' GLM#6 9 ±6,349' ±5,750' GLM#7 -=r 10 ±6,918' ±6,250' GLM#8 NE 11 ±8,470' ±7,639' GLM#9 13 12 ±8,500' ±7,666' Contingent-X Nipple SZ Bolt on Discharge Head Pump G 13 Seals Motors ±8,700' ±7,851' Centralizer Anode PERFORATION DETAIL Zone Top Btm Top Btm (MD) (MD) (TVD) (TVD) Amount SPF Date Comments G-2 10,024' 10,048' 9,033' 9,053' 20' G-4A 10,272' 10,282' 9,242' 9,250' 10' G-4A 10,192' 10,206' 9,175' 9,186' 14' =G-2 G-4A 10,149' 10,169' 9,138' 9,155' 20' =G-4A HK-1 10,460' 10,492' 9,400' 9,427' 32' G-4 HK-2A ±10,455' ±10,487' ±9,396' ±9,423' ±32' Future =G-4 HK-1 HK-2 10,515' 10,590' 9,477' 9,511' 75' 04/02/17 HK-2A HK-2 ±10,516 ±10,587' _9+ 448', ±9,508' ±71' Future um HK-2 = HK-2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open HK-3 HK-3 ±10,604' ±10,687' ±9,523' ±9,593' ±83' Future HK-4 HK-3 10,604' 10,696' 9,523' 9,601' 92' =HK-5 _ \ HK-4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open ;+ 3;:aiHK-3& TD=11,250' PBTD=11,166' HK-4 ±10705' ±10,837' ±9,609' ±9,722' ±132' Future Devi=31"(10,600') HK-4 10,711' 10,727' 9,614' 9,628' 16' 04/02/17 HK-5 ±10,875' ±10,900' ±9,755' ±9,777' ±25' Future Updated 04/04/17 byJLL • 0 . IIDolly Varden Platform D-43RD Current 03/23/2017 Itilcnrp Alaska. Dolly Varden Tubing hanger,CIW-DCB- D-43RD FBB,11 X 4'/:EUE 8rd lift X 13 3/8 X 9 5/8 X 3 1/2 4 Y2 IBT susp,w/4"type H BPV,2-1/8 non continuous control line ports,7" extended neck prep BHTA,CIW,w/internal knockup cap,4 1/16 5M FE IIIIIIIMIN n, w 11 Valve,CIW-F,4 1/16 5M FE, /0740.0 HWO,EEtrim -Alla 10 11.111011.1110. '` Tree,Block,CIW-F,11 5M X '� j1�l 0 Iw 4 1/16 5M run X 3 1/8 5M $ wing,double master and er . 1 74. 6 wing valve,EE trim prepped `J,i.` :—I. for 7"FBB type hanger neck, 4.. ft. w/'A control line exit 1 irteA Adapter,CIW-EN-2CL,11" -f 5M stdd x 11"SM stdd, c :Ijj,: — prepped for 2 control line g/ ,,, _ :, outlets,7"hanger neck r — :AObottom and seal carrier t:AO 11:.= Tubing head,CIW-DCB, 135/83MX115M,w/2- 2 1/16 5M SSO,X bottom 4 07*` ` Valve,CIW-F,2 1/16 SM FE, 111...„:11111 � ��11 iml �� ���1 11,4., HWO,AA trim 4° 7:- a _ tit i fill �, S'1 Casing head,CIW-WF, a�� 13 5/8 3M X 13 3/8 casing 1lt, ii/ III Valve,CIW-F,2 1/16 5M FE, thread bottom,w/2-2 1/16 OI 5MEFO = _ _ HWO,AAtrim = %.0 •_ • i ' II Dolly Varden Platform D-43RD Proposed 03/23/2017 Ifilmrp Alstrka.LTA: Dolly Varden Tubing hanger,CIW-DCB-ESP, D-43RD 11 X 3'/:eue lift and susp,w/ 13 3/8 X 9 5/8 X 31/2 3"type H BPV profile,5%EN, 2-3/8 continuous control line ports,prepped for BIW penetrator BHTA,Bowen,3 1/8 5M FE X 3"Bowen top lei t1E 111 MEP III in Valve,swab,WKM-M, ©k 31/8 5M FE,HWO, � 1 T-24 Valve,Wing,WKM-M, IS 3 1/8 5M FE,w/15" ++ — II' OMNI operator,DD trim Valve,wing,WKM-M, 4 °\I ll 11,4044 l��o I O II T-24 I. vat III Valve,lower master,WKM-M, -L --, 3 1/8 5M FE,HWO,T-24 .S III°MIuI 11.1110 AEI Il III Adapter,CIW-Toadstool, 11 5M 1 Stdd X 3 1/8 5M FE,prepped for j(, S� N` 5'/4 ESP neck,2-Y2 npt continuous /J -H9)-''r'' I a control line ports Tubing head,CIW-DCB, � 6I 13 5/8 3M X 11 5M,w/2- 11 .• 1 pGi= I 2 1/16 5M SSO,X bottom •� Int It Valve,WKM-M,2 1/16 5M FE, �•� HWO,DD gc.11 1l� F ,6 Qty 2 f 2 ®40` • AMIII,_.: ' ■ 3oOO to head,CIW-WF, pl 13 5/8 3M X 13 3/8 casing �I� Valve,CIW F,21/16 5M FE, thread bottom,w/2- lit (r III HWO,AA trim is 2 1/16 5M EFO,CA slips installed in head 11110.1 0��i �� L lir" • . ti Dolly Varden Platform Moncla BOP 12/19/2016 Hilrnrp Alaek;■,LLL al &dm- ,_ J 4.54 .3- Hydril - GK 13 5/8-5000 I 111 .11, '111 111111 1 IWU3 !I III CI c CIW-U E. 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ZQ oD z m Z 5 J .4411 ' , _ D U fY0 • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again,right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT)is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) • • Moncla Rig 404 BOP Test Procedure Hilearp Alaska,LLC Attachment#1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1sT valve on standpipe manifold, close valves 1,2, 10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint,close outside valve on kill side of mud cross,open 15t valve of standpipe, close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross, close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to—1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross),open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. • r • II Moncla Rig 404 BOP Test Procedure Hilrnrp Alaska,LLC Attachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed(e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form(10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • 0 � � CD a / > W2 0 . Cac 2E 002 cw <a E § 3 )cp Th- a) § > ■ \ § I �� £ ff k / / .0 et" > a > = fay / o .§ CD- _ § ED / CI -0 ■ ■ 7 m $ 2 a ) G cCC 2 � c c E7 2 J @ c f £ W 0 CO � ƒ CD a -a " U \ g eL % CL as ..-.:E:' / c = = \ CO C) -.E. k L. ■ E G ° 0 0 k ° C ca a AC 2 o k � k S » O ■ C) "cs »7 c c § c ¢ . Cl) $ p 2 us t ) > 0 2 1.4 CD 2 § � a o / Q / \ 0 cc ci 4 o x q t E 0.0 _ 3 a ■ a Q $ x 0) Icc n .� Ca § x 0 0 0- 0 2 0 � w .2 2 J 0 .. _ % \ m U Z ° / > RS .0 2 > 0 u co 0 U) 2 '- COCD 2 • • .i,OF T� ifr\�����yy��A THE STATE Alaska Oil and Gas --tom o f \ e c��lrl 4 Conservation Commission 1�L�1V Let& i, 333 West Seventh Avenue ^ti_ f GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �-� Main: 907.279.1433 F ALAel Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager E (� Hilcorp Alaska, LLC SON 17- 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU D-43RD Permit to Drill Number: 185-311 Sundry Number: 317-104 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /16 Cathy 7 Foerster Chair DATED thisay of March, 2017. REDms (rte vif51 r. 3 20 • • RECEIVED STATE OF ALASKA / „ ALASKA OIL AND GAS CONSERVATION COMMISSION €vi,d;, 7 ` 017 APPLICATION FOR SUNDRY APPROVALS ^ O : C 20 MC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing 0 Change/� Approved Ptrogram 0 Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other. /�.k /i�rs.4 4 t€(1 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑ ' 185-311 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20373-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A ' Will planned perforations require a spacing exception? Yes 0 No 0 / Trading Bay Unit D-43RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 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): 11,250• 10,083 • 10,734 • 9,634 ' 2,543 psi 11,166 N/A Casing Length Size MD ND Burst Collapse Structural Conductor Surface 3,069' 13-3/8" 3,069' 2,907' 3,450 psi 1,950 psi Intermediate Production 9,839' 9-5/8" 9,839' 8,875' 6,870 psi 4,760 psi Liner 1,699' 7" 11,250' 10,083' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,024-10,718 • 9,033-9,620 3-1/2" 9.2#/N-80 9,914 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker FA-1 Pkr&TRDP-1A SCSSV 9,840'(MD)8,876'(ND)&293'(MD)293'(TVD) 12.Attachments: Proposal Summary 9 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development D v Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 3/25/2017 Commencing Operations: OIL 0• WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilco •.com Printed Name Stan W`)G�olis �(/_ Title Operations Manager Signature `" • i`.•. Phone (907)777-8356 Date 3 r 1 /Z0 i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 37- k LE Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ s HSr 11 �t Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ra2/ Subsequent Form Required: ,-/0 4-t E' *s!S t L pp , APPROVED BY Approved by: P — COMMISSIONER THE COMMISSION Date: 54—/7 ?lam 3 �� f / ® 144011911 /.,�. �/7` / / Submit Form and Form 10-403 Revised 11/2015ap li �or�ii lfc�lid for 12 months from the date of app ll��66val. Attachments in Duplicate • • • Well Prognosis Well: D-43rd Hilcorp Alaska,LLC Date: 03/07/2017 Well Name: D-43rd API Number: 50-733-20373-01 Current Status: Gas-Lifted producer Leg: Leg#A-1 NE corner Estimated Start Date: March 25, 2017 Rig: N/A (E-Line) Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 185-311 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) Current Bottom Hole Pressure: 3,554 psi @ 9,315' TVD 0.437 psi/ft mid perf 2009 SIBHP Maximum Expected BHP: 3,554 psi @ 9,315'TVD 0.437 psi/ft mid pert 2009 SIBHP Maximum Potential Surface Pressure: 2,543 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Brief Well Summary Well D-43rd is a gas-lifted oil well with a comingled completion in the G and Hemlock zones.This project will add perforations in the Hemlock benches 2 &4. ✓ Procedure: 1. MIRU wireline, PT lubricator to 3,000 psi. 2. RIH with slick-line and pull tubing patch 3. Make full drift GR run and tag fill 4. Make Dummy gun run 5. RD slick-line 6. RU E-line and perforate as per program with well open to production 7. RD E-line 8. RU slick-line and reset tubing patch 9. RD slick-line and turn over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic rthur River Field, TBU • ,CHEMATIC• D-43RD coliP leted: 1986-02-23 API: 50-733-20373-01 Hilcorp Alaska,LLC PTD: 185-311 CASING DETAIL SIZE WT GRADE CONN TOP BTM. 1 / 13-3/8" 68 K-55 Butt Surf 3069' 9-5/8" 47 N-80 Butt Surf 9839' 2 7" 29 N-80 Butt 9551' 11250' TUBING DETAIL ^ � 3-1/2" 9.2 N-80 Butt. Surf. 9914' Tubing �/ Patch JEWELRY DETAIL oso toNo Depth Depth ID Item 3,068' (MD) (TVD) � a .15 1 41' 41' CIW'DCB'Tbg.Hgr. 2 293' 293' 2.812 Camco TRDP-1A SCSSV 2.812"profile flapper type w/CS lock 2,134' 2,113' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 4,453' 4,101' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 1) 6,074' 5,511' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 3 7,281' 6,571' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,204' 7,395' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,834' 7,976' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 9,310' 8,416' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 1. 4 9,686' 8,745' 2.880 2.88"Drift Camco'KBUG-CP'Mandrel --1"Nova installed on 10/2/08 5 9,779' 8,824' 2,880 Z B 2.88"Drift Camco'KBUG-ELTS'Injection Mandrel.1-1/2" 4 6 9,828' 8,866' RK Latch 2.880 Baker Locator 2.88"Drift G7 7 9,840' 8,876' Baker'FA-1'Packer ® 8 9,843' 8,878' 2 990 Baker Seal Assy.2.88"Drift.3 its 3-1/2"Tbg tail pipe 2.99"ID 9 9,914' 8,939' 3.000 Half-cut mule shoe 3.00"ID 1 6 PERFORATION DETAIL ,.i.i., Top Btm Top Btm N 7 Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments I-ire 6-2 10,024' 10,048' 9,033' 9,053' 20' 8 G-4A 10,272' 10,282' 9,242' 9,250' 10' G-4A 10,192' 10,206' 9,175' 9,186' 14' 9 G-4A 10,149' 10,169' 9,138' 9,155' 20' HK-1 10,460' 10,492' 9,400' 9,427' 32' _ HK-2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open G-2 HK-3 10,604' 10,696' 9,523' 9,601' 92' =G-4A =--G-4 HK-4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open G-4 HK-1 HK-2 HK-3 HK-4 Notes: 02/16/12 2.70 GR tag at 10,734' TD=11,250' PBTD=11,166' Devi=31"(10,600') Fish: 2 GL Valves Updated: 02/22/16 by JLL rthur River Field, TBU �ROPOSE� : D-43RD 14Completed: 1986-02-23 API: 50-733-20373-01 Hilcorp Alaska,LLC PTD: 185-311 CASING DETAIL SIZE WT GRADE CONN TOP BTM. I. 13-3/8" 68 K-55 Butt Surf 3069' 9-5/8" 47 N-80 Butt Surf 9839' 2 g 7" 29 N-80 Butt 9551' 11250' TUBING DETAIL 3-1/2" 9.2 N-80 Butt. Surf. 9914' Tubing II JEWELRY DETAIL oso toNo Depth Depth ID Item t" 3'068' (MD) (TVD) 1 41' 41' CIW'DCB'Tbg.Hgr. 2 293' 293' 2.812 Camco TRDP-1A SCSSV 2.812"profile flapper type w/CS 3 lock I 2,134' 2,113' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 4,453' 4,101' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 6,074' 5,511' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch I 3 7,281' 6,571' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,204' 7,395' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,834' 7,976' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch • 9,310' 8,416' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch III 4 9,686' 8,745' 2,880 2.88"Drift Camco'KBUG-CP'Mandrel --1"Nova installed on 10/2/08 5 9,779' 8,824' 2,880 2.88"Drift Camco'KBUG-ELTS'Injection Mandrel.1-1/2" 00RK Latch 4 6 9,828' 8,866' 2.880 Baker Locator 2.88"Drift i II 5 7 9,840' 8,876' Baker'FA-1'Packer 8 9,843' 8,878' 2 990 Baker Seal Assy.2.88"Drift.3 its 3-1/2"Tbg tail pipe 2.99"ID 9 9,914' 8,939' 3.000 Half-cut mule shoe 3.00"ID 1 6 PERFORATION DETAIL IR7 Zone Top Btm Top Btm Amt SPF Date Comments �_� W (MD) (MD) (TVD) (ND) G-2 10,024' 10,048' 9,033' 9,053' 20' 8 G-4A 10,272' 10,282' 9,242' 9,250' 10' G-4A 10,192' 10,206' 9,175' 9,186' 14' El 9 G-4A 10,149' 10,169' 9,138' 9,155' 20' HK-1 10,460' 10,492' 9,400' 9,427' 32' G-2 HK-2 ±10,515' ±10,590' ±9,477' ±9,511' ±75' FUTURE G-4A HK-2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open G-4 HK-3 10,604' 10,696' 9,523' 9,601' 92' HK-4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open HK-1 HK-2 ' HK-4 ±10,718' ±10,734' ±9,620' ±9,634' ±16' FUTURE H K-3 HK-4 444 Notes: A'..1,..40.,,-41r.L 02/16/12 2.70 GR tag at 10,734' TD=11,250' PBTD=11,166' Devi=31"(10,600') Fish: 2 GL Valves Updated: 03/06/17 by 1LL STATE OF ALASKA 11 E C E A KA OIL AND GAS CONSERVATION COM SION • REPORT OF SUNDRY WELL OPERATIONS ER 2 9 2°16 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ AuGICi ns shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate El Alter Casing❑ Change Approved Program El Plug for Redrill Cl Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well El Other: Install patch D 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development D Exploratory❑ 185-311 3.Address: 3800 Centerpoint Drive,Suite 1400 StratigraphiC❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20373-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 Trading Bay Unit D-43RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 11,250 feet Plugs measured 11,166 feet true vertical 10,083 feet Junk measured N/A feet Effective Depth measured 10,734 feet Packer measured 9,840 feet true vertical 9,634 feet true vertical 8,876 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3,069' 13-3/8" 3,069' 2,907' 3,450 psi 1,950 psi Intermediate 9,839' 9-5/8" 9,839' 8,875' 6,870 psi 4,760 psi Production Liner 1,699' 7" 11,250' 10,083' 8,160 psi 7,020 psi Perforation depth Measured depth 10,024-10,718 feet '' r' r- , s_�, i� k .4 ``) True Vertical depth 9,033-9,620 feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/N-80 9,914'(MD) 8,939'(ND) Packers and SSSV(type,measured and true vertical depth) Baker FA-1 Pkr 9,840'(MD)8,876'(ND)TRDP-1A SCSSV 293'(MD)293'(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: 98 84 241 1060 169 Subsequent to operation: 149 28 251 1072 134 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations D Exploratory❑ DevelopmentE Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil D Gas El WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-068 Contact Dan Marlowe(907)283-1329 Email dmarlowe(a)hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature b .q,.,, Phone (907)777-8356 Date l'ILII 14 3.-2-'6. /0 W Form 10-404 Revised 5/2015 RBDMS t,L-MAR 0 1 2016 Submit Original Only IIrthur D43RD River Field, TBU • SCHEMATIC Completed: 1986-02-23 API: 50-733-20373-01 Ilileorp Alaska,LLC PTD: 185-311 CASING DETAIL SIZE WT GRADE CONN TOP BTM. 1 13-3/8" 68 K-55 Butt Surf 3069' 9-5/8" 47 N-80 Butt Surf 9839' 2 I 7" 29 N-80 Butt 9551' 11250' III TUBING DETAIL 3-1/2" 9.2 N-80 Butt. Surf. 9914' Tubing DETAIL 3,050' I I 1 to Depth Depth Depth ID Item 3,068• (MD) (TVD) .. 1 41' 41' CIW'DCB'Tbg.Hgr. 2 293' 293' 2.812 Camco TRDP-1A SCSSV 2.812"profile flapper type w/CS 3 lock 2,134' 2,113' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch I 4,453' 4,101' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 6,074' 5,511' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch I 3 7,281' 6,571' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,204' 7,395' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,834' 7,976' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch III9,310' 8,416' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch in 4 9,686' 8,745' 2.880 2.88"Drift Camco'KBUG-CP'Mandrel --1"Nova installed on 10/2/08 5 9,779' g g24' 2.880 2.88"Drift Camco'KBUG-ELTS'Injection Mandrel.1-1/2" E I 4 IS RK Latch IL1 6 9,828' 8,866' 2.880 Baker Locator 2.88"Drift L 5 7 9,840' 8,876' Baker'FA-1'Packer 8 9 843 8 878 2.990 Baker Seal Assy.2.88"Drift.3 its 3-1/2"Tbg tail pipe 2.99"ID 9 9,914' 8,939' 3.000 Half-cut mule shoe 3.00"ID 1 i` 6 PERFORATION DETAIL 7 Zone Top Btm Top Btm Amt SPF Date Comments 3® mg C (MD) (MD) (TVD) (TVD) I 6-2 10,024' 10,048' 9,033' 9,053' 20' 8 G-4A 10,272' 10,282' 9,242' 9,250' 10' G-4A 10,192' 10,206' 9,175' 9,186' 14' 1111 9 G-4A 10,149' 10,169' 9,138' 9,155' 20' HK-1 10,460' 10,492' 9,400' 9,427' 32' HK-2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open 0-2 HK-3 10,604' 10,696' 9,523' 9,601' 92' G-4A - =G-4 HK-4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open 0-4 HK-1 HK-2 HK-3 HK-4 Notes: 4141 02/16/12 2.70 GR tag at 10,734' TD=11,250" PBTD=11,166" Devi=31°(10,600') Fish: 2 GL Valves Updated: 02/22/16 by JLL • ! Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-43RD Slickline 50-733-20373-01 185-311 2/12/16 2/13/16 Daily Operations: 02/12/2016-Friday Spot equipment. Rig up slickline, PIT lubricator to 1500 psi-Good.Secure well for night. 02/13/2016-Saturday Safety meeting and JSA permit. RIH w/2.75" Gauge Ring to 3,200'-No obstructions. Pooh. RIH w/2-1/2"JDC w/D&D hole finder to 2,142'set down, pin sheared. POOH and re-pin. RIH w/same to 3,100'set.Start testing tubing in 5' increments @ 3,055' holding pressure. RIH w/3-1/2"GS w/AD-2 stop to 3,068'set. POOH. RIH w/3-1/2"GS w/spacer pipe&lower pack-off to 3,054',work tool to set. POOH. RIH w/3-1/2" upper pack-off to 3,051',work tool to set. POOH. RIH w/3-1/2"GS w/A-Stop to 3,050',work tool to set. POOH. Rig down slickline. v. • • k%s. 3,, y®F T� w� \I/// ‘s‘ STATE Alaska Oil and Gas °I\..L17S ti �► i'Jl onserVail®n ®BI1111iSSBon �. _z- 7- �= 333 West Seventh Avenue vig w GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 nt i �. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis ,} r `f , b Operations Manager ' S Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU D-43RD Permit to Drill Number: 185-311 Sundry Number: 316-068 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 3 day of February, 2016. RBDMS LL FEB 0 4 2016 • • • RECEIVE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 1 Z016 APPLICATION FOR SUNDRY APPROVALS 07'S z 3`/- 20 AAC 25.280 - 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install Patch 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska, LLC ' Exploratory ❑ Development 0. 185-311 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20373-01 • 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 i Trading Bay Unit D-43RD 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0017594 • McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools • 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): 11,250 10,083 . 10,734 . 9,634 —1200 psi 11,166 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3,069' 13-3/8" 3,069' 2,907' 3,450 psi 1,950 psi Intermediate 9,839' 9-5/8" 9,839' 8,875' 6,870 psi 4,760 psi Production Liner 1,699' 7" 11,250' 10,083' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,024-10,718 . 9,033-9,620 3-1/2" 9.2#/N-80 9,914 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker FA-1 Packer&TRDP-1A SCSSV • 9,840'(MD)8,876'(TVD)&293'(MD(293'(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program Cl BOP Sketch ❑ Exploratory LI Stratigraphic ❑ Development 0 - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 2/15/2016 Commencing Operations: OIL 0 • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe©hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature ,. t. 1-% Phone (907)777-8356 Date Z I t 1 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: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ( Subsequent Form Required: I C -'I 'I D/D p4. .„4...., APPROVED BY Approved by:Cr COMMISSIONER THE COMMISSION Date: Z. 3 -`c / 1 z-Z-16, PM �I�ig. RBDMS V- FEB 0 4 2016 oR ivGi A Lid SubmiForm ane Form 10-403 Revised /2015 r C 1 for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: D-43rd Hilcorp Alaska,LLC Date: 01/28/16 Well Name: D-43rd API Number: 50-733-20373-01 Current Status: Gas-Lifted producer Leg: Leg#A-1 NE corner Estimated Start Date: February 15, 2016 Rig: N/A (E-Line) Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 185-311 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Current Bottom Hole Pressure: 3,554 psi @ 9,315' TVD 0.437 psi/ft mid pelf 2009 SIBHP Maximum Expected BHP: 3,554 psi @ 9,315' TVD 0.437 psi/ft mid pert 2009 SIBHP Maximum Potential Surface Pressure: -1,200 psi gas-lift pressure Brief Well Summary Well D-43rd is a gas-lifted oil well with a comingled completion in the G and Hemlock zones. During a gas- lift survey on 01/26/16 we located a hole at 3,064'.This project will set a patch to cover the hole(s). • Procedure: 1. MIRU Slick-line, PT lubricator to 1,500 psi. 2. RIH with slick-line and set stops and patch over hole at ±3,064'. 3. RD slick-line Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic rthur River Field, TBU : D-43RD SCHEMATIC Completed: 1986-02-23 API: 50-733-20373-01 Hilcorp Alaska,LLC PTD: 185-311 CASING DETAIL SIZE WT GRADE CONN TOP BTM. i 7 1 13-3/8" 68 K-55 Butt Surf 3069' 9-5/8" 47 N-80 Butt Surf 9839' 2 7" 29 N-80 Butt 9551' 11250' TUBING DETAIL 3-1/2" 9.2 N-80 Butt. Surf. 9914' JEWELRY DETAIL Depth Depth No ID Item (MD) (TVD) 1 1 41' 41' CIW'DCB'Tbg.Hgr. 2 293' 293' 2.812 Camco TRDP-1A SCSSV 2.812"profile flapper type w/CS 3 lock k 2,134' 2,113' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 3)1: a 4,453' 4,101' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 6,074' 5,511' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 3 7,281' 6,571' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,204' 7,395' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,834' 7,976' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 9,310' 8,416' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 4 9,686' 8,745' 2.880 010/2/08 2.88" amco'KBUG CP'Mandrel --1"Nova installed n 5 9,779' 8,824' 2.880 2.88"Drift Camco'KBUG-ELTS'Injection Mandrel.1-1/2" N 4 EE RK Latch 6 9,828' 8,866' 2.880 Baker Locator 2.88"Drift G 5 . . 7 9,840' 8,876' Baker'FA-1'Packer 8 9,843' g g78' 2.990 Baker Seal Assy.2.88"Drift.3 its 3-1/2"Tbg tail pipe 2.99"ID 9 9,914' 8,939' 3.000 Half-cut mule shoe 3.00"ID 1 6 PERFORATION DETAIL 7 Zone Top Btm Top Btm Amt SPF Date Comments ': = C (MD) (MD) (TVD) (TVD) G-2 10,024' 10,048' 9,033' 9,053' 20' 8 G-4A 10,272' 10,282' 9,242' 9,250' 10'1 G-4A 10,192' 10,206' 9,175' 9,186' 14' 9 G-4A 10,149' 10,169' 9,138' 9,155' 20' HK-1 10,460' 10,492' 9,400' 9,427' 32' HK-2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open G-2 HK-3 10,604' 10,696' 9,523' 9,601' 92' =6-4A 6-4 HK-4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open G-4 HK-1 =HK-2 = HK-3 - HK-4 Notes: Atit 02/16/12 2.70 GR tag at 10,734' TD=11,250" PBTD=11,166" Devi=31°(10,600') Fish: 2 GL Valves Updated: 11/10/15 by JLL • rthur River Field, TBU : D-43RD R SCHEMATIC Completed: 1986-02-23 API: 50-733-20373-01 Hilcorp Alaska,LLC PTD: 185-311 CASING DETAIL \ / SIZE WT GRADE CONN TOP BTM. I. 13-3/8" 68 K-55 Butt Surf 3069' 9-5/8" 47 N-80 Butt Surf 9839' 2 / 7" 29 N-80 Butt 9551' 11250' TUBING DETAIL 3-1/2" 9.2 N-80 Butt. Surf. 9914' D I imeo JEWELRY DETAIL "7}11) Depth Depth No (MD) (TVD) ID Item a 1 41' 41' CIW'DCB'Tbg.Hgr. 2 293' 293' 2.812 Camco TRDP-1A SCSSV 2.812"profile flapper type w/CS 3 lock 2,134' 2,113' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 4,453' 4,101' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 6,074' 5,511' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 3 7,281' 6,571' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,204' 7,395' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,834' 7,976' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 9,310' 8,416' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch D l 4 9,686' 8,745' 2.880 2.88"Drift Camco'KBUG-CP'Mandrel --1"Nova installed on 10/2/08 5 9,779' 8,824' 2.880 2.88"Drift Camco'KBUG-ELTS'Injection Mandrel.1-1/2" Z 4 E RK Latch 6 9,828' 8,866' 2.880 Baker Locator 2.88"Drift 5 7 9,840' 8,876' Baker'FA-1'Packer 8 9,843' g 878 2.990 Baker Seal Assy.2.88"Drift.3 its 3-1/2"Tbg tail pipe 2.99"ID 9 9,914' 8,939' 3.000 Half-cut mule shoe 3.00"ID 6 6 PERFORATION DETAIL 7 Zone Top Btm Top Btm Amt SPF Date Comments ut, n/ (MD) (MD) (TVD) (TVD) �f�,�l� ) G-2 10,024' 10,048' 9,033' 9,053' 20' 8 G-4A 10,272' 10,282' 9,242' 9,250' 10' G-4A 10,192' 10,206' 9,175' 9,186' 14' 9 G-4A 10,149' 10,169' 9,138' 9,155' 20' HK-1 10,460' 10,492' 9,400' 9,427' 32' HK-2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open G-2 HK-3 10,604' 10,696' 9,523' 9,601' 92' =G-4A G-4 HK-4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open 0-4 HK-1 HK-2 HK-3 HK-4 *itNotes: L .y, 02/16/12 2.70 GR tag at 10,734' TD=11,250" PBTD=11,166" Devi=31'(10,600') Fish: 2 GL Valves Updated: 01/28/16 by JLL STATE OF ALASKA All OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon El Plug PerforatiorFracture Stimulate El Pull Tubing❑ Operations shutdown El Performed: Suspend El Perforate0 Other Stimulate El Alter Casing El Change Approved Program El Plug for Redrill El Perforate New Poo❑ Repair Well ❑ Re-enter Susp Well El Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 185.311 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service El 6_API Number T ' E Anchorage,AK 99503 50-733-20373-01 7.Property Designation(Lease Number): 8.Well Name and Number: N( `V/ 1 2 21M) ADL0017594 Trading Bay Unit D-43RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): �� N/A McArthur River Field/Hemlock Oil and Middle KenaiOr o s 11.Present Well Condition Summary: Total Depth measured 11,250 feet Plugs measured 11,166 feet true vertical 10,083 feet Junk measured N/A feet Effective Depth measured 10,734 feet Packer measured 9,840 feet true vertical 9,634 feet true vertical 8,876 feet Casing Length Size MD ND Burst Collapse Structural Conductor Surface 3,069' 13-3/8" 3,069' 2,907' 3,450 psi 1,950 psi Intermediate 9,839' 9-5/8" 9,839' 8,875' 6,870 psi 4,760 psi Production Liner 1,699' 7" 11,250' 10,083' 8,160 psi 7,020 psi Perforation depth Measured depth 10,024-10,718 feet True Vertical depth 9,033-9,620 feet N- ``aac➢ , ��k'01i9���^ �'h td; 9..A Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/N-80 9,914(MD) 8,939(ND) Packers and SSSV(type,measured and true vertical depth) Baker FA-1 Packer 9,840'(MD)8,876'(ND)TRDP-1A SCSSV 293'(MD)293'(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: 67 60 232 146 940 Subsequent to operation: 139 50 291 1112 166 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run El 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data El 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: 315-613 Contact Stan Golis Email sgolisAhilcori3.com Printed Name Stan Golis Title Operations Manger Signature `"� I U' I G Phone (907)777-8356 Date i t - t t - 15— Form S-Form 10-404 Revised 5/2015 / /Z-�•/.C—i'v it/fXrRBDMS`\, NOV 16 2015 Submit Original Only iti • rthur River Field, TBU SCHEMATIC l: D-43RD Completed: 2/86 Hilcorp Alaska,LLC CASING DETAIL SIZE WT GRADE CONN TOP BTM. i ° 1 13-3/8" 68 K-55 Butt Surf 3069' 9-5/8" 47 N-80 Butt Surf 9839' 2 ' 7" 29 N-80 Butt 9551' 11250' TUBING DETAIL 3-1/2" 9.2 N-80 Butt. Surf. 9914' JEWELRY DETAIL Depth Depth No (MD) (ND) ID Item ,_ 1 41' 41' CIW'DCB'Tbg.Hgr. 2 293' 293' 2.812 Camco TRDP-1A SCSSV 2.812"profile flapper type w/CS `3 lock y 2,134' 2,113' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch / 4,453' 4,101' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 6,074' 5,511' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 3 7,281' 6,571' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,204' 7,395' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,834' 7,976' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch III 9,310' 8,416' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch II 4 9,686' 8,745' 2,880 2.88"Drift Camco'KBUG-CP'Mandrel --1"Nova installed on 10/2/08 5 9,779' g g2q' 2.880 2.88"Drift Camco'KBUG-ELTS'Injection Mandrel.1-1/2" Z 11 4 E RK Latch 6 9,828' 8,866' 2.880 Baker Locator 2.88"Drift .. al5 7 9,840' 8,876' Baker'FA-1'Packer 8 9,843' 8,878' 2 990 Baker Seal Assy.2.88"Drift.3 its 3-1/2"Tbg tail pipe 2.99"ID 9 9,914' 8,939' 3.000 Half-cut mule shoe 3.00"ID 6 PERFORATION DETAIL 11. 7 Zone Top Btm Top Btm Amt SPF Date Comments ®, LIC (MD) (MD) (ND) (ND) G-2 10,024' 10,048' 9,033' 9,053' 20' 8 G-4A 10,272' 10,282' 9,242' 9,250' 10' G-4A 10,192' 10,206' 9,175' 9,186' 14' all 9 G-4A 10,149' 10,169' 9,138' 9,155' 20' HK-1 10,460' 10,492' 9,400' 9,427' 32' I( HK-2 10,522 10,530 9,453 9,460 8' 6 10/17/15 Open G-2 HK-3 10,604' 10,696' 9,523' 9,601' 92' =G-4A =G-4 ✓ HK-4 10,698 10,718 9,603 9,620 20' 6 10/17/15 Open -G-4 HK-1 HK-2 - HK-3 =HK-4 Notes: Alt d, 02/16/12 2.70 GR tag at 10,734' TD=11,250" PBTD=11,166" Devi=31"(10,600') Fish: 2 GL Valves Updated: 11/10/15 by JLL 411/ • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-43RD 50-733-20373-01 185-311 10/17/15 10/17/15 Daily Operations: 10/17/15-Saturday Fly to Dolly Varden and get checked in. Meet for JSA and filled out work permits. Rigged up unit, lubricator,and guns. Pressure test lubricator to 250 psi low and 1500 psi high. RIH with Gamma Ray and 20' 2-1/2" RTG 6 SPF. Ran correlation pass from 10,720'to 10,390'and send log to town. Perforate Hemlock Bench 4 from 10,698'to 10,718'with 2-1/2" RTG 6 spf. RIH with Gamma Ray and 8' 2-1/2" RTG 6 SPF. Perforate Hemlock Bench 2 from 10,522'to 10,530'with 2-1/2" RTG 6 spf. POOH and rig down for the night. 11111111.1111111111111111111.1111111111.111111111111711111111111111111111111.111111.1.11. ti of 711 • �w\\1//7 sv THE STATE Alaska Oil and Gas A ofAConservation Commission LAsKA ; 333 West Seventh Avenue kierGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O,14.,ALAS Fax: 907.276.7542 ��y� DEC o ZO'�5 www.aogcc.alaska.gov la� Dan Marlowe Operations Engineer ~ 31 1 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 1� Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU D-43RD Sundry Number: 315-613 Dear Mr. Marlowe: 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 DATED this eray of October, 2015 Encl. RBDMSSCT 15 2015 • • • RECEIVED 015 STATE OF ALASKA )ofP3� Is ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request: Abandon a Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown❑ Suspend❑ Perforate 0 i Other Stimulate 0 After Casing ❑ Change Approved Program a Plug for Redd a Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development 0 - 185-311 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic a Service a 6.API Number. Anchorage,AK 99503 50-733-20373-01 . 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? CO 228A Will planned perforations require a spacing exception? Yes 0 No El / Trading Bay Unit D-43RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 o McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools , 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): • 11,250 - 10,083 ' 10,734 . 9,634 11,166 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3,069' 13-3/8" 3,069' 2,907' 3,450 psi 1,950 psi Intermediate 9,839' 9-5/8" 9,839' 8,875' 6,870 psi 4,760 psi Production Liner 1,699' 7" 11,250' 10,083' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,024'-10,696' • 9,033'-9,601' 3-1/2" 9.2#/N-80 9,914 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker"FA-1"Packer&TRDP-1A SCSSV ' 9,840'(MD)8,876'(ND)&293'(MD)293'(ND) • 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development I]- Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/15/2015 OIL 0 , WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name 417rlowe Title Operations Engineer Signature P (907)283-1329 Date 9/29/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 13 Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: ,�;! O0 A$ 1015 Spacing Exception Required? Yes El No i Subsequent Form Required: Li(7 RBOW'9 APPROVED BY Approved by:lyp4,......,4,_, , COMMISSIONERTHE COMMISSION Date: /0 —/1-7S !� �y ?" ` 2_ji5- RI G I N A L „ / ' SubmitForm and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate •14 • Well Prognosis Well: D-43rd Hilcorp Alaska,LLC Date: 09/28/15 Well Name: D-43rd API Number: 50-733-20373-01 Current Status: Gas-Lifted producer Leg: Leg#A-1 NE corner Estimated Start Date: October 15, 2015 Rig: N/A(E-Line) Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 185-311 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Current Bottom Hole Pressure: 3,554 psi @ 9,315'TVD 0.437 psi/ft mid pert 2009 SIBHP Maximum Expected BHP: 3,554 psi @ 9,315'TVD 0.437 psi/ft mid pert 2009 SIBHP Max.Allowable Surface Pressure(Pert Job):-1,200 psi gas-lift pressure Brief Well Summary Well D-43rd is a gas-lifted oil well with a comingled completion in the G and Hemlock zones.This project will add the Hemlock bench 2 &4 sands not currently perforated. / E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate Hemlock HK-2 & HK-4 sands per program. Record tubing pressures before and after perforating run. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic • •4rthur River Field, TBU • SCHEMATIC Well: D-43RD Completed: 2/86 Ilileorp Alaska,LLC CASING DETAIL \ / SIZE WT GRADE CONN TOP BTM. • 1 13-3/8" 68 K-55 Butt Surf 3069' 9-5/8" 47 N-80 Butt Surf 9839' 2 / 7" 29 N-80 Butt 9551' 11250' TUBING DETAIL 3-1/2" 9.2 N-80 Butt. Surf. 9914' D JEWELRY DETAIL _ Depth Depth No ID Item (MD) (TVD) D ,� --- 1 41' 41' CIW'DCB'Tbg.Hgr. 2 293' 293' 2.812 Camco TRDP-1A SCSSV 2.812"profile flapper type w/CS lock D 3 2,134' 2,113' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 4,453' 4,101' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 6,074' 5,511' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 3 7,281' 6,571' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,204' 7,395' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch D 8,834' 7,976' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 9,310' 8,416' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 4 9,686' 8,745' 2.880 2.88"Drift Camco'KBUG-CP'Mandrel --1"Nova installed on 10/2/08 D 2.88"Drift Camco'KBUG-ELTS'Injection Mandrel.1-1/2" 5 9,779' 8,824' 2.880 kl RK Latch 4 6 9,828' 8,866' 2.880 Baker Locator 2.88"Drift D 7 9,840' 8,876' Baker'FA-1'Packer D58 9,843' 8,878' 2.990 Baker Seal Assy.2.88"Drift.3 its 3-1/2"Tbg tail pipe 2.99"ID 9 9,914' 8,939' 3.000 Half-cut mule shoe 3.00"ID Li6 7 PERFORATION DETAIL )01= Top Btm Top Btm Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments 8 G-2 10,024' 10,048' 9,033' 9,053' 20' • G-4A 10,272' 10,282' 9,242' 9,250' 10' -. G-4A G-4A 10,192' 10,206' 9,175' 9,186' 14' G-4A 10,149' 10,169' 9,138' 9,155' 20' G-2 HK-1 10,460' 10,492' 9,400' 9,427' 32' • G-4A HK-3 10,604' 10,696' 9,523' 9,601' 92' G-4 G-4 Notes: 02/16/12 2.70 GR tag at 10,734' 8-1 B-3 Fish: -- 2GLValves A . • TD=11,250" PBTD=11,166" Devi=31'(10,600') Updated: 9/28/15 by ALL Irthur River Field, TBU r11 Proposed Well: D-43RD Completed: 2/86 Hileorp Alaska,1.I.0 CASING DETAIL SIZE WT GRADE CONN TOP BTM. i I \ / 1L. 13-3/8" 68 K-55 Butt Surf 3069' 9-5/8" 47 N-80 Butt Surf 9839' 2 / 7" 29 N-80 Butt 9551' 11250' TUBING DETAIL 3-1/2" 9.2 N-80 Butt. Surf. 9914' --77/1150 JEWELRY DETAIL Depth Depth No (MD) (ND) ID Item a 1 41' 41' CIW'DCB'Tbg.Hgr. moil2 293' 293' 2.812 Camco TRDP-1A SCSSV 2.812"profile flapper type w/CS 3 lock 2,134' 2,113' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 4,453' 4,101' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 6,074' 5,511' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 3 7,281' 6,571' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 8,204' 7,395' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch MEM 8,834' 7,976' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch 9,310' 8,416' 2.880 2.88"Drift Camco MMG-CP Mandrel.1-1/2"RK Latch =MP 4 9,686' 8,745' 2,880 2.88"Drift Camco'KBUG-CP'Mandrel --1"Nova installed on 10/2/08 2.88"Drift Camco'KBUG-ELTS'Injection Mandrel.1-1/2" 5 9,779' 8,824' 2.880 RK Latch 4 6 9,828' 8,866' 2.880 Baker Locator 2.88"Drift 5 7 9,840' 8,876' Baker'FA-1'Packer 7-'7" 8 9,843' 8,878' 2.990 Baker Seal Assy.2.88"Drift.3 Jts 3-1/2"Tbg tail pipe 2.99"ID 9 9,914' 8,939' 3.000 Half-cut mule shoe 3.00"ID j 6 PERFORATION DETAIL 7 Zone Top Btm Top Btm Amt SPF Date Comments (MD) (MD) (ND) (TVD) G-2 10,024' 10,048' 9,033' 9,053' 20' 8 G-4A 10,272' 10,282' 9,242' 9,250' 10' G-4A 10,192' 10,206' 9,175' 9,186' 14' ---- 9 G-4A 10,149' 10,169' 9,138' 9,155' 20' HK-1 10,460' 10,492' 9,400' 9,427' 32' HK-2 ±10,522 ±10,530 ±9,453 ±9,460 Future 9-2 HK-3 10,604' 10,696' 9,523' 9,601' 92' -0-4A =G-4 HK-4 ±10,698 ±10,718 ±9,603 ±9,620 20' Future io G-4 HK-1 HK-2 HK-3 HK-4 • Notes: L • 02/16/12 2.70 GR tag at 10,734' TD=11,250" PBTD=11,166" Devi=31°(10,600'1 Fish: 2 GL Valves Updated: 9/28/15 byJJLL Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) /Two-Sided DIGITAL DATA [] Diskettes, No, Other, No/Type RESCAN [] Color items: [] Grayscale items: [] [] Poor Quality Originals: ~3//' Other: ~ TOTAL PAGES!~~ i NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERY~ARI~'~LOWELL Project Proofing OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /s/ PAGES: I ~..~ 7 (at the time of scanning) ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: / ~/~7"' "~/0 ~' "'~"~'--* Quality Checked (done) RevlNOTScanned.wpd ALASKA OIL AND GAS / CONSERVATION COMMISSION / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 19,2003 Dwight Johnson UNOCAL Field Superintendent PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification TBU Well D-43RD PTD 185-311 Dear Mr. Johnson: On May 15, 2003 AOGCC Petroleum Inspector Lou Grimaldi witnessed a "no,flow" test on Well D-43RD at UNOCAL's Dolly Varden Platform, Trading Bay Unit, McArthur River Field. Mr. Grimaldi arrived on Dolly Varden Platform and observed the well flowing to the clean-up tank at 10 psi. The well was shut in, allowed to build pressure and opened to the clean-up tank through 4 cycles over a total observation period of 4 hours. A maximum build up of 2 psi was noted. When the well was opened to flow, a maximum gas rate of 600 scf/hr was recorded which quickly decreased to below the meter threshold of 180 scf/hr if 4 minutes or less. At the end of the observation periods, there was 0 pressure and the gas rate was below the meter threshold of 180 scf/hr. No flow was confirmed using a "bubble bucket". Throughout the observation periods, no liquid flow was observed and only a slight gas flow was noted. The observed performance of TBU well D-43RD (185-311) demonstrated that the well is incapable of unassisted flow of hydrocarbons to the surface. It has been concluded that TBU well D-43RD (185-311) meets the criteria of a "no-flow" performance test and as such, is considered incapable of unassisted flow to the surface. The well's performance meets the criteria at 20 AAC 25.265 (b). Therefore, the well is not required to have a fail-safe automatic SSSV, however, the pilot and SSV must be maintained in satisfactory operating condition. If for any reason the well again becomes capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well file on board Dolly Varden. Sincerely, Thomas E. Maunder, PE , Sr. Petroleum Engineer MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner ~7//?---;/cz:;/ Blair Wondzell, P. I. Supervisor FROM: John Crisp? ,~~ O. SUBJECT: Petroleum In~l~ector DATE: June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be changed out during next Platform shut down due to header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthur River Field. ' -24 wells,-57 COmponents tested, 3 failures witnessed. 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc cc; 'NON-CONFIDENTIAL SVS Dolly Plt. 6-22-00jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: McArthur Rv. / Dolly Var& Separator psi: LPS 110 HPS 6/22/00 WeH Data Pt'lots SV SSV Well Type Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GASorC¥CLE D-01 1670800 110 80 85 P 4 OIL D-02ARD 1750380 110 80 65 P 5 OIL D-03RD2 1830810 110 80 80 ? P OIL iD-04RD 1820410 110 80 80 P P OIL ~D-05RD 1800650 110 80 100 P P 43 OIL D-07RD2 1921550 110 80 80 P P P OIL D-08RD 1740030 110 80 75 P P P OIL D-11 1680730 110 80 80 P P P OIL D-12RD 1800820 110 80 75 P P 43 OIL D-17RD 1810230 110 80 80 P P 43 OIL D-18 1690040 800 700 700 P P P GAS D-20 1690950 110 80 90 P P OIL D-25RD 1780870 110 80 100 P P OIL D-26RD 1981290 110 80 75 P P OIL D-27 1750240 110 80 60 P P OIL D-28 1760360 110 801 100 P P OIL D-30RD2 1880980 D-31RD 1760740 110 80 70 P P 43 OIL D-32 1700370 110 80 75 P P P OIL D-40RD 1820830 110 80 80 P P OIL D-42 1830530 110 80 70 P P OIL D-43RD 1853110 1101 80 70 P P P OIL D-46 1890610 110~ 80 60 P P P OIL D-47 1910110 110 80 70 P P 9 OIL !D-48 1921540 110 80 80 P P P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% [-] 9o oar Remarks: Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. 6/27/00 Page 1 of 1 SVS Dolly Plt. 6-22-00jcl ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June15,1994 Russell Schmidt Union Oil Company of California P O Box 190247 Anchorage, Alaska 99519 RE: 81-0099 83-0053 85-0311 SOLDOTNA CREEK UNIT 31-08 TRADING BAY UNIT D-42 TRADING BAY UNIT D-43RD Dear Mr. Schmidt, A review of our well records and correspondence indicates the referenced wells are missing directional surveys. This requirement was indicated on the permit to drill. The survey should be submitted with the form 10-407 Well Completion Report. This is a compliance check I conducted for missing required data as stated in 20 AAC 25.050 (f). This data has not previously been requested. If you have the surveys, please make a copy and mail to me to correct this problem and update our well files. Sincerely, Steve McMains Statistical Technician STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~o31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operations Shutdownm Stimulate m Plugging__ Perforate X.~ Pull Tubing __ Alter Casing __ Repair Well__ Other 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Achorage, AK 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface Leg A-l, Cond. #9 Dolly Varden Platform 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive interval 443' FNL, 1,202' FWL, Sec. 6-8N-13W-SM At effective depth 121' FNL, 1,150' FWL, Sec. 6-SN-13W-SM At total depth 86' FNL, 1,170' FWL, Sec. 6-8N-13W-SM 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-43RD 9. Permit number/approval number 85-311 / 94-037 0. APl number 50- 733-20373-01 1. Field/Pool Hemlock 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 11,250' feet Plugs (measured) 10,083' feet 11,1 66' feet Junk (measured) 10,009' feet Length Size Cemented 3,069' 13-3/8" 2,945 sx 9,839' 9-5/8" 3,990 sx 1,699' 7" 700 sx See Attachment #1 11,166' - 11,250' CMT None Measured depth True vertical depth 3,069' 2,907' 9,839' 8,875' ,250' 10,083' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 @ 9,914' Packers and SSSV (type and measured depth) Baker "FA-I" Packer @ 9,840' DIL, Camco TRDP-1A SCSSV @ 293' 3 Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcr Water-Bbl. Casing Pressure Tubing Pressure Prior to well operation 278 278 306 940 Subsequent to operation 261lj~-- 127 405 1,000 140 140 ! 15. Attachments 116. Status of well classification as: I Copies of Log and Surveys run __ Daily Report of Well Operations X Oil X Gas Suspended__ -- 117. I hereb~.~rtify t~h% ,ir~~~/~is tr~..~best of my knowledg,~[ Signed ? ~,., [(,.4~JV~P~-~_ ,,~~TM Title Form 10-404 Rev 06/15/88 Service Date SUBMIT IN DUPLICATE~ Bench G-2 G-4 G-4 G-4A Attachment #1 Well D-43RD Perforations MD 10,024' - 10,048' 10,149' - 10,169' 10,192' - 10,206' 10,272' - 10,282' TVD 9,032' - 9,052' 9,138' - 9,155' 9,174' - 9,186' 9,241' - 9,250' B-1 B-3 10,454' - 10,492' 10,604' - 10,696' 9,394' - 9,427' 9,522' - 9,596' [SUNDRYE.XLW]Perf Database Daily Well Operation Well D-43RD 2/12-13/94 RU E-Line. Held safety meeting. PT Lub to 1,000 psi- GOOD. RIH w/2 1/8" Enerjets, 4 SPF, 0° Phased, 0° Offset. Flowed well to obtain underbalance and perforated the following intervals: Zone Interval (DIL) Footage Results G-4A 10,272' - 10,282' 10' G-4 10,192' - 10,206' 14' G-4 10,149'-10,169' 20' All shots fired One shot misfired Two shots misfired 2/14/94 G-2 RD, E-Line. 10,024' - 10,048' Returned well to production. 24' All shots fired EVO/cah/H:\WP\Sundry\D43RD RECE[VEC:' 1994. A~chorage ' ALASKA OIL AND GAS CONSERVATION ^...ov^,s 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__ P'"'~rforate X Othe~ 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive interval 443' FNL, 1,202' FWL, Sec. 6-8N-13W-SM At effective depth 121' FNL, 1,150' FWL, Sec. 6-SN-13W-SM At total depth 86' FNL, 1,170' FWL, Sec. 6-8N-13W-SM Leg A-l, Cond. #9 Dolly Varden Platform 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-43RD 9. Permit number/approval number 85-311 10. APl number 50- 733-20373-01 11. Field/Pool Hemlock 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 1 1,250' feet 10,083' feet 1 1,166' feet 10,009' feet Length Size A~~I~ Ntf, tto[ao~e 11,166'- 11,250' CMT Junk (measured) None feet Cemented Measured depth True vertical depth 3,069' 13-3/8" 2,945 sx 3,069' 9,839' 9-5/8" 3,990 sx 9,839' 2,907' 8,875' 1,699' 7" 700 sx 11,250' 10,083' B-1 10,454' - 10,492' MD B-3 10,604' - 10,696' MD 9,394'- 9,427' TVD 9,522' - 9,596' TVD Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 @ 9,914' Packers and SSSV (type and measured depth) Baker "FA-1" Packer @ 9,840' DIL, Camco TRDP-1A SCSSV @ 293' 13. Attachments Description summary of proposal Detailed operations program__ BOP sketch X Estimated date of commencing operation February 9, 1994 If proposal was verbally approved Name of approver Date approved 15. Staffs of well classification as: Oil X Gas Service Suspended__ 17. I hereby/~e.rtify~goin, g is t_rue and_~0~ct to the best of my knowledge. Signed Title '~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance__ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commision Original Signed By 0avid W. Johnston Approved Copy Returned z. Commissioner SUBMIT IN TRiPLI(~ATE~ Form 10-403 Rev 06/15/88 PROCEDURE DOLLY VARDEN PLATFORM WELL D-43 PERFORATE G-ZONE 1/20/94 OBJECTIVE: Complete G-zone and commingle with Hemlock production 1) 2) 3) 4) 5) 6) Hold operational and safety meeting with platform personnel and service company prior to RU. Identify and minimize any spill potential. Lock open TR SCSSV with auxiliary pump on platform and regulate pressure at 4000 psi. Monitor for any leak off. RU E-Line unit. Ensure adequate lighting for night operations. Hook up communication system in unit. Pressure test BOP's lubricator with water and methanol mixture. Function test BOP's with pressure to verify operation and integrity. PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN HOLE, COMPLETE PERFORATING SAFETY MEASURES. RE-ESTABLISH PERFORATING SAFETY MEASURES WHILE POOH ABOVE 1000'. RIH and perforate the following intervals underbalanced: ** Guns to be selected at later time. G-2 10,024' - 10,048' DIL 24' G-4 10,149' - 10,169' DIL 20' 10,192' - 10,206' DIL 14' G-4a 10,272' - 10,282' DIL 10' RD E-Line. MARATHF1N FIIL COMPANY TRADING BAY UNIT D-43RD COMPLETED 2/86 41' 293' CIW 'DCB' Tbg. Hgr. 4-1/2" EUE Top X 4-1/2" Butt Btm. w/ X-over below, 4-1/2" Butt X 5-1/2" Butt Camco TRDP-1A SCSSV 2 812" profile Flapper type w/ CS lock Encapsulated 3/8" Chem. Inj. Line Casing & Tubing Top Bottom Size O' 5,069' 15-5/8" O' 9,839' 9-5/8" 9,551' 11,250' 7" O' 9,914' 3-1/2" We,ght 68// 47// 29# 9.2// All Mandrel are 2.88" Drift Depth 2,314' 4,453' 6,074' 7,281' 8,204' 8,834' 9,51 O' 9,686' 9,779' Valve 1 2 3 4 5 6 7 8 9 Grade K-55 N-80 N-80 N-80 Descrip Butt Csg Butt. Csg Butt L~ner Butt Tbg. w/ AB Mod Cplgs Mandrel Type Latch Camco MMG-CP 1-1/2" RK Camco 'KBUG-CP' 1" GLV 5/16" Orifice Camco 'KBUG-ELTS' InJection Mandrel BK-2 B-1 B-3 9,828' 9,840' 9,845' 9,914' Baker Locator 2.88" Dr~ft Baker 'FA-I' Packer Baker Seal Assy. 2.88" Drdt 5 Jts 3-1/2" Tbg tad pipe 2 99" ID Half-cut Mule Shoe 3 00" ID Devi = 51°(10,600') PerColations (DIL) ]3-1 10,460' - 10,492' 32' ]3-3 10,604' - 10,696' 92' 10,723' Fill Tagged 9/3/93 WLM 10,678' Bridge Tagged 11-29-92 CTM Fish - 2 OL Valves 11,106' Fill Tagged 5/92 11,166' PBTD 11,250' TD Revision Dote: 10/5/93 Revised By, JDM/evo Reason: Update Pr-ev,ous Revision: t/22/9.3 · DOLLY VARDEN P,,...~TFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) LUBRICATOR 3 1/8' 5000 pal CHISTMAS TREE ~~~_ Pos,m,v,= C.OK'= loo ol, .~---- 2' 5000 psi ~._-- 2' 3000 psi 1. Operations Performed: STATE OF ALASKA ALAo,., OIL AND GAS CONSERVATION COMk .... SION REPORT OF SUNDRY WELL OPERATIONS Operations Shutdown Stimulate Plugging__ Perforate X Pull Tubing Alter Casing __ Repair Well__ 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: Development X Exploratory -- Stratigraphic m Service -- 4. Location of well at surface Leg A-l, Cond. #9 Dolly Varden Platform 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive interval 443' FNL, 1,202' FWL, Sec. 6-8N-13W-SM At effective depth 121' FNL, 1,150' FWL, Sec. 6-SN-13W-SM At total depth 86' FNL, 1,170' FWL, Sec. 6-8N-13W-SM 2. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 11,250' feet 10,083' feet 11,166' feet 10,009' feet Length Plugs (measured) Junk (measured) Size Cemented 3,069' 13-3/8" 2,945 sx 9,839' 9-5/8" 3,990 sx 1,699' 7" 700 sx B-1 10,454' - 10,492' b-3 10,604' - 10,696' MD MD Other 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-43RD 9. Permit number/approval number 85-311 / 93-237 0. APl number 50- 733-20373-01 11. Field/Pool Hemlock 11,166' - 11,250' CMT None Measured depth True vertical depth 3,069' 2,907' 9,839' 8,875' 11,250' 10,083' 9,394'- 9,427' TVD 9,522'- 9,596' TVD Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 @ 9,914' Packers and SSSV (type and measured depth) Baker "FA-I" Packer @ 9,840' DIL, Camco TRDP-1A SCSSV @ 293' RECEIVFr 13, Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure DEC 17',- ', u~ & Gas Con~ ..... ~,, ,,o Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Avera.qe Production or Iniection Data Oil-Bbl. Gas-Mcf Water-Bbl. Casing Pressure 190 ~"~0 253 955 251 4'131 299 1,160 Tubing Pressure 150 150 5 Attachments Copies of Log and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 7. I hereby certify that the foregoing is true and correct to the best of my knowledg.,~. Signed {~. ~.~~.~ ,~'l~ Title Form 10-404 Rev 06/15/88 Date i~. SUBMIT IN DUPLICATE DAILY ~ELL OPERATIONS D-43RD 9/17-19/93 RU E-line. PT lub to 2500 psi. Good. RIH w/ 2-1/8", 6 SPF, 45° phase expendable guns. Flowed well to obtain underbalance and perforated the fol lowing: RUN BENCH DEPTH (DIL) RESULT i HB-3 10,635' - 10,655' Fired 2 HB-3 10,615' - 10,635' Fired RIH w/ 1-11/16" pivot gun, 4 SPF, 180° phase. Flowed well for underbalance and perforated the following: RUN BENCH DEPTH (DIL) RESULT 3 HB-1 10,475' - 10,490' Fired 4 HB-1 10,460' - 10,475' Fired R.D. Returned well to production. H: \wp\WE L LOPS\D43RD RECEIVED DEC 1 7 199~ AI~Sk~ Oil & Gas Cons. Commisstor~ Anchorage ALA,~, ~ OIL AND GAS CONSERVATION COMM,~SION APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation shutdown Re-enter suspended well Alter casin'~ Repair w'~' Plugging -- Time extension Stimula-'~' Change appr~'~d program m Pull Tubing -- Variance__ "~rforate X.~ 1. Type of Request: 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: Development Exploratory Stratig raphic Service 4. Location of well at surface 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive interval 443' FNL, 1,202' FWL, Sec. 6-8N-13W-SM At effective depth 121' FNL, 1,150' FWL, Sec. 6-8N-13W-SM At total depth 86' FNL, 1,170' FWL, Sec. 6-8N-13W-SM Leg A-l, Cond. #9 Dolly Varden Platform RE( EIVED s E P - 3 199 Alaska Oil & Gas Cons. 60mmi; Anchorage 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 11,250' feet Plugs (measured) 10,083' feet 1 1,1 66' feet Junk (measured) 1 0,009' feet Length Size Cemented 3,069' 13-3/8" 2,945 sx 9,839' 9-5/8" 3,990 sx 1,699' 7" 700 sx B-1 10,454' - 10,492' MD B-3 10,604' - 10,696' MD 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. unit or Property name Trading Bay Unit 8. Well number D-43RD 9. Permit number/approval number 85-311 10. APl number rich50- 733-20373-01 11. Field/Pool Hemlock 11,166' - 11,250' CMT None Measured depth True vertical depth 3,069' 2,907' 9,839' 8,875' 11,250' 10,083' 9,394'- 9,427' TVD 9,522'- 9,596' TVD Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 @ 9,914' Packers and SSSV (type and measured depth) Baker "FA-I" Packer @ 9,840' DIL, Camco TRDP-1A SCSSV @ 293' 13. Attachments Description summary of proposal Detailed operations program BOP sketch X Estimated date of commencing operation Sept. 11, 1993 If proposal was verbally approved Name of approver Date approved 15. Statis of well classification as: Oil X Gas Service Suspended__ 17. I hereby ~e)t/Y th/a~the f°r~go~g is llue~n.~c °.rr~,the best °f my kn°wledge' Signed //~ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance__ Mechanical Integrity Test __ Subsequent form required 10- ~r..{ Approved by order of the Commision Returned Commissioner Date JApproval No. Date ~/?y¢~ I ¢ SUBMIT I1~ TI~IPLICATE ,~ Form 10-403 Rev 06/15/88 NELL D-43RD Gauge Ring, Tag and Reperforating Procedure 1. Obtain a well test. 2. RU wireline unit on Well D-43RD (Leg A-l). · Hook up platform PA system in unit. Pressure test lubricator and BOPE to 2500 psi. · Apply 4000 psi control line pressure to the SCSSV with the auxiliary pump and monitor for any leak off prior to RIH. Auxiliary pump to be located near lower wellroom entry door. · RIH w/ 2.70" GR and tag fill. If fill is above 10,655' in HB-3, evaluate bailing to obtain desired depth. 6. RD wireline. 7. RU E-line. HU platform PA, pressure test lubricator and BOPE to 2500 psi. 8. Apply 4000 psi to control line with the auxiliary pump. NOTE: Prior to arming guns, and until guns are 1,OOO' in the hole, complete the perforating safety checklist. Recomplete the perforating safety checklist when guns are at 1,0OO' when POOH. e SI well. RIH w/ 2-1/8" phased retrievable strip guns, 4 SPF and perforate the following intervals underbalanced: RUN BENCH INTERVAL FOOTAGE i 3 10,635' - 10,655' 20 2 3 10,615' - 10,635' 20 10. SI well. RIH w/ 1-11/16" pivot guns, 4 SPF, 90° phase and perforate the following intervals underbalanced: RUN BENCH INTERVAL FOOTAGE 3 I 10,475' - 10,490' 15 4 I 10,460' - 10,475' 15 11. POOH. RD E-line. Return well to production. RECEIVED H: \wp\WL PRO\D43RD P - ,! 199J Gas Oons. Commissio~ )knchorage MARATHON FIlL CF1MPANY TRaDiNG BAY UNiT D-43RD COMPLETED 2/86 41' 293' CIW 'DCB' Tbg. Hgr. 4-1,/2" EUE Top X 4-1/2" Butt Btm. w/ X-over below, 4-1/2" But[ X 3-1/2" Butt Camco TRDP-1A SCSSV 2 812" ID Flapper type Encapsulated 3/8" Chem. Inj. Line Casing & Tubinq Top. Bottom Size O' 3,069' 13-5/8" O' 9,839' 9-5/8" 9,551' 11,250' 7" O' 9,914' 5-1/2" Weight 68// 47// 29// 9.2# All Mandrel are 2.88" Drift Depth 2,314' 4,453' 6,074' 7,281' 8,204' 8,834' 9,310' 9,686' 9,779' Valve 1 2 3 4 5 6 7 8 9 Grade K-55 N-80 N-80 N-80 Descrip Butt. Csg Butt. Csg. Butt. L~ner Butt Tbg w/ AB Mod Cplgs Mandr el Type Latch Camco MMG-CP 1-1/2" RK Camco 'KBUG-CP' 1" GLV 5/16" Ordlce Camco 'KBUG- ELT'S' InJection Mandrel BK-2 B-3 9,828' 9,840' 9,845' 9,914' Baker Locator 2.88" Drift Baker 'FA-t' Packer- Baker Seal Assy. 2.88" Drift 3 dts 3-1/2" Tbg ta~l l)~pe 2 99" ID Half-cut Mule %hoe 3 00" I E) Dev, = 51':'(10,6C)0') Pep£opations (DIL) B-1 10,460' - 10,492' 32' RE 'EIVED E P - 5 t995 qiaska Oil & Gas Cons. Commission Anchorage B-3 10,604' - 10,696' 92' 10,678' Bridge Tagged 11-29-92 CTM Fish - 2 GL Valves 11,106' F,It Tagged 5/92 11,166' PBTD 11,250' TD Revision DaCe, 1/22/93 Rev,seal By~ JDM/evo Reason: Update PF evious Revision: ~-DOLLY VARDEN F-ATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) LUBRICATOR · 4-1~'ff.6~. 5000 psi CHISTMAS TREE POSITIVE CHOKE Anchora,Q~ --.-- 2' 5000 psi ]__ 2' 3000 psi 13 3/8' CASING Unocal North Arum Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 (5 Alaska Region UNOCAL RECEIVED APR 2. O ~993 Alaska Oil & Gas Cons. Commission Anchorage DOCUMENT TRANSMITTAL April 16, 1993 TO: LarryGrant FROM' KirkKiloh LOCATION: 30Ol PORCUPINE DRIVE LOCATION: P.O.BOX 196247 ANCHORAGE, AK 99501 ANCHORAGE AK 99519 ALASKA OIL & GAS CONSERVATION COMM. UNOCAL ........ ;._.__:_:; ............. _ _ __ TRANSMI2~ING AS FOLLOWS TRADING BAY UNIT 1 blueline and 1 sepia Logs from specified wells listed below 5g0--ia~ ..-. D-5RD 7 7--~Z- -- D-7RD ~8.?~ --D-il. gl-&'~ -D-17RD Perforating Record Perforating Record Perforating Record 'Perforating Record · Perforating Record .Perforating Record Completion Record 10-18-92 10-19-92 11-30-92 11-22-92 11-29-92 12-04-92 6-29-92 6,~--q5' -- D-20 Completion Record 6-16-92 D-25 D-43RD D -47 G-1RD M-3 M-7 Completion Re~ord Perforating Record Perforating Record Perforating Record Perforating Record Perforating Record Continuous Gyro Tool Cement Bond Tool '6-20-92 11-21-92 11-25-92 10-17-92 12-03-92 12-18-92 7-24-92 7-24-92 M-28 Perforating Depth Control 8-12-92 M-29 Tubing Patch Record 11-13-92 PLEASE ACI~gOWLEI)GE RECEIFT BY SIGNING AND RETUlhN-ING ONE COPY OF THIS DOCUMENT TRA~SM1TT~. ~ YOU DATED: STATE OF ALASKA ALA~r,J-\ OIL AND GAS CONSERVATION COMN,,~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operations Shutdown m Stimulate m Plugging __ Perforate Pull Tubing Alter Casing Repair Well __ Other 2. Name of Operator UNOCAL (Marathon Oil Company-Sub-Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface Leg A-l, Cond. #9 Dolly Varden Platform 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive interval 443' FNL, 1,202' FWL, Sec. 6-8N-13W-SM At effective depth 121' FNL, 1,150' FWL, Sec. 6-8N-13W-SM At total depth 86' FNL, 1,170' FWL, Sec. 6-8N-13W-SM 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-43RD 9. Permit number/approval number 85-311 / 93-029 10. APl number 50- 733-20373-01 11. Field/Pool Hemlock 2. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 11,250' feet Plugs (measured) 10,083' feet 11,166' feet Junk (measured) 10,009' feet Length Size Cemented 3,069' 13-3/8" 2,945 sx 9,839' 9-5/8" 3,990 sx 1,699' 7" 700 sx Bench 1 Bench 3 10,454' 10,492' MD 10,604' - 10,696' MD Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 @ 9,914' Packers and SSSV (type and measured depth) Baker "FA-l" Packer @ 9,840' DIL, Camco TRDP-1A SCSSV @ 293' 11,166'-11,250' CMT None Measured depth True vertical depth 3,069' 2,907' 9,839' 8,875' 11,250' 10,083' 9,394' - 9,427' TVD 9,522' 9,596' TVD RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Alaska Oil & Gas Co;is. Cornrnissio~ Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcr Water-Bbl. Casing Pressure Tubing Pressure Prior to well operation 1/10/93 327 218 235 1,040 Subsequent to operation 2/14/93 369 175 253 980 160 140 15. Attachments 116. Status of well classification as: I Copies of Log and Surveys run __ Daily Report of Well Operations X Oil X Gas__ -- 17' I hereby ~,.~f~at tc~_fie~and c°rrect t° the best of mY knowledg.~~ Signed ,/(~k~,'"'~ ~ ~..,,~,~*,~,,~ Title (~.~LL ~ ~.~C~ Suspended Service Form 10-404 Rev 06/15/88 SUBMITIN DUPLICAT'E~. DAILY ~ELL OPERATIONS D-43RD 1/17/93 Hold safety meeting. RU lubricator & equipment. Lock open SCSSV w/ auxiliary pump at 4,000 psi. Monitor. Psi test lubricator to 2500 psi. O.K. Establish CBO. Arm 1-11/16" pivot gun, 4SPF, 180 degree phasing. RIH w/ pivot gun. Flowed well to obtain underbalance and performed the following intervals: #1 HB-1 10,470' - 10,480' 10' Fired 2 HB-1 10,460' - 10,470' 10' Misfired RD. Return well to production. 1/25/93 MU lubricator. Pressure test to 2500 psi. Good test. Lock open SCSSV w/ auxiliary pump at 4000 psi. Establish CBO. Arm 30' 2-1/8" enerjets, 4 SPF 0 degree phasing. RIH w/ perf gun. Flow well for underbalance and perforated the following interval: RUN #1 HB-1 10,460' - 10,490' 30' Fired RD. Returned well to production. NOTE: BlairWondzell, AOGCC, approved the added perforation interval on 1/20/93. H: \wp\WEL LOPS\D43RD RECEIVED MAR 1! t99;' Alaska Oil & Gas Ceils. gachorag~ STATE OF ALASKA '~' ~f ~ ~ 6 ~ ~"' .¢~ ~ ALASKA OIL AND GAS CONSERVATION COMMISo,ON APPLICATION FOR SUNDRY APPROVALS I Type of Request Abandon __ Suspend __ Alter casing __ Repair welt __ Change approved program __ 2 Name of Operator UNOCAL(Marathon 0il Co. - Sub Operator) 3 Address P.O. Box 190247 Anchorage, AK 99519 5. Type of Well. Development XX Exploratory __ Strat,grapmc __ Serwoe __ 4 Locahon of well at surface Leg A-l, Cond. //9 Dolly Varden Platform 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive mtervat 44 ' FNL, ~t effective delpth002' 121' FNL, 1,150' At total depth 86' FNL, 1,170' 12 Present well condition summary Total depth: measured 11,250 ' truevertlcal 10,083' Operation s~utdown __ Re-enter suspended well __ Plugging __ T~me extension __ ,~tcmutate __ Pull tubing ~ Vanance__ Perforate AA Other i 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-43RD 9. Permit number Plugs (measured) FWL, Sec. 6-8N-13W-SM FWL, Sec. 6-8N-13W-SM FWL, Sec. 6-8N-13W-SM feet feet feet 10. APl number 50-- 11. F~etd/Pool Heml oc k 11,166' - 11,250' CMT Effective depth measured 11,166' feet true vertical 10,009' feet Casing Length Structural Conductor Sudace 3,069' Intermediate 9,839 ' Produchon Liner 1,699' Perforation depth: measured true vertical Junk (measured) None S~ze Cemented Measured depth 13 3/8" 2,945 sx 3,069' 9 5/8" 3,990 sx 9,839' 7" 700 sx 11,250' Bench I 10,454' - 10,492' MD 9,394' Bench 3 10,604' - 10,696' MD 9,522' Tubing (s~ze, Qrade. aha measured depth) 3 1/2", 9.2//, N-80 e 9,914' el~ d .SS d s Ce , , Ba~8~ r1¢/~-c~ ~)~eea¢ Cq~,~ ~)L Camco TRDP-1A SCSSV 0 293 True vertical depth 2,907' 8,875' 10,083' - 9,427' TVD - 9,596' TVD RECEtVE & G~s Oo~s. 13. Attachments Description summary of proposal ×)_..~ Detaded operations program BOP sketch 14. Estimated date for commencing operation 1/17/93 '16. If proposal was verbally approved MiKe Minder 1/15/93 Name of approver Date approved Service 17 I herel(~)..lertlfl't/~at the f~,~°lTs~rue, c~.~ct t° the bes-t °f mY kn°wledge. S,gned //~.[~/~ Fo~itle ~LL,(..,kt,~C,._.x ~~~~ COMMISSION USE ONLY 15. Status of well classification as: Oil XX Gas Suspended Date Conditions of approval: Notify Commission so representative may witness Plug integrity i BOP Test __ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- ¢~.'~ Approved by order of the Commission David \,.~. Johnston ] Approval No.~,._~ .. t~,¢~ ¢ Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ~. PROCEDURE WELL D-43RD · 3, 1 · Skid rig over Well D-43RD. RU E-line unit. Hold safety/environmental/operational meeting. Hook up platform communication system in unit. Pressure test lubricator & BOPE to 2,500 psi. Apply 4,000 psi control line pressure to the SCSSV with the auxiliary pump and monitor for leak off prior to RIH. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify Logistic Support and establish communication blackout. Re-establish the communication blackout when guns are ~ 1000' when POOH. SI well. RIH w/ 1-11/16" pivot guns, 4SPF, 180 degree phasing and perforate the following intervals, underbalanced. RUN BENCH INTERVAL FOOTAGE I HB-1 10,465' - 10,480' 15' SI well. POOH. RD E-line unit. Return well to production and obtain a 24-hour well test after cleanup. H: \wp\WLPRO\D43RD DOLLY VARDEN PLATFORM Wireline Lubricator 'W/Associated BOPE MANUALLY OPERATED BOP · GREASE HEAD (Hydraulically Activated) LUBRICATOR · 4'-1~'.--1.6~, 5000 psi CHISTMAS TREE !~~___ 2' 5000 psi [_ i. "~ ~-.-.- 2' 3000 psi 13 3/8' CASING POSITIVE CHOKE Encapsulated 3/8" Chem Inj. Line CBMPLETED 2/86 HARATHF1N [3TL uF]IvlPANY TRADING BAY UNIT D-~3RD 41' CIW 'DCB' Tbg. Hgr 4-1/2" EUE Top X 4-1/2" Butt Btm w/ X-over below, 4-1,/2" Butt X 3-1/2" 29.3' Camco TRDP-1A SSSV 2 812" I.D. Flapper type Cas,ng & Tubing Top O' O' 9,551' O' Bottom S~ze Weight Grade Descrip. .3,069' 15-5/8" 68# K-55 Butt. Csg 9,859' 9-5/8" 47// N-80 Butt. Csg. 11,250' 7" 29# N-80 Butt Liner 9,914' 3-]/2" 9 2# N-80 Butt Tbg. w/ AB Mod Cplg~ Depth 2,514' 4,453' 6,074' 7,23t' 8,204' 8,854' 9,510' 9,686' 9,779' Valve 1 2 5 4 5 6 7 8 9 Mandrel Type Latch Camco MMG-CP 1-1/2" RK 2.88" DRIFT Camco 'KBUG-CP' Camco 'KBUG-ELTS' Injection Mandrel 1" GLV BK-2 2.88" Drift B-1 ]3-3 9,828' 9,840' 9,843' 9,914' Baker Locator 2 88" Drift Baker 'FA-I' Packer Baker Seal Assr 2 88" Dr~ft .3 Jts 3-1/2" Tbg ta~l p~pe 299' ID. Half-cut Mule Shoe 300" ID. Devi = 31°(10,600') Per' ~'or'a"c,ons (DIL) ]3-1 I0,464' - 10,492' 28' 8-3 10,604' - 10,696' 92' 10,678' Bridge Tagged 11-29-92 CTM Fish - GL Valve 11,106' Fill Tagged 5/92 11,166' PBTD Revision Dote: 1/18/93 Revised By: JDN/evo Reason: Update Ppev,ous Revision: STATE OF ALASKA 0 R I 6 IN A ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Operation snutclown m Sbmulate m Plugging m Perforate Pull tubing m Alter casing m Repmr well ~ Other __ 2. Name of Operator NO£AL(Marathon Oil Co. - Sub Operator) 3 Address .0. Box 190247 Anchorage, AK 99519 4 Locat~on of well at sur~a~ A-l, Cond. #9 Dolly 54, FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive interval 5. Type of Well: Development Exploratory Stratmgraph~c Serwce Varden P1 atform 43' FNL, 1,002' FWL, Sec. 6-8N-13W-SM At effective depm .21' FNL, 1,150' FWL, Sec. 6-8N-13W-SM At total depth 16' FNL, 1,170' FWL, Sec. 6-8N-13W-SH 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name TY,~ri-inn R~u lin'if 8. Well number D-43RD 9. Permit number/approval number 85-0311 10 APl number 5o- 733-20373-01 11. F~eld/Pool Hemlock 12 Present well condmon summary Total depth measured 11,250 ' Effecuve depth Casing Structural Conductor Surface Intermediate Production Liner Perforation depth true vertical10,083' measured 11,166' true vertical 10' 009 ' Length 3,069' 13 3/8" 9,839' 9 5/8" 1,699' 7" measured true vertical Bench 1 Bench 3 TuDmg (s~ze, grade, and measured depth) 3 1/2", 9.2#, N-80 e 9,914' PacKers anO SSSV (type anO measured depth) Baker "FA-i" packer 0 9,840' DIL, feet feet feet feet Size 10,454' 10,604' Camco Plugs (measured) 11,166 ' Junk (measured) Non e - 11,250' CMT Cemented Measured depth True vert~cat depth 2,945 sx 3,069' 3,990 sx 9,839' 700 sx 11,250' MD 9,394' MD 9,522' - 10,492' - 10,696' TRDP-1A SCSSV @ 293' 2,907' 8,875' 10,083' - 9,427' TVD - 9,596' TVD 13. SUmulat~on or cement squeeze summary Intervals treated fmeasured) Treatment descnpbon mctudmg volumes used and final pressure DEC 2 199 - Alaska 0il & Gas Cons. Commiss~-on Anchorage 14. Representative Daily Average Producl~on or I njecuon Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation 395 !23 131 !020 140 Subsequent to operat,on 281 / 73 213 15. Attachments ~ 16. Status of well class~fmcatlon as: Copies of Logs and Surveys run ! Daily Report of Well Operat)ons ~ Oil ~ Gas m Suspended __ 17. I hereby certify that the foregoing )s true and correct to the best of my knowledge. S,gned Q ct.,..,.& %, ~ ~ ~, Title '~ ~-, ~.k. u,.,,.3 Form 10-404 Re~B/'15~I 740 Service 120 Date II:Jlk~llT Ilkl ri,1 IDI DAILY WELL OPERATIONS D-43RD 11/20-21/92 RU E-line. Hold pre-job meeting. Put SCSSV on auxiliary pump @ 4000 psi. PT lubricator to 2500 psi. Test good. Establish CBO. RIH. Flow well for underbalance. Perforated the following intervals with 15' pivot gun, 4SPF, 22g. DP charges, 180 deg phased, 90 deg offset. RUN #1 10,475 - 10,490 DIL Fired #2 10,460 - 10,475 DIL Fired RD and return well to production. 11/24/92 RU E-line. Put SCSSV on auxiliary pump at 4000 psi. Pressure test lubricator to 2500 psi. Test good. RIH w/ 2-1/8" 0 phased strip gun. Flow well for underbalance. Perforated the following intervals: Run #3 10,630 - 10,660 DIL Fired #4 10,648 - 10,678 DIL Fired #5 10,610 - 10,630 DIL Fired RD. Returned well to production. 11/28/92 ~afety meeting. RU CT. Lock out SCSSV w/ auxiliary pump. Psi test lubricator to 4500 psi. Test blinds to 4500 OK. Run CT past BOPE, test pipe rams to 2500 psi. All tests good. Fill backside w/ 600 bbls FIW. Safety/operational meeting. Open well. RIH w/ 1.5" CT w/ 74" 2.25" O.D. bypass tool, 16.5" 2.125" OD check valves and 2.5" OD swirl nozzle at 100 fpm, flowline open. Roll over pump w/ 24 NH4C1 as RIH. SD pump. Tag at 10,673' CTM. PU to 10,670'. Start NH Cl. , 2000 psi to fill hole. Pumped 50 bbls 24 pumping 2~b~4~le~l 1 ~M Start 24 . wing valve after 2 bbls diesel out end of CT. PO CT to 10,460. Follow diesel with treatment as follows: · 1000 gal pad acid consisting of 7-1/24 HCl, 104 diesel 2 gal/lO00 gal corrosion inhibitor, 20 lbs/lO0 gal Ferchel and I gal/lO00 gal WS-36. · 3000 gal 64 HCl, 1-1/24 HFw/ 2 gal/lO00 gal corrosion inhibitor, 20 lbs/lO00 gal Ferchek and 2 gal/lO00 gal Low-surf 300. · 4500 gal 24 NH4Cl w/ 6 gal/lO00 gal Cla-Sta XP & I gal/lO00 gal Low-surf 300. · 22 bbls NH4Cl. Initial rate was I BPM, 3800 psi. Slowed rate down to 1/2 BPM for HF treatment 1500 psi, annulus pressure - 900. 9-5/8" CP from 100 to 600 psi after flowline SI, then stayed constant. Increased rate slowly during Cla-Sta overflush to 1 BPM, 2200 psi. Final rate i BPM, 2300 psi. Moved CT across perforated interval during entire pumping time. SD pump. Start POOHw/ CT. CT press down O,annulus pressure down 100. POOH w/ CT. 11/29/92 RD/ Return well to production. H :\wp\WELLOPS\D43RD DEO 2 2 ' , ~STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well ~ Plugging ~ T~me extension ~ t~t~mutate ~ Change approved program ~ Pull tubing ~ Vanance __ Perforate ~ Other ~ 5. Type of Well. , 6. Datum elevabon (DF or KE~i ~"? , -- Development ~ 106' KB above MSL "~eet 2. Name of Operator UNOCAL(Marathon Oil 6o. - Sub Operator) 3. Address P.O. Box 190247 Anchorage, AK 99519 Exploratory __ Strabgraph~c __ Service __ 4. Locat~on of well at surf~l..q~g A-l, Cond. #9 Dolly Varden Platform 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive ,nterval 443' FNL, 1,002' FWL, Sec. 6-8N-13W-SM~ At effective depth 121' FNL, 1,150' t [depLh 86Ct ~L, 1,170' FWL, Sec. 6-8N-13W-SM FWL, Sec. 6-8N-13W-SM 12. Present well condlt,on summary 250 ' Totatdepth. measured 11, feet true vertical 10,083 ' feet Anch0raga Plugs (measured) 7. Unit or Property name Trading Bay Unit 8. Well number D-43RD 9. Permit number 85-0311 10. APl number 5o- 733-20373-01 11. F~eld/Pool ~Hemlock 11,166' - 11,250' CMT Effective depth measured 11,166' feet true vert,cal 10,009 ' feet Junk (measured) Non e Casing Structural Conductor Surface Intermediate Production Liner Perforabon depth: Length Size Cemented Measured depth 3,069' 13 3/8" 2,945 sx 3,069' 9,839' 9 5/8" 3,990 sx 9,839' 1,699' 7" 700 sx measured Bench 1 Bench 3 true verhcat True vertical depth 11,250' 2,907' 8,875' 10,083' 10,454' - 10,492' MD 10,604' - 10,696' MD 9,394' - 9,427' TVD 9,522' - 9,596' TVD Tubing (s,ze, grade, and measured depth) 3 1/2", 9.2#, N-80 0 9,914' B, Pack~r,s Cn(;J ~;SSV (type and..m..eas..u.re..d, de. pt.h,) aKer "ra-l" packer Lo ~9,~4U' MIL, Camco TRDP-1A SCSSV @ 293' 13. Attachments Description summary of proposal X Detailed operations program X BOP sketch 14. Esbmated date for commencing operation 11/20/92 16 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~X Gas __ Suspended __ Service 17. I hereby c~ify that the foregoing is true and correct to the best of myknowledge. Signed k,~ ~ ~_~, ~L) ,_.,._O~,.' Title "~ ¢-, ~.~. ~,~ ('~ k'~. ,, FOR COMMISSION USE ~ N I'.y Condmons of a'pCrovaF: Notify Commission so representative may witness Plug integrity __ BOP Test __ Locabon clearance Mechanical Integrity Test __ Subsequent form required 1"~'/ z'/o ,7/ Approved by order of the Commission ORIGINAL SIGNED BY RUSSELL A. DOUGLASS Form 10-403 Rev 06/15/88 Date J Approval No. ?,;¢,,2__ ..~ mC:) ~ Commissioner Date/, ~ -- ~- ~Z~ SUBMIT IN TRIPLICATE PROCEDURE D-43RD Reperforate HB-1 & 3 · · · Skid rig over Well D-43RD. RU E-line unit. Hold safety/environmental/operational meeting. Hook up platform communication system in unit. Pressure test lubricator & BOPE to 2,500 psi. Apply 4,000 psi control line pressure to the SCSSV with the auxiliary pump and monitor for leak off prior to RIH. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify Logistic Support and establish communication blackout. Re-establish the communication blackout when guns are ca 1000' when POOH. SI well. RIH w/ 1-11/16" pivot guns, 4SPF, 180 degree phasing and perforate the following intervals, underbalanced. RUN BENCH INTERVAL FOOTAGE i HB-1 10,475' - 10,490' 15' 2 HB-1 10,460' - 10,475' 15' Test well for 2 days following Bench I reperforating. RIH w/ 2-1/8" strip guns, 4SPF, 0 degree phasing and perforate the following intervals, underbalanced: RUN BENCH INTERVAL FOOTAGE 3 HB-3 10,660' - 10,690' 30' 4 HB-3 10,630' - 10,660' 30' 5 HB-3 10,610' - 10,630' 20' · · · RD E-line unit. Return well to production and obtain a 24-hour well test after cleanup. Obtain a well test following perforating work. Conduct safety, environmental, operational meeting. RU CTU on wellhead. RU Halliburton pump, lines and tanks. Lock SCSSV open w/ the auxiliary pump. MU wash nozzle/BHA on 1.5" CT. Pressure test CT and chicksan lines to 4000 psi using Halliburton pump. Pressure test CTU blind rams to 4000 psi and pipe rams to 2000 psi. H: \wp\~/LPRO\D43RD RECEIVED PROCEDURE D-43RD Page 2 11. 12. 13. 14. 15. RIH w/ 1.5" CT pumping slowly w/ 24 NH4Cl to 10,700' (bottom of perfs) -- flowline open -- fill CT/ 3-1/2 tbg annulus. Pump treatment as follows: a) b) c) d) e) f) Pump 1000 gallons diesel - SI flowline after 24 bbls pumped and move CT nozzle across perforated interval. Follow diesel with 1000 gallons 7-1/24 HCl w/ 2 gal/lO00 gal HAI-85, 20 lbs/lO00 gal Ferchek A and demulsifier additive. Continue moving CT nozzle across perforated interval as treatment is pumped. Follow HC1 with 3000 gallons 7-1/24 HC1-HF w/ 2 gal/lO00 gal HAI-85, 20 lbs./ 1000 gal Ferchek A and demulsifier additive w/ 1/2 ppg Matriseal-O diverter. Follow HCl-HF with 4500 gallons 24 NH4Cl w/ 6 gal/ 1000 gal Cla-Sta XP. Flush treatment with 22 bbls 24 NH4Cl. SD pump. Monitor well. Start POOH w/ CT. Displace CT w/ 22 bbls diesel. Finish POOH w/ CT. RD CTU and Halliburton. H: \wp\WLPRO\D43RD L)OLLY VARDEN PLATFORM ., Wireline Lubricator w/Associated BOPE ,- GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP 4' ~1 ~--1.6"g-. '5000 psi CHISTMAS TREE POSITIVE CHOKE ----- 2' 5000 psi ~~[[~~ 2' 3000 psi I 13 3/8' CASING Coiled DOLLY VARDEN PLATFORM Tubing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/4' Rams 5000 psi WP HYDRAULIC RAMS 4 1/16:5000 psi CHISTMAS TREE POSITIVE CHOKE 2' 5000 psi 2' 3000 psi 13 3/8' CASING 13-3/8" 68# K-55 butt csg @ 3,069' Encapsulated 3/8" Chemical Inj. Line 3-1/2" 9.2# N-80 butt tbg w/AM Mod Cplgs Top of 7" Liner @ 9,551' 9-5/8" 47# N-80 butt csg @ 9,839' (Completed Baker 'FA-I' Pkr (29'1) Set Top @ 9,840' (DIL) Devi = 31° (10,600') Tagged Fill @ 11,146' WLM 5/87 i~\DING BAY Well D-43RD ' CIW 'DCB' tbg. hgt. 4-l/2" EU5 top x 4-1/2" butt btm w/X-over below, 4-1/2" butt x 3-1/2" 293' Camco TRDP-1A SSSV 2.812" ID flapper type Camco '~G-CP' GLM #1 2,314' latches + 1-I/2" GLV's~ 2.88" Drift 4,453' #2 6,074' #3 7,2B1' #4 8,204' #5 8,834' #6 9,310' #7 9,686' Camco 'KBUG-CP' GLM #8 w/BK-2 latch + 1" GLV 2.88" Drift 9,779' Camco 'KBUG-ELTS' Inj Mandrel w/BK-2 latch 2.88" Drift 9,828' Baker Locator 2.88" Drift 9,843' Baker Seal Assy 2.88" Drift 3 jts ~-1/2" tbg tail pipe 2.99" ID 9,914' Half-cut blule Shoe 3.00" ID Perforations (DIL) Bench 1 10,464' - 10,492' 4 HPF Bench 3 i0,604' - 10,69~' 4 HPF PBTD @ 11,166' TD @ 11,250' .(7" 29# N-80 butt csg) 1. Operabons performed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operahon shutdown __ Sbmulate __ Plugging __ Perforate X__. Pull tubng __ Alter casing __ Repair well __ Other 2. Name of Operator UNOCAL(Marathon Oil Co, - Sub Operator) 3 Address P.O. Box 190247 Anchorage, AK 99519 4 Locat,on of we at surf~eg A- 1, Cond. #9 Dol 1 y 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of producbve interval 443' FNL, 1,002' FWL, Sec. 6-8N-13W-SM At effectwe depth 121' FNL, 1,150' FWL, Sec. 6-8N-13W-SM At total depth 86' FNL, 1,170' FWL, Sec. 6-8N-13W-SM 12. Present well condition summary Total depth measured 11,250 ' 5. Type of Well. Development Exploratory Stratlgraph~c Serwce 6 Datum elevation (DF or KB) 1OR' KR ahnv¢, MRI Z Unit or Property name Trading Bay Unit 8. Well number D-43RD Effecbve depth' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth true verbcal 10,083 ' measured 166' true vertical 11, 10,009' Length 3,069' 13 3/8" 9,839' 9 5/8" 1,699' 7" measured Varden Platform 9. Permit numbedapproval number R~_rY'41 1 /Q9-1 7Q 10. APl number 50- 733-20373-01 11. F~eld/Pool Heml cc k feet Plugs(measured) 11,166' - 11,250' CMT feet feet Junk (measured) feet N o n e S~ze Cemented Measured depth True vertical depth 2,945 sx 3,069' 2,907' 3,990 sx 9,839' 8,875' 700 sx 11,250' 10,083' feet true vertical Bench i 10,454' - 10,492' MD 9,394' -9,427' TVD Bench 3 10,604' - 10,696' MD 9,522' - 9,596' TVD Tubing (s~ze, grade, and measured depth) 1/_2", 9.2#. N-80 0 9,914' Packers and SSSV (type and measured depth) Ba~c,r "FA-l" n~r,L-,=,,-, r~ o ~/1/3, RTl 13. St~mulabon or cement squeeze summary Intervals treated (measu red) Treatment descnption ~nclud~ng volumes used and final pressure N 0¥ - 6 1992, Alaska 0il & Gas Cons. Commission Anchorage 14. Representative Daily' Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed,,.'q ,,~~ ~, ~),..,,..~ Title Form 10-404 Rev 06/1~5/88k--.) 461 401 145 1010 635 ~ 550 234 1020 130 120 16. Status of well classification as: Oil X Gas Suspended Service Date ~l]~i ~)'~ SUBMIT IN DUPLICATE DAILY WELL OPERATIONS D-43RD 6/8/92 Safety meeting. RU E-line unit and lubricator. Lock open SCSSV. Pressure test lubricator to 2900 psi. Good test. Establish CBO and arm 20' of 2-1/8" strip guns, 6SPF, 45° offset set up to shoot low side of prod. casing. Open swab valve. RIH and perforate the following intervals. Run #1 HB-3 10,670' - 10,690' DIL Fired Run #2 HB-3 10,650' - 10,670' DIL Fired Run #3 HB-3 10,630' - 10,650' DIL Misfired Run #4 HB-3 10,630' - 10,650' DIL Fired 6/19/92 Run #5 HB-3 10,610' - 10,630' DIL Fired Run #6 HB-1 10,470' - 10,490' Dil Fired Turn well over to production. H: \wp\WE L LOPS\D43RD R'£ EiVED NO V - 6 )992 Alaska Oil & Gas Cons. Commission Anchorage Chast%aaJ. Xn~l. L.tne -- 3-1/2" 9.21 ~-80 butt v/AH Hod CpLia ~ucc es~ @ 9,839' CDzL) ;hm~kJ, O,~3nO balou, 4-t/2" bucc x 3.-t12# 293* ~..~mmo TIU3~-IA SS.qV 2,B12'* ~D 6.07&* 13 8,834' 16 9,310' Latch + t" CLV 2.~8" Drl~C 9,779' ~m~ 'OU~L~, ZnJ ~,a28, Uakmr ~acor 2.~8~ 9,8430 Rl~r Seal Aaay z.as- ~rZ~C 3 Jo, ~-1/2" cbs c~X pipe 2.99" ZD 9,91&0 ~a.t£-euc HuXa Shoe 3,00' ZD Perforaclono (DXL) 10,604' - tO,6OO* 4. Itt*F RECEIVED. NOV - 6 1992 Alaska Oil & Gas Cons. Comr. nission Anchorage PI'rD ~ t1,166* TO 0 11,2~00 (7" 20l N-gO buct esl) 17Irc I / 80 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 __ Ptugg~ng __ T~me extension __ ,,,%m ulate __ Pull tubing __ Vanance __ Perforate ~ Other __ 2 Name o.f Operator UNOCAL(Marathon Oil Co. - Sub Operator) 3. Address P.O. Box 190247 Anchorage, AK 99519 4 Locat,on of well at surfai~eg A-l, Cond. #9 Dolly 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of producbve ~nterval 443' FNL, 1,002' FWL, Sec. 6-8N-13W-SM At effecbve depth 121' FNL, 1,150' FWL, Sec. 6-8N-13W-SM 86~tt~l¢?P~,170' FWL, Sec. 6-8N-13W-SM 5. Type of Well. Development Exploratory Strabgraph~c Serwce Varden Platform 6. Datum elevation (DF or KB) 106' KB above MSL Z Unit or Propedy name Trading Bay Unit 8. Well number B-43RD 9. Permit number 90-671 ~'" O.~l l 10. APl number 50- 733-20373-- ¢ I 11. Reid/Pool Hem 1 oc k feet 12 Present well condltion summary 11 250' Total depth, measured true verhcal 10,083' Effective depth measured 11,166 ' truevert,cal 10,009' Casing Length Structural Conductor Surface 3,069' Intermediate 9,839 ' Production Liner 1,699' Perforabon depth, measured true vertical feet Plugs (measured) feet feet Junk (measured) feet S~ze Cemented None JUL - 6 1992~¢~ Alaska Oil & Gas Cons. commis¢o~ Measured depth AQ6~~cal depth 13 3/8" 2,945 sx 3,069' 2,907' 9 5/8" 3,990 sx 9,839' 8,875' 7" 700 sx 11,250' 10,083' Bench 1 Bench 3 10,454' - 10,492' MD 9,394' - 9,427' TVD 10,604' - 10,696' MD 9,522' - 9,596' TVD Tubing (s~ze. grade, and measured depth) 3 1/2", 9.2#, N-80 ¢ 9,914' Pack~r, n :~SSV(t pean m a d h) Baker ~-1 pair'er ~ ~,~uz~)q e~t[, Camco TRDP-1A SCSSV @ 293' 13. Attachments Description summary of proposal __ Detailed operabons program X__ BOP sketch 14. Esbmated date for commencing operation 6/7/92 16 If proposal was verbally approved Name of approver Mike Mender 6/5/92 Date approved 15. 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. Signed ~,. ~ ' '- Conditions of ap'~val:~tify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Original Signed By Approved byorderoftheCommission David W. Johnston [ Approval N o. ~;::,<-:, Approved Copy Returned 7-~ Commiss,oner Date '7 //O/9 q,, SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15t88 TBU ~ELL D-43RD · e 0 e Skid rig over Well D-43RD. RU 3-line unit. Hook up platform communication system in unit. Pressure test lubricator & BOPE to 2,500 psi. Apply 4000 psi control line pressure to the SCSSV with the auxiliary pump and monitor for leak off prior to RIH. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE, NOTIFY LOGISTIC SUPPORT AND ESTABLISH COMMUNICATION BLACK-OUT. RE- ESTABLISH THE COMMUNICATION BLACK-OUT WHEN GUNS ARE @ 1000' WHEN POOH. RIH w/2-1/8" strip guns, 6 SPF, 45 degree offset and perforate the low side of the hole in the following intervals, underbalanced. RUN BENCH INTERVAL FOOTAGE 1 3 10,670' - 10,690' 20' 2 3 10,650' - 10,670' 20' 3 3 10,630' - 10,650' 20' 4 3 10,610' - 10,630' 20' 5 I 10,470' - 10,490' 20' RD E-line unit. Return well to production and obtain a 24-hour well test after cleanup. H: \wp\w l pro. D43RD bucC e~8 @ 3,069~ Rneapau].aCnd 3/8" Chanul.=ai In.1. L.tn~ 3-1/2" 9.21 H.-80 bucc tbg v/AB Hod Cp.L~,a (Completed ~-86) ~op og 7" L~na~ ~ (2g~} ~ec ~op @ ~.~40~ TI~ADING BAY UNIT cop x 4-1/2" 5uct bom v/X-ovmr be~ov, 4-1/2' buc~ x 3--i/2' 292* ~G=,~.G TP, D~-i& SSSV 2,a12" !D ~Xappm~ £ypm C,imzo '~'~3=C~' cz.l( Irt v/.m~ AP/<· 2,314' laCQlmm + t-i/2" 2, B8" Ortf C 6,07& * 7,231* ~1, 8,204 ' 8,834' t6 9,310t 9,686' C~seo 'ICBUG-CP~ OLH 18 ZaCch + l" CLV 2.88" DttZC 9,779* Cameo IIOIUO-ELTS, lnJ l~tndrlZ w/aK-2 XiCeh 2.8g" Ort~c 9,828* ~akar LoeaCor 2.86" Dcl~C 2,99** ~ Devt - 3to (I0,600*) RECEIVED d U L - G 1992 Alaska Oil & Gas Cons. bommission Anchorage 9,914' t~aZ~-euc HuZe Shoa 3.00" Per~oraclona (DXL) Bench t X0,464* . t0,492' 4 Bench 3 10,604' - 10,690' (2" 291 ~-80 bucc ess) Revised g£C 1/80 JOLLY VARDEN PL,~TFORM Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP 4'-1/.-'1.6~. 5000 psi CHISTMAS TREE POSITIVE CHOKE 13 2' 5000 psi 3/8' CASING 2' 3000 psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Sbmulate __ Plugging Pull tubing ~ Alter casing __ Repair well Perforate X 2. Name of Operator UNOCAL(Marathon Oil Co. - Sub Operator) 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surf~_C~g A-l, Cond. #9 Dolly 754' FSL, 1,207' FWL Sec. 6-8N-13W-SM Attop of producbve interval ' 443' FNL, 1,002' FWL, Sec. 6-8N-13W-SM At effective depth 121' FNL, 1,150' FWL, Sec. 6-8N-13W-SM At total depth 86' FNL~ 1~170' FWL~ Sec. 6-8N-13W-SM 12. Present well condition summary Total depth: measured 11,250 ' 5. Type of Well: Development X__ Exploratory __ Stratigraphic __ Serwce __ Varden Platform feet Plugs (measured) Effechve depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical 10,083 ' measured 11 166' true vertical 10,009' Length feet feet feet Junk (measured) S~ze Cemented 3,069' 13 3/8" 2,945 sx 9,839' 9 5/8" 3,990 sx 1,699' 7"' 700 sx measured Other 6. Datum elevation (DF or KB) lf)6' KB ahnve M.~I 7. Unitor Property name Tradinq Bay Unit 8. Well number D-43RD 9. Permit number/approval number ~N-fi71 10. APl number 5o- 733-20373 feet 11. Field/Pool Hemlock 11,166' - 11,250' CMT None Measured depth 3,069' 9,839' True vertical depth 11,250' Bench i 10,454' - 10,492' MD 9,394' true vertical Bench 3 10,604' - 10,696' MD 9,522' 2,907m 8,875' 10,083' - 9,427' TVD - 9,596' TVD Tubing (size, grade, and measured depth) 3 1/2", 9.2#, N-80 e 9,914' Packers and SSSV (type and measured depth) Baker "FA-l" packer 0 g.840' DIL. Camco TRDP-1A 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure SCSSV 0 293' 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 8/11/90 225 96 12 1050 10/1/90 708 147 82 1130 Tubing Pressure 130 120 15. Attachment~ 1 Copies of Logs and Surveys run ~ Daily Report of Well Operations ~x 16. Status of well classification as: Oil ~ Gas_ Suspended __ Service 17. I hereby certi,~hat the foregoing is true and correct to the best of my knowledge. Signed(/,~O..~.~ ~-~, ~ ~,X_ Title Form 10-404 Rev ~6{15/8~ Date SUBMIT IN DUPLICATE Attachment #1 TBU Well D-43RD Daily Summary of Operations 8/13/90 RU wireline and PT lubricator to 2500 psi, OK. RIH and tag fill ~ 11,095' DIL. POOH, RD. 8/14/900 E-line and ma~e 4 perforating runs using 2-1/8" Enerjet III strip guns, 4 SPF, phasing w/ 30 offset. Perforated HB-3, 10,660' - 10,690'; 10,630' - 10,660'; 10,604' - 10,630'; HB-1, 10,464' - 10,492' DIL. Flowed well after each run to clean up well. POOH, RD. Place well in test. 8/16/90 Well still in test. RU for clay stabilization treatment. PT lines, OK. 8/17/90 RU and PT CTU & lubricator to 3000 psi, PT surface lines to 5000 psi, OK. RIH w/ 1-1/2" CT pumping FIW at 1/2 BPM to tbg tail @ 9914' MD. Displace FIW w/ 1000 gals 154 HCl plus additives 0 1/2 BPM, SD pumps to tag fill. PU CT to 10,675'. Displace remaining acid and pump treatment as follows: Depth Volume (DIL) (Gal) Additives Rate 10,675' 1500 1500 10,646' 1500 1500 10,618' 1500 1500 10,478' 1500 1500 34 Clafix + .64 Cla-sta XP +.14 Losurf 300 1-1/2 BPM 24 Clafix water + .14 Losurf 300 " 24 Clafix water + .64 Cla-sta XP + .14 Losurf 300 " 24 Clafix water + .14 Losurf 300 " 24 Clafix water + .64 Cla-sta XP + .14 Losurf 300, " 24 Clafix water + .14 Losurf 300 " 24 Clafix water + .64 Cla-sta XP + .14 Losurf 300 " 24 Clafix water + .14 Losurf 300 " Displace last treatment w/ excess Clafix flush - 22 bbls. POOH w/ CT & RD. 8/27/90 RU on well PT lubricator to 2500 psi, OK. RIH and perform SBHP survey. POOH, place well on production. 8/29 - 8/31/90 RU electric line and PT lj~bricator 2500 psi. Make 4 perforating runs w/ 2-1/8" Enerjet III strip guns, 0v phasing, offset 30o, 4 SPF. RIH and perforated HB-3, 10,658' - 10,690'; 10,625' - 10,658'; 10,604' - 10,625'; HB-1, 10,464' - 10,492' DIL. POOH, RD, place well in test. \docs\dvp\d43rd 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 m Re-enter suspended well m Plugging ~ Time extension ~ ..Stimulate __ Pull tubing ~ Variance ~ Perforate ~__ Other 2. Name of Operator UNOCAL(Marathon Oil Co. - Sub Operator) 3. Address P.O. Box 190247 Anchorage, Al( 99519 4. Location of well at surfE~,j~ A- 1, Cond. #9 Del ly 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive interval 443' FNL, 1,002' FWL, Sec. 6-8N-13W-SM At effective depth 121' FNL, 1,150' FWL, Sec. 6-8N-13W-SM At total depth 86' FNL, 1,170' FWL, Sec. 6-8N-13W-SM 5. Type of Well: Development Exploratory Stratigraph~c Serwce Varden Platform 6. Datum elevabon (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Welt number D-43RD 9. Permit number 85-311 iO. APl number so- 733-20373 11. Field/Pool Heml cc k feet 12. Present well condition summary Total depth: meas'ured 11,250 ' true vertical 10,083 ' feet Plugs (measured) feet 11,166' - 11,250' CMT Effective depth:measured 11,166 ' true vertical 10,009' feet Junk (measured) Non e feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 3,069' 13 3/8" 9,839' 9 5/8" 1,699' 7" measured true vertical Bench 1 Bench 3 Size Cemented Measured depth True vertical depth 2,945 sx 3,069' 2,907' 3,990 sx 9,839' 8,875' 700 sx 11,250' 10,083' 10,454' - 10,492' MD 9,394' - 9,427' TVD KE EIVEIJ Tubing (s~ze, grade, and measured depth) 3 1/2", 9.2#, N-80 e 9,914' Packers and SSSV (type and measured depth) RakPr "FA-I" narkPr fa cl_R4f3' 13TI 13. Attachments 1; 2, Description summary c~f proposal X__ &3 Camm TRDP=IA ~C~V 0 292' AUG 2 71990 A/aska 0i! & Gas Cons. Detailed operations program __ BOP sk~'.~,~ 14. 16. Estimated date for commencing operation 8/15/9o If proposal was verbally approved Mike Hinder 8/14/90 Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Signed ~l,~ ?~. ~,.,,-~'.. Title ~'P~_~,;=,~,~,_~L. ~,\k.,~ FOR COMMISSION USE ONLY .) Conditions o~j~)pro~,a~.' Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test __ Subsequent for_m required 10- ~Approved by order of the Commission Form 10-403 Rev 06/15/88 I Date lapprova'No. ~).~:;~?/ I ! ORIGINAL SIGNED BY LON;;;,~ O. r ...... ~,,~1¥1~ I I I Approved CoPY ~oner Date SUBMIT IN TRIPLICATE Attachment #1 D-43RD PROCEDURE OBJECTIVE: LATEST TEST/DATE: WIRELINE PROBLEMS: MINIMUM ID: DEVIATION: PERFORATIONS: GENERAL: REPERFORATE HB# 1,3 FOLLOWED WITH A CLAY STABILIZATION TREATMENT 332 BFPD, 306 BOPD, 7.94 WC 7-31-90 NONE TO DATE 2.812 ~ 293' (SCSSV) a) b) MAXIMUM 37 DEGREE ~ 3000' MD THROUGH PERFS 32 DEGREE HEMLOCK B-1 10,464'-10,492' B-3 10,604'-10,690' A pre-job operational meeting will be held with the Production Foreman, Operator, Production Engineer, Arctic Recoil, Halliburton and Schlumberger service company. The proposed work will be reviewed in detail, responsibilities established, and safety issues discussed. Regular communication will be maintained between the personnel involved in the proposed work and updates provided. This operational meeting will be repeated at the beginning of each shift change. The Production Engineer will be present during all critical activities associated with the job. Communications must be maintained between the service companies and the platform operator throughout the job's duration. In particular, during opening and closing of the well or any choke changes. 1) 2) 4) 5) OBTAIN A 24-HOUR WELL TEST WITH A MINIMUM OF FOUR (4) WC'S. RU E-LINE UNIT. HOOK UP PLATFORM PA SYSTEM IN UNIT. PRESSURE TEST LUBRICATOR AND BOPE TO 2500 PSI. APPLY 4000 PSI CONTROL LINE PRESSURE TO THE TRFV (SCSSV) WITH A HAND PUMP AND MONITOR FOR ANY LEAK OFF PRIOR TO RIH. HAND PUMP TO BE LOCATED NEAR LOWER WELLROOM ENTRY DOOR. NOTE: PRIOR TO RIH MAKE SURE WELL IS PINCHED BACK TO ONE OR TWO TURNS OPEN ON CHOKE; KEEP WELL PINCHED BACK UNTIL THE DUMMY GUN OR PERFORATING GUN IS BELOW THE TUBING TAIL. MAKE A DUMMY GUN RUN TO 10,900' (MAXIMUM PERF GUN INTERVAL 30'). TAG FILL. RIH WITH 2-1/8" STRIP GUNS, 4SPF, 00 PHASING, 300 OFFSET AND PERFORATE THE FOLLOWING INTERVALS UNDERBALANCED (WELL FLOWING). OPEN CHOKE AND Well D-43 Procedure Page 2 STABILIZE FLOW PRIOR TO PERFORATING. PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN HOLE NOTIFY LOGISTIC SUPPORT AND ESTABLISH COMMUNICATIONS BLACKOUT. RE-ESTABLISH COMMUNICATION BLACKOUT WHILE POOH FROM 1000' UNTIL GUNS ARE CONFIRMED TO BE DISARMED. RUN BENCH INTERVAL D I L FOOTAGE I HB #3 10,660'-10,690' 30' 2 HB #3 10,630'-10,660' 30' 3 HB #3 10,604'-10,630' 24' 4 HB #1 10,464'-10,492' 28' 8) **FLOW WELL FOR CLEAN-UP APPROXIMATELY 15-20 MINUTES AFTER PERFORATING EACH INTERVAL. PRIOR TO POOH, PINCH WELL BACK AGAIN. SHUT IN WELL TO POOH (AND RIH) IF HEADING APPEARS TO BE A PROBLEM. RD E-LINE. FLOW WELL TO TEST SEPARATOR AT A REDUCED RATE SLOWLY OPENING THE CHOKE COMPLETELY OVER ABOUT 4 TO 6 HOURS. FLOW WELL IN TEST SEPARATOR FOR 24 TO 36 HOURS OBTAINING WC's EVERY FOUR HOURS. MONITOR SEPARATOR SCREEN FOR PERFORATING DEBRIS. SHUT IN WELL. INSTALL TWO PEN RECORDER AND MONITOR CSG AND TBG PRESSURES. BLEED CASING PRESSURE TO FLARE. MONITOR TBG FOR COMMUNICATION. PRESSURE TUBING IF REQUIRED IN ORDER TO CLOSE CHECKS ON GAS LIFT VALVES. 10) RU ARCTIC RECOIL LUBRICATOR, BOPE, AND CTU INJECTION HEAD. RIG UP HALLIBURTON PUMPS AND SURFACE INJECTIONS LINES. PRESSURE TEST SURFACE INJECTION SYSTEM TO 4,500 PSIG. PRESSURE TEST LUBRICATOR AND BOPE TO 4500 PSIG. 11) OPEN MANUMATIC. OPEN CHOKE 1-1/2 TO 2 TURNS. RIH WITH COILED TUBING TO TUBING TAIL @ 9914'CIRCULATING WELL WITH FIW. INJECT 15 BARRELS OF 15% HCl + 2 GAL./M LoSurf-300 + 2 GAL./M HAI-85 + 20 LBS./M FERCHEK-A @ i TO 1-1/2 BPM DOWN CT AND MONITOR FOR RETURNS. ESTABLISH SURFACE PRESSURE AT SPECIFIED RATES. 12) LIGHTLY TAG FILL TO ESTABLISH DEPTH CORRECTION FOR CT. POSITION COIL TUBING TAIL AT 10,675' MD. CLOSE MANUMATIC AND CHOKE. INJECT THE TREATMENT AND FLUSH LISTED BELOW. MAXIMUM INJECTION PRESSURE NOT TO EXCEED 3000 PSI. REPOSITION THE COIL TUBING TAIL AT 10,646' MD AND INJECT THE TREATMENT AND FLUSH. REPEAT FOR STOPS AT 10,618' & 10,478' MD. DISPLACE LAST FLUSH @ 10,478' MD WITH FIW. TREATMENT: 1,500 GALLONS 24 Clayfix water + .64 Cla-Sta XP + .1~o Losurf-300 FLUSH: 1,500 GALLONS 24 Clayfix water + .14 Losurf-300 WHERE: Cla-Sta XP: Losurf: HA 1-85 .' Clayfix: Ferchek A: clay stabilizer surfactant, nonionic, non-emulsifier acid inhibitor ammonia chloride, clay stabilizer oxygen scavenger and reducing agent for converting ferric iron to ferrous iron Well D-43 Procedure Page 3 13) POOH WITH COIL TUBING. RD HALLIBURTON PUMPS AND TANKS. RD COIL TUBING UNIT. OPEN WELL TO GROUP SEPARATOR AT A REDUCED RATE SLOWLY OPENING THE CHOKE COMPLETELY OVER ABOUT 4 TO 6 HOURS. FLOW WELL 24 HOURS IN GROUP. PLACE WELL IN TEST FOR 24 HOURS OBTAINING WC'S EVERY 4 TO 6 HOURS. 14) PERFORM STEP RATE TEST AND TURN WELL OVER TO PRODUCTION. docs\oe51\68.doc Attacnment ~z .~OLLY VARDEN PL,._rFORM Wireline Lubricator w/A~o¢iated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) ,. LUBRICATOR POSITIVE CHOKE 5000 CHISTMAS TREE -~- 2' 5000 pal _.-- 2' 3000 pal 13 3/8' CASING Attachment #3 DOLLY VARDEN PLATFORM Coiled Tubing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/4' Rams 5000 psi WP HYDRAULIC RAMS 3 1/8' 5000 psi CHISTMAS TREE POSITIVE CHOKE ~ 2' 5000 psi ,. 2' 3000 psi 13 3/8' CASING STATE OF ALASKA COMMI~5:51ON J'~ D D GAS CONSERVATION REPOFIT OF SUNDRY WELL OPEFIATIONS § J 1. Operations performed: Operation shutdown ~ Stimulate __ Plugging ~ Pedorate Z... Pull tubing __ Alter casing ~ Repair well ~ Other ~ 2..l~ak'o.e.c~f Q~erato.r, ur~u[,AL[Mara~:non 0il Co Sub Operator) 5. Type of Well: 6. Datum elevation (DF or KB) · Development__X 106' KB above HSL feet Exploratory __ , Stratigraphic __ 7. Unit or Property name 3'l~.d~r. eS§ox 190247 Anchorage, AK 99519 Service__ Trading Bay Unit 4. Location of well at surfaceLeg A-l, Cond. #9 Belly Varden Platform 8...We),l.o~jmber 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM U-~51{U I~ o duc iv i r, val · 9. Permit number/approval number ~t~ ~[[~, i,~)(~ FWL, Sec. 6-SN-13W-SM 9-283 l~ftec~t-d,ep~, 150' FWL, Sec. 6-8N-13W-SM lo. APl number 5O-- 733-20373 11. ,Field/Poql ~tot~[.~th1,170, FWL, Sec. 6-8N-13W-SM ~em~ocK 12. Present well condition summary 11,250 ' Totaldepth: measured 10,083' feet Plugs(measured) 11,166' - 11,250' CMT true vertical feet Effective depth: measured 11,166 ' feet .Junk(measured) None true vertical 10,009 ' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 3,069' 13 3/8" 2,945 sx 3,069' 2,907' Intermediate 9,839' 9 5/8" 3,990 sx 9,839' 8,875' Production Liner 1,699' 7" 700 sx 11,250' 10,083' Perforation depth: measured Bench i 10,454' - 10,492' MD 9,394' - 9,427' TVD true vertical Bench 3 10,604' - 10,696' MD 9,522' - 9,596' TVD Tubjnc~ (size, grade, and measured depth) 31/2TM,9.2#, N-80 e 9,914' BaPka~r~u~d-S~$Vl~t~<~nrdr~e~u~e~(~PP~tL, Camco TRDP-1A SCSSV 0 293' R E C [~ ~ V E a 13, Stimulation or cement squeeze summary Intervalstreated(measured) AUG 1 o ' Alaska 0il & Gas Cons. Commission Treatment description including volumes used and final pressure Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 6/28/89 554 72 31 1020 150 Subsequent to operation 7/13/89 637 194 53 1000 130 15. Attachmentsy, i 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil X__ Gas __ . Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /__/._ ~ Title Environmental Engineer Date 8/7 Form 10-404 Rev 06/15188 )erts ~:~ SUBMITINDUPLICATE ' Attachment #1 TBU Well D-43RD Daily Summary of Operations 7/5-7/6/89 RU E-!/ne and PT lubricator to 2500oPSi, OK. Made five perforating runs using 2-1/8 Enerjet strip guns, 4 SPF, 0 phasing. With well flowing, correlated and perforated Bench 3, 10,660' - 10,690'; 10,630' - 10,660'; and 10,604' - 10,630' DIL, Bench 1, 10,472' -10,492'; 10,454' -10,472' DIL. RD and place well in test. \docs~dvp\D43RD. doc STATE OF ALASKA AL,~,,~KA OIL AND GAS CONSERVATION COM MI~,c~.iON 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 extenmon __ Stimulate __ Pull tubing __ Variance __ Perforate ~_ Other __ 2. Name of Operator I1NOCAL(Marathon Oil Co. - Sub Operator) 3. Address P.O. Box 190247 Anchorage, AK 99519 5. Type of Well: Development___ Exploratory __ Stratigraphic __ Service __ 4. Location of well at surfac(Leg A-l, Cond. #9 Dolly 754' FSL, 1,207' FWL, Sec. 6-SN-13W-SM At top of productive interval 443' FNL, 1,002' FWL, Sec. 6-8N-13W-SM At effective depth 6-SN-13W-SM 6-SN-13N-SM Varden Platform 6. Datum elevation (DF or KB) 106' KB above HSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-43RD 9. Permit number 85-311 10. APl number 121' FNL, 1,150' FWL, Sec. At total depth 86' FNE, 1,170' FWL, Sec. 12. Present well condition summary Total depth: measured 11,250 ' true vertical 10,083 ' feet feet 50- 733-20373 '; "-~".', i.." ~,'-~ .11 Field/Pool ' "' Comm~sCt(.-- ¢, ' Hem-1 ob~ ogs (~ u e ) Effective depth: measured 11,166' feet true verbca110 ,009 ' feet Junk (measured) None Casing Length S~ze Structural Conductor Surface 3,069' 13 3/8" Intermediate 9,839' 9 5/8" Producbon L,ner 1,699' 7" Perforation depth: measured true vertical Cemented Measured depth True vertical depth 2,945 sx 3,069' 2,907' 3,990 sx 9,839' 8,875' 700 sx 11,250' 10,083' Bench I 10,464' - 10,492' MD 9,404' Bench 3 10,604' - 10,690' MD 9,522' - 9,427' TVD - 9,596' TVD Tubing (size, grade, and measured depth) ~ 1/2" 9 2# N-80 @ 9 914' Packers and Sg.'g.V (type pnd m~a,%u re,,,cJ, ¢,qpt~ BaKer ~FA-'I-~' packer ~o ~,~u uIL, Camco TRDP-1A SCSSV @ 293' 13. Attachment~; #1 & Description summary of proposal #2 Detailed operations program __ BOP sketch L 15. Status of well classification as: 14. Estimated date for commencing operation April 19, 1~8.p 16. If proposal was verbally approved Oil X__ Gas __ Name of approver Date approved Service 17. I hereby certif, y that the foregoing is true and correct to the best of m,.f knowledge. Rdy' Roberts /_r , i ~'~' FOR COMMISSION USEONLY Conditions of approval: Notify CorrCmission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved C.opy ORIGINAL SIGNED BY Approved by order of the Commissiob§N?,llE C SMITH o/~_~~mm~'ssioner Form 10-403 Rev 06/15/88 Suspended__ Date 4/12/89 I Approva, No. ~ ~ D ate ~'/'-'~/r2~ .... ~ ,~' SUBMIT IN TRIPLICATE Attachment #1 Well D-43RD Procedure 1. RU E-Line. PT to 2500 psi. 2. Perforate Bench 1 & 3 with 2-1/8" strip guns, 4 SPF, 0© phasing, with 500 psi underbalance. Run Bench Interval Footage I 3 10,660' - 10,690' 30' 2 3 10,630' - 10,660' 30' 3 3 10,604' - 10,630' 26' 4 1 10,472' - 10,492' 20' 5 I 10,454' - 10,472' 18' 3. RD E-line. 4. Bring well on slowly over 24 hours and then put in test. Note' Maximum anticipated SBHP is 2800 psi. em/DVP Attachment #2 ~OLLY VARDEN PL~'FORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) - LUBRICATOR 4,1/~,6~, 5000 psi CHISTMAS TREE POSITIVE CHOKE ~ 2' 5000 pal _.-- 2' 3000 psi ------- 13 3/8' CASING STATE OF ALASKA ~ . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate X Plugging __ Perforate __ Pull tubing __ Alter casing ~ Repair well __ Other 2. Name of Operator U~,OCAL(Marathon Oil Co. - Sub Operator) 3. Address P.0. Box 190247 Anchorage, AK 99519 5. Type of Well: Development X__. Exploratory __ Stratigraphic ~ Service __ 4. Location of well at surfac~Leg A-l, Cond. #9 Dolly 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive interval 443' FNL, 1,002' FWL, Sec. 6-8N-13W-SM At effective depth 121' FNL, 1,150' FWL, Sec. 6-8N-13W-SM At total depth 86' FN[, 1,170' FWL, Sec. 6-8N-13W-SM Varden Platform 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-43RD 9. Permit number/approval number 8-582 10. APl number 5o-- 733-20373 11. Field/Pool Hemlock 12. Present well condition summary Totatdepth. measured 11,250' true vertical 10,083 ' feet feet Plugs (measured) 11,166 ' Effective depth: measured 11,166' feet Junk(measured) None true vertical 10,009 ' feet Casing Length Size Cemented Measured depth Structural Conductor Surface 3,069' 13 3/8" 2,945 SX 3,069' Intermediate 9,839' 9 5/8" 3,990 SX 9,839' Production Liner I ,699' 7" 700 SX 11,250' Perforation depth:measured Bench I 10,464' - 10,492' MD 9,404' true vertical Bench 3 10,604' - 10,696' MD 9,522' 11,250' CMT True vertical depth 2,907' 8,875' 10,083' - 9,427' TVD - 9,596' TVD Tubing (size. grade, and measured depth) 3 1/2", 9.2#, N-80 @ 9,914' Packers and SSSV (type and measured depth) Baker "FA-I" packer @ 9,840'DIL, Camco TRDP-1A SCSSV @ 293' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment #1 Treatment description including volumes used and final pressure RECEIVED 14. Prior to well operation Subsequent to operation 1/24/89 3/6/89 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 512 338 39 1070 465 33 15 :[080 Tubing Pressure 120 110 15. Attachment&( ¢1 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, Signed Form 10-404 Rev 06/15/88 Title Environmental Engineer Date 04/06/89 SUBMIT IN DUPLICATE Attachment #1 Daily Summary of Operations TBU Well D-43RD 2/11/89 RU CTU and PT lubricator to 4000 psi, OK. RIH to 9914' CTM. Pump FIW and RIH to 10,700' CTM, no returns. PU to 10,350', pumping FIW. No returns. Began pumping acid treatment as follows' Rate Pressure Volume Fluid BP___~M P.S.!.. stage 1 stage 2 600 gal 7-1/2% HCl + additives +Cla Sta 1.25 4000 2000 gal 6 - 1-1/2% HC1-HF + additives +Cla Sta 1.25 4000 1000 gal 2% NH~C1 + additives +Cla Sta 1.25 4000 2000 gal 2% NHJCl + additives 1.25 4000 2000 gal 2% NH~C1 + additives + diverter 1.25 4000 1000 gal 7-1/2% HCl + additives +Cla Sta 1.25 4000 2000 gal 6 - 1-1/2% HC1-HF + additives +Cla Sta 1.25 4000 1000 gal 2% NH,Cl + additives +Cla Sta 1.25 4000 4000 gal 2% NH~C1 + additives 1.25 4000 15 bbls FIW 1.25 4000 All volumes injected. PU CT to 200' and displace CT w/ diesel. POOH and RD. Place well in test. em/31B/DVP STATE OF ALASKA ALA~-<A OIL AND GAS CONSERVATION COM~dlSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown . ] Re.enter suspended well ~ Alter casmg T~me extension Change approved program Plugging ? Stimulate .~: Pull tubing Amend order ,r Perforate [' Other 2 Name of Operator 5. D~bu6~ elevation (DF UNOCAL (Marathon Oil Company - Sub Operator) . KB above 1~B) feet 3 Address 6. Unit or Property name P.O. Box 190247 Anchorage, AK 99519 Trading Bay Unit 4. Location of well at surface~eg A-l, Cond. ~9 Dolly Varden Platform 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive ~nterval 443' FNL, 1,002' FWL, Sec. 6-8N-13W-SM At effective depth 121' FNL, 1,150' FWL, Sec. 6-8N-13W-SM At total depth 86' FNL, 1,170' FWL, Sec. 6-SN-13W-SM 7. Well number D-43R~ 8. Permit number 85-311 9. APl number 50-- 733-20373 10. Pool · Hemlock 11. Present well condition summary Total depth: measured true vertical 11,250' feet Plugs (measured) 10,083 ' feet 11,166' - 11,250' CMT Effective depth: measured true vertical Casing Length Structural Conductor Surface 3,069' Intermediate 9,839' Production Liner 1,699' Perforation depth: measured 11,166' feet Junk (measured) 10,009 ' feet Size Cem(~nted None Measured depth 13 3/8" 2,945 sx 3,069' 9 5/8" 3,990 sx 9,839' 7" 700 sx 11,250' Bench 1 true vertical Bench 3 Tubing (size, grade and measured depth) True Vertical depth 2,907' 8,875' 10,083' 10,464' - 10,492' MD 10,604' - 10,696' MD 9,404' - 9,427' TVD 9,522' - 9,596' TVD Pack3ers1 and 'SS9SV~/{~peN;n8d0measured @ 9,914'depth) ' Baker "FA-l" packer ~ 9,840' DIL, Camco TRDP-1A SSSV ~ ~2~aOi~&~c,,~ 12.Attachments 1 & 2 Description summary of proposal ~ Detailed operations program 13. Estimated date for commencing operation August, 1988 14. If proposal was verbally approved Sul~seqnent ~Vork l~eporterl on Form No. --------- Dated ~/--4C-- Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~,~,?. ~~ ~.~.~./b~,'~ .~-~,., Title Envi ronmenta 1 Engineer Signed ~ Roy D. Robe~ts~ I ~ -d~-" Commission Use Only Date 7/~Zff88 Conditions of approval Approved by 0RIGINA[ SIGNED BY [0NN~r. C. RMITH Form 10-403 Rev 12-1-85 N,otify commission so representative may witness I Approval No. 1-., Plug integrity [] BOP Test I-1 Location clearance · ~pproved Copy Returned Commissioner by order of the commission Date Submit in triplicate Attachment # 1 Well D-43RD Acid Stimulation Procedure 1. RU CTU and pump equipment. Pressure test equipment to 4000 psi. 2. RIH w/ coil tubing to 10,700'±. Fill tubing and coiled tubing w/FIW and establish circulation. 3. Circulate in place (across the perfs) the first 10 bbls of 7-1/2% HC1 w/additives. 4. Close annulus and inject into the formation the remaining treatment as detailed below. Do not exceed 4000 psi. Move coiled tubing across all zones throughout job. Treating Volumes a. 2000 gal. 7-1/2% HC1 containing: 0.1% LOSURF 300 surfactant 0.2% HAI-75 corrsion inhibitor 0.6% CLA-STA XP clay stabilizer 40 lbs FERCHECK A iron chelating agent b. 4000 gallons 6% HC1 - 1-1/2% HF containing: 0.1% LOSURF 300 surfactant 0.2% HAI-75 corrsion inhibitor 0.6% CLA-STA XP clay stabilizer 80 lbs FERCHECK A iron chelating agent c. 2000 gal. 2% ammonium cholride containing: 0.1% LOSURF 300 surfactant 0.6% CLA-STA XP clay stabilizer d. 10,000 gal. 2% ammonium chloride containing: 0.1% LOSURF 300 surfactant e. Displace to top perf w/FIW. 5. POH and RD CTU and pump equipment. 6. Unload and test well. em/NEF/DVP Ncre. Static bottom hole pressure not expeded to exceed 3,000 psi. Attachment #2 DOLLY VARDEN PLATFORM Coiled Tubing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/4' Rams 5000 psi WP HYDRAULIC RAMS 3 1/8' 5000 psi CHISTMAS TREE POSITIVE CHOKE 2' 3000 psi 13 3/8' CASING 2' 5000 psi Alaska R n Domestic"P~oduction Marathon Oil Company R O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 June 13, 1988 John F. Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage AK 99501-3192 Dear John' Per our conservation yesterday, enclosed are core descriptions from the Well TBU D-43RD. Regarding the depths from the core not represented in chip samples recently sent; those depths are included in several sections of core which are still frozen in the original sleeves, for the purpose of later analysis. When the core is slabbed and thawed, chip samples will be sent to you as soon as possible. I anticipate this occurring within the next six to twelve months. Thank you. RiP'ch Drumheller DE6-32 Enclosure A subsidiary of USX Corporation 10,459' to 10,460.5' CORE DESCRIPTION - WELL TBU D-43 Hemlock - Bench 1 Coal. Black to dark brown, brittle, slightly fissle, in apparent ero- sional contact with underlying sand. There exists a gravel lag at the base of the coal. Pebble size volcanic and chert fragments. Subangular to subround clasts. Core recovery good, but bedding jumbled. 10,460.5' to 10,462.5' Light gray to light brown sand, medium to coarse grained, subangular, no pebbles, light oil stain pervasive, but not as strongly oil stained as the unit below. Clast composition volcanics, chert, quartz with minor organic debris. Mudstone drape at 10,461.6' for 3" with some climbing ripples noted. Thin beds exhibit maximum dip about 25°. The sand exhibits no obvious grading in this interval. 10,471' to 10,477.6' jL!N 1 7 198,f~, Light bro~ sandy pebble conglomerate. At least e~ght cycles of deposi- tfon observed ~n this Interval less than one foot thlck each. Crude but obvious grading, which f~nes upward indicating high energy environment and rap~d gradient changes v~th~n the stream energy. Occasionally hard, occasionally still porous layers, generally light gray to 11ght bro~. Composition: volcanic grains, chert, and quartz, ~ith mlnor organic debris. ~oderate Imbrication noted ~n most of the pebble clasts. Clasts are subangular to subround elongate pebbles, 1 to 3 em in size. The Core Description ~_£BU D-43 Continued ........... Pag~ ~_~ ................... pebbles are chert, volcanic, and quartz. The volcanics are occasionally larger. The sand matrix supports the pebble clasts and is coarse to fine, locally good size sorting, subangular grains, maximum dip about 50°. 10,480' to 10,482.6' Sandy conglomerate, matrix supported, generally white to light gray with very little oil stain. This is well indurated due to calci~in clay cementing. More organics present than above and minor coal. Organics may have contributed to the calcification of the sandstone. Two deposi- tional cycles are noted approximately one foot each with crude grading fining upward. Pebbles are subangular 2 to 5 cm in size exhibiting a crude imbrication. Matrix is medium to coarse grained sand of similar composition. 10,519' to 10,530.7' Hemlock - Bench 2 Conglomeratic sand. Conglomerate is minor, sand is well bedded with - organic partings along bed surfaces. Color light brown due to oil stain. Pebbles are 1 to 3 cm maximum, usually 1 to 4 mm in size exhibiting good imbrication. Dip maximum is about 45°. Sand is coarse to medium grained Core Description ,___BU D-43 Continued ........... Page 3 and occasionally quite fine at the top of cycle intervals with less apparent porosity at the top due to possible organic content. 10,530.7' - 10,532' Conglomerate with coarse sand matrix with larger pebbles. Sand is coarse almost to pebble size with good dark brown oil stain and apparently good reservoir rock. 10,532' to 10,535' Sandy, light brown pebble conglomerate similar to below but marked increase in pebble content. Brown oil stain strongly imbricated. While much coarses on top, there exists three cycles of fining upward deposi- / tion, each with similar composition. Largest clast generally volcanic and overall composition volcanic, chert, quart/~, with minor coal and lithic fragments. grained. 10,535' to 10,541' Pebbles are 1 to 2 cm in size. Sand is medium Light brown medium to coarse sand with minor pebbles and locally conglomeratic in part. Bedding is evident. Little organic matter. No grading observed in the sand intervals. One 8" section of pebble con- glomerate found at 10,535' to 10,536'. Generally, arkosic or subarkosic Core Description -~.BU D-43 Continued ........... Page 4 appearance, but chert, volcanic, quartz are the observed constituents. Subangular to subround sand, pebbles are subround to subangular. Not a great deal of imbrication noted. Maximum dip about 55°. 10,541 to 10,544.8' Pebble to cobble conglomerate. Dark brown oil stain. Increased oil content. Good a_a_a_~nt porosity and permeability. Check plug taken at 10,541' for confirmation. Three good depositional cycles noted. Good pebble._imbrication. Moderate to poorly sorted core sand matrix also exhibits imbrication. 10,544.8 to 10,545.5' Mudstone/claystone~ gray,--welt bedded, -a dip about 45° maximum. Claystone overlies conglomerate. Claystone has organic debris, woody fragments. Underlying conglomerate has sand matrix which is well indurated due to possible calcic cement. Most of the higher induration occurs near organic debris. The pebbles in the conglomerate are subrounded. Core Description BU D-43 Continued ........ i~.Page 5 10,545.5' to 10,556.5' Medium gray-brown sand, lighter oil stain, about 30° dip indicated. Well sorted sand grains. Clay matrix medium to fine graif'~~ Chert, volcanic, ..... ~rt~_i~omposition grain subrounded to subangular. Organic debris throughout. Clay possibly cause of lesser apparent permeability in this sand unit. 10,562' to 10,573' Pebble conglomerate grading from coarse pebble at the base to fine pebble conglomerate at the top of each of five similar cycles with varying amounts of organic debris present, including woody, coaly matter, and associated intervals with very hard calci~' cementing. Thin section to be taken mt '10,562.2' w~ll show transition from very hard impermeable sand to very porous oil wet sand, which is medium grain, well-sorted subangular and arkosic in appearance. Sand is generally medium grained and the pebbles are 1 to 3 cm in size. 10,573' to 10,576' Two cycles of deposition are noted. Coarse pebble conglomerate grading to fine pebble conglomerate with medium grained sand matrix, including several layers of hard calcic cement; one noted at 10,575' where plug was Core Description -~BU D-43 Continued ........... Page 6 ...... taken.for analysis. This plug occurs 6" above good apparent porosity and permeability. 10,576' to 10,592' Sandy pebble conglomerate, light brown oil stained exhibiting moderate to strong imbrication, possible porosity impairment due to clay content. Oil stain not quite as strong as below. As many a six cycles of deposi- tion are noted within this interval. Pebbles are chert, volcanic, quartz, subrounded, equant to elongate, including minor coal. Sand matrix is medium to' coarse grained, subround to subangular, quartz, volcanic, chert, feldspar, clays having beds occasionally up to 1' thick, nearly devoid of clasts, and occasional beds which are clast supported. Maximum dip is about 30°. 10,592' to 10,592.9' Coarse, light brown sand with minor pebble content. Well imbricated where pebbles are present. The sand has an arkosic appearance, having as ~,constituents quarts, volcanics, chert, plus possible clay and felspar and minor coal. Good apparent porosity and permeability. Core Description .... BU D-43 Continued ........... Page 7 Hemlock - Bench 3 10,663' to 10,665.7' Light brown clast-supported pebble conglomerate. Bedding has an apparent maximum dip of about 50°, strongly oil stained. Clasts are strongly imbricated, subrounded and elongate. Sand matrix is subangular to subround. 10,665.7' to 10,666.8" 10,666.8' to 10,673.6' Light brown matrix-supported pebble conglomerate, 70% sand matrix. Medium to coarse grained, moderately sorted subangular oil stained having chert, volcanic, quartz composition. Me_~re bedding structures observed. Appears to be one general pulse of sedimentation within this interval ~ ~ ~% Some intervals missing, but at least one good sequence represented. Medium to fine grained sand varying to small pebble conglomerate varying to large pebble conglomerate. Similar sand matrix throughout. Similar composition to above. Oil stained except in upper sand, where some calcic cement increases degree of induration and decreases porosity and permeability. Core Description BU D-43 Continued ......... ~7. Page 8 Hemlock - Bench 4 10,714' to 10,721.2' Light brown pebble conglomerate, matrix supported. Similar composition to below. Light brown oil stained matrix. Clasts show imbrication and may exhibit up to 10 to 11 cycles or pulses of deposition within this interval, all of similar energy. Pebbles 1 cm in size generally, moderate sorting, medium to coarse grained sand matrix, composition is chert, volcanic, quartz, with occasional coal fragments. 50% to 70% sand present. Sand is generally more abundant within this interval and below. 10,721.2' to 10,733.0' Pebble conglomerate. Possibly as many as 11 cycles of deposition occur within this interval, each less than one foot thick. 50° dip maximum noted. Imbrication strong throughout this interval. Pebbles are elon- gate, subround and are chert, volcanic, and quartz grains--with_ minor coal. Matrix is medium grained sand exhibiting moderate sorting of similar composition to pebbles with wide spread pervasive oil stain. Generally,_'conglomerate is clast-supported, but occasionally is matrix-supported within the interval. Core Description CBU D-43 Continued ........... Page 9 I0,733' to 10,736' Similar cycle to below, except strongly indurated sand present, probably calcic clay matrix. Otherwise, sand is similar to below, except no oil stain. Oil stain limited to conglomerate intervals. 10,736' to 10,741.6' Matrix-supported conglomerate with basal cobble lag having pebble conglomerate above. Occasionally well imbricated. Maximum dip apparently 30° The pebbles are quartz, vari-colored chert, subangular · to subround, including volcanic clasts as well. Arkosic appearing, medium~s~n~gr~rfn matrix, including volcanic chert and quartz, which is angular to subangular, with good size sorting, pervasive oil stain ~hroughout. ~- 10,741.6' to 10,742' Another similar cycle exhibiting crude grading with minor coal clasts in a subangular pebble conglomerate. 10,743' to 10,744' Pebble to cobble conglomerate. One depositional cycle represented with base about 10,744', including minor quartz and chert cobbles at base grading up to pebble conglomerate near the top. Generally, conglomerate Core Description ~TBU D-43 Continued ........... Page 10 is matrix-supported with minor pebble imbrication. Sand is light brown oil stained, arkosic in appearance, w~ll sorted and subangular to sub- rounded. 10,747.8' to 10,750' Clast-supported pebble conglomerate. Pebbles are quartz, dark chert, which are about 1 cm in size and are moderately to well sorted, subround to subangular, medium-grain sand matrix, oil stained, clay appearance, which is white to yellow in color. Bedding not readily apparent. Possible structural dip less than 5°. 10,750' to 10,769' Massive sandstone, same as below except increased oil content. Pre- sumably better porosity. Occasional pebbly beds present. Arkosic ........... appearance, sorting very good. Medium grained, occasionally woody, coaly debris present. Sand is subangular to subrounded. 10,769' to 10,777.6' __Gray to brown medium grained sandstone. Heavily oil stained. Bedding structures are observed up to 10,769'. Occasional pebbles throughout. Oil stained except at hard streaks, which are apparently non-calsic in this section. Pebbles are quartz to dark chert. Bedding is punctuated Core Description -~rBU D-43 Continued ........... Page 11 by thin carbonaceous layers. Some bedding stratigraphic and showing stratigraphic but not structural dip. Structural dip is about 2° to 5°. 10,782' to 10,799' Sandy conglomerate. Nearly four complete vertical cycles are represented. Generally, medium gray pebble to cobble conglomerate, which is matrix-supported. The clasts are chert, volcanics, mudstone. Dip is less than 10° generally. Clasts are subangular to angular for the larger clasts and subrounded for the smaller clasts; that is, larger clasts may be more locally derived, whereas smaller clasts have traveled greater distance. Matrix is medium to gray and brown oil stained sand, except to light gray at apparent hard streaks. Hard streaks have calcic cement, are well to moderately indurated. Sand has salt and pepper appearance. Composition is chert, volcanics, and quartz. Crude grading noted in each of the cycles. Coarse at the base to fine at the top of each cycle. Imbrication is moderate to strong, indicating probable traction transport of units throughout core. ~ Base of Core June 9, I988 Telecopy No. (907) 276-7542 Rich Drumhelier Geologist Marathon Oil Company P O Box 190168 Anchorage, AK 99519 Re: TBU State D-43RD 85-31i Dear Mr Drumheller: After reviewing the well history and core chips, I see that the following interval~ are missing: Core #I 10,479 Core #5 10,668 669 Core #2 10,526 10,671 527 672 10,537 538 Cor~ #6 10,723 724 Core #3 Core ~4 10,557 558 Core #7 10,737 559 738 560 739 561 10,745 746 10,563 747 564 565 Core #8 10,752 10,570 753 571 10,585 Core ~9 10,766 586 767 768 Core #t0 10,791 792 793 Please look into this matter and give me a call at 279-2433. Sincerely, Alaska F,..~on Domestic Production Marathon Oil Company RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 June 1, 1988 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage AK 99501 Dear John' Per your recent request, we are sending with this letter chip samples from core taken from the Well' TBU State D-43RD. The general core descriptions will be forwarded as soon as possible. Sincerely yours, Ri ch Drumheller Geologist DE6-48 .. Copy' R. C. Warthen, Unocal A subsidiary of USX C6~oration Alaska DIstrict Unocal Oil & Gas Divisio Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL DOCUMENT TRANSMITTAL May 3, 1988 HAND DELIVERED TO: John 8oyle FROM: R.C. Wartnen K. D. Kiloh LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Regarding' Trading Bay Unit, McArthur River Field, D-43 (D-43RD) well One copy of Well History PLEASE ACKNOWLEDGE RECEIPT 8Y~IGNING AND RETURNING ONE COPY OF THIS DOCLNENT RECEIVED BY: ~ ~___~ ~ AJaska C~t & G~:, Cc,~:. C;,mmissiorl Anc:;om9. e 11-84 ~ 3-%i. h..~F:IATHON OIL HISTORY OF OIL OR GAS WELL BLOCK .... % McArthur " River WELL NO. D-43 LEASE Tradinq Bay Unit STATE Alaska . . ELEV SEC. 6 TWP 8N r.1. 3W-SM COUNTY Kenai Peninsula Borough . t ToP oF OIL STRING ELEV,~ MEASUREMENTS TOP OF ROTARY TABLE~ ELEV. TAKEN FROM [ORD. OR MAT, ELEV. ~ S. K. Bushue HISTORY PREPARED ElY TITLE Secretary II is o! the grealest importance lo hove a complete hislory of the well. Use this-form in reporting Ihe history of all Important operations at Ihe well, logether with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1984 __ 11-06: 11-07 11-08 11-09 11-10 11-11 11-12 11-13 11-14 11-15 11-16 11-17 '11-18 11-19 601'TD 1,301'TD 1,930' TD 2,790' TD TBU Well D-43 (Marathon AFE'#8217-4) .,.,,, .... ... -RECEIVED General RU. "~V~A'y'O /t l,gq~a :.. -.. General Ru.NasEa-0ii'& Gas Cons. dommlsslon Continued mobilizing ~g ~76. Continued mobilizing Rig #76. Continu/ed mobilizing Rig #76. Fin mobilizing Rig 976. RIH, conductor #9, w/26" bit. Tagged fill & cir clean @ 345'. POH. RIH w/14" magnet to recover pile hammer guide. Recovered +1/2 gal large rust chips in two runs. RIH w/26" bit. Circ clean @ 349'. POH. .Tripped magnet. Recovered 1" thick plate of triangular shape 15-1/4" x 11-3/4" x '9-1/4"; part of hammer guide. Tripped magnet w/no recovery. Tripped 26" bit &circ cl~h @ 354'. RIH w/magnet. · . Continued fishing for pile hammer guide. Tripped 14" magnet twice--no recovery. RIH w/26" bit &circ mud sweep.. POH. RIH w/14' magnet & 26" cut lip skirt. Circ & rotate to 359'. POH. Recovered 1/2 gal rusty metal chips. Center of magnet polished. Tripped same tools & circ to 361'.. POH. No recovery. Tripped 14" magnet w/flush guide. Pumped mud sweep. POH. No recovery. Ran gyro survey in conductor. RIH w/26" bit. Fin RIH w/26" bit. Washed to 363'. Circ & POH. Tripped 14" magnet w/flush guide. No recovery. RIH w/14" magnet w/26" skirt. Washed & rotated to 368'. POH. Recovered remainder of pile hammer guide. RIH w/26" bit. Washed & rotated to 400'. POH. Began RU diverter syst. em. RU diverter system. Mixed spud mud. MU 17-1/2" BHA. RiH to 400' w/17-1/2" assbly. Displ FIW w/mud. Fn tstd diverter. Drld to 452'. POH. RIH.w/12-1/4" bit & DD. Oriented due west & drld & surv 452-601'. Drld 601-633' w/DD. Surv & POH. RIH w/drop assbly. Drld & surv 633-1301'. POH. MU DD, MWD BHA & RIH. Fin RIH. DD 1301-1308'. Surv w/MWD. Checked w/SS gyro. DD 1308-1588' Surv w/MWD. Checked w/SS gyro @ 1562'. DD & surv to i775'. POH & LD DD assbly. RIH w/build assbly. Drld & surv to 1930'. Drld & surv 1930-2520'. POH. Worked on drwk brake & chgd MWD electronics package. MU locked BHA & RIH. Drld & surv 2520-2790'. well History - Dolly Varden No. D-43 p&g e '2 11-20 3,077' TD 11-21 3,077' 11-22 3,077' TD 11-23... .... '.: 3077' TD 11-24 3077' TD 11-25 3077' TD 11-26 3077' TD 11-27 3120' TD 11-28 3492' TD 11-29 3492' TD 11-30 3492' TD 12/01 3492' TD Drld from 2790 '-3077'. Surv. POH & L/D DP. Open 12-1/4" hole to 17-1/2". Opening at 1398' at 0700 hrs. Opened 12-1/4" hole to 17-1/2" from 1398'-3075' with triP for new cutters at 2239'. Presently circ to clean hole at 3075' · Circ hole. POH. Replaced dra. wworks brake adjustment assembly. RIH w/HO. CBU. 5 std short trip. No fill. /8" CBU. POH & L/D 17-1/2" ~ools. R/U & run 13-3 surface csg @ 0700 hrs. . Fin running 13-3/8""csg to 3069'. Circ. Test cmt'ing .lines. Cmt'd w/1785 Sacks gel slurry followed w/580 sacks class "G" neat. CIP @ 2030 hrs. - 11/22/84. WOC & N/D 20" riser. N/D & P/U 20" riser. Cut off 13-3/8" csg. Move out 20" riser & BOPE. Good hard cmt in top of conductor. Chip out. Weld on 13-5/8" sOW head.. Test--OK. Begin N/U · . BOP. Completed N/D 13-5/8" BOP & lines. Pulled Out hydromatic brake--change out seals. Make' preparations to skid crown to center traveling block overhole. Change out & install new flex-hole choice line. . ~.~. Fin installing new choke line. Worked On choke ~& kill manifold valves. Tested BOP. Test witnessed by AOGCC. Presently finishing repairs & installing hydromatic brake. Fin hooking up hydromatic brake. BHA. RIH to FC @ 2980'. Tested csg to 2000 psi. Drld FC & hard cmt to 3063'. Circ. POH. Ran gyro from surface to 3050'. Moved tools to crown & attempted to move crown block West--unable to move' to West--need larger jacks. RIH. Drld shoe & 5' of hole. Ran leak-off test to 13.3 ppg. EMW. Drld to 3120'. Drld 3120'-3155'. POH. M/U locked BHA. RIH to csg shoe. Down 5 hfs w/DC power failure--burnt contactor. RIH & ream 3077'-3155'. Drld & surv 3155'-3492'. Well flowed on conn. SI well. SIDP - 500 psi & SICP - 200 psi. Circ at slow pump rate--had gas alarm. Circ w/well'on choke thru degasser. circ thru choke. Incr MW to 10.5 ppg. SI well. SIDP - 500 psi, SICP - 390 psi. Resumed curc & incr MW to 11.4 ppg by 0700 hrs. Circ thru choke. Incr MW 11.4 to 12.0 ppg. SIDP - 390 -psi & sIcP - 160 psi. circ & incr MW 12.0 to 13.0 ppg. SIDP - 170 psi & SICP - 40 psi. Open choke--well flowed 2" stream. Circ w/choke open--gained 8 bbl in 1/2 hr & cut MW 13.0 to 12.2 ppg. Circ thru choke & incr MW to · 13.3 ppg in & out. S/D pump & open choke--flowed 1" stream. SI well. SIDP - 80 psi & SICP - 20 psi. Resume circ. · Circ thru choke & incr MW from 13.3 to 13.5 ppg. S/D pump & open choke. Observe well. Well dead. Open annular--observe well. Well dead. Circ at 25 SPM w/annular open--some light spots in mud. S/D pump--observe well. Dead. Circ & add barite to light spots. MW out 13.3 ppg. Attempt to incr MW w/o success. S/D pump--well began flowing. Circ w/well on choke & brought MW to 13.5 ppg. Circ w/choke open--13.6 PPg in & 13.5+ out. ~gell History - Dolly Va~a-en No. D-43 Page 3 2-02 3492' TD 12-03 3492' TD 12-04 3492' TD 12-05 3492' TD 12-06 3492' TD 12-07 3492' TD 12-08 3492' TD 12-09 3492' TD 12-10 3492' TD 12-11 3492' TD Cont circ thru open choke w/13.7 ppg in & 13.6 ppg out. S/D pump. No flow. Opened annular--no flow. Closed ann & circ @ 25 SPM holding 40 psi (70 min) & 60 psi (50 min) on backside w/choke. Equiv of 14.1 ppg @ shoe. S/D pump--well dead. Open ann--well dead. Circ w/ann open beginning @ 25 SPM (4.6 BPM) & increasing to 43 SPM (7.9 BPM) over 12-1/2 hrs. S/D & check for flow occasionally--well dead w/13.7 ppg in & 13.6+ ppg out. Recovered clabbered mud. & formation out of hole. Down 1 hr to clean trash o~t'~of pump suctions. Well dead. .. · · . Fin cleaning trash out of pusp suction. Circ w/annular open w/13.7 ppg in & 13.6 ppg out. Worked stuck pipe w/max 300,000~. Torqued pipe. No movement. Moniter well-~dead. R/U WL & RIH w/free point indicator. HWDP stuck just under csg shoe @. 3069'. POH & R/D WL. Resume curc& got air-cut mud jout. Closed ann &circ thru choke.. MW out 12.3 to 12.8 ppg, Showed 50 bbl gain. Circ& got MW in & out back to 13.6 ppg S/D pumps. No flow. Open ann &circ w/13.7 ppg in & ~3.6 ppg out @ 0700 hrs. TOF @ 3030'. Circ & cond'mud to 13.8 ppg around. S/D pumps--well dead. R/U WL. RIH & made backoff @ 3030' WLM. Observewell 1/2' hr--dead. Circ--no light mud back. Observe well--dead. POH slowly. M/U fishing tools & RIH @ 07'00 hrs. TOF @ 3030' & length of fish 444'. TOF @ 3030' RIH w/fiShing tools· Break circ. Screw into fish @ 3'030'... CBU.. S/D pump--observe well,-dead. Jar on fish--no movement up or down. MW out cut 13.5 to 13.7 ppg--showed 12 bbl gain. Circ thru choke & Cond MW to 13.8 ppg in & out. Open annular--observe well--no' flow. Circ. TOF @ 3030' Circ & cond mud while mixing SFT spotting · fluid. MW in 13.8 & MW out 13.8 ppg. Spotted 55 bbl SFT in open hole around fish & left 20 bbl in DP. Observe well while, soaking fish in spotting fluid--well dead. TOF @ 3030'. Soaked fish in SFT pill for 24-1/2 hrs Jarred on fish w/240,000#--max pull 280,000#. Move ~FT pill 1 bbl every 1/2 hr. No movement w/fish. Stopped jarring @ 1900 hfs & let fish soak in SFT until 0700 hrs--12/07. TOF .@.3030' Jarred on fish w/240 M, max pull 310 M. . Moved SFT pill 1 bbl every 1/2 hour. No movement of fish. Ran FPI. .First tool jt below csg shoe stuck. Backed off @ 3030'. C&C mud. POH. MU WP & RIH. WO top of fish & washed to 3080'. .TOF @ 3030'. WO fish 3080-3232'. Milled staDilizer blades 3232-3234'. Dulled shoe. POH. Hole good condition. Chgd shoe & RIH. WO fish 3030-3265'. TOF @ 3235'. WO fish 3265-3322'. C&C. POH. MU fishing tools. RIH to 3030'. Screwed into fish. Attempted backoff @ 3297'--no good. Backed off @ 3235'. POH & LD fish (6 jt HWDP, jars, XO, stabilizer)· TOF @ 3032', RIH w/fishing tools & screwed into fish @ 3235' Jarred to 270 M, pulled 400 M, circ through fish. · Stuck )ars. Backed off @ '3032'. POH & LD tools. Tstd BOPE. RIH w/bumper jars & DC's. Screwed into fish & bumped jars loose. .Shot for backoff @ 3235'. well HistOry - Dolly Varden No. D-43 Page 4 12-12 3492' TD 12-13 3492' TD 12-14 3492' TD 12-15 3492' TD 12-16 3492' TD 12-17 3492' TD 12-18 3492' TD 12-19 3492' TD 12-20 3492' TD 12-21 3492' TD 12-22 3492' TD TOF 3233'. Backed off @ 3233'. POH & LD fish. MU WO shoe & 4 j t WP & RIH to 13-3/8"' shoe. Decreased 'MW to 12.9 pPg from 13.8 ppg. (Check effect of D-13 flow back on D-43) well flowed @ 12.9 ppg, dead @ 13.1 ppg. C&C mud. .. TOF 3233'. Checked well for flow w/13.1 ppg mud. Flowed 1/2 gpm. C&C mud to 13.3 PPgi'-' Well dead. Cond mud to 13.5 ppg & RIH to 3207' w/WP. Washed to TOF @ 3233'. Washed 3233-3237' where progress slowed. Washed to 3238' & POH to chk WO shoe. Shoe worn on btm of cutting structure only. Chgd to drag tooth WO shoe & RIH. WO DC's 3233-3272'. - · TOF 3235'. WO DC's 3272'-3333'. Milled stab blades to 3335'. Shoe quit. POH to csg shoe. Slipped & cut drlg line. RIH to 3208'. PU kelly & WO fish to 3333'. POH. Hole condition good. MU fishing tools & RIH. Tagged fish & attempted to screw in. POH. Recovered damaged screw-in sub. RIH w/WP. TOF 3029'. RIH w/WP to 32'08'. WO TOF @-3235' & washed to top of stab @ 3333'. WO stab to 3335" and DC's to 3351'. POH. RIH w/OS. Worked OS over fish & engaged. Fishing string stuck. Backed off fishing string in csg. @ 3029'. POH. RIH w/bumper jars to attempt to free fishing string. TOF 3'b30'. Jarred on stuck fishing string w/no success. Backed off @ 3030'. POH. PU WP & RIH. WO stUck DC's 3030'-3160' .:.-. ~: .... . ?? . WO stuck DC's '3160'-3233'. Circ & POH. MU fishihg . string & RIH to TOF @ 3030'. Screwed into fish & attempted to release OS. Could not release. Backed off above OS @ 3233' & POH. LD all fishing tools. RIH w/12-1/4" bit & csg scrpr to 3025'. POH w/bit & scrpr. Logged gamma ray 3000'-2200'. Tripped gage ring/JB. Set cmpltn pkr @ 2889' on DP. MU seal assbly & RIH w/DP. Tstd pkr. POH LD DP. Fin. L/D-DP. ~ P/U BOP & installed tbg spool. N/U BOP & tested. Broke out & L/D drlg equip. Began running 3-1/2" completion tbg. Fin running 3-1/2" completion tbg. Spaced out & stab pkr @ 2889'. Tested annulus--ok. Land tbg. N/D BOP. N/U tree & test. Pull BPV. R/U & test lub. RIH & pull' dummy ball valve. RIH w/tool ~o shift XA circ sleeve @ 2859'-- tool would not pass below sleeve. POH w./WL. Modified WL tool string. RIH w/WL & opened circ sleeve @ 2859'. Displ drlg mud from tbg w/FIW. RIH w/WL & closed circ sleeve. Ran SSSV & check oper--ok. Released rig #76 from Well D-43 at 2400 hrs - 12/20/84. At 0700 hrs the SITP on D-43 is 580 psi. Presently deactivating Rig 976. D-43 shut-in tubing pressure: 540# D-43 'Shut'in casing pressure: 0 TBU Well D-43 Continued (Marathon Oil AFE 8217-4) (11-06-84 through 12-22-84 of this 'report on Lanier) 1984 12-23-84 12-27-84 12-27-84 .. 12-28"84 12-28-84 12-31-84 .. 12-31-84 3492' TD ~ Started flowing @ 2300 12/26. Flowed water @ 55 gal/9minutes until 0145, 12/27. Slight black scum to begin with, not oil. Rate fell to 55 gal/45 minutes, 0~ TP. Shut-in @ 0230. Fluid was 10.9 ppg, clean (no oil)mud. Shu~-in pressure @ 0700, 50#. Total volume flowed= 25 bbls. H.ooking-up full 2" line to overboard thru a 55 gal drum. D-13 Total water bmckfl°wed 12/26 = 1097 bbls. FI? = 600,'FCP = 600. Two hour build-up 12/26: SITP = 680, SICP = 710. D-43 -.. Well would not flow 0230 to 2045 12/27. Tubing pressure built up to 580# and resumed flowing @ 2045. Total volume flowed 2045 12/27 to 0600 12/28: 93 bbls. F~p = 560# D-13 Total volume flowed 12/27:. 1097 bbls. FI? = 580, FCP= 610 SITP= 680, SICPTM 710. D-43 12/28/84 154 BWPD,. 580 F~P, 7.5% solids· 12/~9/84 220 BWPD,'595 F~P, 3.5% solids 12/30/84 ~ 270 BWPD, 550 FTP, 5.0% solids D-13 ~ 12/'28/84 115~ BWPD, 590 FTP:f685 SICP, 1 hour build-Up 12/29/84 1066 BWPD, 580 F~P 680 SICP, 1 hour build-up 12/30/84 1058 BWPD, 575 FTP, 670 SICP, 1 hour build-up D, 43 ' 1985 01-29-85 01-30-85 01-31-85 02-01-85 'partial rig crew onbomrd 0830 9/28/85 to ccmplete deactivation of Rig ~76. Following Rig #76 deactivation, Rig %77 will be activat- ed for D-3RD #2 workover. Finished cleaning Rig #76 mud tanks. Offloaded ~illing mud mat' 1. · Deactivation is approx 80% cc~plete. Completed deactivation of Rig ~76. Released rig crews to D-3RD ~2 workover @ 1200 hrs 01/31/85. !. 08-04-85 08-06-85 12-21-85 12-22-85 3492' TD Accepted Rig ~76 frcmD'30RDWO @ 1200 hrs on 12/20/85. Prepare piperack sections to offload onto Monark. Offload pipermck deck panels, cantilever, and piperack sections. Offload piperack sections & mud tanks to Monark. Skid Rig #76 from Leg B-1 to A-1. Return pipermck Sections & mud tanks to platform. Secure piperacks & install mud tank service lines. Well D-43 Well History Page 2 . 12-2~-85' 3492' TD 12-24-85 12-25-85 12-26-85 12-28-85 12-29-85 12-30-95 12-31-85 3336' Continued securing piperacks & mud tanks. Offload piperack ~eck panels & cantilever. Secured same. Hang BOP's in sub structure & continue RU. Finished moving & RU stabbing board. Installed rotary_ table. RU wireline equipment & lub. RU kill line to D-43 X-mas tree. Press test kill line to 2000 psi. Unsuccessfully attempt to bullhead FIW down tbg @ 1500 psi. RU Otis to pull BV. BV not cc~pletely open, took several attempts to latch & retrieve. RIH w/ sinker bar. Set down @ 2938'-WI/4. POH. RIH w/ "XA" sleeve shifting tool. Set down @ 2855' WI/4. Shifted sleeve & broke circ w/ FIW. Displaced oldmud w/ FIW. Mixed 800 bbls drlgmud. NU BOPE. Change seals on water spear in drawworks. Test BOPE & install wear bushing. MU rotary shoe & PRT tool. RIH to 1860'. C - ""--= ~ 1860' DPM. RIH to 2820'. Circ & condmud. Tag irc & cona muu ~ Baker KB pkr @ 2~89' - Mill pkr 2889'-2891'. POH. RIH w/ slick assembly to 2990 . Cleanout intermittent bridges to 3060'. Circ hole cle~n. Cleanout bridges to 3236'. Circ hole clean. POH. RIH w/ OEDP to 3225' to set cement plug. Circ & condmud for cement piug@ 3225'. RU cementers & test lines to 3000 psi. Pumped 50 bbls H.O ahead, 550 sks Class "G" w/ additives @ 16.2 ppg & 5 bbls H20 be~ind- POH 10 std & circ for cleanup. WOC. ,,30 jts DP. RIH to 1800'. Circ & condmud. Repair washout in. mud line. Circ & condmud @ 1800'. RIH to 2207'. Circ & con~ mud. RIH. Tag cement @ 2667'. Circ & condmud. Drld cmt frcm 2667'-3118'. CBU. POH,~: LD 13 jts 5" DP. '. O MU BHA w/ Teleco MWD. RIH. Orient bent sub & BHA 140 right of high side. Drld from 3118'-3255!. Survey. POH. MU locked BHA. RIH. Ream from 3069'-3254'. Drkd from 3254'-3336'. Surveys 3211' & 3215' not in agreement. POH w/ MWD. 1986 01-01-86 4043' 01-02-86 4600' 01_03-86 5039' 01-04-86 5531' 01-05-86 6268' 01-06-86 6533' POH. MUBHAw/'newMWD' RIH. Survey w/ new M~D @ 3215' MD, still have interference. POH to csg shoe & ~4D gyro. RIH. Wash from 3308'-3326'. Survey w/ gyro. Drld from 3336'-3393'. Survey w/ gyro. Drld from 3393'-3457'. RIH w/ gyro, tool stopped @ jars, no survey. Drld & surveyed w/ bSqD from 3457'-4043 Drld & surveyed frcm 4043'-4322'. POH. Reamed tight area from 3535'-3442'. Continue POH. Change BHA. RIH. Set down @ 1778'. POH. Check BHA, OK. Rotate very_ slowly thru section from 1770'-1790'. Set down =~h time @ 1778'. Suspect configuration of BHA. Continue RIH. ~~ & w-ash from 3520'-3650'. Continue RIH. Drld from 4322'-4600'. Drld & surveyed w/ ~D frcm 4600'-5039'. Circ & drop single shot survey. POH. Hole tight frcmTD to csg shoe. ID 20 jts "G" DP. Test B OPE. MU new BHA & RIH. Set down @ 3496'. Work thru tight spot. Wash 60! to bottcm. ~ - , Drld & surveyed from 5039'-5498'. POH. MU bit #11. RIH. Wash 60'.to b0ttc~. Drld from 5498'-5531'. Drld from 5531'-5652'. Surveyed. Drld & surveyed from 5652'-6268'. POH. LD 30 jts "G" DP MU bit #12. PU 30 jts "E" DP. RIH. Ream 38' to bottom. Drld frcm 6268'-6515'. Drop survey & ID 27 jts "G" DP. Hole in good sha.pe. MU bit ~13. PU 27 its "E" DP. RIH. Ream 40' to bottom. Drld frcm 6515'-6533'. Well 'D-43 Well History Page 3 . 01-0'7-86 6924 ' 01-08-86 7254 ' 01-09-86 7566' 01-10-86 7811' 01-11-86 8036' · . 01-12-86 8212' 01-13-86 8286' 01-14-86 '' ' 8431' 01-15-86 8431' 01-16-86 8533' 01-17-86 8756' 01-18-86 9019' · 01-19-86 9075' 01-20-86 9165' 01-21-86 9352' 01-22-86 9500' Drld & surveyed frown 6533'-6901'. Circ. POH, hole OK. PU 'lead collar & MU bit #14. RIH. Ream 40' to bottcm. Drld from 6901'-6924'. Drld & surveyed from 6924'-7186'. POH. Change out 2 pins in rotary_ beam. MU bit #15 & PU 1 stab. RIH to 7141'. Ream from 7141' to 7186'. Drld frcm 7186'-7254'. Drld & surveyed frcm 7254'-7545'. Circ & POH. MU bit #16. RIH to 7485'. Ream frcm 7485'r7545'.' Drld from 7545'-7566'. Drld & surveyed frcm 7566'~7811'. Circ & POH. MU bit #17 & PU 6 jts HWDP. Slip 45' drlg line. RIH. R ~___ ~c~, 7811'. Drld & surveyed frcm 7811'-8010'. POH. eam iraqi ~,u~ - - ..... ' RIH REam Change out jars & 2 stab. -MU blt ~1~. Test BOPE. · frown 7975'-8010'. Drld frc~n 8010'-8036'. Drld from 8036'-8059'. Repair mud pumps. Drld frcin 8059'-8203' & surveyed. CBU. POH. MU~TDw/ mud motor & 1-1/20 bent sub. RIH. orient tool face 100° to left of high side. Drilled frown 8203'-8212'. Orient & drld w/ mud motor from 8212'-8286'. POH. MU bit 920. RIH to csg shoe. Slip & cut drlg line. Finish RIH. Hit bridge @ 8120'. Wash frcm 8120'-8286'. Orient mudmotor 80° to left of highside. Orient mudmotor"&'~drld .from 8286'-8431'. POH. MU bit 921 on mud motor. RIH to 8370'. 'Unsuccessfully attempt to circulate and unplug bit. POH. ~ POH w/ mud motor & MhTD. Found n4udmotor would not turn. PU locked BHA & bit ~21RR. RIH to 8203'. Reamed frcm 8203'-8307'. DP became stuck while reaming @ 8307'. Had full returns. Worked & jarred on DP w/ no movement. Spotted 2 bbls drlg det across BHA. Worked pipe, no movement. Pipe came free when began circ. Finished reaming motor run from 8307'-8406'. C&C hole. POH. MU bit #21RR2 on mud motor. RIH. RIHf w/ mud motor to 8400'. Washed to 8431'. Orient motor w/ M~D. Drld frcm 8431'-8533'. Circ. POH. ID mudmotor & Mh~D. MU bit ~22 on BHA. RIH to 8406'. Reamed frc~'8406'-8533'. Drld frc~n 8533'-8593'. Circ &~dropped survey. POH. Did not get survey. PU locked BHAw/ ~4I) & bit 923. RIH to 8530'. Cut & slip drlg line. Wash & ream from 8530'-8593'. Drld & surveyed from 8593'-8756'. Drld frc~n 8756'-8802'. Circ & surveyed w/ MWD.. POH. MU bit 924 on locked uP HBA. RIH to 8732'. Washed & reamed to bottcm. Drld & surveyed frcm 8802'-9019'. Drld from 9019'-9038'. Circ & cond hole. Drld from'9038'-9065'. Circ & work pipe prior to trip. Had cc~plete DC power failure. Got 1 traction motor on line. POH. Repair DC cable to traction motor. Tst B OPE. MU bit 925 on mudmotor. RIH to shoe. Slip 45' of drlg line & function tstMWD. Orient mudmotor & drld frc~. 9065'-9075'. Drld from 9075'~9165' w/ mud motor. POH. First 5 stds tight. If mud motor, foUnd problem w/ motor bearing seals. MU bit ~26 on drlg BHA. RIH w/ bit 926. Broke circ'@ 7000'. Set down @ ~816'. Reamed from 8816'-8878'. RIH 2 stds. Reamed 9004'-9165 · Drld & surveyed from 9165'-9352'. CBU & work pipe. POH. Finished POH. MU bit 927. RIH to shoe. Cut & slip drlg line. Finished RIH. Drld & surveyed frcm 9352'-9498'. C&C hole for Well D-43 We. ll History Page 4 01-23-86 9654' 01-24-86 9786' 01-25-86 9786' 01-26-86 9786' 01-27-86 9845' . · , 01-28-86 9845' " 01-29-86 9845' trip. POH, Hole in good shape. MU bit ~28. P~H. Wash 37' to bottcm. Drlg @ 9500'. Drld from 9500'-9633'. Surveyed w/ MWD. C&C hole for trip. Dropped single shot survey. POH to shoe. Hole tight 8374'-8250'. Switched DC pow~.r to Rig #77 to position blocks for WLwork. Switch power back to Rig #76. POH. MU bit #29 & PU stab. RIH. Wash & ream 9569'-9633'. Drld frcm 9633'-9654'. Drld from 9654'-9685'. Circ & su~ey w/ ~WD. POH. MU bit #30. RIH to 9560'. Wash &'ream~rom 9650'-9685'. Drld from 9685'-9786'. Circ & cond hole for logs. Short trip. Hole OK. Circ for logs. POH. RU loggers. RIH to 3700' w/ DIL-GR. Logging unit not operational on surface. Log 500' below 13-3/8" csg shoe. Send tape to town for film develop- ment. RD loggers. MU bit. RIH. Hole OK. Circ & cond. Fin circ. POH. RU loggers· RIH w/ C=q~DIL. Log 9786'-3853'. Tool stuck. ~ fishing tools. MU overshot. RIH. Slip DP over WL. Fish pulled free. POH w/ DP stripping out over WL. Finish stripping over wireline and retrieved fish. RIH and drill 9786'-9845'. C&C..f0r 9-5/8" casing. Begin POH. Finish POH and LD BHA. RU and run 233 jts 9-5/8" casing to 9839'. RU cementers and begin cementing. I Pumped total of 3990 sks Class "~" w/ additiVes. CIP @ 0920 on 1/28/86. Cut off 9-5/8" csg. NU tbg spool, tstd to 3000 psi, OK. 5~ & tstd BOPE. 01-30-86 9852' 01-31-86 10,072' 02-01-86 10,425' 02-02-86 10,482' 02-03-86 10,522' Change out drlg line. PU DC's & MU RRbit. RIH. Tag cement top @ 9748'. Drld hard cement & float equip to 9840'. Drld to 9852'. CBU. Ran formation integrity test to 12 ppg EFS{. POH. ~ bit #32 on new BHA. RIH to 9852'. Drld frcm 9852'-10,023'. Circ & drop survey. POH. MU bit ~33. PU ~SD/GR. RIH. Drld frcm 10,023'-10,072'. Drld & surveyed frcm 10,072'-10,414'. Short trip to 9-5/8" csg shoe, hole OK. Drld from 10,414'-10,425'. Drld from 10,425'-10,459'. CBU. POH. MU BHA for core #1. RIH to i0,429'. Reamed frcm 10,429'-10,459'. Core #1 from ' 10,459'-10,482'. Core bbl janmed. Circ. POH. POH w/ core ~f~"- -LD' fiberglass inner bbl. & from same in dry ice. MU bit #35 on drlg BHA. Reamed 10,452'-10,482'. Drld 10,482'-10,519'. CBU. POH. PU core bbl for core #2. RIH. Wash 10' to bottom. Cored 10,519'-10,522'. 02-04-86 10,563 ' Cored from 10,522'-10,549'. POH w/ core #2, 100% recovery. Core #1 frozen & cut into 3' sections for shi~znent to lab,' Service bbl & RIH for core #3. Cored from 10,549'-10,563'. Core bbl jan~. POH. Hole OK. ID inner bbl. Recovered 13.2' of 14' cut. Service core bbl. 02-05-86 10,661' 02-06-86 10,712' Finish RIH for Core #4. Reamed 5' to bottcm. Cored frc~ 10,563'-10,593'. Circ & POH. ID inner bbl. Recovered 100% of core cut.- MU bit #36 on drlg BHA. RIH. Reamed 10,505'-10,593'. Drld from 10,593'-10,661'. EOP constant @ 2 min/fit. CBU. Mostly sand across shakers. POH. Finish POH w/ bit #36. PU coring BHA. RIH for core #5. Reamed 5' to bottom. Cored from 10,661'-10,674'. Core bbl jan~.d POH. Hole in good shape. LD fiberglass inner bbl. Cut 13' of core, recovered 12'. MU bit #37. RIH. Reamed frcm 10,629'-10,674'. Drld frcm 10,674'-10,712'. CBU. POH. Well D-43 Well History Page 5. 02-67-86 10,725' 02-08-86 10,750' 02-09-86 10,770' 02-10-86 10,803' 02-11-86 11,067' 02-12-86' 11,145 02-13-86 11,197' Finished POH w/ bit #37. RIH w/ core bbl for core #6. Ream 5' to bottcm. Circ & drop ball. Cored frc~ 10,712'-10,725'. Core bbl jan~. POH. Hole in good condition. LD fiberglass inner bbl. Cut 13' of core w/ 100% recovery. Core bbl janmed w conglcmerate which came loose frcmmatrix. Service core bbl & PU new core~ead. RIH for core #7. Circ & reamed 12' to bottcm. Cored from 10,725'-10,750'. Core bbl janxned. Attempted to pull off bottom, pipe stuck. Jarred to free pipe. Worked pipe, hole OK. POH. Hole in good condition. ID fiberglass inner bbl. Unconsolidated conglomerate in core catcher. Cut 25' of core, recovered 20.2'. Made clean@ut trip. Wash 5' fill on bottc~n. CBU. CBU. POH. Hole in goodcondition. PU coring BHA. RIH for core #8. Circ & ream 10' to bottom. Cored from 10,750'-10,766'. Core bbl janm~d. POH. LD core #8~ Cut 16' of core w/ 100% recovery.. Loose, sandy conglcmerate in corehead. Service core bbl. RIH for core #9. Wash & ream 5' to bottcm. Cored 10,766'-10,770'. Cored from 10,770'-10,782', Core bbl-janm~d. POH w/ core #9. Hole tight @ 10,750'. 'Remaining hole in good condition. LD fiberglass inner bbl. CUt 16'~ of core & recovered 13.1'.~ Service core bbl. RIH for'core.-#10.. Cored frcm 10,782'.10,803', bbl janvned. Pulled 85,000# over @ 10,788'. Worked pipe. POH. Finished P OH.' LD core #10. Recovered 18.7' of 21' cut. LD core bbl. MU bit #36 RRon drlg BHA.~ RIH. Washed & reamed from 10,721'-10,803'. Drld from 10,803'-10,890'. Surveyed on Drld frc~n 10,890'-11,067'. Drld frcm 11,067'-11,071'. 'CBU. Dropped. survey. POH. Hole tight @ bit 10,689' & top stab @ 10,391'. Became'stuckwhile attempting to work thru tight spot. PU kelly & WOrked pipe free. Jars did not workwhile stuck. POH. MU bit #39 & changed out 'jars. RXH to 10,408'. Reamed 10,408'-10,603'. RIH to 10,689', Hit ledge & worked past. Hard reaming from 11,001'-11,071'. Drld from 11,145'-11,197' Circ & cond hole. POH. Hole in good condition. RU loggers. ~gging run #1,-NGT/CNT/LDT/DIL, from 11,196'-9590'. POH. Logging run #2, SDT (array sonic), from 11,190'-9790'. POH. MU bit & BHA for wiper trip. RIH. 02-14-86 11,250' 02-15-86 " Finish RIH to 11,162'. PU kelly. Wash & ream to 11,197'. CBU. POH hole tight @ 11,100' & 10,400'. RUWL. RIH w/ RfT/GR. Could not work tool below 10,380'. POH. RD WL. RIH w/ 8-1/2" bit on drlg BHA to 11,137'. Reamed from 11,137'-11,197'. Drld frcm 11,197'-11,250'. CBU. POH, SLM. POH~ RU csg crew. RIH w/ 7", 29# N-80 on 5" DP. CBU @ 9-5/8" csg shoo. P_IH to 11,250'. Circ & condmud ,&ile reciprocating liner. RU cementers & tested lines to 4000 psi. Pumped 20 bbls H~0 ahead. Mixed & pumped 30 bbls mud f~u~h @ 12 ppg. Pumped 20 bSls H20. l~_xed'&'purap~ 700 sks Class G w/ additives. Pumpod 20 bbls H20 behind. Bumped plug to 2800 psi, hanger 'set. CIP @ 0135 hrs. on 2/15/86. POH 10 stds & rev circ to clean DP. 02-16-86 " POH. LD liner setting tools. LD HWDP & 20 jts "E" DP. Tested BOPE. RIH w/ bit. T~gged TOC @ 9116'. Drld firm cement frcm 9116'-9327' . 02-17-86 " Drld cmt from 9327'-9551'. Circ hole clean. POH. MU bit & 9-5/8", 47# csg scraper. RIH to TOL @ 9551'. Made 2 passes frcm 8800' to TOL. CBU. POH. MU DST tools. RIH. Filled DP w/ 4000' of fresh water. Set pkr @ 9490'. Open tool for 1 hr. Had light blow for 5 min. Closed tool for 2 hr shut in. 02-18-86 " Finished shut in for dry test. Unseat pkr. POH. Found fluid level in DP had risen 5'. Rev circ DP. Finished POH Gauges showed 570 psi pressure buildup when tool shut in. ~ RR$6 bit on 9, 4-3/4" DC's. PU 3-1/2" DP & RIH. RIH to TOL @ 9551'. Drld cement 9551'-9582'. RIH to 11,080'. Drld c~ent frcm 11,080' to Well D-43 Well History Page 6 02-19-86 11,250 ' 02-20-86 02-21-86..-" .. 02-22-86 02-23-86 02-24-86 02-25-86 02-26-86 02-27-86 02-28-86 03-01-86 03-02-86 03-03-86 03-04-86 landing clr @ 11,166'. Circ hole clean. POH. RU loggers. Run . l CET/GR/CCL frcm 11,164'-9530' POH. MU 6" bit & 7" 29# cSg scraper. RIH. RIH w/'6" bit & 7", 29# csg scraper t© 11,166'. Circ hole clean.- Press test csg' to 2500 psi·, OK.' Leaned pits & changed hole over to FIW. MLxed & spotted 100 bbl pill of 3% KCL in FIW across Hemlock. POH w/ bit & scraper. RUWL. Run gyro survey from 11,150' to surface. LD gyro tool. PU gauge ring.& junk basket. RIH. Unsuccessfully attempted t6 work gauge·ring/Junk basket into liner. POH. Gauging marked as it setting on liner top. PU pkr. RIH on WL. Worked pkr 5' into liner where set down. POH. PU·6'' bit & 7" 29# scraper. RIH. Cleanout liner top. Rev circ hole clean. POH. RUWL. RIH w/ pkr, no problems. Top of pkr set @ 9840' DIL. POH. LD 6-1/4 & 4-3/4 DC's.. MU test seal assembly on DP. Tested pkr to 3000 psi, OK. POH & LD DP..Changed piperams to 3-1/2". RU to run tbg w/ sidestring chemical-inj ..line. MU downhole chemical injection equi~nent on 3-]./2" tbg. Tested sidestring connections to.5000 psi. Total of 118 jts 3-1/2'~, 9.2#, N-80 BTC tbg run W/ six. GLM's & sidestring inj line. / Ran total of 300 its 3-1/2" 9.2# N-80 butt w/ AB mOd cplgs & sidestring chemical injection line. Located pkr, tested seals & sheared out of PBR. Connected & tested control line & chemical injection line. Set BPV. ND BOPE & NUX-mas tree. Finished NU X-mas tree. Turned well over to production. NU flowline & gas lift line. Tested chemical inj line. Unload well to separator w/ 750 MCFD. Produced 319 BFIW & shut in well. RU perforators. Test lub to 2000 psi. RIH w/ 2-5/8" guns lo~dedw/ 4 SPF @ 0° phasing. Gun run #1 located from 10,658'-10,690' DIL. POH. Fin perf B-3 10,604'-10,690". Flow test well. Avg rate 588 BFPD, 3% WC, 570 BOPD, TP 110#, CP' 1036#. Cum prods= 801 bbls. Load vol = 704 bbls. Well still stabilizing. Ave rate last 6 hrs = 528 BFPD, .8% WC, 524 BOPD, GOR = 300, lift gas = 1627 MCFD. Ave rate: 539 BFPD, 535 BOPD, 0-8% WC, lift gas = 1690 ~,~FD, TP = 150 psi, CP = 1020 psi. Released rig to D-24Aworkover @ 1800 hrs on 2/25/86. Continued flow testing well. 24 hr ave: 542 BFPD, 539 BOPD,. 0.6% ~'~, lift gas = 1865 MCFD, TP = 150 psi, CP = 1110 psi, GOR = 300. 24 hr ave: 541 BFPD, 539 BOPD, 0.3% WC, lift gas = 1801 MCFD, TP ~ 120 psi, CP = 1050 psi, GOR·= 243. 24 hr ave: 526 BFPD, 525 BOPD, 0.1% WC, lift'gas = 1833 MCFD, TP = 120 psi, CP = 1050 psi, GOR = 126. . 24 hr ave: 512 BFPD, 511 BOPD, 0.1% ~E, lift gas = 1833 MCFD, .... TP = 120 psi, CP = 1050 psi, GOR = 129. 24 hr ave: .501 BFPD, 500 BOPD, 0.1% WC, lift gas = 1833 MCFD, TP = 120 psi, CP = 1050 psi, GOR = 198. 24 hr ave: 490 BOPD, 0% WC, lift gas 1865 MCFD, TP = 170 psi, CP = 1100 psi, GOR = 122. FINAL REPORT. STATE OF ALASKA ALAS~.~, OIL AND GAS CONSERVATION COIV,_..~$SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Alter Casing [] Other [] 2. Name of Opera,pr UNOCAL Operation shutdown [] Stimulate ~ Plugging [] Perforate ~ Pull tubing [] 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-l, Cond. #9 Dolly Varden Platforz 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive interval 443' FNL, 1,002' FWL, Sec. 6-8N-13W-SM At effective depth 121' FNL, 1,150' FWL, Sec. 6-8N-13W-SM At total depth 86' FNL, 1,170' FWL, Sec. 6-8N-13W-SM 11. Present well condition summary Total depth' measured true vertical 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-43RD 8. Approval number 7-407 9. APl number 50-- 733-20373 10. Pool Hemlock 11,250' feet Plugs(measured) 11,166' - 11,250' CMT 10,083 ' feet Feet Effective depth: measured 11,166 ' feet true vertical 10,009' feet Casing Length Structural Conductor Surface 3,069 ' Intermediate 9,839 ' Production Liner 1,699 ' Perforation depth: measured Junk (measured) None Size Cemented Measured depth True Vertical depth 7" 700 sx 11,250' 10,083' MD 9,404' - 9,4~' Bench i 10,464' - 10,492' MD 9,522' - true vertical Bench 3 10,604' - 10,696' Tubing (size, grade and measured depth) 3 1/2", 9.2#, N-80 @ 9,914' SE Packers and S,,~SV (t~pe and measured dep, th) Baker FA-1 packer @ 9,840 DIL, Camco TRDP-1A SSSV @ 293' Stimulation or cement squeeze summary See Attachment #1 Daily Report of Well Ope:q~l~l'~'r~l~ 12. Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data A. ch0rage Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7/24/87 128 149 Subsequent to operation 8/18/87 863 359 2 1110 psi 160 psi 75 1090 psi 110 psi 14. Attachment.~ #1 Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowle~.~ ~ * Ma~rathon 0il Company - Sub Operator ~ ~~f~ Signed Roy~ ,.~'. ~,obe~ts Title Environt'~ntal Engineer Date 9,,/1/87 Form 10-404 Rev. 12-1-85 Submit in Duplicate 13 3/8" 2,945 sx 3,069' 2,907' 9 5/8" 3,990 sx 9,839' 8,875' Attachment #1 Daily Report of Well Operations Well D-43RD 7~29~87 RU wireline unit. Make up 32' of 2-5/8", 4 SPF, 0° phasing perf guns. RIH, correlate, bleed tubing pressure from 900 psi to 585 psi, and perforate Bench 3 from 10,664' - 10,696'. POOH, shut down and secure well. 7130187 Make up 32' of 2-5/8", 4 SPF, 0° phasing perf guns. RIH, correlate , bleed tubing pressure from 700 psi to 320 psi and perforate Bench 3 from 10,636' - 10,668' and POOH. Make up 32' of perf guns as before. RIH, correlate, bleed tubing pressure from 400 psi to 120 psi and perforate Bench 3 from 10,604' - 10,636'. POOH and RD. RU service company, take on FIW and begin mixing clay stabilization chemi- cals. 7/31/87 Complete mixing chemicals. Began pumping at an initial rate of 1BPM until tbg filled. Rate decreased to 1/8 BPM @ 3000 psi over 22 min. Increased rate to 1/3 BPM @ 3200 psi. Rate decreased to 1/6 BPM @ 3150 psi over 50 min. Shut down. Shut well in, secure operations. 8~3~87 RU CTU and make up CT injector head. Open well and RIH w/CT. Pump 15 bbls displacement fluid followed by 7-1/2% HC1 plus additives. Displaced acid into perforations with clay-stabilization treatment. Acid pumped was 1500 gal 7-1/2% HCl followed by 3000 gal mud acid plus additives. Over displaced acid w/20 bbls clay-stabilization material. POOH w/CT. RD CTU and acid tanks. RU lines and ammonium chloride tanks. Pump remaining clay-stabilization material, 70 bbls and ammonium chloride overflush treatment, 240 bbls @ 1-1/2 BPM, 1500 psi. 8~4~87 Finished pumping ammonium chloride overflush. Mixed 10 sacks ammonium nitrate w/last 100 bbls of overflush. POOH and secure well. RD, put well back on production. NEF/em/31B/Sundr2 STATE OF ALASKA ALA-~-.,A OIL AND GAS CONSERVATION CO,~.~iISSION APPLICATION FOR SUNDRY APPROVALS feet 1. 'Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate:E] Other [] 2. Name of Oper~.tor UNOCAl, 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg A-l, Cond. ¢f9 Dolly Varden Platform 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive interval 443' FNL, 1,002' FWL, Sec. 6-8N-13W-SM At effective depth 121' FNL, 1,150' FWL, Sec. 6-8N-13W-SM At total depth 86' FNL, 1,170' FWL, Sec. 6-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-43RD 8. Permit number 85-311 9. APl number 50-- 733-20373 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface 3,069' Intermediate 9,839 ' Production Liner 1,699' Perforation depth: measured 11,250' feet Plugs (measured) 10,083 ' feet 11,166 ' feet Junk (measured) 10,009 ' feet 11,166' - 11,250' CMT None Length Size Cemented Measured depth 13 3/8" 2,945 sx 3,069' 9 5/8" 3,990 sx 9,839' 7" 700 sx 11,250' True Vertical depth 2,907' 8,875' 10,083' Bench 1 10,464' - 10,492' MD 9,404' - 9,427' TVD true vertical Bench 3 10,604' - 10,690' MD 9,522' - 9,596' TVD ~bing(size, grade and measured depth) 3 1/2", 9.2#, N-80 @ 9,914' Packers and SSSV(type and measured depth) Baker "FA-l" packer @ 9,840' DIL, Camco TRDP-1A SSSV @ 293' 12.Attachment~¢/1 Description summary of proposal [] Detailed operations program :~ BOP sketch [] 13. Estimated date for commencing operation June 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge , / ,' ; , ,~ - .- Title Environmental Engineer Sign ~oy U, ~ob~rts Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI NO, Date6/19/87 * Marathon Oil Company - Sub Operator Approved by [J¥ ~-~;~.:~[ g, ~'~:~,~ Form 10-403 Rev 12-1~5 ...... E ..... - ......................... by order of Commissioner the commission Date Submit in triplicate Attachment #1 Well D-43RD Procedure Perforation and Clay Stabilization Treatment 1. Rig up E-line and perforate Bench 3 (10,604' - 10,696' DIL) with 2-5/8" guns, 4 spf, 180° phasing with a 500 psi underbalance. 2. Do not flow well during perforating job. Allow wellhead pressure to stabilize and rig down E-line. 3. Rig up Halliburton pumping equipment to D-43RD tree. 4. Pressure test surface equipment to 5,000 psi and pump treatment as follows: Stage 1 - 7500 gallons - 2% Clayfix, 0.6% FDP-W396 Clay Stabilizer, 0.1% Losurf 300 surfactant mixed with FIW. Stage 2 - 10,000 gallons - 2% Clayfix, 0.1% Losurf 300 surfactant mixed with FIW. Treatment to be pumped at 3 BPM, if possible. Surface pressure will be controlled so facture gradient is not exceeded. 5. Rig down Halliburton. 6. Bring well back on production slowly. Test well until further notice. *Actual stage volumes may vary slightly. WLB/em/31/Sundr2 STATE OF ALASKA ALA~. ~, OIL AND GAS CONSERVATION COIV. .,SSION REPORT OF SUNDRY WELL OPERATIONS JAN j 9 ]987 1. Operations performed: Operation shutdown [] Stimulate [] Plugging ~ Perforate ,~ Pull t~In~7.._ LOCKWO( Alter Casing [] Other [] 2. Name of Opera.~or UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-l, Cond. #9 Dolly Varden Platfor~ 754' FSL, 1,207' FWL, Sec.-6-8N-13W-SM At top of productive interval 443' FNL, 1,002' FATL, Sec. 6-8N-13W-SM At effective depth 121' FNL, 1,150' FWL, Sec. 6-8N-13W-SM At total depth 86' FNL, 1,170' FWL, Sec. 6-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Tr~H'in¢~ B~qv T,~nir. 7. Well number D-4 3RD 8. Approval number 645 9. APl number 50- - 733-20373 10. Pool Hemlock Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 3,069 ' Intermediate 9,839 ' Production Liner 1,699' Perforation depth: measured 11,250 ' feet Plugs (measured) 10,083 ' feet 11,166 ' feet Junk (measured) 10,009' feet Size Cemented 13 3/8" 9 5/8" 11,166' - 11,250' CMT None Measured depth 2,945 sx 3,990 sx 3,069' 9,839' True Vertical depth 7" 700 sx 11,250' Bench 1 true vertical Bench 3 2,907' 8,875' 10,083' 10,464' - 10,492' MD 10,604' - 10,690' b~ 9,404' - 9,427' TVD 9,522' - 9,596' TVD ~bing(size, grade and measured depth) 3 1/2". 9 2#, N-80 @ 9,914' Packers and SSS~(type and measured depth) Baker "FA-i" packer @ 9,840' DIL, Camco TRDP-1A SSSV @ 293' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data 12/31/86 1/7/87 OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 45 15 1 880 857 376 0 900 Tubing Pressure 2OO 160 14. Attachment~: #1 Daily Report of Well Operations Copies of Logs and Surveys Run FI 15. I hereby certify that the foregoing is true and correct to the best of my knowledge *Mar. a2tho~.~O~ ~omp_~any - Sub-Operator S,-ned ~,~/r/''/' ¢'~~ 'u ~oyO~D. Roberts Title Environmental Engineer Form 10-404 Rev. 12-1-85 )D Date 1/19/87 Submit in Duplicate Attachment #1 Daily Report of Well Operations Well D-43RD 1/03/87 1. RU E-line. 2. SI tubing & lift gas. 3. PT lubricator to 2,500 psi - OK. 4. Bleed tubing pressure from 900 psi to 410 psi. 5. Perf B-3 from 10,658' to 10,687' using 2-5/8" Titans, 4 SPF, 0° phasing (bottom 3' of gun did not fire). 1/04/87 1. PT lubricator to 2,500 psi - OK. 2. Bleed tubing pressure from 675 psi to 175 psi. 3. Perf B-3 from 10,630' to 10,662' as above (all shots fired). 4. Pressure test lubricator to 2,500 psi - OK. 5. Flow well for 45 min. w/gas lift on. 6. Perf B-3 from 10,604' to 10,630' using same gun w/well flowing (all but 4 shots fired). 7. 12 hour test - 1000 BOPD. 8. Suspend further perforating. 9. RD E-line. 10. Put well on production. MRO/em/31B/Sundr2 STATE OF ALASKA ALAS .... OIL AND GAS CONSERVATION COM,,, .,5SION - REPORT OF SUNDRY WELL ?PERATION £c ........... .t 5 1986 '~,,~ 1. O'~erations performed: Op"--erati-----~n s--'~ut~ow--~-'~--~ti--~ulat-----~ ~ PI-Tugging - Perforate ~ Pu~t, ut~.g ~OCKWO0]~ Alter Casing [] Other [] 2. Name of Oper~or 5. Datum elevation (DF or KB) ~ UNOCAL 106' KB above MSL Feet 3. Address -~. ~ ~rr ~ ~ P.O. Box 190247 Anchorage, AK 99519 4. LocationofwellatsurfaceLeg A-l, Cond. #9 Dolly Varden Platfo~ 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM Attop ofproductiveinterval 443' FNL, 1,002' FWL, Sec. 6-8N-13W-SM Ateffective depth 121' FNL, 1,150' FWL, Sec. 6-8N-13W-SM Attotaldepth 86' FNL, 1,170' FWL, Sec. 6-8N-13W-SM Trading Bay Unit 7. Wellnumber D-43RD 8. Approval number 9. APl number 50-- 733-20373 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 3,069' Intermediate 9,839 ' Production Liner 1,699' Perforation depth: measured 11,250' feet Plugs (measured) 10,083 ' feet 11,166' feet Junk (measured) 10,009 ' feet Size Cemented 13 3/8" 9 5/8" 11,166' - 11,250' CMT None Measured depth 2,945 sx 3,990 sx 3,069' 9,839' True Vertical depth 7" 700 sx 11,250' Bench 1 true vertical Bench 3 2,907' 8,875' 10,083' 10,464' - 10,492' MD 10,604' - 10,690' MD 9,404' - 9,427' TVD 9,522' - 9,596' TVD Tubing (size, grade and measured depth) 3 1/2", 9.2#, N-80 @ 9,914' Packers and SSSV (type and measured depth) Baker "FA-l" packer @ 9,840' DIL, Camco TRDP-1A SSSV @ 293' RECEIVED 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 5L'C I ? 1986 Alaska Oil & Gas Cot6, uommission Anchorage 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 4/15/86 269 38 1 1030 psig Subsequent to operation 4/24/86 261 100 1 1000 psig ~bing Pressure 130 psig 175 psig 14. Attachments: #1 Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed * Marathon,, Oil Company - Sub Operator O. KoDem;s Title Environmental Enqineer Form 10-404 Rev. 12-1-85 Date 12~5/86 Submit in Duplicate 4/17/86 1. Attachment #1 Daily Report of Well Operations Well D-43RD RU wireline unit. 2. RIH w 2 5/8" perforating guns w/0° phasing. 3. Perforated w/4 SPF as follows: Bench 1 10,464' - 10,492' 4. POH w/perf guns. 5. Return well to production. MDC/em/31A/Sundr2 , ~-' STATE OF ALASKA -~ ~ ALAS. , OIL AND GAS CONSERVATION COM .... SSION DEC ! .5 ]986 -' APPLICATION FOR SUNDRY APPROVALS. w. oc woop 1. Type of Request: Abandon [] Suspend ~ Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other ~ ___] 2. Name of Operator 5. Datum ~ o--"~ UNOCAL 106' KB above MSL feet,~t~ 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg A-l, Cond. #9 Dolly Varden Platform 754' FSL, 1,207' FWL, Sec. 6-8N-13W-SM At top of productive interval 443' FNL, 1,002' FWL, Sec. 6-8N-13W-SM At effective depth 121' FNL, 1,150' FWL, Sec. 6-8N-13W-SM At total depth 86' FNL, 1,170' FWL, Sec. 6-8N-13W-SM 11. Present well condition summary Total depth: measured true vertical 11,250' feet Plugs (measured) 10,083 ' feet 6. Unit or Property name Trading Bay Unit 7. Well number D-43RD 8. Permit number 85-311 9. APl number 50-- 733-20373 10. Pool ' Hemlock 11,166' - 11,250' CMT Effective depth: measured 11,166 ' true vertical 10,009' feet Junk (measured) feet None Casing Length Structural Conductor Surface 3,069' Intermediate 9,839 ' Production Liner 1,699' Perforation depth: measured Size Cemented Measured depth 13 3/8" 2,945 sx 3,069' 9 5/8" 3,990 sx 9,839' 7" 700 sx 11,250' Bench 1 10,464' - 10,492' MD true vertical Bench 3 10,604' - 10,690' MD ~bing(size, grade and measured depth) 3 1/2", 9.2#, N-80 @ 9,914' Packers and SSSV(type and measured depth) Baker "FA-I" packer @ 9,840' DIL, Camco TRDP-1A SSSV @ 293' True Vertical depth 2,907' 8,875' 10,083' 9,404' - 9,427' TVD 12.Attachment~ #1 Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation December 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~)~,~.¢~' ~<!~>L ~.~..-f~ Title Environmental Enqineer 'R'~' D. Roberts Date 12/15/86 Commission Use Only Conditions of approval * Marathon Oil Company - Sub Operator Approved by ~;¢ Form 10-403 Rev 12-1-85 Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner [ Approval No. ~ the commission Date Submit in triplicate Attachment #1 Well D-4 3RD PERFORATION PROCEDURE 1. Test well for 24 hrs. 2. Skid rig 77 over Well D-43RD. 3. Rig up E-line with 2-5/8" guns, 4 SPF, 0° phasing, 11 gm charges. 4. Pressure test lubricator to 2,500 psi. 5. Perforate and test as shown in table below. (Perforate with 500 psi - 800 psi underbalance) Run Bench Depths(DIL) Footage i 4 10,702~ - 10,732' 30' 2 4 10,732~ - 10,752' 20' Test well for 12 hrs., record 1WC every 3 hrs during test. 3 2 10,520~ - 10,540' 20' 6. RD E-line. 7. Place well in test for 48 hrs. Take at least 1WC every 6 hrs. MDC/em/31/Sundr2 P-O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska D~strict April 8, 1986 Hr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Hr. Chatterton: SUNDRY NOTICES AND REPORTS ON WELLS DOLLY VARDEN PLATFORH Attached for your approval are two (2) copies each of Form 10-403 for wells D-3RD2; D-SRD and D-43RD. Upon approval, please return one copy of each Notice to the undersigned. Very truly yours, Environmental Engineer 00280 cc: Trading Bay Unit Participants RECEIVED APR 0 9 11t86 Alaska 0il & Gas Cons. Commission STATE OF ALASKA, ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Unocal* 85-311 3. Address 8. APl Number P.O. Box 6247 Anchorage, AK 99502 50233-20373-01 4. Location of Well OTHER [] Surface: Leg A-l, Cond. #9 Dolly Varden Platform 754' FSL, 1207' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (~nd~cate KB, DF, etc.) 106' KB Above MSL 6. Lease Designation and Serial No. ADL 18729 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-43RD 11. F~eld and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altenng Casing [] Stem u late [] Abandon [] Stem u lation [] Aba ndonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note. Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent detads and give pertinent dates, mcluding estimated date of startmg any proposed work, for Abandonment see 20 AAC 25 105-170). PERFORATE TBU WELl, D-43RD It is Marathon's intention to perforate the well with 2 5/8" guns, 4 SPF, 0° phasing, under drawdown. 1. Rig up WL and lubricator, pressure test to 2500 psi. 2. RIH and perforate B-i; 10,464' - 10,492' DIL 3. Return the well to production. Perforating operations are expected to begin April 10, 1986. * Marathon Oil Company - Sub Operator S~gned The ~pace belo~ for Comm~s$io~ u~e ,,~ :~ ~'~: :~j~' ~ By Order of Approved bY ~ .... .. ~ COMMISSIONER the Commission 4/8/86 Date Date Form 10-403 Rev. 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duplicate Environmental Group Alaska District Unocal Oil & Gas Divisir'~ ' Unocal Corporation R O, Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL March 26, 1986 Mr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001Rorcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: WELL COMPLETION REPORT D-43/~D Attached please find two (2) copies of the Well Completion and/or Recompletion Report for D-43, Trading Bay Unit for your information and file. Very truly yours, R'o~/ D. Roberts Environmental Engineer tj/O124n Attachments (2) RECEIVED 1986 STATE OF ALASKA ~ ALASKA L AND GAS CONSERVATION G.. LMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Serwce Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Union Oil of California* 85-311 3. Address 8. APl Number P.O. Box 6247, Anchorage, AK 99502 50- 4 Locatlon of well at surface Leg A-l, Cond. #9, Dolly Varden Platform 9 Un~t or Lease Name 754' FSL, 1207' FWL, Sec. 6-8N-13W-SM Trading gay lTn~t At Top Producing Interval 10. Well Number 700' F~CL, 1135' ~qL. Sec. 6-8N-13W-SM D-43~D At Total Depth 11. Field and Pool 630' FWL, 335' FNL. Sec. 6-SN-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106'KB above MSLI ADL-17594 MacArthur River Field 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, ~f offshore 116. N° of Completions ~'¢"l--2-,LS~l~'/$t/C;y 2/14/86 3/3/86 106'KB feetMSL (1) one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey [ 20. Depth where SSSV set I 21. Thlckness of Permafrost l1250'MD 10083'TV]) ll166'MD 10009TV])YES~ NO[] 293' feetMD 22. Type Electric or Other Logs Run Sonic, NGT/CNT/DIL/LDT, OR, CBL, GET, CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13 3/8~ 68¢f K-55 Surface 3069 17 1/2" 580 sx cl."O" Neat 9 5/8" 47# N-80 Surface 9839 12 1/2" 1500 sx cl "G" 2490 sx cl "G" 7" 29# N-80 9551 11250 8 1/2" 700 sx cl "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) B-3 DIL 3 1/2" 9914' 984~,' _ MD TVD 10,604' - 10,690' 9,523' - 9,596' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 4SPF, o° phasing 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 2/24/86 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 2/28/86 24 TEST PERIOD I~ 525 165 1 ' -- 314 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 120 1050 24-HOUR RATE I~ 525 165 1 35.1 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. MAR 2 5 1956 f¢¢~ 2 8 1986 Alaska Oil & 6as Cons. c, ummi,~io~ Ak Environmental Group Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S,g,edROFD. Roberts Title Envir. Enqineer Date 03/26/86 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 SUpl~lemental'records for this well should show the details of any multiple stage cement- lng 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, S,,h,ut-in, Other-explain. Item 28: If no cores taken, indicate "none". SURVEY REPORT Marathon Oi 1 Co~k~any Trading Bay, McArthur River Dolly Vardon, Well #0-43 February 18, 1986 Gimdatm Services, Inc. 2171-A Portola Road Ventura, Califomia 93003 805/658-0994 February 21, 1986 Mr. Paul Mazzolln( Marathon 0il Company 3201 "C" Street Anchorage, AK 99503 RE' TRADING BAY, MC ARTHUR RIVER, DOLLY VARDON, WELL Dear Mr. Mazzol[n(: Enclosed is one (1) original and six (6) copi~es of the completed survey for wel ! number ~, Do] ly Vardon. Th~nk you'fo.,r~.usi, ng~:Gyrodata and ~we 1,ook. forward to serving you, in the future. Sincerely, GYRODATA SERVICES, INC. Russel! W. Truby Distri ct Manager 'RWT: If Enclosures Gyrodata Services. Inc. Houston, TX/Lafayette. LA/New Orteans. LA/Ventura. CA/ADercleen. U,K A Gy r od at a Direct ional for Survey MARATHON OIL COMPANY TRADING BAY, McARTHUR RIVER Date Rur,: i8-FEB-86 22:50:0 J":,b Number: AK0286G035 Surveyor: TRUBY Calculaticr, Metncd: RADIUS OF CURVATURE Pfc, posed, Weil, Direction: N 4deg 4mir~ Osec E ~e~ticai Sectior: Calculated from Well Head Loc~tion Closure C~lcuiated frcm~ Well Head Locatio~ Hori~orrt~i Coordinates Calculated from Local Horizor~tal Reference CERTIFIED SURVEY DATE__ / MARATHON OIL COMPANY TRADING BAY. McARTHUR RIVER DOLLY VARDO~, WELL D-43 Page MEAS INCL BORE HOLE VERT DEPTH BEARING DEPTH ft deo min deg min ft VERT C L 0 S U R E H 0 R I Z 0 N T A L SECTION DISTANCE AZIMUTH C O 0 R D ft ft deg feet 0.0 0 0 N 0 0 E 0.0 0.0 0.0 0.0 .0 N .0 E 100.0 0 7 N 24 50 W 100.0 .1 .1 335.1 . 1 N .0 W 200.0 0 10 N 5 18 E 200.0 .3 .4 345.7 .3 N .1 W 300.0 0 11 N 12 54 E 300.0 .6 .6 355.4 .6 N .0 W 400.0 0 8 S 46 16 E 400.0 .7 .7 13.6 .7 N .2 E 500·0 1 29 N 78 48 W ~0.0 - 3 4 229 9 3 S 3 W 600.0 3 16 N 86 i8 W 599.9 -.1 4.4 273.4 .3 N 4.4 W 700.0 3 32 S 85 31 W 699.7 -.5 10.4 271.2 .2 N 10.3 W 800·0 3 30 S 86 24 W 799.5 -1.4 16.5 269.2 .2 S i6.5 W 9~0.(~ 3 1 N 88 48 W 8'99.4 -1.9 2.2. 1 269.1 .3 S 22.1 W 1000.0 2 19 N 87 24 W 999.3 -2. 1 26.8 269.6 .2 S 26.8 W 1100.0 1 45 S 84 6 W 1099.2 -2.4 30.3 269.4 .3 S 30.3 W 1200.0 1 30 S 80 3 W 1199.2 -3.0 33.2 268.8 .7 S 33.1 W i300.0 1 33 N 75 3 W 1299.1 -3,1 35.8 269.1 .6 S 35.8 W ~ Z~I.. 0 3 4 N 20 44 W 1399.0 -. 7 38.7 273· 0 2.0 N 38.7 W 1500.0 5 20 N 10 46 W 1498.8 6.2 41.7 282.6 9.1 N 40.7 W !6~0.0 8 18 N i7 39 W !598.1 i7.5 48.2 2~95.3 20..6 N 43.6 W 1'700,0 11' 11 N I'9 W I'698."6 33, 1 6i.'1 3'0'~'.8 3:~.6 N 48',9 W 1800.0 13 21 N 14 54 W 1794.3 52.9 79.2 3i5.9 5~.9 N ~ ~.1 W t900.0 1~5 38 N 14 50 W 189t~1 76.6 10~.8 322,8 Si.1 N 6i,5 W 2000.0 18 27 N 15 · W 1986.7 104.3 129.4 327.7 109.4 N 69.1W 2t00.0 21 4 N 15 34 W 2080.8 136.2 162.0 331.2 142.1N 78.0 W 2200.0 23 54 N 15 12 W 2173.2 172.2 199.4 333·7 178.9 N 88.1W 2300.0 26 59 N 16 18 W 2263.5 212.6 241.8 335.6 220.3 N 99.8 W 2~00.~ 29 40 N 16 37 W 2351.5 257.1 288.9 336.9 265.8 N 113.2 W DOG-LEG SEVERIT de~/100 0.00 · 27 1.60 1.80 · 55 .06 .55 .71 · 63 · 28 .66 2.50 2.38 3.07 2.89 2.34 2.29 2 2.83 3.13 2.69 MARATHON OIL COMPANY TRADING BAY, McARTHUR RIVER DOLLY VARDON, WELL D-43 Page MEAS INCL BORE HOLE D .... TH BEARING ~t deo mir, deo ~in ., 2580.0 31 53 2600.0 32 50 2700.0 33 37 2800.0 34 34 2900.0 35 33 3000.0 36 27 3100.0 35 18 3200.0 30 16 3300.0 29 50 3400.0 29 55 3500.0 29 45 3600.0 29 49 3700.0 30 15 3800.0 30 8 3900. ~] 30 9 4~Z~00.0 30 4 4100.0 30 19 4 200~~ 0 30' ~'~9 4300.0 29 59 4400.0 29 51 4500.0 30 7 4600.0 29 47 4'700.0 29 39 4800.0 29 38 4900.0 29 20 N 1539W N 1653W N 1652W N 1639W N 17 2W N 17 12 W N 1753W Nil 38W N 9 2W N 928W N 9 11 W N 9 12W N 9 1 W N 9 11 W N 9 15 W 924W 9 9W 9 936W 957 W VERT DEPTH ft VERT C L 0 S U R E H 0 R I Z 0 N T A L DOG-LEG SECTION DISTANCE AZIMUTH C 0 0 R D SEVERIT ft ft deo feet d eo / 100 -- N 9 57 W 4141.6 i305.8 1377.9 345.4 1333.7 N 346.2 W N 9 56 W 4228.3 1354.2 1427.7 345.6 1382.9 N 354.8 W N 10 12 W 4315.1 1408.3 1477.1 345.7 1431.7 N 363.5 W .18 N 10 5 W 4402.0 1450.2 1526.3 345.8 1480.3 N 372.2 W .06 N 10 19 W 4489.0 1497.9 1575.5 346.0 !528.7 N 380.9 W .34 2851.1 567.3 619.7 340.3 583.6 N 208.4 W .92 2932.1 621.8 678.2 340.5 639.5 N 226.0 W 1.22 3016.2 673.0 732.2 340.8 691.8 N 239.8 W 6.06 3102.7 721.5 781.7 341.4 741.1 N 248.8 W 1.37 3189.4 7'70.0 830.9 342.0 790.2 N 256.8 W .23 3276.2 818.4 880.1 342.4 839.3 N 264.9 W .22 3363.0 866.8 929.3 342.9 888.4 N 272.8 W .07 3449.6 915.5 978.9 343.3 937.8 N 280.8 W .45 3536.0 964.5 1028.8 343.7 987.5 N 288.7 W .15 3622.5 1013.4 1078.6 344.0 1037.0 N 2:96.8 W .04 3709.0 1062.8 1128.5 344.3 1086.5 N 304.9 W .12 3795.4 1111.1 1178.5 344.6 1136.2 N 313.0 W .29 D88~t'~8 t'I~60~I~ t228'~5 344~'8 1~85.9N '~21.0W .18 3968.3 1208.9 1278.4 345.0 1235.3 N 329.1W .89 4055.0 1257,3 1328.1 345.2 1284.5 N 337.6 W .22 2437.4 305.1 339.7 337.9 314.9 N 127.4 W 2.26 2521.9 355.3 393.0 338.7 366.3 N 142.4 W 1 ~6 2605.6 406.5 447.7 339.3 418.8 N 158.3 W 2688.4 458.9 503.6 339.7 472.4 N 174.4 W . 2770.2' 518.5 560.9 340.0 527.4 N 191.1 W 1.00 MARATHON OIL COMPANY TRADING BAY,~ McARTHUR RIVER DOLLY VARDON, WELL D-43 Page MEAS iNCL BORE HOLE VERT VERT DEPTH BEARING DEPTH SECTION ft den min deo min ft ft 5000.0 29 4 5100.0 28 53 5200.0 29 46 5300.0 29 3 5400.0 29 35 5500.0 29 5t 5600.0 29 41 5700.0 29 30 5800.0 30 11 5900.0 29 30 6000.0 29 23 6100.0 29 48 6200.0 29 39 6300.0 29 59 6400.0 29 56 6500.0 29 12 6600.0 28 58 67'00."0 28 2~ 6800.0 27 15 6900.0 26 35 7~00.0 27 28 7100.0 27 48 7200.0 28 38 7300.0 28 11 7400.~ 27 37 N 923W N 10 2W N 9 8W N !0 10 W N 850W N 841W N 752W N 8 5W N 727W N 647W N 632W N 550W N 5 4W N 4 5 W N 334W N 1 54W N 055W N 055 'E N 1 51 E N 257E N 357E N 4 2E N 448E N 527E N 6 1SE 4576.3 4663.8 4751.0 4838.1 4925.3 5012.2 5099.0 5185.9 5272.7 5359.4 5446.5 5533.4 5620.3 5'707.0 5793.7 5880.7 5968.0 6055;8 6144.2 6233.4 6322.5 6411.1 6499.2 6587.1 6675.5 1545.2 1592.2 1639.8 1687.5 1735.1 1783.5 18.32.0 1880.3 1929.0 1977.8 2026.1 2074.7 2123.6 2172.7 2222.2 2271.2 2319.6 '2367.5 2414.1 2459.3 2504.8 2551.1 2598.4 2648.0 2692.7 CLOSURE DISTANCE AZ IMUT~ ft de~ - 1624.1 346.1 1672.4 346.2 1721.3 346.3 1770.3 346.4 1819.1 346.5 1868.5 346.7 1918.0 346.8 1967.2 346.9 2016.7 347.1 2066.2 347.2 2115.1 347.3 2164.2 347.5 2213.4 347.6 2262.7 347.8 23!2.1 348.0 2360.8 348.2 ~4~8. Z 348.4 2~'55,'7 34'8~6 2501.3 348.8 2545.3 349.1 2589.3 349.3 2634.2 349.6 2680.0 349.8 2725.9 350.1 2771.0 350.4 HORIZONTAL COORD feet 1576.8 N 389.2 W 1624.5 N 397.4 W 1672.8 N 405.6 W 1721.2 N 413.8 W 1769.5 N 421.9 W 1818.5 N 429.4 W 1867.6 N 436.6 W 1916.5 N 443.4 W 1965.8 N 450.! W 2015.2 ~ 456.3 W 2064.0 N 462.0 W 2113.1N 467.3 W 2162.5 N 472.1W 2212.1N 476.0 W 2261.9 N 479.~ W 2311.2 N 481.7 W 2359.8 N 482.9 W 2407,8 N 482.9 W 2454.4 N 481.8 W 2499.7 N 479.9 W 2545.0 N 477.2 W 2591.3 N 473.9 W 2638.4 N 470.3 W 2685;8 N 466.0 W 2732.3 N 461.3 W DOG-LEG S£VERIT de~/100 .53 · 27 .44 .21 .74 .75 .17 .54 .41 .58 .26 !.10 .54 1.05 1.23 · 84 .91 .54 .68 MARATHON OIL COMPANY TRADING BAY, McARTHUR RIVER I)OLLY VARDON, WELL D--43 -- MEAS ! NCL BORE HOLE DE PTH BEAR I NG ft deo rain deg mir, 7500.0 27 28 '?600.0 26 50 7700.0 27 3 7800.0 26 39 7900~0 2:6 38 8~00.0 26 18 8100.0 25 39 8200.0 24 59 8300.0 23 25 84~0.0 23 8 8500.0 22 14 8600.0 22 !9 8700.0 22 4 8800.0 21 26 8900~0 20 44 N 726E N 749E N 935E N 10 2E N 1020E N 1237E N 1352E N 1447E Nil 3E N 5 1 E N 3 7E N 3 57 E N 341 E N 534E N 6 13 ~ 9~00.0 20 22 N 8 25 E 9!00.0 21 52 N 8 57 E 9200,0 23 53 N' 5 47 E 9300.0 25 35 N 6 49 E ':J4(-')0.0 27 26 N 8 10 E ~500.0 F'9 F'3 N 8 54 E 9600.0 31 ii N 11 26 E 9'700.0 3i 52 N 12 24 E 9800.0 3~. 27 N 13 23 E 99:,?.,~.0 3! t. 5 N i3 58 E VERT VERT DEPTH SECTION ft ft 6764.2 2738.9 6853.2 2784.5 B942.3 2829.6 7031.5 2874. G 7120.9 2919.2 7210.4 2963.4 7300.3 3006.6 7390.7 3048.7 7481.9 3089.2 7573.8 3128.6 7666.0 3167.2 7758. B 3205.1 7851.2 3242.8 7944.0 3279.9 8037.4 3315.8 8131.0 3350.9 8224.3 338B.8 8316.4 3425, G 8407.2 3467.4 8496.7 3511.9 8584.7 3559.4 8G71.0 3609.5 8756.2 3661.3 8841.4 3713.2 8926.8 3764.5 CLOSURE DISTANCE AZIMUTH ft deg 2815.4 350.6 2859.1 350.9 2902.2 351.2 2945.1 351.5 2987.6 351.7 3029.6 352.0 3070.5 352.3 3110.2 352.6 3148.7 352.9 3186.9 353.1 3224.7 353.2 3262.0 353.3 3299.1 353.4 3335.5 353.5 3370.6 353.7 3404.8 353. 3439.6 354. 3477.4 354. 3518.4 354. 356i.8 354. 3608.0 354. 3856.6 354. 3706.6 355. 3756.6 355. 3806 0 ~=~ H 0 R I Z O N T A L DOG-LEG C 0 O R D SEVERIT feet c~e~ / 100 2778.2 N 455.8 W .56 2823.5 N 449.7 W ~6 2868.3 N 442.9 W (~ 29t2.8 ~ 435.2 W . 2956.9 N 427.2 W ..1.4 3000.6 N 418.4 W !.07 3043.2 N 408.3 W .85 3084.7 N 397.7 W . 77 3124.6 N 388.6 W 2 19 3!63.7 N 383.1 W 2.40 3202.2 N 380.3 W 1.16 3240.0 N 378.0 W .33 3277.7 N 375.5 W .27 3314.6 N 372.5 W .9~ ~ .... 0.4 N 368.8 W 3385.2 N 364.3 W .85 3420.8 N 358.9 W 1.52 345~.4 N 353.9'W 2.36 3501.0 N 349.3 W 1.74 3545.2 N 343,5 W 1.96 35~2.3 N 336.5 W ~:,i 364!.9 N 327.6 W 2.~0 3693.1N 316.8 W .85 3744.2 N 305.~ W .67 3794.8 N 292.8 W .,37 ~ARATHON OIL COMPANY TRADING BAY, McARTHUR RIVER DOLLY VARDON, WELL D-43 - MEAS INCL BORE HOLE DEPTH BEARING ~t deg ~in de@ min 10000.0 31 56 N 15 15 E 10100.0 32 2 N 16 16 E 10200.0 32 51 N 17 36 E 10300.0 32 41 N 17 16 E 10400.0 32 35 N 18 27 E 10500.0 32 7 N 19 51 E 10600.0 31 11 N 21 10 E 10700.0 32 2 N 22 0 E 10800.0 -30 ...... 0 N 23 51 E 10900.0 29 37 N 25 54 E 11000.0 29 1 N 28 55 E 11100.0 28 55 N 30 57 E 11150.0 29 0 N 32 30 E VERT VERT DEPTH SECTION ft ft 9012.0 3815.9 9096.8 3867.8 9181.2 3920.1 9265.2 3972.8 9349.5 4025.1 9433.9 4076.8 9519.1 4127.1 9604.2 4177.1 9689.9 4225.9 9776.7 4272.3 9863.9 4317.3 9951.4 4360.8 9995.2 4382.3 CLOSURE HORIZONTAL DISTANCE AZIMUTH C 0 0 R D ft de@ feet 3855.6 355.8 3905.4 356.1 3955.6 356.3 4006.2 356.6 4056.5 356.9 4106.1 357.2 4154.3 357.5 4202.2 357.8 4248.9 358.0 4293.4 358.3 3845.5 N 279.5 W 3896.4 N 265.2 W 3947.8 N 249.5 W 3999.4 N 233.3 W 4050.7 N 216.8 W 4101.3 N 199.2 W 4150.4 N 180.8 W 4199.1 N 161.6 W 4246.6 N 141.5 W 4291.7 N 120.6 W 4336.2 358.7 4335.1 N 98.1 W 4377.7 359.0 4377.1 N 73.9 W 4398.1 359.2 4397.7 N 61.2 W DOG-LEG SEVERIT deo/100 .95 .88 1.17 .95 2.24 1.09 1.59 .99 1.52 Fir, al Station Closure: 4398. 1 feet o o North 0 deg 47 ~in 49 sec West Directional Surve~ Table JUNE 21, 1994 10:26 TRADING BAY UNi~ D-43RD UNOCAL/ALASKA . EPARJJD API# 507332037301 OPERATOR MARATHON Survey datum Survey elevation Survey company Survey method Survey date Surface location projection township 208456.0 2490833.00 STATE ALK4 D43RD Measured Vertical Depth Depth 0.00 0.00 100.00 100.00 200.00 200.00 300.00 300.00 400.00 400.00 500.00 499.96 600.00 599.80 700.00 699.61 800.00 799.43 900.00 899.29 1000.00 999.20 1100.00 1099.16 1200.00 1199.12 1300.00 1299.09 1400.00 1398.94 1500.00 1498.51 1600.00 1597.46 1700.00 1695.56 1800.00 1792.86 1900.00 1889.16 2000.00 1984.02 2100.00 2077.34 2200.00 2168.76 2300.00 2257.88 2400.00 2344.77 2500.00 2429.68 2600.00 2513.71 2700.00 2596.98 2800.00 2679.33 2900.00 2760.69 Calculation method Reference Subsea Drift Depth Angle Azimuth 106.00 0.00 0.00 6.00 0.12 335.50 -94.00 0.17 5.30 -194.00 0.18 12.90 -294.00 0.13 133.73 Coordinates X Y 208456 2490833 208456 2490833 208456 2490833 208456 2490833 208456 2490833 -393.96 1.48 281.20 -493.80 3.27 273.70 -593.61 3.53 265.52 -693.43 3.50 266.40 -793.29 3.02 271.20 208454 2490834 208448 2490834 208442 2490834 208436 2490834 208430 2490834 -893.20 2.32 272.60 -993.16 1.75 264.10 -1093.12 1.50 260.05 -1193.09 1.55 284.95 -1292.94 3.07 339.27 208426 2490834 208423 2490834 208421 2490834 208418 2490834 208416 2490839 -1392.51 5.33 349.23 -1491.46 8.30 342.35 -1589.56 11.18 340.90 -1686.86 13.35 345.10 -1783.16 15.63 345.17 208415 2490849 208411 2490862 208405 2490881 208400 2490903 208393 2490930 -1878.02 18.45 345.00 -1971.34 21.07 344.43 -2062.76 23.90 344.80 -2151.88 26.98 343.70 -2238.~7 29.67 343.38 208386 2490960 208377 2490995 208368 2491035 208356 2491078 208343 2491126 -2323.68 31.88 344.35 -2407.71 32.83 343.12 -2490.98 33.62 343.13 -2573.33 34.57 343.35 -2654.69 35.55 342.97 208330 2491177 208316 2491230 208301 2491283 208286 2491338 208270 2491394 : Tangential (default from database) : Map projection STATE ALK4 Measured Vertical Subsea Drift Depth Depth Depth Angle Azimuth Coordinates X Y 3000.00 2841.13 -2735.13 36.45 342.80 3100.00 2922.74 -2816.74 35.30 342.12 3200.00 3009.11 -2903.11 30.27 348.37 3300.00 3095.86 -2989.86 29.83 350.97 3400.00 3182.53 -3076.53 29.92 350.53 208254 2491451 208238 2491506 208229 2491556 208222 2491605 208215 2491655 3500.00 3269.35 -3163.35 29.75 350.82 3600.00 3356.11 -3250.11 29.82 350.80 3700.00 3442.50 -3336.50 30.25 350.98 3800.00 3528.98 -3422.98 30.13 350.82 3900.00 3615.45 -3509.45 30.15 350.75 208209 2491704 208202 2491753 208195 2491803 208188 2491853 208182 2491902 4000.00 3702.00 -3596.00 30.07 350.60 4100.00 3788.32 -3682.32 30.32 350.85 4200.00 3874.79 -3768.79 30.15 350.90 4300.00 3961.41 -3855.41 29.98 350.40 4400.00 4048.14 -3942.14 29.85 350.05 208175 2491952 208168 2492002 208161 2492052 208154 2492101 208147 2492151 4500.00 4134.64 -4028.64 30.12 350.05 4600.00 4221.43 -4115.43 29.78 350.07 4700.00 4308.34 -4202.34 29.65 349.80 4800.00 4395.26 -4289.26 29.63 349.92 4900.00 4482.43 -4376.43 29.33 349.68 208139 2492200 208132 2492249 208124 2492298 208117 2492347 208109 2492396 5000.00 4569.84 -4463.84 29.07 350.62 5100.00 4657.39 -4551.39 28.88 349.97 5200.00 4744.20 -4638.20 29.77 350.87 5300.00 4831.62 -4725.62 29.05 349.83 5400.00 4918.58 -4812.58 29.58 351.17 208103 2492444 208095 2492491 208089 2492541 208081 2492589 208075 2492638 5500.00 5005.31 -4899.31 29.85 351.32 5600.00 5092.18 -4986.18 29.68 352.13 5700.00 5179.22 -5073.22 29.50 351.92 5800.00 5265.66 -5159.66 30.18 352.55 5900.00 5352.70 -5246.70 29.50 353.22 o 6000.00 5439.83 -5333.83 29.38 353.47 6100.00 5526.60 -5420.60 29.80 354.17 6200.00 5613.51 -5507.51 29.65 354.93 6300.00 5700.12 -5594.12 29.98 355.92 6400.00 5786.78 -5680.78 29.93 356.43 208069 2492687 208063 2492736 208058 2492785 208052 2492835 208048 2492884 208043 2492933 208040 2492982 208036 2493032 208034 2493082 208032 2493132 6500.00 5874.07 -5768.07 29.20 358.10 6600.00 5961.56 -5855.56 28.97 359.08 6700.00 6049.52 -5943.52 28.40 0.92 6800.00 6138.42 -6032.42 27.25 1.85 6900.00 6227.85 -6121.85 26.58 2.95 208032 2493180 208032 2493229 208034 2493276 208037 2493322 208040 2493367 7000.00 6316.57 -6210.57 27.47 3.95 7100.00 6405.03 -6299.03 27.80 4.03 7200.00 6492.80 -6386.80 28.63 4.80 7300.00 6580.94 -6474.94 28.18 5.45 208045 2493413 208049 2493459 208054 2493507 208060 2493554 Calculation method : Tangential (default from database) Reference : Map projection STATE ALK4 Measured Vertical Subsea Drift Depth Depth Depth Angle Azimuth 7400.00 6669.55 -6563.55 27.62 6.25 7500.00 6758.27 -6652.27 27.47 7.43 7600.00 6847.50 -6741.50' 26.83 7.82 7700.00 6936.56 -6830.56 27.05 9.58 7800.00 7025.94 -6919.94 26.65 10.03 o 7900.00 7115.32 -7009.32 26.63 10.33 8000.00 7204.97 -7098.97 26.30 12.62 8100.00 7295.12 -7189.12 25.65 13.87 8200.00 7385.76 -7279.76 24.98 14.78 8300.00 7477.52 -7371.52 23.42 11.05 Coordinates X Y 208066 2493600 208073 2493645 208080 2493690 208089 2493734 208098 2493778 208107 2493822 208118 2493865 208129 2493907 208141 2493947 208150 2493986 8400.00 7569.48 -7463.48 23.13 5.02 8500.00 7662.04 -7556.04 22.23 3.12 8600.00 7754.55 -7648.55 22.32 3.95 8700.00 7847.22 -7741.22 22.07 3.68 8800.00 7940.30 -7834.30 21.43 5.57 208154 2494025 208157 2494063 208161 2494101 208164 2494138 208169 2494174 8900.00 8033.82 -7927.82 20.73 6.22 9000.00 8127.57 -8021.57 20.37 8.42 9100.00 8220.38 -8114.38 21.87 8.95 9200.00 8311.81 -8205.81 23.88 5.78 9300.00 8402.00 -8296.00 25.58 6.82 208173 2494210 208179 2494244 208186 2494280 208191 2494321 208197 2494363 9400.00 8490.76 -8384.76 27.43 8.17 9500.00 8577.89 -8471.89 29.38 8.90 9600.00 8663.44 -8557.44 31.18 11.43 9700.00 8748.37 -8642.37 31.87 12.40 9800.00 8833.68 -8727.68 31.45 13.38 208205 2494409 208214 2494457 208225 2494508 208238 2494559 208251 2494609 9900.00 8919.16 -8813.16 31.25 13.97 10000.00 9004.03 -8898.03 31.93 15.25 10100.00 9088.80 -8982.80 32.03 16.27 10200.00 9172.81 -9066.81 32.85 17.60 10300.00 9256.97 -9150.97 32.68 17.27 208265 2494659 208280 2494710 208296 2494760 208314 2494812 208331 2494863 10400.00 9341.23 -9235.23 32.58 18.45 10500.00 9425.93 -9319.93 32.12 19.85 10600.00 9511.48 -9405.48 31.18 21.17 10700.00 9596.25 -9490.25 32.03 22.00 10800.00 9682.85 -9576.85 30.00 23.85 208350 2494914 208369 2494963 208389 2495011 208410 2495060 208431 2495105 10900.00 9769.79 -9663.79 29.62 25.90 11000.00 9857.23 -9751.23 29.02 28.92 11100.00 9944.76 -9838.76 28.92 30.95 11150.00 9988.49 -9882.49 29.00 32.50 11250.00 10075.95 -9969.95 29.00 32.50 208454 2495149 208478 2495190 208504 2495231 208518 2495251 208545 2495292 Calculation method : Tangential (default from database) Reference : Map projection STATE ALK4 Form to be inserted in each "Ac--~ve" well folder to check for timely compliance with our regulations. Reports and Ma:terials to be received by..~ ~ate Required Date Received Remarks Completion Report Well History Samples Core Chips Core Description ~ Registered Survey Plat Inclination Survey Drill Ste m Test Reports Production Test Reports ~~- . . , , , LoE Run Digitized Data Unocal Oil & Gas Divisie Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL DOCUMENT TRANSMITTAL Alaska D~stnct March 14, 1986 HAND DELIVER TO: Bill Van Alan FROM: R.C. Warthen R. B. Stickney LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting: MARATHON TBU D-43RD McArthur River Field Cook Inlet, AK Sec 6, TBN R13W (SM) ARI #50-733-20373-01 For the well indicated above, please find the following data: One (1) blueline and one (1) sepia of: DIL/SFL ~', & ~,,) DIL/SFL (TVD) ~2") Array Sonic Waveform '%<5") Arrey Sonic NGT ~5,,I CNL/LDT 5" Bulk Density/PEF ~5") NGS 3,050 to 11,190' 3,050 to 11,190' 9,839 to 11,179' 9,839 tO ll,lYg' 9,600 to ll,190' 9,600 to ll,190' 9,800 to 11,132' One (1) copy of the following tapes and listings: ~ ~NJLIS tape 12,300 to 14,277 -~¢-~~---~-O/~-J/-~~ -]11c~0 ~ Gyro Directional Survey 0 to 11,150 DATED: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: ,/)RJSCF V _ ¢¢ ska 0il & Gas COrlS~ Commission Anchorage _.~ STATE OF ALASKA ALASKAC AND GAS CONSERVATION CCi tlSSION ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS l~-."Drllllng well ~] Workover operation [] 2. Name of operator 7. Permit No. Unocal * 85-311 3. Address 8. APl Number P.O. Box 6247, Anchorage, AK 99502 50- 733-20373-01 4. Location of Well at surface Leg A-l, Conductor #9, Dolly Varden Platform 754' FSL, 1207' FWL, Sec. 6, T8N, R13W, SM * Marathon Oil Company - Suboperator 5. Elevation in feet (indicate KB, DF, etc.) / 6. Lease Designation and Serial No. 106' KB Above MSLI ADL-17594 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-43 11. Field and Pool McArthur River For the Month of February , 19 86 12. Depth at end of month, footage drilled, f~shing jobs, directional drilling problems, spud date, remarks Total Depth for 8-1/2" hole of 11,250' was reached. R ~ f" ~ 1%! !~1~ .tEl V IZI.; . MAR 1 3 1986 Alaska Oil o ~,.,s uuns. ~o~ission Anc~0rnge 13. Casing or I~ner run and quantities of cement, results of pressur9 tests Ran a total of 1699' of 7" 29# N-80 buttress liner with the liner hanger at 9551' and cemented with 700 sacks of cement. The liner lap was successfully dry tested. The entire casing string was pressure tested to 2500 psi. 14. Coring resume and brief description Ten cores from Hemlock Benches 1-4 were cut. A total of 201' of core was cut and 193' of core was recovered. The cores were obtained from the following depths; 10,459'-10,482', 10,519'-10,593', 10,661'-10,674', 10,712'-10,803'. The recovered. cores were massive sandstone with thin interbedded conglomerate sections. 15. Logs run and depth where run A cement evaluation log was run from 11,164'-9530'. 11,150' to surface. A .gyro survey was run from 16 DST data, perforating data, shows of H2S, miscellaneous data The Hemlock Bench 3 was perforated from 10,604'-10,690' with 4 SPF at 0° phasing. 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Royj/Do Roberts Env i ronmenta 1 'Eng i neer SIGNED TITLE DATE 03/11/86 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Unocal Oil & Gas Divis~ Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Enwronmental Group Alaska District February 14, 1986 Mr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: MONTHLY REPORTS D-43 & K-25 Attached please find two (2) copies each of the Monthly Report of Drilling and Workover Operations for K-25 & D-43, Trading Bay Unit for your information and files. Very truly yours, Ro~D .' Roberts Environmental Engineer tj/O124n Attachments ~.. STATE OF ALASKA -- ALASKA .AND GAS CONSERVATION C( ¢IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well Workover operation [] 2 Name of operator Unocal * 3. Address P.O. Box 6247, Anchorage, AK 99502 4. Location of Well atsurface Leg A-i, Conductor #9, Dolly Varden Platform- 7. Permit No. 85-311 8. APl Number 50- 733-20373-01 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-43 ~P 11. Field and Pool 754' FSL, 1207' FWL, Sec. 6, T8N, R13W, SM Marathon Oil Company - Suboperator 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' KB Above MSLI ADL-17594 McArthur River For the Month of. January ,19 86 12. Depth at end of month, footage drilled, fmhing jobs, directional drilling problems, spud date, remarks Total depth at end of month was 10,425'. A total of 6382' of hole was drilled. correction runs were made with a downhole mud motor to correct for excessive righthand walk. A GR/DIL logging string became stuck at 3853' and was successfully fished. Three 13. Casing or liner run and quantities of cement, results of pressure tests The 9-5/8", 47#, N-80 and P-110 casing was set at 9839' and cemented with a total of 3000 sks Class "G" cement with additives. The 9-5/8" was pressure tested to 3000 psi. A formation integrity test to 12.0 ppg EMW was performed after drilling 10' of new hole. 14. Coring resume and brief description 15 Logs run and depth where run A DIL/GR log was run from 9786' to 3853'. 16. DST data, perforating data, shows of H2S, m~scellaneous data 17. I herebv certify that the foregoing is true and correct to the best of my knowledge. SIGNED I~'Oy U ........ - TITLE Environmental En,qineer DATE 02/14/86 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate December 23, 1985 ADMINISTRATIVE APPROVAL NO. 80.51 Re.. The application of Union Oil Company of California, operator of the Trading Bay Unit, to drill, complete, and produce the Trading Bay Unit No. D-43RD well as part of the pressure maintenance project approved by Conservation Order No. 80. Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502-0247 Dear Mr. Anderson: The application was received on December 20, 1985 and stated that the drilling, complgtion,, and production of the Trading Bay Unit No. D-43RD well'will provide for additional oil recovery. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, compietion,w and production of the referenced well pursuant to Rule 5 of Conservation Order 1~o. 80. Yours very_ ~r~ly, Lonnie C.' S~ith, Commissioner BY ORDER OF TtlE COM~I$SION be:3.AAS0 December 30, 1985 ~-{r. Roy D. Roberts Environmental Technician Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502-0247 Re: Trading Bay Unit D-43RD Union Oil Company of California Permit No. 85-311 Sur. Loc. 754'FSL, 1207'FWL, Sec. 6, T8N, R13W, SM. Btmhole Loc. 666'FSL, 26'FEL, Sec. 31, T9N, R13W, SM. Dear Mr. Roberts: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V/er~ tru~M~-ypur§, ~ C~ If. C'~t~'rton Chairman o f Alaska Oil and Gas Conservation Commission be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux ALASK, STATE OF ALASKA elL AND GAS CONSERVATION PERr IT TO DRIll.. 20 AAC 25.005 ,MMISSION la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~] DEVELOPMENT GAS [] SERVICE [] STRATL~APHIC [-] SINGLE Z(~ I-Ii '~.~ MULTIPLE ~"~NE []~.~J~--. ( ~ 2. Name of operator Union Oil Company_of California 3. Address P. O. Box 6247, Anchorage, Alaska 99502 9. Un,t or lease name L~,d~'~[, C,~.c~" Trading Bay Uf~/t 4. Location of well at surface Leg A-1, Cond #9, Dolly Varden- Pltf 754' FSL, 1207' FWL, Sec. 6, 8N-13W-SM At top of proposed producing interval 200' FNL, 900' FWL, Sec. 6, 8N-13W-SM At total depth 666' FSL, 26' FEL, Sec. 31, 9N -13W-SM 5. Elevation in feet (~ndicate KB, DF etc.) 106' KB above MSL 6. Lease designation and serial no. ,_ ADL-17594 , . 12. Bond inform§tion (see 20 AAC 25.025) TYpe Blanket Drilling Surety and/or number B-2-165-724-1 10, Well number 11. F,eld and pool McArthur River Field ' Amount $ 2 (")fi, O~f') - Q¢) ~. 13. Distance and direction from nearest town 21 Miles NW of Kena~niles 16. Proposed depth (MD & TVD) ll,318'MD, 10,095'TV[Jeet 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 21 14. Distance to nearest property or lease line 3 5 0 0 ' feet 17. Number of acres in lease ' 3085 3.150 feet. MAXIMUM HOLE ANGLE 37°1 SIZE Hole I Casing Weight 12% 8½1, 7" 29 20. Anticipated pressures (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program CASING AND LINER Grade Coupling Length 15. Distance to nearest drdllng or completed well D- 11 @ 1000 feet 18. Approximate spud date 12-15-85 2 8 6 0 ' ps,g@ Q Surface 3500 psig@l 00 95ft. TD (TVD) SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD K-55 Butt 3055 ' Surf N-80 Butt 9327' Surf MDBOTTOMTVD 3069' 12908' 9370' 18257' 10700~9385' 10500'19220' (include stage data) 25o0 sx Cl G 1250 sx C1 G I 11318 ~10095 I P-110 Butt 1330' 9370' 1825'7' 1250 sx C1 G I I stg collar @ 6500' N-80 Butt 1335' 400 sx C1 G 22. Describe proposed program: "Well D-43~rilling Program" 1. With to s 2. Dril csg~ 3. Dril 4. Comp 13-3/8" casing @ 3069', set ide track fish @ 3233'MD. 1 12%" hole to 10,~00'. Run cement plug and kick off open hole logs. Run and 1 8½" hole to 11,318' . Run open hole logs. Run and lete the well as a Hemlock producer. @ 3150'MD cmt cmt 9-5/8" 7" liner. *Marathon Oil Company - Sub Operator 23. I hereby cert,fy/that the foregolng~s true and cosrect to the best of my knowledge ~f~ S,GNED Roy D. Roberts ~/' T,TLE 5nv~r0nmental Speciali$~ATE 12/17/85 The space below for Commission use Samples required I--lYES I~NO Permit number APPROVED BY Form 10-401 CONDITIONS OF APPROVAL Mud log requ,red []YES /~NO ACpr°va' d.~ / 30/85 Directional Survey required [~ES []NO APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER by order of the Commission DATE December 30, 1985 Submit in triplicate Unocal Oil & Gas Divisie '-' Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District December 18, 1985 Hr. C.V. Chatterton AK. 0il & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached for your approval are 3 copies of the PermLt to Drill application with spacing exception letter for D-43~rading Bay Unit along with check number 19390 to cover the required filing fee. Please return the approved Permit to the undersigned. Very truly yours, . Roy D~' Roberts ENVIRONMENTAL SPECIALIST tj/OOgln Attachments RECEIVED A!aska 0/1 & Gas Cons. An:.%r~9,~'~ . Comrmssion ( ft x LO00 } o VERTICAL SECTION 0.60 !.~0 t.80 8.40 TV TH 3.00 3.60 4.80 4.80 5.40 6.00 6.60 7.;'0 7.1)0 8.40 g.o0 9.60 tO.20 tO.80 -0.60 A MARATHON OIL COMPANY DOLLY PLATFORM WELL NO. 43RD ~ RADIUS OF CURVATURE ! 11/26/85-GYRO g PLAN i SCALE' 1 inch : 1200 feet -- PLANiIED WELl D-43 EC 'IVED AncI orate __ .~-~T,,RGET ~( 645 MD 9506 TVD 1 )095 TMD 1 0 0.60 ~..20 :L.80 ';'.40 3.00 3.60 4.;?0 4.80 5.40 6.00 6.60 Depanture Ift x ~.ooo 1 Notes ' All values in feet. Depths shown are TVD. Closure: 4664 ft at N 3 deg 49 min W Bottom hole: TVD i0095 TMD 1t3tB Magnetic declination: 24 deg 30 min E HORIZONTAL VIEW MARATHON OIL COMPANY DOLLY PLATFORM WELL NO. 43 RADIUS OF CURVATURE 11/26/85-GYRD ~ PLAN SCALE: ! inch : BOO feet DRAWN: 11-7-B5 ,, 10095 l ~- TARGET 10~45 MD :1506 lVi] (TOP H :'MLOCK) ,, <- D-43 PLANNED WEL ,, 3%~'~ - -43 ORZGINAL '2ELL , , , RI'C, EIVED A!~ska · · · · · · · .. .r. '~'~ 20 ( .?. ,. · .'~ tO-14,d / / / ..... / ~ / .. / · / · / · / : / : · · · / : :o~. ~ / .: ! ~ .......... ...:_ / : / : -- / : //.~- ..---- / · / i~ / / : .... ~11111111111 ) ~ ~I ' I i --Jt~m TRADING BAY UNIT ~' ~ ]' McARTHUR RIVER FIELD I 1114 I I · I~I I .Im · · .4 · · · · · e · · · -MARATHON Oil_ GO. -- DOLLY VARD-~N PLATFORM - · . U f Drillin9 ilipple _ % Ahhular Preventer o~ (20", 2,ooo H.ydril ) Wc. lt Room 'X _ C. la~p- or~ l-lub Ca C-T) , ~k~CEi'V[D MARATHO OIL GO.- - DOLL'Y' VARDEN! PLATFORM U I: J MuJ Pan u~ -- Drillin~ blippl~- C. ollar' 1'3 ~/~" £urf~ce O~si~8 C~onduc±or .~_. Well Room 12~)~5, O00~ Go, sing l.--tec~d w/Flan~ed Outle_t's 2_ Ff. Spool [o° o o] cl~ co~~o~ r D~ll Deck rlooF / ~ ~ . - .~~ ~ CI~ Swin~- Bolt J~ / ConneatorsOi°mP --'Diagram~ ~ --i~/8"x B, OOO~ [o Ol ~ Riser ~ BOP St~ck For to, , a~ D~illin ' From Uhd~ J3~/~'~ · Surface O.s,ng To TD.-- '~ VA .va' ' · , ~ . _ . . . DVP ~ , i~, I · · , I . , . , i . · . -j Anchora~, District Production Umted States Marathon Oil Company P.O. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 September 20, 1984 U. S. Environmental Protection Agency Attn: Director, Enforcement Region X -Mail Pouch 521 1200 Sixth Avenue Seattle, W~ 98101 DOLLY VARDEN PLATFORM PERMIT No. AK-000041-8 DRILLING _W~3D FOR W~I. D-43 Marathon Oil Company hereby advises that in keeping with the permit referenced above, a lignosulfonate drilling hud system will be used on the Dolly Varden Platform. We plan to oontinue using a water based lignosulfonate hud system. The system contains the following compounds at the approximate percentages by weight as listed: Lbs/Bbl Mud % of System by Material (Approx.) ~c. (Approx.) Bentonite Barite Sodium Hydroxide Causticized Lignite L~gnosul fonate Sodium Carboxymethyl Cellulose Sodium Carbonate Organic Entity Neutralized w/ Amines Detergent Walnut Shells Water 87 20.9 69 16.6 6 1.4 5 1.2 13 3.1 3 0.7 2 0.5 4 1.0 3 0.7 3 0.7 221 53.2 ,, _ TOTAL 416 100.0 We plan to maintain a volume of 1600 to 2000 barrels in the system. Periodic mud disposal through the cutting chute outfalls 001 may be necessary throughout the drilling of the well. RECEIVED U. S. Environmental Protection Agency September 20, 1984 Page Two These discharges are limited to the excess hud as a result of displacing the mud systems with casing cements and completion fluids. The expected volumes of discharge will vary as circumstances dictate. Normal Drilling Dally loss to desander, desilter, and over shakers will be approximately 20 to 30barrels. Cementinq Casing The amount cut with cement and dumped when circulating out after a cement job (liner hanger, squeeze cementing, etc. ) will be approximately 20 to 30 barrels. Running Casing Maximum amount possibly dun~wh/le running casing due to casing displacement would be approximately 60 barrels. This well will oommence about September, 1984. Operations are expected to continue for approximately seventy (70) days. K. A. THOMA Operations Superintendent KAT: cas xc: Southcentral Regional Office State of Alaska Dept. of Environmental Conserv. 338 Denali Street Anchorage AK99501 W. J. Laverdure Unocal Oil & Gas Divisio~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Robert T. Anderson District Land Manager Alaska District December 18, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT 5~at~ p.~ ,AlAska NcArthur River Field Application to Drill and Complete TBUS D-43 Gentlemen: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to drill, complete and produce Trading Bay Unit State D-43RD in the Hemlock Oil Rool pursuant to Rule 5, Conservation Order No. 80. The proposed completion of this well will result in additional recovery of Hemlock Rroduction. Your approval of this request will be appreciated. V?~y truly yours, Landman sk CC: C. Case R. Warthen RECEIVED Gas Cons. Commission CHECK LIST FOR NEW WELL PERMITS Comp any Lease & Well ITEM APPROVE DATE (1) Fee (2) Loc (2 thru 8) . (3) Admin 9. (9 thru 12) 10. (10 and 12) ' 12. (13 thru 21) 14. 15. 16. ' 17. 18. 19. 20. 21. (22 thru 26) (6) Add:.~A~_~/m...~..~.~- 22. 23. 24. 25. 26. 27. 2. Is well to be located in a defined pool ............................ 3. Is well located proper distance from property line ................. 4. Is well located proper distance from other wells .... 5. Is sufficient undedicated acreage available in thl; ;;;1 ~i~i~.~ 6. Is well to be deviated and is wellbore plat included ............... 7. Is operator the only affected party ................................ 8. Can permit be approved before ten-day wait ......................... YES NO .. Is the permit fee attached .......................................... Does operator have a bond in force .................................. ~.~ ., Is a conservation order needed ...................................... Is administrative approval needed ......... Is the lease number appropriate . i'' '[[[[~'~[[[[[[[~[['['~ Is conductor string provided ......... Is enough cement used to circulate ;~'con~;;;:';;~';;;~:;;;':::::::::~ "' Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... .'~ _ Will surface casing protect fresh water zones ....................... 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 ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~dg(/) psig Does the choke manifold comply w/API RP-53 (Feb.78).: .............. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: ~.~_.~ ,~~ ~_ I , - - , ~ " / , ' -' ,,, INITIAL GEO. UNIT ON/OFF - POOL CLASS STATUS AREA NO. SHORE , RD4ARKS 0 HO t 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. LIS VE R I ~: IC ATI 0,~.' 'LIS RECEIVrO ~ 011 & Gas Co,~. ~..,,...m~smn Anchora~ LV,P ,OtO'H02 VERIFIC~TI3N LISTINg' ~ REEL HEADER SERVICE NAME :E2IT 3ATE DR [ SIN :. RE:_L NAqE : SD4TINU~TI]N ~ :01 ~REVIO~S REEL : S044ENTS :LIBRarY T~PE e* TAPE HEADER ~-~ SE2WICE NAqE :EDIT DATE : ~$/03/11 ]RI~IN :.00 O0 TAPE NA4E. :1275 CO~TINJATIDN # :01 PREVIOUS T~PE : SOMMENTS :LIbRaRY T~PE ~* :ILE HEADER SERVICE VERSION RAX'[MUM LEqGTH FILE TYPE : PREVIOUS' FILE ~ INFDRMATION ~ECDRDS ~* CONTENTS .~N : WN : RI~ER. FIELD~ T O W ~: g'N SECT: 3Z C O '~ 4: K E N A I STAT': ALASKA CT R ¥: USA JNIT TYPE CATE OOO~ 000 000. OOO ODD 000 O 0 0~0 ~.00 000 000 ~)00 SIZE 020 020 002. 005 ' 006 003, M N E 'M: C O N T E ,4 T-.S 'g N I 'T T Y P E C * T E S I Z E -------- ,m. ,,. m -- ,,,m,.,,,m -- ~.. -- m ~m~, .,,m .,mm ,m. PRES: E ODD ~)00 001 ~:, COMMENTS C D O E 065 065 065 065 0'65 CDDE 065 LV,~ ,010.HOZ VERI~IC~lrI2~ LI~TIN~ PA~E 2 ALASKA COMPUTI~S CENTER ~ CO'qPANY = M~R~THO4.0IL COMPANY WELL = 3-~3 FIELD = MCARTHU:R RIVER FIEL,3 STATE = ~LAS<A JD3 NUVt3ER AT RU~ #1~ DATE LDO: M. DG~E~ ACC: 71329. LgGGED: ~ 2S'JA~-86 CASING = 13.375" ~ 3069..0" TYPE FLJID = LIGN3SULFONATE DEqSITY = 9.5.0 LB!3 vIS"osIrY = ¢5.0 S PM = ~O.Z ~LJID LQSS =' 9oD C3 MATRIX SANDSTDNE BIT- SIEE = ZZ'ZS" TO 9786.0' RM = Z.6O~3 ~ 70..0 DF RMF = 2.350 @ ?O.O DF RMC = 1.9~3 @ 70.0 DF RM ~T BHT -- ~.3~ @ I~Z. DF LV,P ,010.H02 VERiFIC&TID~ LISTIN2 JOB NUMBER AT ACC: 71275 RU~I #2, DATE LD~GED: 13-FEB-86 LDP:. M. DS]EN CASING TYaE FLdIB DE~iSITY VISCOSITY PH ~=L JID LOSS MATRIX SAN3SI'ONE = ).625" B 9839.0' - BIT SI[E = 8.5" TO 111~7.0° = LIGN'3SULFONATE = ~.20 LB/S RM = 1.95D ~ 51.0 DF = ~3.3 S / RMF = 1.813 ~ 59.0 DF = 5.~ C3 RM ~T B~T = .75Z B 168. DF THIS DATA flAS SEEN DEPTH S~IFTED T3 THE DIL ~ee~e~ee~e~e~ SCHLJ'MBERSER LOGS INCLUDED WI'tH T~IS ~GNETIC e ~.JAL INDJCII3~ SPt.ERICALLY F3CUSE) LOS (DIL) -~, 3AT~ AV~ILAB_E: .[1193.0'-TD 385.0.0' LV,.~ OiO.HOZ CERIFIC&TI]I LISTINS PAGE DENSITY COMPENSATED LDS (LDT) C]MPEYS~T-D ~EUTR3N L]G (LDT) ]AT~ AV~ILAB_E: 11193.0, TO 9600.0' ~TUR~L ~MM~ TOOL (NST) D~T~ AV~IL&BLE: [ll~2.0' T3 9800.0' SD~[C (SDT) DAT~ AVAILABLE: 11179o0' TO 9839.0' SD~ DISET&L? S3~IC D~TA INCLJDED ON THIS TAPE -- DTCD.SDr - DELTA T COMPRE$SIDNAL DT-$M. SDT - DELTA T SHEAR LV,~ 010.H02 VERIFIC~TI04 LISTIN~ PAGE TiE NST )~TA 2N TiIS TAPE CONSISTS OF THE REPEAT JP T3 A DEPTH OF 13750.0' aND THE ~EM~INDER IS FRO~ T~E MAIN LOG (RUN TiE K~LM~q FILTER WAS APPLIE3 TO THE qGT 2ATA. T~E DTCD.SDT ~ND THE 2TSM.SDT WERE P~OCESSED PRO~ THE RAW D~T~ BY W~VEF3RM SNAL¥SIS DONE ~T THE CDM~UTING CENTER. THESE CHANNELS 03 NOT~ O~'ERL~¥ TH~.BLJELI~E.. MER$,E POINTS ~OR THE ~IL - 9778.0~ S$~.DIL - 9753.0. ENTRY )LOC<S TYPE SIZE RE3R C~E ENTRY Z 1 66' ~ 1 66 t 9 ¢ 7'3 SO 15 1 66 3 i 66 O DATJM S)ECI~ICArION BLOCKS 4NEM SERVICE SE)V'ICE J'qIT ~PI ~PI API ~PI FILE SIZE SPL~ REPR ID ~E~T: SFL~ 3IL IL3 3IL IL~ )IL SP SG.~ SG~, LOT CALI LOT N'R A T LDT P.N,R.A LOT L'DT mCNL~ LDT PROCESS DR)ER ~OG tYPE CLASS ~3D ~0. FT~ O0 000 O0 0 3~MM_ 00' 220 01 0 3~HM O0 120 66 0 D~MM O0 120 66 O 4~! 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SGR THOR SGR SGR NC.4L SGR TH3R $ G.R ILO SG,) NRta: T~,R SGR ILO SG~ ~C~L .SGR 30.754g ¢2.7930 1.5225 4.063.5~00 q.Z.7~30 3.3~,59 ~,5.1680 50.8367 1.8839 ~.123.2500 4.2898 ~,3. 3867 12.6895 51-5~30 2.5002 2~23.51300 51.5t, 30 50.8242 16.1143 73.8'398 4.2525 1~,68.6875 73'8398 7.9500 58- 9.56'8 12.2129 50'5~30 50' 5~ 8398 3.6?99 159'8' :$',375 5. B 3:98, 5.03.20 $6.5;Z73 19,3543 1-7589 ~627'~500' ½6. 93'0 IL4 CALI RNR~ FCNL CGR UR~N IL4 CALl RNRI~ FC~L: CGR URaN RNR~ FCNL CGm. UR~N ILM RN)~' FC~L CGR. - IL.R CALI C G.R: UR.A~ ILM' 'LI FCNL CG~ URn4 CALI RN~ R FC~L CGR 25.0830 14.7910 1.5¢30 2633.5000 32.6055 1.3848 55.1055 11.1973 1.9210 21¢5.5000 38.2305 1.3917 12. 8926 10.5254 2.7598 874.8125 64.2617 0.9897 8'3770 15.2129 4.8171 304-8906 52.~92 2.9045 22.~580 20,7O8O 5.1765 278- ° 6~06 &1-1:367 1 -,'2784 9-7051 13.&629 3,9006 ~09,6&06 ~1.01t'7 3.3'733 19.¢111 8.712'9 1.8272 2531.5000 61..0117 LVP ,O13.HOZ VER[FIC~TI3q 3TC3 75.0000 DTS~t DEPT 10100.0000 SFLJ SP -3.5291 SGR RH33 2.5120 DRd3 qPtI 19.0~30 PEP ~SS -0.0200 QLS POT~ 1.7578 POT~ 3TC3 67.0000 DT$~ DE~T 10000.0000 SFLJ SP -66.0352 RHJ3 2.~531 ~P~I 15.3320 ~SS -0'~273 ~LS PDT~ 1.6502 POT~ iTC3 80.0000 DEPT 9900.0000 SFLiJ SP ~.~968 SGR ~H3B 2.5959 DR't3 NPHI 25.53:½8 PEP QSS -0.032~ QLS PDT~ 1.9531 POT~ DTCD 96.0000 DTSq OEPT 9B'00.'0000 S. FLJ Sa -202-0.S25 SGR. 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