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Home My WebLink About180-072STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 5''�% :� f -Ta Fes" � tL f;w— �}}— S"(auw'C;E� VE, 2) 16 2019 1. Operations Abandon LJ Plug Perforations ✓ Fracture Stimulate U Pull Tubing Li Operations shutdrWn Li Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ >_rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. CT N2 + Cmt Sqz❑✓ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 180-072 3. Address: 3800 Centerpoint Or, Suite 1400 Anchorage, 6. API Number: AK 99503 50-283-20067-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL00175921ADL0017599IFEDA029656 Beluga River Unit (BRU) 214-35 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Beluga River/ Undefined Gas 11. Present Well Condition Summary: Total Depth measured 6,818 feel Plugs measured N/A feet true vertical 6,000 feet Junk measured 3,931 feet Effective Depth measured 6,818 feet Packer measured 3985;4249;4435 feet true vertical 6,000 feet true vertical 3257;3483;3652 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 97' 30" 97' 97' Surface 410' 20" 410' 410' Intermediate 3,930' 13-3/8" 3,930' 3,124' 3,450psi 1,950psi Production 6,818' 9-5/8" 6,818' 6,000' 5,750psi 3,090psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3.5" 9.2# / K-55 4,456 -MO TVD N/A; N/A N/A Packers and SSSV (type, measured and true vertical depth) 3 Baker FH Pkrs 3,985'MD/3,257'TVD 4,249'MD/3,483'TVD 4,435MD73,652'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: 0 0 0 265 0 Subsequent to operation: 0 500 0 265 80 14. Attachments (required per 20 AAC 25.070.25.o7l, s 25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory[--] Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ✓ WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-162 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcoro.com Authorized Signature: Date: ) b J ti 2 J t 9 Contact Phone: 777-8420 Form 10404 Revised 4/2017 / �-! 1/ Submit Original Only ,4G <r RBDMS .L�A"'JUL 18 2019 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 214-35 CTU 50-283-20067-00-00 1 180-07 6/21/19 1 6/26/19 Daily Operations: 06/21/2019 - Friday PTW, JSA. Mobilize equipment from N pad to D pad. Lay pit liner. Spot in equipment. Spot 2x rain for rent tanks. RU CTU 13. Coil mechanic on location tracking down voltage short from generator to ops cab. Transfer and load N2 into pump truck. 06/22/2019-Saturday PJSM, PTW. Start BOPE test. Test all rams and vales 250/3,500 psi. 24 hr BOPE test witness notification sent 6/21/19 @ 0700 hrs. Witness waived by Jim Regg Via phone call. BOPE test complete. 1 FP indicated on test form. #3 choke manifold valve leaked. Greased and tested good. Pick injector head stab 20' of lubricator. Make up roll on coil connector. Pull test 25k. 1.75" OD coil connector, 1.75" DFCV, 1.75" MBT, 1.75" MBT, 2.6" down jet nozzle. BHA length 9.52'. Stab on well. PT stack. 250/3500 psi. Bleed down . Open well. 0 psi WHP. RIH. Pump 1 bbl/min to fill wellbore. 13 bbls returns to surface. Fluid level was at 1,395' via displacement. Cleaned out to 4,207' getting 1:1's. At 4207' hit sand bridge. Lost all returns. Pick up clean. Wash down to 4,300'. POOH to surface. Pop off well. Break down BHA and lubricator. Rack back injector head. Pressure test coil connector for Cement job run. 250/4500 psi. Rig down and move Cruz crane. Location secure. Waiting for AK-Eline. SLB crews head to Shirleyville to get cementing chemicals and pick up truck. AK-Eline on location. MIRU. Make up Halliburton 3.5" EZ drill CIBP and setting sleeve. Stab on well. PT lubricator 250/3000 psi. RIH. 4,125' cant pass. Target depth 4,230'. POOH to surface. Park in lubricator. Online down 3.5" tubing at 6 bbls/min. caught fluid . Pressure up to 850 psi at 2 bbls/min. Bullhead tubing volume of 40 bbls. RIH with E-line and 3.5" CIBP Tagged at 4,088'. Pulling heaving. Plug is stuck. Call town engineer to discuss. Set plug. Log OOH. Plug is set at 4,115.2'. POOH to surface. Rig up Owen tubing punches. RIH. 4.2' CCL to top shot. 8.8' CCL to bottom shot. Correlate depth. Pu and park CCL at 4,062.8' Shoot tubing punches from 4067'-4070.2' . 18 holes punches at .4" ID. POOH to surface. 0 psi WHP. Fire up fluid pump. Perform injection test into perfs at 4,082'-4,205'..6 bbls/min @ 510 psi. .8 bbls/min @ 640 psi. 1 bbl/min @ 700 psi, 1.5 bbls/min @ 740 psi, 2 bbls/min @ 800 psi. 20 bbls injected. MU 3.5" Halliburton EZ drill cement retainer and setting sleeve. RIH. CCL to top of plug 7.5'. Correlate depth. Park CCL at 4,042.5' . Set cement retainer at 4,050' Top of plug. Bottom of plug 4,052.5'. Pick up and re tag plug. Plug set. POOH to surface. Close master and swab. 0 psi SITP. Rig down AK-Eline. Location walk around complete. SDFN. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 214-35 CTU 50-283-20067-00-00 1 180-07 6/21/19 1 6/26/19 Daily Operations: 06/23/2019-Sunday PTW, JSA. Fire equipment. Pick injector head. Stab 11' lubricator. Make up BHA. 1.75" OD CC, 1.75" x 5' Weight bar, Fluted 1.65" OD centralizer with cement stinger polished bore. Stab on well. PT stack 250/3,500 psi. Open master and swab valve. 0 psi WHP. IA 120 psi. Fill wellbore with 2 bbls. Pressure test tubing to cement retainer at 4,050'. 250 low 2,000 psi high. Bleed down PT. RIH with 1.75" CT and cement retainer. 4,050' tag cement retainer at 5'/min. set 2,500 lbs down. Attempt injection test. Line up pump down CT. Well is fluid packed to surface. Online down CT at 1 bbl/min. Returns up IA to surface indicating we are not stung in. Attempt to sting into cement retainer. Increase rate down CT to 1.5 bbls/min. No increase in Circulation pressure. Should have pressure increase when entering retainer. RIH at different speeds stack down to -10K. POOH to surface to check BHA. At Surface. Inspect BHA. No signs of marks or damage. Add 18' of stingers to make BHA straighter. Straight joints 23' . Total BHA length 27'. Stab on well. Pt stack 250/3,000 psi. RIH. Tag cement retainer top at 4,050'. Attempt injection test. Returns to surface. Not stabbed in. Try walking into retainer with surging pump up and down to straighten coil and pop off ledge into retainer. Pressure up tubing and coil to 1500 psi and then drop pressure to choke when at top of Retainer. No luck stabbing in. Pick up to 5,250 lbs up weight. Line up down back side and pump 5 bbls/min 2,800 psi. attempt to latch no luck. Continue to work pipe and latch. No luck. POOH to surface. Break down BHA. Cut 150' of coil in attempt to change the memory. Make up new BHA. 1.75" external slip connector 2.375" OD. fluted centralizer 2.65" OD. x over, 8' straight joint, x over, cement stinger with 1.65" fluted centralizer. Total BHA length 16'. Two centralizers should help centralize stinger into retainer. Stab on well. PT stack 250/3,000 psi. RIH stack 10k down at 4,050'. Multiple attempts at different speeds and pump rates to stab into cement retainer. NO luck. POOH to surface. At surface. Close master and swab. Pop off well. Cement stinger has blue grease on polished bore. If stabbed in grease would be smeared on polished bore. Break down BHA. Rig back injector head. Install night cap. Location secure. NOTE: Installed Cement stinger into bore of extra cement retainer. Fit was good. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 214-35 CTU 50-283-20067-00-00 180-07 6/21/19 1 6/26/19 Daily Operations: 06/24/2019 - Monday PTW. JSA. Fire equipment. Pick injector head. Make up 2x II'lubricators. Pull test Quadco coil connector external slip style to30k. Make up DFCV, Jars, Disconnect, Motor, 2.65" Convex mill. Stab on well. Function test and listen for motor spinning. Pressure test stack to 250/4,000 psi. Bleed pressure. Open well and RIH. 4,000' WT Check 5,700 lbs up. Slak of weight -250 lbs. Tag top of cement retainer at 4,047' CTMD. Pick up. Come on line with pump @ 1.5 bbls a minute. Establish free spin parameters. 2,500 psi circ pressure. Getting 1:1 returns. Start seeing motor work at 4,046.5' Lost returns for 3-5 minutes when we stalled on rubber element. Milled through plug at 4,048.6' CTMD. Push remainder of plug to 4,100' stack Sk down. Pump 10 bbl flo vis pill around. Chase pill OOH to surface. Tagged up at surface. Pop off well. Break down milling assembly. Make up weight bars and cement ball drop nozzle. Stab on well. PT stack 250/4,000 psi. Perform injection test at 1 bbl/min 800 psi. 2 bbls/ min 850 psi. Cement crew rigged up . Hold tail gate safety meeting. Pump 5 bbls of fresh water ahead down CT. Pressure test cement lines 250/4,000 psi. RIH with CT. Tag top of CIBP at 4,110'. PU to 4,070' below tubing punches. Cement wet at 1500 hrs. CT reel volume 33.8 bbls. Online with cement down coil. Zero coil micro motion when 15.8 density. Pump 14 bbls of 15.8 Glass G cement down CT. Chase with 5 bbls of fresh water. Swap to coil pump. Cement at nozzle 33.8 bbls pumped. close choke, start injecting 34 bbls on counter, cement through tubing punches and washed out sliding sleeve. Pu with coil to 4,058' above sleeve. 42.8 on MM cement at perfs, injection pressure went from 800 psi to 950 psi at 1 bbl/min slow rate to .5 bbls/min. Perform hesitation squeeze with last few bbls. Cement out of coil at 47.8 bbls. Injection or squeeze pressure at end of cement squeeze 1,125 psi. Cement in place at 1600 hrs. Monitor pressure for 30 minutes before POOH. Pressure slowly dropped to 850 psi (original injection pressure). Start POOH with CT maintaining 800-850 psi on squeeze. At surface. Shut in well with 820 psi. Rig back injector head. Install night cap. Both masters and swab valve closed. Well secure. SDFN. Cement needs 24 hours to build 500 psi compressive strength. Cement job was performed to isolate the Sterling A sands from 4,082'- 4,205'. 06/25/2019-Tuesday PJSM, PTW. Fire equipment. Pick injector head. Grab 2x 11' lubricators. Make up BHA. CC, DFCV, Jar, circ sub, disconnect, Motor and 1.65" Parana mill. Circ sub drifted and confirmed 1/2" ball. Stab on well. PT stack 250/4,000 psi. Cement has setup for 24 hrs. Cement sample in ops cab is hard. Open Swab and master. 0 psi WHP. Pressure test cement job to 500 psi. Good solid flat line. RIH tag TOC at 4,060'. Pick up establish free spin 1.38 bbls/min 2,115 psi. Mill from ,4060' to 4,070'. Pump bottoms up. Park coil. Close choke and perform another pressure test against cement job. 625 psi. Hold for 10 minutes. Good PT. Drop circ sub ball and pump to seat. 1800 psi to shear pins. Circ sub open . Online with N2 at 1000 scf/min. POOH to 3,563'. Unload fluid to surface RIH tag 4,072' continue to unload fluid 58 bbls returned. All N2 at return tank. Close choke POOH and start pressuring up to 1,200 psi. 106,000 SCF pumped.1138 gallons. 1,800 gallons remain. Tagged up at surface. Shut in well with 1,274 psi SITP. Rig down SLB CTU 13. Leave riser and p sub with return iron rigged up to choke and return tank. SLB rigged down equipment staged on edge of pad. Pollard E-line in Beluga. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 214-35 CTU 50-283-20067-00-00 1 180-07 1 6/21/19 1 6/26/19 Daily Operations: 06/26/2019 -Wednesday RU Pollard E-line. Waiting on tools from shop.;Make up Tools and 23' gun. Stab on well. PT 250/3,500 psi. Wellhead pressure 1,200 psi from CTU N2. RIH. CCL to top shot 12'. Log and correlate depth. Park at 4,009' CCL depth. Shoot 2.375" guns loaded 6 spf from 4,021'-4,044'. (23') Shoot guns. POOH to surface. Guns dry. Bull nose plug pulled dry as well. WHP dropping from 1200 to 865 psi.;Make up 4' gun and RIH. Log strip. Send log to town. On depth. Shoot 4' gun from 4,012'-4,016'. POOH to surface. Shut in well. 851 psi SITP. Guns dry. Bull nose plug dry. Rig down AK E-line. K cora Alae4o.I.I,C RKBto MSL=95' RKBto GL=17.9' 13-3/8" 2 Squeeze @ 3 3,992' 4 51 Tubing Punches_1 @ 4,067'-4,072' 6 6/22/19 7' TOC @ 4,080' 8 ( l 9 10} 11 1 12 pn, 1 P2/P3/P4� P5 1 SCHEMATIC Beluga River Unit Well: BRU 214-35 Last Completed: 3/7/1981 PTD: 180-072 API: 50-283-20067-00 DFTAI I Size Type Uri Grade Conn ID 2.75 30" Conductor 133# Cond. WELD 29" 20" Surface 94# K-55 Butt 19.124" 5 13-3/8" Intermediate 68#/72# K-55 Butt 12.347" M4,664- 9-5/8" Production Casing 40/43.5# N-80 Butt 8.755" 2.867 9-5/8" Production Casing -�7# N-80 Butt 8.681" 4,435 2-3/8" Heater String 4.7# N-80 EUE8rd 1.995" TUBING DETAILS 3.5" Production String 9,2# K-55 Armco 2.992" 4,456' Seal-lok Min I.D. p1 Heater string: 1.995?" JEWELRY DETAIL Production String: 2.71" Production String Sterling Sands 21 A B [.] Beluga Sands I P6 8,TD=6,818' TVD 'Moo' PBTD = 6,818' ED=4,636' END=3,840' Max Angle = 47 deg @ 3,017' ID. Depth MD (ft.) ID (in.) I Description 1 111 2.75 Baker'F' Nipple 2 3,981 2.813 Otis'XA'Sliding Sleeve 3 3,985 2.867 Baker'FH' Packer 4 3,998 2.75 Baker'F' Nipple 5 4,059 2.813 Otix'XA' Sliding Sleeve Open/cut out 8/93 6 4,110 Open CIBP w/40' cement(TOC4,070') 06/25/19 7 4,213 2.9 Brown'CC'Safety joint 8 4,249 2.867 Baker 'FH' Packer 9 4,374 2.9 Brown'CC'Safetyjoint 19 4,435 2.867 Baker'FH'Packer 11 4,443 275 Baker'F'Nipple w/ Plug. WARNING: Nipple will grab tools going up & be difficult to set a plug in going down. 9/1/93 12 4,456 2.375 i Shear Sub Heater HA 142' 1.995" Baker'S' Nipple Pos 1 Plutrc/rich - ID. Depth MD (ft.) ID (in.) Description P3 3,931 Casing Hole Opener Bull Nose P2 4,608 - 2 Baker'F'Plug 9/6/1993 P3 4,609 - Two 3500 PSI Pressure Bombs & Knuckle Joint 3/1/81 P4 4,610 - 26 Ft. of 2-5/8" Dresser Atlas 2-5/8" Perf Guns 2/27/81 PS 4,665 - 9-5/8" Stage Collar P6 6,730 - Float Collar PFRFCIRATHIN nFTAII Sands Top (MD) Btm (MD) Top (ND) Btm (TVD) SPF Phase Date Status Sqz 3,992' 3,992' 3,262' 3,262' 4 2/1/1981 Sqz Sterling A-1 4,012' 4,016' 3,279' 3,282' 4 6/26/2019 Open Sterling A-2 4,021' 4,044' 3,286' 3,305' 23 6/26/2019 Open Sterling A 4,082' 4,205' 3,337' 3,443' 4 34 2/23/1981 Isolated Sqz 4,284' 4,284' 3,514' 3,514' 4 2/1/1981 Sqz Sterling 4,327' 4,334' 3,554' 3,560' 4 28 2/20/1981 DST#9 Sterling B 4,380' 4,390' 3,602' 3,611' 4 28 2/16/1981 DST#7 Sqz 4,395' 4,395' 3,616' 3,616' 4 2/1/1981 Sqz Sterling C 4,484' 4,504' 3,835' 3,995' 4 28 2/1/1981 Plug Sqz 4,590' 4,590' 3,795' 3,795' 4 1/1/1981 Sqz Sterling D 4,631' 4,645' 3,835' 3,995' 4 21 2/17/1981 DST#6 Sqz 4,650' 4,650' 3,854' 3,854' 4 1/1/1981 Sqz Sterling 4,684' 4,700' 3,886' 3,901' 4 21 2/19/1981 DST#8 Sqz 4,798' 4,798' 3,995' 3,995' 4 1/1/1981 Sqz Sqz 4,930' 4,930' 4,123' 4,123' 4 1/11/1981 DST#5 Beluga E 5,175' 5,182' 4,363' 4,370' 4 14 2/1/1981 DST #4 Beluga F 5,408' 5,418' 4,593' 4,603' 4 9 1 2/10/1981 DST #4 BelugaG 5,861' 5,870' 5,043'5,053' 8 5 2/9/1981 DST #3 Beluga G 6,006' 6,026' 4,197' 5,208' 4 5 2/6/1981 DST #2 B elugaH 6,530' 6,547' 5,711' 5,729' 4 2 1/28/1981 DST#1 Updated by DMA 07-15-19 THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beluga River Field, Undefined Gas Pool, BRU 214-35 Permit to Drill Number: 180-072 Sundry Number: 319-162 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w ww. a o g c c. a l o s k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner rd DATED this day of April, 2019. RBDMS-T' APR 0 4 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 DECEIVED APR 0 2 2019 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations [0 ' Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate 21. Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ L Plug for Redrill El Perforate New Pool ElRe-enterSusp Well El Alter (�' 'T AI[er Casing IV .�- ('.Mr Rr 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: 5QZ Hilcorp Alaska, LLC Exploratory ❑ Development [a ' Stratigraphic ❑ Service ❑ 180-072 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-283-20067-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 168 Will planned perforations require a spacing exception? Yes ❑ No ❑� Beluga River Unit (BRU) 214-35 9. Property Designation (Lease Number):. 10. Field/Pool(s): • ADL00175921ADL0017599IFEDA029656 Beluga River! Undefined Gas - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (it): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,818' 6,000' - 6,818' 6,000' -978 psi NA 3,931' Casing Length Size MD TVD Burst Collapse Structural Conductor 9T 30" 97' 97' Surface 410' 20" 410' 410' Intermediate 3,930' 13-3/8" 3,930' 3,214' 3,450psi 1,950psi Production 6,818' 9-5/8" 6,818' 6,000' 5,750psi 3,090psi - Liner Perforation Depth MD (ft): Perforation Depth TVD (it): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3.5" 9.2# / K-55 4,456' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (it): 3 Baker FH Pkrs; N/A 3,985'MD/3,25TTVD; 4,249MD/3,483'TVD; 4,435MD'/3,652'TVD; N/A 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: April 27, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@bllCeta.LOm Contact Phone: 777-8420 1 Authorized Signatur . Date: r / 2-,. COMMIbSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -hf Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ t, pp 1 q ``` pp Spacing Exception Required? Yes ❑ No Subsequent Form Required: / o •� Q RBDMS-. APR 0 4 2019 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: �-- VZ i/- p •ove 0 f" / 1 %/!/�//� Submit F m 10-403 Revised 4/ 017 / Approved applicatio i 1 o he date of approval. Attachments / -/ Attachments in Du icate //Z /9 YL U Ilik.m Alaska, LL, Well Prognosis Well: BRU 214-35 Date: 4/1/2019 Well Name: BRU 214-35 API Number: 50-283-10027-00 Current Status: Gas Well Leg: N/A Estimated Start Date: April 27, 2019 Rig: N/A Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 162-018 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Bottom Hole Pressure: —650 psi @ 3,279 TVD (4,012' MD) (Based on offset production.) Max. Potential Surface Pressure: —978 psi (Based on 0.1 gas gradient to surface) Brief Well Summary BRU 214-35 was originally drilled in 1981 as a 3-1/2" single string Sterling completion. The well was directionally drilled under the inlet to a bottom -hole target in the Beluga H - with all zones present Poor cement bond initiated 6 squeezes in order to DST the zones, 9 total DST's were performed and all 9 subsequently isolated. BRU 214-35 was then completed in the Sterling lower A and C sands, separated with packers and sleeves. The C sands were isolated with a tbg plug in June 1984 and the A sands produced from 6/24/1984 to 9/22/1993. The A sands produced gas at 8-5 MMCFD with little to no water or sand. The plug isolating the Sterling C sands was pulled in June of 1993, to produce the C and to add perfs. The perfs were not added due to production of water and sand, which filled the casing. The sliding sleeve @ 4059' MD appeared to be cut out. A plug was reset to isolate the Sterling C interval and the A produced until 1999 when the well could not sustain flow into the 900# system (without compression). The well cum'd just over 15 BCF from the Sterling A interval. In October of 2018 an attempt was made to shut off the Sterling A sand with calcium carbonate and test the Sterling Al and A2 sands. Shutting off the Sterling A sand was initially successful, but broke down when the fluid level was swabbed down to get the correct underbalance to perforate Al and A2.. The purpose of this Sundry is to utilize coil tubing to P&A the Sterling A, B and C sands and then perforate the Sterling Al and A2. Well was SI until Coil could get there to pump cement. Workover Rig Procedure: 1. MIRU CTU. Test BOPE to 3,500 psi. 2. PU RIH W/ let nozzle to top of fill (Est. TOF @ 4,067'). Jet fill to clean out well to 4,230'. PU and circ clean. Note Nitrogen may be needed to lift well. POOH W/ Coil. 3. RU E -line. Pressure test lubricator to 3,500 psi high, 250 low. 4. PU, RIH W/EZ Drill BP to 4,230'. Set Same. /5. PU tubing punches, RIH and punch tubing at 4,200 —4204', 4,143-4,147', and 4,082-4086'. POOH with E -line. 6. PU EZ Drill Cement Retainer and RIH to 4,065'. Set same. Establish PIR. 7. RU Cementers. Perform Suicide Squeeze. Pump 10.3 bbls. of Class G 15.8 PPG cement. Un -sting from retainer. 8. PU and clean out coil tubing. Stand back Coil. WOC. R 110.e y Afeeku, LU Well Prognosis Well: BRU 214-35 Date: 4/1/2019 9. RU SL. RIH and tag top of cement. If Cement is below 4049', go to step #11. Otherwise, go to step 10. 10. RU Coil Tubing. PU motor and bit. C/O cement to 4,049'. PU and circ. Hole clean. 11. With CT in the well, RU Nitrogen and blow well dry. Leave 1,100 psi on tubing. RDMO CTU. 12. RU E -line. PU Perfguns. RIH and Perforate the following two intervals through tubing: Zone Sands Top (MD) Btm (MD) FT Sterling A-1 ±4,012' ±4,016' 4 Sterling A-2 ±4,021' ±4,044' 23 a. Intervals will be shot one at a time starting with the deeper zone first. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf interval. d. Correlate using proposed Gamma/CCL. e. Conservation Order 168 governs the addition of the Sterling perforations in this well bore. 13. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. CT BOP Stack 4. Standard Nitrogen Procedure S. Coil Tubing Fluid Flow Beluga River Unit Well: BRU 214-35 SCHEMATIC PTD:Last 80 - Completed: 3/7/1981 Hitcuru A1.eka, iJ.0 API: 50-283-20067-00 RKBto MSL=95' RKBto GL=17.9' CASING DETAIL P6 9-5-8" A TD 6,818' TVD =6,000' PBTD = 6,818' ED 4,636' END=3,840' Max Angle = 47 deg @ 3,017' Size Type WT Grade Conn ID Btm 30" Conductor 133# Cond. WELD 29" 97' 20" Surface 94# K-55 Butt 19.124" 410' 13-3/8" Intermediate 68#/72# K-55 Butt 12.347" 3,930- 9-5/81, Production Casing 40/43.5# N-80 Butt 8.755" 4,664' 9-5/8" Production Casing 47# N-80 Butt 8.681" 6,818' 2-3/8" Heater String 4.7# N-80 EUE 8rd 1.995" 2,031- 1 3.5" I Production String I 9.2# I K-55 I Armco I 2.992" I 4,456' I Min I.D. Pl Heater string: 1.9957" Production String: 2.71" Sterling Sands JEWELRY DETAIL Production String ID. Depth MD (ft.) ID (in.) Description 1 111 2.75 Baker'F'Ni ple 2 3,981 2.813 Otis'XA'Sliding Sleeve 3 3,985 2.867 Baker'FH' Packer 4 3,998 2.75 Baker'F' Nipple 5 4,059 2.813 Otix'KA' Sliding Sleeve Open/cut out 8/93 6 4,213 2.9 Brown'CC'Safety joint 7 4,249 2.867 Baker'FH' Packer 8 4,374 1 2.9 Brown'CC'Safety joint 9 4,435 2.867 Baker'FH' Packer 10 4,443 2.75 Baker'F' Nipple w/ Plug. WARNING: Nipple will grab tools going up & be difficult to set a plug in going down. 9/1/93 11 4,456 2.375 Shear Sub Heater HA 142' 1.995" 1 Baker'S' Nipple Pos 1 Plugs/Fish ID. Depth MD (ft.) ID (in.) Description PS 3,931 - Casing Hole Opener Bull Nose P2 4,608 2 Baker'F' Plug 9/6/1993 P3 4,609 Two 3500 PSI Pressure Bombs & Knuckle Joint 3/1/81 P4 4,610 26 Ft. of 2-5/8" Dresser Atlas 2-5/8" Perf Guns 2/27/81 P5 4,665 - 9-5/8" Stage Collar P6 6,730 Float Collar PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Phase Date Status Sqz 3,992' 3,992' 3,262' 3,262' 4 2/1/1981 Sqz Sterling A 4,082' 4,205' 3,337' 3,443' 4 34 2/23/1981 Open Sqz 4,284' 4,284' 3,514' 3,514' 4 2/1/1981 Sqz Sterling B 4,327' 4,334' 3,554' 3,560' 4 28 2/20/1981 DST#9 Sterling B 4,380' 4,390' 3,602' 3,611' 4 28 2/16/1981 DST#7 Sqz 4,395' 4,395' 3,616' 3,616' 4 2/1/1981 Sqz Sterling C 4,484' 4,504' 3,835' 3,995' 4 28 2/1/1981 Plug Sqz 4,590' 4,590' 3,795' 3,795' 4 1/1/1981 Sqz Sterling D 4,631' 4,645' 3,835' 3,995' 1 4 21 2/17/1981 DST #6 Sqz 4,650' 4,650' 3,854' 3,854' 4 1/1/1981 Sqz Sterling 4,684' 4,700' 3,886' 3,901' 4 21 2/19/1981 DST#8 Sqz 4,798' 4,798' 3,995' 3,995' 4 1/1/1981 Sqz Sqz 4,930' 4,930' 4,123' 4,123' 4 1/11/1981 DST#5 Beluga E 5,175' 5,182' 4,363' 4,370' 4 14 2/1/1981 DST #4 Beluga F 5,408' 5,418' 4,593' 4,603' 4 9 2/10/1981 DST #4 Beluga G 5,861' 5,870' 5,043' 5,053' 8 5 2/9/1981 DST#3 Beluga G 6,006' 6,026' 4,197' 5,208' 4 5 2/6/1981 DST#2 Beluga H 6,530' 6,547' 5,711' 5,729' 4 2 1/28/1981 DST#1 Updated by DMA 09-19-18 H EGlcorP Alaska, LLC PROPOSED SCHEMATIC RKB to MSL 95' RKB to GL=1 'r 1 HA 20" h 13-3/8" 2 Squeeze 3 .59 @ 3,992' TOC @ 4,080' 5 Sas, Tubing 6 Punches @ +- t4082-4086 7�' t4143-4147 f. 14200-4204 " 8 9 10 11 P2/P3/P4,' P5 Beluga River Unit Well: BRU 214-35 Last Completed: 3/7/1981 PTD: 180-072 API: 50-283-20067-00 CASING DETAIL Size Type WT Grade Conn ID Btm 30" Conductor 133# Cord. WELD 29" 97' 20" Surface 94# K-55 Butt 19.124" 410' 13-3/8" Intermediate 68#/72# K-55 Butt 12.347" 3;930' 9-5/8" Production Casing 40/43.5# N-80 Butt 8.755" 4,664' 9-5/8" Production Casing 47# N-80 Butt 8.681" 6,818' 2-3/8" Heater String 4.7# N-80 EUE 8rd 1.995" 2,031' TUBING DETAILS 3.5" Production String 9.2# K-55 ArmcoSeal-lok 2.992" 4,456' Min I.D. pl Heater string: 1.9957" JEWELRY DETAIL Production String: 2.71' Production String Sterling A-1 Sands A-2 r � 3-�o P6 9'5-8" TD=6,818' TVD=6,000' PBTD = 6,818' ED=4,636' END=3,840' Max Angle = 47 deg @ 3,017' C Beluga Sands E F G G H ID. Depth MD (ft.) ID (In.) I Description 1 111 2.75 Baker'F' Nipple 2 3,981 2.813 Otis'XA' Sliding Sleeve 3 3,985 2.867 Baker'FH' Packer 4 3,998 2.75 Baker'F' Nipple 5 4,059 2.813 Otix'XA' Sliding Sleeve Open/cut out 8/93 5a ±4,065 Proposed Cement Retainer w/±16' cement (TOC±4049') 6 4,213 2.9 Brown 'CC' Safety joint 6a ±4,230 TBD CIBP 7 4,249 2.867 Baker'FH' Packer 8 4,374 2.9 Brown'CC'Safety joint 9 4,435 2.867 Baker'FH' Packer 10 4,443 275 Baker'F' Nipple w/ Plug. WARNING: Nipple will grab tools going up & be difficult to set a plug in going down. 9/1/93 11 4,456 2.375 1 Shear Sub ID. Depth MD (ft.) ID (in.) Description P3 3,931 - Casing Hole Opener Bull Nose P2 4,608 - 2 Baker'F' Plug 9/6/1993 P3 4,609 - Two 3500 PSI Pressure Bombs & Knuckle Joint 3/1/81 P4 4,610 - 26 Ft. of 2-5/8" Dresser Atlas 2-5/8" Perf Guns 2/27/81 P5 4,665 - 9-5/8" Stage Collar P6 6,730 Float Collar PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Phase Date Status Sqz 3,992' 3;992' 3,262' 3,262' 2/1/1981 Sqz Sterling A-1 ±4,012' ±4,016' ±3,279' ±3,282' 4 TBD Proposed Sterling A-2 ±4,021' ±4,044' ±3,286' ±3,305' 23 TBD Proposed Sterling A 4,082' 4,205' 3,337' 3,443' 4 34 2/23/1981 Open Sqz 4,284' 4,284' 3,514' 3,514' 4 2/1/1981 Sqz Sterling B 4,327' 4,334' 3,554' 3,560' 4 28 2/20/1981 DST #9 Sterling 4,380' 4,390' 3,602' 3,611' 4 28 2/16/1981 DST#7 Sqz 4,395' 4,395' 3,616' 3,616' 4 2/1/1981 Sqz Sterling C 4,484' 4,504' 3,835' 3,995' 4 28 2/1/1981 Plug Sqz 4,590' 4,590' 3,795' 3,795' 4 1/1/1981 Sqz Sterling D 4,631' 4,645' 3,835' 3,995' 4 21 2/17/1981 DST #6 Sqz 4,650' 4,650' 3,854' 3,854' 4 1/1/1981 Sqz Sterling D 4,684' 4,700' 3,886' 3,901' 4 21 2/19/1981 DST#8 Sqz 4,798' 4,798' 3,995' 3,995' 4 1/1/1981 Sqz Sqz 4,930' 4,930' 4,123' 4,123' 4 1/11/1981 DST#5 Beluga E 5,175' 5,182' 4,363' 4,370' 4 14 2/1/1981 DST #4 Beluga F 5,408' 5,418' 4,593' 4,603' 4 9 2/10/1981 DST #4 Beluga G 5,861' 5,870' 5,043' 5,053' 8 5 2/9/1981 1 DST #3 Beluga G 6,006' 6,026' 4,197' 5,208' 4 5 2/6/1981 DST #2 Beluga H 6,530' 6,547' 5,711' 5,729' 4 2 1/28/1981 DST #1 Updated by DMA 04-01-19 H Ilaemp kh- .- H.( Beluga River BRU 214-35 3/21/2019 ailed Tubing HR580 Injector Head & Gooseneck Weight= 12,850 lbs 4-1116" 10K Comenfional Stripper SK C062 Lubricator SK C062 x 4-1116" 10K Flange 4-1116" 10K Combi BOP Tap Set RIiM/Shear Se.dSer Pi asflp 4.1116" 1 OK Flow Cross Manual 2X2 Valve 1: 2" 15M x 2-1/16" IOK Rarge Manual 2x2 Vs vet: 2-1/16" 10K x 2-1/16" 1OK Range Manual2x2 Valve32-1/16" 10K x2-1/16" 10K Marge Manuel 2x2 Velve4:2" 1502 x 2-1/16" 10K RaMe 4-1116" 10K x Wellhead Adapter Flange Wellhead STANDARD WELL PROCEDURE I lilcorp Alaska, HA: NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 30.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 Forward N2 Jetting (Returns up Annulus) 00 Coiled Tubing Und ,y — i�'Ix_ to rmdudlan NC 0 0 NC o e Skid N3 Pumping Unif Opn—Top Tank w/ Diffuser a MLLEO 1p Bix6 uWl Ni v,rT c ILO. SIIINnTL r � 10,000,000 1,000,000 C O G 100,000 LL V O N 10,000 f0 0 O O N Rf d ti 1,000 V � 7 V C m 100 N 0 0 t 10 HILCORP ALASKA LLC, BELUGA RIV UNIT 214-35 (180-072) BELUGA RIVER, UNDEFINED GAS Monthly Production Rates 10,000,000 W m 1,000,000 fD0 0 O 100,000 0 7 S 10,000 0 1 W d 1 1,000 u CM G d M 100 Z m Z 0 O K 10 S 1 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 --. Produced Gas (MCFM) r GOR � Produced Water (BOPM) t Produced Oil (BOPM) SPREADSHEET _Prod -I nject_Curves_W ell_Gas_V120_1800720_BRU_214-35_20190402.XISX 4/2/2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED APR 0 2 2019 1. Operations Abandon LJ Plug Perforations Ll Fracture Stimulate LJ Pull Tubing L Operations shutd6*n Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Pfogvm ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Water Shut-off ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑✓ Exploratory ❑ Stratigraphic❑ Service ❑ 180-072 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-283-20067-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL00175921ADL0017599IFEDA029656 Beluga River Unit (BRU 214-35) 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Beluga River/ Undefined Gas 11. Present Well Condition Summary: Total Depth measured 6,818 feet Plugs measured N/A feet true vertical 6,000 feet Junk measured 3,931 feet Effective Depth measured 6,818 feet Packer measured 3985;4249;4435 feet true vertical 6,000 feet true vertical 3257; 3483; 3652 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 97' 30" 97' 97' Surface 410' 20" 410' 410' Intermediate 3,930' 13-3/8" 3,930' 3,124' 3,450psi 1,950psi Production 6,818' 9-5/8" 6,818' 6,000' 5,750psi 3,090psi Liner Perforation depth Measured depth See Attached Schematic CAC'41 ` True Vertical depth See Attached Schematic ! e� f ,)✓p l Tubing (size, grade, measured and true vertical depth) 3.5" 9.2# / K-55 4,456'MD TVD N/A; NIA N/A Packers and SSSV (type, measured and true vertical depth) 3 Baker FH Pkrs 3,985'MD/3,257'ND 4,249'MD/3,483'TVD 4,435MD'/3,652TVD 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 -Md Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 265 0 Subsequent to operation: 1 0 0 0 265 80 14. Attachments (required Per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory❑ Development0 Service ❑ Stmtigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil LJ Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-416 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerfdhilcom.com Authorized Signature: DateContact Phone: 777-8420 Form 10-404 Revised 412017 / O T%Sii 0106DMSA' APR 0 2 2019 Submit Original Only 4-1 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 214-35 50-283-20067-00-00 180-07 10/6/18 1 3/28/19 Daily Operations: 10/06/2018 -Saturday Arrive at Otter Hanger. Travel to West Side after stopping at Drift River. Arrive Beluga. Get Sundry paperwork ready and walk out location. Barge unloaded. Check equipment and verify everything made it. 10/07/2018 -Sunday Fire up hot oil truck at Freeman's barge landing. Mobilize to well site. Purpose of job is to pump shut off material out of the sliding sleeve and inot the perforations from 4,082'-4,205'(123') to shut off the water flow. If successful we will then swab down hydrostatic column and perforate the Al and A2 interval and attempt to flow well. RU hot oil truck, data acquisition, load pallets with baroid chemicals and install on top of truck. RU mix hopper and hose to c pump end. Having issues with the SSV not operating properly. Production working on a solution. WHP 0 psi. Fill front compartment of hot oil truck with 18 bbls of fresh water. PT lines 250/3,500 psi. Good pressure test. Calibrate tank volume. Bullhead 18 bbls down well to check tank volume vs. totalizer, caught fluid at 14.7 bbls. 3.5" tubing was void down to 1,689.03'. Perform injection test. 1.5 bbls/min @ 780 WHP, drop gear. 1 bbl/min WHP 720 psi injection rate and pressure. Offline with pump. Close down hole 8 bbls pumped for injection. 1 bbl/min @ 800 psi. After shutting down from injection test WHP of 800 psi dropped to 0 psi in seconds. Fill front tank compartment with 15 bbls of fresh water. Start mixing CACI Calcium Carbonate pill. Checking viscosity with Vis funnel after every product change. Mix sequence and procedure: 1.5 ppb BARAZAN D PLUS (xanthan gel) = 22.5 (1sx). 2.0 ppb DEXTRID LET = 30 lbs (1sx). 30 ppb BARACARB 5 = 450 lbs (9 sxs). 30 ppb BARACARB 25= 450 lbs (9sxs). 10 ppb BARACARB 50= 150 lbs (3 sxs). Final viscosity before pumping down hole was 58 visc. Calcium Carbonate 15 bbl pill mixed and ready. Line up and pump down hole on the fly. 0 psi WHP pump 7.3 bbls at 1.5 bbls/min before catching fluid WHP climed 800 psi. drop rate to 1 bbl/min. 15 bbl pill pumped swapped to water. 35.7 bbls pill at sleeve. 41 bbls pill at perfs. 53 bbls pumped. Shut down. 3 bbls shy of all pill being pushed into formation as per stroke counter. 16:10 hrs shut down pump. WHP dropped from 800 psi to 236 psi after 20 minutes. Previous injection test resulted in WHP dropping off within seconds of shutting down pump. Looks like pill may be working. SDFN to give pill time to setup. Plan for AM will be to check WHP. Then pump at slow rate to catch fluid to see how much drop in hydrostatic. Once fluid packed attempt stepped pressure test of Calcium Carbonate pill. NOTE: while shutdown for 1 hr to mix pill it took 7.3 bbls to catch fluid. Fluid level dropped 832' in one hour. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 214-35 50-283-20067-00-00 1 180-07 10/6/18 1 3/28/19 Daily Operations: 10/08/2018 - Monday Finished safety meeting with Pollard E-line crews on BRU 214-26. Arrive at hot oil truck. Fire equipment. Check WHP 0 psi. Pump to catch fluid. 8.7 bbls pumped fluid at surface. Fluid level 991.8' after 15 hrs. Shut in pressure on well 310 psi. Dropped to 160 psi after 5 minutes. Head back to BRU 214-26 to pull HES EVO trieve plug and WTF ISO plug. Load hot oil truck with 15 bbls of fresh water. 65°F. Mix Xanthan Gum (barazan D plus) slowly for 1 hour. Keep circulating tank to let Gel thicken. Good funnel visc of 55. Start adding rest of recipe. Mix sequence and procedure: 1.5 ppb BARAZAN D PLUS (xanthan gel) = 22.5 (1sx). 2.0 ppb DEXTRID LET = 30 lbs (1sx). 30 ppb BARACARB 5 = 450 lbs (9 sxs). 30 ppb BARACARB 25= 450 lbs (9sxs). 10 ppb BARACARB 50 = 150 lbs Online with 15 bbl Calcium Carbonate pill. 1 bbl/min 978 psi. Shut down pump. Swap to produced water. Pump at 1 bbl/min pressure maintaining 850-900 psi. 41 bbls pumped pill is at perfs. 53 bbls pumped shut down. 12 out of 15 bbls of Carbonate pill injected into formation. No increase in wellhead pressure noticed. Shut down pump close wing valve. Monitor WHP. SITP 580 psi @ 1600 hrs. Leave acquisition on to monitor and record WHP. Head back to Slick line unit at 214-26. Arrive back at BRU 214-35. Wellhead was showing -30 psi. Shut down acquisition. 10/09/2018-Tuesday Fill vac truck with 88 bbls of water. Load pallet with chemicals and securely place on top of hot oil truck. Fill vac truck with 15 bbls of water. Circulate triplex back to tank and c pump up to mix hopper. Start mixing Xanthan Gum. Continue to circulate gel to get proper viscosity. 587 bbls circulated through pump while mixing gel. Start adding LCM (loss circulation material). 1.5 ppb BARAZAN D PLUS=22.5 (1SX). 2.0 ppb DEXTRID LT= 30 lbs (1sx). 30 ppb Baracarb 5= 450 lbs (9sx). 30 ppb Baracarb 25= 450 lbs (9sx). 10 ppb baracarb 50= 150 lbs (3sx). Initial WHP 0 psi. Online with 15 bbl Calcium Carbonate pill. Pumped 8 bbls before catching fluid. Fluid level at 912'. Consistent with last 3 pills. Attempt to keep pressure below 650 psi. Pump at min rate .2 bbls/min. Have to increase rate for truck to continue to run 720 psi .5 bbls/min. 15 bbl pill pumped in well. Fill hot oil truck tank with 23 bbls to clean up. Pump pill to tubing sleeve 4,056'. Pressure increased to 786 psi. Drop rate to .2-.3 bbls/min. Pill at perfs. 2 bbls into perfs pressure dropped from 778 psi to 760 psi. Instructed to shut down pumping and monitor wellhead pressure. 760 psi SITP. Close wing valve. After 5 minutes pressure dropped consistently from 760 psi to 630 psi. After 15 minutes pressure at 494 psi. Continue to let acquisition system record WHP. 1,700 hrs pressure was at 120 psi. 2,000 hrs pressure was at 0 psi. Shut down acquisition to pull graph. Secure location. Shut down for night. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 214-35 50-283-20067-00-00 1 180-07 10/6/18 1 3/28/19 Daily Operations: 10/10/2018- Wednesday 0 psi WHP. Online with produced water down tubing at 1 bbl/min, catch fluid after 1.5 bbls pumped. Highest fluid level yet. Fluid level at 171'. Walk WHP up to 600 psi. shut in and monitor. 450 psi to 240 psi after 30 minutes. 570 psi to 340 psi after 30 minutes. 590 psi to 374 psi after 30 minutes. Prep for slick line. Rig down hot oil truck. Move to barge landing. Spot containment and rig up return tank and 1502 iron for swabbing. T off tank and run iron to adjacent well house. RU Pollard SL with .125" wire. RIH with 3.5" swab cups. Swab fluid down to 2,038'KB, then get a fluid tag at 1,798'KB, fluid rises to 1,668'KB, relay information to town. Calcium carbonate pill not working. Plan forward is to pull pack off plug. RIH with equalizing prong to 4,067' . POOH with kobe marks on prong. RIH with 3" GS to 4,064' KB. Pull A stop OOH. RIH with same to 4,065' KB, pull plug. hung up in F nipple at 3,998'. Work tool string pull free. OOH no element on pack off plug. RIH with 3" GS to 4,065'. Latch and Pull AD2 stop. At surface. Shut in well. Rig down Pollard SL unit. Turn in permit and arrive at camp. 11/07/2018- Wednesday Need Coil unit to Cement well. 12/05/2018 - Wednesday Review Coil Tubing Availability. 01/03/2019 -Thursday Waiting on weather to get coil to the West Side. 01/31/2019 - Thursday WOW. Coil did go to the Slope. 02/28/2019 -Thursday WOW. Waiting on Coil. 03/28/2019 -Thursday Waiting on Coil to Return form the slope. corp Alaska. I.I.0 K - RKBto MSL=95' RKBto GL= 13-3/8" 1 L.-+Iiiiiiiii MHA 2 Squeeze 3� @ 3,992' 4 TOC @ 4,080' 5 6: 7r 8' 9' 10�11 P2/P3/P4PS ! _. r - P6 45-8" TD=6,818' TVD =6,000' PBTD = 6,818' ED=4,636' END=3,840' Max Angle = 47 deg @ 3,017' C Beluga River Unit Well: BRU 214-35 Last SCHEMATIC PTD: 180-072 Completed: 3/7/1981 API: 50-283-20067-00 CASING DETAIL Size Type WT Grade Conn ID Btm 30" Conductor 133# Cord. WELD 29" 97' 20" Surface 94# K-55 Butt 19.124" 410' 13-3/8" Intermediate 68#/72# K-55 Butt 12.347" 3,930' 9-5/8" Production Casing 40/43.5# N-80 Butt 8.755" 4,664- 9-5/81, Production Casing 47# N-80 Butt 8.681" 6,818' 2-3/8" Heater String 4.7# N-80 EUE 8rd 1.995" 2,031' 0 Beluga Sands F ID. Depth MD (ft.) TUBING DETAILS Description 1 3.5" Production String 9.2# K-55 Armco Seal-lok 219 4,456' Min I.D. 3,985 2.867 Baker 'FH' Packer pl Heater string: 1.995?" 3,998 JEWELRY DETAIL Baker'F' Nipple Production String: 2.71" 4,059 Production String Dtix'XA'Sliding Sleeve Open/cut out 8/93 6 4,213 2.9 Brown'CC'Safetyjoint 7 Sterling Sands 2.867 Baker'FH' Packer 8 4,374 0 Beluga Sands F ID. Depth MD (ft.) ID (in.) Description 1 111 2.75 Baker'F' Nipple 2 3,981 2.813 Otis'XA'Sliding Sleeve 3 3,985 2.867 Baker 'FH' Packer 4 3,998 2.75 Baker'F' Nipple 5 4,059 2.813 Dtix'XA'Sliding Sleeve Open/cut out 8/93 6 4,213 2.9 Brown'CC'Safetyjoint 7 4,249 2.867 Baker'FH' Packer 8 4,374 2.9 Brown'CC'Safety joint 9 4,435 2.867 Baker 'FH' Packer 10 4,443 275 Baker'F'Nipple w/Plug. WARNING: Nipple will grab tools going up & be difficult to set a plug in going down. 9/1/93 11 4,456 1 2.375 1 Shear Sub Heater HA 142' 1.995" 1 Baker'S' Nipple Pos 1 Plues/Fish ID. Depth MD (ft.) ID (in.) Description P1 3,931 - Casing Hole Opener Bull Nose P2 4,608 - 2 Baker'F' Plug 9/6/1993 P3 4,609 Two 3500 PSI Pressure Bombs & Knuckle Joint 3/1/81 P4 4,610 - 26 Ft. of 2-5/8" Dresser Atlas 2-5/8" Perf Guns 2/27/81 PS 4,665 - 9-5/8" Stage Collar P6 6,730 - Float Collar PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Stm (TVD) SPF Phase Date Status Sqz 3,992' 3,992' 3,262' 3,262' 4 2/1/1981 Sqz Sterling A 4,082' 4,205' 3,337' 3,443' 4 34 2/23/1981 Open Sqz 4,284' 4,284' 3,514' 3,514' 4 2/1/1981 Sqz Sterling B 4,327' 4,334' 3,554' 3,560' 4 28 2/20/1981 DST#9 Sterling B 4,380' 4,390' 3,602' 3,611' 4 28 2/16/1981 DST #7 Sqz 4,395' 4,395' 3,616' 3,616' 4 2/1/1981 Sqz Sterling 4,484' 4,504' 3,835' 3,995' 4 28 2/1/1981 Plug Sqz 4,590' 4,590' 3,795' 3,795' 4 1/1/1981 Sqz Sterling D 4,631' 4,645' 3,835' 3,995' 1 4 21 1 2/17/1981 1 DST#6 Sqz 4,650' 4,650' 3,854' 3,854' 4 1/1/1981 Sqz Sterling 4,684' 4,700' 3,886' 3,901' 4 21 2/19/1981 DST#8 Sqz 4,798' 4,798' 3,995' 3,995' 4 1/1/1981 Sqz Sqz 4,930' 4,930' 4,123' 4,123' 4 1/11/1981 DST #5 Beluga E 5,175' 5,182' 4,363' 4,370' 4 14 2/1/1981 DST #4 Beluga F 5,408' 5,418' 4,593' 4,603' 4 9 2/10/1981 DST #4 Beluga G 5,861' 5,870' 5,043' 5,053' 8 5 2/9/1981 DST#3 Beluga G 6,006' 6,026' 4,197' 5,208' 4 5 2/6/1981 DST#2 Beluga H 6,530' 1 6,547' 1 5,711' 5,729' 4 2 1/28/1981 DST#1 Updated by DMA 09-19-18 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOP¥: (907) 276-7542 July 26, 1994 Mark H Wittow Preston Gates & Ellis 420 L St Ste 400 Anchorage, AK 99501-1937 Re: Z-Energy Spacing Exception Request Dear Mr Wittow: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you .wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. Chairman ~ -'""J jo/rpc~z-energy ~ç~ ~ q E A J l~Æ~~~ ~ '0 ALASKA OIL AND GAS CONSERVATION COM!IISSIOl\T July 26, 1994 D A Grove, BRU/Kup Staff Mgr ARCO Alaska Inc POBox 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Grove: ) . , WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit 212-35 212-25 232-04 233-27 14-19 244-04 212-24 241-34 224-13 212-18 221-23 Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Burglin Pretty Creek Unit 214-35 232-09 224-23 232-26 BRWD-1 211-03 224-34 214-26 X33-12 #1 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. "N David W JOh~to;-- Chairman ..J jolrpc\z-energy 4'::9 prirllf'd (H) rec'r'CI('· n.lf)n !' ;' C 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 July 26, 1994 Rosanne M Jacobsen, Atty ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Jacobsen: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit' 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the matedal in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. David W Jol~nston \ Chairman jo/rpc~z-energy r,p¢inted on recycled paper ALASKA OIL AND GAS · CONSERVATION CO~IMISSION WALTER J. HIGKEL, GOVERNOR ,.,.. 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 2767542 July 26, 1994 Paul Craig, President Z-Energy Inc 2900 Boniface Pkwy #610 Anchorage, AK 99504-3132 Re: Z-Energy Spacing Exception Request Dear Mr Craig: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga RiverUnit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hOle well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission David W Johnston \ ~" ~ Chairman ~ jo/rpc~z-energy ARCO Alaska, Inc.( ~" Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 C( 'FILE November 22, 1993 Mr. David Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Application for Sundry Approval (Approval No. 93-209) Notification of Perforation Work not Done on BRU 214-35 Dear Mr. Johnston: Attached is a copy of the approved Application for Sundry Approval to perforate an additional sand from 4543'-4552' MD of the Sterling 'C' zone completion on BRU 214-35. Plans to perforate the 'C' sand this summer were canceled due to sand fill in the casing. Please add this note to your files and cancel the Sundry Approval. If you require any further information, do not hesitate to call Brian Noel at (907) 263-4879. BRU/Kuparuk Staff Manager DAG:BDN:ab (044) Attachment cc: A.J. Durrani, L. S. Mathis, Shell Western E&P, Inc. Chevron U.S.A., Inc. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany TRANSMITTA( [iD ACKNOWLEDGEbff~NT OF RECEIPT ( ?b\TERIAL - (ALASKA) .- DATE THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. -- FD--. Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueltne PLEASE CHECK AND ADVISE IMMEDIATELY. i i 3g // 3tz.' _ c/. 33z~ 5z ? ; REMARKS ON OTHER BY ~ON U. S3L INC. BOX 7-839 SIDE, THIS SNOT AFIC~.,ORAGE, ALASKA 99,510 ARCO Alaska, Inc.t~'' Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 16, 1993 Mr. David Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Subject: Submittal of Application for Sundry Approval to Perforate BRU 214-35 Attached is an Application for Sundry Approval to perforate an additional sand from 4543'-4552' MD of the Sterling 'C' zone completion on BRU 214-35. Please refer to the attached perforating procedure and well schematic for details of the · . operation. If you require any further information, do not hesitate to call Brian Noel at (907) 263-4879. Sincerely, D. A. Grove BRU/Kuparuk Staff Manager DAG:BDN:fl (017) Attachment CC' A. J. Durrani, L. S. Mathis, Shell Western E&P, Inc. Chevron U.S.A., Inc. RECEIVE D Alaska.Oil & (las Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany AR3B-6003-C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Operation Shutdown_ Re-enter suspended well Plugging _ Time extension _ Stimulate ~ 1. Type of Request: Abandon Suspend Alter casing _ Repair well Change approved program_ 2. Name of Operator ARCO Alaska, lnG, 3. Address Pull tubing _ Variance _ Perforate ~ Other _ P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 1177' FSL & 896' FEL of Sec. 34, T13N, R10W, SM At top of productive interval 312' FSL & 811' FWL of Sec. 35, T13N, R10W, SM At effective depth 146' FSL & 979' FWL of Sec. 35, T13N, R10W, SM At total depth/~J.~3 ~J... ~J 6 _~FNL & -1-1'15~/~/L'"-of Sec.~'~ T12N, R10W, SM 12. Present well condition summary~'' ~' 6. Datum elevation (DF or KB) 95' KB 7. Unit or Property name Beluga River Unit feet 8. Well number BRU 214-35 9. Pej:mit number -'72- 10. APl number 50-283-;~0067-00 11. Field/Pool Belucja River/Sterlincj Total Depth: measured 6819' true vertical ' 6001' Effective depth: measured 4636' true vertical 3981' Casing Length Size Structural Conductor 7 9' 3 0" Surface 410' 2 0" Intermediate 3930' 1 3- 3/8" Production 6818' 9- 5/8" Liner Perforation depth: measured feet feet feet PBTD feet Cemented Driven 490 sx class G 1100 sx class G 942 sx class G Measured depth True vertical depth 79' 79' 410' 410' 3930' 3211' D Current: See Attached Well Schematic true vertical Current: See Attached Well Schematic Tubing (size, grade, and measured depth 3-1/2" 9.2# N80 @ 4456' Packers and SSSV (type and measured depth) Packers: Baker FH ~ 3985'~ 4249'~ 4435' 13. Attachments Description summary of proposal_ Proposed: Proposed: 4543-4552' MD A U 6 - 3656-3665' TVDAiaska.0jj & Gas C01~,s, C0rl~missic Anchorage Detailed operation program BOP sketch X 14. Estimated date for commencing operation July, 1993 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas X Suspended Service 17. I here, I;~( certify ti),a,t the foregoing is true and correct to the best of my knowledge. Signed ~;J-'~ ' ~ i~l~ Title i~{U'~j~ ~,.i~J~/~j~3@rO~.. ~"+~'?"~' ~~ Date I FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Plug integrity BOP Test Location clearance _ __ IiAppr°va~ ~°':' o,~ O Mechanical Integrity Test _ Subsequent form require 10-~¼ Approved Copy Returned Original S~gned By _ ?,/~,/'~.~ Approved by the order of the Commission David W. Johnston Commissioner Date Form 10-403 Rev 5/03/89 SUBMIT IN TRIPL~ATE Well BRU 214-35 Perforate additional C sand BR 29 July 9, 1993 Objective: Perforate additional C sand from 4543-4552' (DIL). This well was completed in 1981 in the Sterling A and C sands. The Sterling C sand perforations were produced from 9/82 to 6/84 at rates of 3-4 MMcfd. A tubing plug was run 6/84 to isolate the C sand and obtain a deliverability test on the Sterling A sands. Only the A sands have been produced since 6/84 at rates up to 7 MMcfd. Fill was tagged in the tubing in 9/85, 10/87, and 5/91. Bailer runs on 6/3/93 worked through an --11' bridge and tagged the tubing plug. The C sand perforations were last produced at 3.1 MMcfd with no water problems noted. After pulling the tubing plug and flow testing the existing C sand perforations, another C sand may be perforated. The additional rate will increase field deliverability and be used as sparing capacity to meet winter peak demands. Status nrior to nullin~ olum .... Last deliverability test 7.3 MMscfd (A sands). Last Tag Fill: Bailed sand bridge (4186-4197' WLM, =4204-4215' KB) Tagged F plug (4424' WLM, =4442' KB) with 2.71" gauge ring Plug: Tubing plug @ 4443' MD Pressures: SITP: 1212 psia on 4/6/93. (A sands) Last recorded SITP (C sands) 1282 psia on 6/84 Tubing size: 3-1/2" Casing size: 9 5/8" Min. ID: 3-1/2" 'F' nipple @ 111' MD - 2.71" gauge ring will pass Perforation Data: Tie-in Log: 02/05/81 Dresser Acoustic CBL (CBL is off depth with DIL; CBL = DIL-8') DIL: 01/18/81 Schlumberger (5") Rlln No. Zone Interval (MD-CBL) Interval (MD-DIL) Leneth SPF -- 1 C 4535-4544' 4543-4552' 9' 6 Gun: 2-1/8" conventional Enerjet strip, 6 SPF - 0° phasing, EJ 3 RDX - 14.0 gm charge R' ¢EIVED AU G - g 799,3 ~ia,$_~a Oil :& Gas Cons, Commissiorl Anchorage Perforatin~ [~rocedure: _ - o Hold safety meeting and obtain detail description of all wireline tools to be run in well. Record SITP on WSR. 2. MIRU electric line unit and lubricator. 3. Pressure test lubricator to 2000 psi per wellsite supervisor's instructions. . Make-up tool string of adequate weight bars, perforating guns, decentralizer, and CCL. Turn off radios, phones and electric welders before arming perforating guns (Enerjet strip gun - 6 SPF with 0° phasing). 5. RIH with well SI at wing valve and tie-in with CBL log (depths in bold print). Park gun at proper depth. . Open wing valve to flow well and establish an underbalance. Maximum drawdown: AP of 100 psig from SITP (min. FTP) or 5 MMcfd (max. rate). Then fire perf gun. . Continue to flow well for at least 30 minutes to clean up new perforations and unload rathole brine (=4 bbls). Monitor contactor's scrubber for rathole fluid returns and choke well as needed to prevent fluid slugging. . Close wing valve and POOH with perforating strip. Check gun and record depths of any misfires. Repeat gun run if necessary. o A decision to re-shoot the interval will be made dependent on the well's reaction to the first run. If reperforating, repeat steps #4 - 8. 10. RDMO electric line unit and lubricator. Return well to production; 11. Bring well on slowly to ensure that rathole fluids are unloaded. Monitor for associated sand and/or water. Produce well until stable rates are attained. 12. Conduct a step rate test. Maximum recommended drawdown: AP of 100 psia from SITP (min. FTP) or 7 MMcfd (max. rate). RI ¢EIVED Alaska Oil ,& Gas Cons. Commission gnch~r~c~e · AI~O Al~sko~ Inc. I~RU 214 35 Spud Date: 12/24/80 Last Compl: 3/7/81 ~<:hematic Rev: 10/31/91 ...W 1/4 Sec. 35, T13N, RIO, SM Be ~ ,a River Unit APl#: 283-~7-I~ Original RKB (Depth Ret): Ground Level: Maximum Hole Angle: Angle at Perforations: 95" 77' 47~ 20.30~ Well Type: Gas Producer Annulus Fluid: Gas Top of Sterling: 4006' ~ 2620175~18669 Single w/heater string Jewelry 1 111' 1.1' 2 3981' 4.1' 3 3985' 8.15' 4 3998' 4.1' 5 405~ 58.9' 6 4213' 1.6' 7 4249' 9.0" 8 4374' 1.66' 9 44&5' 8.05' 10 444.3' 4.14' 11 4456' .58' 12 ~ Casing and Tubing 3 1/2" BAKER "F" Nipple 3 1/2" Otis "XA" Sleeve Baker "FH" Pkr. 3 1/2" BAKER "F" Nipple 3 1/2" Otis "XA" SI eeve Brown" CC" Safety Jnt. Baker "FH" Pkr. Brown" CC" Safety Jnt. Baker "FH" Pkr. 3 1/2" BAKER "F" Nipple, Plugged 6/84 Shear Sub Fish, (2-1 3/4" Pressure Bombs 26' of DA 2 5/8" Perf Guru) Conductor 30" Surface 20" 94# K-55 Butt Intermediate 13 3/8" 68# K-55 Butt Production Csg. 9 5/8" 47~.5A0~ N-80 Butt Production Tbg 3 1/2" 9.2# N-80 Armco Heater 2 3/8" 4.7# N-80 EUE 8RD Perforations 3992' 3262' 4082'-4205' 3337'-3443' 4 SQZ Packer 4 58' 4284' 3514' 4 SQZ 4327'-4390' 3554'-3611' 4 SQZ 4395' 3616' 4 SQZ 4484'-4504' 3697'-3715' 4 20' 4590' 3795' 4 SQZ Packer Pgck~ Crnt. Plug E F H 4631 '-4798' 3835'-3995' 4 SQZ 4930'-5182' 4123'-4369' 4 SQZ 5408'-5418" 4593'-4603' 4 SQZ 5861 '-6026' 5043"-5204' 4 SQZ 6530"-6547' 5711 "-5729' 4 SQZ PBTD 4636 TD 6819' 2.75" 4117 393[7 6818' 4456' 2031' Closed Open Closed Closed Closed Ck)sed 6/84 Closed Closed Closed Closed Closed Closed 2.4" gauge ting, fill at 4226' z.~," 3~.,~ ~,'.~, '~z,~' ~.,,,_,.., - r,¢, JLB 10/31/91 Anchorag8 4300 440 4500 .. 4600 .31' J ~P (MV ) COMPANY CHEVRON U.S.A. INC. 0.0 WELl_ BELUGA RIVER UNIT 214-35 ILD (aHMM) 0.0 0.0 SFLA(OHMM) SFLA(BHMM) 50. oo, AU~ - ;~ ~S9~ 10 00~lSka Oil & Gas Cons, Corrimis$io~ . C I L~ (MM/M) 50 O0 11000 ....... SCHL. FR 6517 SCHL. TD ro 820 DRLR. TD 6812 FIELD BELUGA RIVER COUNTY BELUGA RIVER STATE ALASKA Elev: KB DF Gl. E-Line BOPE's Grease Head/ Hydraulic Packoff ~ Lubricator Extension Manual Rams ~wab Valve Ataska Oil & Gas Cons. Commissio~ anchorage Double M~te~t Valves Wellhead ., ~ -~ KB to TUBINJr . DONUT "~ 105.82 X-O PUP 110.87---4,_ "F" - - 112.01 --~ NIPPLE ~ 117.11 -- X-O PUP HEAD ~. 410' -. 2030.99--- -- 2~" O.D. 4.7;~ HEATER STRING ~,, 3930' 3992' --133 JTS. 3~' 9.2, N-80 tUBING ........3981.26' 'P- OTIS. "XA" SLEEVE ....3985.36' )- BAKER "FH" PACKER 3993.51' ~---, I PUP BUTT JOINT 3~'~ TBG ~ 3997. 59' ~.~-' F" NIPPLE ' . .. $998.73" ~- X- OVER , 4o~.~ ' ' ~ 2 JTS. 3~ SEAL- LOK TBG ' OTIS ~ 4126~ (OPEN 5 JTS. 3~"SEAL- LOK TBG 4~-°~'4207'5I' ~- X-OVER PUP -- 4212 59' - --' ,~BROWN CC SAFETY JOINT -- 42i4.2i ~ X- OVER PUP ', ~-' I JT. 3~" SEAL-LOK TBG. ~ 4248.57' ~-- BAKER "FH" PACKER 4327" ~ I 4334'.~ . -~ - 4 JTS. 3~,SEAL-LOK' TBG. ~4372.-e6' ~ X- OVER,, , ~[~.~; .~ BROWN CC SAFETY JOINT · · ' 3~0~ I 3es' - ~ Z JTS. 3~ SEAL-LO'K TBG. .... 4435.3~ ~ BAKER "FH" PACKER 4484~ OPEN j _ ~4~o4'~ -F~sh ~'2' I~ Pressure Bombs 4'2'8l 4631 4s,s' Top of Plug 46~6' " 50' 4700' '"°' C/tV[D 5408' I ~870' 6008' i 6~47. . 5.05 1.14' 5.10' 203 9.9 9' 3859.10' 4.10' 8.15' 4.08 1.14' .92 58.90 4.88' 144.08' 5.08 1.62 5.10' 29.26' 9.05' 115.24' .82' 1.66' .90' 59. 07', 8. o5~ I. 14! 10.45' .8~ .58' RAN TUBIN6 2-26-81 1~-20- 8~ B.R.u.' ...... CASING 8~ TUBING DETAIL SECTION 34 T. I,~N.,R. IOW.' CHEVRON U.S.A. INC. ,.- · KB to TUBING(,~',;~,AD L DONUT · 105.82 X-O PUP ' "110.87---4~ - 112.01 -.-~"F" NIPPLE ~ 117. II m X-O PUP 5.05° I. 14' 5.10' · · · :. · · 410' ....... 2030.99~ 3930' :3992' 3981.2 6 - 2~1" O.D. 4.7m HEATER STRING 2.039.99' --133 JTS. 3~' 9.2, N-80 TUBING 3859.10' · ,= ~,~, 2'- OTIS. "XA" SLEEVE 4.10' ~ $9o~,..,~ >- BAKER "FH" PACKER ,,. 8.15' 3993.51'. ~--IPUP BUTT ,JOINT 3~ TBG 4.08' -- 3997.59~ ~" F" NIPPLE ' 1.14' , , 3998.73 .... . . ~ X- OVER ,, .92' :4oea~ .. ,..,, ~2 JTS, 3~ SEAL-LOK TBG 58.~ ~o;.~058.55 ~OTIS "XA" SLEEVE 4.88' ;4m IO'.~ / ,, ~4,~(o.~. . J--5 JTS. 3~. SEAL- LOK TBG 144.08' ~207.51'~ X-OVER, P~ 5.08J ,. 4212.59'~ BROWN CC SAFETY JOINT . 1.62 -- 4214.21' .~ X- OVER PUP 5. I0' ', ~ I JT.. 3~" SEAL-LOK TBG. 29.26] 4248.57~BAKER "FH" PACKER 9.05~ 432T,' , _~J - - 43~4. , , 4 JTS. 3~.SEAL LOK TBG, 115.2 "': 4~72'.-86:~ X- OVER ' '.8~1 ' 4373 68~ " " .... '..~ BROWN CC SAFETY JOINT .. 1.66 [390~ J ,~5" ~ ~ JTS. ~ SEAL-LOK TBG. 59.0 .80 ' ~-2 PUP 3~" BUTT TBG. ~?~ .... ?~ ~ ....... '~ I0~ 4456 ~5' 'r .~-- .... ~ · , -$H EAR- SUB -' , 4504'J . eJ: ' 4s2o' ~ !'" ' '4590" Top of Plug 4636' ,~ 4631 ,50- 4?OO' 7-20 - 47~8' , - ., ,, - BRu' 214 235 5182' B418' · ,. 5~1' · ' · s.7o' CASING ~ TUBING 6008' 6oas' SECTION '6530' 6~47' 796' - TD.68~9' DETAIL 34 T. I~N,,R. I0 W. CHEVRON U.S.A. INC. Chevron CHEYRON; U.S.A. INC.' TRANSMITTAL A~: ACKNOWLEDGEMENT OF RECEIPT OF~ FERIAL - (ALASKA) · DE?T.: PLACE: DATE · ~- t% FI) - Folded R -- Rolled S - Sepia F - Film X - Xerox B - Bluelime THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. _.. .. RECEIVED BY .... ,.,. r,~l .~ aas Cons,'Commission - ~"~" .... Anchorage REMARKS ON OTHER SIDE, THIS SHEET ~o~ tT.S.,., mc. BOX 7~39 ANCHORAGE, ALASKA 99510 CORRECTED WELL COMPLETION OR RECOMPLETION REPORT AND LOG '1. ~l,:atus of Well . Classification of Service Well ~ . OIL [] GAS ~ SUSPENDED [] ABANDONED [] · SERVICE [] · 2. Name of Operator 7. Permit Number _ Chevron U.S.A. Inc. 80-72 3. Address 8. APl Number P'. O. BOX 107839, Anchorage, AK 99510 50-283-20067 4. Location of well at surface 1177' N & 896' W from the S.E. Cor. , 9. Unit or Lease Name Section 34, T13N, R10W, S.M. At Top Producing Interval 893' S & 1738' E of the surface location. 10. Well Number BRU 214-35 At TotaI Depth 1238' S & 2052' E of the surface location· 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Beluga River - Sterling 77·1 G.L.I A-029656 - ADL 17599 12. Date Spudded 13. Date I.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 12/24/80 1/22/81 3/7/81 -- feet MSLI 1 ,17. Total Depth (M D+TV D)18. Plug Back Depth (MD+TVS)! 19. Directional SurveY68196001 M~i~D.D ~ ,Mr~ f) YES [}: NO [] [ 20. Depth where SSSV set. -- feet MD I21' Thickness °f Permafr°st' -- 22. Type Electric or Other Logs Run DIL, SFL, SONIC, FDL-CNL-GR, CBL, VDL 23. CASING, LINER ANDCEMENIING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 1" Wall Cond. Surface 79 ' -- Driven 20" 949 K-55 "' · 410' 26" 490 SX 13 3/8" 68~ K-55 " 3930' 17%" 1100 SX 9 5/8"47 ,43. 5~f N-80 " 6818 12%" 942 SX 24. Perforations open to Productioo (MD+TVD of T~)p .and Bottom and 25. TUBING RECORD 'interval, size and number) .. SIZE DEPTH SET (MD) PACKER SET (MD) 3%" 4456 3985,.4248, 4435 · 2 3/8" 2031' See attachment ~1 ....,., ... 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. '.... '--, . - DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See ·attachment ~. 1. ' -- ' . ·. . 27. PRODUCTION TEST Date F~fst- Product on .... . ..... Method of Operation (Flowing, gas lift, etc.) ~ ' 9/20/82 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO ' . I 'See .'attac~. merit #2 : TEST.PERIOD . ~.. ...... Flovy. Tabigg ' Casing Pressure .. , CALCULATED: ~ OIL-BBL GAS-MCF . WATER-BBL OIL GRAVITY-APl (corr) ~, ',,,. ,: '~'Press;,~' '~.,- · 24,HouR,RATE-- "' "' ' ' ' . ' ""':',.i" 28. CORE DATA . - Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. - ~ ' '. ,.i' .' ' -: .. :, .,~. .. ~ t. , ; ,. , ".~, , , . See attachment #3. · · :~ ,. ... . · . ' , ,, . ,~-;,.~ : , - . ,. . ,, · .. .. 'i,'. MAY2 5:i§83 .. · .., .... · , Alaska 0il & Gas Cons,C ..,., . ~ ,.. . ,. Anch0rage,,,° $siol! · , Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE submit in duplicate 2"- .. 29. 3O. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sterling 4055' 3316' See attachment #4. Beluga 4608 ' il 3813 ' 31. LIST OF ATTACHMENTS Core analysis, DST reports, Perforation record, Production test data 32. ~ hereby certify th@t the foregoin§ is true and correct to the best of my know~ed§e Signed ~- ~, ~ Title Area Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion: Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. .Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- 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, Shut-in, Other-explain. Item 28' If no cores taken, Form 10-407 indicate "none". Attachment t! ! BRU 21/4-35 PERFORATION RECORD DST Itl ~;530'- ~;547' (squeezed with 100 SX)* WSO 4930' (squeezed with 125 SX - resqueezed with 125 SX)* WSO 4650' (squeezed with 125 SX)* WSO 4798' (squeezed with 150 SX)* WSO 4590' (squeezed with 150 SX) WSO 4395' (squeezed with 150 SX) WSO 428/4' (squeezed with 150 SX) WSO 3992' (squeezed with 150 SX) DST DST tt3 /t3RR 6008' - 6026'* 5870' - 586 I' (perforated twice) * DST tt3A 5408 - 5418* DST 1t/4 5172'- 5182'~ it4RR DST It5 4/;31' - 46/45' (squeezed with 18/4 SX)* DST tt~; 4380'- DST 1t7 4327'- DST 1t8 4~84'- 4185' - 4110' 4082' /~484' All perforations 4390' (squeezed with 250 SX) 4334' (squeezed with 150 SX) /4700'* 4205' ~ 412~;' Open to Production 4504-1.' /4- ~ JHPF *Hole plugged with cement from 4~;36',- 6818'. 2 5 A[aska 0il & Gas Cons. CommiSsion Anchorag8 · . i,, LOGS: Schlumberger Dual Induction SFL Borehole Comp. Sonic Comp. Formation Density Comp. Neutron Form. Den. Cyberlook Cyberdip Cased Reservoir Analysis Continuous Dipmeter Long Space Sonic 8'-10'-12' Polywog Proximity Microlog Acoustic CBL-VDL DIL-TVD DSTNDT Depth 410'-6817' 410'-6789' 400'-6820' 410'-6820' 3930'-6012' 3930'-6016' 3990'-6710' 3930'-6016' 410'-6002' 3900'-6000' 3930'-6017' 3494'-6494' 410'-6000' 3900'-6744' Runs ~1-2-3 1-2-3 1-2-3 1-2-3 2-3 2 1 2 1-2 2 2 1-2 1-2-3 4 11__ I! 2 "-5" 211_ 5" 211-511 .5!1 5" 5" 5" 2 "-5" · 2 "- 5" 2 "-5" 5" 2" 5" PERFORATIONS: Jet perfed 4-1/2" holes per foot 4082'-4104' 4110'-4126' 4185'-4205' 4327'-4334' 4380'-4390' 4484'-4504' 4631'-4645' 4684'-4700' 5172'-5182' Squeezed Squeezed Squeezed 5870'-5861' '5408'-5418' 6008'-6026' 6530'-6547' reperfed Jet perfed 4-1/2" holes per foot 3992' 4284' 4395' 4590' 4650' 4798' 4930' (squeezed) -'/:;],~:.'!"..}< !'?:'-!';¢!?' ~- ;-' ', ~,i': .'-.'-. i~ ); [- ~:, '.'... ;..:.:.::,-~'~, :v/i:.:..-: --: ~it',' :',~, '. :~< J.~..t-:/;.,i!-;-?. 'l oPOIXT TEST .'" '~'-":;,-.;t?'-';'.~t~' -'- ·: ~... ' ;:' ':~ ' ) ,.'"-'.~,;.¥'"'I:;,.'- ~ !''~'~'~ ;t'~ i': '..: . .~-"-,-.:'- . .;' ,:,~ '.:~'-'- ?,-' - .-.:,:;., . · , .................. · ..:~.'leid : ::7 ::':'; ":'i").:: :.:'.! '. ::::., ..,,::. ",:: .: -.', ' ,:: ?,..,.-.-..-j Reservoir -,.'..~." '/:.~?;-., "": '? .': .~ ~ ':: .'.:'f':??¥/-: :;-' ."'-':..'-- :":'::~.-i-::?'.':'::,. ~ <. ' ';':.'--.::',':-': ~,,. ,u..-. - , . - .~/..,,:. - ',..,.~, :?..,._ .-.-< . ;*-.,-;~ .:., ..~ , · .:-. ,-<, .::: .... : .,: ,-: . .: ..-:~ ,.,:.~-,.~,-.;. . ~ :2<luo , r¢,.,,,ec ........... . ..--. J .... ..... :...:,:, ...... ..: .<.. :.::.:: ;.::?,'.'.' ~---,~m - US/~ ":::K~ Fl</-.~ ." ....... :, :.,. ~?ounty -:-.::,.'... .... J Location :-.:.i:'~i:-. -... .... -'~ ": ..... :: ::-. '-< .... ".'..": -.' · '.'.' ....':. ] Co=pl~Uo~e '[ ~o~pa ] ~.'%.:.% ....:.:~:. 2 f::~',:.~-..:.: ' [ · ',, '..:'..', ::' .,.::.",-i;-f..'.':".::W,' ¥".~'~'.:';"'~ ': -~ .'.:..': ,;,.' '..::t'~:~.. '.., '. ,-.. :., ,~i.:,'.:'::..;".'-' :, '--,: :': . ~ J :, · '-. ~ '-'~'--'? · ' ~-'"-., ' ,-.-. ..... --,' . '" ' · ' ....... , , ' · "\!'i~ :~r, oducl,nl~ Thru J R~r~olr ..J Wellhead J C~. Size J .., ,. ,~Vt/Ft -..~ J ':' :,:'~: 'T r~ ' J Ra~ r~, . i., :.. , , ,- :. :,. :,.. a.,- j,,~,' -,-.~,,, ~---,~:,:...~ -'.' t~:/?~.:.s, ize J ,..,:~.~ UF.t...?>,,:~J ;...?.:;:...p. ,p...:.:A.M ,-.:!/.:'.L~: ::~...'.,:.~.~].. Set, @..~.1: .~,, ~,evJt, i. A,~. ~,0~ -i - aL ..J. ~,.,.u,,,Jd H~-d~,~oo, .. 1: ~,,t, or ':~1'::~'!.3°~ ' 'J "9,? :~ ,"?- :J :"~['~, "'-':'" "M '-.-~ ~o-~ # -'-' ?:1 ~r,,'.; ; J '(Separator) [ Length (L) J :' , :;~J . ~Ratlo ~lt'F l~r Bbl...,':J Ll~id (Apl) '.- ~,, , ,~...> ., ,.:,. .- .: ~:. ~ , I..... 1..- ,, '" '- ' ; ' i' -"" J · · · -'J , .Pipeline Connection .-: ..... /.,. ,~ ' :...: :i.:~",>-t.u ,-'. -,'~ :::~a,:. :--;,:;<~.,r...-., ~ .~, ,~ ... ?~. j ,. -.' Type Taps ' ',', ~ .*-;., ..... ',,;: ;": ~ '. '.*'~ :, a,, ,', . - ~ .~; ' ~; - -.s- :,'~, · ,:,!:~: .......... , . ~ ~:,~,,- ,,,.. '*-.:~ .... :~-., ~ - '...,<:.~,.' .,,.': ??'~':'(:t'.:-~l ,.!;! . . ~ ...... :' :'~ -"::' ?, ,b./,~:,.~ ~:","'}': %:- ~:',',.¥ -',,*.:~,,i'..; ~.c.~?i.i- '~;' % " ....... '' ' · ' ~ ' "'. .... . ', · ","1 ........ ..... : .... " , : "~"' ' . ';' '." . ....... I ....... "<" ' ~' ' .... tg- : - j , '",' , .' ............. ~. .'"~'~r':~-'.. ...,, ...... ..r--,~ ~ -;~-.~" ..... ':~Jl ~'"~J'~.i~-s '~..~.~'~:~.-~' '.~ ....... ' ' ' ' '" * .... ~ ~ ' ' ~~" .... , ?:'' Time ' -: :(Prover) '~ (Choke) ..~,'::.Press. .: ,, .~-.,.:...<., . '-~ ~ , :',:.'.:Press. . ":?~ess. '..~' '" .... ~o. ' 0fFlow "'" . (:'::'?(Line) . . . (Orifice) "":" '-: ~:~:?:, :~ . . -.' Hours -...:j ": Size '~ ':~: .'.. Size , ...... ' . ,'~ . o .... ~" Z. Z5 '"-" '" t~ -: . - j. 3.oo · '~" -' ~.'z5 .", ~.".' ' S.oo''~'.::~ ":~""'"'"":. " FJz5 · :'"" ...... ' j...~ ....'i~:i..l~°':: ' ' "' elent ~,:.. ~'..:.. . (24 Hr.) w . r~ ~. : ..... ,'.".?.CERTIFICATE: I, the undersigned, state that X am th,-- and that I am authorized by said company to make this report; and that ~"" ........ ., .....,, ~ '.~ · .~ ,:.,,v. ~, :~':.; ':.:~: ,j~ ':, ·, · ,, ,:> ':;?!pared under my sUPervision " "'the facts stated therein are true, correct and ',,'~::,/?... ltle best of ~ knowledge. Signature ' '~. L, ~0~ !Alaska Off and Gas Conservation-Commission Well Flow Test' by Order No.' e. ,e. .:. ,e. ~ ,e, ~ e, ,e. .e. ,e. e. ,e. e, ,e. 4, ,e. e. ,e. e, ..~ e. ,e. · · k,~ '.-:. i,..:. ~ ~. :vi. ~.~ .~. :.~ ::': :.-. .~. :.:: .) > ~ ~ lq .q o~ m · .,ILL STEM TEST REPOR BAS lC DATA LOCATION IJq~"N ~ ~q(~/~. ~ CL~R~. ~C .~ ~ J)COUNTY. ~g~-~ DATE I-~&-~l Mug ~PE G~ WT. q~ VIS. ~ W.L. q,g FORMATION ELEV. ~5 ~ TYPE CUSHION ~O~ OF. MECHANICAL DATA . BOT. CHOKE ~ il "B DRILL COLLAR LENGTH .. ~0N~ I.D. ~ BLS/FT. -- / . DRILL PiPE SIZE & ~PE ~ 'it" F~ LENGTH ' WT. ~. ~ ",.D.3,~)~ "EELS/FT. ,OIV~Z TOP PACKER (S) SET AT: ~O~ AND .... ~3 AMT.PERF.ANCHOR BOT.PACKER~ T.O. (~J~ HOLE SIZE~,~ RAT HOLE SIZE HHi ~ ~ .... RAT HOLE VOL.(EELS.) ~ CSG. S,ZE ~ WT. ~SJ, H)S ~ C~lO ~ , O FT.':SIZE & WT. ~~~ FT.;ND.REC.__ ~__ ~ , ,, ' ., ., ,, ~,, TEST DATA SET PACKER ('~' '"~: . OPEN TOOL @ F~.(~'~. )(P.m.) IFP~ HRS. MIN.; ISl HR MIN SFP_i~ HR,. ~} MIN.; SFSl ~ HR. ~ MIN.; FFP~ HR. ,, MIN.: FSJP__ HR. __ MIN.; BLOW . . . CUSHION TO SURFACE -- HR, -- MIN. '-- GAS TO SURFACEi --/HR, ~ MIN. GAS RATE: INITIAL ~L MCF/DAY: MAXIMUM / MCF/DAY~ FINAL MCF/DAY FO~ATI~ FLUID ~C)N~.. ~_~C)~]~.~E~ '" II TO SURFACE 'N~ HR. ~~'N. R ~OUNT (FT. OR EELS.) DESCRIPTION · GRAVI~ SALINITY Rw ......... c ........ ~o .~H-' ~%E I~ H~/'~- g,~, ~ o,. ~d0~ '~Pd~C~d~, FL.r~b., ....... ~... o,. O ..... / N O ~.~ . ~ of. E ~ .... TOTAL FORMATION FLUID RECOVEREDII ~ ' ~ ~ [~' ' ............. PRESSURE DATA MAX.CrOCK TIME q~.~ HRS. L(8, HRS. g'L .,s. ~¢) HRS. .ECHANICALLY ~ YEs '~'~ ' b ~ ~ ' FINAL F,P, . .i FINAL S.I.PRESS. ~[s~l~ co._H,~Ll~U~O'N BHT °F. °'F. °F. '°F. ... .... TICKET NO Sg~J~ ~ ! GEOLOG I S T BATE PRIINTED I U. k'~,L~'rl I L L STEM TEST BAS lC DATA DATE 2"'Z'"~'/~ MUD TYPE ~'~// WT. ?j VIS. '~4:~ W.L. ~-~' RMF .~. ,~' % ~/ °F. ,.,v. dD t¥,, MECHANICAL DATA TEST NO. 2 INTERVAL~I~__,~',~.~,~' CONVEN.~]: STRADDLE Fl; OTHER (TYPE) SUR.CHOKE ~, '~ BOT. CHOKE ~ D, iLL COLLAR LENGTH LEN6T. ' WT. ~1 .D. ~ - T.D.~/~ HOLE SIZE~ RAT HOLE SIZE -- - , RAT HOLE VOL.(BBLS. cs~.slz~ ~ wt. ~.~ ..... ~ ~¢/¢ ft.:s~z[ ~ wt. TEST DATA TOOL @ ~::~1~/(,~' ~A.M~)(p.M.) IrP '--~ HRS. ~ MIN.; IS, / HR. SET PACKER OPEN CUSHION TO SURFACE HR. MIN. GAS TO SURFACE ~ HR. MIN. ~S RATE: INITIAL ~ MCF/DAY: MAXIMUM MCF/DAY: FINAL ~ MCF/DAY FO~ATI~ FLUID ~ ~//----~~ -- TO SURFACE IN ~ HR. ~--' MIN R AMOUNT (FT. OR BBLS.) DESCRIPTION GRAVI~ SALINITY Rw c g o' -, F. ~ OF. V 'I ~ °f. Cf PRESSURE DATA .- GAUGE LOCATION ~'/,/~J*/~ ~*'/~'/~ f~'//~t,~t~,j~~,~~' MAX. REG. BHT~° F.. ' SETTING DEPTH J¢~ ft. ~JO FT. ~¢~FT. ft. TEST SUCCESSFUL? ....... MAX, CLOCK TIME ~ HRS. ~ HRS. q~ HRS. ~ HRS. MECHANICALLY ~YES D NO" INITIAL ,.,. ~~2 ~~ ~7~ ~2~ PRESSURES m YES a NO ' INITIAL S.i.PRESS. J3b~ ~~ ~/~ ~J~/ ~/~//~?~ - I ~ ..... FINAL F.P. . , BHT ~ °F' ~ °F- ~O OF-~ . /O OF' TICKET NO. ..... GEOLOG I ST DATE RP 464-1 (CD. 6s:74) PRIINTED IN Uo ~:'~~:~,'~'.f :~ ,':-::::..~.,~x~,~' ,-:~~~ :.~ ,, :,.,~-:,~,~ '- :..' .,:":::~;,.L'.,~~ .... ~.Z: ' ': '" - .... '"' ..................... '~"~"'~~ ?:~:~?F?~:;7~'?:~'~':~:~::~:~;.::~f'~;:~'t~f.:'?~''~. ~]-:~-~ ~. ~' "' ;::~"L::~'~:.:,,: ~',":?~ % z ~... ~. ~, .,..,,..::~ .~ ....... ~,~-~. ,%:;ONi:IDJ NTIAL ~,ILL STEH' TEST REPOR BAS lC DATA O~.~,A'rO, ~I"IEV~/3N ,_~,,~ BELUGA I~IVER LINITw~LL NO. "~L4.~35_ ~-,-,,-r~ A LA.~,KA LOO, T,ONII'/i'N 'J. BCtI:.I~IeF be CaR,MAT- 51/ ~,~,_o/~ELLIEA DATE J°/"~g"~:)J MUD TYPE ~ WT. ?~I': V;aS.40 w.-,. Il.g, ,., ._~.~ ~__/,~__°~. MECHANICAL DATA TEST NO. ,,.~ IINTERVAL~.J.~"~_~J'~'I~,~a~"~' ~'*"~'~'' ~JJ""~"~JJ'"~'~ CONVEN.~ STRADDLE ~; OTHER (TYPe) .... SUR. CHOKE BOT. CHOKE DRILL COLLAR LENGTH I . D. "BBLS/FT TOP PACKER (S) SET AT: AND . AMT.PERF. ANCHOR BOT.PACKER~ [~:~ ~J~' .~OLE sIZE~ RAT HOLE SIZE SOI ~ .~..~ ~ ~ RAT HOLE VOL.(EELS., SG. S1ZE A WT. · ~ FT.:'SIZE ~ WT.~@ ~ FT.;NO.REC,,~ ~ . A __ PLU~ AT TEST DATA SET PACKER ~ : Ill2,, OPEN TOOL @ _ (P.M.) IFP HRS....MIN.; ISl HR.. MIN. . -' i4- --- ---- SFP HR. MIN. : SFSI HR. MIN.; FFP HR.~ MIN.:FSIP__ HR. -- MIN.;BLOW CUSHION TO SURFACE '""'"'HR. ~' MiN. ~ GAS TO SURFACE.."'" HR. "'I' MiN. GAS RATE: INITIAL MCF/DAY: MAXIMUM ""~ MCF/DAY; FINAL MCF/DAY FORMAT,ON ,LU,D NoNE I~COVEEED ,o SUR,AC, ,N__ AMOUNT (FT. OR EELS.) DESCRIPTION , GRAVITY SALINITY Rw .... /,,1~' OF DIESEL ~ o,. - "z4.o' " Eht,4 of. ~ I/,,' " ~i~ILLING FLUID '" , o,. @ OF. ~£ T'a~ ,WA5 TdRNEp To'~ o?~N ~O~IllON TOTAL FORMAT,ON FLU,° RECOVERED FOR ~£COND FLoW W/NO RE~QLI~ FERF, PLU~6~O o~Fw A'~MPLE F~OM ~E JCIP ~PLER W~ PRESSURE DATA GAUGE LOCATION T.I B.T. ~o. B o MAx. REG.,,* 73 · . · SETTING DEPTH 580~, .T. 5'BIO f,. ~844 FT. ~~ FT. TEST SUCCESSFUL' MAX.CLOCK TIME ~2 ,,,. 4B H,,. 46 .,s. ?Z H,,. INITIAL S.I..RESS. q I ~ 901 q~O qAB SECOND S.I.PRESS. FINAL F.P. FINAL S.I .PRESS. TESTING ADDLTIONAL REMARKS WJJ.~L I~EI~F_..PF INTERVAL { TIBET. SECOND T'I~T WILL ~E F~LL[D ~ R/R ~g ~~[ OF ~A~D ~N TOOL O~ TAIL ~0L ~1~[~ . GEOLOGIST -- DATE ..... RP 464- ! (CD-6.74) PRIINTED IPi U. S. A, :CON ENTIAL ILL STEM' TEST REPOR BASIC DATA OPERATOR QI4F--vRON 'EASE 8£LJ6A I~II/ER )JNl'F W.~ .0.2~4'~5 ~. ALA~ LOCATION 11~]'~(SQG'~aF 6E ~O~. 6~.)4.ZISN¢[~I~W· ~-Sd FIELD 8ELU6A TESt no.-~ DRILL PiPE SIZE & TYPE 4V'2.~! MECHANICAL DATA CONVEN.~: STRADDLE [-]; OTHER (TYPE) DR ILL COLLAR LENGTH I , D. "BBLS/FT. LENGT. ' .T. Il,..&' TOP PACKER (S)SET AT: 5B1~1¢) AND '--" AMT.PERF. ANOHOR 9! DOT.PACKER@ ~.~. /,,818 ,o,~ ~,z~ ~ ,*T ,0,~ ~,z~ 54' 4 . RAT HOLE VOL.(BBLS.) TEST DATA SET PACKER ~ ' _ .. OPEN TOOL @ 9: 3~, (P.M.) ,F'P _ HRS. IQ MIN.: ISl I HR. ~ MIN. SFP HR. MIN.; 5FSI HR. MIN.: FFP HR.~ MIN.;FSIP HR. ~ MIN.:BLOW CUSHION TO SURFACE '"'" HR.~MIN,~ GAS TO SURFACE~HR.~MIN. GAS RATE: INITIAL NONE MCr/BAY: MAX,mUM """""' MCr/BAY: FINAL '--"--' Mcr/bAY FORMATION FLUID NoNE ~£COV'EI~F.D TO ,URFAOE ,,~,,. ~.,,. AMOUNT (FT. OR BBLS;) DESCRIPTION , '-'~IESEL ¢59.,5' ¢ °F. '~A't' HOLE MUI~ '2~'1' @ °F~ /:~LLtN6 FLU~ Icc' ~ o~. @ OF' @ OF. TOTALFORM×T,ONFLU,DRECOVERED 1.4''6BL~ ~ NO TAKEN AH D WA'5 REMARKS , [ ,/ PRESSURE DATA SETTING DEPTH 6~0~ FT. ~BO~ FT. ~3~ FT. ~o~... ~54-8~5 ?b3-B~ 888-919 FINAL F.P. FINAL S,I .PRESS, TESTING CO. ~,~ ~3 o~. qB o~. ~3 o~. ~3 o~. ~,~,,o. ADDITIONAL REMARKS F~I~T~ON ¢~_RY T~6!-!T. 5oME OAMA6E. GEOLOG I ST DATE RP 1~6~ E4~'l {CD'6s:7.4} ' '~'""-~. uRILL STEH TEST REPORTx BASIC DATA OPERATOR ~"'.~/~=V/'~.C~ ~,/~1 LEASE 8 /~U WELL NO.~..J'"~J"~.~Z'~STATE ~J ~A~ ~ LOCATION //77~/, ~ ~ //~, ~~C~/, COUNTY ,~A T-~g FIELD~ ~ i.. DATE~--JO --~I MU6-~PE~E~ ~t. 7~ ~FVIS. W.L. RMF ~ OF. FORMATION ELEV. ~ ~ TYPE CUSHION ~A~E~ AMOUNT //70 '~--A //~, ~ MECHANICAL DATA TEST NO.,~Y~ INTERVAL~..~'"~A"'4/c'~_D CONVEN.'~ STRADDLE E]: OTHER (TYPE) SUR.CHOKE Jl BOT. CHOKE DRILL COLLAR LENGTH I.D. DRILL PIPE SIZE & ~PE~ // ' '" TOP ,AC~EB (S) SET,T: .~d~ ~ND ... ~T.,~,~ ~.C.O, .... · BOT. PACKER~ _ . .HOLE SI RAT HOLE SIZE RAT ,OLE VOL.(BBLS.) . ! SET PACKER *~--~:-~OPEN TOOL @7-~"c~- (A.M.)'(N~"~,M-P) IrP.:i / HRS../?~1'' MIN.: IS,~ H,.~ ~IN. s~ .. ~,~.: ~, ,,. ~,..: F~, I ,,.~. ~,..:F~,~ ~ ...~~,,..~OW/~ CUSHION ~O S~FACE HR. VM~N. GAS TO SURFACE.,, HR. MIN ~' GAS RATE: INITIAL MCF/DAY; BAXIMUM MCF/DAY; FINAL MCF/DAY R ~OUNT (FT. OR BBL'S.) DESCRIPTION GRAVI~ SALINITY Rw ........ E ~ OF. .. , -- C . ' ~' ~ OF' ~ OF O ........ ~ °F' V ~ °F. E "' ' ' TOTAL FORMATION FLUID RECOVERED ~ven.,e~ ~0~~,~ ~ OrO~X O~ ~',~ ~ ir . . . ~/=e ~7u¢/~ /~4, ,r/~e /- , , GAUGE LOCATION )~ZN.5'/ZTE'~CT.Z;Y$/~/f~P OuT,5"/~ ~TOU~/~ ' .~x. SETTING DEPTH ~/ FT. ~~ FT. ~2~ FT. ~~ FT. T,ST SUCCESSFUL? INITIAL H.H. ~7 / ~~ ~3~ ~0~ PRESSURES mYES INITIAL F.P. ~~ 7/~ ~O7--~ ~O '7~ ~'' 7~ REMARKS SECON~ ~.P. ~7~3~ ~'~ 6~'~0~ ~'~47 PI~;~ /~ /~, SECOND S ' ' ' PRESS' I~¢0 I~1 1~7~ t~7% ~lo~. ~ F~NAL r.P. ~"~ ~ '~/0 ~ FINAL H... ~~ 2/~ ~~ ~ O~ TESTER C~/~ BHT °F OF. OF. OF. . · TI CKET NO ADD I TI ONAL REMARKS GEOLOG I ST DATE RP 464- I (0F).6-74) C~ILL STEM TEST REPOR BAS lC DATA MECHAN I CAL DATA TEST NO. "~ ,NTERVALE/_?.~."_J~/(~J,~. CONVEN.JJ~' STRADDLED; OTHER (TYPE) SUR-.CHOKE~BOT. CHOKE ~ ~ DRILL COLLAR LENGTH I.D. , "BBLS/FT. DRILL PiPE SIZE ~ ~PE ~'~ / / I~' ~ L ~ N G T H ' WT.~ ~I.D~ "BBLS/FT. TOP PACKER (S) SET AT:~/~ AND AMT.PERF. ANCHOR /~ y . -- BOT.PACKER~ T.D.~~P/O~HOLE SIZE RAT HOLE SIZE ~'~ RAT HOLE VOL.(BBLS.) ~A:/e v"Y = ~ ~o~ ri~'zn ~'"~'~ ~.~A~/e ~ ~~, = ~ ~ ~ ~ j~ D ~ ~ ¢~m~ ~ = ~'~TEST ~ ATA ~ ~ ~ m 0 ~ ~j ~ ~~ ,~&""t3 ' - I ,RS.W_~ .,,.= ,s,-3 ,. ~ SET PACKER OPEN TOOL ~ 7,~J~ ~ ( A. M. ). - .'- ) I FP . CUSHION TO SURFACE _HR.__~IN.__ GAS TO SURFACE__HR ..... UIN. ~S RATE: INITIAL ~CF/DAY; ~AXI~UU ~CF/DAY~ FINAL ~CF/DAY FO~ATI~ FLUID ~ ~ ~ ~ ~ ~- TO SURFACE IN~ HR. ~MtN'. ~ouNT (FT. OR BBES.) DESCRIPTION GRAVI~ SALINITY Rw "~ TOTAL .O.~T~O. ~L~ ..COV...g ~ ~ '"' , DATA SETTING DEPTH ~1~-- FT. ,~1~ FT. ~[~, FT. ~1~,,,7, FT,. TEST SUCCESSFUL? MAX,CEOCK TIME 72 HRS. ~ HRS. ~ HRS. 7~ HRS. MECHANICALLY' ~ YES g NO , , INITIAL F.P. ~-- ~' ~ ~--~ ~ --~ ~-- ~0 ~ REMARKS INITIAL S. i PRESS. f~7~ /~ f~ t~0-- /~DICAFE ~/~ SECOND F.P. ~7~--~e / ~-- G87 ~'+~ --/~0 ~--/37~ PZU ~ SECOND S. ~.PRESS. /~0 /~~ ./~ 0 , ~ / ,, FINAL F.P. .FINAL S.I.PRESS. TESTING CO.. BHT °F. °F °F, °F. · TI CKET NO. ADDITIONAL REMARKS GEOLOG I S T DATE RP 464-! (CD-6-TA4) P RIINT/D IN Uo i ~LL STEM TEST REPORT BAS lC DATA OPERATOR ~'~/'/'ZzU ROA/ LEASEZ~'EZ~:',4 ,~/VER ~H/~WELL NO ~t~'~s~ ~. ] DATE~-/q- g/ MUD TYPE ~E~ WT. ?~ VIS. ~ W.L. RMF ~ . ~ OF. ] FORMATION ~/~ ELEV. ~ ~ TYPE CUSHION ~¢~ AMOUNT ~9~--,~, MECHANICAL DATA ~1~I E ~I: k.'~ A;] TEST NO.~' INTERVAL ~'~'~/ -- ~~ CONVEN.~: STRADDLE ~; O~~~i ~ !~ SUR.CHOKE~~. ~ BOT.CHOKE ~ DRILL COLLAR LENGTH ~ I.D. ~ "BBLS/FT. ~ -' 3~" ' ' - DRILL PIPE SIZE & '~PE LENGTH ' ~T. ~.~ NI.D. ~ "BBLS/Fr.~ TOP PACKER (S) SET AT: ~,~ AND AMT.PERF.ANCHOR BOT.PACKER~, _ T. mY~W~- ,O~E S,~ ,*T ,O~E S,ZE · ~7~ ,AT ,OLE VO~.(~,LS.) -~- Z~ TEST DATA SET PACKER @ ~.'/O OPEN TOOL@ ~t/q (aljd,) (P.M,) ' F PI ~ HRS' ~ ~' m. ;' S ' 4 SFP ~ HR.~O MIN.; SFS,~ HR. ~ MIN.: EFP~"' HR. ~ MIN . ;FSIP HR. ~ MIN. ;BLOW .... .. CUSHION TO SURFACE ~ HR. ~IN. ~GAS TO SURFACE ~" HR. ~MIN. GAS RATE: INITIAL MCF/DAY; MAXIMUM MCF/DAY; FINAL MCF/DAY FO~ATI~ FLUID ...... ~~*~~ TO SURFACE IN~ HR. ~MIN. R A~OUNT (FT. OR BBLS.) DESCRIPTION GRAVI~ SALINITY' Rw ,c,,, 3¢fY' ~/%~ /~ ~' ~/~/~m ~ o.. ~ ~ °F. O Y 17o5 'PRESSURE DATA SETTING DEPTH ~ q FT. q~ ET. ¢~?~ FT. ¢~ FT. TEST SUCCESSFUL? MAX.CEOCK TIME 2~ HRS., ~ HRS. q.~ HRS. ~ HRS. MECHANICALLY ~YES U NO INITIAL .... ' . l¢/q f?/O I¢g3 1¢3¢ ,.~ss,.~s FINAL F.P. FINAL S.I.PRESS. TESTING CO. BHT °F bF °F. °F. - · TICKET NO. ADD I T I ONAL REMARKS GEOLOG I ST DATE RP 464-1 "(CD-6-74] P RIINTED IN ,tILL STEM TEST REPOR BAS lC DATA OPERATOR ~'/"/£V/ed/Y LEASE.g£/Z./~A ,q/V~",~ /J/V/r WELL NO. ~STATE LOCATION ~/~7'~. / ¢~'~ S~- ~O~- ~C-~¢ XW~COUNTY/~,,~,~i~ /~~J/ FIELD DATE ~.-/~-~/ MUD TYPE~WT. ~ VIS. ~2 W.L. RMF ~ OF. ., , ~ FORMATION ~~/,~'~ ELEV. ~/ ~ TYPE CUSHION ~.~ AMOUNT MECHANICAL DATA TEST NO. J~' INTERVAL ~.~4~--/J/.~O CONVEN.~- STRADDLE ~; OTHER (TYPE) 1 SUP.CHOKE 3/~. ~ BOT. CHOKE ~/~ DRILL COLLAR LENGTH ~ I.D. -- "BBLS/FT. DRILL PIPE SIZE ..... ,~, ~.~. ' ~. 1~.~,.~. ~.~ "..~s/~.~ TOP PACKER (S) SET AT: · ' ...... ' ~ BOT.PACKER~ - zt~// ~/,, . _ T.D .... ,','.~, ~ HOLE SIZE CSG. S~ZE ~ WT. ~ TEST DATA ~ ' :"o ,,. :/ / b' o _,.A_ I SET PACKER @ ~,,. OPEN TOOL @ (A.M.)(P.M.) IFP - HRS. MIN.; ISI HR. MIN. SFP ,/ HR. ~ MIN.; SFSI HR... MIN.: FFP.~HR. MIN.:FSIP~HR.~MIN.;BLOW CUSHION TO S,URFACE -~ HR. ~- MIN. - ...... GAS TO SURFACE. ~--' HR. ~-- MIN. GAS RATE: INITIAL /~/~A/~- ,. MCF/DAY: MAXIMUM MCF/DAY: FINAL MCF/DAY FO~ATI~ FLUID il /~ '/~ /~ ~'' ~'~C)~/~/~ TO SURFACE IN HR. ~MIN. ~OUNT (FT. OR BBLS.) DESCRIPTION GRAVI~ SALINI~ Rw .~ . ~ ~ ' . ~ OF. ~.~ q:~:- .... I ..... , o,. ' TOTAL FORMATION FLUID RECOVERED ~ ~''' ~ / ' ~ ~ , F '/7,'~ (~ ~ ' ' ~ .' 43 PRESSURE DATA GAUGE LOCATION .,,~'t-(2.~ T~,~.~,~/~ '~'-.,~-, --'., ~ -~ .... ;/'' ~ o ,,' ~ : .,).. . :~' .,9'. --~'t~[~; ' ' ~ ,,"'~/ ~/~J~ ~ ~, ~'",~y/,~;' ~ MAX. REG. BHT . F. SETTING DEPTH MAX, CEOCK TIME INmTmAL H.H. '/~/ 't~ /~A /~f~ PRESSURES ~YES ~NO SECOND F.P. FINAL F.P. FINAL S.I.PRESS. TESTI FINAL H.H. BHT ~.-~ OF. ~ °F. ~. ~ OF. ~ OF. ,,,-'a~ TI CKET NO . ., GEOLOG I ST DATE RP 464-1 (CD-6-74) PRIIIiTED IN U. BAS I C DATA OPERATOR C_/~'~__~[-(Ot'~ LEASE P_,~,,~('_-~- PII,]~[~ [-,~'JJ'~ELL NO.'?~J-'~ . . . ~ ~ STATE FORMATION ELEV. ~ ~ TYPE CUSHION ~~ AMOUNT MECHANICAL DATA .o..'7 SUR.CHOKE~/~J:~/~) - OR,LL COLLAR LENGTH ~ , O. - "BBLS/FT. , . , DRILL PIPE SIZE G~'( .T.D ..... ' RAT HOLE VOL.(BBLS.) . .. ~'~ . _ ~ . ~ ) FT.:SIZE & WT. ~~~ FT.;NO.REC.__ ~__.. & . ........ TEST DATA j SET PACKER ~ ~'. 0('t' OPEN TOOL @ 2.' OR ' 4. (A.M..) ,FP HRS. 3~) MIN.; ,SI HR. MIN. CUSHION TO SURFACE ~ HR. ~ MIN. ~ GAS TO SURFACE ~'HR.~MIN. ~S RATE: INITIAL ~O~E..~ ~CF/DAY: UAXlMUM ~CF/DXY: FINAL UCF/DAY , ,. ~OUNT (FT. OR' BBLS.) DESCRIP'~ION ' ' GRAVI~ SALINITY Rw - '~ '~ ' ~. 0 F. REMARKS. m/]"~Z(~_..~ . ,.~~. I0~ %, (~. ~ ......... PRESSURE DATA -2 r' GAUGE LOCATION '-T'oP, J N% - f~o.T, Chi S , ~O OUT ~OT, C)~' MAX. REG. B,T ~ °F. SETTING DEPTH ~..~$ FT. '~ ~ FT. ~.qS FT ~q~ FT TEST SUCCESSFUL~ '~__ .... MAX.ClOCK TIME ~ ~ HRS. ,,~ HRS. ,,, ~ ~ HRS. q ~ HRS. MECHANICALLY ~YES ~ NO ....... INITIAL .... ~]~3 . ~]~ , . ~.~OO ~ ~ PRESSURES OYES ~NO INITIAL S.i.PRESS. ,,, ..... SECONO S. - FINAL F.P. FINAL H.H.' .... ~3 ~') I]3~ TESTER ~_~ . (, ~.~~ ..... ' BHT OF OF. OF OF. · . TICKET NO. I ~, ~ . ~ ..... i :11¸ .~ ~. O ~LL STEH TEST REPORT(,. BAS I C DATA OPERATOR ¢,L~i. VK0hi LEASE BEL~G~ K\VEF~ ~)~T,WELL NO lt~--3S STATE DATE ~--~--~! .. MUD ~PE C~EL WT. m~ VIS. ~ W.L ~, ~) R.F ~'~ OF. MECHANICAL DATA TEST NO. 5 INTERVAL ~? --~¥'~--) ,.. CONVEN.~; STRADDLE r-l; OTHER (TYPE) ,, ../~,, SUR.CHOKE E_ ~ BOT. CHOKE ' DRILL COLLAR LENGTH ,. ~&,, TOP PACKER (S) SET AT: HGq3 AND AMT.PERF.ANCHOR q NOT.PACKER* 'T.~. ~q~ ,OLE S,ZE ~'~ ,~T HOLE S,ZE %~' .AT HO~E VO~. (,,~S.) H. ,~.,~ ' ~We/' C&l~, FT.:SIZE & WT. ~ FT. ; NO . REC. ~ & CS~.S)ZE ~ WT. H3,$~ ., TEST DATA · 9~'%~ (A.M.)(~g~) ,FP ?-- o .R. .IN. SET PACKER @ ~°~W~ OPEN TOOL @ HRS. MIN.: IS, ~ S'FP ' HR. MIN,; SFSI ~ HR. ,. MIN.; FFP HR.-- MIN.IFSIP HR. -- MIN.;BLOW CUSHION TO SURFACE ~ HR. ~ MIN. ~ GAS TO SURFACE~HR.~MIN. ~S RATE: INITIAL ~O~~ MCF/DAY; MAXIMUM ~ MCF/DAY; FINAL ~ MCF/DAY FO~ATI~ FLUID /'/~ ~QA.~,~ . To SURFACE IN~ HR. MIN. ~OUNT (FT. OR BBLS.) DESCRIPTION GRAVI~ SALINITY Rw · OF' .... , -,, X T~,.~~, ~u~. ~-',,,,~,, ~I ~s* ~ ~,>~m ~ > i&~ ~~ ~ o~. TOTAL FORMATION FLU I D RECOVERED REMARKS ~ · ' F v ~ - / - PRESSURE DATA GAUGE LOCATION'-'~3j~-' [)pl~..l/. ..~.~f.~/'.' "J"~p Ot.)~l~ /.~o~", ~]~;: ~>T. ~)~. MAX. REG. BHT .. F. **T, , ,* ****, %00 *T. V6% *T. H~a~*T. ~'~/ *T. T**T*UCC****~L* MAX.CLOCK T,ME ~ HRS. ~8 HRS. L~ 8~ HRS. ] ~ HRS,:,, .ECHANICALLY ~ YES 0 NO INITIAL H.H. ~qG] ~flS] ~fl~ PRESSURES ~YES INITIAL S.i.PRESS. ~0 I G~S IGql t:Gq~ .J*~ ~~. .~,,A, ~.~. ~~'~0~ FINAL S. I .*"ESS. TESTING C;: BHT ~' O °F ~ 0 °F- 0 °F. ~ O °F. I J . "] TICKET NO. BRU 214-35 December 17 - 22, 1980 Rig up. · December 23 Drilled 79' of 30" conductor. December 24 Drilled rat hole and mouse hole. December 25 Drilled 17~" hole to 101'. Mud weight 78 and vis 138. Spudded. 78 P.C.F. December 26 Drilled 17%" hole to 420' POH. Picked up 26" hole opener and opened hole to 420'. ,ii 74 P.C.F. December 27 Circulated hole clean. Rigged up and ran 10 joints of 20" 94~ ft. K-55 butt. casing. Shoe at 410'. Stab in the shoe and cemented casing with 490 sacks of class "G" mixed with 2.4% pre-hydrated gel by weight of water. Good returns while cementing. , . " .. 7 P.C.F.~ December 28 Cut off 30" conductor. Cut off 20" casing and installed 20" top flange with 20" shaffer single gate and 20" hydril. ~'- -~.~ .... ~.~L~..~ .' .'~ 67 P.C.F. December 29 · Tested hydril, ~ipe rams and choke mainfold to 800 psi. Picked up 17 1/2" bit Ran in and cleaned out cement and shoe. Drilled 17 1/2"'hole to 460'. Pooh. December 30- Picked up dynadril and bottom hole assembly. Ran in hole. Oriented Dyna drill. Drilled and surveyed to 697'. Note: 662 ft was 5°N 59E. 68 P.C.F. December 31 Continued Dyna drilling and surveyed to 739'-/ Pulled out of hole. Laid down dynadrill. Made up bottom hole assembly~ Run in and drilled 17%" to 1,179 ft. 71 P.C.F. BRU 214-35 PAGE TWO ganuary 1, 1981 69 P.C.F. Drilled and surveyed 17%" hole to 1,211 ft. Pulled out of hole. Picked up dyna drill. Ran in hole with dyna drill. Dyna drilled and 17%" hole to 1,321 ft. January 2 68 P.C.F. Continued drilling 17%" hole to 1,644 ft. january 3 68 P.C.F. Continued drilling 17%" hole to 2,087 ft. January 4 70 P C.F. Continued drilling 17%" hole to 2,444 ft. January 5 70 P.C.F. Dyna drilled to 2506'. Attempted survey. SurVey tool stuck. Survey tool line parted. Pulled out of hole. Recovered survey tool and replace mule shoe assembly. Drilled to 2725'. Unable to hold orientation of dyna drill. Pulled out of hole. Laid down dyna drill and 17%" bit. Picked up new dyna drill and 12%' bit and ran in hole. January 6 ' 71 P.C.F. Dyna drilled 12%" hole to 3,098 ft. Directional control improved in reduced hole size. Pulled out of hole and laid down dyna drill. Picked up new bit and locked bottom hole assembly. January 7 71 P.C.F. Reamed thru dyna drill run 2,729'-3,098' . Drilled and surveyed 12¼" hole to 3,642 ft. Pulled out of hole to change locked bottom hole assembly to angle dropping bottom hole assembly.' January 8 73 P.C.F. Ran in hole and drilled 12¼" hole to 3928 M.D.'Circulated. Made short trip. Pulled out of hole for logs. .Rigged up Schlumberger.r` Ran DIL, long spaced sonic. . ~ January 9 71 P.C.F. Continued logging. Run SDC/CNL/Gamma Ray and Sonic Log. Rigged down Schlumberger. Picked up 17%" bottom hole assembly and hole opener. ~Opened 12¼" hole to 17%" and drilled 17%" hole to 3,'025. January 10 71 P.C.F. Continued opening 12¼" hole to 17%". Drilled to 3,934. BRU 214-35 PAGE THREE January 11 71 P.C.F. Circulated bottoms up. Dro~ped survey on-line. Line came off shield. Pulled survey tool. Pulled out of hole. Laid down hole opening bottom hole assembly. Left bull-nose on hole opener in hole. Rigged up and ran 101 jts. of 13-3/8 68~ . K-55 butt..casing with shoe at 3930'. .. January 12 73 P.C.F. Stabbed in to duplex collar at 3880'. Circulated hole for 2% hours. Pumped 10 barrels of water ahead of 1,100 sacks of class "G" cement mixed with ~.4% prehydrated gel by weight of water. R/D. Halliburton. Wait on cement 12 hours. Nippled down BOP. Removed 20" casing head. Cut off 13-3/8 casing head. Installing 13-3/8 of slip mount and well head. January 13 72 P.C.F. Continued rig up of Class III, BOP. Tested pipe rams, blind rams, hydril and all valves to 3000 p.s.i. Oil and Gas Conservation Commission Waive Test. Made up 12¼" bottom hole assembly? Ran in hole. Tested casing to 2500 p.s.i. RIH to duplex collar at 3880'/ Circulated and conditioned contaminated mud. Drilled out collar and 10 ft. of cement. January 14 70 P.C.F. Drilled out cement and shoe at 3930'. Drilled 12¼~' hole to 3935'. Picked back up into shoe of 13-3/8". Worked pipe attempting to find hole opener, bull nose l~tin hole. On second attempt set down on Fish. Top of Fish 3931. Pulled out of hole. Picked up Tri-State junk basket and head, Run in hole. Attempt to washover fish. Pulled out of hole with no recovery. Laid down junk basket. Run in hole open ended. Hung pipe at 3933'. Rigged up Halliburton and laid 75 sacks of Class G. Pulled out of hole at 3888'. Reversed out excess cement. Made up 12¼ bottom hole assembly and ran in hole to 3800'. Cleaned out cement at 3925'. January 15 ~ 76 P.C.F. Hit bull nose at 3931'. W6rked pipe past bull nose several times. Drilled 12¼" hole to 3969'. °.Increased torque due to bottom, stabilizer going past bullnose. Drilled ahead to 4335'. January 16 ~, 77 P.C.F, Drilled 12¼ hole to 5000'.. January 17 78 P.C.F. 'Drilled 12¼ hole to 5743'. Survey at 5622 was 5¼°S 38 E. January 18 80 P.C.F. Drilled 12¼ hole to 6015'. Circulated bottoms up. Took survey and wiped hole to shoe of 13-3/8" casing. Hole extremely tight. Drag of 135,000 lbs. · BRU 214-35 PAGE FOUR January 19 78 P.C.F. Strapped out of hole. SLM 6022'.~ Rigged up Schlumberger to log. Ran in hole with DIL. Tool stopped at 3475!. Rigged down loggers. Run in hole to .6022. Circulated bottoms up. Chained out of hole to shoe of 13-3/8" at 3930. Continued to pull out of hole. Rigged up loggers and ran in hole with DIL to 6018'. January 20 78 P.C.F. Continued logging. Rigged down loggers. Made up 12¼" bottom hole assembly. Drilled 12¼" hole to 6335'. January 21 79 P.C.F. Continued drilling 12¼" hole to 6396. Made wiper trip. Hole extremely tight. Pumped out 9 jts. Dragged 150,000 lbs. over string weight. Circulated bottoms up. Surveyed at 6335 1½°S 30 E. Drilled 12%' to 6760'. January 22 80 P.C.F. Drilled 12¼" hole to 6813'. Made 12 stand short trip. Found 8 ft. of fill. Circulated 20 minutes. Took survey at 6813'. 3/4°S 18E. Rigged up Schlumberger Could not get DIL past 6318'. R/D Schlumberger. Made clean out run to TD. Circulated hole clean. Rigged up Schlumberger., Ran in hole with DIL/SFL/Sonic Tool. January 23 80 P.C.F. Continued to log. Rigged up tool and ran 70 jts. of 9 5/8" casing. January 24 Continued to run 9-5/8" casing. January 25, 1981 Rig down casing crew, rigged up Halliburton. Cemented through shoe. with 618 sacks of class "G" cement with slurry weight of 116 pcf. Good returns throughout the job. Failedto bump plug after circulating displacement Pumped an additional 15 barr'~ls which was 3% over theoretical. Shut down pumps with shut-in pressure of 700 psi. Less 700 psi off casing. Dropped bomb in open state collar with 800 psi. Circulated hole. Cemented 9-5/8 casing through stage collar with 324 sacks of class "G" with slurry weight 117 lbs per cubic foot. 9-5/8 casing shoe at 6818. Float collar at 6732. Stage collar at 4666. Nipple down BOP and set 9-5/8 casing with 200,000 lbs. tension. Cutoff 9-5/8 casing installed Grey tubing head and equipment. Modified choke and kill lines. Cutting section of flow nipple and nippling up. · J~ua ..~ 26 Completed nippling.~up of BOP. Tested same to 3000 psi. Tested hydrill to 1500 psi. Ran in hole with 8-1/2 bit and 8-1/2 bottom hole assembly. Tag, plug and stage collar at 4664. Drilled out stage collar and continued in hole. Tag bridge at 6400. Drill stringers and spotty cement to top of flow collar at 6739. Continue to drill stringers at 6690. Circulated and conditioned mud. Pulled out a hole rig up Dresser Atlas and ran in the hole with CBL/VQL. January 27 Continue to log with major problems. Unable to get gamma ray in and collar locator to work. Made up 8-1/2 bit and ran with 9-5/8 casing scrapers. Ran in the hole to 6731. Circulated and condition mud. January 28 Pulled out a hole. Rigged up Schlumberger - ran in hole, logging. Ran in hole with 4" casing gun perforaged 9-5/8 casing with four 1/2" jet holes per foot from 6530 to 6547. Pulled out of hole. Picked up Halliburton DST tools. Ran in hole with DST assembly. January 29 i Set packer at 6503. 'Tail 'to 6522 with no cushion. Open tool and ran DST. Charts indicated plugging above inside recorders during second flow period. Pull out a hole With DST. Ran in hole with Halco EZSV cement retainer on 4-1/2" drill pipe set at 6496. Rigging up Halliburton and tested lines to 5,000 psi. Squeezed through retainer with 20.5 barrels of class G neat cement. 118 pcf. Pulled out of hole. January 30 Rigged up Dresser Atlas lubricator. Ran in hole with casing gun, shot four ½" holes at 4930'. Ran in hole with RTTS, set packer at 4830'. Tested lines to 4000 psi. Squeezed holes at 4930' with 25.6 barrels of class G cement with weight of 118 pcf. Did not establish squeeze"pressure. Cleared perfs with 17 barrels of mud. Wait on cement 2 hours. Requeezed perfs at 4930' with 25.6 barrels of class G cement with slurry weight of 121 pcf. January 31 Waited on cement 3% hours. Released packer. Pulled 1 single set packer ,and pressure tested casing 2000 psi. Held okay. Pulled out of hole. Rigged up Dresser Atlas. Ran in and shot 4 jet holes per foot at 4798'. Run in hole with RTTS and set packer at 4708'. Squeeze perfs at 4798' with 30.7 barrels of class G cement, Slurry weight of 118 pcf. Release packer and pulled out a hole. Rigged up Dresser Atlas. Ran in hole with 4" casing gun and shot four %" jet holes per foot at 4650'. Run in hole with RTTS to 4500'. February 1 Set RTTS packer at 4514'. Squeeze perfs at 4650' with 26 barrels of class G cement, ll9pcf. Released packer and pulled out of hole. Ran a hole with 8%" bit and 5" casing scraper. Polished plut to 4620'. Rigged up Dresser Atlas. Ran in hole with 4" casing gun. Shot four %" holes per foot at 4590'. Run in hole with RTTS set packer at 4435'. Squeezed perfs at 4590' with 30.7 barrels of 119 pcf class G cement. February 2 Pulled out of hole~ Rigged up Dresser Atlas. Ran in hole with 4" gun. Shot four %" jet holes per foot at 4395'. Squeezed perfs at 4395' with 31 barrels of 120 pcf class G cement. Released packer. Pulled out of hole. Ran in hole with8%" bit and 9-5/8" scraper. Tagged plug at 4354'. Pulled out of hole. Rigged up Dresser Atlas.. Ran in hole with 4" casing gun and shot four jet holes per foot at 4284'. Ran in hole with RTTS and set packer at 4121'. Squeezed perfs at 4284' with 31 barrels of 117 pcf class G cement. Released packer, pulled out of hole'. Rigged up Dresser Atlas.. Ran in hole and shot four %" jet holes per foot at 3992'. Ran in hole with RTTS set packer at 3840'. Squeezed perfs at 3992 with 31 barrels of 118 Pcf class G cement. February 4 Released packer. Pulled out of hole. Run in hole with 8-1/2" bit and 9-5/8" casing scraper. Tagged plug at 3940'. Drilled cement and plugs and contaminated mud from 3940' to 4430'. February 5 · '~ Drilled cement a~d cleaned out stringers to cement retainer at 6496'. Pressure tested casing at 1500 psi. No leak off. Pulled out a hole. Rigged up Dresser Atlas. Ran CBL from 6496' to 3500'. Cement bonding showed significant improve- ment. Pulled out of hole picked up perforating gun. ECEIVED · aska Oil & Gas Cons. February 6 Ran in hole with perforating gun and perforated with 4 jet holes per foot, from 6,008 to 6,026. Made uR Halliburton DST. Ran in hole and set packer at 5940'. February 7 Ran second DST released packer and pulled out of hole without final shut-in laid down DST. Picked up Halliburton cement retainer and stabin tool. Ran in hole and set retainer at 5935'. Stabbed into retainer stinger plugged off twice. Pulled out of hole attempting to reverse out continuous plugging. Found large amount of cement scale inside drill pipe. February 8 Rigged up Dresser Atlas ran dump bailer with 3 sacks of class G cement to 5931 and dropped cement. Pulled out of hole. Ran in hole with perforating gun and shot 4 jet holes per foot from 5870' to 5861' for DST #3. Made up Halliburton DST set packer at 5820'. .February 9 . Ran DST #'3 charts indicated formation plugged off. Made 8%" bit and 9-5/8" casing scraper. Tagged top of plu~ at 5925'. Circulate and condition mud and pulled out of hole. Rigged up Dresser Atlas and ran in with 4" casing guns and perforating tool. Perforated 5861' to 5870' with 4%" jet holes per foot. February 10 Ran in hole with DST and set ~acker at 5816'. Released packer and pulled out of hole. Charts indicated test mechanically successful rig-up Dresser Atlas and ran in hole with cement retainer and set retainer at 5799'. Ran in hole with dump bailer and dumped 3.8 cubic foot of class G neat cement on plug at 5799'. Ran in hole with 4" casing gun and perforated 5408' to 5418' with 4%" jet holes per foot. ~ February 11 Ran in hole with'set packer at 5348' open tool for. initial flow period. Flow declined to very faint. Released packer and pulled out of hole. Rigged up Dresser Atlas ran in with cement retainer and set at 5341'. Run in hole with dump bailer and dumped 3~8 cubic foot of class G cement on plug at 5341'. Rigged up Dresser Atlas and ran in hole 4" casing gun perforated at 5172' to 5182' with 4%" jet holes per foot. February 12 Set RTTS at 5128' DST showed light blow declining to weak released packer and pulled out of hole. Charts indicated toot had plugged. Pulled of hole laying down 4%" drill pipe. Rigged up and began picking up 3%" 9.3 # N-80 buttress tubing. BRU 214-35 February 13 ~. 73 P.C.F. . Picked up and ran in hole w/154 jts of 3%" tubing. Pull out of hole and lay-down tubing. Made up DST on original 4%" work string and ran in hole. Set RTTS at 5136'. Open tool. Blow was very weak, eventually died. Test was mechanically successful. Charts indicated partial plugging. Rigged up Dresser-Atlas and ran hole with Halliburton cement retainer. Set cement retainer at 4850'. Run in hole with dump bailer and dump 3.8 cu. ft. of Class G cement on top of retainer. February 15 72 P.C.F. Picked up a 160 jts of 3%" N-80 12.95# tubing and ran in hole. Circulated and conditioned mud. Pulled out of hole. Rigged up Dresser-Atlas and ran in hole with 4" casing gun. Perforated 4 jet holes per ft. from 4631' to 4645r Rigged up and ran in DST tools. Set packer at 4573'. Open tool. Light blow continued throughout test. February 16 Released packer and pulled out of hole. Rigged up Dresser-Atlas. Ran in hole with cement retainer. Set retainer at 4520'. Ran in hole with dump bailer and dump 3.8 cubic ft. on top of retainer. Ran in hole with 4" casing gun and perforated 4 jet holes per ft. from 4380 to 4390 for DST 96, Picked up Halco DST tools and set packer at 4353. Open tool steady weak blow throughout test. Release packer and pulled out of hole. February 17 72 P.C.F. Ran in hole with bit and casing scraper for cleanout and prep for DST 97. Pulled out of hole. Tested all BOP to 3000 p.s.i. Tested Hydril to 1500 p.s.i. Run in hole and cleaned out sand and .cement from 4510~. grilled out EZSB at 4520' and.cleaned ~ou~ to 4750'. ~.Circulated and conditioned hole. Pulled out and picked up casing scraper and made casing scraper run. Made up RTTS tool on 4%" drill pipe. Ran in and set packer at 4567'. Squeezed perfts at 4631 to 4645 with 38 barrels of class G cement. · · February 18 71 P.C.F. Released RTTS and reset at 4318'. Circulated and conditioned mud. Squeezed perfs at 4380' to 4390' with 46 ~arrels of class G cement. Released RTTS and pulled out of hole. Picked up 8%" bottom hole assembly and casing scraper. Ran in hole and tagged top of cement at 4322'. February 19 72 P.C.F. Drilled and tested DST perfs 4380' to 4390' to 1000 p.s.i. Drilled out and tested DST 95 perfs 4631' to 4645' to 1000 p~.i. Pulled out and laid down bit and casing scraper. Ran in hole with 4 jet holes per ft. and shot from 4684' to 4700'. Picked Halco DST tools. Ran in hole, set packer at 4643'. BRU 214-35 PAGE TWO February 19 (Continued) Continued DST Zone #8. Release packer and pulled out of hole. Charts indicated plugging occurred. Ran in a hole with 4%~' drill. Plugged 9-5/8" casing from 4714 to 4614 with 36 sacks of 118 pcf class G cement. February 20 71 P.C.F. Ran in and perforated 9-5/8" casing with 4 jet holes per ft from 4327'. to 4334'. Made up DST tools and ran in hole. Set packer at 4281'. Opened tool and medium blow occurred. Blow continued until dead. Release packer and pulled out of hole. Charts indicated plugging. Made up RTTS squeeze packer and ran in hole. Set packer at 4225'. Attempted to establish breakdown. Established pump in rate of less than 1 cu. ft. per minute. Let off RTTS and released same. February 21 70 P.C.F. Pulled out of hole. Made up 8%" bit and cleaned out sand bridge'f~om 4337' to 4347'. Made up RTTS and set at 4223~. Pumped 150 sacks of 118 pcf class G cement. Released packer and pulled out of hole. February 22 71 P.C.F. Made up bit and casing scraper. Ran in hole and located top of cement at 4230'. Cleaned out cement and cement stringers ~from 4230' to 4636'. February 23 75 P.C.F. Continued to circulate and condition mud for perforating. Perforated with 4 jet holes per ft. Intervals 4185' to 4205'. ~4110' to 4126'. 4,082 to 4104. February 24 78 P.C.F. Picked up 4%" drill pipe. Ran in hole with bit and casing scraper. Circulated bottoms up w/bit at 4218. 'Made 10~stand short trip. .Ran in hole to 4218'. Circulated approx. 50 barrels of gas-cut mud. Raised mud wt. to 77 pcf. Circulated bottoms up. Mud wt cut from 77 to 74. Raised mud wt. to 78 pcf. Pulled out of hole and laid down casing scraper. Ran in hole with bit Circulated bottoms up approx. 50 barrels of mud wt cut from 78 to 77~p.c.f. February 25 77 P.C.F. Made 10 stand short trip. Gas in returns. Shut_ down for 1 hour then circulated bottoms up. Pulled oUt of hole laying down drill pipe. Tested class III BOP for 3%" tubing.. February 26 73 P.C.F. Ran and landed 150 jts. of 3%" 9.2 lbs per ft. Armco Seal Lock tubing with 3 packers. Ran and landed 65 jts of 2-3/8 4.7~ N-80 EUE 80 rd tubing with position no. 1 nipple at 2031 ft. Pulled down BOP and installed gray dual tree and tested same to 3000 p.s.i. BRU 214-35 PAGE THREE February 27 .~. 73 P.C.F. Dropped ball down 3%" tubing. Ball seated'in shear nipple. Pre'ssure in stages to 2600 p.s.i. Set 3 packers. Top packer at 3985. Middle packer at 4248'. Bottom packer at 4435'. Ran in hole with 2-5/8" perforating guns and perforated 9-5/8" .casing with 4 jet holes per ft. From 4484' to 4504'. Pulled out of hole and stuck perforating gun and ,F" nipple at 4433. Pulled out of rope socket with 3900 lbs. leaving 26 ft. of perforating gun fish stuck in tubing. -Ran in hole with pulling tool and drive gun to chase to bottom. 26 ft. of fish. Top of fish estimated 4610. Ran in hole with CA White Tan. 3500 p.s.i. Pressure reported in 2 72 hour clocks to 3900 ft. February 28 Open well and unloaded well. Gas to surface in 3% minutes. Continued to test well. .. March 1 Pulled out of hole' with wire line but no bombs recovered. Left bombs in hole. March 2 '.. Runin hole with C. A. White spear and attempt to recover pressure bombs. Left two pressure bombs connected with knuckle jt in hole. Ran in hole and opened bottom interval to flow. Tested bottom interval for approx, four hours. Encount~re( ice and frozen mud at surface. C. A. White made clean out run with tool. Ran in hole with Baker 2.75 FSR bypass blanket plug to set in "F" nipple at. 4443'. March 3 Pulled out of hole and tested plug. Plug did not hold. Pulled out of hole and redressed blanket plug. Ran in hole and landed blanket plug and ,F" nipple at 4443' and sheared off. Pulled out of hole. Tubing pressure at 130 p.s.i. Ran in hole with feeler run. Tagged blanket plug at 4443'. Ran in hole with C. A. White with selected tool to open .~'xa" at 4058. March 4 · - Open well to test perfs 4082'to 4205'. Gas to surface in 9 minutes. Flared gas on 3/8" choke. Well stabilized. March 5 continued flaring well. Closed ,iXA" sleeve at 4058,'. Bled off tubing pressure to 1050, p.s.i. Check for leak in .'~XA" sleeve. No leak. Picked up shear prong - and.~at~emp~ t6 shear~pin~ .in P..~R,byp,ass p.lugl at 4443'. ~Pi~k-up sand pump and baile~ and recovered approx. 3' gals. of bar. · .. March 6 Continued running bailer and sand pump. Ran in hole with closing tool and closed sleeves. Redressed 2-3/4" FSR Baker bypass and blanket plug in "F" nipple. Bled · . off pressure above plug from 1300 p.s.i, to 0 and plug held. BRU 214-35 PAGE FOUR March 6 Poured 10 gals. of methanol.~down 3%" tubing and filled tree with methanol between valves. Cleaning mud pit and'~raining up rig. Prep to release rig,' March 7 Released rig at 2:00 p.m. Prep to stack rig on location MRS . o -' , ..~ ~ . KB to TUBING H~,.*r) C}ONUT ~ . · -~, t~ J.-105.82_.4,,~ X'O PUP' 5.05' I10 87 · .. ' I~'n~ ~ F NIPPLE 1.14' ii .... x-o 5. o' 7.11 ~ . .. ~410' ~ 2030.99" 2~"~O.D. 4.7 ~ HEATER STRING ~039.99' ""~ :"':~: --I~ ~TS. 3~.'; 9.2, N-80 TUBING 3859.10' ~ ~ 3930''~ ' · '3981.26 · "XA" 3985.36' ~ OTIS. SLEEVE 4.10' BAKER "FH" PACKER 8.15' · +~~; ~.',~ a~3.51' -..~:,~'~ I PUP BUTT.,.dOINT ~. /z' TBG ,,.~~:~~.08 3997. 59" ' ~" ' - 3998.7.3'"' ~ ~"F" NIPPLE ~ '..'1,14' ~.??.~:~:~:.:~;~ - -., ,.;~ X- OVER , K .~. . - 4082' '":::'~""."?. .... -- 2 ~TS. 3.~ SEAL: LO TBG : 58.91 { i" 4058.55' '~OTIS "XA" SLEEVE 4.88' ., :.' ~': --- -- ~ - 4104 ..... 411.0' . 4126' --5 dTS. 3~ SEAL-LOK TBG 144.08 . 4185~ · ~~ X , 4Z 2~ BROWN ~CC" SAFETY ~OINT -'.. - ,:'~:~1~62' . ~4: ~' X- OVER PUP . -'"' ' ' 5. I0' " ,.I jT;.. 3~"SEAL-LOK TBG. ~ - 29.2-6: - ~':-?~-::-' 4Z48 .~7'" '' ,[~ BAKER "F H" PACK E R ' : 9.05 ':~ .: 'J/,'. ',. ..-..' r.': ~ : ~n ' -': ' ::'"' ::.-':.:.' .- -' 4327' -- 4 JTS. 3 SEAL-LOK TBG. 115:24' ' 4334' : ' ' ~.. - :' . . ~-' -. : .:, ;. " " i ' . .... ~.~,~, . _ . . '~: .... . ,~'~~:," ~4372.86, '.'"~ X OVER ~'~:;~'~:~'~?.~:~::':~'~'~:~"~:~ .~o,o.~u, ~ BROWN CC SAFETY JOINT " ' "I 4375 34 ~ ' OVER ' 438o~ ' . ~ .,~ X- ~ .. ' .' '~''.' "- .:~:~ '. 90' -,,~.:,:~.-: '"-"., I~ . 44~3.36 ~"F'/NIPPLE , ...... :' I. 14 '"'::':':: '' ~2 PUP 3~ BUTT TBG. - ... lO 45: ~'?~": .. ~ ~ "._~ 4456 33'~";~J;' -..- ." · :~¥:,~ ': ~ ' 4520' -:""~:~; '" '~, ~ . ...... ~;.. ~ 4590' ~'~'?' ~?~: ' ~" ' 'i I 463 I' .~- . :): ........ :==' ... ';~??~, 4645' Top'°'f Plug 4636' '- B,R.U..- 2,1 4 ' 3 5 '. 4650' ., ~ ..... ' ' ..-- -. J::::' :' ::'?:" 493o' CASING TUBING DET I 6530'- , 6547' SECTION ~4 T. 13N,,R. IOW. . ": 6796' .~ ~ CHEVRON U.S.A. INC. -: - '- T.D. 68]9' ' """' ';' "" ':"'" ':" TRANSMITTAL.~^,ND ACKNOWLEDGEMENT OF RECEIPT O~,r ~b\TERIAL - (ALASKA) TO: DEPT.: PLACE: .. .. THE FOLLOWING IS A LIST OF MATER. IAL ENCLOSED HEREIN. FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. ElY REMARKS ON OTHER SIDE, THIS SHE'ET ANCHORAGE, ALASKA 99510 GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY CHEVRC)N lISA COMPANY BRU-214-35 WELL NAME Bel uga,,~ Alaska LOCATION AL-1 2-80-D38 Sinqle Shot . 1/29/81 TYPE SURVEY DATE JOB NUMBER BOB PRICE Engineer NAHE T I TLE S I GNATURE DEPTH INTERNAL ...... 460. , 6819 , FROH TO 12/28/80 1/21/81 DATES SURVEY WAS TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in Strictest confidence. Additional copies of your survey report can be made from the original by any blueprint company. RECEIVED OCT 2 6 1982 Alaska Oil & Gas Cons. Commission Anchorage .... -.-:--:.' .......... VERTICAL SECTION , !' CHEVRON USA .~., - WELL 214-35 ~ ,~-~-;:_: .............................................................. RADIUS OF CURVATURE : ' MAGNETIC SINGLE - SHOT SCALE I"" = I000" dAN. 27, 1981 ... 400' '- BO0- · "~:,~ ~' ~ ~',;', .... ~ .... 1600 , ,~-,,.~,~,,' ',,:,,~,.~.~=~,,,.,,:...~.,~.~,,.~ ....... '- ~.~}~,,.. :~ ~,¥...'.,~ ..... ,.. ,,...~ ~':~,..-,~ ....... ...... , .......... ..~,,~...~.~ ~....? . 600~ · ,. ~ ..... . -. .... ............ ~'.:. ,.~'. ~...,..,.. ~, -;,.~..~ ,. :.,.[r~'~r~.. ..... , ~ : ~ . .: ........... · .; . . ; . ~, :.. ~ , '~..~ '~.~: ~52o ; . .... ~ , . . ~ : - , ~ ,, ...~ ~. · { ' ~.-.;~ - ~ ~ - - ' { 5600- .......................................................................................... ~---~...soo~ T V D = 6 0 01 ' : { TMD = 6819 ~ .. ~ ..... .~ .... : ......_ ~ ,' ~ ....... ~ ............ ..... ..... ~.~: ,¥: ~ ....... ...... · .~ .: ...... ' '_ , '. ALL DEPTHS SHOWN ...... ARE TVD - .. .. j : · HORIZONTAL VIEW ...... CHEVRON USA _ .......... WELL 214-$5 -- . "'!. --':".: ............................................. : .............................................................. RADIUS OF CURVATURE .................. ..................... ................ ................... MAGNETIC.,i. SINGLE - SHOT : SCALE = I000" - ........ : ......... ; .._:. : .... , ....... .............................................................. :-: .... :-'dAN. 27, 1981 ...................................... . .. ~ ......., ................................. : ...... .... . ......... . ... ~ --- . . ..... ..... ~. ................~ . . ,. .. .+ ....... .~_ .._' .. ~. .... £... , - ..... ~ ................ ~ ...................... ~ ........ ~ ........................ ...... ... .-... ................ . ............. ~ . ..... ~ ................. ~ .... ....................... .:,.:,: ............................................ ~. ....................... L .............. ~, .................................................... : ~ ....... ........ . .......... : ..... .................. : ........ ~ ..... . ...... . . . . .... ; ........... . ....... : : ........ ......... ~ .......... . ~ ............. ~._ .... .............. · .......... ~ - : ......... _, ,_ , : ............. ~ ......................... ._. ~ - ............ '.,,~ .................................. :....~...,. ............................................. : ................................................................ - ........................................................................ . .. ' F L U I D S A M P L E Dqk k Dote 2-20-8l TicketNumber 697394 Sampler Pressure P.S.I.G. at Surface Kind Halliburton of D.S.T. CASED HOLE Location ANCHORAGE Recovery: Cu. cc. Oil Ft. Gas cc. Water Tester WARREN Witness BILLINGS cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF # 58 NM Gravity ° APl @ °F. EQ U I PM E N T & H 0 L E D A T A i Gas/alt Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation 77.1 ' GL Ft. CONTENT 7I I I Net Productive Interval (4320 - 4327 ) Ft. Recovery Water ~ ~ ~°F. ppm All Depths Measured From Kelly Bushing Recovery Mud ~@~°F. ppm Total Depth, 4600' PBTD Ft. Recovery Mud Filtrate __ @ ~ °F. ppm Main Hole/Casing Size 9 6/8" Mud Pit SampleI@ ~ °F. ppm Drill Collar Length - I.D - I.D, 2 750" Mud Pit Sample Filtrate ~ @_ °F. ppm ~,~*~t.-,,,~ TUBING 4241' . Packer Depth(s) 4281 ' it. Mud Weight ~ vis ---3~ ~ec. Depth Tester Valve 4257' - - Ft. TYPE AMOUNT Depth Back Surfac~ . _ .Bottom Cushion WATER 100' Ft. Pres. Valve NONE Choke~4 -½II-3/8"-¼"Choke .7 Recovered 3791' Feet of ,gas and mud cut water ~ 'ri Recovered 570' Feet of formation sand Recovered Feet of ~. Recovered Feet of Recovered Feet of Remarks SEE PRODUCTION TEST DATA SHEET... tN ,. ~. r' I ~ r' ,% KCLCIVCL/ OCT 2 6 ]982 ;Alaska Oil & Gas Cons. COmmission Anchorage / TEMPERATURE Depth:4245' Ft. Depth:4265'Ft.[ Depth:4269' Ft. (o0:00-=4:00 h~.) ' ' 48 Hour Clock 72 Hour Clock 48 Hour Clock Tool ., Est. (~-I 1 ] °F, Blanked Off NO Blanked Off NO Blanked Off NO Opened 1407 Opened Actual °F. Pressures Pressures Pressures Bypass 2028 Field Office Field Office Field Office Reported Computed Initial Hydrostatic - - 1773 1774.4 1772 1 775.5 M~,,t,, ..~: Initial 50 39 2 634 634 1 624 631 9 .~..o_ FI ow . ' · · :,, ~., Final 1537 1538.9 1549 1550.7 1548 155.2.2 90 ' Closed in 1456 1454.5 1556 1555.9 1558 1558.6 180 '~ Initial 1588 1509.7 1 556 1 561 1 1558 1 563 7 c o Flow ' ' ' :8'r- Final 1445 1444 8 1558 1557 6 1558 1559.9 90 Closed in - 1469.1 - 1 566.4 - 1 563.7 21 ~ Initial .s.o Flow ~.., Final Closed in Final Hydrostatic - - 1 766 1 767.4 1764 1 769. l i i FORM lBS--R2 -- PRINTED IN U,S.A, FORMATION TEST DATA FLUID ~3mpler Pressure- , Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. Gravity- G=s/Oil Ratio SAMPLE P.S.I.G. at Surface APl @ °F. cu. ft./bbl. Ticket Dote 2-20-81 Number 697394 K~nd Halliburton of D.S.T. CASED HOLE Location ANCHORAGE Tester WARREN Witness BILLINGS Drilling Contractor "58 NM BR!NKERHOFF .,-. EQUIPMENT & HOLE DATA Formation Tested RESISTIVITY CHLORIDE CONTENT Recovery Water ~ ~ °F. ,ppm Recovery Mud ~ @ __ °F. ppm Recovery Mud Filtrate ~ @ __ °F. .ppm Mud Pit Sample ~ @ .__ °F. .ppm Mud Pit Sample Filtrate __ (~ ~ °F. .ppm Mud Weight vis .sec. Elevation Net Productive Interval, Ail Depths Measured From Total Depth Main Hole/Casing Size. Drill Collar Length Drill Pipe Length Packer Depth(s) Depth Tester Valve TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks Ft. Ft. Ft. tt, FOURTH GAUGE FIFTH GAUGE TEMPERATURE Est. °F. Actual °F. Initial Hydrostatic Gauge No. 3647 Depth: 4295' Closed in Final Hydrostatic Ft. 48 Hour Clock Blanked Off YES Field P ressu res 1 800 Initial 81 2 Flow 1 Final 1 57 0 Closed in 1 573 Flow F~no~ ~ ~573 Closed in - Initiol Flow Final 177fi, Office 1786.7 817.5 1569.9 1569.9 1576.9 1576.9 1576.9 1779.7 Gauge No. 7582 [ Gouge No. I TIME Depth: 4299' (oo:00-=4:oo h~.) Ft. , Depth: Ft. 72 Hour Clock Hour Clock Tool Blanked Off YES Blanked Off )ened Field 1800 814 1578 1 580 1580 1583 Pressures Office 1801.0 811.8 1575.2 1 581.6 1 584.1 1 584.1 1 588.0 1794.6 Field Pressures Office Opened Bypass Reported Computed Minutes Minutes FORMATION TEST DATA Cat~ng peris.---.--- __BottomC~~°ke Surf. temp ....... °F Ticket No 697394 Oil gravity GOR C.~$ gr~viW.-.-------~ ~Chloride,~ ppm R~.. ~ ~. graviS- INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED , ,,, ~te ~- ~ 0- ~] Choke Surface Gas Liquid %me a.m. Size Pressure Rote Rate Remarks ~i ~CF BPD p.m. - ~]5 Run ~n ~he hole ~h ~he ~oo]s. ] 4' 04 Se~ ]4'07 Opened ~oo~ ~h ~ ve~ good b]o~ - b~o~ ~nc~e~sed, bu~ d~ng b~ ~he end o~' ~he f]o~ pe~od. ]5'37 Closed ~oo]. .., ]8:37 Opened ~oo] ~h ~ ~ea~ b]o~ - b~o~ decreased. ~0-07 Closed ~oo]. 20'28 Pulled p~c~e~ loose. .... ..~ .. . . ........ ..... '° ...... "'-""'"'"'"'""'""- PRODUCTION TEST DATA · 96672 I~M 8/74 I Ik..l%l- I INk.). D~/O~ Drill Pipe or Tubing ............. Drill Collars ..................... Reversing Sub .................... Water Cushion Valve ............. ~,~.~ TUB !NG ............... D,,:~9:~.~'* Ap..CASE ............. Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual ClP Sampler ................ Hydro-Spring Tester ................ Extension Joint .................... AP RUNNING CASE AP Running Case .................. Hydraulic Jar ..................... VR Safety Joint ................ Pressure Equalizing Crossover ......... Packer Assemb~9. $.Z8'.'. RT. TS ....... Distributor ........................ Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube .......... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... FOIM 1I?--~2 --P~INTED IN U.$.J~ O, D, 3.50" 2.25" 3.50" 2.750" 5" 3.06" 5" .87" 5" .75" 5" 1.00" 5" 1.00" 5" 3.06" 5" 3.06" 5" 1.75" 5" 1.00" 8. 175" 2.25" 2. 875" 2.00" 3.87" 3.00" 3.87" 3.00" ,, EQUIPMENT DATA LENGTH ]2II 4241 ' 49.38" 81.01" 63.75" 29.93" 49.38" 49.38" 60.00" 33.40" 48.00" 10' 48.34" 48.34" DEPTH 4245' 4253' 4257' 4265' 4269' 4281' 4295' 4299' 460¢' PBT LITTLE'S 111036 ?SC 2/Ii F L U I D S A M P L E D , Date 2-15-81 Ticket 576518 .~g Number _ Sampler Pressure P.S.I.G. at Surface Kind Halliburton&klF, l_lrlDAr,_C. ~ Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location n,,~,,,vi~nuu '£ cc. oil SHEPARD GARDNER ° I cc. Water Tester Witness BRINKERHOFF DRILLING COMPANY f 58 sm-' CC. Mud Drilling Tot. Liquid cc. Contractor I I IGravity °APl @ °F. EQUIPMENT & HOLE DATA co Gas/Oil Ratio cu. ft./bbl. Formation Tested t ~ ' RESISTIVITY CHLORIDE Elevation 77.1, ground level Ft. co CONTENT Net Productive Interval 10' (4380-4390') Ft. Recovery Water __ @ ~ °F. .ppm All Depths Measured From 95' Kel 1 y bushing Recovery Mud ~ ~. __ °F. .ppm ·Total Depth 4~2~' I:;7 Dril 1 Ft. Recovery Mud Filtrate ~ @ ~ °F. .ppm Main Hole/Casing Size 0 ~/~" Mud Pit Sample ~ @ ~ °F. .ppm Drill Collar Length - I.D Mud Pit Sample Filtrate __ @ ~ °F. .ppm Drill Pipe Length 4306.59'1.D 2. 750" Packer Depth(s) 4352.59' Ft. Mud Weight 72#/ CU. ft~rs 38 sec. Depth Te~ter Valve 4324.11' Ft. · TYPE AMOUNT Depth BackL)[~ J' i~ :~amp I ersurfoce Bottom Cushion water 130 Ft. Pres. Valve 4313.02' Choke½-3/8"Choke. 75" Recovered Feet of ~ Recovered Feet of Recovered Feet of m. c: Recovered Feet of ~ Recovered Feet of Remarks Sanded out 4 stands above DCIP tool REC~!~E D SEE PRODUCTION TEST DATA SHEET OOT26 ,, Anc~0rage , 'Gauge No. 6141 Gauge No. 3646 Gauge No. 7581 T,M~ TEMPERATURE 4310 29 4337 61 Ft. Depth: 4341 67 Ft. I Depth: . Ft. Depth: · . (00:00-2'4:00 hrs.) ~r~ Hour Clock 72 Hour Clock 48 Hour Clock Tool Est. 70 °F. Blanked Off ,no Blanked Off no. Blanked Off no Opened 2028 Opened ...... ,Actual ° F. Pressures Pressures Pre. ssures Bypass · Field Office Field Office Field Office Reported Computed Initial Hydrostatic - - 1801 1798.9 1801 1801.0 Minute, Minutes ..= Initial 47 47 3 964 1026.1 963 965 7 ~ o Flow ..... iZ~. FinaI· 1523 245 1 1546 1545.4 1542 1540 8 110 Closed in 1445 1449.6 1571 1569.9 1569 1568.8 182 ..... ~ Initial 1522 1521 1 1571 1571 6 1569 1568 8 : o Flow ' ' ' ~o.: F~nal 1491 1483 7 1575 1571 6 1570 1572 7 60 Closed in - 1467.5 1579 1576.9 1570 1579.0' 28 ~o Flow Initial ~_~. Final *Clockl apparently stopped during final closeJ in pressure peri3d ..... Closed in r'- Final Hydrostatic - - 1792 1793.7 1792 1795 9 , - FORM 181--R2 -- PRINTED IN U.S.A.. FORMATION TEST DATA LITTLE'S 111033 7SC Ticket . F L U I D S A M P L E D A Dote 2- 15-81 Number 576518 Page 2 Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE cc. Oil cc. Water Tester SHEPARD witness GARDNER cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY # 58 sm Gravity. ° APl Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation Ft. CONTENT Net Productive Interval .Ft. Recovery Water ~ @ Recovery Mud ~ @ ~ °F. ppm Total Depth Ft. Recovery Mud Filtrate ~ @ ~ °F. ppm Main Hole/Casing Size Mud Pit Sample ~ @ ~ °F. ppm Drill Collar Length I.D Drill Pipe Length I.D Mud Pit Sample Filtrate ~ @ ~ °F. ppm Packer Depth(s) Ft. Mud Weight vis ,sec. Depth Tester Valve Ft. , TYPE AMOUNT Depth Bock Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of , Recovered Feet of Recovered Feet of .~ Recovered Feet of Recovered Feet of Remarks , , FOURTH GAUGE FIFTH GAUGE Gauge No. 3b~/ Gauge No. 7582 Gauge No. TIME TEMPERATURE Depth: 4365. 38 Ft., Depth: 4370.38Ft. Depth: Ft. (00:00-24:00 hrs.) ~r8 Hour Clock 72 Hour Clock Hour Clock Tool Est. *F. Blonked Off n0 Blanl~ed Of~0 ,, Blanked Off Opened Opened Actual ° F. Pressures Pressures Pressures Bypass , , Field Office Field Office Field Office Reported Computed , Initial Hydrostatic1802 1805.9 1818 1818.8 Minutes Minutes Initial 1008 1073.4 1010 106'7.6 I~-c Flow iZ~. Final 1550 1550.7 1564 1559.9 Closed in 1576 1575.1 1590 1586.7 ~ Initiol 1576 1575.1 1590 1586.7 c o Flow ~o-: F~na~ 1577 1578.6 1593 1589 2 Closed in 1580 1583.9 1595 1591.8 Initial ._~._o Flow ~.~ .., Final Closed in FinaIHydrostatic 1802 1802.4 1811 1808.6 FORM 181--R2 -- PRINTED IN U.S.A. FORMATION TEST DATA LITTLE'S 111033 75C. 2/80 C6sing per~s Bottom c e Surf. temp.. °F Ticket No. 576518 Gas gravity Oil gravity GOR Spec. gravity_ ,Chlorides ppm Res. ~,. INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED Date Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks psi MCF BPD 2028 I Opened tool 2030 Opened 1/2" choke 2055 Closed 1/2" choke 2218 Closed tool 2-16-81 0120 Opened tool 0220 Closed tool 0248 Pulled packer loose. ~ , PRODUCTION TEST DATA LITTL£'$ ~6572 51.I 8/7~/' Ho ding Sub & Choe ssembly .... Dual CIP Valve ................... Dual ClP Sampler ............. Hydro-Spring Tester ............... Drill Pipe or Tubing ..... Drill Collars .............. Reversing Sub ........... Water Cushion Valve .......... Drill Pipe ............... Multiple CIP Sampler Loc-.byp.ass... Extension Joint ................... AP Running Case ................ II Hydraulic Jar ................. VR Safety Joint ........... Pressure Equalizing Crossover ......... Packer Assembly ................... O.D. 3.50" 3.5" 5" 11 5" 5" 8. 175" 2.875" 3.87" 3.87" i.D. 2.25" 2.750" 3.06" ]" l" 3.06" 1" 2.25" 2" 3" 3" LENGTH DEPTH 12" 4306.59' 49.38' 81.01" 4310.29' 29.93' 4324.11' 49.38" 49.38" 6~" 33.40" 48I, 10' 48.34" 48.34" __ 4337.61' 4341.67' 4.352.59' 4365.38' 4370.38' Distributor ........................ Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ......... Blanked-Off ~.T. Running Case ....... II II Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor ................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ EZ Drill Total Depth ....................... FORM 1~7--R2 -- PRINTED IN U.S.A. EQUIPMENT DATA 4520' LITTLE'S 111036 75C 2/~ ~. F L U I D S A M P L E D A Date 2-14-81 Ticket 576517_page 1 Number 'Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE ,= cc. Oil ce. Water Tester MR. SHEPARD Witness MR. GARDNER cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY #58 bc co Gravity o APl @ °F. E Q U I PM E N T & H O L E DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested· RESISTIVITY CHLORIDE Elevation 77.1, GL Ft. '~' CONTENT Net Productive Interval. 4631 ' - 4645' 14' Ft. Recovery Water ~ @~°F. ppm All Depths Measured From 95' Kelly Bushing. Recovery Mud ~ ~ ~ °F. .ppm Total Depth 4850' EZ-Dril 1 Ft. Recovery Mud Filtrate __ @ ~ °F. ppm Main Hole/Casing Size 9 5/8" Mud Pit Sample ~ @ ~ °F. ppm Drill Collar Length - I.D Drill Pipe Length 4533' . I.D 2 750" Mud Pit Sample Filtrate ~ @ ~ °F. ,ppm 4576' Packer Depth(s) Ft. Mud Weight 72#/cu. ft. vis 38 ,ec. Depth Tester..V_olve 4550 · Ft. Depth Back ~ con~ Surface~ i, Bottom TYPE iA3M~pNT DC i F VAL v c Cushion Water Ft. Pres. Valve ~t;~o:~ Choke ~ & 3/8mI Choke · 75n .., Recovered Feet of ~ Recovered Feet of · ~:~ Recovered Feet of ~ ~.~ Recovered Feet of ~ ~ I--,I Recovered Feet of Remarks Charts indicate partial plUgging during flow periods· RECEIVED SEE PRODUCTION TEST DATA SHEET. OCT 2 6 ][982 Alaska 0ii & Gas Cons. 6'omm~soio.' ~ TEMPERATURE GougeDepth: No. 461536417' Gouge No. 3646 G~uge No. 7581 ., TIME ---I - Ft. Depth: 4564 02' Ft. Depth: 4568 08I Ft. (00:00-24:00 hrs.) (/3 · 48 Hour Clock 7~2 Hour Clock 48 Hour Clock Tool Est. °F. "' Blanked Off No Blanked Off No Blanked Off No Opened 1 81 2 4601 ' Opened 0720 , Actuo~ 72 'F. Pressures Pressures Pressures Bypass , Field Office Field Office Field Office Reported Computed Initial Hydrostatic - - 1 91 4 1 91 7.8 1916 1917.0 Minutes Minutes Initial 57 133.9 173 174.8 17 173.4 _~.o~ Flow-,. ..~. Final 993 974.0 977 979.1 1029 1044.4 121 121 Closed in 993 996.7 1570 1573.4 1573 1576.5 241 239 ~O r-- -o.o Initial 993 996.7 1059 1055.7 1053 1057.1 O-- (./3 ~ Flaw Final 1421 1423.7 1490 1493.0 1491 149'6.1 118 121 Oosedin 1407 1404.2 1589 1592.6, 1589 1595.6 308 308 .~ Initial ._~.o_ Flow ~_~. Final Closed in Final Hydrostatic 1903 1899.3 1899 1902.1 1896 1903.0 _ ,i _ FORM 1El--R2 -- FEINTED IN.U.S.A. FORMATION TEST DATA Ticket FLUID SAMPLE TA 2-'14-81 , ' Date Number 576517- page 2 Sampler Pressure P.S.I.G. at Surface Kind Halliburton of D.S.T. CASED HOLE Location ANCHORAGE Recovery: Cu. Ft. Gas cc. Oil cc. Water -re~t~r MR, SHEPARD Witness MR. GARDNER cc, Mud Drilling Tot. kiquidcc. Contractor BRINKERHOFF DRILLING COMPANY #58 bc Gravity, ° APl @ °F. E Q U I PM E N T & H O L E D AT A Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation Ft. CONTENT Net Productive Interval Ft. Recovery Water __ @ --°F. ppm All Depths Measured From Recovery Mud ~ @ ~ °F. ppm Total Depth Ft. Recovery Mud Filtrate ~ @ ~ °F. ppm Main Hole/Casing Size Mud Pit Sample ~ @_ °F. ppm Drill Collar Length . I.D Drill Pipe Length.. I.D Mud Pit Sample Filtrate ~ @_ °F. ppm Packer Depth(s) Ft. Mud Weight vis ~ec. Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks 4th GAUGE 5th GAUGE I Gauge No. 3647 ~ Gauge No. 7582 Gauge No. TIME TEMPERATURE Depth: 4591 . 82' Ft. Depth: 4596' 82' Ft. Depth: Ft. (00:00'24:00 hr,.) 48 Hour Clock 72 Hour Clock Hour Clock Tool Est. °F. Blanked Off No Blanl~ed Off Yes Blanked Off Opened , Opened ..... Actual 'F. Pressures Pressures Pressures Bypass Field Office Field Office Field Office Reported Computed Initial Hydrostatic 1933 19 35.3 1938 1940,0 Minutes Minutes -] Initial 1 81 1 78 9 183 184 l I~.: Flow ' ' ~:~., , Final 1070 1082.1 1015 1070.1 Closed in 1595 1597,9 1597 1598.2 ~ Initial 1083 1080 4 1084 1080 2 : o Flow ' ' ' 8': Final 1 51 5 1 519 2 1 522 1 519 l Closed in l 610 l 61 3.6 1 61 6 1 61 4,7 , Initial !~o Flow i~_~ .,, Final Closed in Final Hydrostatic 191 3 1919,5 l 927 1 924.7 -- FORM 1B!--1~2 -- PRINTED IN U.S,A, FORMATION TEST DATA Casintj perfs. Bottom choke Surf. temp .°F Ticket No Gas gravity. Oil gravity C-OR Spec. gravity., Chlorides ppm Res, INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED Date 2-1 4-81 Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks p.m. psi hqCF BPD - 1812 I Opened tool with a moderate blow through bubble hose 1815 Opened ½" choke 1830 ½" Weak bubble i1831 Closed ½" choke 1920 10 Blow increased 201 3 Closed 'tool L -- I d--('..) l 0014 Opened tool 0045 25 Gas to surface 0052 Opened ½" choke 0059 Closed ½" choke 021 2 Closed tool Opened DCIP reversing port and reverse~ out Dropped bar 0720 Pulled packer loose , FORM 1Bs'.FIi--PRiN?£D IN U.S.A. PRODUCTION TEST DATA LITTLE'c= 96672 SM B/7/,~. Drill Pipe or Tubing .............. Drill Collars ..................... Reversing Sub .................... I IL. Kb.I NL). blbDJ. I 5.7B" O.D. I.D. Drill Collars .................... 5" Dual CIP Valve ................... Dual ClP Sampler 5II Hydro-Spring Tester ................ 5 II 2- 7g" 2.750" 3.06" Multiple ClP Sampler ................. 5" 1.O0" Extension Joint .................... 5u 1.00" 3.06" AP Running Case .................. AP RUNNING CASE Hydraulic Jar .................... 1! 5" II 1 . I1o" VR Safety Joint ............... Pressure Equalizing Crossover ......... Packer Assembly ................... 8. 175" 2.25" 2.00" 3.00" LENGTN DEPTH 12.0" 4533' 49.38" 81.01't ?q-03" 4537' 33~40" 48.00" 4564' 4568' 4~576' Distributor ........................ Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube .......... Blanked-Off B.T. Running Case .. 2 .... Drill Collars ...................... - X~c'h~r ~m~ sm~r~-zo mr HT.. 5 0.0 ..... 2.875" 3.87" 3.87" 10' 48.34 '/ ,,1.,5' 4592' 4597' 4601 ' Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor -- FORM 117--R2 -- PRINTED IN U.S.A. Blanked-Off B.T. Running Case ........ Total Depth ....................... EQUI PMENT DATA 4850' ,_ ZLUID SAMPLE DA Dote 2-12-81 'icket 576516 " Number Sampler Pressure ,, , P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE cc. Oil cc. Water Tester MR. SHEPARD Witness HR. PILCHER cc. Mud Drilling MR. SIEFKE Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY RIG #58 Gravity. o APl @ °F. E Q U I PM E N T & H O L E D Gas/Oil Ratio cu. ft./bbl. Formation Tested - RESISTIVITY CHLORIDE Elevation77.1 GL Ft. CONTENT Net Productive Interval (5172' to 5182' )- 10' Ft. Recovery Water ~ @ ~°F. ppm All Depths Measured From Kelly Bushing - 95' Recovery Mud @ °F. ppm Total Depth 5341 Recovery Mud Filtrate __ @- °F. ppm Main Hole/Casing Size 9 5/8" Mud Pit Sample ~ @ __ °F. ppm Drill Collar Length - I.D. - Drill Pipe Length 5089' I.D.- 3.826" Mud Pit Sample Filtrate ~ @__ °F. ppm , Packer Depth(s) 5135 ' Ft. Mud Weight 72#/cu. ft~is ~ec. Depth Tester Valve 5107' Ft. TYPE AMOUNT Depth Back Surface - 8" Bottom Cushion Ft. Pres. Valve Choke 1/2" 3/ Choke 3/4" Recovered Feet of . · ' P Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks SEE PRODUCTION TEST DATA SHEET .... CHARTS INDICATE SEVERE PLUGGING OF PERFORATED ANCHOR .... UTR = UNABLE TO READ .... ,,, KC:LI::i V r ~ i ii OCT 2 BT #6141 ran above tool Alaska 0il & Gas Cons. Commission Anchorage ' ' Ga.~e No. 6141 GaugeNo. 3646 GougeNo. 7581 I T~. TEMPERATUREJ Depth: 5093' F,t. Depth: 51241 Fi. Depth: 51281 Ft.., (O0:O0-24:0Ohrs.) 48 Hour Clock 72 Hour Clock 48Hour Clock Tool Est. °F. Blanked Off N0 Blanked Off N0 Blanked Off NO ,Opened 0904 5158' Opened Actual 73 'F. Pressures Pressures Pressures Bypass 1358 Field Office Field Office Field Office Reported Computed Initial Hydrostatic 0 _ 2168 2169.5 2175 2175.1 Minutes Minutes ..-o Initial 99 117 6 127 129 3 132 129.1 . o Flow ' ' .~-= Final gg 120.9 127 132 8 133 132 9 74 Closed in 129.0 944 916.3 918 921.3 120 ~ Initial 120.9 133 132 8 136 135 4 c o Flow ' ' 8': Final 124.1 133 132 8 133 134.1 54 Closed in 129.0 276 277 9 284 282 2 46 Initial ~ Flow ,' ~ Final Closed in Final Hydrostatic - UTR - UTR - ,J UTR I FORM 181--R2 -- PRINTED IN U.S.A. FORMATION TEST DATA LITTLE'S ' F L U I D S A M P L E ~., T A Dote 2-12-81 Ticket 576516 Number Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE cc. Oil MR. SIEFKE ,o cc. Water Tester MR. SHEPARD Witness MR. PILCHER cc. Mud Drilling 4:~ Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY r, 58 b~i ~,w ...~-rmvitv * APl (~ °F. E Q U I p M E N T & H O L E D A T A ~-~ Gas/Oil Ratio cu. ft./bbl. Formation Tested z RESISTIVITY CHLORIDE Elevation Ft. ~-~ CONTENT CD Net Productive Interval Ft. Recovery Water ~ @ ~ °F. ppm Alt Depths Measured From Recovery Mud ~ ~ ~ °F. ppm Total Depth Ft. Recovery Mud Filtrate ~ @ ~ °F. ppm Main Hole/Casing Size Mud Pit Sample ~ @ ~ °F. ,ppm Drill Collar Length I.D Drill Pipe Length I.D Mud Pit Sample Filtrate ~ @ ~ °F. ppm · Packer Depth(s) Ft. Mud Weight vis sec. Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke ..... Recovered Feet of ~ '" D "11 Recovered Feet of 3 co Recovered Feet of ~ Recovered Feet of ~ Recovered Feet of .:x:~ Remarks UTR = UNABLE TO READ .... iO it" i.-e FOURTH GAUGE' FIFTH GAUGE: Gauge No. 3647 Gauge No. 7582 Gauge No. TIME TEM. P ERATUP, E Depth: 5152' Ft. Depth: Ft. ca:: Ft. Depth: 51571 (00:00-24:00 hrs.) 48 Hour Clock 72 Hour Clock Hour Clock Tool Est. °F. Blanked Off NO Blanked Off YES Blanked Off Opened 0904 ., 5158' Opened Actual ' 73 °F. Pressures Pressures Pressures Bypass 1358 Field Office Field Office Field Office Reported Computed Initial Hydrostatic 2182 2187.0 2191 2193.0 Minutes Minutes · -~o Flow ,, Initial 426 424.5 422 416.8 :.: 584.5 74 ~iZ · Final 577 578.9 587 Closed in 929 933.3 933 934.3 120 !~ Initial 600 601.7 582 575.7 ,, ~ >r-- : o Flow ~e Final 573 578.9 585 582.0 54 C~osed in 640 642.1 649 643.9 46 ., Initial _~.o_ Flow .: ~ Final Closed in Final Hydrostatic - UTR _ UTR , FORMATION TEST DATA ( ( 576516 Bottom choke Surf. temp ,,'F Ticket No, Gas gravity-- ,.,.,, Oil gravity GOR Soec. gravity~ Chlorides ppm Res, @ °F iNDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED Date Choke Surface Gas Liquid Pressure Rate Rate Remorks Time a.m. Size psi MCF BPD Domo _ 2-12-81 ,,, 0902 Set packer. 0904 Opened tool with a weak blow. 0908 No blow-Closed 3/8" choke. Bubble _ pi cked up-weak. 1018 Closed tool for closed in pressure. · 1218 Reopened tool with a weak blow thru bubble hose. ' 1312 Closed tool for final CIP period. Reversed out-no recovery. 1358 Pulled packer loose. ,, -'ORM IIB2-Rt~PRINTED IN U.S.A. PRODUCTION TEST DATA LITTLE'$ ~'6672 O.D. Drill Pipe or Tubing Drill Collars ..................... Reversing Sub .................... 5.75n Water Cushion Valve .............. Drill Pipe ...................... 4,50n Drill Collars .................... · ~" Ap. CASE-5.00" Dual CIP Valve ................... Dual CIP Sampler .................. 5.00n Hydro-Spring Tester ................ 5.00n 5.00" 2.75" 3.826" 3.06" .87" · 75" Multiple ClP Sampler ............... 1.00" Extension Joint ................... 5.00" 1.00" AP Running Case .................. 5.00" · 5.00" Hydraulic Jar .................... 5.0O n VR Safety Joint ................. Pressure Equalizing Crossover ......... 9 5/8" RTTS- 8.175" Pecker Assembly ................... 3,06" 3.06" 1 . 7~" 1.00" 2.25" 2.00" 3.00" 3.00" Distributor ........................ Packer Assembly ................... ..... ~., .... ,~. 2 7/8" DRILL PIPE- 2.875" Pressure Equalizing Tube ......... Blanked-Off B.T. Running Case ....... (2) Each- 3,87" Dr~l', C~,,'{;r~-, ...................... Anchor Pipe Safety Joint .H.T..500..T. EHP, 3.87" Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... TICKET NO. -- 576516 LENG'T'H DEPTH 12.00" 5089' 49.38" 81.01" 29.93" 5093' 5107' 49.38" 49.38" R,q- QN" 33.40" 48.00" 10' 48.34" 48.34" · 5]24' 5128' 5135' 5152' 5157: 5158' 5341: ~'ORM 1iT--R2 -- PRINTED IN U.S.A. EQUIPMENT DATA LITTLE/~ 75C 2/BO ~. ' ' F L U, I,D S A M P L E D A Date 2-11°81 ~ck~e~r576573_ page 1 _ Sampler Pressure P.S.I.G. at Surface Kind Halliburton ~ o of D.S.T. CASED HOLE Location ANCHORAGE Recovery: Cu. Ft. Gas iX~O . cc. Oil ce. Water Tester MR. SHEPARD Witness MR. REDWINE cc. Mud Drilling BRINKERHOFF DRILLIN¢ COMPANY ~58 bc Tot. Liquid cc. Contractor , Gravity. ° APl c~ °F. EQ U I PM E 1'4 T & H O L E D A T A Gas/Oil Ratio cu. ft./bbl. Formation Tested co RESISTIVITY CHLORIDE Elevation 77.1 ' GL Ft. , CONTENT 51 72' ' Net Productive Interval .... -51 82 (10') Ft. __~ Recovery Water ~ @ __ °F. ppm All Depths Measured FromKelly Bushing 95' co Recovew Mud @ °F. ppm Total Depth 6510' ~ ~ Ft. Recovew Mud Filtrate ~~~°F. ppm Main Hole/Casing Size,~~'~:~/O"~'--: -basing ! ,,,,=,,I Mud Pit Sample ~ ~ ~ °F. ppm Drill Collar Length - i.D.. Drill Pipe Length 5093.49'~.D._, 3.826" Mud Pit Sample Filtrate ~ ~ ~ °F. .ppm l::;1 , Packer Depth(s).'~ ,~u Ft. Mud Weight 72#/cu ft vis sec. Depth Tester Valve. 511 1 0' · , · Ft. TYPE AMOUNT Depth Back Surface Bottom 7 C~shion Water 465' Ft. Pres. Valve Choke 3/8" & ½" Choke · ...... Recovered Feet of . Recovered Feet of :1-~1 Recovered Feet of ~ r- Recovered Feet of Recovered Feet of Charts indicate partial plugging during flow periods· Initial closed in Remarks pressure may be questionable...SEE PRODUCTION TEST DATA SHEET. ,. RECEIVED ~on OCT 2 6 !982 Alaska 0il & Gas Cons. Gauge No. 6141 Gauge No. 3646 l Gaugeno. 7581 I Anchorage TEMP £P~,TUP. E Depth: 5093 49' Ft. Depth: 51 24 51 ' (00:00-24:00 hrs.) · · Ft. Depth: 5l 28.57I Ft. CZ 48 Hour Clock 72 Hour Clock 48 Hour Clock: Tool , Est.70°F. Blanked Off NO Blanked Off NO . Blanked Off NO Opened, 0735 Opened 1855 Actual °F. Pressures Pressures Pressures Bypass Field Office Field Office Field Office Reported Computed , Initial Hydrostatic - - 2175 21 78.3 2175 2!76.4 M~.ut. Mihute, ,,, initial- 235.2 257 255.2 254 255.6 i. :1~.9 Flow , :F.~. Final 381 419.9 430 430.0 438 431.6 115 Closed in - 419.9 1972 1973.7 1971~ 1977.0 240 ~-~ Initial - 419.9 378 370.6 404 402 .5 r- ~ o Flow ' u°': Final 523 532.4 538 538 3 543 541 8 182 Closed in - _ 1260 1263.0 1265 1266.4 143 Initial - ._~.o_ Flow .c ~ Final Closed in Final Hydrostatic 21 66 21 62.3 2164 2166.0 2173 2171.3 . __ FORM Ill--R2 -- PRINTED IN U.S.A. FORMATIOXl TEST DATA LITTLE'$ · F L U I D S A M P L E D A Date 2-11 -81 Ticket 576573 page~ ~ , Number ', Sampler Pressure , P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE cc. Oil ce. Water Tester MR. SHEPARD Witness MR. REDWINE cc. Mud Drilling Tot. Liquid cc. _,Contractor BRINKERHOFF DRILLING COMPANY =58 bc Gravity_ ° APl @ °F. E Q U I P M E N T & H O L E D A T A Gas/Oil .Ratio cu. ft./bbl. Formation Tested co RESISTIVITY CHLORIDE Elevation Ft. , CONTENT Net Productive Interval .Ft. -.~ Recovery Water ~ ~--~ ~ °F. ppm All Depths Measured From Recovery Mud ~ @ ~ °F. .ppm Total Depth ,,, Ft. Recovery Mud Filtrate ~ @ ~ °F. .ppm Main Hole/Casing Size ..... Mud Pit Sample ~ @ ~ °F. .ppm Drill Collar Length .... I.D Drill Pipe Length I.D Mud Pit Sample Filtrate ~ @ ~ °F. .ppm , Packer Depth(s) Ft. Mud Weight vis ........ sec. Depth Tester Valve Ft. , ,,, TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke ..... Recovered Feet of ., ~!~ Recovered Feet of Recovered Feet of i~ I(:~:: < Recovered Feet of o_ Recovered Feet of Remarks , , 4th GAUGE 5th GAUGE Gauge No. 3647 Gauge No. 7582 Gauge No. TIME --~ TE/V~P EP. ATURE Depth: 51 52 31' Ft. Depth: 51 57 31 ' · · Ft. Depth: Ft. (00:00-24:00 hrs.) J C/3 48 Hour Clock 72 Hour Clock Hour Clock[ Tool c::: Est. °F. Blanked Off NO ..... Blanked OffYes Blanked Off " Opened Opened Actua ! ° F. P ressu res P ressu res P ressu res By pass Field Office Field Office Field Office Reported Coml3uted .... Initial Hydrostatic21 85 2187.0 ,;. 2197 2195.6 Minutes Minutes ~.~o Initial 324 264 9 265 268 5 I~-: Flow-' ' ' ~ F~no~ 439 445.6 455 453.9 C~osedi~ 1986 1987 7 1995 1993.6 ~ Initial 448 445 6 459 456 5 ~.. Flow Final 970 929 .8 981 935 .5 Closed in 1 290 1 290 2 1 291 1 295 9 Flow .- Final ,, Closed in Final Hy.drostatic 21 63 2181.8 2188 21 85.4 FORM 1~1--R2 - PRINTED IN U.S.A. FORMATION TEST DATA ~ [ ~ 576573 " Bottom choke Surf. temp .... °F Ticket No j C~,~g p~rfs Oil gravi~ ~R i ~, gmvi~~ ~ graviS- ,Chlorides ..... ppm i ~NDI~TE TYPE AND SIZE OF GAS ~EASURING DEVICE USED ...... , ,, j ~e Choke Surface Gas Liquid P re~ure ~ate Rote Eemo rks T, a.m. Size ~i MCF BPD , p.m. 0730 J Se~ packe~ w~h some slippage 0735 Too~ opened w~h 8 wesk blow, ~nc~eas~r ...... 0815 Opened 3/8" choke, blow dec~eas~ng , 0~30 Closed ~ool w~[h 8 we~k blow ....... 1330 Opened ~ool w~h 8 we~k blow ~htough 3/8" choke. Blow ~ema~ned .... we~k, no fluid ~o surface ,,, 163~ Closed ~ool. Ro[8~ed DC[P ~o ~eve~se ,, pos~on. D~opped bat and wen~ 1815 Pulled p~cker loose I ,, ...... ,, , FOISt4 1B2.RI~pRINTt=D Iff U.S.A, PRODUCTION TEST DATA TICKET NO. Drill Pipe or Tubing .............. Drill Collars ..................... Reversing Sub ................... Water Cushion Valve ............. Drill Pipe ....................... ~_.~.~ .... AP.. Cas.e ...... Handling Sub & Choke Assembly .... Dual CIP Valve ................... Dual CIP Sampler ................ Hydro-Sprinc~ Tester Locke8 open '5y;pa~ ....... Multiple ClP Sampler ............... Extension Joint ................... Co. ........ (2.) ...... Hydraulic Jar .................... VR Safety Joint ................ Pressure Equalizing Crossover ......... Packer Assembly ................... Distributor ........................ Packer Assembly ................... 2 7/8" D.P. Flush Joint Anchor ................. Pressure Equalizing Tube ......... ,,o. ed-Of Co...(.2.!.. Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... O.D. I.D. LENGTH FORM 187--R2 ~ PRINTED IN U.S.A- 5.75" 2.75" 1 2" 4)~" 3.826" 5093' 5" 3.06" 49.38" 5" .87" 81.01" 5" · 75" - 5" 1" 29.93" 5" 1" - 5" 3.06" 49.38" 5" 1.75" 60" 5" 1" 33.4.0" 8.125" - 48" 2.875" 2" 10' 3.87" 3" 48.34" 576573 EQUIPMENT DATA DEPTH 5093.49' 5111.0' 5124.51' 5128.57' - 51 36' 51 52.31 ' 51 57.31 ' 6510' LITTLJE'S 111036 7SC 2/RO/ ~'~"-'r'~ (' ('Ticket .~°'~ ~ J F L U I D S A M P L E D A Dote 2-10-81 N~r~ber 576572 Sampler Pressure P.S.I.G. at Surface Kind Halliburton.. Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE I cc. Oil r' J cc. Water Tester ,]AMES R. SHEPARD Witness I cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF R]~G # 58 DR I ° APl @ °F. EQ U I PM E N T & H OLE DATA ._,' J Gravity _ t Gas/Oil Ratio cu. ft./bbl. Formation Tested ~' j RESISTIVITY CHLORIDE Elevation 77.1' GL Ft. '. CONTENT Net Productive Interval. 5408- 5418' 10' Ft. Recovery Water __ @ ~°F. ppm All Depths Measured FromKell,v Bushin9 95' Recovery Mud ~ @ ~ °F. ppm Total Depth 6510' Ft. Recovery Mud Filtrate ~ @ ~ °F. ppm Main Hole/Casing Size 9 5/8" Csg. Mud Pit Sample ~ @ ~ °F. .ppm Drill Collar Length - I.D. - Drill Pipe Length.. 5310' I.D. 3.826" Mud Pit Sample Filtrate ~ @ ~ °F. ppm Packer Depth(s) 5348' Mud Weight vis sec. Depth Tester Valve 5327.52 ' Ft. , TYPE AMOUNT Depth Back Surface ~/~'' Bottom Cushion 3195' Water Ft. Pres. Valve Choke 1/2" Choke °75" ., Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks Charts indicates Dossible partial DlUgging during flow periods. UTR-Unable to read RE£EIVED OCT 2 6 1982 Alask~ 0il & Gas Cons. ~,~.'~mission Gauge No. 6141 Gouge No. 3646 Gouge No. 7§~ar~; TIME TE/V~ERATURE (00:00-24:00 hfs.) Depth: 5313.7' F,t. Depth: 5341.02 Ft. Depth: 5345.08 Ft. 48 Hour Clock 72 Hour Clock 48 Hour Clock Tool Est. °F. Blanked Off NO Blani~ed offNo Blanked Off NO Opened 08' O0 5375' Opened Actual 73 "F. , Pressures Pressures Pressures Bypass 1 7'45 Field Office Field Office Field Office Reported Computed Initial Hydrostatic - 2370.6 2370,6 2364.4 Minutes Minutes · -~o Flow Initial 489.2 590,5 590.5 587.5 I~': Final 489 2 632 4 632 4 631.9 7'7 Closed in 586.0 1594.4 1594,4 1591.8 174 ~ Initial 599.0 63.5 8 635 8 581 2 : o Flow ' ' ' ::~ 8'r- Final 620.1 637 6 637 6 637 0 84 r- Closedin 629,8 1536 7 1536 7 1538 2 250 Initial I ~o Flow ~_~. Final Closed in Final Hydrostatic 2306.8 IITR IITR UTR '°"""'-"'-"'""~"~'~'"~' FORMATION TEST DATA '"'"" ir1'1 Ticket F L U I D S A M P L E . T A Date 2-10-81 Number 576572 - :~mpler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE cc. Oil cc. Water Tester JAMES R. SHEPARD witness ...... cc. Mud Drilling Tot. Liquid cc. Controctor BRINKERHOFF RIG # 5(~ . DR Gravity. ° APl @ °F. EQ U I PM E N T & H O L E DATA co Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation _Ft. CONTENT Net Productive Intervol ......... Ft. Recovery Water ~ @ ~ °F. .ppm All Depths Measured From Recovery Mud ~ @ ~°F. .ppm Total Depth ,. Ft. Recovery Mud Filtrate ~ @ ~ °F. .ppm Main Hole/Casing Size Mud Pit Sample ~ @ ~ °F. ,ppm Drill Collar Length . I.D, Drill Pipe Length I.D, Mud Pit Sample Filtrate ~ @ ~ °F. .ppm . Packer Depth(s) I t. Mud Weight vis ~ec. Depth Tester Valve Ft, TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke ..... Recovered Feet of ~ Recovered Feet of ..... Recov,e. red Feet of ~ Recoy, e. red Feet of <~ Recovered Feet of ::~ Remarks FOURTH FIFTH TEMPEP. ATUEE Gauge No. 3647 Gauge No. 7582 Gauge No. TIME --I Depth:5368,2F.t. ,Depth: 5373.2 Et. Depth: Ft. , (O0:00-24:OO hfs.) 48 Hour Clock 72 Hour Clock Hour Clock Tool c:: Est. 'F. Blanked ,Off NO Blanl~ed Off Yes .... Blanked Off Opened Opened Actual °F. Pressures Pressures Pressures Bypass ,,,, , Field . Office Field Office Field Office Reported Computed Initial Hydrostatic 2391.6 2398.9 Minutes Minutes .~ ~nmal 608 7 613 6 ' - I~-: Flow , ' ~,~. Final 657.8 660.6 Closed in 1270.0 1622.4 =.~ Initial 663 1 650.2 - c o Flow ' ~o.: F~na~ 663 1 666.6 Closed in 1566.4 1567 6 , ' r"' ~o Flow Initial .... cn::~ ~.~. ,, Final Closed in Final Hydrostatic I ITR UTR " UTR-I Inabl e t~0 read , FOEM '181--~2 -- PIHNTED IN U.S.A. FORMATION TEST DATA L,.,,., Drill Pipe or Tubing .............. Drill Collars ..................... Reversing Sub .................... Water Cushion Valve .............. Drill Pipe ....................... ~x~cx AP... Case ........... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple ClP Sampler ............... Extension Joint .................... AP Running Case ....... (.2) ........ · Hydraulic Jar ................... VR Safety Joint ................ Pressure Equalizing Crossover ......... Packer Assembly ................... Distributor ........................ Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ...(2). Drill Collars ...................... Anchor Pipe Safety Joint ............ HT-500 Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............. Side Wall Anchor .................. Drill Collars Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... O.D. I.D. 5.75" 2.75" 4 1/2" 3.826" 5" 3.06" 5" .87" 5" .75" 5" 1.00" 5" 1.00" 5" 3.06" 5" . 1,.,.75 " 5'-' 1.00" 8 1/g" 2 7/8" 3.87" 3.00" TICKET NO. LENGTH 576572 DEPTH 12" 5310' 49.38" 5313. 7; 8].0]" 5316.43' 5327.52' 29.93" Lock bypass 49.38" 60.00" 33,40" 5341.02 5345.08' 48.00" '5348.00' 1 0~ O0" 48.34" 5368..2' 5373.2' 5375' 6510' '°-'"'-" -'"""" EQUIPMENT DATA · Ticket F L U I D S A M P L E A T A Dote 2-9-81 Number 575765 I --Ir" Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE cc. Oil cc. Water Tester JACK BOWEN Witness cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF RIG # 58 DR Gravity. ° APl @ °F. E Q U I PM E N T & H O L E D AT A Zc° Gas/Oil Ratio cu. ft./bbl. Formation Tested - RESISTIVITY CHLORIDE Elevation 77.1' GL Ft. CD CONTENT 9 Ft. Net Productive Interval 5861-5870'' Recovery Water ~ @ °F. ppm All Depths Measured From Kelly Bushing 95' Recovery Mud @ °F. .ppm Total Depth 5925' Ft. Recovery Mud Filtrate __ @ __°F. .ppm Main Hole/Casing Size 9 5/8" Casing Mud Pit Sample @ °F. ppm Drill Collar Length - I.D - Drill Pipe Length 5777' I.D. 3.826" Mud Pit Sample Filtrate @ °F. ppm Packer Depth(s) 5816' 0 It. Mud Weight vis sec. Depth Tester Valve 5788' Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Diesel 2344' Ft. Pres. Valve Choke .50" Choke.75" Recovered Feet of IF I~>-~_~ Recovered Feet of 3 Recovered Feet of ~ m - Recovered Feet of - Ii-,I Recovered Feet of I'rl Remarks Charts Jndicate possible partial plugging during fln~ O-Ouestionable R~ f F I VI: n LJTR-linabl~ tn r~ad F1/~T~ ~ Second cl osed i n pressure non-usabl e ~)'_s.t:~ OJJ & ~.-,~ ~,,~. u~mmis~io Anchorage Gauge No. 6141 Gauge No. 3646 Gauge No. 7581 TIME TEM. P ERATURE (00:00-2'4:00 hrs.) ca:: Depth: 5773 Ft. Depth: 5802 Ft, Depth: 580(~ Ft. Ca 1 c. 48Hour Clock 72 Hour Clock 48 Hour Clock Tool ,,, Est. ~30 °F. Blanked Off No Blanked OffNo Blanked Off NC) Opened 0933 Opened Actual °F. Pressures Pressures Pressures Bypass 61 0 Field Office Field Office Field Office Repo~ted Computed Initial Hydrostatic 2618 2628.9 0 - 2629.1 O Minute, Minutes ~-~o Flow Initial 766.2 762 759.5 760 761.4 I~': Final 793 8 808 738.6 779 777 9 10 10 C)osed i, 793.8 2136 2141.0 2139 2140 .6 60 57 ~ in~t~al 793,8 754 761.3 {763 761.4 ~.~ Flaw Final 826.3 855 858.8 J 864 833 7 65 63 . Oosed in - .2134 - 2137 - 17 -- Initial 826 3 858.8 851.5 ~ Flow ' Nl': Final 844 I 858_8 861 6 66 83 Closed in 852.2 ?1 34.6 m 2130.4 179 168 Final Hydrostatic 2607.4 I ITR 2727 UTR _ FOIIMIII--1~2--PIlNTEDINU.S.A. FORMATION TEST DATA LffTLE'$ /6 Ticket i FLU I D SAM P L E , [ 5c.~'.pler Pressure-- P.S.I.G. at Surface Kind Halliburton of D.S.T. CASED HOLE Location ANCHORAGE Cu. Ft. Gas [ &¢covery:j cc. Oil cc. Water Tester JACK BOWEN Witness i j cc. Mud Drilling Tot. Liquid cc. Contro:torBRINKERHOFF RIG $,avih/_ ° APl @ °F. E q U I PM E N T & H O L E DATA Gas:al! Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation Ft. CONTENT Net Productive Interval Ft. Recovery Water ~ @ ~ °F. ppm All Depths Measured From Recovery Mud ~ @ ~ °F. ,ppm Total Depth Ft. Recovery Mud Filtrate ~ @ ~ °F. ppm Main Hole/Casing Size Mud Pit Sample ~ @ ~ °F. ,ppm Drill Collar Length I.D Drill Pipe Length I.D Mud Pit Sample Filtrate ~ @ ~ °F. .ppm Packer Depth(s). .t t. · ~ud Weight vis sec. Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom C,,~ion Ft. Pres. Valve Choke Choke _ .., _Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of :<: Recovered Feet of _ Remarks FOURTH FI FTH Gauge No. 3647 Gauge No. 7582 Gauge No. TIME TEMPERATURE Depth:5832Ft. Depth:5835Ft. Depth: Ft. (O0:O0-24:00hrs~) 48 Hour Clock 72 Hour Clock Hour Clock Tool Est. °F. Blanked OffYes Blanked OffYes Blanked Off Opened Opened ,Actual °F. Pressures Pressures Pressures Bypass Field Office Field Office Field Office Reported Computed , Initial Hydrostatic 2658 2660.8 2661 2660.7 , Minutes Minutes '~ Flow Initial 793 794.7 798 797.9 ~.~.., Final 818 814.0 !856 845.9 C~osed ~n 2168 2167.8 2175 2172,6 -o~ Initial888 854.3 860 858 5 I c o Flow ' i~ Final 919 861.4 890 858 5 I ~a. ' Closed in 2159 - 2165 - == Initial 877 1 890 1 -- ._~_o Flow .... ~. _ Final 887.7 890.1 Closed in 2157.3 ~ 2163.6 ..... FinalHydrostatic 2766 2632.8 Q 2632.6 Q , - ~ ,, FORMATION TEST DATA ""'"' /,/..¢' i ;.e.r~g peris.. Bottom choke Surf. temp, °F Ticket No., 575765 ,., Oil gravity. GOR ~ grovi~--.~ Sclc' gravity-- Chlorides ppm Res. ~ °F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED Dote ChokeI Surface Gas Liquid Time p.m.O'm' Size,I PressUrepsi MCFRate BPDRate Remarks -- I 0.__99'33 Opened tool with a 1i qht blow on 1/2" choke 09'43 Closed tool 10'43 Opened tool with a weak blow through _ · bubble hose 11'48 Closed tool ,. 11-57 Opened by pass 12'05 Closed by pass and open tool wi~ch a 1 ight blow 12'45 14ell dead 13'11 Closed tool and reversed out 16'10 Pulled packer loose .... · '°"""'-"'-""'"""':"""'""' PRODUCTION TEST DATA Drill Pipe or Tubing Drill Collars ..................... Reversing Sub .................... Water Cushion Valve .............. Drill Pipe ....................... Drill Collars .................... Hor, dling Sub & Choke Assembly ..... Dual CIP Valve ................... Dual CIP Sampler ................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint ................... AP Run.lng Case ..... (2) .......... Hydraulic Jar .................. VR Safety Joint ............... Pressure Equalizing Crossover ......... Packer Assembly ................... O,D. TICKET NO. 1. D. LENGTH 4 1/2" 5n BI, 5n 5" 5" 5" 5" 2.75" 3.826" 3.06" .87" .75" 1.00" 1.00" 3.06" 1.75" 1.00" 12' 5777' 49.38" 81.01" 29.93" 49.38" 60.00" 33.40" 48.00" 8 1/8" Distributor ........................ Packer Assembly :. ................. Flush Joint Anchor ................. 2 7/R" Pressure Equalizing Tube .......... Blanked-Off B.T. Running Case ...(2). 3.87" Drill Collars ...................... Anchor Pipe Safety Joint ............ 11 3.00" 48.34" Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor ................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... 575765 DEPTH 5773' 5788' 5802-5806' ' 5816' 5832'-5835 5925' ,o..,,,_._.,.,,.,...,..EQUIPMENT DATA /¢ ~ Ticket L U I D S A M P L E ., T A Date 2-8-81 N,,mber 575764 1 ~mpler Pressure P.S.I.G. at Surface Kind Halliburton . ;,~covery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE I cc. Oil cc. Water Tester JACK BOWEN': Witness cc. Mud Drilling Tot. Liquid cc. Contractor BR][NKERHOFF RIG~, ~ 58 BM-DR Gravity- ° APl @ °F. E Q U I P M E N T & H O L E D A T A Gms/Oil Ratio cu. ft./bbl. Formation Tested, RESISTIVITY CHLORIDE Elevation Ft. CONTENT Net Productive Interval Ft. Recovery Water ~ @ ~ °F. ppm All Depths Measured From Recovery Mud ~ @ ~ °F. ppm Total Depth Ft. Recovery Mud Filtrate ~ @_ °F. ppm Main Hole/Casing Size Mud Pit Sample ~ @ ~ °F. ppm Drill Collar Length I.D Drill Pipe Length,. I.D Mud Pit Sample Filtrate ~ @ ~ °F. ppm . Packer Depth(s) t Mud Weight vis sec. Depth Tester Valve Ft. _ TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke __ ., Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks FOURTH FIFTH Gauge No.3647 JGauge No.7582 Gauge No. TIME TEM. PEP, ATURE Depth: 5832 Ft.j Depth: 5835 Ft- Depth: Ft. (00:00-24:00 hrs.) 48 Hour Clock 72 Hour Clock Hour Clock Tool Est. °F. Blanked Off Yes Blanked Off Yes Blanked Off Opened Opened ,Actual °F. Pressures Pressures Pressures Bypass Field Office Field Office 'Field Office Reported ComPuted Initial Hydrostatic 2655 2652,1 2649 2651.7 Minutes Minutes ~..= Initial 282 284 2 281 280 0 _~ Flow · * ' ..~.., Final 272 277.1 277 277.4 ... Closed in 930 926.3 923 924.2 'o'o:,, Initial 328 340.3 321 337.6 - Flow §'~ Final 338.5 336 3 Closed in 359.6 358.0 ~ Initial .. ; _.-~.° Flow t~ --, Final Closed in Final Hydrostatic ?~*15 3_g73 ~ ?;24 2B76. B .. , g-i~c zrr :O~M Itl--R2 -- PRINTED IN,U.S.A. FORMATION TEST DATA ' Ticket 'F L U i D S A M P L E ,, T ^ Date 2-8-81 Number 575764 '~ Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE ~[' cc. Oil ~cc. Water Tester J ACK BOWEN Witness cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF RIG # 58 BM-DR Gravity, o APl (~ _°F. EQ U I PM E N T & H O L E DAT,~, Gas/Oil Ratio cu. ft./bbl. Formation Tested - RESISTIVITY CHLORIDE Elevation 77.1' GL Ft. CONTENT 586;]-5870' 9' Net Productive Interval. Ft. Recovery Water __ ~ -- °F. ,ppm Ail Depths Measured From 95' Kal l~v Bushin.q Recovery Mud ~ @ ~ °F. ppm Total Depth 5925" Ft. Recovew Mud Filtrate ~ @~°F. ppm Main Hole/Casing Size 95/8" Casing- Mud Pit Sample ~ @ ~ °F. .ppm Drill Collar Length I.D .... Drill Pipe Length 5777' I.D. 3.826" Mud Pit Sample Filtrate ~ @ ~ °F. .ppm . Packer Depth(s) 5816 ~ It. Mud Weight vis sec. Depth Tester Valve 5788~ Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion 610' Diesel Ft. Pres. Valve Choke .50" Choke .75" Recovered Feet of · ., 13 Reco~/ered Feet of ~'~ ~_ ~ I' ! t! I- ~ - Recovered Feet of .... ~ r~_ ucf 2 6 ]982 = Recovered Feet of °<: ~:~ Alaska 0ii & Gas Cons. C0rnmis~i0n Recovered Feet of Anchorage Remarks 0oened tool .@ 8'15 with a strong blow on 1/2" chokP_. Cln_~p_d tool fa 0Dened tool fa .9:32 with no blow. £1nsP. d tnnl_ R~v~r~d m~t Charts indicate possible partial plugging ..... Gauge No. 6141 Gauge No. 3646 Gauge 'No. 7581 TIME TEM. PERATUREI (00:00-'~4:00 ~rs.) --I Depth: 5773 Ft. Depth: 5802 Ft. Depth: 5806 Ft. 48 Hour Clock 72 Hour Clock 48 Hour Clock Tool c:= Est. . °F. Blanked Off NO Blanked OffNo Blanked Off NO Opened 8' 15 5837' @ Opened Actual 7~ °F. Pressures Pressures Pressures Bypass 11 ' 05 Field Office Field Office Field Office Reported Computed Initial Hydrostatic 2634 2635.8 2616 2617.6 Minutes Minutes Initial 210 207,5 278 295.4 229 268.3 ..... lt.: Flow i;~ Final 272 207,5 227 276,2 247 256,9 10 9 Closed in ,272.8 916 921.6 901 904.8 67 64 Initial 287.5 283 312.9 268' 294.9 : o Flow 8': Final 289 2 319 9 316 4 ? 54 Closed in - 349.6 336.7 ? 42 ,r- Initial ._~.o_ Flow ~. Final Closed in Final Hydrostatic 2628,6 2587 2606,2 2591 2592.0 . FORM I15-R2 -- PRINTED IN.U.S.A. FORMATION TEST DATA · / f~ TICKET NO. 575764 · Drill Pipe or Tubing ...... ~. ....... Drill Collars .................... Reversing Sub .................... Water Cushion Valve .............. Drill Pipe ....................... Drm Collars ........ AP..Case .... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual ClP Sampler .................. Hydro-Spring Tester ................ Multiple ClP Sampler ............... aa D. 5.75" 4 1/2" 5" 11 .~" 5n 2.75" 3.826" 3.06" 11 Extension Joint .................... 1.00" AP Running Case ......... (.2) ...... 5" Hydraulic .Jar .................... 5" 3.06" 1.75" VR Safety Joint ............... Pressure Equalizing Crossover ......... 11 1.00" Packer Assembly ................... 8 ]./~'t LENGTH DEPTH 12" 5777' 49.38' 81.01" 5773' 29.93' 5788' Locked bypass 49.38' 60.00" 33.40" 48.00" 5802-5806' - 5816' Distributor ........................ Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube .......... Blanked-Off B.T. Running Case ....... HT-500 Temp. Recorder Drill Collars ...................... Anchor Pipe Safety Joint ............ ? 7/F~" 3_87" 3.87" 11 3:00" 113.013' 48 _34" 1.5' 5R37' 5837' Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Totol De~th ....................... 5925' & LITTLE'S 111036 7SC 2/80 ,o..,,,_. _.,.,. ,. EQUIPMENT DATA '~, , F L U I D S A M P L E D A Date 2-5-81wk Ticket 575763 Page 1 Number _ -- -- Sampler Pressure ..... P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE ,--. cc. Oil cc. Water Tester MR. BOWEN Witness cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY #58 bc co ' Gravity. ° APl @ __°F. EaU I PM E N T & H O L E DATA I Gas/Oil Ratio . cu. ft./bbl. Formation Tested -- RESISTIVITY CHLORIDE Elevation 77.1 ' GL Ft. co CONTENT - 6026' ' Net Productive Interval 6008' (18) Ft. Recovery Water ~ @ °F. ppm All Depths Measured From95' Kelly Bush in.q Recovery Mud __ @ __ °F. ,ppm Total Depth6510' Ft. Recovew Mud Filtrate __ @__ °F. .ppm Main Hole/Casing Size ~)5/8" Casing Mud Pit Sample __ @ __ °F. .ppm Drill Collar Length - I.D Drill Pipe Length 5901' I.D 3.826" Mud Pit Sample Filtrate __ @ __ °F. .ppm .Ft. -- Packer Depth(s). 5940 ' Mud Weight vis sec. Depth Tester Valve 5912 ' Ft. TYPE AMOUNT Depth Back b/qlVlFLI'K Surface Bottom Cushion Diesel 3750' Ft. Pres. Valve 5900' Choke ~" & ½" Choke .75" .. Recovered Feet of Recovered Feet of ] m Recovered Feet of Recovered Feet of Recovered Feet of SEE PRODUCTION TEST DATA SHEET. OCT 2 6 1 82 · Anchnr~,~ C°fllmi$2,i~n ,,, Gauge No. 6] 41 Gauge No. 3646 Gauge No. 7581 TIME , TEAAPERATU~E Depth: 5896' Ft., Depth: 5926 I Ft. Depth: 5930 Ft. (00:00-24:00 hrs.) ~:~--t 48 Hour Clock 72 Hour Clock 48 Hour Clock Tool Est. 'F. Blanked Off No Blanked Off NO ,, Blanked Off NO Opened 081 4 c= 5959' Opened 1 733 Actual 80 °F. Pressures Pressures Pressures Bypass , , Field Office Field Office Field Office Reported Computed Initial Hydrostatic - - 2702 2707.3 2692 2694.3 Minutes Minutes ~nmo~ 1124 1211.0 1134 1135.8 1133 1131.9 i~.: Flow iZ~. Final 1 264 1 267.8 1 237 1 278.7 1 275 1270.2 1 0 9 Closed in - 1 266.2 2362 2367.1 2354 2356.7 60 59 -o.o Initial - 1266.2 1258 1259 5 1252 1251 2 : o Flow ' ' ~'~ ~-~ F~na~ 2189 9 1410 2192 3 2181 2182 8 400 400 -- . · . ~" Closed in 21 89 2342 6 2331 2332 4 89 91 initial ._~_o Flow ~.. Final Closed in ,., Final Hydrostatic - 2666.1 2954 2663· 7 2977 2653.4 ,,, , ,o,,.,,,,_,,_,,,.,,,,,,,,.,.,. FORMATION TEST DATA ""'"' I · F L U I D S A M P L E T X Date 2-5-81 Ticket ~75763 Page 2 .,~2o Numbek' _ ~ -"Ir" Sampler Pressure P.S.I.G. at Surface Kind Halliburton · Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE ~. cc. Oil MR. BOWEN cc. Water Tester Witness cc. Mud ' Drilling Tot. kiquidcc. ControctorBRINKERHOFF DRILLING C0NPANY #58 bc co Gravity ° APl @ °F. EQU I PM E N T & H O L E DATA , Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation Ft. CONTENT Net Productive Interval Ft. .,.,-I Recovery Water ~ @ ~ °F. ppm All Depths Measured From CD Recovery Mud ~ @ ~ °F. ppm Total Depth Ft. ~- Recovery Mud Filtrate ~ @ ~ °F. ppm Main Hole/Casing Size Mud Pit Sample ~ @ ~ °F. ppm Drill Collar Length I.D. Drill Pipe Length I.D Mud Pit Sample Filtrate ~ @ ~ °F. ppm Packer Depth(s) Ft. , Mud Weight vis sec. Depth Tester Valve Ft. , ,,. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of .. ~ Recovered Feet of ~ Recovered Feet of ~ ---- < Recovered Feet of Recovered Feet of Remarks 4th GAUGE 5th GAUGE ,, Gauge No. 3647 Gauge No. 7582 ' Gauge No. TIME TEM, PERATURE (.7) Depth: 5953' (00:00-24:00 hrs,) CZ: Ft. Depth: 5957' Ft. Depth: Ft. 48 Hour Clock 72 Hour Clock Hour Clock Tool Est. °F. Blanked Off Yes Blanl~ed Off Yes Blanked Off Opened Opened Actual 'F. Pressures Pressures Pressures Bypass , Field Office Field Office Field Office Reported Computed ...... Initial Hydrostatic 2725 2727·2 2730 2729.5 Minutes Minutes ..~ Initial 11 58 11 60.8 1166 1165.8 _¢.~ Flow Final 1 269 1 304 2 1258 1 255 1 Closed in 2381 2388.1 2386 2388·7 ~ Initial 1283 1281.4 1 287 1 285 7 r- e o Flow ' .o.= F~no~ 2204 2208 0 2210 2211 0 ~ Closedin 2358 2358·4 2359 2360.6 Initial ~ Flow ~. Final Closed in Final Hydrostatic 2778 2681.8 2779 2688.7 ,o,,.,,,,_,,_,.,,,,,,,,,,,.,.,. FORMATION TEST DATA 575763 Casing perfs. Bottom choke. Surf, temp °F Ticket No Gas gravity Oil gravity. C~R SpeC. gravity Chloride,~ ppm Res .... @ 'F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED Dat'"';- Choke Surface I Gas Liquid Pressure Rate Rate Remarks Time a.m. Size psi MCF BPD D.m. -- 0814 J Opened tool with a weak blow through ¼" choke 0824 C1 osed tool 0924 Opened on ¼" choke with a weak blow, -- decreasing with diesel cushion to surfa -- 1057 Flowing very slowly, heading, no gas -- 1604 Closed to°l. Reversed out remainder __ diesel cushion and formation water, __ no gas __ 1733 Pulled packer loose __ ~ORJ4 I~2-RI~PRINTED IN U.S.A. PRODUCTION TEST DATA '! ~. ..c: , ~- J I ~ ti... .... ,~ ,.,: ........ o d E : 0 ~ o,'-...~o~o,,.oroc:n,.oroo-,~o,.,iol Z ,'.- ,, i: ................-- ~ "~: O&c .......... , · , ~E~ ~ o c:n r-.. c,,: o'., co o4 t--. ,~- ,.- 'o ':' 0~1 00.0 CD ,-- .,_..~,l-- ,.- ,-.-:..1!(%1 -)c E ~,b c::~,::::t-cm,:::::t-0OO')0Oo,.Ir.-. .r'..~ [ · CD 00,--..,-- C%1 ¢x. JOOOO c~:c:::l.- ' ....... o n~b C:D 0 -- ,-- O,J CO CO ,ct' LO I.~ ~ ~oo. ._ ,,¢u ~.,..,"° i i i i i i iii iii i i TICKET NO. 575763 Drill Pipe or Tubing .............. Drill Collars ...................... Reversing Sub .................... Water Cushion Valve .............. Drill Pipe ....................... ~:~m~:.. A.P.cas. e .......... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Locked open by-.pass Multiple ClP Sampler ............... Extension Joint .................... Co. ......... (2) ...... · Hydraulic Jar .................... VR Safety Joint ................ Pressu re Equa I i zing Crossover ......... 4.~,, 5n 5" 5" 5n 5" 5n 5n 5n 2.75" 3.826" 3.06" Packer Assembly ................... 8 1/8" .87" · 75" 1" 1" 3.06" 1.75" 3" .--. . LENGTH DEPTH 1 2" 5901' 49.38" 8:1.01" 29.93" 49.38" 60" 33.40" 48" 10' 48.34" 1.5' 5896' 5912' 5926' 5930' 5940' 5953' 5957' 5959' Distributor ................... .. .... Packer Assembly ................... Flush Joint Anchor 2.. 7. / .8.".. D: P., .... Pressure Equalizing Tube .......... Blanked-Off B.T. Running Case ...(~.). HT-5O0 Drill Collars ...................... A~chor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... 2 7/8" 3.87" 3.87" 651 0' PRINTED IN U.S.A. EQUIPMENT DATA ,' F L U I D S A M P L E D A Date 1-28-81 Ticket 575761 . Number . e_. Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE ', _-. cc. oil MY,. FiLCHER - cc. Water Tester MR. BOWEN Witness MR. REDLINE cc. Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF-SIGNAL DRILLING COMPANY Gravity. ° APl @ °F. E q U I PM E N T & H O L E D AT A Dj " Gas/Oil Ratio cu. ft./bbl. Formation Tested Beluga RESISTIVITY CHLORIDE Elevation77.1 Ground LevelFt. CONTENT 6530' to 6547' (Perf's) Ft. co Net Productive Interval Recovery Water ~ @ ~ °F. ppm All Depths Measured From Kelly Bushin.q -95' Recovery Mud ~ @~°F. 275 ppm Total Depth 6731' Ft. Recovery Mud Filtrate ~ @ ~ °F. ppm Main Hole/Casing Size9 5/8" Casing ~-° Mud Pit Sample ~ @ ~ °F. ppm Drill Collar Length - I.D. - Mud Pit Sample Filtrate __ @_ °F. ,ppm Drill Pipe Length 6466' I.D, 3, $26" Packer Depth(s), 6503' lt. Mud Weight 76#/cu. ft. vis sec. Depth Tester Valve. 6475' Ft. TYPE AMOUNT Depth Back Surface 4 '~- ,~ottom_ .. ,, Cushion Ft. Pres. Valve Choke1/ 1/2ChokeJ//Jr Recovered 504 Feetof reversed out 7.17 barrels sandy drilling fluid Recovered 210 Feetof sandy drilling fluid below bar drop reversing sub .... Recovered Feet of Recovered Feet of ('~T 9/q ~i30G Recovered Feet of Alaska I]il ,~, P~n~ n~,,~. .......... Remarks SEE PRODUCTION TEST DATA SHEET .... Anchorage * Tools apparently plugged after 85 minutes .... Closed in pressure started at this time .... Charts indicate severe plugging of anchor perforations throughout flow periods .... #6141 Ran above tool Gauge No. 6141 Gauge No. 3646 Gauge No. 7581 TIME --! TEMPEr^TURF , Depth: 6460' n. Depth: 6489'Ft. Depth: 6493' Ft. (00:00-24:00 hrs.) ~CZ 48 Hour Clock 72 HourClock 48Hour Clock Tool ~ Est. °F. Blanked Off Blanked Of~10 Blanked Off NO, Opened 0800 b b JU' Opened Actuc~6 ,9 'F. Pressures Pressures Pressures Bypass [ 5 ) 0 Field Office Field Office Field Office Reported Computed initial Hydrostatic - . J(Jb4 3055.9 3161 3056.1 M~,,te, M~n~t,, ...... Initial 26 35.9 56 62.9 58 51.8 .Do~ Flow Final 26 37.5 49 47.2 52 49.3 10 11 ~'" Closed in - - 2656 2660.2 2666 2657.2 66 66 ~= Initial 65 55 5 80 75 I 77 72 1 i-: FlawFinal 181 189 5 2298 209.7 1933 211 3 104 85* Closed in - - 2681 2675.9 2680 2675.1 250 269 ,~, Initial .... ._~.o_ Flow ~.~.. , Final Closed in ., .... Final Hydrostatic 3163 3042,3 3034 3047.2 3038 3049.7 ...... , FORM 181--R2 -- PRINTED IN U.S.A. FORMATION TEST DATA LITTLE'S Page 2 FL U I D S A M P L E D , Dote 1-28-81 Number 575761 Sampler Pressure P.S.I.G. at Surface Kind Halliburton J Recavery: Cu. Ft. Gas _ _ of D.S.T. CASED HOLE Location ANCHORAGE / =c. Oil MR. PILCHER I cc' Water Tester MR BOWEN Witness MR REDLINE J cc. Mud Drilling J Tot' Liquid cc. Contractor BRINKERHOFF-SIGNAL DRILLING COMPANY JGrovi_ty~ °APl@ ____~°F. EQUIPMENT & HOLE DATA bj-'~'_ J Ga_~_s/Oil Ratio cu. ft./bbl. Formation Tested. RESISTIVITY ~1-~ Elevation Ft. CONTENT Net Productive Interval, .Ft. J Recovery Water @ °F. .ppm All Depths Measured From J Recovery Mud @ °F. .ppm Total Depth .Ft. J Recovery Mud Filtrate @ °F. .ppm Main Hole/Casing Size Mud Pit Sample ~ @ ~ °F. .ppm Drill Collar Length I.D j Mud Pit Sample Filtrate ~ @ ~ °F. .ppm Drill Pipe Length I.D Packer Depth(s) t t. iMud Weight vis sec. Depth Tester Valve, .Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of Recovered Feet of I Recovered Feet of Recovered Feet of Recovered Feet of i, Remarks * Tools apparently plugged after 85 minutes. Closed in pressure started at this time .... Charts indicate severe plugging of anchor perforations throughout flow periods .... FOURTH GAUGE· FIFTH GAUGE; Gauge No. 3647 Gauge No. 7582 Gauge No. TIME TEMPERATURE Depth: 6523~ Ft. Depth: 6527' Ft.I Depth: Ft. (00:00-24:00 hrs.) 48 Hour Clock 72 Hour Clock Hour Clock Tool Est. °F. '"Blanked Off YES Blonl~ed OffY[$ Blanked Off Opened 0800 6530" Opened Actual 867 °F. Pressures Pressures Pressures Bypass 1510 Field Office Field Office Field Office Reported Computed InitiaIHydrostatic 3090 3078.6 3089 3083.~ Minutes Minutes .,.~o Initial 84 96 4 80 80,5 ~.c Flow .... . · ~..~. Final 70 71.9 77 72.8 10 ... Oosed~n 2688 2685,3 2681 2681,9 66 66 =: Initiol 91 96 4 97 95.9 · ~.~ FlawFinal 1967 585 9 1989 588.3 104 85* Oosed~n 2708 2704.5 2703 2702,0 250 269 Initial .~_.e Flow ~. _ Final Closed in _Final Hydrostatic 3060 30.54.. 1 ~06.R ~flR~.q .... _.. , ~ O FORM III-R2 - PRINTED IN U.S.A. FORMATION TEST DATA ., Casing perfs .... Bottom choke Surf. temp_, °F Ticket No Gas gravity Oil gravity ~GOR Spec. gravity ..... Chloride~ , ppm Res. @ °F INDICATE TYPE AND SIZE OF GAS MEASURING DE¥1CE USED . -- Date Choke Surface Gas Liquid Time a.m, Size Pressure Rate Rate Remarks o.m. ~i MCF BPD 08:00 Opened tool wi th a light bubble hose -- blow. -- 08'10 Closed tool for closed in pressure period. _ 09'16 1/2" Opened t~ool with a light bubble hose _ blow, decreasing to dead. _ · 11'00 Closed tool for final CIP period. 11' 36 Reversed out. 15'10 Pulled tools loose. ,,, ,,, _ ,, ! F'ORM 18:~.RI--PRINTED IN U.S.A. PRODUCTION TEST DATA LITTLE:'$ 96672 51~ 8/74// O.D. Drill Pipe or Tubing .............. Drill Collars ................... Reversing Sub .................... 5.75ll Water Cushion Valve .............. Drill Pipe ....................... 4.50" Drill Collor~ ..................... AP CASE-5. 00" Dual ClP Valve ................... Dual ClP Sampler. ................ 5.00" ~-..d,o-s~:!.-.; T=::~ ......... ! N.D. EX .I NG 5.00" J, D, 2.75" 3.826" 3.06" .87" · 75" 1.00" 3.06" 3.06" 1.75" 1.00" 2.00" 3.00" _~,,,,,.,,o r,, Snm.-'_~r . .L0.C.K-.B.Y.-.P. ASS AP RUNNING CASE AP Running Case .................. Hydraulic Jar .................... 5.00" 5.00" 5.00" 5.00" 5.00" 8 1/8" VR Safety Joint ................ Pressure Equalizing Crossover ......... RTTS Packer Assembly ................... Distributor ........................ Packer Assembly ................... ........ ,~. 2 7/8" DRILL PIPE- 2 7/8" 1 I~.~11 ~lglllJ f~*ll~llm ................. Pressure Equalizing Tube ' Blanked-Off B.T. Running Case . (2.)... 3.87" Drill Collars ...................... Anchor Pipe Safety Joint ............ TEMP. RECORDER ~c'.,c~ ,*,~ r.:~%b- ................... 3.87" Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... LENGTH 12n 6466' 49.38' 3.75' 29.93" 49.38" 49.38" 60.00" 33.40" 48.00" 10.00' 48.34" DEPTH 6460' 6475' 6489' 6493' 6503' 6523' 6527' 6530' 6731' FORM 187--R2 -- PRINTED IN U.S.A. EQUIPMENT DATA ~ L U I D S A M P L E ,' A Date 2-i 8-81 . Ticket 576520 page 1 Number So~Pler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of D.S.T. CASED HOLE Location ANCHORAGE .. cc. oil MR. SHEPARD cc. Water Tester Witness cc. Mud DrnI~ng BRiNKERHOFF DRILLING COMPANY #58 bc Tot. Liquid cc. Contractor Gravity. °.APl @ °F. E Q U I PM E N T & H O L E D A T A Gas/Oil Ratio cu. ft./bbl. Formation Tested. ~-~ RESISTIVITY CHLORIDE Elevation 77.1, GL Ft. CONTENT _.~ Net Productive Interval 4684' - 4700' (1 6' ) Ft. CD Recovery Water ~ @ ~ °F. ppm All Depths Measured From95' Kel 1.y Bushinq Recovery Mud ~ @ ~ °F. .ppm Total Depth /~800 ' Ft. Recovery Mud Filtrate ~ @ ~ °F. .ppm Main Hole/Casing Size 9 5/8" Mud Pit Sample ~ @ ~ °F. ppm Drill Collar Length ,, - I.D Mud Pit Sample Filtrate ~@~°F. ppm Drill Pipe Length Tubing 4597' ~.D 2.750" . Packer Depth(s)., 4643 ' Ft. Mud Weight 72#/cu. ft.;is 38 sec. Depth Tester Valve 4615' ........... Ft. , TYPE AMOUNT Depth Back IJblF VALVbSurfocel ,i Bottom 75,1 Cush~on Water 130' Ft. Pres. Valve 4603' Choke ~ & 3/8m' Choke . 2335.81' Sand and formation water (17.16'barrels) Recovered Feet of Recovered Feet of ~ co Recovered Feet of ~ Recovered Feet of ~ Recovered Feet of Remark~ Charts indicate partial plugging during flow periods. RECEIVED *Tools apparentl.v did not close at time attempted. SEE PRODUCTION TEST DATA SHEET. OCT2 6 ]982 on ;Alaska Oil & Gas Cans. ~,,,,.,,,~,s~io~ Gouge No. 6141 Gouge No. 3646 Gauge No. 7581 TIME > TEMPERATURE Depth: 4600~ (00:00-24:00 hfs.) ---I Ft. Depth: 4628' Et. Depth: 4632' Ft. 48 Hour Clock 72Hour Clock 48 Hour Clock Tool c: Est. 70 °F. Blanked off No Blonl~ed Off NO Blanked Off No Opened 2053 Opened 0908 Actual OF. Pressures Pressures Pressures Bypass , Field Office Field Office Field Office Reported Computed Initial Hydrostatic - - 19 57 19 57.9 Minutes Minutes ...~ Initial 50 76.7 CLOCK 1 39 141.7 r,.: Flow J~ L[~. , Final - 364.3 STOPPED .... 373 529.1 120 184' eased ~,~ 360 366.0 1 671 1 670'.9 255 1 88* ~= Initial _ 366.0 421 407.5 : o Flow 8'c Final 745 745 1 777 852 7 120 120 ~r- Closed i~ ~ 1622 ' 1624 9 240 242 Initial ._~._o Flow ~: ~ Final Closed in Final Hydrostatic - 1 944.8 1 944 1946.4 I , FORM 1ill--R2 -- PRINTED IN U.S.A. FORMATION TEST DATA S A M P L E D ~ Date 2-1 8-81 Ticket 576520 page 2 Number t-.--~~~ .P.S.I.G. at Surface Kind HalliburtonAiqC, l.iFiD/lP. IZ t ~,er p~essure CASED HOLE '= of D.S.T. Location n~ ,u,~nu~- , Recovery: Cu. Ft. Gas cc. oil MR SHEPARD · cc. Woter Tester · Witness cc. Mud Drilling BRINKERHOFF DRILLING COMPANY #58 bc , Tot. Liquid cc. Contractor Gravity- ° APl @ °F. EQ U I PM E N T & H O L E D A T A Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation Ft. ! CONTENT ,,..ii Net Productive Interval .Ft. CD Recovery Water ~ ~ -- °F. .ppm All Depths Measured From ;~" Recovery Mud ~ @ __ °F. .ppm Total Depth Ft. Recovery Mud Filtrate ~ (~_ °F. .ppm Main Hole/Casing Size Mud Pit Sample __ @ ~ °F .ppm Drill Collar Length I.D Drill Pipe Length I.D. Mud Pit Sample Filtrate ~ (~ ~ °F. ppm , Packer Depth(s). Ft. Mud Weight vis sec. Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke -- Recovered Feet of . Recovered Feet of Recovered Feet of Recovered Feet o{ Recovered Feet of Remarks 4th GAUGE 5th GAUGE Gouge No, 3647 Gauge No. 7 582 Gauge No, TIME '" ---i TEMPERATURE (./3 Depth: 4656'Ft. Depth: Ft. Depth: Ft. ..... CZ:: 4661 ' (oo:oo-~4:oo h~.) 48 Hour Clock 72 Hour Clock Hour Clock[ Tool Est. °F. BlankedOff Yes Blanl~edOff Yes BlankedOff Opened _ , , Opened Actual °F. Pressures Pressures Pressures Bypass _ Reported Computed Field Office Field Office Field Office Initial Hydrostatic 1967 1 970.2 1978 1978.3 ~.,,te. Minutes Initial 1 54 1 54.3 161 1 61.1 _ .~.~. Flow ,~. Final 421 547.3 425 553.0 Ctosed in 1685 1687.0 1696 1697.7 _ Initial 491 492.9 502 503.7 r- '}-(3 -- ~.~ FlowFinal 1 289 1 069 9 1 278 984 8 Ctosed in 1635 1638.1 1646 1651 7 Initial -- __ ._~._o Flow ~: ~ Final Closed in Final Hydrostatic - 1963.2 - 1975.7 , ,,, .,, ! ,o,,,,,,,_,,_,,,.,,,,,.u.,... FORMATION TEST DATA 576,520 ,: ; pcrfs Oii gravity.~'~ · Chiorides __ppm Res ..... ~' °F ~D~cATE TYPE AND SIZE OF GAS MEASURING DEVICE USED. ~ ~q ' Sub'ace Gas L~quid '~'~ '~ } ~-OJ Choke ¢ - a.m. : Size Pressure Rate Rate ~emarks p.m. ~ psi MCF BPD t i ....... ~ , ; i , ] ~ ~ 0~ened to,s] v,'~th a stron,~ blow 1253 , I [ thxough bubb]e ~ose, {ncxeasing 9108 ~ ~ Opened 3/8" choke, gas to surface~ but wouqd not unload cushion 2113 3/8" 20 2121 " 0 Closed 3/8" choke 2125 lO 2137 0 2150 20 22t5 lO 2253 / 20 Closed tool 0308 Opened tool ~hxough 3/8" choke 0343 Blow dead 0345 Closed 3/8I' choke 0350 4 0508 Closed tool 0908 Pulled packer loose ...... t , ,,, ~ c.l~l,~ ~I~2-R1--PIRINTED IN U.S.A. PRODUCTION TEST DATA O. D. TICKET NO. LENGTH Drill Pipe or Tubing .............. Drill Collars .................... Reversing Sub .................... Water Cushion Valve .............. Drill Pipe ........... Tubi.ng .... _~_m__~__m~__~ AP Case Handling Sub & Choke Assembly .... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-,Spriqg T/~ster ._. LOCKed open byzpas'~ .... Multiple ClP Sampler ............... Extension Joint .................. AP Running Case ........ (2) ....... Hydraulic Jar .................... VR Safety Joint ................. Pressure Equalizing Crossover ......... Packer Assembly ................... 3.50" 3.5" 5" 5" 1! 11 5" 5" 5" 8.175" 2.875" 3.87" 2.25" 2. 750" 3.06" II 3.06" 1.75" 1" 2.25" 2" 3" · 576520 ~ .------,i, DEPTI-! 1 2" 4597' 49.38" 81.01" 4600' 29.93" 4'61 5' 49.38" 60" 33.40'l 48" lO' 48.3J~" 4628~ 4632' §643' 4656' 4661' Distributor ........................ Packer Assembly ................... Flush Joint Anchor .2..7/.8.".. D.,.Pt... Pressure Equalizing Tube .......... Blanked-Off B.T. Running Case . .(,2).. Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor Blanked-Off B.T. Running Case ........ Total Depth ....................... 4800' FORM 187--R2 -- PRINTED IN U.S.A. EQUIPMENT DATA LITTLE'S 111036 7~,2~0 Check Form for timely compliance with our regulations. Operator, Wel 1 Name and Number Reports and Materials to be received by: Date Completion Report Required Yes Core Chips Directional Survey Drill Stem Test Reports Yes i Yes Date Received Remar}[s Chevron Chevron U.S A. Inc. P.o. Box 7-839, Anchor:~e, AY, TRANSMITTED TIIE FOLL0WI~G IS A LIST OF MATERIAL ENCLOSED HER£IN. PLEASE CtIECK AND ADVISE I~D~IA'. .... , RE:C~IYED AND By ~, . . ~ z~,'-~//~2,.- z'/~ ,,, ~AN-/I~83 RETURN.' DATB' Alaska 0il & Gas Cons. Commission ' A~M~o~age T R A N S. STATE OF ALASKA ~(' ALASKA . .L AND' GAS CONSERVATION CO .SSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Receipt of the following material which ._ was transmitted via hereby acknowledged: QUANT I TY DESCRIPTION Copy sent tg~ sender YES ~ NO 5o'I 'a PaZT~'l:(l- /:aA.:mg UOT~UTTOUI- &aA=ns paT~Tq~aO- ~O~STH [ Ta~- ~e~, 5o"1: '~ peZT~T6Ta- teA~n~ UOTl~UII ouI- I8/6~tg ~t££-IE# 'a 'AT~/ uosue~$ a~e& 5o.,i .:~ PaZTq, TSTC~- 5o,I 'E paZT~TSTG- ZStS/O~ ~'eT~1 XaA~n~ paTa:Tq~a.D- 6£8-~ xoa ~86T 'LT aun£ m --o ~ .-- -1 f~ x f-- "~ '~ O, o, C o o -.. "1 !"'il.~ o' ~ o, ~ o, ..~ 0 n t- Fn , 0 ¢ o ! . .chevroq Chevron U.SA. Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 May 25, 1982 T. L. Perryman Area Operations Superintendent Production Department . WELL COMPLETION INFORMATION .State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. Kugler Dear Mr. Kugler: Enclosed is the material requested in your April 21st correspondence. Also included with this transmittal is information on Soldotna Creek Unit well #323-4. Not included are mechanical drawings for wells SCU 42-5A, SCU 44-8A and SCU 41-9A. Our drafting department is presently overloaded. I will forward these drawings to you when they have been completed. Also missing arethe~ested samples and core Chips from Beluga River Unit wet~'#2~,35~ There were no core samples taken from this well. ~- Should there be any questions contact this office. Very truly yours, T. L. Perrym~4 DMW.: draw Enclosure COMPLETION REPORT - NEW WELL AREA: Beluga River Field LAND OFFICE: Kenai Peninsula, Alaska Anchorage PROPERTY: Beluga River Unit LEASE NO: ADL - 17599 WELL NO: BRU 214-35 API NO: 50-283-20067 LOCATION AT SURFACE: 1177' N & 896' W of the Southeast Corner, Section 34, T13N, R10W, S.M. LOCATION AT TOTAL DEPTH: 1238' S & 2051~' E Of surface DATE: 1/82 BY: AREA SUPERVISOR DRILLED BY: Brinkerhoff .Signal Drilling Company Rig 958 DATE COMMENCED .-WORK: DATE COMPLETED . WORK_: RETURNED TO PRODUCTION: 1'2/17/80 -3./7/81 TOTAL DEPTH: 6819 ' EFFECTIVE DEPTH: 4636 ' SUMMARY, PLUGS: 4636 ' (cement) CASING: 30' driven at 79' 20" cemented at 410' I Ei:EIYEI) 13 3/8" cemented at 3930' 9 5,/8" cemented at 6818' MAY 2 ? 1982 ~k~ 0il & Gas Cons. Commission ~chorag~ ~£LL ~0. BRU ~ELL SURVEY Pro-312 214-35 COU:.,lI¥ *OF. Bel ug_a CITY OF ,'TO'~ISHIP 13N RAI4GE 10N r'~ $.i~.B. & ti. ~ - LOT HO, FI ELD :~ -, LO CAT I ON 1::3 ~.D.B. & H. 1177' North' of and 896' West from Southeast Corner, Sedtion 34, T13N, RIOW, S.M.., Alaska ELEYATIO~i: GRCU~ID ' ' C~CRETE HAT "' DERRICK FLO02 A L T E R N A T E O"R "S U R V E y E D L 0 C 'A'-j- j'O ~ .......... ' LOCATIO~ ' ' DESI GaATIOX - LOCATION COOR'D I =lATE3, Final y: 2 621 067.2~ :,'."' :.' '~:. · -' ..... , ,, .. , , , ......... ,., ,, ,J , , m. , x 316 9'74,'43 ' ..- ..... . , ~ ~, , , ,, , , _ . , . Lat. = 61°.10'i2'~:2357N~' " ':' '" ,,. '"' , .' ,, :-" ,. ,,i .~ . . , · "Inn_~n~: 151°02'12.001"W . ..'~' · .... -' . - , ,. , , ,, , , , ., , , . '. ..... .~ ~.'~?".~t: :~'. :. ...... ..':,'~.' ...... . ,....-[. ,....~..' ~ ~. .~ ~ i'{~.,'~' . .. .... , , , ~ , .. . .. ?.~ ~. : · ,'. }-...~. ; ~;:~ 'r. ,, ,~. ~...','~'...,~.:.,'.~ ', .... , .,, ,. ~ . ... :~. .... :/. ~.', ~... . .- ,,,, , , ~ ,. ~ ./,.~.';} .,'. .: , , ,. ~ ,, ,, , .... ~... ~ ~. ~ ~x~*-~ ........ - ....... . . .._ , .::.,,:?...,.- -,..~.',.~,~.:-,~ . .-.:/.:*.,' --:'::.: .... · .. I ' ': .... : ,.-;;-.-': I i~';:~'.,:~:::!'~ . :...:? . ---+-''-~:::':'+-:~='~ ..-!-:.,';'Co°rdi~ates are..:'ala~k~ State Plane ' "' I" ' I , ' .... ' 3.4 I . : .' -. I. -": ' ..:.~ .... . . I '.., LOC.'..,<-. ': :=;' ' ...... "' --- ,+---- J-,:': ' .... I:";'~"-'i I I"'?-'"" i'~.! ! ' '"' ~'''?'? ......'11'~1 "':;" I . - , ,|'.'" ,:t-' -~ -MAY271982 SOUTH BF,~C~t NA R× I S: .......... C.C. DIV.. FILE .~ 1 Chevron Chevron U.S.A. Inc. Tran ~ Regional Technical Services Exploration, Land and Production Western Region P.O. Box 1272, Plat 103, Richmond, CA 94802 ~ittal of Confidential Data 0ate 5/4/82 Ship to By D. L. GIBS ON/mlm A~HO~GE, ~~ 99503 ~ Ck'd. By Waybill No. Attn' HI~ GATES~ 6183724 ,., ~ In,ure-Value $ ~ Register-No. ~ Certify-No. ....... I Quantity Description Area Line Profiles Remarks 2 BO~ CO~AINING T~ FO~OWING ~LL: C~ON ~LU~ R~R ~T ~m,~ 35 M/L... 5~ '-68~ / SECO~ S~. .... . .............. ,,, .... ,, ,, I ...... ,, ............ ,., ........ I nstru ctio ns: Please acknowledge Raceipt and return. By ,~ . ,/ ." EXP- 175-1 (CD-4-81 ." Printed in U.S.A. JAY S. HAMMOND, E, OVEIINOR ALASKA OIL AND GAS CONSERVATION COMMISSION Mr. T. L. Perryman, Area Operations Supervisor Chevron U.S.A. Inc. P. O. Box 7-839 Anchorage, Alaska 99510 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501;-3192 TELEPHONE (907) 279.'-1433 April 21, 1982 Dear Mr. Perryman: We wish to bring to your attention that the belch-indicated material on the following 'Chevron wells has not yet been received by the Alaska Oil and Gas Conservation C~mmission: Well 'Completion Date Beluga River Unit 9214-35 3/7/81 (2nd notice; see attached copy of 10/8/81 letter) Soldotna Cr. Unit #21-4A 3/7/81 Soldotna Cr. Unit .942'-5A 10/5/8l Soldotna Cr. Unit .#44'8A S°ldotna Cr. Unit #41-9A 11/7/81 6/2/81 Missin9 Material History ~fied Survey Plat -Directional Survey -DST or Prod. Test Reports -Digitized E. Log Tape -Certified Survey Plat -Digitized E. Log Tape C. I.X~S -Digitized E. Log Tape -Well History _~~cl HistDrY . ~s -D:igit±zed ~.. Ix~ Tape Swanson River Unit .931-33WD Swanson River Unit ~32-33WD 5/29/81 5/29/81 -Inclination Survey -Digitized E. Log Tape ~ History -Certified Survey Plat -Inclination Survey -Digitized E. Log Tape Please submit the above material at your earliest convenience since you are now in violation of Title 20, Chapter 25 of the Alaska Administrative Code. Very truly yours, Harry Kugler C~mmissioner ~¥ ~,~,'~ ~.". "r~.~ March 11, 1982 Mr. T. L. Perryman Area.Opera'tions Superintendent .Chevron' u.s.A. Inc. P. O. Box 7-839 Anchorage, Alaska 99510 Dear Mr' Perryman: $Ve have received your letter of ~1arch 5, 1982 concerning a time for testing of certain wells in the Beluga River Field. This letter will serve to notify you that the',Alaska Oil and Gas Conservation Commission, per 20 AAC 25.225~.~.~~pproves the testing of wells No. 221-23, No. 224-13 and ~q~-. 214.7~3~during the ~ sunm. aer months of 1982. The results o~f'-Lr'a'~5-multi.-point back pressure test must be reported 30 days after the test has been completed. Yours very truly, Harry ~¥. Kug Commi ss loner BY ORDER OF THE COP~II SS IONER Chevron Chevron U.SA. Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 T. L. Perryman Area Operations Superintendent Production Department March 5, 1982 WELLS 221-23, 224-13, 214-35 OPEN FLOW POTENTIAL TESTS BELUGA RIVER FIELD, ALASKA Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Chatterton, We, as operator of the Beluga River Uni~_~recently completed Well # 221-23 and will soon complete Well~~and # 224-13 for produc- tion. These wells are being complete~ f~r use as backup wells for the existing Beluga River wells and will only be produced in emergency sit- uations. Pursuant to article 3, section 225 of the AOGCC regulations we request that we, as operators, be allowed to perform the required tests during the upcoming summer months. Please advise us of your approval on this matter. Very truly yours, T. L. Perryman JBL:fw MAR o 91982 Alas~ Oil & 6a$ Cons. Commission Anchorag~ TIG\NSHITTAL AND ACKMOb~I.EI)GEHI"NT OF RFCEII'T OF NATI':RIAL - ,90GCC, · FOLLOWING IS A LIST OF ~TERI,~ ENCLOSED HE~IN. CtlECK ~D ~VISE I}~DIATELY. RUNS (ALASKA) BLUELINE PLEASE SEPIA INDUCTION ELECTRICAL LOG ~ DUAL INDUCTION LATEROLOG ~om~o~.~ co~,sNsa~:~n sonic BO~tlOLE CO~. SONIC w/caliper BO~IIOLE COb~. SONIC. w/ga~aa BO~tIOLE TELEVIEk~R -~High Rep.,~ CONTINUOUS ~m.m. TER ~-~ CD~f- ~ .... r__,__ CE}~NT BO~ CASING COLLAR LOG - Per~, Rec, COMPENSATED FO~.~TIO~ COF2ENSATED NEUTRO~ ~, FOP&~TION ~ALYSIS LOG FO~L4TION DENSITY LOG F F FOF&L~TION TESTER FO~.bkTION FACTOR F F G~=, tl ~Y - NEUTRON G~,~% ~Y CO:LL~ LOG 14I CROLATEROLOG ~Z~T~O~ ~os -- ~~ MICROLOG PROXIHITY RWA COF~ARISON PLOT S~'~DSTONE ~ALYS IS S~.A~,~D S Ip'EWALL NEUTRON POROSITY . x _ _ TE~eE~TU~ L~ / ' cO:.~'LZT~O:~VO~T .......... ~CTXO::AL SU~VZY _ CORE DATA SA}~kB,~:D TABUI Am LISTING ~ .... ._ _L_ ;. ~_ ~ ~.. ~ :~.._ .... ,..a~ I,v_ _ ~~' ~~~~y: .... ~,,.~d .~d ¢~d by: '.OCT 2 O 198t Naslm 0il & Gas Cons. Commission A~chomge · I ! I00 200 October 8, 1981 Area ~ations Superintendent Che~on ~A, ~c. P.O. ~ 7-839 Anchorage, A~ska 99510 Beluga River Unit No. BRU 214-35 Permit ~o. 80-72 Dear lit. Magees The subject well was 'completed ~rch 7, 1981. Please 'be advised that as of October 8, 1.98'i, the Alaska Oil and Gas Conservation Co~missto~ has not received the following required material on the wel 1 = -Wel 1 histor~ -Samples (washed and dried ditch cuttings) -Core chips (a wedge chip frc~ each foot of recovered core ) -Core description -Mud leg -Registered survey plat -Dir.e~ional ~rv~ -All l~s run an~ tape of digitized log ~ata, as per 20 AAC 25.~36(a}9 (b)(5}, and Pleas~ submit the above material a~ soon as possible. very truly yours, ~illi~ Van Alen Petrole~ ~ologis~ STATE OF ALASKA ~-~ M -'--'HL¥OIi1'-ALASKA ~r". AND GAS CONSERVATION CC(' ~llSSlON · REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well J~, Workover operation 2. Name of operator 7. Permit No. CHEVRON U.S.A. INC. 80-72 3. Address 8. APl Number P.O. Box 7-839 Anchorage, Alaska 99510 50- 283-20067 4. Location of Well at surface 1177' N. and 896' W. From S.E. corner Sec. 34, T13N, ,RIOW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 77. l' GL 6. Lease Designation and Serial No. 9. Unit or Lease Name Beluga River Unit 10. Well No. BRU 214-3 5 11. Field and Pool Belug~ River Field For the Month of March ,19 8l ' 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Effective plug depth 4636'. Top of fill at 4610'. Shut in well wi th tubing plug at lll' Released rig at 2'OOpm March 7, 1981. Awaiting surface facilities a~d flow lines. 13. Casing or liner run and quantities of cement, results of pressure tests Left 2-3500 psi pressure bombs with clocks in hole at 4614'. 14. Coring resume and brief description 15. Logs run and depth where run 1 6. DST data, perforating data, shows of H2S, miscellaneous data Flow tested interval 4082'-4104'; 4110'-4126'; 4185'-4205'. Tested 1.8 mef at 1360 psi through 1/4" choke; 3.5 mcf at 1280 psi and 3/8" choke; 5.5 mcf at 1000 psi and 1/2" choke. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,-~~ Area Operations Supt ~ ..,~-~_~/ SIGNEE[."'~I',~'~_/° ? / /~~ TITLE ...... r~ DATE NOTE--Report on this form is req~d for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commis~on by the 15th of the succeeding month, unless otherwise directed. Form 10~04 Submit in duplicate Rev. 7-1-80 TUBING RECORD SIZE 3 1/2" O.D. 9.2#/Ft 2 3/8" O.D. 4.7#/Ft DEPTH SET 4456.33' 2030.99' PACKER SET 4435.31 4284.57 4021.36 CEMENT SQUEEZE DEPTH MATERIAL 6796' 4930' 4798' 4650' 46~1' - 4645' 4590' 4395' 4380' - 4390' 4284' 3992' 4327' - 4334' 4520' 6530' - 6547' 100 Sx Class G 250 Sx " 150 Sx " 125 Sx " 184 Sx " 150 Sx " 150 Sx " 250 Sx " 150 Sx " 150 Sx " 150 Sx " 184 Sx " 1 O0 Sx " '"'c~Ora~o' ~'oro,-o/smbo May 12, 1981 Mr. T. L. Perry~an Area Operations Superintendent Chevron USA, Inc. P. O. Box 7-839 ~ Anchorage, Alaska 995~0 Re~ Beluga River Unit Well BRU 214-35 Dear Mr. Per~man~ Our ~ta are incomplete on the subject well. We have no record of having received a 5k)nthly Re~rt of Drilling Operations and Workover Operations (Form 10-484) for the month of March, which was due April 15. Available information indicates the well was complete4 as a gas well on March 7, in which case a Well Comple- tion or Recompletton Report and Lq (Form 10-407) was due April 6. Please sen~ over the appropriate forms in duplicate at your earliest convenience, or copies of these forms if they were sent previously. Sincerely yours, A. I~vorsen Petroleum ~ologist STATE Or: ALASKA ~ CLASSIFIED ALASK/~ ..... !L AND GAS CONSERVATIONC_( 1MISSION MONTHLY REI ORTgF DI=IILLII IO ANg WOR OV -R OI ERATION$ ' Drilling well ~ ~ ~ :2. Name of operator 7. Permit No. CHEVRON U.S.A. INC. 80-72 3. Address 8. APl Number P. O. Box 7-839 Anchorage, Alaska 99510 50- 283-20067 4. Location of Well at surface From the Southeast Corner, Section 34, 1177' North and 896' West in T13N,'RIOW, S. M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. I ADL-175~ For the Month.of February 9. Unit or Lease Name Be]uqa River Unit 10, Well No. BRU214-35 1 1. Field and Pool Beluga River Field Sterling & Beluga Pools ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 6819' - plugged back to 4614' - shot 4 JHPF and squeezed for segregation zones @ 4650', 4590', 4395', 4284' and 3992'. w/150 sx of class "G" cement each. 'set retainers @ 5935', 5799I, 5341', 4850'"'~a. od 4520 each w/35 sx of cement on top. Drilled out retainer @ 4520 and squeezed w/184 sx of class "G" cement squeezed holes @ 4380-90 w/250 sx class "C'l cement. Laid cement plug for 4614' to 4714', " squeezed holes @ 4327-34 w/150 sx class "C" cement. 13. Casing or liner run and quantities of cement, results of pressure tests Ran and landed 150 jts 3 1/2 9.2#/ft and 65 jts 2 3/8" 4.7#/ft produCtion tubing. Installed 2nd tested tree to 3000 psi. R.I.H. w/wireline perforating gunsZperforated for 4484-4504. Lost perforating guns in hole. R.I.H. w/wire- line pressure recorders and 72 hr. clocks. Lost inhole. Alaska 0il &Anc.hOracj.~Gas Oor~s Cot~miSsio~ 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data · 6008-6026' - medium blow to dead thur 1/4" choke/5870-5861 med. blow to dead thur 1/2" choke/5408-18 faint blow to dead thur 1/2" choke/5177-82 light tweak blow thur 3/8" choke/4684-4700 med to light thu 3/8" choke/4631-45 med to light blow thur 1/2" choke/4380-90' reed to strong blow to dead thur 1/2" choke 4327-34 weak to dead thur 3/8" choke. Ran production test for interval at 4484-4504 thur 32/64", 28/64" and 24/64" chokes ¢_ 7.7, 7.5, 6.6 HHCFD respectively. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNE LEh of status of operations, and must be filed in duplicate with the Alaska NOTE--Report on this form is req~ed for each calenda ont , regardless the Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Submit in duplicate Form 10404 . Rev. 7-1-80 ' ' STATE OF ALASKA · CLASS IF'lED ALASK( ~IL AND GAS CONSERVATION 0("~' ~IMISSION MONTHLY REPORT DRILLING AND WORK:OVER OPERATIONS · Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. CHEVRON U.S.A. INC. 80-72 3. Address 8. APl Number P. O. Box 7-839 Anchorage, Alaska 99510 50_283-20067 4. Location of Well at surface From the Southeast Corner, Section 34, 1177' North and 896I West in T13N, RIOW, S. M. 9. Unit or Lease Name Beluga River Unit 10. Well No. BRU214-35 · 1 1. Fiel~l and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. I ADL- 17599 _ For the Month of January Beluga River Fi eld Sterling & Beluga Pools · 1981 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks , 6819' drilled depth, 5498' footage drilled. Fished for 17 1/2" H.0. bull nose. No recovery. Cemented w/plug and drilled around. In 17 1/2" hole had trouble orienting too face. Drilled 12 1/4" fr 2725' to 3938' directionally and opened up to 17 1/2" hole. Spud date 12/24/80. 13. Casing or liner run and quantities of cement, results of pressure tests Ran 101 jts. of 13 3/8, 6.8#/ft., K-55, Buttress set @ 393~)' - cemented w/llO0 sx of ciass IIGll mixed w/2.4% gel. Ran 162 jts of 9 5/8I', 47#, 43.5#, 40#, 43.5#, N-80, Buttress. Cemented w/618 sx class I'G" w/.O1% HR6-L. Stage. Job j324 sx of class "G'l w/.Ol% HR6-L. $_queeze EZSV Retainer @6496' cemented w/20 1/2 bbls of class "G" to perforations ~ 6530' ' 6547' w/2500 psi. Squeeze: 4930' w/250 sx class "G" @ 1825 psi 4798' w/150 sx class "G" @ 2300 psi 15. Logs run and depth where run RECEIVED FEB 1 0 1981 Alaska 0il & Gas Cons. AnGhorage Logged w/D.I.L., Long Space Sonic, FDC/CNL and Sonic fr 410' to 3960' Logged w/Long Space Sonic, dipmeter, BHC sonic,.EDC/CNL fr 3930' to 6022' Logged w/D.I.L., Sonic, FDC/CNL fr 5800' to 6820' .Logged w/CBL fr 6730"to 3400' 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perforated w/4 - 1/2'l jhpf fr 6530' - 6547' - Set RTTS @ 6503' -opened tool for IF thur 1/4" choke for 10' mins - ISl 64 mins - opened tool for second flow period medium blow- to dead in 1 hr. 46 min. FSI 4 hr 8 min - Reversed out 17. I hereby certify that the fore~s true and correct to the best of my knowledge. T. L. P~ryp~in/ _ Area Operations - A~ .~Z~/~//_--~ ' A ~'~ Superintendent ' February 6, 1981 NOTE~-Report on this form is req~uuired fo~ each calendar month regardless of the status of operations, and must be flied in duplicate with 'the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev. 7~1-80 Submit in duplicate January 19, 1981 Mr. T. L. Perryman Area Operations Superintendent Chevron U.S.A. Inc. P. O. Box 7-839 Anchorage, Alaska 99510 Dear Mr. Perryman: The recent MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS forms that you submitted for well BRU 214-35 are old outdated forms. These outdated forms will be accepted this time, however in the future only new current forms will be accepted. Some copies of the new forms are attached. Additional forms are available at our office or they can be mailed to you on request at no charge. Sincerely, Harry ~. Kugler Commi s s i one r Enclosure MWK:be Form ~o. P---4 l~"d*. $- I-?0 STATE OIL AND GAS CONSERVATION CO/~AI'i-rEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUI~MIT n',,l' IDtJPLICATm- · ,PI NUTVIERICAJ.., CODE 50-283-20067 6 LF~SE DF, SIGI~A~'FION AND SERIAL NO. ADL-17599 1. ? IF INDIAN, ALOTIE~ OR TRIBE NA~IE 0IL O GAS ~] WSLL W~LL OT~R ~. NA2~IE OF OPIgi~ATOR CHEVRON U.S.A. INC. 3. ADDRESS OF OP]gl:~ATOR P. O. Box 77839 Anchorage~ AK ~9~10 4.LOCATION OF WI~-T,L From the Southeast Corner, Section 34, 896' West in T13N, R10W S.M. 11771 North and 8. L~IT F.~dRA{ OR LEASE Beluga River Unit 9. WELL NO BRU 214-35 10. FIELD AND POOL. OR %VILDCAT Sterl i ng ~ Beluga River Field - Beluqa 1~. S~-C., T., R., ~.. (BO'~O~ HO]-~ Poo 1 s o~ Sec. 35, T13N, RIOW S.M. 12. PERMIT NO. 80-72 13. REPORT TOTAL DEPTH AT END OF MONTH,, CHA.XGF~ IN HOLE SIZE. CASING AND CEiViENTING JOBS INCLUDING DEPTH SET A~-D VOLI/MES USED, PERFORATIONS, TF, STS A2%rD !q~ESULTS. FISHING JOBS. JU/~K LN HOLE AND SIDE-TIq3~CKED HOLE ASqD A.NY OTI-EElrt SIGNIFICANT CI-La~'qG~V-~ IN HOI~ CONDITIONS. December. 1980 Summa ry December 24. Rigging up. Spud 6:00 p.m. December 24, 1980. Drill ahead I in 17 1/2" hole to 101, using a gel-water spud mud at 78 pct. December 25-27 Drilled from 1011 to 420' in 17 1/2" .hole. Opened from 97' to 420' to 26." Ran 10 its 20)" 94// H-40 Buttress casing to 410'. Ceme.nted 20" casing with 490 sacks Class "G" cement, premixed with 2.4% Gel by weight of water. Good return throughout with cement to surface. WOC. December 28-29 Cut off :~0" casing. Install and test 20"-2000 psi. Class lIB BOPE. Drill out cement from 3891 to 410'. Clean out to 420.' Drilled 17 1/2" hole to 460'. December 30-31 Directionally drill ahead 'in 17 1/2'l hole from 4601 to 1179' at month end with 71 pcf Gel-ligno mud. RECEIVED JAN 1 9 1981 Alaska Oil & Gas Cons. Commission Anchorage ~-, . CONF I DENT I'AL 14. I hereby certify tl~a~ t the,d~regJ~g !~/true mad correct J · , ~/" I,_ gl{RRYIVt, A~ ARF..A NPI~.RATTN'M.q qTT'P'I~T~T'T'I~I~T'hlq"I~TT NOTE ~Report on this form is required for each calendar month~ regardless of the etotus of operations, and must be filed in duplicate witl~ the oil and gas conlervotion commiffee byfhe 15lb of the succeeding month.unless otherwiee directed. July 17, 1980 Mr. C. F. Kirkvold Area Operations Superintendent Chevron U.S.A. Inc. P. O. Box 7-839 Anchorage, Alaska 99510 Re~ Beluga River Unit BRU 214-35 Chevron U.S.A. Inc. Sur. Loc.~ 1210tN, .931~W of S~ cor Sec. 34, T13N, R10W, SM. Bottondlole Loc.= 50tN, 1180~E of SW cot Sec. 35, T13N, R10W, Dear Mr. Kirkvold = Enclosed is the approved application for permit to drill the above referenced we11. Well samples, core chips and a mud log are re~uired. A directional survey is required. If available, a tape contain- ing the digitized log information on all logs shall be sub- mitred for copying except experimental logs, velocity surveys and dtpmeter surveys. ~any riyers in Alaska and their drainage systems have been classified as important for the spawning or. migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code}. Prior to commencing operations you may be contacted by the Habitat Coordinator~s office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter ~, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended- Prior to Mr. C. F. Kirkvold -2- Beluga River Unit BRU 214-35 July 17, 1980 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface.casing shoe is drilled. In the' event of' suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, · H. Hamilton Chairman of BY ORO~'R OF TH~- CO~ISSION Alaska Oil & Gas Conservation Commission Enclosure cc: De.par~ent of Fish & Game, Habitat Section w/o eno1. Department of Environmental Conservation w/o/enc1. Department of Labor; Supervisor, Labor Law Compliance DiViSion w/o eno1. Form 10-401 REV. 9-1-78 SUBMIT IN TR TE (Other instruct ~, ,n reverse side,, STATE OF ALASKA E PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL b. TYPE OF WELL OIL GAS WELL [~] WELL OTHER DEEPEN 2. NAME OF OPERATOR CHEVRON U.S.A. INC. 3. ~DRESS OF OPERATOR P. O. BOX 7-839, ANCHORAGE, ALASKA 99510 4. LOCATIONOFWELL Atsur~ce Approximately 1210' North and 931' West from Southeast Corner of Section 34, T13N, R10W,S.M. Atpropo~d~ depth: Approximately 50' North and 1180' East from Southwest Cor. of Sec. 35, T13N, R10W, S.M. aPI #50-283-20067 $. 6. LEASE DESIGNATION AND SERIAL NO. ADL-17599 7. IF INDIAN, ALLOTTEE OR TRIBE NAME ..~.U.NIT FARM OR LEASE NAME BELUGA RIVER UNIT 9. WELL NO. BRU 214-35 10. FIELD AND POOL, OR WILDCAT BELUGA RIVER FIELD gTERT,TNG & BELUGA POOLS 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) SECTION 35, T13N, R10W,S.F. 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. Approximately 40 miles West of Anchorage, Alaska 1~. BOND INFORMATION: TY~ENationwides~retyand/orNo. U89-75-81-34 A~ount $150,000 15, DISTANCE FROM PROPOSED * + 4000' from bottom LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. -- h o 1 e t o un i t (Also to nearest drig, unit, it' any) ' bound ary 18. DISTANCE FROMPROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT.1 Ge arion + 3700'to BRUfr°m 21b~t ~m_ 16. No. OF ACRES IN LEASE A-029656 - 845.08 A~. ADL-17599 - 818.03 Ac. 19. PROPOSED DE~H 6000' 17. NO.ACRES ASSIGNED TO THIS WELL 640 Ac. 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WILL START Estimated ground level 35' July 15, 1980 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING ~IGHT PER FOOT GRADE SETTING DE~H ~antity of cement 30" 30" 1" Wall 80' 26" 20" 94# H-40' 400' 450~Sx Class G w/ 2.4% Gel in Wa 17%" 13-3/8" 68# & 72# K-55 3925' 1800 Sx Class G w/ 214% Gel in Wa 12~" 9-5/8" 43.5# & 40.C N-80 6000' 880 Sx Class G Water Water Drilling Program attached. NOTE: We request all information pertaining to the drilling of this well to be held CONFIDENTIAL and haVe limited access. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen dixectionally, give pertinent data on subdurface locations and measured and true vertical depth~;ive blowout preventer p~ggram' SIGNED24' I hereby certify t~ f , ~~~~~~_ _ Area Operat ions DA E June 26 1980 C. F. Kirkw~zu T, ; TITLE Superintendent (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUIRED MUD LOG OTHER REQUIREMENTS: g YES [] NO ~ YES [] NO DIRECTIONAL SURVEY REQUIRED A.P.I. NUMERICAL CODE ~YES [] NO 50-283-20067 8U-72 PERMIT NO..~/' '~~~~~ ~t/~ ~$~ ~- APPROVAL DATE APPROVED BY TITLE (~laJ.~ ~:' O~ ~ THE CO~MISSIO~e Instruction On Reverse Side July 17, 1980 DATE 07/17/80 PR SAI, ?'OR WEI,L O}'ERATIONS PRO 31,,. i DRILI, ING PRO(;RAH Field: Beluga River Property and Well No.: Beluga River Unit 214-35 Security Classification: CONFIDENTIAL Surface Location: Approximately 1210' N. and 931' W.'of the Soutlteast Corner of Section 34, T. 13 N., R. 10 W., SB&M. ,. Bottom Itole Location: Approximately 50' North and 1180' East of tile Southwest C~rner of Section 35, T. 13 N., R. 10 W., SB&M. Elevation: Estimated 35' Ground and 50' K.B. Bfowout Prevent ion Considerations 1. Potential Problems: a, Oas: APF~OvED PP, OG RAM C, ~'4. S,."~..~r~,qr The proposed well is a step out location on th'~ southeast fiank of a knotm gas field. Numerous gas sands are expected to be penetrated during the course of drilling this well to total depth. Gas entries into tl~e mud co].umn ca~ cause serious preblems. Care .must be taken at all t.{mes to prevent tt~ese entries caused by either swabbing t}~e well wtmn pulling pipe to hydraulicing the formation, with associated .lost circulation, on trips. Rapid penetration rates cause an increase in mud weight and incl-ease the risk of lost circulation and subseqtmnt kicks. Penetration rates will. be restricted. Coal beds at Beluga can cause serious problems. The beds contain some gas, s].oUg}~ readily, and drill rapidly. If tl~ick beds are encountered, reduce the penetration rate and/or circulate bottOms up. b. Lost Circulation and Water l';~t'rics: In well BRU 212-24 circulation was lost using, 70 pcf m~d while t:he drill, pii,e was stuck at 927'. Frown this deptl~ to 377/' some loss in mud was noted. Mud weights varied from 70-75 pcf. No seri. Ot~s losses were recorded, but extreme care must be used in maintaining solids free mud wi. tl~ t:l~e l~ropert.ics outlf~cd in the Drilling FJt, Jd~; Pro;~ram. Penetration rates will. be limited to maintaining optimum drilling fluid propert, tes. Ki. ckn should be l~a,dled by ot.r nonn,ql l~rc, ccdures. Drilling cri.,t.:,; should be made aware of tl~csc m,,tl~ods. C~'e sl~ould i~e excreta;cd at ali times by every member of tile crew. Tl~e ltole must be kel,t full nt a].l t tree s. Proposal for Well Operations PRO 316-I Drilling Progr a~m 2. Estimated Dcp,.t,hs and Format[on Pressures: Measured Vertical Est. Press. Gradient Zone or Marker .. Depth Depth Psi Psi/?'t. Top Sterling "A" "A2'' Harker Top Beluga Formation Top "Fl" Total Depth 3905' 3200' 1510 . 47 3958' 321~5 ' 1535 . 47 4550' 3765 ' 1800 · 48 5327' 4525' 2170 .48 6000' 5197' 2625 .49 3. Maximum Anticipated Surface Pressure: 4. Blowout Prevention E~,uipmcnt: a~ 20" - 2000 ps~, Class lib on 20" casing. 12" - 3000 psi, Class III on the 13 3/8". 10" - 3000 psi, Class III on 9 5/8" casing. Based on gas column to surface, 2380 psi. PROGRAM C. r,l 5. .Objectives: Sterling and Beluga Formations. Proposal for Well Up ~ gions PRO 316-1 Drilling Program Drilling Program: BRU 214-35, Beluga River Field ?~i~?:~': ~ii~ i~i~ ~'.:~!~ iA~.~ 1. Drive 30" conductor pipe to approximately 80' below the ceii~C~ floor. 2. Drill for 20" casing to 400'±. Maintain drilling fluids per attached Drilling Fluids Program. 3. Cement 20", 94#/ft, H-40 Buttress casing at effective depth witl~ s~'ff~cient Class G cement premixed with 2.4% Ge], by weight of water, to rcacl~ the surface. If no Cement returns to surface, recement through 1" pipe hung at 90'. Use a duplex shoe with stab-in-connector. Note: Yields: 1.86 cu. ft. slurry per sack cement Water required: 1.38 cu. ft. per sack cement Gel required: 1.5# per cu. ft. water Slurry weight: 97-98 pcf. Properties of Class G cement premixed with 2.4% Gel, by weight water: (.' 4. Install 20"-2000 psi slip-on Gray Too]. Company casing head. Install Class IIB BOI'E per attached sl~eet. Nipple up blow and kill lines, and manifold for 3000' psi service. A Class III 12"-3000 psi BOPE will bc installed later. Test BOPE to 1500 psi and casing to 400 psi. O~1 & Gas Conservation Commission to witness test. 5. Drill out cement and shoe of 20" casing. Directtonally drill' 17-1/2" hole, per attached plat~ to a depth equivalent to 3050' in well BRU 241 34, now estimated at 3925'. On a course of S61°E, starting at 450', build angle 3° per i00' to 45°. near 1950'. Hold 45° .to near 3640'. Drop angle 2-1/2° per 100' to 2-1/2° near 5320'. Hold 2-1/2° to a total depth of 6000'. Note: a. L~mit penetration rates as necessary to maintain optimum drilling fluid weight and solids content. b. Instal]. biud Loggers at: the shoe of the 20" casi. ng. Maintain to tot'a], dcptl~. Detailed instruction included Jn the attached Formation Evaluation Program. 6. lh,n logs per Formation Evaluation Program from effective deptl~ to sl~oc of 20" casing. 7. l)rilJ at,cad ]~ 17-l/2" hole, ]f n(~c(,:-;s;iry, to appro>:itn:~tely 15' b~,l~,w the i, ,, ) [ · top of tl~e A Sterling Sand, a depth equivalent to 3(~0' in BRU 241-34 Repeat logs if necessary. · 8. Cement 13-3/8", 68#/ft. K-55 Buttress cas[T~g in the st~ale section lmmedi ately below tl~e "A" St'(,rllng Sa,~d witl~ sufficient C]oss G cement l)t'cm~xed witl~ 2.4% Col, by'w,..igl~t of water, to reacl~ t:l~e surface, l.f ceme~t does n~t re;~cl~ surface, do a top jr,b t:hrougl~ a 1" ptl,e h,~ng at 90'5. U:~e a float sl~oe and d~plex collar witl~ stab-in connector. Proposal for Well Ope 1ohs PRO 316-1 Drilling Program 9. Cut off 13-3/8" casing to all. ow top of tubing head to be above ground level upon completion. Install 13-3/8" SOW casing l~ead. Install 12"-3OO0 psi Class III BOPE per attachment and test system to 3000 psi and casing to 2500 psi. Oil and Gas Conservation Commission to wt. tness tests. 10. Drill out cement to within 10' of float shoe. Run Variable l)ensity CBL from effective depth to the 20" casing shoe. blake shut olT te:;ts as required. 11. Drill out cement and shoe and directionally drill ahead, in 12-1/4""hole to a total depth of 6000'. Note: Limit penetration rates to maintain optimum drilling fluid weight and solids content. Circulate out drilling breaks or reduce penetration rate as directed by Chevron Drilling Representative. 12. Run logs per attached Formation Evaluation Program from effective depth to shoe of 13-3/8" casing. 13. Cement approximately 6000' of 9-5/8", 43.5 and 40# N-80 Buttress casing on · bottom in two stages as follows: a. Use f]ot shoe and float collar. Run one stage collar and place the base of the Ster].ing sand estimated to be 4550'. Bakerlock the bottom two casing Cement the 9-5/8" casing in two stages as follows: . 1) Stage 1 through the shoe using 410 sacks Class G cement. Use excess. Fill calculated from 6000' to 4550'. Ca].culate volume from caliper. 2) Stage 2 through stage collar near 4550' with 470 sacks Class G cement. Fill calculated to the. 13-3/8" shoe plus 1000' into the 13-3/8" x 9-5/8" casing annulus and includes 25% excess cement on the open hole portion. 14. I.and tlle 9-5/8" casing. Install 12" - 3000 psi x 10" - 3000 psi tubing head and second~ry seal assembly. Test secondary seal. to 3000 psi. Install 10" - 3000 psi Class II.I~ BOt'E per attachment. Test BOI'E system t.(~ 3000 ps i. 15. Drill. o~t cement at stage col.].ar and clean out to top of float collar. Run V;~riable DensJ. ty Cement Bond l,og from effec, t~.ve depth to sl~oe of 13-3/8" casing, l~st:ablisl~ segregation p.o[nts as required by squeeze cementing. Segrt,.gation points Lo be provided after log lnterl,retatton. 16. Test, perfov;~tlnl;, and completi, on program will be l~rovlded after tho total deptlt logs l~nve been run. W. D. BAUER DRII,I,1. NC F[.UII)I'ROCRAlq Bi';I,UCA P, IVEI/ 314-35 BEI,UGA RI VER I"I F. LI) Basic System Lightly treated Lignosulfonate mud. Optimum Properties Value To 13-3/8" Csg. Point 13-3/8" Csg. Pt. to T.D. Weight, pcf Viscosity, sec/qt., AP1 Flutd loss, cc, AP1 Plastic Viscosity, CPS Yield Point, lb./lO0 ft.2 Gel, lb./100 ft.2-10 min. pH Solids Content, % volume Diesel Oil, % Remark s: .Chemically disperse mud with lignosulfonate. 73-76 76-80 40-200 40-45 - I.ess than 8 - 15-25 - 8-15 - lO Hax. - 8.5-10.0 - 10-18 - 4-7 AFFgOV[.D Maintain adequate supply of lost circulation material and barite at the loca t ion. ' Run desander and desilter to keep solids at a minimum while drilling. Increase viscosity while drilling surface hole as required to control gravel. -o APPROVE[., PROGRAM C. t,J. S-"' ," ", r, Item Approve Date Yes (1) Fee ~-c,J~i. ~-/~,~-i)~ 1. Is the permit fee attached .......................................... __ ~ 2. Is well to be located in a defined pool ............................. ( 3 ) k]min. ~Q~/~: No 3. Is a registered survey plat attached ................................ 4. Is well located proper distance frcm property line .................. 5. Is well located proper distance frcm other wells .................... 6. Is sufficient undedicated acreage available in this pool ............ 7. Is well to be deviated .............................................. 8. Is operator the only affected party ................................. ~ .... 9. Can permit be approved before ten-day wait .......................... ¢~_ __ ! 10. Does operator have a bond in force .................................. 11. Is a conservation order needed ...... '~. ......... "~...',, ..... .. .... .-~ .... 12. Is administrative approval, needed ................................... 13. Is conductor string provided ............. Lease & Well No. ~/~ Remarks (4) Casg. ?- 2 14. Is enough cement used to circulate on conductor and surface ......... 15. Will cement tie in sUrface and intermediate or production strings . .. 16. Will cement cover all known productive horizons ..................... 17. Will surface casing protect fresh water zones ....................... ~ 18. Will all casing give adequate safety in collapse, tension and burst. (5) BOPE ~/~ -- Additional Requirements: 19. Does BOPE have sufficient pressure rating - Test to 3~o0 Approval Reccmmended: ,Geology: Engin~qring: JAL~ rev: 03/05/80