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175-034
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS /4� 1. Operations Abandon LJ Plug Perforations L1 Fracture Stimulate Ll Pull Tubing 7 Operations Shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Fish 2 SL Tools, CTCO, N2 Q 2. Operator 4. Well Class Before Work: Hilcorp Alaska, LLC 5. Permit to Drill Number: Name: Development Q Exploratory ❑ 175-034 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, Stratigraphic❑ Service 1:16. API Number: AK 99503 50-283-20049-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0058820 / Beluga River Unit (BRIJ) 212-18 /moi 5 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 71 N/A 5 C Beluga River/ Undefined Gas ? 11. Present Well Condition Summary: , Total Depth measured 7000 feet Plugs measured 5880 & 6422 feet true vertical 6998 feet Junk measured 87 & 377 feet Effective Depth measured 5580 feet Packer measured 4975, 4820 feet true vertical 5579 feet true vertical 4975, 4820 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 54' 30" 54' .4/_ I Z5 54' D'- Surface 411' 20" 411' 411' 1,530psi 520psi Intermediate 3,376' 10-3/4" 3,376' 3,376' 3,130psi 1,580psi Production 6,509' 7" 6,509' 6,509' 7,530psi 5,650psi Liner Perforation depth Measured depth See Attached Schematic ei,.1 True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / N-80 4,521' MD 4,521' TVD Packers and SSSV (type, measured and true vertical depth) 2 Bkr PH Pkrs; N/A 4075 & 4820 MD 4075 & 4820 TVD N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 00 0 355 1020 Subsequent to operation: 0 0 0 357 1100 14. Attachments (required per 20 AAC 25.070, 25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas L��J 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: 319-269 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(a�hilcom com fA� �Y �Sf2. f / Authorized Signature: ar v; A Date: oI ✓), o//q Contact Phone: 777-8420 Form Form 10-404 Revised 4/2017'! f1 � "' Z 'BDMS SEP 2 3 2019 Submit Original Only 10 - Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 212-18 CTU 1 50-283-20049-00-00 1 175-034 6/17/19 1 8/23/19 Daily Operations: 06/17/2019 - Monday PJSM. PTW. MIRU SLB CTU 13 with 1.75" CT. Start BOPE test. Test all rams and valves 250/4,000 psi. 24 hr BOPE test witness notification sent to state on 6/16/19 @ 15:14 hrs. AOGCC's Jim Regg waived witness via email on 6/17/19 @ 10:11 hrs.. Transfer N2 from tanker to pump truck. Location walk around complete. SDFN. 06/18/2019 -Tuesday Obtain PTW. Hold PJSM with crews. Fire equipment. Pick injector head. Stab 32' of lubricator. Make up Fishing BHA. CC, DFCV, Jars, Disconnect, Motor, x over to series 10 overshot, overshot. Perform maintenance on unit while awaiting flight for 1.75" Grapple insert for seires 10 over shot. Install 1.75" grapple. Stab on well. PT stack 250/4,000 psi. Open well. Input coil depth of 21' . Coil zero to tubing hanger. RIH. Tag TOF @ 131' CTMD. Pick up 4k overpull. Latched up to fish. Work tool string up and down to set grapple teeth. Work tools up . Perform 10 up jar licks. Jars are hitting before max overpull of 25k achieved. Jars firing at 3k over. Slack off and perform 10 down jar lick attempts. Not able to see jars. Worked up to 26k over pull and fishing tools and fish disconnected. POOH to surface and inspect. Pop off well. pulled guts out of series 10 overshot. Overshot barrel egged. Missing overshot guide, control and 1.75" grapple. Drive to slick line unit and remove core from 2" JDC overshot (not able to release). Make up to bait sub (GS spear). Make GS spear up to end of jars. Stab on well. PT stack. RIH attempt to latch. No luck latching. POOH. Swap baited JDC and GS out for 2.31" LIB. RIH and set 10k down on fish at 131'. POOH to surface. LIB has small chunk of overshot grapple stuck inside lead. Also shows rope socket with braided line still attached. Break down BHA. Stack down lubricator and set injector on back deck. Install night cap on BODE. Location walk around complete. Location secure. 06/19/2019- Wednesday Obtain PTW. Hold safety meeting. Fire equipment. Pick Injector head. Stab 40' of lubricator. Make up Fishing BHA. CC, DFCV, accelerator, 2x weight bar, Haley jars, Disconnect, Motor, 2 x overs, 2.23 Rare earth magnet. Stab on well. PT stack 250/4,000 psi. RIH 0 psi whip. Tag top of fish @ 131' CTMD. Pop off well. Recovered 3 pieces of metal (grapple chunks). Stab on well. RIH same magnet to 131' POOH to surface. No metal chunks. Break off magent. Make up 2.23" concave mill. Stab on well. Pt stack 250/4,000 psi. Rlh and dry tag TOF @ 131' CTMD. Pick up and come online down CT at 1 bbl/min 2,150 psi circ pressure. Tag fish while milling 3 times. POOH to surface. RIH with 2.25" magnet 3 times. to 131'. First magnet run 4 good metal chunks from grapple. Make up Mill. RIH dress top of fish at 131'. POOH to surface. RIH with 2.2" LIB to 131'. Set down 5k . POOH to surface. Good clean rope socket impression. Make up baited (GS) JDC gutted. Not able to shear slick line JDC down or up. Stab on well. PT stack. RIH and latch up to fish at 131' CTMD. Attempting up jar licks. Slick line jars and CTjars both going off. Jars are going off to early and firing at 4-6k over pulls. Should be able to getjar licks at 25-30K over pulls. Call Weatherford and send 2.125" jars to Otter hanger. Stack 15k down not seeing down jar licks. While stacking weight close choke and line up down back side. Pressure up tubing to 2500 psi. Fish not moving. Bleed down pressure. Continue to work fish. Released from fish. POOH to surface. Close master and swab. Pop off well. Inspect JDC overshot. Latch dogs are rolled. Break down BHA. Cut 50' of coil. Make up new external slip coil connector. SDFN. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig AN Number Well Permit Number Start Date End Date BRU 212-18CTU 50-283-20049-00-00 175-034 6/17/19 1 8/23/19 Daily Operations: 06/20/2019 - Thursday PTW. ISA. Location walk around complete. Fire equipment. Pick injector head. Stab 40' of lubricator. Make up new external slip coil connector pull test 35k. Make up BHA w/ overshot. Stab on well. Pt stack 250/4,000 psi. Open well RIH. Tag with 2.375" coil connector at hanger top. 2-7/8" tubing with 2.441" ID will not pass 2.375" coil connector. POOH to surface. Break down BHA. Cut off coil connector. Re head with slim dimple connector. Pull test 35k. Make up fishing BHA. Weatherford Jars on location. Make up fishing BHA and series 10 overshot. Stab on well. PT stack. RIH. Tag TOF at 131'. Not able to latch. -16k jar licks. Continue to work jar. No luck latching. POOH to surface. Small marks on bottom of overshot guide. Break off overshot. Mu 2.23" rare earth magnet. RIH. Tag at 131'. POOH to surface. magnet clean. Make up Venturi junk basket. RIH and pump 30 bbls at 3,542 psi. POOH to suface. No trash in junk basket. Make up 2.3" magnet. RIH. Tag TOF at 131'. POOH magnet full. Chunks of series 10 1.75" grapple. Braided line attached. Make up Junk basket. RIH Pump 10 bbls. POOH to surface. Small chunk of metal in basket fingers. Mu 2.3 magnet. RIH. Tag TOF at 131'. POOH to surface. no debris on magent. Make up series 10 overshot and 2' extension loaded with 1.75" grapple. Latched up to fish. Work fish and jar up at 15-20K over pull. Jar down 10k down jar licks. 30 jar licks total. After 30th jar lick over pull to 80% 34K. Weight broke off. Heard noise in ops cab. POOH to surface. coil pulled off coil connector. Call tool companies to modify overshot, coil will return to well once all fishing tools arrive. Rig back injector head. Rig down CTU unit. Fish/BHA left in hole. Internal Dimple connector 1.508"x 3.971" slick fish neck. 2.13" DFCV, 2.25" Hailey Intensifier, 2x 2.13" weight bar, WTF Bi -Di jar, 2.13" Disconnect with 9/16" Ball, 2.5" TTS spear, 2.5" Bait sub, 2.13" x over, 2.33" Logan overshot with 1.75" grapple. (quadco). Total BHA length 30.79'. 08/18/2019 -Sunday PTW. JSA. Rlg up SLB CTU 13, spot supply and return tanks. Swap from 1.75" to 2.0" CT. Install BOPE on well. Stab 2" pipe into injector head. Ready for BOPE test in the AM. 08/19/2019 - Monday PJSM, PTW. Start BOPE test. Test all rams and valves 250/3,000 psi. 24 hr BOPE test witness notification sent 8/18/19 @ 11:20 am. Witness waived by Jim Regg 8/19/19 @ 0944 hrs. BOPE test complete. Pick injector head. Stab 3x 11' lubricators. Make up Fishing BHA. 2.125" OD on all. CC, DFCV, 2x weight bars, BiDi jars, Hydraulic disconnect 1/2" ball, Modified series 10 overshot. (MHA pressure tested 250/3,000 psi. Pull tested coil connector 50k). Stab on well. PT stack 250/4.000 psi. Bleed down. Open master and swab 17 turns. Initial WHP 80 psi. RIH and stack down on fish at 80'. Pick up. Fish latched. Slack off 10k down on fish. Online down CT 1.3 bbls/min 1856 psi PU fish free. POOH to surface. Close swab. Pop off well and break down coil BHA assembly. Hot work permit. Weld coil connector. RIH with 2" Hydraulic GS spear. Latch up to fish at 108'. Pick up and let jars fire. Straight pull to 40K. Fish moving . At surface. First fish recovered 1 3/4" Slick line fishing assembly. Rope socket, accelerator, jars, Spangs, weight bar x 2. Heavy duty JDC overshot. Overshot missing half of skirt. Call pollard to deliver LIB and Rare earth magnets to hanger. Break down fishing BHA. stack down lubricator and injector head. Secure well with night cap. SDFN . Location walk around complete. Hilcorp Alaska, LLC Well Operations Summary Well Name —FRU Rig API Number Well Permit Number Start Date End Date 212-18 CTU 50-283-20049-00-00 1 175-034 6/17/19 8/23/19 Daily Operations: 08/20/2019 -Tuesday PTW, JSA. Fire equipment. Pick injector head. Stab 33' of lubricator. Make up Fishing BHA to existing coil connector with weld. Fishing tools all 2.125" OD. DFCV, Accelerator, weight bar, WTFjars, Disconnect, and Hydraulic release JDC overshot for- 3/8" fish neck. Open well. 230 psi WHP. RIH stack down 5k on fish @ 140.2'. Pick up clean no latch. Continue to attempt latch. Online down CT at 1.5 bbls/min to wash around fish neck. Set down 3k on fish. Shut down pump. Small down jar lick. Pick up clean. Unable to latch rope socket. POOH to surface. Hydraulic JDC overshot had 2 of 3 dog arms damaged and flared out/bent outside of overshot body. Remove JDC overshot and install 2.25" rare earth magnet. RIH with magnet. Stack down at 140.2'. POOH to surface. Small chunk of series 10 grapple (from previous fishingjob). Run 2.25" magnet again. POOH to surface. Only metal shavings no large chunks. RIH with LIB. Good sign of rope socket. Break out magnet. Make up series 10 overshot. 2-5/16" OD. Dressed with 1.5" grapple and barrel extension. RIH and stack 5k down. PU no over pull. 4 more attempts. POOH to surface and inspect tool. Damage to inside of guide. Part of slick line JDC body could be on side of rope socket. Break down BHA. Make up 2.125" motor and 2.3" mill. RIH and tag with mill at 140.6'. Stall. Pick up and continue to move fish around. 5 heavy stalls on fish. POOH to surface. Mill marks show wear on center of bit. RIH with magnet to 140.2'. POOH to surface. 3 chunks of Slick line JDC overshot skirt. Swap back to motor and mill. RIH and tag Top of fish. Stall 3x on rope socket. POOH to surface and swap back to magnet. RIH with magnet 3 times. small chunks of metal debris. 3rd run magnet was clean. Modify broken overshot barrel from previous fishing attempt. Make a cut lip guide in hopes of dislodging debris on side of fish. RIH at work cut lip finger with motor. POOH . (spray paint in barrel indicates 9-10 inches of travel over fish. Lay down motor and mill. Make up jar and Series 10 overshot with barrel extension. 2-5/16" OD. ID of overshot 2.0" OD of Control in overshot 1.80". RIH Tag fish at 140.3'. Jar down . Pick up clean with no overpull. Continue to attempt latching while pumping and not pumping. POOH to surface. Series 10 control broke. Missing skirt from JDC overshot is 1.9" OD. Overshot cut lip guide will fit past. 2 broken controls in side 2.0" ID overshot. Controls have ID of 1.80". Rope socket fish is 1.5" OD. Broken skirt that was left on or around fish neck was 1.90" OD. Looks like controls inside overshot are breaking due to the body of the slick line JDC wrapped around 1.5" rope socket with a 1.90" OD causing control to shear. Stack down SLB CTU injector head and lubricator. Call Weatherford and have the build burn shoe for 2-7/8" tubing with 1.5" ID for rope socket. Will be delivered to hanger in AM. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 212-18 CTU 50-283-20049-00-00 175-034 1 6/17/19 1 8/23/19 Daffy Operations: 08/21/2019- Wednesday PTW, JSA. Fire equipment. Pick injector head. Stab 33' of lubricator. Make up Milling BHA. 2.125" OD. CC, DFCV, DISCO, Motor, Burn shoe. Burn shoe 2.3" OD x 1.5" ID. Open well. WHP 540 psi. RIH with burn shoe. Tag 141.5, Pick up Online down coil 1.5 bbls/min 1650 circ pressure. Stall heavy at 141.5' three separate times. Continue to Burn over 1.5" rope socket and stem. POOH to surface. Inspect burn shoe. Cut two holes 6" above shoe tip for water courses. Stab on well. PT 250/3,000 psi. RIH tag at 141.5' Back to milling. Milled with motor work to 142.1' POOH to surface. Break down motor and burn shoe. Make up 2.125" Fishing assembly. CC, DFCV, Accelerator, weight bar, BiDi Jars, Disco, Series 10 overshot dressed with 1.5" basket grapple and barrel extension. Stab on well PT stack 250/3,000 psi. Open well 0 psi. RIH and stack 5k down at 143.7', Pick up confirm latch. Start working fish. After 40k straight pull notice fish m hole. Continue jarring. 22 jar licks. over pull at 25k Weight dropped off. POOH to surface. Parted Overshot barrel extension. Series 10 overshot left in hole around slick line fish. 2.303" OD x 9" long. Call Weatherford and Pollard for more overshot parts. POOH to Coil. Rack back injector head and secure well. Night cap installed. Fuel equipment. 08/22/2019 - Thursday PTW, JSA. Pick injector head. Make up lubricator. Make up BHA motor and burn shoe. PT 250/4,000 psi. Open well 370 WHP. RIH with burn shoe to clean up fish neck. No indication of debris. POOH to surface. Break down motor and burn shoe. Make up 2.125" fishing BHA. CC, DFCV, accelerator, weight bar, Bidi jars, Hydro disconnect, Weatherford slim catch hydraulic release overshot dressed with 1.5" grapple. stack weight at 141.1'. Latched up. PUII up to 20k and slack off to -15k. Work grapple into rope socket body. Perform 15 down jar licks. close choke. Pressure climbing to 233 psi in 10 minutes. After 15 down jars licks close choke and isolate CT reel. Pump down backside and pressure up wellbore to 2500 psi while stacking 20k down. Attempting to apply force to dislodge fish. Pressure slowly bleeding down through fish-W-Uame somecommunication with below fish Pick up with pressure on wellbore. Released from over shot. Bleed down pressure to return tank. Engage fish at 141.8' Pull up and attempt up jar licks at 25k. Afterjars fire straight pull to 45k. Perform 25 jar licks with same weights. Attempt to pump off hydraulic overshot to lay in diesel and squeeze below fish. Pressure up coil to 2,500 psi and then up to 5,000 psi. Not able to release from fish. Not able to circulate through coil and fishing BHA. Overshot seems to be plugged up. Start overpulling to max 80% coil yield. 58-62K. Work coil from - 20k to 60K. PU to 62K and weight broke back. to neutral. POOH to surface. Close master and swab 17 turns. Pop off well. Slick line rope socket inside overshot. Threads pulled through. BHA is pressure locked. from check valves to overshot. Relieve pressure. Sand and grey fluid bleeding from tool string. Break down overshot and install down jet nozzle. Stab on well. PT stack 250/4,000 psi. RIH washing at 3.2 bbls/min 3,650 circ pressure. Tag at 140.3' Fish may have moved up hole 1'. Wash down and circulate 15 bbls to try and clean sand/debris from below fish. Circulate diesel down coil and up back side 5 bbis pumped. Pressure up tubing to 4000 psi. POOH to surface. Shut in master and swab. Let pressure squeeze through fish overnight. Bleed down lubricator. Pop off well and break down BHA. Set down lubricator and rack back injector head. Install night cap on BOPE. Location walkaround complete. SDFN. Remaining slick line fish in hole. All 11 OD. 5' Stem, 5' stem, 7' spangs, 2' swab cup mandral with 2 cups. 19' long. Fish is stuck at X nipple at 155'. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Per Number Start Date End Date BRU 212-18 CTU 50-283-20049-00-00 175-034 6/17/19 1 8/23/19 Daily Operations: _ .. . 08/23/2019 - Friday PTW, JSA. Fire equipment. Initial WHP 230 psi. Pick injector head. Stab 33' of lubricator make up BHA. Trimmed 100' of pipe. Install new CC and weld on. DFCV, Accelerator, weight bar, Jars, Disconnect, G spear. Baited Series 10 overshot dressed with 1.5" grapple. Stab on well. PT stack 250/4,000 psi. RIH tag top of fish 141.8' Not able to latch up. Try multiple times. POOH to surface. Ding marks on series 10 guide. Break down Jar. Install 2.125" motor with burn shoe. 2.3" OD burn shoe x 1.5" ID. PT stack 250/4000 psi. RIH tag top of fish 141.8'. Pick up and get free spin 1800 psi. RIH and see motor work start at 142.2' Burn over to 143.1' and stall motor. Repeat 3 times. Make up venturi junk basket. RIH and Circulate 5 bbls on top of fish. POOH while circulating bottoms up from 141.8'. close master swab. Pop off well. Break down venturi junk basket. Clean no metal or debris. Make up Jar and GS spear baited with series 10 overshot. Stab on well. Pt stack 250/4,000 psi. RIH tag at 141.8' Not able to latch up. Continue jar down attempts. still cannot latch slick line stem. POOH to surface. Rig down CTU 13 Swap to 1.75" coil. Remaining fish in the hole. from bottom up. 2.0' of swab cup mandrel with 2 swab cups., 7' of 1.5" OD spangs, 5' x 1.75" OD weight bar, 5'x 1.5" OD weight bar. 17" x 3.303" OD series 10 overshot barrel with 1.5" grapple, control, and guide still on tool string 15" down first stem. Location secure. ilJlcoro Alneka, L RKB to MSL = 91.5' 3 4 5 6 7 8 9 10 11 12 P1 P2 P3 CP = 19.5' ( r TOC @ 3,380' IMin Heater I.D. 1.5' SCHEMATIC Beluga River Unit Well: BRU 212-18 Last Completed: 5/7/1985 PTD: 175-034 API: 50-283-20049-00 1 Size (0 Type WT Grade Conn ID MD Btm 30" Conductor - - Welded 29" 54' 20" Surface 94# H-40 Butt 19.124" 411' 10-3/4" Intermediate 40.5# K-55 Butt 10.05" 3,376' 7" Production 23# 5-95 Hutt 6.366" 6,509' 1.9" Heater String 2.9# 111— O EUE 1.516" 2,004' Beluga Sands Bel D BelE Bel E Bel G1 Bel G2 Bel H1 Bel H2 Bel H3 Bel H4 Bell TO = 7000' TVD =6998' PBTD=6,417' ED = 5,580' ETVD = 5,579' Max Angle = 2 deg @ 1,599' ID. DepV1551.58 th (ft.) ID (in.) Description 1 P3 6,422 � 2.875 Tubing Hanger 2 4,216' .58 2.313 0 4 10/7/1975 TUBING DETAIL 2.313 Otis 55-XA Sliding Sleeve4 2-7/8" Tubing #6.5 N-80 8RD 2.441" 5,421' / Baker FH Packer6 4275.5' JEWELRY DETAIL .58 2.313 «ii Closed XA r..r;-- - Camco MMX GLM w/ DMY Valve, CEV Latch 10/12/1975M114,828 Beluga Sands Bel D BelE Bel E Bel G1 Bel G2 Bel H1 Bel H2 Bel H3 Bel H4 Bell TO = 7000' TVD =6998' PBTD=6,417' ED = 5,580' ETVD = 5,579' Max Angle = 2 deg @ 1,599' ID. DepV1551.58 th (ft.) ID (in.) Description 1 P3 6,422 .38 2.875 Tubing Hanger 2 4,216' .58 2.313 2-7/8" Otis S Nipple3 4 10/7/1975 3 2.313 Otis 55-XA Sliding Sleeve4 .04 2.31 Brown'CC'Safety Jt.5 Sleeve .68 2.875 Baker FH Packer6 4275.5' U4539.4'25' .58 2.313 Otis S Nipple7 Closed XA .02 - Camco MMX GLM w/ DMY Valve, CEV Latch 10/12/1975M114,828 1.4 2.31 Brown 'CC'Safety Jt. Beluga G1 4,960' 3.18 2.313 Otis 55-XA Sliding Sleeve '* 4 6.68 2.875 Baker FH packer 5,133' 5,238' 158 2.313 Otis 5 Nipple 4 10/3/1975 0.91 - Camco D Nipple Heater ID. Depth MD (ft.) Length (ft,) ID (in.) Description A 173 0.6 1.5 Otis N Nipple PIIIP< ID. Depth MD (ft.) ID Description P3 5,580 - Howco EZ Drill Bridge Plug 8/1/1984 P2 5,880 - Howco EZ Drill Bridge Plug 8/1/1984 P3 6,422 - Float Collar, Cementto 6,417' 09/1975 o[ocnonnnni nrru, Sands/Zone Top (MD) Btm (MD) Top (TVD) t SPF Date Status Beluga D 4,168' 4,216' 4167.6' '* 4 10/7/1975 Closed XA Sleeve Beluga E 4,276' 4,540' 4275.5' U4539.4'25' - '* 4 10/7/1975 Closed XA Sleeve Beluga G1 4,960' 5,055' 4,960' '* 4 10/5/1975 Open Beluga G2 5,133' 5,238' 5,133' '* 4 10/3/1975 OpenBeluga H1 5,367' 5,392' 5366.2' 5' 4 10/2/1975Beluga H2 5,461' 5480' 5,460' ,19' 4 10/2/1975 Open Beluga H3 5,521' 5,532' 5520.2' 5531.2' 11' 4 10/1/1975 Open Beluga H4 1 5,737' 1 5,856' 1 5736.2' 15855.2' 119' 1 4. 10/1/1975 Plug Beluga) I 5".., I I M9t,.Z I 5967.7' 1 71' 1 a I inM H07c 1 oi.... *Partialiv Perforated Interval Created By: JJ 5/19/2016 THE STATE °fALASKA 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 212-18 Permit to Drill Number: 175-034 Sundry Number: 319-269 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 og c c.a loska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this Zi day May, 2019. iROMS-LEYNA1 3 o 261 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 90 AAc 95 9R0 REME V F MAY 2 11 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Fish 2 SL Tootls, CTCO, N2 ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 175-034 ' 3. Address: 3800 Cenlerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-283-20049-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No Beluga River Unit (BRU) 212-18 " 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0058820 Beluga River/ Undefined Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): 5,580'; Junk (MD): 7,000' 6,998' 5,580' 5,579'-1,850psi 5,880'; 6,422' 87'& 377' Casing Length Size MD TVD Burst Collapse Structural Conductor 54' 30" 54' 54' Surface 411' 20" 411' 411' 1,530psi 520psi Intermediate 3,376' 10-3/4" 3,376' 3,376' 3,130psi 1,580psi Production 6,509' 7" 6,509' 6,509' 7,530psi 5,650psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5# / N-80 5,421' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 2 Baker FH Pkrs; N/A 4,075' MD/rVD-4,821' MDlfVD; N/A, N/A 12. Attachments: Proposal Summary � Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 11, 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§-h_ilcoro.com Contact Phone: 777-8420 Authorized Signature: Date: %.f 19 COMMISSION US ONLY Conditions of approval: Notify Commission sso_ tthhat a representative may witness Sundry Number: �7 I Plug Integrity ❑ BOP' t [�J Mechanical Integrity Test ❑ Location Clearance ❑fJ� Other: 000 RBDMS-�F-W 3 0 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: APPROVED BY /Zq /� Approved by: COMMISSIONER THEHECOMMISSION Date -! ` S �1A S Z�' / r{t��1 ❑� 1 - I A Submit Form and orm 1100-403 Revise 412017 Approved appli t rf1 R` IH`9Thr11 A the date of approval. Attachments in D licate 9 H Hikmp nweka, M Well Prognosis Well: BRU 212-18 Date: 5/24/2019 Well Name: BRU 212-18 API Number: 50-283-20049-00 Current Status: SI Gas Producer Leg: N/A Estimated Start Date: 06/11/2019 Rig: CTU Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 175-034 First Call Engineer: Ted Kramer (907) 777-8420 (0) (987) 867-0665 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Surface Pressure: Maximum Expected BHP: Max. Predicted Surface Pressure: 1,020 psi Shut in Tubing Press. 5-22-19 —2,396 psi @ 5,479' TVD (Calc. Norm Gradient to H2) — 1,850 psi (Based on .1 psi/ft. gas Grad) Brief Well Summary BRU 212-18 Was Spudded in September of 1975. The well was originally completed and tested in the G&H and the D&E Sands in October 1975. The well was then Sl waiting on surface facilities until April 1984. ✓ The well produced until November 1997 when it sanded up and died. Slickline was put on the well to attempt to swab it clear but tools were lost (1-1/2" string). A braided line unit was put on the well to fish the tool string and it lost the 1-3/4" string (below). The purpose of this work is to fish the two tool strings out of the well with Coil and then clean out to depth. " Notes Regarding Wellbore Condition • Two Tool Strings lost in the well. 0 1-1/2" tool string 37'6" long plus 27' of.125 wire (377' 0 1-3/4" tool string 35' long plus V of braided wire (87' (+/-)) Coil Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,000 psi Hi 250 Low. 2. PU overshot. RIH and fish 1-3/4" tool string. Latch on and POOH W/ Same. 3. PU wire grab and RIH twisting up Slickline. Grab Wire and POOH, fishing wire and 1-1/2" tool string. 4. RU Nitrogen Unit and clean out well W/ Nitrogen to 5,461' through 1-3/4" coil tubing ( 71' out of the tubing tail). 5. POOH with Coil. 6. Turn well over to production to test. Attachments: 1. Current Schematic 2. Coil Tubing BOP Stack 3. Current Well Head Diagram 4. CT Flow Diagram Forward Jetting 5. Nitrogen procedure Beluga River Unit Well: BRU 212-18 SCHEMATIC Last Completed: 5/7/1985 PTD: 175-034 HBeon Alaska, LLC API: 50-283-20049-00 RKB to MSL = 91.5' RKB to GL = 19.5' CASING DETAIL TOC @ 3,380' Min Heater I.D. 1.5" S d3 4- 5'- Beluga A- ?00! 6 �. Sands Bel D Bel E 12 PS P2 P3 Be[ G1 Bel G2 Bel H1 Bel H2 Be[ H3 Bel H4 Bell TD = 7000' TVD =6998' PBTD=6,417' ED = 5,580' END = 5,579' Max Angle = 2 deg @ 1,599' Size Type Wr Grade I Conn ID MD Btm 30" Conductor Tubing Hanger - Welded 29" 54' 20" Surface 94# H-40 Butt 19.124" 411' 30-3/4" Intermediate 40.5# K-55 Butt 10.05" 3,376' 7" Production 23# S-95 Butt 6.366" 6,509' 1.9" Heater String 2.9# 30RD EUE 1.516" 2,004' TUBING DETAIL 2-7/8" 1 Tubing#6.5 1 N-80 I 8RD 2.441" 5,421' JEWELRY DETAIL Tuhino ID. 6 �W Depth MD (ft.) Length (ft.) ID (in.) Description 1 20 1.38 2.875 Tubing Hanger 2 155 1.58 2.313 2-7/8" Otis S Nipple 3 4,050 3 2.313 Otis SS-XA Sliding Sleeve 4 4,063 1,04 2.31 Brown'CC'Safety Jt. 5 4,075 6.68 2.875 Baker FH Packer 6 4,081 1.S8 2.313 Otis S Nipple 7 4,771 13.02 5,238' Camco MMX GLM w/ DMY Valve, CEV Latch 10/12/1975 8 4,817 1.4 2.31 Brown'CC'Safety Jt. 9 4,818 3.18 2.313 Otis SS-XA Sliding Sleeve 10 4,821 6.68 2.875 Baker FH packer 11 4,828 1.58 2.313 Otis 5 Nipple 12 5,390 0.91 Beluga H3 Camco D Nipple Heater ID. Depth MD (ft.) length (ft.) ID (in.) Description A 173 0.6 1.5 1 Otis N Nipple Plugs 19ydYOTt -141TOTIVIlT11 Sands/Zone Depth MD(ft.) ID Description liID, PS 5,580 Howco EZ Drill Brid a Plu 8/1/1984 P2 5,880 - Howco EZ Drill Bridge Plug 8/1/1984 P3 6,422 Float Collar, Cement to 6,417' 09/1975 19ydYOTt -141TOTIVIlT11 Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status Beluga 4,168' 4,216' 4167.6' 4215.6' 42'* 4 10/7/1975 Closed XA Sleeve Beluga E 4,276' 4,540' 4275.5' 4539.4' 25" 4 10/7/1975 Closed XA Sleeve Beluga GI 4,960' 5,055' 4,960' 5,055' 80'* 4 10/5/1975 Open Beluga G2 5,133' 5,238' 5,133' 5,238' 74'* 4 10/3/1975 Open Beluga H1 5,367' 5,392' 5366.2' 5391.2' 25' 4 10/2/1975 Open Beluga H2 5,461' 5,480' 5,460' 5,479' 19' 4 10/2/1975 Open Beluga H3 5,521' 5,532' 5520.2' 5531.2' 11' 4 10/1/1975 Open Beluga H4 5,737' 5,856' 5736.2' 5855.2' 119' 4 10/1/1975 Plu Beluga 5,897' 5,968' 1 5896.2' 1 5967.2' 1 71' 4 1 10/1/1975 Plug *Partially Perforated Interval Created By: A 5/19/2016 2" 1502 x Mwg (Ml Beluga River Unit BRU 212-18 5/22/2019 Coiled Tubing HR580 Injector Head & Gooseneck Weight = 12,8501 bs 4.1116" 10K Conventional Stripper SK C062 Lubricator SK 0062 x 4.1/16" 10K Flange 4.1116" 10K Combi BOP Tap Set MMIShear Second Sel'.Pipe/Slip 4-1/16" 10K Flow Cross Mama) 2x2 Valve 1 2" 1502 x 2-1/16" 10K Flange Marcel 2x2 Valve 2'. 2-1/16" 10K x2-1/16" 10K Flange Marcel 2x2 Valva 3'. 2-1/16'10K x21/16" 10K Range Manual 2x2 Valve 4 2" 1502 x 21/16" 10K Flange 4-1/16" 10K x Wellhead Adapter Flange Wellhead H llilnakp U:.rk.. LI.L Beluga River 212-18 Current 05/22/2019 Bebge Puerllni iu>n8 nenga9 G,ryCWG 313-18 FS p2r7/8IST 81CrE IOU<X)%3 )/0x390 LIP, LIR aM3)/8101 cusp B W p'INIb in paWaion sift Wn8er,9x33/B ShO B IIfix33/810is...... T..8 GG-30angew/ 3%TypeO WlpLg slrinBstle Gisx w,nave Y' hops WP Gray IYW OPV p1o111e Xat C_1TfS71 mppb i�mnom T—. ap.l Weak, swee, ..,Gray D I.,. ends %$9/163M%E 9/103., mtta Tree, Nal Week, Mxttt, WKWLA, G,W 0lhryeenas %E9/165M%39/I65M. a• eem.,x Tree, NL Nx%Mxbr, W%MM,GrevDOryeenas %E9/165MXEU103M, eenMx Tuehg head, Gny. CWC.P, ./aoa a o..ol pox, 135/83M x93M, W/b E be.— U],CWGP balsam prep cavng nea0.cawtton .w. / JMX10% SOW, w/EM U165M EM A -pttr, Dual, Gray D, 9"S.L.' WRpn% Spetlal Gray DSWd by camas Sf 3)R"I.SW � r STANDARD WELL PROCEDURE I MCorp =Alaska, LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -lob Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 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 vl Page 1 of 1 10,000,000 1,000,000 100,000 10,000 1,000 100 10 1 Jan -1985 HILCORP ALASKA LLC, BELUGA RIV UNIT 212-18 (175-034) BELUGA RIVER, UNDEFINED GAS Monthly Production Rates 10,000,000 1,000,000 100,000 10,000 1,000 100 30 1 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 • Produced Gas (MCFM) - GOR . Produced Water (BOPM) a Produced Oil (BOPM) SPREADSH EET_1750340_BR U_212-18_Prod_Curves_Well_GaS_V120_20190528.xisx 5/28/2019 ConocoPhillips July 30, 2009 Cathy P. Foerster, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 k-1 5 -C)3 "ibs :p s: � a- Gay . t� ras'>tzSS6t� James T. Rodgers ftncharzls -0 Manager — GKA Light Oil Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1220 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: 20 AAC 25.300 (Request for Information) — Status of Oil and Gas Wells Dear Ms. Foerster, In response to your June 22, 2009 letter regarding status of wells, attached is a listing of wells operated by ConocoPhillips which have been inactive for five years or longer, including the status and respective documentation. If you have any questions concerning this data, please contact Mark Kovar at 265-6097. Sincerely, J es T. Rodgers Manager- GKA Development Greater Kuparuk Area ConocoPhillips- Status of Oil Gas Wells Is well on a pad Does pad with producing activity assure Proposed or service Is a wellhead adequate Operator Permit No. Unit Name Well No. Status wells? installed? surveillance? Plans for well ConocoPhillips Alaska Inc. 175-034 Beluga River Unit 212-18 Shut In Yes Yes Yes Evaluate for CTU cleanout. ConocoPhillips Alaska Inc. 180-072 Beluga River Unit 214-35 Shut In Yes Yes Yes Workover or sidetrack candidate. ConocoPhillips Alaska Inc. 176-072 Beluga River Unit 221-23 Shut In No Yes Yes Evaluate conversion to disposal well. ConocoPhillips Alaska Inc. 184-136 Beluga River Unit 232-09 Shut In No Yes Yes Application for Class I disposal with EPA. Well will be evaluated for future utility e.g. as a sidetrack, ConocoPhillips Alaska Inc. 182-036 Kuparuk River Unit 1E-10 Shut In Yes Yes Yes Brightwater® or LoSal "^ candidate. Well will b3 evaluated for future utility e.g. as a sidetrack, ConocoPhillips Alaska Inc. 182-079 Kuparuk River Unit 1 E-14 Shut In Yes Yes Yes Brightwatera or LoSal"I candidate. Retain wellbore for monitoring reservoir pressure and/or fluid saturations to understand fluid movements in the reservoir. Surveillance plan was approved via form 10-403 ConocoPhillips Alaska Inc. 201-230 Kuparuk River Unit 1M-17 Shut In No Yes Yes on 5/2/02. Well will be evaluated for future utility e.g. as a sidetrack, ConocoPhillips Alaska Inc. 195-133 Kuparuk River Unit 1 Q-21 Shut In Yes Yes Yes Bri htwatere or LoSaITM candidate. ConocoPhillips Alaska Inc. 193-104 Kuparuk River Unit 2E-07 Shut In Yes Yes Yes Future rotary drilling candidate. ConocoPhillips Alaska Inc. 184-240 Kuparuk River Unit 2E-09 Shut In Yes Yes Yes Future rotary drilling candidate. ConocoPhillips Alaska Inc. 202-243 Kuparuk River Unit 2G-17 Shut In Yes Yes Yes Future rotary/CTD drilling candidate. Well will be evaluated for future utility e.g. as a sidetrack, ConocoPhillips Alaska Inc. 197-251 Kuparuk River Unit 3G -14A Shut In Yes Yes Yes Bri htwatere or LoSal"' candidate. ConocoPhillips Alaska Inc. 187-055 Kuparuk River Unit 3M-18 Shut In Yes Yes Yes Well will be evaluated for future development opportunities. k -t S-o3`E SARAH PALIN, GOVERNOR i1 r` RT ���t�HA7 ®� A.ND�+ `�S 333 W. 7th AVENUE, SUITE 100 CONSERVATION fvO1��1��SSION ANCHORAGE, ALASKA 99501-3539 J�l� 1� fv 1•�1•�JI�►7� PHONE (907) 279-1433 FAX (907) 276-7542 June 22, 2009 James Rodgers ConocoPhillips Alaska Inc. PO Box 100360 SANE Anchorage AK 99510-0360 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Rodgers: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by ConocoPhillips Alaska Inc. have been inactive for five years or longer. If, for any listed well, ConocoPhillips Alaska Inc. believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, ConocoPhillips Alaska Inc. agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve ConocoPhillips Alaska Inc. of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertnalaska. Dov. Sincerely, a44�/� Cathy . Foerster Commissioner Enclosure Operator Permit No. Well Name ConocoPhillips Alaska Inc. 175-034 Beluga River Unit 212-18 ConocoPhillips Alaska Inc. 180-072 Beluga River Unit 214-35 ConocoPhillips Alaska Inc. 176-072 Beluga River Unit 221-23 ConocoPhillips Alaska Inc. 184-136 Beluga River Unit 232-09 ConocoPhillips Alaska Inc. 182-036 Kuparuk Riv Unit 1E-10 ConocoPhillips Alaska Inc. 182-079 Kuparuk Riv Unit 1E-14 ConocoPhillips Alaska Inc. 201-230 Kuparuk Riv Unit 1M-17 ConocoPhillips Alaska Inc. 195-133 Kuparuk Riv Unit 1Q-21 ConocoPhillips Alaska Inc. 193-104 Kuparuk Riv Unit 2E-07 ConocoPhillips Alaska Inc. 184-240 Kuparuk Riv Unit 2E-09 ConocoPhillips Alaska Inc. 202-243 Kuparuk Riv Unit 2G-17 ConocoPhillips Alaska Inc. 197-251 Kuparuk Riv _ Unit 3G -14A ConocoPhillips Alaska Inc. 187-055 Kuparuk Riv Unit 3M-18 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 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 "~'~24~18:~.~'o-'O~' ~-[~retty 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 Coromission 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. jo/rpc~z-energy Chevron Chevron U.S.A. Inc. 6001 Bollinger Canyon Road, San Ramon, California Mail Address: P.O. Box 5043, San Ramon, CA 94583-0943 Production Department Western Region January 16, 1987 Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, AK 99501 'Attention: Mr. Chat Chatterton Gert tl emen: Enclosed, per your request, are the following: 1. BRU 211-3 2. BRU 212-18 3. BRU 241-34 Drill Stem Test Compl etlon Report 'Sundry Notice Any further questions may be addressed to Mr. Jess Brookley (415) 842-0321. Sincerely, Jbhn F. Coltart Manager, Non-Operated Joint Ventures MA:skw Enclosures RECEIVED FE9 0 2 1987 Alaska Oil & Gas Cons. Commission Anchorage i For:ti ~ . ~ ~ , STATE OF ALASKA ~- OI/ ANI~GAS CONSERVATION COMMITTEE i ii i i i I i i i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* iii I ii z.. ~'~ b. TYPE OF COMPLE~ON: : W E I,L OV ER EN DACK EESV R. Other SUBMIT IN other tion~ on r e vc-.~.,, e side/ 2..'~IME OF OPERATOI% Standard Oil Company of California', WOI 3. ADDRESS OF OPERATOR P. O. Box 7-839, Anchoraqe, Alaska 995~0 4. L0c,~II0.~ 0F WEIA, tReport location clearllt and in accordance with a,;; State requiremgnts)* At ,u~aee 1799' from North line and 100' from West line of ,~ SeC. 18, Td--bI~oNw' R-9W SBYM · ' At top prod· interval report 1799" from North line and 100' from West line of Sec. 18; T-13N~ R-9W, SB&M ' at to,al depm 1799' from North llne and 100' from West line of Sec. 18; T-13N, R-9W, SB&M 18. TOTAL DEPTH. ~LD & TVD ~ PLUG, B~CK 7,000'MD 5. API NU~LEIUCAL CODE 50-283-20049' ADL 58820 '& ~/D'F. MD IF ~LT]I°LE HOW MA.NY' 5580'MD PRODUCING !N~VAL(S;. OF ~IS COMP~TION~P. BO~OM, NAME (~ AND .Top 4960' MD ' . :Bottom 5480 'MD ~ " 7. 1F INDIAN, ALLO'CI~E OR TRIBE NA3IE UNIT,FAIIlVI OR LEASE NAME 9. W~LL NO. BR 212-18 10. FIELD AND POOL. OR WILDCA. T .. Beluga River Field 11. SEC., T., R., ,M., (P-OTTOM HOL~ OI~JECTIVE) Sec. 18; T-13N, R-9W, SB&~ 12. PER3IIT NO. 75-34 ELEVATIONS IDF, RI{Il, RT, GR, WFC;* {17. EL,EV. CASINGItEAD ! 92,03 KB · ~ ROTARY TOOLS ·! i 0-7000 INTER%'ALS DRiLl, ED BY CAUI,E TOOLS - 0 23. WAS D!RECTIONAL SURVEY iV~A D E I i 24. TYPE ELECTP, IC A_ND OTHF_~ LOGS RUN D1L, BCS, . FDC, CNL ~ PML cement bond r .dipme.ter ......... -- iii ii g CASING ~ECO~ (Report ~11 strings iet in v,'ell) CASI2;C; SIZE WEIGEIT. LB, FT. ~ GRADE [ DEP~q SET (B,ID) I ,.. J 54' · i0 3/4" 40.5 { K-55 I _.3376'. _. - { s-Os { so9, -26. LINER lqEC O iCX) L ' 2& PERFORATIONS OPEJq TO PRODUCTION (interval. size and number} Four 1/2" jet holes per foot p~ODUCTION -..'l, ~. = ,. ii · i i · , J PIlODUCT1ON i%IEI lied (FlowiL,.g. ga~ 1i£~. p~,aping--size and type of pump, '4960 - 4972' 5209 - 5218' .4980 - 5028' 5227 - 5238' .5133 - 5160' 5461 - 5.480' ~',.~1.95..~ 5200' · . DATE FIRST PIIODLICTION [ : IDriv~.n ........... ! hlnn~ _ 26" i'347 SK~ amt. 1~.~ . is,' , 9 7/8" [shoe 720 Sksi'Staqe collak ag 3s92 - .. ' SCL~ i~D; SIZE ~ DEPTH SET (5~D) ~ PACi~ER SET , - i Il I 29. ACID. Si:CT. FiIA:I JRE, C~.iE.N'T SQL'LEZC. ETC. [~,m~.i~,' '-~hut2in . ~ou~s ~SrZD. |¢nOXE SiZE ]PI-'.OD'N FO.q c-^Su~ P.m~ssuaE IC~I.CULA~ Om--z~L. (;as 1Surd} U,ed ~°r ]uel, t'ent~'d, etc.) - · .. OIL,--BBL. GAS--~ICF. ',VATER--IDB L. : _~ . _ ', . 1TM I[2. 1,181' OF ATT&CH,MKNT8 "fr~n all-avatla/}lt'l' recurd~ .... --33. i hereby certify that ihb foregoing ~n(l attached~inO,~u~fiJfls~'~t~a~eef~ dete~mfi~6d : /~ ' ~ ' ' ' ' DATI' /~~ · ' · _ ............ 3 II I II I I u I _ II II Illl . *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS Gen'~i~l: This form is designed for submitting a complete and correct well completion report ~nd log on- all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used ns reference (where nov otherwise shown) for depth mensure- mentsgiven in alher spaces on this form and in any ntlachments. . Item_s 20, and 22:: If this well is:completed for separatc. Production from more than one interval zone (multiple completion), so stale in item 20, and in item 22 show the prc.ducing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item2&: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 211: Submit a separate completion report on this form for each inlerval to be separately produced. (See instruction for items 20 ,nd 22 above). F. T. of'Perffs.- 5897' - 5912~ and 5946~ - 5968". Open 3 hours 30 minutes Good blow off a±r dec~l~n~ng to dead after open i hour, 20 minutes, then . occasional bubbles for balance of test. Recovered 552' rise in 3 1/2" A~'FACI! U~iEF DESC~tlPI~ONS-O~ LITiiOLOGY. ·POROSITY. FI{A~'I~JFt~S..A~PAR~F2¢T '~}XpS DATA. ~ : . State of Alaska ~.Oi] add Gas Conservation C<~'~-.~.tee ~ag~~ 2 ,~ F.~. of Perfs. 5737-5742', 5747-5754', 5767-5774', 5778-5782', 5787-5792', 5799-5804', 5807-5814', 5830-5834', 5837-5842', and 5853-5856'. Open 3 hours l0 minutes. Gas to surface in 30 minutes at 3mcf/D rate, delcining to lmcf/D rate at end of test. Recovered 1292' rise of gas cut drilling fluid in 3 1/2" drill pipe. . Flowing pressure 82-716 psi. Shut-in pressure 2056 psi. F. T. of Perfs, 5461-5480'. Open 12 'hoUrs 20 minutes. Gas to surface in lO~inutes. Flowed gas at 1048 to 3276 mcf/D rates for balance of test. Fo~ no fluid rise. Flowing pressure 84-775 psi. ~ shut-in pressure 2536 psi. F. T. of Perfs. 5133-5160', 5195-5200', 5209-5218', 5227-5238'. Open 5 hours 43 ~utes. Gas to surface in 55 minutes at 1 mcf/D rate for balance of test. Recovered 860' rise of slightly gas cut drilling fluid in 3 1/2" drill pipe. Flowing pressure 96-527 psi. Shut-in pressure 1958 psi. F. X. of Perfs. 4960-4972', 4980-5028'. Open 12 hours. Gas to surface in 3 m~utes. Flowed gas at 2885 to 3094 mcf/D rate for balance of test. Recowered 197' rise of drilling fluid in 3 1/2" drill pipe. Flowing pressure 108--692 psi. Shut-inpressure 2300 psi. 1 a. TEST: ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN'FLOW POTENTIAL TEST REPORT INITIAL 1~] lb. TYPE TEST STABILIZED [] NON STABILIZED ANNUAL [] MULTIPOINT [] CONSTANT TIME SPECIAL:i'l: OTHER ~ Modified 2. Name of OPerator . Chevron U.S.A. Inc. 3. Address P.'O;'Box 107839, Anchorage, AK 99510 '4:' Location' of Well 1799' S, 100' E of the Northwest corner of Section 18, T13N, R9W, SB&M 5. Elevation in feet (indicate KB, DF etc.) ] 6. Lease Designation and Serial No. I 92' 12. Completion Date . 113. Total Depth 114. PlugbackT.D. Drilled 10/15/75 Corn _nl~r~d q/?/85 I 7000' I 6317 16. Csg.' S~ze Wmght per foot, lb. I.D. in inches Set at ft. 7" 23#/ft. 6.366 6509' 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 2-7/8" 6.5 #/ft. 2.441 5421' 7. Permit No. 8. APl Number 50-- 9. Unit or Lease Name Beluga River Unit 10. Well Number BRU 212-18 11. Field and Pool Beluga River 15. Type Completion (Describe) Single String Completion Perforations: From To 5532' - 4960' 4540' - 4168' 18. Packer set at ft.4081, + 4822 [19. GORcf/bbl. J20. API Liquid Hydrocarbons .... 21. Specific Gravity Flowing fluid (G) ISOCHRONAL~ '. . · -. ,' ..' Tbg.~l '' csg. [] ~,, '103OF ?o 23. Length of flow channel (L) Vertical Depth i~--L.cG~.--'--~'~' ~ CO2 5420' 5420' ! .56 [Trace 24. Flow Data Prover Line No. Size (in.) i . 4.026 . 4.026 3. 4.026 4. 4.026 ,5, Choke Orifice Size (in.) 18/64 20/64 22.6/64 14/64 Pressure psig 1869 1803 1753 1958 Diff. hw 7.1 7.8 8.3 7.2 Temp. °F. 103 1'03 103 103 Mean Annual Temp. o F. 33°F % N2 % H2S 1.0% -- Tubing Data Pressure psig 1600 1520 1470 1650 Temp. °F. 80° 75° 110o 95° Pressu re psig Barometric Pressure (Pa), psia 14.65 psia Prover [ Meter run [ Taps Casing Data Duration of Temp. Flow °F' Hr. 3 hrs. 3 hfs, 3 hrs. 26 hrs. No, 3. 4. 5. Basic Coefficient (24-Hour) Fb or Fp Pressure Pm 5.9 6.0 5.9 5.7 Flow Temp. Gravity ] Super Comp. Factor J Factor Factor Ft Rate of Flow Q, Mcfd 3880 4335 4536 2793 AnchoraGe No. Pr 3.47 Temperature T 3.46 3.45 563°R 3.47 563OR.. · 563°R 563°R "1;64 1.64~,, ,64 .64 ~835 ,835 ,835 .835 Critical Pressure Critical Temperature for Separator Gas Gg 667.8 psi: 343,37°R for Flowing Fluid G Form 10-421 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate Pc Pc2 pf p f2 No. Pt Pt2 Pc2 - Pt2 Pw Pw2 Pc2 - Pw2 Ps ps2 pf2 . ps2 1. 2. 3. 4. 5. 25. AOF (Mcfd) 9000 mcf/D n .875 Remarks: See attached data sheet and graph. A modified isochronal test was performed. This was agreed to by Mr. Blair Wonzell of the AOGCC in June 1985,.. The abo~e~ data is not applicable to a modified isochronal test (see attached). . I hereby certify that the fore§oin§ is true and correct to the best of my knowledge ~. S,§aed..~. "~. Xc~~~ yt,e eroductionEngineer Date 8-2-85 AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc ~pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate 'of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/-X/hwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor=-x/1/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air=1.000), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back--pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual Of Back-Pressure Testing Of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Fnrm 1CI-471 Well No. BRU-212-18 Modified Isochronal Test Run 7/17-20/85 Data Choke Size (inches) qse (mef/d) Pws(Dsia) 18/64 3880 2317 20/64 4335 2312 22.6/64 4536 2305 14/64 (Stabilized Rate) 2793 2317 Pws2 - Pwf2 (3 hrs) 18/64 1,819,033 psia2 20/64 2,040,220 22.6/64 2,187,201 14/64 (Stabilized Rate) 1,475,760 Pwf (psia) 3 hrs 2 hrs 1818 1835 1768 1790 1973 (26 hrs) Pws2 - Pwf2 (2 hrs) 1,758,489 psia2 1,978,119 2,108,925 PR = 2317 psia ~R2 = 5,368,489 psia2 from graph AOF = 9000 mcf/D Data n = turbulence factor = ' 1 = & log q se~ slope A log/SP" = .875 note: n between .5 to 1.0, turbulence is negligible. C = flow coefficient = qse n = .0112 (PR2 _ pwf2) Calculated AOF Potential = qse/AOF)= C (PR2)n = 8666 mef/D * this value is within 4% of extrapalated AOF value of 9000 mef/D RECEIVED Alaska Oil & Gas Cons. commission Anchorage AOF TEST BRU 2 12-18. 7/17-20/85 RECE:". qsc MMCf/d AUG05 1S85 Alaska 0il & Gas t\ r*,, .' ,, ' ~"~' STATE Of ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No, Chevron U.S.A. Inc. 75-034 3. Address ?.0. Bo× 107839, Anchorage, 4. Location of Well 99510 1799'S & 100'E of the NW Cor., Section 18, T13N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 8. APl Number 50-283-20049-00 9. Unit or Lease Name Beluga River 10. Well Number BRU 212-18 11. Field and Pool Beluga River - Beluga 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Surface facility work was comPleted 4-16-85. Well was put on test to clean up on 4-17-85. Due to slugs of diesel, drilling mud and formation sand the subject well took 21 days for clean up. The subject well was put on production through facilities 5-7-85. REC£ V£D MAY! AlasKa Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~/~'~/~-----"z'J'~-~ Title Area Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by COMM ISS ION ER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate DEPT o PLACE L,, I"1 I:. V I't U i~1 U. ~. A.~..~I N t;. TRANS~I!~'~L AND ACKNONLEDGEHENT OF RECEI Folded Rolled Sepia Film Xerox Blueltne THE FOLLONING IS A LIST OF MATERIAL ENCLOSED HEKEIN. PLEASE CHECK AND ADVISE IMMEDIATELY. ii i i i RECEIVED 8Y · i iH · REMARKS ON OTHER SLOE, THIS SHEET BY C~E%~ON U.S.A. INC. BOX 7-839 'ANCHORAGE, ALASKA 99510 STATE OF ALASKA ,~",~ ALASKA ..,IL AND GAS CONSERVATION C._ ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] Name of Operator 7. Permit No. CHEVRON U.S.A. INC. 75-034 3. Address 8. APl Number P. O. BOX 107839, ANCHORAGE, AK, 99510 50-283-20049-00 4, Location of Well 1799' S and 100' E of the N.W. Corner, Section 18, T13N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) K.B. ELEV. 92' I 6. Lease Designation and Serial No. ADL-58820 12. 9. Unit or Lease Name BELUGA RIVER 10. Well Number BRU 212-18 11. Field and Pool BELUGA RIVER - BELUGA Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well ,~ Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, 'including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). SEE ATTACHED PROGRAM. THIS WORK WILL BE PERFORMED ON OR ABOUT AUGUST 1, 1984. 14. I hereby certify ~a~he foregoing is true and correct to the best of my knowledge. /Ill S,.ne, The space below for Commission use Date ~-~"~/-f~ Conditions of Approval, if any: ! 'llllltllll[ llI~l[ll Approved by Approved Copy ~eturned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate WBI~WOBK PROCEDURE SUMMARY WELL: BRU 212-18 FIELD: Beluga River Unit 1799' S & 100' E of the N.W. Corner LOC.: of See 18 T13N R9W SB&M TYPE WELL: Gas Producer TYPE JOB: P & E Existin~ OBJECTIVE: Build facilities, flow lines, and perform needed down hole wire line work to place this well on production. WELL DATA:K.B. to To~. Han~er: 19.5' KB Elev: 911' TD: 7000' PBTD: 5580' CASING: 7" 23# S-95 to 6509' 10 3/4" to 3376' 20" to 411' 30" to TUBING: 2 7/8" 6.5# N80 EUE 8rd to 5421' (string I) 1.90" 2.9# NS0 10rd to 2003' (sUing II - heat) PERFORATIONS: See attached detail Notes: No BPV in heat string CONSTRUCTION PROGRAM: Designed by D & C Group to handle maximum 8MMCF/D with average of 4 MMCF/D and use oil as a heat circulating medium. WELL PROGRAM: A) After completion of the flow line and production faeiUties. 1) 2) MIRU 0.092" wire line unit with lubricator. Pull 1{" PN plug from N nipple at 173' out of string II (heat string). 3) 4) PuU Gray BPV from string I (2 ?/8"). Pull Otis position 4 "S" plug from 2 7/8" nipple in string I at 155'. Close XA sleeve at 4818' in string I. Bleed down string I tubing pressure 500 psi less than static to cheek that the XA sleeve is holding. PuU the CEV valve from the 2 7/8" Cameo MM mandrel at 4772'. · 5) 6) ProduCtion test the D-E zone (4168' to 4540'). Test rates and duration to be determined by Anchorage Engineering. Replace CEV valve in the 2 7/8" Cameo MM mandrel at 4772'. 7) Pull plug from 2 7/8" Otis S nipple (position 2) at 4829' in string L WKLL WORK PROCKDURK SUMMARY (COH'PD.) 8) 9) l~etion test the G-H zone (4960'- 5532,). Test rates and duration to be determined by Anchorage Engineering. PlaCe well on eontinous production on G-H zone or D-E zone. J. A, CONN 3/29/84 *AOFP Test will be performed q L · I.B. TO TUOXIIG ~ 2,003 · . 2 J~S. 2~" 6.5! 2 PUP J?~. 2~" 6,~ gUg, 2 J~S. 2~e" 6.5,# 8U8 Urd g-~O ?UBXNO )' OTXS "S" NZPPL~, PosLtJ. on ~ 01'~ "H" NXPPL~ I .600 21 J?$. 2~" 6.5~ £U~ 8td N-80 ?UBXNO CAMCO "O' ~ZPPLg 1 J?. 2~ gug ~rd ~1-80 TUDING OR. PLUG f~ ~;5§0' ' PLUG U 58U0, TOP OF PLUG · 6317, ?.O. 70GOt' . I ii il 63.57' 7,20" 63.17' 1.58, · 1.. 5U, 3893,70' X,C~' 6.6a' ~89.90' 31.65' 1.hO' · 560. ~6 ' BEL U GA" RIV ER '"212-t8 CASING 8~ TUBING DETAIL SECTION. 18. T. 13N,,R. gW STANDARD OZt, CLIqPANY OF CALXFORNZA STATE ~f .,ALASKA TO: ~ O.K. Gilbre~], Director Division of Oil and' C~s DATE File: 3.14 ? ' oo.4z : Sep~ 21, 1976 FROM: SUBJECT: Socal's ltr. of 9/14/76 Pedro Denton ~~ Chief, Minerals Sectio Enclosed is a letter frc~ Socal requesting lease ADL's 58820 and 58831 be put on a minimtm~ royalty payihg status. Please confirm whether ~e wells identified in the letter are capable of producing in paying quantities. ,/, Chguron · J. L. Rowland Area Supervisor Standard 0ii Company of California, Western Operations, inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9066 September 14, 1976 Producing Depar tmon[ Application 'for a Decision Certifying Oil and Gas Leases Capable of Production Beluga River, Alaska State of Alaska Department of Natural Resources Division of Lands 323 East Fourth Avenue ~ Anchorage, Alaska 99501 Attention: Mr. Peclro Denton, Chief Minerals Section The following leases have had gas wells drilled on them which are capable of production as evidenced by data furnished to the State: ADI~-58820 - " ~ ....(~!'' ...... , ~z,--588Sl - - , · '. ~, "~'?''': ~-~ .. Standard Oil Company of California, as Operator, respec'tft~lly requests these leases be certified as capable of producing gas in pay'_zD_g quantities and that- said leases be placed on a minimum royalty status, ..... · Will you kindly furnish your decision concerning this request. Very truly yours, · '--"G. Matiu~/ /! CC: Mr. T. S. Cate Shell Oil Company 601 West Fifth Avenue, Suite 810 Anchorage, Alaska 99501 Mr. T. N. Burdette Atlantic Richfield Company P. 0. Box 360 Anchorage, Alaska 99510 TRANSMITTAL AND~,KNOWLEDGEMENT OF RECEIPT OF MA ]IAL - (ALASKA) _ TO :__ Mr, %'. R. Ma rz h a ! 1 Statc of Alaska DEPT. Division of Oil & Cas L 500~L Po- -~,~. ~: c~p~,.e Drive PLACI' Anchoraga, Alaska .9950z~ DATE FD- Folded R - Rolled S - Sepia F - Film X ' Xerox B - Blueline THE'FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPANY WELL HISTORY LOG .~0C4 ~_ ~c~/ /?_4~/0 /~~/ P- 7 2t! 5I! I I I00 200 CN?D OJVI.51ON OF OIL Al,ID GA3 . ':' '.' RE '~*ARK$ OH OTHER SIOE, THIS SNE*'ET Perforations: Pour 1/2 holes per foot: 5946' - 5968:~ 5897' - 5912 5856' - 5853'~? 5842' - 5837' 5834' - 5830' 5814' - 5807' 5804' - 5799' 5792' - 5787' 5782' - 5778' 5774' - 5767' ~ '5133' - 5160') 5754' 5747'~ 5035' - 5055' 5746' 5737'-~ '4980' - 5028"~ Z,~'' 3'~t4/~ Cf'lb 5521' - 5532' '4960' 4972'2 5461' '- 5480t- ~-~c~ 4526' - 4540' 5367' - 5392' 4276' - 4287' 5227' - 5238~ 4196' - 4216' 5207' 5218'~ \ ~r/"~ 4168' - 4190' Halliburton Formation Test: 1. 5897' - 5968' 2. 5737' - 5856' 3. 5461' - 5480' 4. 5133' - 5238' 5. 4960' - 5028' Logs: S ch lumb erger Dual Induction Log Borehole Sonic Compensated Neutron Formation Density Proximity Log Microlog Continuous Dipmeter Depth 412'-- 7000' 412" - 6992' 411' - 7000' 411' - 7000' 3372' - 6992' 3376' - 7000' Go International Gammm-Ray Neutron Cement Bond Log Runs Scale 3 2" - 5" 2 2" - 5" 2 5" 2 5" 1 5"' 1 5" Chevron W.L.S. 3350' - 6407' 1 5" 3350' - 6406' 1 5" Dipmete~ Quality Control Plot Dipmeter 'Dip and Azimuth Display (All picks) Dipmeter Dip and Azimuth Display (Selvec) Azimuth of dip vs depth DIVISION OF TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF MATERIAL - (ALASKA) TO: 14r. T.R. 14?.rsha].J. State of DEPT. : Div~ ~; i:.m PLACE: Anchor;~g~ Al,~!.~;'ka 995(14 THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. RUNS BLUELINE INDUCTION ELECTRICAL LOG DUAL INDUCTION LATEROLOG BOREHOLE COMPENSATED SONIC BOREHOLE COMP. SONIC w/caliper BOREHOLE COMP. SONIC w/gamma BOREHOLE TELEVIEWER~ CONTINUOUS DIPMETER- High Res. CDM - POLYWOG PLOT CEMENT BOND LOG CASING COLLAR LOG - Perf. Rec. COMPENSATED FORMATION DEN. COMPENSATED NEUTRON FORMATION ANALYSIS LOG FORMATION DENSITY LOG F F FORMATION TESTER FORMATION FACTOR F F GAMMA RAY GAMMA RAY - NEUTRON GAMMA RAY COLLAR LOG MICRO LOG MICROLATEROLOG MUD LOG NEUTRON LOG PROXIMITY MICROLOG RWA COMPARISON PLOT SANDSTONE ANALYSIS SARABAND SIDEWALL NEUTRON POROSITY SONIC COMPLETION =PORT DIRECTIONAL SURVEY CORE DATA DIVIS!OM OF OIL A~4i) G.z,,.% SARABAND TABULAR LISTING Received and Checked by:~ / I I I00 200 TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF MATERIAL - (ALASKA) TO: Hr. T.R. ~arshail State of Alaska DEPT. Division of O~_.,_ & Gas 3001 Porcupine Drive, PLACE: Anchorage, Alas'ka 99504 . D~Vf31OI4 THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPA SCALE XEROX SEPIA BLUELINE RUNS INDUCTION ELECTRICAL LOG DUAL INDUCTION LATEROLOG BOREHOLE COMPENSATED SONIC BOREHOLE COMP. SONIC w/caliper BOREHOLE COMP. SONIC w/gamma BOREHOLE TELEVIEWER CONTINUOUS DIPMETER- High Res. CDM- POLYWOG PLOT CEMENT BOND LOG CASING COLLAR LOG - Perf. Rec. COMPENSATED FORMATION DEN. COMPENSATED NEUTRON FORMATION ANALYSIS LOG FORMATION DENSITY LOG F F FORMATION TESTER FORMATION FACTOR F F GAMMA RAY GAMMA RAY - NEUTRON GAMMA RAY COLLAR LOG MICRO LOG MICROLATEROLOG LO0 NEUTRON LOG PROXIMITY MICROLOG RWA COMPARISON PLOT SANDSTONE ANALYSIS SARABAND SIDEWALL NEUTRON POROSITY SONIC TEMPERATURE LOG I I ,o0 206 COMPLETION REPORT DIRECTIONAL SURVEY CORE DATA SARABAND TABULAR LISTING Received and checked by: SUBMIT IN DUPL/C2 TE* STATE OF ALASKA st ructions on reverse side OIL AND GAS CONSERVATION COMMITTEE III Ifil I WELl_ COMPLETION OR RECOMPLETION REPORT AND LOG* Il IIII I ,~. ~,r~. 'o~ w~,,: ' o,}', ~' %A~ ~ V,' ELL W ELL DR Y Other b. TYPE OF COMPLETION: WELl, OVER EN BACK RESVR Other 2. NAME OF OPERATOR Standard 0il Company of California, WOI ... 3. ADDRESS OF OPERATOR P. O. Box 7-839, Anchorage~ Alaska 995~0 4. LOCATION Ob' WELL-(Report location clearly and in accordance with any State requirements)* At surface 1799' from North line and 100' from West line of Sec. 18, T-13N, R-9W. SBYM at top prod. interval reporte4 below 1799 i from North line and 100' from West line of Sec. 18; T-13N~ R-9W, SB&M At total depth 1799' from North lane and 100' from West line of Sec. 18; T-13N, R-9W, SB&M 13. DATE SPUDDED' '[I4. DATE T:D. 'RF_J~CHED 9/l/75 J 9/23/75 15. DATE CO,MP SUSP Og AB'AND. 10/15/75 18. TOTAL DEPTH, ~iD & TVD f9. PLUG, BACK MD & TS/DF. IF AIULT~PLE COIViPL. t21' I{OW i~L/kNY* ROTARY TOOLS 7,000 ' MD 5580 'MD O-7OO0 22. PRODUCING !NTE1RVAL(S), OF TI-IlS COMPLETIO~N'~TOP, BOTTOM NAME (1VID AND D)* Top 4960' MD :Bottom 5480 'MD AP1 N~CAL CODE 50-283-20049 ~'%EASED~iGNk~ONANDSER~LNO, ADL 58820 7, IF INDIAN, ALLOTTEE OR TRIBE NA1VIE 8. UNIT,FA/%/Vi OR LEASE NAME 9. WELL NO. BR 212-18 10. FIELD AZqD POOL, OR WILDC&T , B~luga ,River Field i1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 18; T-13N, R-9W, SB&M 12. PEReVIIT N'O. 75-34 ELEVATIONS tDF, RRB, R'r, GR, ETC)* 17. E/~EV. CASINGtiEAD 92.03 KB INTERYALS DRiLl,ED BY CABI.E TOOLS ., 0 ,23. WAS DIRECTION/kL SURVEY MADE 1 24'. TYPE ELECTRIC AND OTHER LOGS RUN D1L, BCS, FDC, CNL, PML, cement bondf dipmeter 2.5. CASING RECORD (Report all strings set in well) 20" 94 H-40 411' [26" [347 SKS em~. 40.s i i . ' .. 7"..... 23 ['S-95 [ 6509'. 9 7/8". IShoe 720 Sks. 'Staqe collaE a RECO~ TUBING RE C. OP~D 3~ LINE~ 27. SIZD - TOP (>,'ID) -]SOTTON/ (AID) SACKS CEMENT* SCi%EEeq(R{DI SIZE DEPTK SET (MD) I PACI{ER SET (MD) I I I · Ill II ~'~7 I ~8. PERFORATIONS OP~-_iN TO PRODUCTION (interval, size and number) 29. ACID, Si:©T, F;IACX (/RE. CEd,tENT SQU~._ZE. ETC. 4960 - 4972 ' 5209 - 5-218 ' Four 1/2" D~i INTERV.g (MD) ! AM. OUNf 2~ND I-i!iND OF lXiATEP.,'AL USD 4980 - 5028' 5227 - 5238' jet holes 5133 - 5160' 5461 - 5480' per foot -- - 5~95. _-. 52.00 ' ....... ~ ! [ ! ii ii i /I 30. PRODUCTION DATE FIRS~P PI%ODUCTION I FP~ODUCTION MEi[{O'D (Flowii~g. gas lifL, pumping--size and type of pump~ ]V/ELL fJ'FATU$ (Producing or ! a,~ut-ln~ Shut-in FLOW, TUEING CAShNG P.RESSURE [CAL~TE]2) OIL--BBL. GAS--r~CF. WATEI{~EBL. [OIL GRAVITY-API (COR~.) 1 31. om?osm'Ior or (]AS (Sold, usek f~r fuel, vented, etc.)' ! WITNESSED '..So)d.. __~ ..... , ~_,, .... ~ ........... 32. 'CmT 0~' TUbina detail DIL" Bag. ~F~TM_ em. 'Du'[' ...... + ~ /~;Z/e~ OC~- 23. ! hereby certify that-the fo}egotng ~nd atthc~le_0,~l~o~on ls--c'6~h'p~%l~'aff'd~61~ecf a~ deiermYn~d f~om all-available r'ecords sm N~D R. M McKinley .-~ ,--..-.~,, ~.LE "Area W. nglneer o awE_ __ *(See Instructions and Spaces [or Additional Data on Reverse Side) " INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. 'i!~i~%:~? Item: 16: Indicate Which elevation is used as reference (where not otherwise showr~) for depth measure- ments given in other spaces on this form and in any ~tt~chments. ~ Items 20, ~,ncl 22:: If this well is completed for separate, production from more thar~ one nterval zone (multiple completion), so state in item 20, and in iteq~ 22 show the prcducir~9 interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv~l reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately pr°ducedl show- ing the additional d~ta pertinent to such interval. ' Item26: "Sacks Cement": Attached supplemental records for this ,well should show the alL, tails of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See in'struction for items 20 and 22 above). 34. SUMMARY OF I"O{'~MAT'ION TESTS II~("LUI)IN(; INTEr(vAL TE~q'FED. PHE~SUllE DATA A.N'D~0VERIES OF OIL'. GAS. 3,5, G ]DOI..,OG I C M AR K'I~R~ WATER AND MUD NAMlg ~E^S. F. T. of Perfs. 5897' - 5912' and 5946' - 5968'. Open 3 hours 30 minutes. ~...~;. ........... Good blow of air declining to dead after open 1 hour, 20 minutes, then occasional bubbles for balance of test. Recovered 552' rise in 3 1/2" of drill pipe of drilling fluid. Flowing pressure 84-360 psi. Shut-in pressure 1305 psi. . See Attachment Page 2 ) · , · ~6. CORE DATA. A'I'FACll I'ITtlE~v DESCIIIPIT~ONS OF L1TIIOLOGY. POROSITY. FRAC'TIJRES. API~A.RE'NT AND I)EI'EC~i'EI) SII()WS OI" OIL, GAS O11 I · I Illll FORM 1509R2 ' E).S.T., Report Distribution ,, ALLI BU RT S{RVlC£S A Division of Halliburton Company DUNCAN, OKLAHOHA 73533 Company Name - - Lease Owner Requested Distribution of Completed D.S.T. Report Fol(~er -for Ticket No... ~'./ 7 7~)~ '~ (This Order Must Be Fi I led Out and Signed By Company Representative) Orig. Chart & ~r~-e port s Company O ATT. P.O. BOX STREET & NO. BUILDING CITY Reports STATE Company ATT. P.O. BOX STREET & NO. BUILDING CITY Reports STATE Company. ATT. P.O. BOX STREET & NO. BUli. DI!4G -- CITY Reports STATE Company. ATT. P.o. BOX STREET & NO, BU;LOiNG CITY Reports STATE Company. ATT. P.O. BOX STREET & NO. BUILDING CItY Reports STATE Owner - Operator- or His Agent Send 1st, 2nd and 3rd Copy with Charts (Use Additional Sheets When Necessary) , Agent RECORDING PRESSURE GAUGE CHART / F~LD ~~GS ,, , B.T. ' Rstimated Gauge G~'fige Depth ~ ? / Ft. Depth Temperature Thousands of Inch Pressure P.S.I.' '~""""" ",¢~' .... ' Mud Pressure / ¢ ;> Initial Flow 0 t/'7 pr.essure , (.~0 __ Final Flow "..,,.r. ,y7 First Closed '7 ,. ,,,,,,,,, / :..~,/ Initial la. ow Pressure -' Plnal l~low Pressure Second Closed In Pressure , , , ,, Inttial Flow Pressure l~inal Flow. ' ~ Pressure .... Third Closed In Pressure Final Hydro ......, , ; ,Mud Pressure F"-, · '~"- '';/: Tester, Printed in Photographic negative for this chart on file three years from date at Halliburton Dtmcan, Oklahoma 73533 RECORDING PRESSURE GA. UGE CHART T~a,~t ~o_ ~'!'7 7 6 ,,L_.. ~;e.. / ~ - / - 7--r FIELD READINGS ,, , , B. T" Estimated GauBe ~2~uge Depth ~,.)~? /~/ · Ft. Depth Temperature //:?: ~,~ _ Thousands of Inch Pressure P.S,I. Initial Hydro. ,,,u,,~,.,,..ur. Initial Flow Pre~ure ,o7 .~ '~,..,,~o.. /,/ ?/~" Pressure , First Closed In Pressure I, 7: ,Z,,0 :¢ , Initial How Pressure Final Flow Pre~ure Second Closed In Pressure Initial Flow Pressure Final Flow Pressure Third Closed In Pressure I Mud Pressure , F'ORM 892-R4 ./~ _ . . '7 ., : ,'.~? ,': LLIBURTON Halliburton Company Photographic negative for this chart on file three years from, date at Halliburton Duncan, O_k'l-homa 73533 RECORDING PRE$$Ui~ GAUGE CHART / 0'- / 7_3" FIELD RBADINGS' B.T. Bst~ated Gau~e ~u,eDep~ ~~ Ft. Depth Temperature /.~_. ~. ~ __ Thous~ds ot Inch Pressure P.S.I. ~t~ Hyde. Mud Pressure , ~t~ Flow Pre~ure F~t Closed InPressure ? 7~ ~-~ ~ 7 ,, ~ Flow P~ure ~ ~low ~ Pre~ure ~cond Closed ~ Pressure ~ Flow Pre.ute F~ Flow Pressure T~d Closed In Pressure F~ Hydro. Mud Pressure "- ' / F'ORM 892-R4 , .. . Tester / , ( .... :.:~-'.:' ~" '''~ .... . ''? ' Printed in U.S.A." ~/"-' ~ O~ T HALLIBUR Ik,~~ ..,, A Halliburton Company Photographic negative for this chart on file three years from date at Halliburton Duncans Oklahoma 73533 RECORDING PRESSURE .~AUGE CHART fi/7 7~ ~- "r~,~'.~ /,~ - / - 7~ , , B.T. Estimated Gauge Gauge DePth ~ ~; 7 ~ Ft. Depth Temperature Thousands of Inch Pressure P.S.I. Initial Hydro. -" " ' , ~ , ,-,,,., ,,,o..,0 -': Pressure ~ Final Flow ' __P, ressure , 5Z' In P~essure . ~ t ...... Initial Flow Pressure '~ l~lmd Flow I'q Pressure Second Closed In Pressure , Initial Fl°w Pressure "i~'~' ~ Pressure , ,, Third Closed In Pressure Final Hydro. / Mud Pressure ,. u~' 7, ../ / /' FORM 892-R4 .,~,,, _~ //., ./' x Tester,, - --.~.~-. '7'. ~ ,; r r~ ~ ~ Printed in-U.S.A, f......_~~___ _ _ ~ Photographic negative for this ~ L L.I..I~.,?..R T ~ char~ o~ til~ ~hree )'ears lrom dat~ a~ Hllllb-r~on Duncan, .el Halliburton Company Formation~Testing ServiCe Report~ DUNCAN, OKLAHOMA Fach Horizontal Line Eaual to 1000 p.s.i. OF3 -- Theoretical OpE OF4 -- Theoretical Open Flow Potential with/Damage IRemoved Min. Ps PF Po~ Q R r,,, -- Radius of Well Bore . t -- Flow Time :.~ t o -- Total Flow Time '~' . Z -- Temperature Rankine . Z -- Compressibility Factor ~LI -- Viscosity Gas or Liquid .... 10~1 -- Common Log IZre~h W~fer ~._.orrecte~ --- Extrapolated Static Pressure ...................... Psig. --- Final Flow Pressure .......................... Psig. -- Potentiometric Surface (Fresh Water') .................... Feet --- Average Adjusted Production Rate During Test .............. bbls/day -- Theoretical Production w/Damage Removed .................. bbls/day '--Measured Gas Production Rate ...................... MCF/D -- Corrected Recovery ...................... bbls ..................... Feet .................... Minutes .................. Minutes ............... oR Whe'~ .n_ e..~flon N~~ G;ven, Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ... ...................... Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ............. '... Multiple CIP Sampler ............... Extension Joint .................... A~:~unning Case ................... II II Hydraulic jar '~ VR Safety Joint ......... - .... Pressure Equalizing Crossover ......... Packer Assembly ................... Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube .......... Blanked-Off B.T. Running Case ....... II II Drill Collars .. ..................... Anchor Pipe Safety Joint ............ HT - 500 Packer A~sembly ................... Distributor ........................ Packer Assembly ................... 0o D. ,1 3½" 3.88" 3.9" 3.87" 3.87 '~-'' 3.9" 3.88" 5.75" 2.88" 3.87" '3.87" 3.88" Anchor Pipe Safety Joint ............ Side Wall Anchor ................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. R~inning Case ........ Totol Depth ....................... ~j! ~TJxCKET NO817701 2.25" 2.764" 2.25" .87" .62" I 5694.15' 124.11' 6.46' 5.81' 4.57' 4.57' 5.09' 3.45' ', 4.35' 7.68' 4.07' 4.05' 1.04' 5816' 5822' 2. 185" 1.99" 5827' 5831 ' 5844' 5856' 5860' 5865' 6417' P B D F L U I D SAM P L E DATA Date 9-30-75 Number 817701 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton ' Recovery: Cu. Ft. G~s i of Job HOOK WALL District ANCHORAGE cc. Oil cc. Water Tester C.H. BOATMAN Witness MR. TINKER cc. Mud Drilling Tot. Liquid cc. Contractor KENAI DRILLING COMPANY SM Gravity ° APl @ °F. E 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¢i~,Drill Collar Length I.D. Mud Pit Sample Filtrate~ @~*F. ppm'?Drili Pipe Length I.D. · " Packer.Depth(s) __ Ft. Mud Weight vis !'~; cp ~Depth Tester Va!ve I:t, TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of ~:!.~ Recovered . Feet of 3 Recovered Feet'of Recovered Feet of ~ Recovered Feet of Remarks Fourth gauge I -- ,, Gauge No. 753. Gau~e No. ' Gouge No. TEMPERATURE TIME Depth: 5860 Ft. Depth: Ft. Depth: Ft. 24 Hour Clock Hour Clock Hour Clock, Tool : A,M. .... Est. °F. Blanked Off ,yes Blanked Off Blanked Off Opened P.M, Opened A.M. . _Actual °F. Pressures Pressures :?. Pressures Bypass P.M. ' Reported Computed Field Office Field Office Field Office _-initial Hydrostatic 3] 83 31 ~t Minutes Minutes · '~o Initial 86 ! O2 ~.r. Flow ~-Z Fi~a~ 466 480 Closed in 1 ~1 1 _ '~'o Initial !§.o_ Flow :i.,. ' -- i u '- Final Closed in Initial -- ~ Flow ~... Final _. Closed in __Final HydrOstatic 31._8_3 3185 r Ticket F L U I D S A M P L E D A T ^ Date 9-30-75 Number 817701 ' Sampler PressUre .P.S.I.G. at Surface Kind Halliburton i Recovery: Cu. Ft. Cas of Job HOOK., WALL District ANCHORAGE cc. Oil cc. Water Tester C.H. BOATMAN Witness ~. TINKER cc. Mud . Drilling ...., Tot. Liquid cc. Contractor KENA! DR!LLING COHPANY SM co Gravity ° APl @ oF. EQ U I PM E N T & H O L E DA TA --I Cas/Oil Ratio cu. ft./bbl. Formation Tested Be1 uga Ri ver RESISTIVITY CHLORIDE Elevation 70 ~ Ft. CONTENT ~--. Net Productive Interval37"Ft. Recovery Water @ °F. ppm All Depths Measured From Kelly bushing 90' Recovery Mud ~ @~°F' ppm Total Depth 6417' PBD Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size 7" 23// Mud Pit Sample ~ ~i~ °F. ppm Drill Collar 'Length 124.11~.'~,!i. 2.25 "' Mud Pit Sample Filtrate~ @~°F. ppm Drill Pipe Length. 5694.15.'D'.'~'' 2.764" ,,, Packer Depth(s) 58~.4 ' Ft. Mud Weight ':~: : ' vis :' cp Depth Tester Valve 5822 ' Ft. , TYPE AMOUNT Depth Back ~ Surface Bubble Bottom Cushion Ft. Pres. Valve 5816 Choke ho s e Choke 5/8" ...... Recovered,,, 579 ::? Feetof drilling mud ; [ Recovered Feet of : -4 m Recovered Feet of ~., ~r-- . Recovered Feet of ~< ::~ ,, Recovered Feet of Remarks Opened tool with a light blow with 6# surface pressure in 5 minutes. Opened to sump in 8 minutes, blow declining to weak - dead in bucket at 1 PM...started bubbline at 1'30 with weak blow and heading remainder of test. Closed tool for 94 minute closed in pressure period. Charts ..indicate severe_.plugging of tail pipe perforations. , . TEMPERATURE Gauge No. 597 Gauge No. 489 Gauge No. 611 TIME Depth: 5827 Ft. Depth: 5831 Ft. Depth: 5856 .Ft. ,, , ; 24 Hour Clock 24,Hour Clock 24Hour Clock Tool A.M. Est. ,,~,.°,F, Blanked Off .no Blanked Off no_ Blanked Off ,yes .... Opene. d 11 · 4i~.x~ DOOO Opened A.M. Actual 114 °F. Pressures ,~- Pressures Pressures Bypass :" 4' 46 P.M. :; ....Reported Compuied Field Office Field Office Field Office -[~itial Hydrostatic L~"164 3168- i 3183 3179 3186 3192 .... Minutes Minutes .~o ~n~t~o~ --84 84 ~ 86 ,~102 94 '11 2 ~.~. Flow ' . .' · ~:~ .... F~na~ 3.60 360 370 374 471 '475 210 .... Closed in 1305 1307 ~'31 3 1320 1 584 1 579 94 -~-o Initial ~,.e Flow ....... u ~, Final ~'~' Closed in . Initial ~ F~ow ....... ~. Final _____ - -- Clos~'d in _Fino__~_lH__vdrostatic ] ~ 3'152 .. 3168 31~- ~' ;---3179 3186 31'g2-- . TI'CT SERVICES DUNCAN, OKLAHOMA ~TIME~ Ec~ch Horizontal Line Equal to 1000 p.s.i. OF~ -- Theoretical Open Flow P OF4 -- Theoretical Open Flow Potential with/Damage Removed Min ..... MCF/D P s -- Extrapolated Static Pressure .................... Psig. P F -- Final Flow Pressure ............... Psig. p o, -- Potentiometrlc Surface (Fresh Water') ............... Feet Q '-- Average Adjusted Production Rate During Test .......... bbls/day Theoretical Production w/Damage Removed ........... bbls/day, Qg Measured Gas Production Rate ................. MCF/D Corrected Recovery ................ bbls r w Radius of Well Bore . · -- Flow Time ............ Feet ........... Minutes t o Total Flow Time .... Temperature Rankine Compressibility Factor ...... ....... Minutes · . · °R ,)j ~ Viscosity Gas or Liquid ...... CP Log -- Common Log * Pofentiome~ric .~urf.~ce JR ' ,- z:...~,-, T~r','~ ¥.~v~eo E:ev~t;on N:~t Given, F-resh Wc~-er Corre +e=~ ::.: '~ - Ticket !~' FLUID SAMPLE DATA Date 10-1-75 Number 817702 ',~_ Sampler Pressure .P.S.I.G. at Surface Kind Halliburton ~'~ RecoVery: Cu. Ft. Gas of Job HOOK HALL District ANCHORAGE '§ cc. Oil cc. Water Tester C.H. BOATMAN Witness HR. RICHARDS cc. Mud Drilling Tot. Liquid cc. Contractor KENAI DRILLING COMPANY SM S Gravity ° APl @ °F. EQU I PM E N T & H OLE DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested Beluga River co, RESISTIVITY CHLORIDE ' Elevation 70' CONTENT ~ Ft. '-I Net Productive Interval 52 m Ft. Recovery Water @ °F. ppm All Depths Measured From Kelly bushing 90' Recovery Mud @ °F. ppm Total Depth Plug back depth 5880' , Recovery Mud Filtrate ~ @ ~°F. ppm Main Hole/Casing Size7" 23// Mud Pit Sample @ o,~,~ ppm Drill Collar Length 124 11 ' I.D. 2 ~ud Pit Sample Filtrate~ @~°l;'?~' ppm Drill Pipe Length 5539' I.D. 2. 764" i Packer Depth(s)5690' ~ud Weight -!'L'. vis cp Depth Tester Valve 5668' i": Ft ~ Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve 5662' Choke ChokeS/8" ',, Recovered 1292 Feet:of gas cut drilling fluid "~ Recovered Feet of ~ 03 m Recovered Feet of Recovered Feet of .- Recovered Feet of Remarks SEE PRODUCTION TEST DATA SHEET... Char~s indicate possible leakage during closed in pressure Der~od. Gouge No. 597 Gouge No. 489 Gauge No. 611 TEJd PERATURE ~ ' TIME ~ Depth:5673Ft. Depth: 5677 Ft. Depth: 5701 Ft. . 24 HOUr Clock 24 Hour Clock 24 Hour Clock Tool A.M. _Est. °F. Blanked Off no Blanked Offno Blanked Off ,yes '! Opened3.48P.M. 5710' ~ Opened _Xctuall 12 °F. Pressures Pressures Pressures Bypass 8' 55 P.M. , _ - ::;'L Field Office Field Office Fi'eld Office Reported Computed -initial Hydrostatic 31 7fi 'R177 Il ER ]176 .31RF; 31 9.3 Minutes Minutes Initial ' - ~ Flow 84 78 74 Rq. R? lDO ~.~.. Final 6q? 7N4 76)1 706 716 717 1 R? 1 _ Closed in ~n.~_~ ?n~ 2fl47 ?Fi.~.~ 2Flfi6 2067 12n 121 . ~o Flow Initial ........ ~°~ Final Closed in -- '~_~ Flow Initial :~. _ Final .... Closed in _Final Hydrostatic 3176 3174 3_1_5.8 3165 , 3186 3175 -- , , ,, Ticket FLUID SAMPLE DATA Date 10-1-75 Number 817702 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE cc. Oil · CC. Water Tester C.H. BOATMAN Witness MR. RICHARDS cc. Mud Drilling Tot. Liquid cc. Contractor KENRI DRILLING COMPANY SM S Gravity , ° APl @ °F. EQU I PMENT & H OLE DATA 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 Si.ze .. Mud Pit S~.~ple @ °F. ppm Drill Collar Length .;":" I.D. Mud Pit SS'mple Filtrate @ °F. ppm Drill. Pipe Length ' I.D. Packer D.~pth(s) Ft, i~Mud Weight vis cp Depth Te~'er 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 c]aucle Gauge No. 753 Gauge No. Gauge No. TEMPERATURE ~ TIME _ Depth: ,~7r~.~ F,t. Depth: , Ft. Depth: Ft. 74 Hour Clock Hour Clock Hour Clock Tool A.M. _Est. °F. Blanked Off Spt; Blanked Off Blanked Off Opened P.M, ;. Opened A.M. ~Actual °F .... Pressures Pressures Pressures Bypass P.M. ,. Field Office Field Office Field Office Reported C~mputed ~lnitial Hydrostatic 31 95 319~r Minutes Minutes '~ Flow ..... Initial 98 103 ~ ;,-,~ 721 718 o. ,. 2067 2068 c 6 Flow -- : _ Closed ih Initial ,013 _~.o_ Flow ~_~. _ Final Closed in _Final Hydrostatic 3195 3178 f'o,l~l~ iii. Ri~PRiNTirD IN U.I.A. C'/~DI~AATI~Ikl 'T'C'C'T ~ Cas)no perfs.5737-5856' Bottom choke 5/8" Surf. temp 4;> 'F Ticket No. 81770;> C~s gravity ,56 Oil gravity GOR - Spec. gravity. .Chlorides . ppm Res. @ *F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED ... Date Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks p.m. psi MCF BPD 10-1-75 3'48 PM Opened tool 4'03 6# Opened to sump · 4::15 3 -';;. Gas to the surface " 4'35 5 ~,~ Turned to flare 4-50 1/4" 6 5' 20 " 5 3/4 "" ::.:' . 5'40 " 5 6- 20 ,, 5 6:50 " 4 3/4 Closed tool for closed in pressure .... period. 8' 55 Pul 1 ed 1 oose. ,,, ..- _ No. 597 First Flow Period First Closed In Pressure Time Deft. PSIG Time Dell. . t -~- i~ Temp. .000" Corr. .000" Log t~~ e No. .3231 5673' Clock No. 8420 817702 Second Flow Period Second Closed In Pressure J Ticket 2'4 hour No. Third Flow Period Third Closed In Pressure , ~ PSIG Time ?,e, fit:: PSIG Time Defh .~ PSIG Temp.PSIG Time Deft. Temp.PSIG Time Deft. log Temp. .000 ' '"?i! Temp. .000" LOg Temp. Corr. .000" Corr. .000' Corr. Corr. Corr ,,, Depth , Clock No. 1 IR20 14 hOur Interval REMARKS: *First interval is eaual tn 36 minutes. ** = 13 minute~. · Minutes , , , SPECIAL PRESSURE le No. First Flow Period 611 Time Deft. PSIG Time Defl. t-~-~ Temp. Log .000" Corr, .000' I Depth First Closed In Pressure PSIG Temp. Corr. 5701' Second Flow Period Time Deft. .000" PSIG Temp. Corr. Clock No. 13874 Second Closed In Pressure Time Deft. o000" Log~-~ PSIG Temp. Corr. ITicket 24 hour No. Third Flow Period Time Deft. PSIG Temp. Corr. 817702 Third Closed In Pressure Time Deft. - t -J- ~ .ooo" LOgT PSIG Temp. Corr. 7 ! 7 · 1075 1 264 1423 1663 174.3 1~27 1902 1066 2021 2067 e No. 753 Depth 5705' Clock No. 16147 24 hour Intervol 30 RENLARKS: *First interval is equal to 36 minutes. **: 13 minutes. Minutes _ SPECIAL PRESSURE DATA "'""'"'""='/" Drill Pipe or Tubing ................ Reversing Sub ....................... 11 i. Do Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual ClP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ 3,88" , 9" 764" 2.25" 3" 3" 1.25" · 75" 2.185" 1.99" Multiple CIP Sampler ............... Extension Joint .................... AP Running C~se .................. II II H "'~aulic*./ar Jar ' 3.87" 3.87" 3.9" 3.88" 5.75" VR Safety Joint .................. Pressure Equalizing Crossover ......... Packer Assembly ................... -mm~.m.r~o~-.. P.e.r. fs ................2.88" Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... II II Drill ~.ollors ..... '.'... .............. Anchor Pipe Safety Joint ............ HT 500 Packer Assembly .................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wail Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. · Blanked-Off B.T. Running Case ........ Total Depth ....................... 3.87" 3.87" 3.88" 8i7702 DEPTH 1 124.11' 6.46' 5.81' , · 4.57' 4.57' 5.09' 3.45' 4.35' 5662' 5668' 5673' 5677' 5690' 7.68' · 4.07' 4.05' 1.04' 5701' 5705' 5710' 5880 PBD Formation Testing Serviee Report HAI / IBIIlI TOIV SERVICES DUNCAN OKLAHOMA Each Horizontal Line Equal to ~000 P.s./. .. OF3 -- Theoretical Open Flow Potential with/D OF4 ~ Theoretical Open Flow Potential with/Damage Removed Min .... MCF/D ~ Extrapolated Static Pressure ................... Psig -- Final Flow Pressure ................... Psig -- Potentiometric Surface (Fresh Water') ................ Feet -- Average Adjusted Production Rate During Test ........... bbls/day ~ Theoretical Production w/Damage Removed ............ bbls/day --Measured Gas Production Rate ................ MCF/D Ps Q R -- Corrected Recovery ..... r w -- Radius of Well Borer t -- Flow Time t o = Total Flow Time Z ~ Temperature Ranklne Z -~ Compressibility Factor . . ~lJ -- Viscosity Gas or Liquid . Log z Common Log .................. bbls ................. Feet .................. Minutes ...... Minutes ....................... °R CP * Potenf;o,-"e*,.- ....Su,t-.~ze Re e ~' D.;~_~r, i:~b!e Whe~ E!eva*'~n, ,4.;, ~'' -~ .even, F L U I~D S A M P L 'E DA.T A . Date 10-2-75 Nu,-ber 817703 -Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery:' Cu. Ft. Gas of Job HOOK WALL District __~I~LCHORAGE cc. Oil cc. Water Tester MR. BOATMAN Witness MR. RICHARDS cc. Mud Drilling Tot. Liquid cc. Contractor KENAI DRILLING COMPANY BJ S Gravity ° APl @ °F. E Q U I PM E N T & H O LE D A T A C~s/Oil Ratio cu. ft./bbl. Formation Tested Beluga River RESISTIVITY CHLORIDE Elevation 701 J:t. CONTENT Net Productive Interval 1 9 ' Ft. Recovery Water ~ @~ °F. ppm All Depths Measured From Kelly Bushing (90' ~ Recovery Mud ~ @__ °F. ppm Total Depth 5580' PBD Ft. Recovery Mud Filtrate ~ @ ~°F. ppm Main Hole/Casing Size 7"-23# Mud Pit Sample @ °F. .;:! ppm Drill Collar Length 124.11" LD. 2.25'" Mud Pit S.ample Filtrate~@~°F. :?: ppm Drill Pipe Length : 5258' I.D. 2. 764" ~' Packer Depth(s) 5408' ': Ft. Mud Weight v~s cp D~pth Te~ter Valve 5386' ' Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve 5380' Choke 15/16_3/4_l/~hoke 5/8" · Recovered Feetof :'No recovery reported ~ Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks Ooened tool for a .741 minute first flow ~eriod with a medium blow. increasina durina test. Closed tool for a 479 minute first closed in pressure period. SEE PRODUCTION TEST DATA SHEET FOR ADDITIONAL INFORMATION. CHARTS INDICATE PARTIAL PLUGGING OF TOOLS ON CHOKE DURING FLOW PERIOD. C~uge No. 597 Gauge No. 489 ' Gauge No. 611 TaM~aATUR~ T~aa .Depth: 5391' F,t. Depth: ~,';Jql:[' Ft. Depth: 5419' 24 H~r Clock '- ~4 Hour Clock Ft. ?4 Hour C~ock Too~ 10- 2 A.M. Est. 'F; BlankedOff ,NO Blanked(iff NF~ BlankedOff YFq Opened ]~_0 P.M. . : Opened 3 A.M. Actual 'j 0~ °F. Pressures pressures Pressures Bypass 202 P.M. '~" Reported C'omputed~ ",'i Field Office Field Office Field Office Initial Hydrostatic .':J ~ ~ 3034 3037 3035 3043 3052 Minutes Minutes '..-~ Initial - _ i t.c Flow 84 96 98 ,- 94 94 99 i~~. F~no~ 775 777 773 784 798 812 742 741 Oosed in 2536 2542 2536 2535 2531 2543 478 479 ~-o Initial : o Flow ~°'c Final Closed in Initial ,. o Flow ...... i~ Fin°l _ Closed in Final Hydrostatic j --30! ! 2993 3037 2991 3031 3013 · F' F21kAATif'"NNI TI='C,T r"IATA ~,T,-,',,,0,,,o-,/,, ' Ticket FLUID SAMPLE DATA Date 10_2_75 Number 817703 ',~- · Sampler Pressure .P.S.I.G. at Surface Kind Halliburton ~, o no Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE ~' cc. Oil cc. Woter Tester MR. BOATMAN Witness MR. RICHARDS cc. Mud Drilling I Tot. Liquid CC. Contractor KENAI DRILLING COMPANY BJ S Gravity ° APl @ ' ' °F. E Q U I P M E N T & H O L E D A T A r~o Z Ga~/Oil Ratio cu. ft./bbl. Formation Tested - I 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 Pj.t'..Sample @ °F. ppm Drill Collar 'Leng~:~:t I.D. Mud 15ii~:'-Sample Filtrate @ ,--°F. ppm Drill Pipe Length I.D. . · Packer;Depth(s)' . Ft. Mud Weight vis cp Deptl~ Tester Valve F~, TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of :"' D Recovered Feet of - ~' 3 rtl Recovered Feet of ~ ' ..1 Recovered Feet of Recovered Feet of Remarks Ffl~ lr~T~ 6AUGF i Gauge No. 753 Gouge No. Gauge No. TEMPERATURE I TIME _ Depth: 542~ ' Ft. Depth: Ft. Depth: Ft. 24 Hour Clock Hour Clock Hour Clock Tool A.M. , Est. *F. Blanked Off YES Blanked Off Blanked Off Opened P.M. · Opened A.M. Actual115°F, Pressures Pressures Pressures Bypass P.M. ., Field Office Field .'Office Field Office Reported Computed -init. iai Hydrostatic 3062 3047 ~,~,~te, -- · -~o Initial I ~' · ' e'c Flow __98 98 ' ' ~. _. F~,~a~ _818 80_6 C~o~ed in 2528 253_8 ~ Initial c o Flow - __ ' ~o.~_ Final ...... Closed in : ~ Flow I~itial ~ Final -- -- Closed in Final Hydrostatic [ 305~_ 3010 Casing perfs.,5461- 5480' Bottom choke 5/8n Surf. temp.. , 'F Ticket No. 817703 C~s gravity, ,Oil gravity. GO.R " spec. gravity Chlorides ppm Res. INDICATE TYPE AND SIZE' OF GAS MEASURING DEVICE USED 2.12'5 0ri fi ce P1 ate · i Date ' Choke Surface C~s Liquid Time a.m. Size Pressure Rate Rate Remarks a.m. psi MCF BPD 10-2-75 140 Bubble Hose opened tool. 150 15/1~ 6# Gas to surface. . 200 " 15 Fluid to surface. .. 205 " 24 .: To flare. 220 ?;" 230 56 245 '...: 65 -. 300 100 Cleanina uo slowlv. : :315 125 . 330 - 140 1048 345 145 400 150 415 160 430 162 2317 445 160 500 162 515 170 . '530 170 2707 545 172 ' .. 600 172 · 630 180 2868 645 185 700 185 715 --- 180 730 180 Casing perfs. 5461-5'480 .Bottom choke 5/8" Surf..temp 'F .Ticket No, , 8] 7703 ~s groviw. '' ~ : Oil graVis. Spec. gravi~ , -Chlorides ,,pPm R~. ~ 'F INDICATE TYP[ AND SIZE OF GAS MEASURING DEVICE USED ~.]~5 0pifice Plate ~te Choke Surface ~s Liquid Time o.m. Size Pressure Rate Rate Remarks ~i MCF BPD ~.m. 745. 185 800 15/1 {. 188 815 " 189 830 ,. " 1gO 3108 'r 855 3/4 Changed chokes. 900 "~ 240 915 ~" 250 930 251 2536 945 258 lO00 256 lO15 25O 1030 250 3120 Cleanin~ up. 1045 249 llO0 252 lll5 260 11J..O 250 2960 l~ 255 12uO 1/2 .,;~ 260 1215 " 50~ 1230 " 500 3276 1245 500 ., 1 O0 500 ll5 505 130 505 Casing perfs, ~46]-~48C) Bottom choke ~/8" . Surf. temp 'F Ticket NoL R177~3 Gas gravity Oil grovi~ , . ~R Spec. graviS, Chlorides ppm R~. INDICATE TYPE AND SIZE OF GAs MEASURING DEVICE USED , , , ~te Choke Surface ~s Liquid Time a.m. Size Pre~ure Rate Rate Remarks ~i MCF BPD ,,, 1~ 510 3179 518 200 202 C1 os ed i n, .:~ -~.~. 1000 Pul 1 eJ?:i oose. . . . . , : , .... , ..' ... .. ,,,, ,, , ,, Time E~fl. i .000" i'°1 ,oooo l J . 1 6593 it'°717 2.0740 2. 4840 1°I It 12 "13 ~,auge No,597 F i rst Flow Period I Depth 5391' First ClOsed In Pressure Second Flow Period Clock No. 8420 Second :, Closed In Pressure J Ticket 24 hour No. Third Flow Period 817703 Third Closed In Pressure .~ .~ PSIG Time De fl. PSIG Time Dell. .~ PSIG PSIG Time Deft, PSIG Time Deft, PSIG Time Defl. Log Temp. Log Temp. Temp. Log 'Temp. Temp. Temp. Corr. .000" Corr. .000" Corr. .000" Corr. .000" Corr. .000" Corr. 96 .0000 777 465* .1 043 2300'" '~ 2368 715 552 .2120 .3196 2409 600 .4274 2435 .5350 .6427 .7504 .8581 .9658 2456 2473 2485 2496 2:506 1.0734 ...... 2513 1. 1811 2520. 1.2888 2527 1.3965 1.5042 1.6120 618 , 618)C 777 2532 2537 Gauge No. 0 .0000 .4195 1 2385 4~1.6480 si2.0575 ; ~12. 0600 i12.4670,°t 11 489 15' Reading Interval 123 ~4 467* 529 559 6O7 634 626)C 784 .00O0 · 1 .(13_3 ,2 Q.9_9 ,3_1_65 .4221 .5398 .6364 .7430 .8496 .9562 1.0629 1.1695 2761 · 1 3827 1.4893 · 5960 32 2542 Depth 784 2298*' 2365 2407 2435 2453 2469 2483 2493 2502 2510 2517 2523 2528 2533 395' Clock No., , 13829 2535 '.4 hour REMARKS: * INTERVAL = 126 MINUTES ** iNTERVAL : 31 MINUTES C : CHOKE CHANGE' J Minute :,.I Gouge No. First Flow Period J Time Deft. PSIG Temp, .000" Corr. o .0000 99 .4234 __~ _,8367 1 2500 4 1.6633 S6 2.0766 (2. 0840 i2.4900 13 ,15 493* 561 596 641 671 658), 812 ,611 Time Deft. .000" I Depth First Closed In Pressure .0000 · 1041 . ~2_12 6 .3191 ,_4.266 .5341 .6.4]_6 .7491 .8566 ,9641 1.0715 1,1790 1. 2565 L..3.240 1.5015 1 _"6090 L t+f} ag--T- PSIG Temp. Corr. 812 2303 2371 2411 2437 245~ 2_47_4_ 2486 2498. 2507 2515 2_5.23 2529 2,5_3_3_ 2538 2543 54,19 Second Flow Period Time Defl. .000" PSIG Temp. Corr. Clock No. 13874 Second Closed In Pressure Time Defl. .000" PSIG Temp. Corr. ITicket 24 hour No. 'Third Flow Period Time Defl. .000" PSIG Temp. Corr. 7703 Third Closed In Pressure Time Deft. Log-L~- .000" PSIG Teml:>. Corr. Gouge No. oi . ooo_o ~1 .4j_163 ! 21 ,8-22.6.-. 3 1.2289 41 1.63_53 st'2.0416 a. (2. 0480! .2. 4480 10 I1 '1"2 13 Reading Interval REMARKS: 753 98 !! .OliO0 49_1' · 102_4 556 .2082 592 .! .33_3_9 636 .4197 676 .5254 652)( , 631._2 806 .7369 .8426 .9484 1.0542 1.1599 1.2657 1.3714 1.4772 '1. 5830 Depth rSO6 2297: __.__23.67_ 24Q5. 2(L3_3 2J_53 2470_ 2483 5423, Clock No. 16147 '.4 2494 2504 2512 2518 2524 2529 2534 2538 123 32 * INTERVAL =126 MINUTES ** INTERVAL = 31 MINUTES C = CHOKE CHANGE Minute' FORM 183-RI~PRINTI='O IN U.S.A. SPECIAL PRESSURE DATA LITTL'-:"$ 9667:~ 75C 8/74 I ' Drill Pipe or Tubing ................ Reversing Sub Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ..... Duel CIP Valve ................... Duel CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... ~x~x~mxx. AP.-RUNNING..CASE AP Running Cc~~ ':,: : . . Hyd:~aul,c Jar . VR Safety Joint ............ Pressure Equalizing Crossover ......... paCker Assembly ................... O~ff~X...PERFS ............... Jo Do 2: 2~" 1 _nn' 3.50" 2_~ 764" 2: 2~" 124_11' 3; RS" : R7" 6_ 46' 5380' _62" ~.81' 5386' 3.00" 3_ riO" 1.25" 4.57' 5391' .. 4.57' 5395' Packer Assembly ................... 3: qo" 3_ fl7" 3.45' 3: R7" ~_ q" 88" ~. 75" ;. 2_ BR" 2. 185" 4.35' 5408' ,,- 1_ 9g" 7.68' Flush Joint Anchor ................. Pressure Equalizing Tube ......... Blanked-Off B.T. Running Case ....... ~Kx~m~<x .AP..CASE ............ AnChor Pipe Safety Joint ............ 3.87" 3- 87" 4,07' 5419' 4, 05" 5423' ~~~.."m-. 500 ......... Distributor ........................ Packer Assembly .................. Anchor Pipe Safety Joint ............ Side Wall Anchor ................. : Drill Collars ..................... Flush Joint Anchor .................. Blanked-Off B.T. Rdnning Case ........ Total Depth ....................... 3.88" I. 04' 5428' ~_5580'__ Formation ,esting.Servic~ Report HA//IBIIH~OIV SEII Vi~, E$ DUNCAN, OKLAHOMA TIME Each Horizontal Line Equal to 1000 10.s.i. OF3 Theoretical Open Flow potential with/Damage OF4 -- Theoretical Open Flow Potential with/Damage Removed Min .... MCF/D Ps Extrapolated Static Pressure ................ Psig P F Final Flow Pressure ...................... · . Psig. Po, Potentiometric Surface (Fresh Water') ............... Feet C} -- Average Adjusted Production Rate During Test ... .... bbls/day Q1 Theoretical Production w/Damage Removed .......... bbls/day Measured Gas Production Rate ................. MCF/D -- Corrected Recovery ............... -- Radius of Well Bore ........... bbls Feet t Flow Time .............. Minutes Total Flow Time ............. . Temperature Rankine .................... .... Minutes oR Z -- Compressibility Factor ................... ~U -- Viscosity Gas or Liquid .. Log -- Common LOg CP * Pc~e""i';or'ne~'r[c Surface P-,e;ere~ze~--.,.~ .... ~,~-a~, Tab e Wheh c,~_ .... s, o~' Not C,[ven, Fre Water C,s~,~e ,e~ to i-~?O F. Ticket FLUID SA'K4 P LE DATA Date 10-4-75 Number 817704 '~- --Ir" _, Sampler Pressure .P.S.I.G. at Surface Kind Halliburton' Recovery: Cu. Ft. Gas . · of Job HOOK WALL District ANCHORAGE cc. Oil cc. Water Tester MR. BOATMAN witness MR. RICHARDS Cc. Mud Drilling Tot. Liquid cc. Contractor KENA! DRILLING COMPANY DR S co Gravity APl @ °F. EQ U I P M E N T & H O L E D A Z A --t o C~s/Oil Ratio cu. ft./bbl. Formation Tested Be1 uga River ._ I RESISTIVITY CHLORIDE Elevation 70 ' CONTENT . Net Productive Interval 74' Ft. Recovery Water ~ @~ °F. ppm All Depths Measured From 90' Kelly Bushing RecoVery Mud @ °F. ppm TOtal Depth 5280' PBD Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size 7"-23# Mud Pit Sample :L @ °F. ppm Drill Collar'Length. 12'4.11 ' ~:;.~ ~ ~ ~ ..... ~.D. 2.25" Mud Pit Sample FilJrate . @ °F. : ppm Drill Pipe Length 4914' I.D. 2.764';' ": Packer Depth(s) ~¥; 5065 ~ Ft. Mud Wbight : : vis cp Depth,Tester Vo'J~ 5043' Ft. TYPE AdNAOUNT Depth Back Surface 'i 5/16" BottomS/8'' Cushion Ft. Pres. Valve 5037 ' Choke Choke ., Recovered 860 Feet of gas cut mud .::.~i O Recovered Feet of ~: RecOvered Feet of O Recovered Feet of Recovered Feet of .... Remarks Opened tool for 343 minute flow wJth a light bubble hose blow, gas to surface Jn 55 minutes. Blow decreased to a very weak blow during test. Closed tool .. for 150 minute final closed Jn pressure. CHARTS IHDICATE PARTIAL PLUGGING OF TAIL PIPE PERFORATIONS DURING FLOW PERIOD. POSSIBLE LEAKAGE DURING CLOSED IN PRESSURE'. ...... , .............. " Gauge No. 597 Gauge No. 489 Gauge ~o. 611 TEMPERATURE -~ TIME ,, Depth: 5048 Ft. Depth: .... 5052 Ft.,.. Oep,h: 507(] Ft. 24 HOUr Clock "24 Hour CloCk 24 Hour Clock Tool A.lvi. Est. °F. Blanked Offl~10 Blanked Off NO,,, Blanked offyes Opened 6' 50 P.M. 5085' ~ . Opened A.M. Actual.. 103 'F. Pressures , Pressures Pressures "~' Bypass 3'03 P.M., :'~i': Reported Computed' Field Office Field ' Office ~ Field Office -_. Initial Hydrostatic 2737 2745 2744 2748 2769 2765 ~,~t,, ._3 Initial 96 96 ~ 99 ,1-03- 118 155 o lC-r_ Flow ..... ~ F~o~ 527 529.. 530 534- i 553 557 , , 343 343 Oosedin 1958 1949 1936 1951 1949 1969 150 150 I-o~ Initial c o FIow:~ , ,, :": -- I°'-~'- Final Closed in __ - Initial ~o Flow .......... ~. _ Final . ClosPd in Final Hydrostatic "2737 "' 2740 2744 2743 2769 ' 2763 i Ticket FLUID SAMPLE DATA Date 10-4-75 Number 817704 -- Sampler Pressure .P.S.I.G. at Surface Kind Halliburton ~ecovery: Cu. Ft. C~s of Job HOOK WALL District ANCHOR^GE cc. Oil cc. Water Tester MR. BOATMAN Witness HR. RI]CHARDS ., cc. Mud Drilling Tot. Liquid cc. Contractor KENA! DRILLIN6 COMPANY Gravity o 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 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. M~d Pit Sample Filtrate @ *F.?~' ppm Drill Pipe Length ,. I.D. Packer Depth(s) Ft. Mud Weight !2. "vis cp Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke -- Recovered Feet-'i~f Recovered Feet of ; Recovered Feet of ~ Recovered Feet of Recovered Feet of Remarks .... FOURTH 6AU6E Gauge No. 753 Gauge No. I Gauge No. TEMPERATURE ::I TIME _"!- Depth: 5080 I Ft. Depth: Ft. LDepth: Ft. 24 Hour Clock Hour Clock l Hour Clock Tool A.M. Est. °F. Blanked Off ,,V. es Blanked Off[ Blanked Off Opened P.M. Opened A.M. Actual °F. Pressures ;; Pressures Pressures Bypass P.M. - ':!' Reported comPuted :'!~ Field Office Field Office Field Office Initial Hydrostatic 2758 2757 Minutes Minutes ..~ Initiol 1 23 123 --' ~'c Flow .... c~__F~a~ 551 551 I _ Closed in 1 958 1962 '~ Flow ,' Initial I ~'~' Closed in .... -- ,. ~'~ Flow--Initial -- Clased in ---¢~r~al Hydrostatic 12758 2754 .............. _ 'rE'CT RATA .................. /-- Gauge No. ~ 3 First Flow Period 597 }Depth F i r s t Closed In Pressure 5048' Second Flow Period Clock No. 8420 Second Closed In Pressure Ticket 24 hour No. Third Flow Period 817704 Third Closed In Pressure Time Dell. PSIG Time Defl. t Jr_ t~ PSIG Time Dell. PSIG Time Defl. t-I-~ PSIG Time Defl. PSIG Time Defl. t-t-~ PS~G Temp. Log Temp. Temp, Log Temp. Temp. Log Temp. .000" Corr. .000" T Corr. .000" Corr. .000" T Corr. .000" Corr. .000" T Corr. -' 0 .000 96 .000 ' 529 1 1.150 529 .0504 937 2 .1008 1 326 Pluggir g .1512 1486 .2016 1602 · '2520 1694 ·3024 1769 .3528 1827 .4032 187'8 .4536 1911 · 50.40 1 949 _Gauge No. 489 ol .000 ..... 103" i..i'i, 53, uggl Reodinc~ Intervol REMARKS: Depth 5052' Clock No. 13829 hOUr 24 .000 534 .0498 .0996 · 1494 .1992 9__38 1326 1604 .2490 1694 .2988 1765 .3486 1829 · 3984 1879 . .4482 1912 · 4980 1951 1 5 Minutes · ,:. ~ ' FOR~¢ I$3-R1--PRINTE:D lS U.$.A, SPECIAL PRESSURE DATA Gauge No. 611 I Depth 5076' I First I First Second. Flow Period I Closed In Pressure Flow Period Time Deft. Time Defl. .000" .000" PSIG Temp. Corr. c .000 1~55 1.148 557 Time Deft. Lo- t -f- t~ PSlG Temp. .000" g ~ Corr. .000 557 .0501 965 · 1002 1361 .1503 1513 Pluggi rig · 2004 1637 · .2505 · 3006 · 3507 · 4008 .4509 .5010 753 123 .000 551 .0497 .0994 1728 1798 1849 1900 1932 1969 PSIG Temp. Corr. Clock No. 1387ar Second Closed In Pressure .~_~' PSIG Time Deft. Log Temp. .000" Corr. jTicket' 24 hour No. Third Flow Period Time Defl. .000" PSIG Temp. Corr. 817704 Third Closed In Pressure Time Defl. Log-L~- .000" PSIG Temp. Corr. ~ !::, .000 ~ 11.130 , ~, Pluggi -- [ ~:~EMARKS: .... .1491 .1988 .2485 .2982 .3479 .3976 .4473 .4970 15 Depth hour 551 950 1 340 1501 1620 1711 1786 1845 1892 1 926 19~2 508( Clock No. 16147 Minutes ,o ........... , .... , ....... SPECIAL PRESSURE DATA Drill Pipe or Tubing ................ Reversing Sub 5" ~L~K ET NO. p~i11~ 7 ~~ I.D. " LENGTH DLFTH 2.25" l' 2.764" 4914' 2.25" 124.11' .87" 6.46' .62" 5.81 ' 3'"':, 4.57' 1.25' 5.09' .75" 3.45' ,~ 2.185" 4.35' 1.99" 7.68' Perfs. Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler ................. Hydro-Spring Tester ................ 3½" 3.88" 3.9" 3.87" 3.9''? 3.88" 5.75" 2.88" 3.87" 3.87" 3.88" 5037' 5043' Multiple ClP Sampler ............... Extension Joint AP Runn,ng Case ........... (2)... ?:, Hydraulic Jar '~ . 5~)~8, 5052' VR Safety Joint .......... Pressure Equalizing Crossover ......... Packer Assembly ................... Distributor ........................ 5065' Packer Assembly ................... Flush Joint Anchor ................ Pressure Equalizing Tube .......... Blanked-Off B.T. Running Case ....... ~m:c,~ . .B, T....Case. Anchor Pipe Safety Joint ............ UT cnn Packer Assembly ....... U.' .-.u..u.u ..... Distributor ........................ Packer Assembly ................... ';~ Anchor Pipe Safety Joint ............ Side Wall Anchor ................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... 4.07' 4.05' 1.04' 5076' 5080' 5085' 528_0_' _.P__B_D. Formatio~[eSting Servi~e Repor'~ HA//IBIlIIWAI SEfl VWE$ DUNCAN OKLAHOMA Each Horizontal Line Equal to ~000 /O.s.i. 3 -- Theoretical Open Flow Potential with/Damage Removed Max ..... MCF/D OF,~ -- Theoretical Open Flow Potential with/Damage Removed Min ..... MCF/D Ps -- Extrapolated Static Pressure .............. Psig. P F -- Final Flow Pressure ............. Psig. P o, -- Potentiometric Surface (Fresh Water') ....... Feet Average Adjusted Production Rate During Test ........ bbls/day Theoretical Production w/Damage Removed ..... bbls/day Qg r w Measured Gas Production Rate Corrected Recovery Radius of Well BOre .......... MCF/D ...... bbls .... Feet t -- Flow Time ..... ........ Minutes t o -- Total Flow Time -- Temperature Rankine ............. Minutes oR Z -- Compressibility Factor ........... ~ -- Viscosity Gas or Liquid Log - Common Log CP * Pofentiometric Surface Re: ..... ~ ~ g--'~-, T~ble VvXeo E~e,'~*ion N f Oiven, Fresh Water Corre,,:tej FLUI.D SAMPLE D,-~, A Dote 10-5-75 Number 817705 ',o · ~O Sampler Pressure ' P.S.1.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of.Job HOOK WALL TEST District ANCHORAGE cc. Oil cc. Water Tester MR. BOATMAN Witness MR. RICHARDS cc. Mud Drilling ' Tot. Liquid cc. ControctorKENAI DRILLING COM'PANY PW S ..~ 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 Beluga River' ~z RESISTIVITY CHLORIDE Elevation 70 ~ Ft. CONTENT - Net Productive Interval 60 ~ Ft. Recovery Water @ · OF. ppm All Depths Measured From Kelly Bushing 90' Recovery Mud @' °F. ppm Total Depth 5050' P.B.D. Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size 7" 23# _ Mud Pit Sample @ °F. ppm Drill Collar Length 124:!/ I.D. 2.25'"' Mud Pit Sample Filtrat~i-: @ °F. ppm Drill Pipe Length 4759:~ I.D. 2 764~t Packer Depth(s) :: .:, 4910 ' Ft. Mud Weight- vis cp Depth Tester Valve "- 4888~ Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke 15/16"-3/4''-Choke 5/8" ' 1/2" Recovered - 197 Feet of Fluffy gas cut mud. i- } Recovered Feet of :. Recovered Feet of ~ c:~ RecoVered Feet of °<: Recovered Feet of ~", Remarks CHARTS INDICATE PARTIAL PLUGGING OF TOOL ON CHOKE DURING FLOW PERIOD. UNABLE TO RELIABLY READ CHOKE CHANGES. · SEE PRODUCTION TEST DATA SHEET FOR REMAINDER OF REMARKS ..... Gauge No.597 Gauge No. 48 9 ~auge No. 611 TEMPERATURE TIME _ Depth: 4893'. Ft. D~pth: 4897' Ft. Oe,oth: 4921',, Ft. 24 '-Iour Clock 24 Hour Clock 24 Hour Clock Tool A.M. Est. °F. Blanked Of. fN... o .... Blanked Off No Blanked Off Yes .... Opened .07 · 00::~M.,, 4930 ' :- Opened A.M. ~_Actual 98~.., °F. PresSures Pressures Pressures ,-., Bypass 03.' 00 P,M._ .. Field Office Field ;;' Office Field Office Reported Computed -J'nitial Hydrostatic 2690 2704 2711 2709 2726 Minutes Minute, "3 I~-it~a~ 108 115 I ,~22- 106 120 ---- ~-c Flow- " , .......... ~ Fina~ 692 7 11 926 I 937 720 7-2-0 Closed in 2300 22§7 2305 230'6 ...... 480 480 ~ Initial CLOCK F[~-L--URE - '~ 8.~ Flow Final '. 03 Closed in Initial ~ Ffo~-. __ ~. Finol Closed in ~ ........... Final Hydrostatic -- 2690 2675 .... j___27_.._0_9_ ................. ~_¥~ / ,. ............................ F©RMAT1C~N TF.C,,T FIATA ,_,,r ..... .... ........ ,',, , ,., -" Ticket FLUID SAMPLE DATA Dote 10-5-75 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton of Job HOOK WALL TEST District ANCHORAGE Recovery: Cu. Ft. Gas cc. Oil cc. Water Tester MR. BOATMAN Witness MR. RICHARDS cc. Mud Drilling Tot. Liquid cc. Contractor~Z~NAI DRILLING COMPANY PW S Gravity o APl @ °F. E Q U I P M E N T & H O L E O A T"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, · Mud Pit Sample Filtrate @ °F. .:"- ppm Drill Pipe Length' I.D. '~, Packer Depth(s) Ft. . Mud Weight : vis cp Depth Tester Valve ....... Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered , Feet of O Recovered- ., Feet of ,.. .Recovered Feet of ..... Recovered . Feet of Recovered Feet of Remarks ,,, -,,, FOURTH GAUGE: , Gauge No. 753 Gauge No. Gauge No. TEMPERATURE TIME . .Depth: 4925 I, Ft.. Depth: Ft.~ Depth: .... Ft. , 24 Hour Clock Flour Clock Hour Clock Tool A.M. ., Est. ~F. Blanked Of{les Blanked Off BIo,nked Off Open, ed P.M. Opened A.M. Actual °F. Pressures Pressures Pressures Bypass P,M_ · ;: Report'ed Computed · Field Office Field Office Field Office Initial Hydrostatic 2722 2721 Minutes Minutes 'o Initial 98 123 I ~.~ Flow .,, ~ Final 927 931 Closed in 2297 2297 ' " '~ 'Initial ' -- ~, ~ Final Closed in Initial t~ Flow ............. '" Closed in '-'Fi---~01 ~¥d~-~static j 2698 268~ ...... Casino er' .4960' -4930 ' 5/8" ..Bottom choke Surf. temp. °F Ticket No 817705 p ,s..56 Gas gravity ...... .Oil gravity.. GaR Spec. gravity__ Chlorides .,ppm Res. @ °F INDICATE TYPE AND SiZE OF GAS'MEASURING DEVICE USED Date Choke surface C~s Liquid Time . a.m. Size Pressure Rate Rate Remarks psi MCF BPD 7'00 Opened cool. 7' 03 15/16 Gas to surface. 7: 15 " 100# : , 7:45 219 8'00 220 8.15 210 8'30 205.. 3093.8 Cleaning up good. 8: 45 200 9' O0 195 9:15 191 9'30 198 3092.8 9.45 190 10: O0 190 10.15 " 10' 30 189 3000.3 10'45 182 11-00 185 · 11.15 ~90 11: 30 188 2995.3 · 11'35 3/4" Changed surface choke. __ 11:45 " 233 12:00 233 - , · 12' 15 234 12'30 238 2817.4 12'45 237 Casing perfs. ' Bottom choke 5/8" -.Surf. temp .......... °F Ticket No. 817705 Gas gravitY Oil gravity · . GaR Spec. gravity. Chlorides ' ppm Res., @. °F 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 1-00 3/4" 230 ., 1-15 " 242 ., 1:30 240 .~, . 1'45 :'?:~? 241 ~ 3091.1 t . 2-00 --'" 242 : 2.15 243 ., · · 2' 30 : 240 2' 45 235 3048.4 .-: 3' O0 240 ,,, 3'02 1/2" ,, Changed surface choke. 3' 15 " 452 3 '30 " 452 · 3'45 459 2951.6 4- O0 " 4' 15 458 4' 30 460 4' 45 460 3014.6 5:00 " · 5' 15 455 ,:~ ' 5.30 " ... . 5'45 458 2969.4 ... 6' O0 .~- 453 6' 15 · ,, 6'30 -455 6'45 45__0.__ 2969.4 ., 817705 Casing perfs. , Bottom choke ,Surf. temp °F Ticket No. Gas graviTM _Oil' gravity __GOR .... Spec. gravity - Chloride, ppm Res.. @ °F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED ,,, [~te Choke Surface C-as Liquid Time a.m. Size Pre~ure Rate Rate Remarks ~).m. psi MCF BPD .,, 7:00 440~ Closed tool, ,, 10-6-75 03:00 Pulled loose. · ~.'., · :: ;{~ :. :..;f '; ~ .: , .. ..... .... . . ... ,, , , , ,, , . , ,,, Gou..ge No. 11 First Flow Period 597 Time D~fl. .000" .000 i Gguge .No. oi .000 PSIG Temp. Corr. 115 Depth ,,4893' First Closed In Pressure Time Deft. .000" .000 Log~-~ ...... P$1G Temp. ,'Corr. 711 .4013 557 . 1073 2217 .8027 517 .2147 2251 1.2040 559 .3220 2265 1.6053 546 .4293 2274 2.0007 677 .5367 2278 2. 4080 711 . 6440 2280 .7513 2283 489 Second Flow Period Time Deft. .000" PSIG Temp. Corr. Clock No. 8420 Second Closed In Pressure Time Defl. .000" ' PSIG Temp. Corr. 24 hour No. 817705 Third Third Fl~!i:geriod Closed In Pressure T me Deft. Temp.PSIG Time Defl. .~ .000" Corr. .000" IL°g Temp. Corr. . 8586 2284 .9660 2288 1.0733 2290 1. 1806 2291 1. 2880 2293 1.3953 2295 1. 5026 2296 , I 2297 Depth 4897 ' Clock No. 13829 . 24 ':C'hou r 1.6.100 122 CLOCK FAILURE Reodina Interval 120 32 Minute><' REMARKS: ' .......... ,. .... , ......... SPECIAL PRESSURE DATA ·· .... Gau~,e No. 6 11 First Flow Period j Depth First Closed In Pressure 4921' Second Flow Period Clock No. 13874 Second Closed In Pressure Ticket 24 hour No. 817705 Third Flow Period Third Closed In Pressure Time Defl. PSIG Time Dell. t-J-0 PSIG Time Dell. Time Defl. t-J-0 PSlG Time Dell. PSIG Time De fl. t"kO PS~G 'Temp. Log Temp. Log Temp. Log Temp. .000" Corr. .000" T Corr. .000" T Corr. .000" T Corr. .000 120 .000 937 .4017 749 . 1073 2224 J .8033 870 .2145 2259 . 1.2050 889 .3218 2273 1.6066 799 .4290 2281 2.0083 828 .5364 2285 2.4100 937 .6436 2287 2290 2293 2297 2298 .000" Corr. 2299 Temp. .000" Corr. ,, P$1G .7509 .8582 .9654 Gauge,No. 753 1.0727 1. 1800 1.2872 2302 1. 3945 2303 1.5018 2305 2306 : 1.6010 o~ . 000 1 .3943 il.7887 1. 183 0 1.5773 2.3600 lo 14 Depth 4925 ' Clock No. 1'6147 24 hour 123 .000 931 795 .1052 2218 850 ,2104 2252 914 .3156 2266 792 .4208 2274 822 .5260 2279 931 .6312 2280 .7364 2283 .8416 2286 .9468 2289 1.0520 2290 1.1572 1.2624 1.3676 2292 2294 2295 1.4728 2296 I 1.5780 2297 Reading Interval 120 32 Minutes REMARKS: SPECIAL PRESSURE DATA J. D. DEPTH Drill Pipe or Tubing Reversing Sub ...................... 5" 2.25" 1 Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler ................. Hydro-Spring Tester ............... 3 1/2" 3.88" 3.9" 3.87" 2.764" 2.25" .87" .62" " ,. 3" 3" 4759' 124' 6.46' 5.81' 4.57' 4.57' 5.09' 3.45' 4.35' 4882 ' 4888* Multiple CIP Sampler ............... Extension JointA. P. Run.n.i.n.g.C.a.s..e. AP Running Case .................. Hydraulic Jar .................. ~i.; 3.88" 5.75" 2.88" 3.87" 3.87" 3.88" 1.25" .75" 2. 185" 1.99" 4893 ' 4897' VR Safety Joint ............ Pressure Equalizing Crossover ......... Packer Assembly ................... Distributor. ?~- f 0r.a t i 0RS ........ 7.68' 4910' Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube .......... Blanked-Off B.T. Running Case Drill Collars . .B..~...gg. .°.FF..B...T.- . Anchor Pipe Safety Joint ............ 4.07' 4.05' 1.04' 4921' 4925' 4930' H T 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 ' 5050' P.B.D State of Alaska ~ Oil and Gas. Conservation Co~--ttee Page 2 F.T. of Perfs. 5737-5742', 5747-5754', 5767-5774', 5778-5782', 5787-5792', 5799-5804', 5807-5814', 5830-5834', 5837-5842', and 5853-5856'. Open 3 hours 10 minutes. Gas to surface in 30 minutes at 3mcf/D rate, delcining to lmcf/D rate at end of test. Recovered 1292' rise of gas cut drilling fluid in 3 1/2" drill pipe. Flowing pressure 82-716 psi. Shut-in pressure 2056 psi. F. T. of Perfs. 5461-5480'. Open 12 hours 20 minutes. Gas to surface in 10 minutes. Flowed gas at 1048 to 3276 mcf/D rates for balance of test. Found no fluid rise. Flowing pressure 84-775 psi. Shut-in pressure 2536 psi. F. T. of perfs. 5133-5160', 5195-5200', 5209-5218', 5227-5238'. Open 5 hours 43 minutes. Gas to surface in 55 minutes at..1 mcf/D rate for balance of test. Recovered 860' rise of slightly gas cut drilling fluid in 3 1/2" drill pipe. Flowing pressure 96-527 pSi. Shut-in pressure 1958 psi. F. T. of Perfs. 4960-4972', 4980-5028'. Open 12 hours. Gas to surface in 3 minutes. Flowed~gas~at2885 to 3094 mcf/D rate for balance of test. Recovered 197' rise of drilling fluid in 3 1/2" drill pipe. Flowing pressure 108-692 pSi. Shut-in pressure 2300 psi. COMPLETION REPORT - New Well STDfNDAPd) OIL COMPANY OF CALIFOPfNIA, ~.~ESTERN OPERATIONS, INC. AREA: BELUGA RIVER COOK INLET ALASKA LAND OFFICE: ANCHORAGE PROPERTY: BELUGA RIVER LEASE NO: ADI58820 WELL NO: BR 212-18 APl NO: 50-283-20049 LOCATION AT SURFACE: 1799' South and 100' East from NW corner Section 18, T. 13N, R. 9W., Seward B&M LOCATION AT DEPTH: ELEVATION: 92' KB DATE: October 20, 1975 R. M. McKinley Area Engineer DRILLED BY: Kenai Drilling Company of Alaska, Rig. #1 DATE COMMENCED DRILLING: September 1, 1975 RIG RELEASe- OCtober 15, 1975 '~×P DATE OF INIT-~kqL--PRC~YdCTIO~~jhut in October 15, 1975 TOTAL DEPTH: 7000' EFFECTIVE DEPTH: CASING: 30" Conductor at 54' 20" Cemented at 411' 7" Cemented at 6509' S Ub~_A_RY PLUGS: Br. 5880' and 5580' peptember 1, 1975 Drilled and cased rat hole and rigged to drill. Spudded well at 5:00 AM. Drilled 15" hole to 406'. Circulated and pulled out. 70 - 74 pcf mud September 2, 1975 Open 15" hole to 26" to a depth of 431'. Circulated hole clean. 75 pcf mud September 3, 19 75 Ran 10 joints (413') of 20", 94#, H-40 Buttress shoe hung at 411'. Circulated hole clean. Cement 20" casing with 347 sacks of class "G" cement mixed with 479 cu/ft water premixed with 2.4% Gel by weight of water. Cement in place at 10:00 AM. Good circulation and cement returns to surface. Pumped 50 cu/ft of cement on top of shoe. Cut 30" off 20" casing and installed 20" slip-seal casing head. September 4, 1975 Completed installation of 20" casing head and installed class ll-B B.O.P.E. Pressure tested casing head and B.O.P.E. OK. Repaired choke manifold leaks. 70 pcf mud September 5, 1975 Tested manifold to 3000# OK. Conditioned cement out mud and located top cement at 394'. Drilled out cement 394' - 411' cleaned out to 431' and drilled 15" hole to 548'. 73 pcf mud September 6, 1975 Drilled 15" hole 548' - 1319' 771' 70 pcf mud September 7, 1975 Drilled 15" hole 1319' - 2440' 871' 72 pcf mud September 8, 1975 Drilled 15" hole 2190' - 2967' 777' 74 pcf mud September 9 ~ 1975 Drilled 15" hole to 3325' circulated clean and pulled to run Schlumberger Dual Induction log 412' - 2990' was stopped at 2995'. Ran in and reamed tight spot. 74 pcf mud September 10, 1975 Drilled 15" hole from 3325' to 3400' (75'). Pulled and ran Schlumberger logs Dual Induction log 412' - 3400', Borehole Compensated Sonic 412' - 3395', Formation Density log 411' - 3404', Compensated Neutron Formation Density 411' - 3404'. After log runs, circulated and pre-pared to run 10 3/4" casing. 75 pcf mud September 11~ 1975 Hung l0 3/4" 40.5# K-55 Buttress casing at 3376' and prapared to cement in place. 74 pcf mud September 12 ~ 1975' Circulated and conditioned mud. Cemented 10 3/4", 40.5# K-55 Buttress casing in place with 1425 sacks of class "G" cement treated with 2.4% Gel (by weight of mix water). Mixed at 98 pcf good cement returns. Released 10 3/4" OK. Stripped off Class ll-B B.O.P. and cut off 20" and 10 3/4" casing. Top 84 joints Next float collar 1 joint shoe cut Total 10 3/4" Casin~ Detail 3332.84' 10 3/4" 40.5# K-55 2.20 42.28 10 3/4" 40.5# K-55 1.80 3379.12 -3.00 3376.12 September 13~ 1975 Installed 10 3/4" S.O.W. casing head (12"-3000 psi). Pressure tested welds, OK. Installed Class 111 B.O.P.E. and Shaffer rotating B.O.P. September 14, 1975 Completed installation of B.O.P.E. and tested under 3000 psi as per operating instructions D-17. Tested B.O.?. and 10 3/4" casing under 2000 psi. Witnessed and approved by D.O.G. 77 pcf mud September 15, 1975 Conditioned mud and located top cement at 3205'. Drilled out cement to 3330'. Drilled out Duplex collar and tested 10 3/4" casing under 2300 psi, OK. Drilled ahead to 3510' made 110' of hole. September 16, 1975 Drilled 9 7/8" hole 3510' - 4203' (693') 79 pcf mud September 17, 1975 Drilled 9 7/8" hole 4203' - 5064' (861') 78 pcf mud September 18, 1975 Drilled 9 7/8" hole 5064' - 5582' (518') 80 pcf mud September 19,. 1975 Drilled 9 7/8" hole 5582' - 5893' (311') 80 pcf mud September 20, 1975 Drilled 9 7/8" hole 5893' - 6215' (322') 99+ pcf mud September 21, 1975 Drilled 9 7/8" hole 6215' - 6557' (342') 80 pcf mud RECE ¥EI) r: 9 o 2 1981 Oil & Gas Cons. Commission Anchorage September 22, 1975 Drilled 9 7/8" hole 6557' - 6845' (circulated) (288') 80 pcf mud September 23, 1975 Drilled 9 7/8" hole from 6845' to 7000', circulated and prepared to run logs. Ran Schl~,mberger Dual Induction, Borehole Sonic, Formation Density, Compensated Neutron with Gamma Ray and Proximity Microlog, all intervals were from 3376' to 7000'. 80 p cf mud September 24, 1975 Continued Schlumberger logging. Shot 74 sidewalls with ten lost and three misfires. Completed Schl,~mberger work and removed Shafco rotating head and installed flow nipple. 80 pcf mud September 25, 1975 Ran in hole and circulated, condition mud at 7000'. Mixed 40 bbls. fresh Gel pumped at 6500' to 7000'. Pulled out and installed rams in B.O.P.E. Prapared to run 7" casing. 80 pcf mud September 26, 1975 Ran 154 joints of 7" 23# S-95 Buttress casing, hung off 13 3/8"x7" Cameron hanger, with Baker float shoe on bottom 6508'. Baker float collar two joints above shoe (87') and Baker stage collar at 3892'. Cemented in two stages. Cement detail 1. Howco cemented through 6517' of 7" hung at 6509' with 830 cu/ft class "G" cement 119# slurry preceded with 50 cu/ft of water, followed by 25 cu/ft of water, displaced with 1410 cu/ft of mud, bumped plug on float collar with 2000 psi, had good circulation. 2. Opened stage collar at 3892', circulated out 50 sacks excess cement above stage collar. Howco cement through stage collar with 447 cu/ft of class "G" cement, 119# slurry; precededwith 30 cu/ft of water followed by 25 cu/ft of water, displaced with 837 cu/ft of mud, bumped plug and closed stage collar with 2200 psi held OK, with good circulation. Top of cement at 2375' est. Cut off 7" casing and placed 12" 3Mxl0" SM Gray tubing head. September 27 =, Completed tubing head installation and-tested flange and secondary pacl~ off to 3000 psi, with diesel oil. OK:. Instailed..Class lll ]~.OoP.E. and tested in accordance with Operating Instructions D-17. . · Coat/hued and completed tests. Ran in hole and found hard cement at 3736'. Drilled out hard cement to 3880'. - . · . · September 29~ 1975 & SePtember 30~ 1975 .Circulated hole and pressure tested 7" casing to 2000 psi':,' '.OK.' ' · Drilled opt stage collar at 3887' - 3889", Pulled and ~£rCulat. e'd... hole in preparation for Go International logging. Ran Gam~a' .Ray Neutron 6407' - 3350' , and Cement Bond Log 6407' -'3200'. . Pressure tested casing and prepared to perforate. Go International perforated from 5946' - 5968' and 5897' - 5912' with 4 1/2" ~et holes per foot and tested as follows.. '·' ~-'." .' "..'-'- '" - '- .' .... : -'. 78 per mud . : . o ..' .- ' '~'." .-- "ltffr #J. .5897' .- 5968' (9-30-75) Set packer at 5845~' with tail ,. .% · · · . · -. · o~ ..-~: ., . , _ . · · ~' -/.:.;...:.' · . .. :. · ~ .' o. .... . · · · .- ~,. . · . · '~ .%, .. · -; .. · · .? ..: '. . . "~ ' . '. ' at 5865'. Opened tool for 3 1/2 hours flow period. "' ' ":-- -" "- :"' Shut-in for 1 hour 30 rains. FSI used no cushion. 'Had .'..':. '.'. .':?'. ' ' .2-.. ':"fdmmediate good blow. Pressure bled off and blow decreased " '" "~' :: to dead in 80 min. Had spasmodic blows ti1 shut-in. .. · .... _-' No gas to surface. Pulled, recorded 552' .net rise of drilling fluid.' Bottom 350' gas cut, found no sand. ._-- .. Charts indicated partial plugging during flow period " -:... and build up. Test considered conclusive. Zone tight · ~- ::--' 'and not gas or water productive. Pressure data "- .-." . ~ . Depth IHH IFP _ FFP FSI FHH Top Imside .5,827 3,164 84 360 1,305 3,152 Mott~m Inside 5,831- 3,183 88 370 1,313 3,183 Top Outside 5,856 3,186 94 471 1,584 3,186 BOttOm Outside 5,860 3,183 86 466 1;581 3,183 -October 1, 1975 - Rigged up Go Internationai and jet perforated 4 1/2" holes per foOt (Selectively); 5737' - 5856' and ran formation test number two. .~CT ~2 5.737' - 5856' (10-1-75) Set packer at 5690' with tail at 5710'. Opened tool for three hours ten'mins. Gas after 30 mtns. max. rate 3 MCF/D. Shut in for two hours 'for final shut in. Recovered 1292' of Gas cut drilling fliud.' Top Inside . 5,673 3,176 ' ~84 692 2,053 "~ttom Inside 5,677 . 3,158 74 701 2,047 Top Outside 5,701 3,186 82 716 2,056 Bottom Outside 5,705 3,194 98 -~21 2,067 3,176 3,158 3~186 3,195 October 2, 1975 Removed test tools, charts OK. Ran in hole with scraper to 5890" circulated and condition mud. Pulled, rigged up to run Go International perforations. Perforated 7" casing with four 1/2" jet holes per foot from 5,461' to 5,480'. Prepared to run HCT ~3. HCT #3 5461' - 5480' (10-3-75) Packer set at 5408' tail at 5428'. Opened tool, gas to surface in ten minutes . Flowed gas to flare for 12 hours 20 min. Flow data Surface Flow MAX MAX Choke Period MCF/D' W.H.P. (F.S.I.) 15/16" 7 hrs~lS'min 1788 155 3/4" 3 hrs 5 min 2872 256 1/2" 2 hrs 3226 502 . Pressures Depth IHH IFP FFF Top Inside 5391 3034 84 775 Top Outside 5395 3037 98 775 Bottom Inside 5419 3043 94 798 Bottom Outside 5423 3062 98 818 FSI 2537~ 253~ 252~ FHH 3011 3037 3031 3050 October 3, 1975 Completed test. Ran in with scraper to top of bridge plug at 5580'. Conditioned mud. Rigged up to perforate 7" ca~ing and perforated four 1/2" holes per foot at 5133'~, 5115' - 5200', and 207' - [ October 4', 1975 Completed jet perfs. ~_~_~.. _ Rigged to test. HCT #4 5133' - 5238' (10-4-75) Packer set at 5065' tail at 5085'. Opened tool, Gas to surface in 55 minutes. Flowed Gas to flare for 5 hours and 43 mins. at 1 MCF/D rate. Shut-in fo~ 2 hours 30 mins. F.S.I. Pulled to rise and recovered 860' of slightly Gas cut mud. Charts OK. Pressure Data Depth IHH IFP FFF FSI Top Inside 5048 2737 96 527 1958 Bottom Inside 5052 2744 99 530 1936 Top Outside 5057 2759 118 553 1949 Bottom Outside 5080 2758 128 551 1958 FHH 2737 2744 2769, 2758 October 5, 1975 Prepared to perforate. Go International perforated the 7" casing with four 1/2" jet holes per foot from 4960' - 4972' and 4980' - 5028', and set to run H.C.T. #5. HCT #5 4960' - 5028' (10-5-75) Set packer at 4910' tail at 4930'. Opened tool; Gas to surface in 3 mins. Flowed gas to flare. Flow data Surface Flow MAX MAX Choke Period MCF/D W.H.P. (F. S. I. ) 15/16" 4 hrs 35 rains. 3014 .- 232 . 3/4" 3 hrs 27 mins. 2983 245 1/2" 3 hrs 58 mins. 2976 460 Closed tool for 8 hours F.S.I. Recovered 197' of mud. Pressure Data Depth IHH IFF FFF FSI FHH Top Inside 4893 2690 108 692 2300 2690 Bottom Inside 4897 ..... Top ·Outside 4921 2707 106 926 2305 2709 Bottom Outside 4925 2722 98 927 2277~ 2698 .. October 6~ 19 75 Completed test. Ran in hole with scraper to 5045' circulated and condition mud. Drilled out bridge plugs at 5045' and 5280' to top bri~dge plug at 5580'. Pulled and prepared to perforate 7" casing. 78 pcf mud October 7, 1975 Rigged up and perforated 7" casing with four 1/2" jet hole per foot - 4168' - 4190', 4196' - 4216', 4276' - 4287', 4526' - 4540', 5035' - 5055', 5367' - 5392', 5521'? 5532'~ Scraped casing to top of bridge plug at 5580', Circulated out and rigged to complete. Depth 7000' with bridge plugs at 5880' and 5580'. October 8, 1975 I-~E~} 0 2 1987 Circulated prepared to complete. '~Sk'~ 0~ & G~s Cons. C0~missi0n October 9~ 1975 Following work done at Ivan River 14-31 to complete BR 212-18. Exchange of tubing~ heads. Pulled 3 joints of 2 7/8" tubing and removed 12" 3M x 8" SM' tubing head. Completion held up for lack of seals and other completion equipment. .~ .78 pcf mud Work continued at ~i2-18 October 10, 1975 Ran in hole with Baker retrievable bridge plug set at 684' amd pressure tested to 2000 psi (OK). Raised Class 111 B.O.P. stack and removed tubing head secondary seals. Installed tubing head and tested secondary seals and flange at 2500 psi (OK). Re-installed B.O.P. 78 pcf mud October 11~ 1975 Completed B.O.P. installation. Tested B.O.P. equipment to 3000 psi OK. Pulled retrievable bridge plug at 684'. Ran 2 7/8", 6.5# N-80 tubing with production equipment and tested to 5000 psi. String #1. October 12~ 1975 Completed tubing run with Baker "FH" packers at 4822' and 4075'. Ran Go International Neutron log. Adjusted tubing string down 6 1/2 feet to "E" log depth. Landed string #2, 1.9" O.D. tubing at 2022', with "N" nipple at 172'. Rigged up C. A. White and installed "PN" plug in "N" nipple at 172' with Gray back pressure valve. Removed Class 111 B.O.P. 78 pcf mud October 13~ 1975 Installed x-mas tree and pressure tested~flange to 5000 psi and tree to 3000 psi OK. Pulled "PN"plug in string #2 and pumped 10 bbls. of diesel down string. Installed "PN" plug at 172'. Closed "XA" sleeves at 4050' and 4818' (string #1). Displaced 78 pcf mud with diesel. October 14~ 1975. Set plug in "D" nipple at 5499', set "FH" packers at 4075' and 4822' by pressuring string #1 to 4000 psi. Pulled plug from '!D"'~. hippie: flaring Gas 0ni~il/2" choke from string~#1 for 8 1/2 hours at 3000 MCF to 4500 MCF rates. Placed "PS" plug in position #2 "S" nipple and bled well down. Attempted to open "XA" sleeve at 4818'. In pressuring tubing to 2000 psi moved "PS" plug down hole, reset. October 15~ 1975 Opened "XA" sleeve and started flaring Gas on 3/8" choke. Closed well in for production test. Production Test: Opened well for one hour, flowed diesel oil and Gas to sump for five minutes. Turned to flare on 3/8" choke, and found leak in flare line. Repaired leak and returned well to flare. Well flowed at 5-6 MCF/D rate declining to 4120 MCF/D in 2 hours 25 minutes. Measured Rates: 4330 MCF/D on 3/8" choke 1400 psi test pressure 4120 MCF/D on 3/8" choke 1390 psi test pressure Final shut-in test pressure 2175 psi. Ran in hole with C. A. White shifting tool, unable to close sleeve at 4818. Pulled and pumped 10 bbls. of diesel oil down 2 7/8" tubing, set plug in "S" nipple at 155', bled tubing off, OK. Set Gray Back pressure valve in productive side of x-mas tree, close all valves. Rigged down Howco equipment and flare line. Installed companion flange on x-mas tree. Cleaned drill site, drained pumps and shut well in. Rig released at 12:00 midnight, October 15, 1975. J. W. Wilson RE£E VED 1987 TRANSMITTAL AND ACKNOWLEL~£MENT OF RECEIPT OF MATERIAL - ,. ~ASKA) DATE: THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. CHECK AND ADVISE IMMEDIATELY. ~ ~-~'~I~UCTION ELECTRICAL LOG BOREHOLE COMPENSATED SONIC BOREHOLE COMP. SONIC w/caliper BOREHOLE COMP. SONIC w/gamma BOREHOLE TELEVIEWER CONTINUOUS DIPMETER - High Res. CDM - POLYWOG PLOT CEHENT BOND LOG CASING COLLAR LOG - Perf. Rec. COMPENSATED FORMATION DEN. COMPENSATE~ NEUTRON - '-' '- "' FORMATION ANALYSIS LOG DENSITY LOG F F TESTER FACTOR F F FORMATION FORMATION FORMATION GAMMA RAY GAMMA~Y - NEUTRON GAMMA RAY COLLAR LOG MICRO LOG MICROLATEROLOG MUD LOG NEUTRON LOG PROXIMITY ~CROLOG RWA COMPARISON PLOT SANDSTONE ANALYSIS SARABAND SIDEWALL NEUTRON POROSITY SONIC TEMPERATURE LOG PLEASE XEROX SEPIA BLUELINE / /_ 7--/ / / / , · ? / / I '! ,6b'2oo COP~LETION REPORT DIRECTION3iL SURVEY CORE DATA SARABAND TABULAR LISTING =----_ ~ ~ ~,, ~ _ ,. '. _ , . . Received and checked by: ~z~-f ~-~, ~,~ ~,~.z"~ TO: DEPT.: PLACE: TRANSMITTAL Af"~F~CKNOkrLEDGEFdgNT OF. RECEIPT OF ~ate et Al~ka : Division of 011 & Ga8 --:. ~1 Porcupine Drive Anchorage, Alaoka 99S~ ---- .,, !;RIAL- (ALASKA) DATE,, FD - Folded - · R - Rolled ., . S - Sepia ... F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF, MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. WELL HISTORY LOG '. I00 20O .: · RECEIVED 8Y REIvlARRS O/OTHER SIDE, THIS SHE'ET Form No. P--4 lt,,_~"~. 3-1-1'0 STATE Oi-_ ALA.SKA Oii. AND GAS CONSERVATION SUBMIT IN I)UP. LICATE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS 2. NAM.~- OF OP~,ATOR Standard Oil Company of California; WOT_ P. O. Box 7-839, Anchoraqe, Alaska 4 12DCATION OF WELL 1799' from North line and 100' from West line of Sec. 18; T-13N, R9W, SB&M ~A-PI NUAiERICAL CODE 50-283-20049 6 L~,ASE DESIGNATION AND SEi~IAL NO. ADL-58820 ? IF INDIAE[ ALOTT'EE OR TRIBE HAME 8. L,~IT F.~J~M OR LEASE NA3ME · BR 212-18 10 FLFJ~D A_~;D POOL. OR WILDCAT Beluqa River Field ,, 11 SEC. T.. R. 1%{(BOTTOM HOl.~ Sec. 18; T-13N, R-9W, SB&M 12. PEP, MIT NO 75-34 13. REPORT TOTAL DEPTH AT END OF MONTH. CHA. NGES IN HOLE SIZE, CASING AND C~MF~%I%I'ING JOBS INCLUDING DEPTH SET AND VOLLTM'I~ USED PEI{FORATIONS. 'I-F_.STS A/~"D RESUL%I~S FI~HIi~.TG JOBS JL."NKIN HOLE AND SIDE-~CK. ED HOLE A.N'D ~L.N'Y O~ SIGNIFIC.A. NT ~]1~ IN HOLE CO~-DITIONS September 1975 Drove 30" conductor pipe to 54'. September 1, 1975, commenced operations at 5:00 A.M. Driltedl5" hole from 54' to 431'. Opened 15" hole to 26" from 54' to 431'. Cemented 20", 94#, H-40, buttress thread casing at 411' with 347 sacks of class "G" cement. Installed class .IIB BOPE and pressure tested Q~ under 400 psig. Drilled out cement from 394' to 411' and Cleaned out to 431'. Drilled 15" hole from 431' to 3400'. Ran DIL, sonic, Density- neutron logs. Cemented 10 3/4", 40.5~ K-55, buttress thread casing at 3376' with 1425 sacks of class "G" cement. Installed class III BOPE and pressure tested ok under 3000 psig. Drilled out cement from 3205' to 3376' and cleaned out to 3400'. Drilled 9 7/8" hole from 3400' to 700'. Ran D~L, sonic, density-neutron-GR and PML logs. Took sidewall samples. Cemented 7", 23#, S-95, buttress thread casing at 6509 with 720 sacks of class "G" cement, cp'd at 3892; with 388 sacks of class "G cement. Installed class III BOPE and tested ok under 3000 psig. Drilled out cement from 3880 - 3892', cleaned out to 6417!. Ran cement bond log. Perforated four 1/2" jet holes per foot from 5897' to 5912' and 5946 to 5968'. F.T. of perforations 5897 - 5968'. Open 3 hrs. 30 min. Good blow declining intermittant heads after 80 min. Intermittant heads for balance of test. Recovered 552' rise of mud in 3 1/2" drill pipe. Charts indicated partial plugging. 14. I hereby certify tha~, the foregoing is ~ / NOTE ---Reoort on this form is required for each calendar mantles regardleSS of the-~tatus of o~)erations, o.d must I~ filed in dupli~te with the oil and gas conservation committee bythe 15~ Of the sumc~diflg mn~. ~le~ ~thmrwimm directed. 41&8, 4196 · 4ZTG i- 42.87 4.~76 4540 .. .. 5175. ?:r~,... ~.I ~- ~oo . 5207 ..... 5461 ~.:~. ~.. 5480 · . - 57~7 5778 - I $79Z ' ~799 . . . 5830 : 5831 I I I I' · 5946 .. · K.B. TO TUBING RANGER ~2,OO3.54' ' · 4;050.22'-- 2~" x 2~" EUE X-over TUB~-:G tlANGER .... 2 JTS. 2~a" 6.5/; EUE 8rd N-80 TUBING 2 PUP J~'$. 2~" 6.'5,~ EUE ~rd N-80 T~. ' 2 J'~S. 2~" 6.5.~' EUE 8rd N-80 TUBING OTIS "S" NIP?~, Position ! OT~ "N" NIPP~ .60' '~ ~ J~. ~,..2.~,~ ~US ~or~ T~. Z~O.~, . . · - I a ·" ,. .- 4,O63-42' I¢ · ~g,~ "CC" SAFETY JT. ~ 4,O7h.~8, 1'__~ .- '2%, PUP 6.5.~ ZU~' 8rd ~-80 TU3ING .~,O81.26,__~ 2~', x 7" 29f ~KE~ "~t" PACKER . . 22 J~. '~"~Sf EUE 8rd )~-80 TUBR~G . . . ~ . .~'.. .. ' 4,772.29 ' --~ C~MCO PM MANDREL JT. 2~" 6.5// EUE 8rd N-80 TUBING 4,817.18' ~ BRO~ "CC'~ SAFETY JT. h,818.5~'~ OTIS "XA" ~ ~L~ OP~M 4,~21.76' 2~" x 7" 29~ BAKER "FH" PACKER ~ "S" NIPPLE, Fosition~2 PL~~ · 1.38' 63.%7' 7.20' 63.17' 1.~8' 3893.70' 3,00I lO.CO' 1.O~' 10.12' 6o68~ ~89.90' 13.O2' 31.65' .1.ho, 3.18' 6.68, 1.~' '5,39d.18'. 21 JTS. 2~" 6.~# £UE 8rd N-80 TUBING CAMCO "D" NIPPLE 'e BR LUG ~ 5~80' ' ;- 1 JT. 2%'% EUE ~rd N-80 TUBING · · · · · .. ., /. BR. PLUG o · TOP OF PLUG @ 6317, 'T.D. 7OOO,' , , 11 i Il BELUGA RIVER 212-I CA'SING TUBING DETAIL SECTION 18 T. I~N,,R. gW. STANDARD OIL COMPANY OF CALIFORNIA PerfOrations: Four 1/2 holes per foot: 5946' - 5968' '5897' - 5912' 5856' - 5853' 5842' - 5837' 5834' - 5830' 5814' - 5807' 5804' - 5799' 5792' - 5787' 5782' - 5778' 5774' - 5767' 5754' - 5747' 5746' - 5737' 5461' - 5480' 5367' - 5392' 5227' - 5238' 5207' - 5218' 5175' - 5200' 5133' - 5160' 5035' - 5055' 4980' - 5028' 4276' - 4287' 4196' - 4216' 4168' - 4190' Halliburton Formation Test: 1. 5897' - 5968' 2. 5737' - 5856' 3. 5~61' - 5480' 4. 5133' -.5238' 5. 4960' - 5028' Logs: Schlumberger Dual Induction Log Borehole Sonic Compensated'Neutron Formation Density Proximity Log Microlog Continuous Dipmeter Depth 412' ~- 7000' 412'-.6992' 411'-- 7000' 411' - 7000' 3372' - 6992' 3376' - 7000' Go International Gamma-Ray Neutron Cement Bond Log 3350' - 6407' 3350' - 6406' Chevron W.L.S. Dipmeter Quality Control Plot Dipmeter Dip and Azimuth Display (All picks) Dipmeter Dip and Azimuth Display (Selvec) Azimuth of dip vs depth · l~uns 3 2 2 2 1 1 Scale 2" - 5" 2" - 5" · 5t! 5'! 5!! 5!! 5!! 5" TRANSMITTAL ANff ~qOWLEDGEMENT OF RECEIPT OF I~,~'~IAL - (ALASKA) TO: .... Mr, T. R. Marshall ~ate of Alaska DgPT. :_ Division of O11 & Gas ~)01 Porcupine Drive PLACE: Anchorage, Alaska-99504 FD - Folded R - Roll. ed S - Sepia F - Film X - Xerox B - Bluetine THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMb~DIATE£,Y. WELL ttISTORY LOG 2" 5" I00 200 RECEIVED BY .... ~ ,:' / RE HER SLOE, THIS SHE[T ~/' 02-001B STATE of ALASKA FROM: O.K. Gilbre~h, Director D~v~slon of October 10, 1975 Division of Oil and Gas Pe~ro De~tol% '~ SUBJECT: BRU 212-18 Well Chief, Minerals Section In response to your memo of October 3, 1975, ~ are se~ you a copy of SOCAL's plan of operations ~n B~3 212-18. As you can see, Standard has provided for lining the reserve pit with an impervious membr~e, but has not provided for a fuel dike. Sin~e your A~ 19, 1975, memo, we have required ~pervi~ dikes around the TRANSMITTAL ACKNOWLEDGEMENT OF RECEIPT OF TERIAL - (ALASKA) Mr. T. R. Marshall TO: l~tate of Alaska Division of O{I & Gas DEPT.: 3001 Porcupine Drive Anchorage, Alaska 99504 PLACE: l"'i 'i,'~ iii~ ,,.'~ .... [! FD.- .Fplded i !.'~ ,({~J ""~,.~i~?J I.I R.'i' ~-, l~b'lled S - ~epia x~. - Xerox '~ ~ ' . B~ ~. Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPANY WELL HISTORY LOG 2" 5" ! I Imo0 m ~ O~ * , /"), REMARKS ON OTHER SIDE, THIS SHE'ET .ORANDUM o~vist~ of 0tl and TO: ~0. K. State ot Alaska DATE: FILE NO: TELEPHONE NO: SUBJECT: September 17. 1975 SOCAL Beluga Rtver 212-18 BOP Stack Test. u~ohn Hiller and ! de. fred our heees at 9:00/~t, Saturday. September 13, 1975, for a 9:30 PM departure b~ $OCAL cha~ered Era ftxed ~ng aircraft to Beluga alrstrip arr!v~ng at 9:55 PM.. Hr. Wtll Richards, SOCAL Drtll~ng Foreman. met us at the atrstrtp and checked us Into a roam at the camp advtstng we should exper a m~datght call ~ vrl~ss ~esttng procedures at the location. ~ call came at 5:40 AM. Sunday, Septe.ber 14. and we arrtved on locatton to flnd the. ~111ng crew pressuring the choke mantle-Id by pneumatic pmnp. ~e toured ~ l~tJoe and famed the well stgn In order, the reserve plt dtked and lJ~ wJth ptastlc slieet~ng and the fuel area dfked wtth a gravel berm. (Mr, Richards ~as puzzle~' as to ~hy the reserve plt was requtred to be 11ned but the fuel dtked area was not_.) General housekeeping was poor both on and adjacent to the pad and mater~al stockp~les ~ere. not organized. Testing.of the choke manifold ..~_~gan at 8:00 AM and the manual choke, remote controiled choke and all assoclated ~alves were tested to 3000 pstg. All com- ponents tested sat~sfactori!y except one gate valve ~htch could not be fteld repaJred. A replacement ~alYe was ordered from another rlg. , -~. The BOP stack and a11 assecJa~d valves were pressured to 3000 pstg by Ha il~burten and al l tests ~~sed on pressure recorder. The b11nd rams and all ass~jated v&lves except .~he ch~k valve tn the kill 11ne tested sattsfac- toriiy. Test of the pipe rams failed when a gate valve, tested smttsfactorf'ly in a previous test, fai'led and. COuld not be fteld repaired. A replacement check valve and gate val. ve were ordered by radto. '~' --1~hjle awatting replacement Valves we checked Ng.bottles on the accumulators and read pressures of t900,-I~, 1850, 2200, 2100 and 2150 pstg. Three of the .Ng bottles and an addJttonal acc~lator were manifolded Jnto the clostng system as back.up, The primary control system actuated all rams satisfactorily:. ~ The faulty choke manifold valv~;~as replaced and Ha111burten was connected to the oppostte stale of the stack threugh the choke manifold. The hydrtl was tested to 2100 ps~g and then opened. The etght tnch flowl.tne valve and rotattng BOP were then ~tested to 2000 psjg. Ftnally, the p~pe rams and recently replaced choke-manifold valve were- tested to 3000 psJg. Halliburton then coneected to the kel.ly saver sub and the lower kelly valve and upper kelly cock were tested to 3200 and 2.800 ps.~g respectively. The floor safety val~e was checked as were Jndlcator: l~ghts on the remote clostng panel. O. K. Gllbreth, ~lr. B. Le gorma~-Fteld Trfp ~.t SOCAL Beluga R~ver Page 2 September 17, 1975 A leaktag swivel precl~ any further tests on the rotary hose and stand- pipe system. The tests were-completed at 7:25 PM. A Field Inspection Report was prepared with a copy to Mr. Richards and a copy to Mr. Bt ll Sauer of SOCAL's Anchorage office indicating the following: 1. Check valve and gate valve in kill line must be replaced and tested to 3000 psig. 2. Swivel leak must be repaired. 3. On and off pad clean up must be Initiated. Mr. Richards was asked to call this office on September 15 regarding these matters. We departed Beluga airstrip on the same charter aircraft delivering the re- placement check add gate valves for the kill line at 7:45 PM, arriving in Anchorage at 8:15 PM and at our respective homes about g:O0 PM. Mr. Richards called John Miller at 8:1§ AM, September 15 from SOCAL's Beluga No. 212-18 reportteg the swivel had been repaired and the rotary hose, standpipe and standpipe ~lve tested successCully to 3000 pstg. The new check and gate valves were installed in the kit1 line and tested to 3000 pstg. In sUmmary, the BOP stack, choke manifold assembly and kelly to standpipe system on Kenat Orllltng Rig No. 1 was successfully tested to 3000 pstg in order to drill out from under ~ace on $OCAL's Beluga No. 212-18. 'i..~ '?" Alaska'~Oil and Gas Conservation _ -~ .; :~ - :~'-i. -?- ~ :~,:. Field Inspection Report '- -' -~ -~ Drilling Permit Operator ,.~O'C,~ / Well Name & No.~~ ~~tl-/~~ Number Inspected my ~ff~ /.~ ~.~-~Operator's Rep. ~'// ~/[~ ~_y Contr. Rig No. Satisfactory Yes () -60 I tern- No ( ) 1. Well Sign ( ) 2. Safety Valves-Floor Saris factory I rem ; Yes No ~ ( ) 11. Manifold Pressure Test (K) ( ) 12. BOP Pressure Test ( ) 3. Safety Valves-Kelly (X) ( )' .~13. Reserve Pit ( ) 4. Safety Valves-Subsurface ~ -( ) 14. Pit Berm ( ) 5. BOP Closing System ( )A/~,t-~( ) 15. Location Berm (~-) ( ) 6. Remote. Controls ~ t.~)~ .i~( )- 7. Drilling Spool-outle~ , (>0 (), 8. Flow Lines .' (Y$ ( ) 9. Kill Lines (X) ( ) 10. Manifold Chokes () () () 16. Fuel Berm 17. Operations off "Pad" 18. "General Housekeeping" 19. Abd. Marker in place 20. Water Well covered Submit "1 ntentions" in Trl 311cate ~"~"~ STATE OF ALASKA 5. APl NuMERIc'AL CODE OIL AND GAS CONSERVATION COMMITTEE 50-283-20049 6. LEASE DESIGNATION AND SEF SUNDRY NOTICES AND REPORTS ON WELLS ~': (DO not u, this form for proposals ,o drill or to deepen Use "APPLICATION FOR PERMIT~' for such proposals.) ~ 58~0 [' OIL ~ GA5 ~ 7. IF INDIAN, ALLOTTEE OR TRll WELL~ WELL OTHER ~ NAME OF OPERATOR S. UNIT, FARMER LEASE NAME Standard Oil Comply of California, WOI ~ ~DDRESSOFOPER~TOR 9. WELL NO. P. O. Box 7-839, ~chorage, Alaska 99510 BR 212-18 At su~ace 1799' from North line ~and 100' from West line Beluga River Field Section 18, T13N, R9W, SB&M [[. SEC.,T. R.. M.. (S~TTOM HOL Sec. 18, ~13N, R9W SM ...... 13. ~LEV~TIONS (Show whether DF, RT, GR, et~) 12. P[RMIT NO. D. F. 92.03' 75-34 CheCk Appropriate Box To Indicate Nature of Notice, Re ~ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF L---J PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Commence operations SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL fRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBEPROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent cletails, and give pertinent dates, Including estimated date of startingany proposed work. Beluga River 212-18 was spudded on September 1, 1975. SEP 9 i97 16. I hereby certify that the foregoing is true aj;~l coj'recV/~, R. M. McKinle¥,~F~~iTLE SIGNED (This space for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY: TITLE Area Enqineer DATE - DATE See Instructions On Reverse Side 4u1~ 15, 1975 Dear Sir: Encl~_ed is the approwd appllcat~n for permit to drill the above referenced welt at a lacat-~ in SecUon 18, Tewnship 13 It, Range g W, SM. ~1'1 samples, cow) chips, and a mud log are not required.. A directional survey is not requtre~l. Any rivers !n Alaska and the__t~:~ drat~ systems have been classified as '~ for tim ~tug or. ml.~tlon of anadrom~ ft~h. Operations in the~ ar~as are sub~.~t ~ AS 16,50.870 and ther~ regulations promulpted there- u~der {Tltle 5, gl~ ~nistratlve ~).. prtor to c.ommenct~ operetlons y~ wbe con**~:~ by t~.hbttat Coordlnat~'s office, l)~partm~nt of Ftsh Game. Pollutt~ of a~ waters of the State is prohibited by AS 46, Chapter 03. Attic.lc 7 and the.. regulati~ .promulgated thereunder (Title 18. Alaska Admtnls~ttve Code, Chapter 70) and by the Federal t4ater Po!1utton Control Act, as amende~. Prior to-commencing opet~ations you may be contacted by a rep.- resen~ve of th~ ~rtment of Environamntal Conservation. event, of suspeas~to~ or abandonment please give this office adequate a~ance not~ft~tion so that wee ay have a witness present. Enclosure cc: Department of Fish and ~, Habitat Section w/o encl. Department of Environmental Conservation w/o eric1, De~r~t of Labor, Supervisor, Labor Law Compliance Olviston w/o e~cl; . S~ Oil co. ~f C~LiEo~' P.O. ~ 7-~39 Ao~2x~ge, alaska 99510 ~ ref~ 1~ ~ati¢~l iS h~~ ap~ subjec~ to the 2. All op~rat, t~ areas ~~ bm ~ and upo~ comp~ of of ope~ations~ DIV~$10N OI~ 011. AND OAS ANCHORAGI~ Chevron Standard 0il Company of California, Western Operations, Inc. P.O. Box 7-839, Anchorage, Al<; 99510 · Phone (907) 279-9666 J. L. Rowland Area Supervisor Producing Department June 9, 1975 Peri, it to Drill Beluga River#212-18 Well state~OfAlaskaLease ADL-58820 'BelU~a.'River'Field, Alaska C. ENO Il 2 ENG 3 ENG ....... 4' q"'~ · 2 G ~ OL 3 CEOL REV DRAFf SEC CONFER: FILE: Mr. O. K. Gilbreth, Director Division:of Oil andGas Department of Natural ReSOurces 30'01 Porcupine Drive Anchorage,'Alaska 99504 Dear Mr. Gilbreth:' standard Oil Ccmpany of California, on behalf of itself, Atlantic Richfield Ccmpany and Shell Oil Ccmpany, proposes' to drill the'Subject well at a location as shown on the' attached' plat. ~ For your consideration and approval we Sutm~t, in triplicate',' state of Alaska Oil and Gas Conservation Cc~ittee form "perm~'t to Drill or DeePen", and our check in the amount of $100.00 together with copy of the Plan of Operation. As shown on the' attached .plat, the proposed well will be located on State lease ADL-58820, 1800' South and i00' East' of the Northwest Corner of Section 18, T. '.13 N., R. 9 W., S.M. The west boundary line of Section 18, is also the boundary line between leaSes ADL-58820 and ADL-5883i. Pursuant to Oil and Gas Conservation RegUlations and the applicable statutes of the State of Alaska, Standard Oil Cc~pany of California, as operator of State of Alaska Lease ADL-58820, hereby requests the Alaska Oil and Gas Conserva- tion committee to issue an order allowing exception to Title 11, Alaska Administra- tive Code, Section 22.055 to permit the drilling of subject well at the proposed location. Standard Oil Company, Atlantic Richfield Ccmpany and Shell Oil Cc~pany, each to an undivided' one-third interest, are the' sole ~X~rking interest owners in the lease to be drilled and are also the owners, in like proportions, of the working interest in state lease ADL-58831.' There 'are no other working interest owners or operators which would be' affected by the granting of the exception requested. DIV:SION OF OIL A~ GAS ANCHORAGE Mr. O. K. Gilbreth, Director Division of Oil and Gas -2- June 9, 1975 There are ~resently no wells ~leted or drilling on lease ADL-58820 or within the governmental section containing the Proposed location. If further data is required', please advise. Very truly yours, statet of Alaska ) Third Judicial District ) ss R. M. McKINIA~, being first duly sworn, upon oath deposes and says that he is Area Engineer, emPloyed by Standard Oil Ccmpany of California, and to the best of his knowledge and belief the facts stated herein and shown on the accompanying plat are true, and that the accompanying plat is drawn to scale and correCtly reflects l pertinent and required' data. R. M. McKINLEY Y Subscribed and sworn to before me this My cc~mission expires , 1975 cc: Atlantic Richfield Company Shell Oil Ccmpany ., DfV:SION OF OIL AND ANCHORAGE Porto I0-- 401 REV. I --I--71 · IA. ?YI~m 0F WOIK StrBM1T IN TRII- .~T~ (Other instructions on reverse side) STATE O,F ALASKA OIL AND GAS CONSERVATION ,COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL [] DEEPEN b. TYPIOr WBLL °'L Fq °'" I]1 WiLL WJL~ OJHJJ ~-ONJ ~.ON 2. NAME OF OPER. ATOR Ii API #50-283-20049 ~. L,F~W. SE D~IGNATION AJ~D S~IAL NO. ADL 58820 ?. IF INDIAN. A/j~-rr~:~. OR TRIBle NAME 8. UNIT FARM OR LEASE NAME 9. WELL NO. BR 212-18 10. FIELD AND POOL, OR WILDCAT Beluga River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Standard Oil Company of California, Western operations: 3. ADDRE,.~ (YF OPF_~TOR P. O. Box ?-839, Anchorage, Alaska 99510 4. LOCATION OF At surface f~%! South and 100' East .of the Northwest corner of · Section 18, T13N, R9W. Final survey will be supplied_at _a At proposed prod. zone latez date ~0N' South and 100' East. Qf. the No~thv~es.t coin.er of .Section 18 R9W, Fina% s~rvCy w~ D~_ .qim~.~ ~ ~ ,_~ 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OF-I~IC~~---- . Approximately 40 m~ les w~st of 14. BOND INFORM ATION: . S~c. 18, T13N~ R9W~ .S.M' TYPEStatewide Surety and/or No. 45163~ 15. DISTANCE FROM PROPOSED' 100' to lease line LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, ii any) 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR. 4000' + from BR 224-13 t16. NO. OF ACR~ IN ~EASE 889.92 19. PROPOSED D~'IH 7000' vertical ,100~000 . 17, NO, ACRES ASSIGNED TO THiS WELL 640 1~. R'oTARy OR CABLE 'TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, CH, etc.) 22. APPROX, DATE WORK WILL START* Ground, 70' + D.F. 90' + July 15~ 1975 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE'OF CASING WEIGHT-PER FOOT GRADE S~ING DEPTH quantity of cement · 26" ' 20" " 94~' ": ' H'40 400' 4_85 sacks , 15" 10 3/4'' 40.5~. ' K-55 3400' (~,~F.~; 1275 sacks 9 7/8" 7" 23~ , S-95 ' 7000~ ~'~< ~240 sacks , , ~ . .~ ~ program. DIV:SION OP OIL AND GA..5 ANCHORAGE IN ABOVE SPACE D~SCRIBE PROPOSED PROGRAM: If ~1 Is to dee~n give ~ on p~sent ~u~iv~ ~ ~d p~ ~w preclusive ~ne. I~~1 ~ ~ grill 0r ~n Q~to~lly, give ~ent ~' on'sgbSu~a~ ~t~ 've~ical dept. Gi~ blo~{ P~e~e~ter' p~am. S,~N~ ' ,~~~~,: .... ' ~-- ff-/[/ Area Engineer . , , , (This space for S~te office u~) J CONDI~ONS OF ~V~, 'IF A~' SAMPLES AND CORE CHIPS ~,DIRIEC~IONAL SURVEY ~ Y~S ~NO JMI~,D LO'G~ [] ~ NO A.P.I, ~CAL COD~ o o- Z$5- ZOo',Lq } I July 15, 1975 July 15, 1975 · -~- _ . PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING PROGRAM Field: Beluga River - Pr0per~y_and Well No.: Beluga River 212-18 Surface Location: To be determined upon inspection of area. Bottom Hole Location: Approximately 1800' South and ~00' East of the Northwest Corner of Section 18, T13N, R9W, SB&M. . Elevation: Estimated 70' Ground and 90' K.B. Blowout Prevention Considerations ~ 1' Potential~Problems: a. Gas: The proposed well is a step out location on the northerly plunge of a known gas field. Numerous gas sands are expected to be pene- trated during the course of'drilling this well to total depth. Gas entries into the mud column can cause serious problems. Care must be taken at all times to prevent these entries caused by either swabbing the well when pulling pipe or hydraulicing the formation, with associated lost circulation, on trips. Rapid penetration.rates cause an increase in mud weight and increase the risk of lost circulation and subsequent kicks. Penetration rates will be restricted. Coal beds at Beluga can cause serious problems. The beds contain some gas, slough readily, and drill rapidly. If thick beds are encountered, reduce the penetration rate and/or circulate bottoms up. b. Lost Circulation and Water Entries: -In well BRU 212-24 circulation was .lost using 70 pcf mud while the drill pipe was-stuck at 927'. From this depth to 3777' some loss in mud was noted. Mud weights varied from 70-75 pcf. No serious losses were recorded, but extreme care must be used in maintaining solids free mud with the properties outlined in the Drilling Fluids Program. Penetration rates will be limited to maintaining optimum drilling fluid properties. c. Precautions: Kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods. Care should be exercised at all times by every member of the crew. The hole must be kept full at all times. 2. Estimated Depths and Formation Pressures: I)IV:SION OF Oil. AN~ OAS ANCHOFIAO~ Proposal for Well Operations PRO 316-1 ~ ~'° - Drilling Program .~. ' . · ; ~ . · 2 · ,~ .o · '. '- ...:~::..-/.. · .:. ~.. -' . , · . ....: .... · -'=., ~ ."~.i '=--.. gone or Marker- Top Sterling "A" 3420' : · · TOp of Sterling "A2" 3470' .... Top Beluga River Formation .3870' TOp "Fl'' 4580 ' Total Depth ?000' Vertical Subsea _ Depth._ Depth 2 Est. Press. Gradient' Psi Psi/Ft. ., · · · · · -3330' 1610 .47 -3380' 1680 .47 -3780' 1860 .48 .. -4490' 2200 .48 -6910' 3430 .49 ~; MaximumAnticipated Surface Pressure: Based'on gas column to surface, 3000 psi. -. . 4. Blowout Prevention Equipment: a.' 20" - 2000 ~si, ~lass IIB on 20" casing. . b. 12" - 3000 psi, ClaEs III and Shaffer Rotating Blowout Preventer · . on the 10 3/4". c. 10" - 3000 psi, Class III on 7" ca~ing- - 5. Objectives: Sterling and Beluga River Formations. .- · . -' ' _ -=. .. PROGRAM . . · - 1.- Drive 30" conductor pipe 60' to 80' below cellar floor. 2. Drill for 20" casing to 400'+. Maintain drilling fuilds per attached -Drilling Fluid Program. · · o 3. Cement 20", 94~/ft., H-40 Buttress casing at 400' with 485 sacks of Class "G" cement premixed with 2.4% Gel, by weight of water. This .provides a 50% excess cement volume. If cement does not return to the surfa.ce, do a top job through a 1" pipe at 90'+. · a. Cement-Gel Properties: '"" ' Yield: 1.86 cu. ft. slurry per sack cement Slurry Weight: 97-98 pcf Water Required: I. 38 cu. ft. per sack cement · .. ' Gel Required: 1.5~ per cu. ft. water b. Use a duplex shoe with stab-in connector. ~.. Bakerlock or weld casing to shoe. d. Centralize casing over the entire 400'. 2 - - DIV:SlON C;,}: OIL AND GAS .- A~CHORAC~E '- 4. Install Class IIB BOPE on the 20" casing per attachment. Nipple up blow and kill lines, and manifold for 3000 psi service. Class III, .12" - 3000 psi BOPE with Shaffer Rotating Blowout Preventer will be · Anstalled later. Test BOPE per Operating Instructions Q-17. No~e: Burst pressure for 20", 94~/ft., H-40 casing is 1530 psi with -- no safety factor· Do not exceed a 400 psi test· · · i&e' '.~ Proposal for Well operations PRO 316-1 Drilling Program _ 5. Drill out cement and shoe of' 20" casing. Directionally drill ahead in '15" hole .to a dull bit near 3.37'5'. '"Condition mud and hole for logging. 3 Note: a. Limit penetration rates as necessary to maintain optimum drilling fluid weight and solids content. b. Install Mud Logging Unit at the shoe of the 20" casing and retain to total depth. Specific instructions will be provided to the Mudloggers under, separate cover. 6. Run and tape the following logs. Ail logs are to be run from total depth to the shoe of the 20" casing. Take a 1/2 gallon sample of drilling fluid immediately prior to pulling drill pipe for logging. Dual Induction - Laterolog: 2" = 100' - Arithmetic, 0-50 ohm-meters resistivity and +10 mv SP scale. '5" = 100' - Logarithmic, 0.2-2000 ohm-meters resistivity and +_10 my SP scale. b. Combination Compensated Neutron-Density Log: Density scale 2.0 to 3.0 grams/cc. Neutron scale 0 to +60 sand- stone porosity units. Gamma-ray and caliper curves to be recorded in the left-hand track. c. Borehole Compensated Sonic .Log with Integrator: . Use 50 to 150 microseconds transit t/me. d. Have on location a Proximity Log, Dipmeter tool, and sidewall sample gun. 7. Drill ahead in ~5" hole to top of the gas productive Sterling sands, depth equivalent to 3340' in well BR 224-13. · Repeat logs if necessary. ~;-, 8. Cement approximately 3400' of 10 3/4",40.5# K-5~_~&C~)casing, in the shale section immediate~above the uppermcst productive Sterling sands, with ~275 sacks Class "G" cement premixed with 2.4% Gel, by weight of water. Bring cement up to 1000'+. Calculate required cement volume base~--6~-~lper log and d~-~n°t use any excess. a.- Cement properties as same as Step 3a. · . b. Use a 'float shoe and du~.lex collar with stab-in connector. ' ~. Install Halliburton "FO" cementing collar at 800'+. ~. Bakerlock the bottom five casing joints. ~~[~rE~l, ~ ~ e. ~se centralizers at and above the casing shoe ~ ~n the 20" casing. -~' · . DIVISION OF OIL AND OAS ANCHOI%~G~. ,I Proposal for Well Operations PRO 316-1 Drilling Program 9..Cut off the 10 3/4" casing to allow top of tubing head to be above ground level upon completion. Install 10 3/4", 12" - 3000 psi top flange, SOW casing head. Test welds to 3000 psi. 10. Install 12" - 3000 psi Class III BOPE including a Shaffer Rotating Blowout Preventer per attachment and Operating Instructions D-17. Connect blow and kill lines. Pressure test all BOPE to rated pres- sures per Operating Instructions D-17. 11. Drill out cement in 10 3/4" casing to within 10' of float shoe. Run Variable Density Cement Bond Log fr6m effective depth to the 20" casing shoe. Make shut-off tests as required. Pressure test 10 3/4" casing to 3000 psi. ' · 12. D_~ut cement and shoe, and drill ahead in '~9 7/8"' hole to 300' below the lowermost gas shows or to dull bit near 70.00'. Condition mud and hole for logging. a. consideration will ~e given to spot coring selective intervals in the Sterling and Beluga River sands. b. Limit penetration rates as necessary to maintain Optimum drill- ing fluid weight and solids content. Circulate out drilling breaks or reduce penetration rate as directed by the Standard Oil Company Drilling Representative. 13, Run and tape the following logs at the effective depth. Ail logs are to be run from the total depth to the shoe of the 10 3/4" casing. Take a 1/2 gallon sample of drilling fluid immediately p~ior to pulling drill pipe for logging. a. Dual Induction - Laterolog: Same scales as Step 6a. b. Combination Compensated Neutron-DensitY Log: Same scales as in Step 6b. c. Borehole Compensated Sonic Log with Integrator: Use 50 to 150 microseconds transit time. Caliper and SP curves are to be recorded in the left-hand track. SP to have +10 my scale. d. Proximity Log - Microlog with Caliper: Use logarithmic resis- tivity scale of 0.2 to 2000 ohm-meters; micro normal 2", 0-20 ohm-meters; and micro inverse 1" x 1", 0-20 ohm-meters. e. Run four arm HR dipmeter and record using both analog and magnetic tape. f. Be prepared to take sidewall samples. 14. Set bridge plug on wireline at + 1000'. Open Halliburton "FO" cementing collar at 800'+, and cement 10 3/4" casing until suffici- ent returns are noted at the surface. Use Class "G" cement premixed with 2.4% Gel by weight of water. Slurry proper~~i~ ~T~ ANCHOI~AGI~ Proposal for Well Operations PRO 316-1 Drilling Program .5 15. Drill o~t cement below "FO" collar. Pressure test casing Do not -exceed 500 psi surface pressure. Drill out remaining cement and bridge plug. 16. Cement approximately 7000' of 7", 23#, S-95 _ - Buttress casing on bottom in two stages as follows: a. Use "flo~t shoe and float collar. Run one stage collar and place near the base of tke Sterling sand. b. Bakerlock the bottom five casing joints. c. Centralize the casing throughout the productive intervals. d. Cement the 7" casing in two stages as follows: 1) Stage 1 through the shoe using 7~ sacks Class G neat cement. Use no excess. Fill calculated from 7~00' to 3800'. 2) Stage 2 through stage collar near 3800' with 400 sacks Class G cement. Fill calculated to the 10 3/4" shoe plus 1000' into the 19 3/4" x .7" casing annulus and includes 3'3% excess cement o~ the open hole portion. 17. Land the · 7" casing. Install 12" - 3000 psi x 10" - 3000 psi tubing head and secondary seal assembly. Test secondary seal to 3000 psi. 18. Install 10" - 3000 psi Class III BOPE. Install kill and blow lines per attachment. Test BOPE per Operating Instructions D-17. Test lines to 3000 psi. ! 19. Drill out cement at stage collar and clean out to top of float collar. Run Variable Density Cement Bond Log from effective depth to shoe of 10 3/4" casing. Establish segregation points as required by squeeze c.ementing. 20. Test, perforating, and completiOn program will be provided after the total depth logs have been run. Note: It is planned to complete the well without perforating or running tubing. APR 2 2 '~'5 RMM W. A. Brommelsiek DIV:SIOIq Ol: OIL AND OAS ANCHORAG~ 'L · .. DRILLING FLUID PROGRAM ~ - BELUGA RIVER ~.~-I8 _'_ BELUGA RIVER FIELD Basic System Lightly treated Lignosulfonate mud. Optimum Properties Weight, pcf Viscosity, seC/qt., API Fluid lOss, cc, API Plastic Viscosity, CPS Yield Point, lb./100 ft.2 Gel, lb./100 ft.2-10 min. Calcium, ppm Solids Content, % volume Diesel Oil, % CONFIDENTIAL Value Range To 13 3/8" 13 3/8" Csg. CS~- Point Pt. to T.D. 73-76 40-50 20+ . -- 76-80 ' 40-45 4-6 10-15 5-10 10 max. 8.5-9.0 50 max. 8-10 4-7 Remarks: Chemically disperse mud with chrome lignosulfonate. Treat calcium out as required. Maintain adequate supply of lost circulation material and barite at the location. Run desander and desilter to keep solids at a minimum while drilling. Increase viscosity while drilling surface hole as required to control gravel. Limit dry jobs to 10 sacks of barite or as directed by Drill- lng Foreman. , , DIV:$10i,.I Ol'~ Oil, AN~ GA5 ANCHORAG~ --" , " : PROP'0SAL FOR WEL ?PERATi0P $ PRO-316 A (TO B. SED AS A G0-111) " CASI[ JG REQUIREI%IENTS AND PRODUCING EQUIPIVIENT WELL/LOCATION NO. Beluga River 212-18 FI'ELD Beluqa River TOTAL.DEPTH 7000 METHOD OF PRODUCTION ~EST!MATED O/W/G / /__ EQUIP. FOR STEAM CASING Gross Footage APl Size .Weight Conductor 400 ' 20" 94# Grade H-40 ~ DATE April 15, 1975 -- - ESTIMATED SPUD DATE. July 15o 1975 - MAX. ESTIMATED SURF. PRESSURE 3000 INJ. PRODUCER Threads Coupling Computer Design For: Butt This Well Standard Design For Field Well No. Max. Drift Angle Surface PSI ': .E] 0 3400' 10 3/4" 40.5# K-55 8RD LT & C ' " Water String: Design based on mud density 76 lbs./cu, ft. and above max. surf. pressur~ 7.000 ' 7" 23# S-95 Butt Stored in Alaska Cementing Accessories Conductor: Duplex Shoe (Stab In) 10 ea. 20" x 26" centralizers S~rface: Float shoe, Duplex collar (stab in), Halliburton "FO" cementing collar, 20 ea. 10 3/4"'x 15" centralizers · Water String: Float shoe, float collar, stage collar, 25 7" x 9 7/8" centralizers Pe'rfo~rated ,, (NO~oe: All f, loat eqU~e~h,t~o be bu~,ss) Slots, Centers,'__ DASING } 3000 10 3/4" UNITIZED HEAD' .. PSi CWP. Bottom Conn. Top Conn. 12" 3000 psi ,,, 'Fittings 1 - 3000 psi valve with blind flange, 1 - flange with bull plug MC MUC outlets CASING SPOOL ~UBING HEAD .I'UBING Bottom Next Fubing Catcher ~acker 3000psi 'PSI CWP. Bottom Conn. Top Conn. I0" - 3000' psi Type Suspension 7" secondary pack-off 12" 3000 psi 2 - 2 " .... flanged outlets .Feet APl Size Weight Grade Threads Type Remarks (Cross-overs, etc.) To be supplied when well is completed for production. Tbg. Bonnt 10", 3000 psi x 2 1/2" 5000 psi-w/ 2 7/8" bottom bowl & 1/2" L.P. test port. Tbg. Hanger 10 3/4" x 2 7/8" - 2 7/8" 8RD EUE threads . Tbg. Plug 2 1/2" Valve 2 1/2" 5000 psi~ f~.anged " type. t.,sg.~ze " with XMAS TREE __ Tubing Beans Header Stuffing Box )UMP: RODS: Grade__, PUMPING UNIT. AP1 Size Engine __ Arm #-wt. Arm 'of . f' " Type Motor Wt. Install at Type with ' "stroke at Other Fittings PS! CWP. Dwg. No. Type " PSI CWP. Dwg. No. Type. Polished Rod _ Type at HP Max. Stroke "Set at Remarks Type "x ' Long "Stroke and SPM ~repare(! By ~AB 4-17-75 Area Supervisor Approved by Drlg. Supt. PRO-316-A DIV:$1ON O~ OIL.A~) ' ' ;-'' '~ ,..' · .; ,. . ~ ~.' "" : · ','-', '. ....... ;~,, '.: .~ · 'I,/ .; '~"~".~'~ ~', ~ ' '~ I I . ,, .'.. :.~, :' ~ ,'.~.... ,? ':.:.,...' :. ' ~',-,.~.,~'~ v'..,.:.~':. ~.,., .'.~,.. ~"/~,, .,,. ? ~ ,..-. . ~',.. , .,-~. , , , ,. ;'"' :';~ ;~'-':--' .'~.';': ~ ' 'SHAg~ER' ROTATING 'nn~k'"'~::~:':,':.'.~:'/' :?', :"1:,':' ~...',".". ':' '~:: ;':".:.';.~.:?":'?.:;~,::.':'.::;,'.;:;?¢;.:~'-':(i~'~..-~.~.:.';(-..:. ,'.~,.: :' .~. ,.~.- ,.:': "."--.~" .~-. · ~,, ' - . ~ · ' i i - - . ~ ~ / ~ .'~e ,~ · -~ '. ' -.' ' '. '. i i ' ' ~ ~, t ...' ' ~ .,-., - . ' ,. ' -',e . .. ~-. , ,- · ~,. ~, :. ~..-. . # . ~ .... .~. ,~ ,,~ ..'. ,. , ,. . ,. ,. ~..~ ,. · ~ '~ . ...-. · / '~, '"' ,i '.-".'-'.~' ! I .' AND STRIPPER 1~..3000.n'Sl..'~..,:.'.:.,':~:~.,.,'. ,~... I I , : .... ":~'.',~. "-..; ..: '"~ ~'":.'.-. : .: ..... ".' '; '"=~ '.',,.'.:" ".. ~... :" ...a' .... ~. ..-' ,. :~'...,., ~o L~ ~-4~ .... ,"~ ':. ' .... . "',.'....~.,.'.,'.':.~,.,:'..~.: .~ .',:,",~ .... .'-'.' ' ,~'.. ~:',.-,~ ;,, " ,.. ~,,L ~ ~ ~ ,' .,' " .~''..'."... ~.'~ '~;. ~ · .' .~ '~' .~ .'.'.~'~'~ ?:~,.." 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'.'." . - --I ----~ ..... ~"'1 ~:.:X'.':. ~??."-' ~.'.. · -. ; Il .J ~ . ~. '...' ~..,:;:?, .'..,;.~.t., ...;: ..... <'. ..... , I I I . , . - :~ "- :'~.~ '.~...-:?,... ,, .... ' ' ~''- '~:/-- . .,,,...:_.:.... :.:.:-':...,......-, ..... ,, ,.., ........ ..- - . - . ~ . - ...~ :~ . , ', .'.-¥ , ..' . ~ . ,' ~ - . ~ ,- · ' '. ' .: . ~ ' . ','.. ' ' ~i": ~ .. ~" ·.., .' /' ~ ~ - - ' .~' ~ ' '" '~ ' '~ ~ ' ~ :+., . ~. ... :'.-..,: .?' ......:..~..?~.:. :..--.:?..::. ~. · ... - .~.. ..,. J · . ,. .... ~.-~ .... ;....,...,-.~,~..,;....~,. , ~. . . - ~', ,-· I. , ~.~ .;'~. . *:..~., "..'~ ~.~,(:' *' '~." " . . ' ... '~ , ..' '+ ~,~ ..~.'~ .. ' .- .. ;.~ .r ..... , '. · 'r .. '~ ,.. T..~ . · .... , . . 4~ .... ',, ,.' ,'.,..,.~ ,(.., .~t ,~,,,"v~l,~,-.~,, .... ) .... . ~, ~ ,...,, . ~. .~ ..... t..; =. , ,,, .. : '"'"'- ,'CLASSB " '"' ' ' 0 p . ,,,."= ,~ .., ...~...,,,...~ ¢-- .~,~ . ... - - · '-~':,' .-,.~.,?~.,. ij .,...~..;'; .. h ~ .-. · ., .:.. .~..,,., .... ,.....-.:,~ ~- · <--. , . ~ .. ,.., . .' , .-' . .. . . . . . . p . .. . · . · .... .. .. ;': · . -.. · ~ ,. -"~ . .: .. ..... · . . -. . "'" ' LO :T. '"'" '"""" ' ' .-...:. .-.,. . ..-. .. , ..... . ...._ .. BOPE..... · DETAIL'. ,,:"'FOR". ,.. E .. G~ RIVE~ ~ IZ-18 -8oe.- 18.. 13~', R.¢ W.' $:M. '..' .-; ~ ~'-..:-. '- . - : -~-. ·. ~ "~.~:'.' :,.~ .... · .... ,'.~'.: ~ . : ' .. .' ~ ~ . · . . ,-. ........ _' ~.~..:,~.;,: ,-. PLAN OF OPERATION '.. '""- , . :._....-._ -'.-' BELUGA RIVER WELL 212-18 . _. .. ': ~ '.. ': "' "''~ BELUGA RIVER AREA, ALASKA - '~ ~ ~: .J.'* '"':'- "'..~ ~. '....,: ·' ~'i:.~-' -. ~ ' Wel! Site and ~ettin~ "i~,~'!:i-"~iiI~.'''''''''' :,i':.:"i::i'ii;~;"I, '' The ~roposed location for well 212-18 is ,approximately 1800' south an~ 100~ east of the NW corner of Section 18, T13N, Rgw, SB & M. A new permanent gravel pad will have to be constructed at the pro- ~x)sed site. About 2'.to 3' of tundra covers the underlying gravel, and this will be cleared in the area of the site including the mud waste pit. Excavation material from the pit will be used for a por- t,on of the location gravel. Additional gravel will be needed for the pad and will be needed to build approximately 4000' of a new ac~ess road from an existing road. This gravel will be removed from a mew borrow pit to be developed with the approval of State of Alaska, Division of Lands. It is estimated that a total of 15,000 cubic yar~s of new gravel will be required for pad and road construction. Al~J)lications for gravel permits will be submitted as soon as a suit- alm~e borrow pit is located. %....~ . . The~proposed access road will be constructed in an existing cleared seismic trail. Additional side clearing to approximately forty feet wide is required to permit road construction. The drill site is located in a forested area. Cleared trees and brush will be stock- piled and disposed of in the sump at the time of cleanup. . 2. Existing Roads and Airstrip "' ........ "~" · All .roads in this area from the Superior Landing to the south to the :- '-. Beluga River Bridge to the north were built in the 1962-1965 era by Standard Oil Company of California as operator for the Beluga River Thait as well as during the course of other exploratory activity. The ~roposed 4000' access road to the proposed BR 212-18 location wi]/ be a spur road from one built during 1965. · 'The Beluga River Airstrip will be used in support of the proposed drilling operations at BR 212-18. .. . -. 3. Water Supply . A new water source well will be drilled at the location to support the drilling operations. 4. _Dr. ~lling Rig We ]~lan to use the Kenai Drilling Company Rig No. 1 to drill the pro- ~osed well. We anticipate moving to BR 212-18 during the first half of July and after completing drilling operations at Ivan River Unit DIV:$1ON OF OIL AND GA~ ANCHOR'AGt~ Beluga River Well 212-18 ~ ~- - Beluga River Area, Alaska 5. Access to Site' and Method of Supply' -~ ~e site is r~ote and is not connected to the Anchorage area by road. ..... '~' ~e only access is by one of more of the following: A. B~GING TO ~E S~E~OR ~NDING (STATE ~SE~D A~A ADL-45327) ................ ~ing most of the year, ~rging is possible from the Kenai or ~chorage area to 'the Superior Landing and thence by truck to :~.~ > ~..~--~ the pro~sed wellsite. Use of this l~ding will definitely be re~ired to drill the pro~sed well. Most all of the materials ........... ~ .............. and supplies re~ired to drill this well will have to be barged ~ to the Superior L~ding. 7~"}':.:.'.-,}'>:}:.'}::'~'~ :':'.~. The Beluga Airstrip can handle Hercules-type airplanes, ~d we ~ntend using this method to move. freight and other it,s as c~ be justified economically, in addition to barging. S~nce the rig uses diesel fuel, we.will probably fly in the fuel. Sufficient hard tankage is available to eliminate con- sideration of "bladder" tanks. The rig location will be graded so that any fuel leakage will be conducted to the waste pit. .~ :. ... .._ A 50,000 gallon fuel dump is established at the Beluga Airstrip ~i'~' ;.~ ~..~-.:-~-?' '- ~ ". ' ~' at the same location as existing facilities installed in 1962. . . ~' .- . ' These tanks are installed in a diked area which will contain any ~ fuel spillage or leakage. ---..-! -~ .. 6. Personnel Support ' '- A camp-capable of housing and feeding approximately 40 men has been installed in an area adjacent to the existing airstrip and will be o%1r base of operations. Personnel-will be flown in and out on a scheduled basis of approximately 10 days working and 5 days off. Food and other supplies will be flown in on an "as needed" basis. Sanitation facilities for the camp, consisting of a septic tank and two leach pits, have been constructed with the approval of the ATlchorage Office of the Department of Environmental Conservation. A water well, drilled and biologically tested during 1974, is in use at the camp. In addition to the camp, a house trailer has been installed for Standard Oil Company supervisory personnel. DIV:51ON C~I': OIL AND ANCHORAG~ . . Plan of Operations - :. BelugaRiver Well 212-18 Beluga River J~'ea, Alaska · · · . .~.:~ ~ :. 7. F~.scellaneous Related Drilling Items -- : :'""": .. ".' ... ' ..... ::'::.~'..~:~-.':: .~"-A. The waste pit will be lin~ with an ~pervious membrane and ~'-'-:":~:::"' .... ::" ';~'"'~' diked as necessary to prevent the ~ssibility of any seepage - : '" '"" '~ "-'" :~'" to ~he surrounding terrain or drainages U~n completion of ::' '. ;::..:./":-:':','~::-...-drillin~ activities, the waste pit will be filled, leveled, :~':'::~-:':~-.~.':-'..:'_ ':"- and the area rehabilitated as necessary .......... ,.- . -:. : . .: ..... -. ...- ...... ~ .~ .... · . B." Sanitary facilities at the rig location will be ch~ical toilets. ......... ':. - :: These toilets will be ~pt'ied periodically and the material '' ' -::"-.:-.:':; ~'--::~. -~-~:':-':~:~: ::--hauled and d~ped into the c~p septic tank. · ........ ~_'/~¥~-:"~'~,:'~3-..:~:~C~:_ ~.: ~e pro~sed locaeion is approx~atel7 1000' from the Beluga' '"--'~ :'~'- ::' '"'- ........ ~ver anti 400' from. tho.bluff ovorlookin~ Cook Inlet. ~r pro- ' :-"? (.~"-'~-~:?-~' ..... -~ '- ~sefl flrillin~ operations shoulfl cause rain.al disturbance .-:: . -.. : ~s area . .' ._ .: ._...~ ./.:..~..'?/.:-...-..'. .- _ ... .-,.' ,- : .... . . .-. ,-"~ .,.-.' ; '.'~c.,7',"': _ -. ' :. 8. ~er Cons~uction on the Site - --'~';-:~ ...... ": ":-::. "~ :" :':::: '~ ~ :' ' ..... '~-'-'"' ' . Well BR 212-18 is a development location, and Commercial production s]~3uld be encountered. This well is being drilled to aid in the determination of the field reserves and productive limits. There is no immediate market for the gas volUmes expected because our existing m~.]_ls to the south have the capacity to supply our contractual requirements to Chugach Electric Association. Accordingly, produc- tion facilities will not be immediately installed. When they are ii,stalled, the production, dehydration,, and.metering facilities on- site will be similar to those already installed for six existing - l~roducers, The existing gas gathering system will be extended north- %ra~d in the future to receive production from the proposed well. .. -' ._9. General Comments . , , . : - . ~ ..-;.'~., . "..' a; S~rface disturbances will be kept to a minimum, and no unneces- _ _ ..~ .... - ...... sary surface digging will be allowed. In the past we have restored construction areas and taken measures to encourage ..: .-'~'-' native vegetation. Regrowth in the Beluga Area is rapid and · · . .. '- does not appear from past experience to require much help .... except fertilizer. · '' B. Solid wastes such as mud sacks, kitchen waste, etc., will be . -. hauled to the central waste pit near the airstrip and buried, .. ' - while other hard wastes, such as drilling bits, etc., will be disposed of in the waste pit when it is closed and covered after drilling is finished. :" .... '-:." Attachment - Beluga River Area Map DlVlSlON OF OIL AN-ID ANC:HOI~AG~. ..=. J . . .. _ ..:.. G'A., RIVER 14-19 I · . I '. BELUGA RIVER UNIT AREA PROPOSED B.R. 212-18 ..j 'SHOWING LOCATION AND L[:ASES IH ..,, AROUND SECTION 15, T. 13N.,RIOW. S.M.! . ~ STAIqDA"D OIL,~OI~PANY oF CAI~IFo~IA TRANsMIZTAL AN[/ ~KNOWLEDGEMENT OF RECEIPT OF bi ~ixn- (AnASr, A) DEPT.: PLACE :_ DATE THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. ~~, c~, FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND'ADVISE IMMEDIATELY. COMPANY WELL HISTORY LOG 2" 5" ! ! ~ . ~ _. ~OO 200 ~O .~lod " " " " -- e4-9 cf_ (5~J~.. Il OIL AND GAS RECEIVED REMARKS O~'/OTI-iEF~ 5tOE, THIS SHEET :: ~tELL SURVEY Pro-312 BRU 221-18 COUNTY OF CITY OF 18 .TOYNSHIP 13N RANGE 9N r-~ s.e.~, & ,, LOT NO. FI ELi} Be1 uga Ri ver WELL NO., SECTION NO. TRACT NO. E~ PROPOSED I:::::] PRELININARY 1::3 FINAL [:3H.D.B. & H. IJOCAT I ON 1,182 feet southerly at right.angle from north boundary of Sec. 18, and 611 feet easterly at right angle from west boundary of Sec. 18, T13N, Rgw, Seward Heridian ELEVATION: OROU#Q CONCRETE HAT DERRICK FLOOR ........ &,L, .T E' I~ N A T:E 0 R $ U R"V E Y £..D L 0 C'A T I O'N LOCAT I Off ' , DESpGNATi. ON LOCATION cOoRDINATES HOVE REHARK$ ProPosed x = 329,3]8.2 y = 2,639,639'.5 , , ,,, ,, ......... _ .... · , , · NORTH I I =~_~___~ + .... I Sec 18 I ! ' 8011111 SKETCH OR REt4ARK$ Coordinates are Alaska State Plane, Zone .4. ....... STATION BE:ARI~ ," i)IST~IIC"E' SINE COSINE NORTH ~OUTH Irk$T' ' WEST I I I...... ; , · .............. C.C. DIV. ENGR. l~'I,~ ,3 () FILE SURVEYOR G. D. Drasky #AINT. FRNN. NAINT. SUPT. DATE April 28, 1975 DATE I~ION OF OIL AND --- ~, ~,- . ~ ' · "'"' """-'- ~h:g~h q ,~ 2~O-CD. I. 58 ) L CHECK LIST FOR NEW WELL PERMITS Company Yes No 1. Is the permit fee attached ..................... ./~¢. ~K 2. Is well to be located in a defined pool .............. 3, Is a registered survey plat attached ................ 4. Is well located proper distance from property line . o , ° ..... 5. Is well located proper distance from other wells .......... ~/m]< 6. Is sufficient undedicated acreage available in this pool ...... ~ 7. Is well to be deviated ....................... 8. Is operator the only affected party .- ............... /¢¢a~ 9. Can permit be approved before ten-day wait ............. 10. Does operator have a bond in force ................. ~4~Z: 11. Is a conservation order needed ................... ~ 12, Is administrative approval needed ................. 13, Is conductor string pro.vided ..................... 14. Is enough cement used to circulate on conductor and surface .... !5. 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 & burst 19. Does BOPE have sufficient pressure rating ............. · ~dditional Requirements: CL~ ~(~ ~ /~ /.!~//.~r ~T~ :. ,, ,? Approval Recommended' Geology. Engineering' TRM~ HWK OKG HHH/~. -~ .~', JCM JAL ~ LCS ...~_~- -- , Revised 1/15/75 B C D E F G It. ICL/x-/E- +1 WELLHEAD BLDG. 12'x 14' 150'+ ADDED PIPING '-SCH 80 GAS PRODUCTION 2"-SCH 80 OIL RETURN 2"-SCH 80 OIL SUPPLY I" -SCH 80 INSTRUMENT GAS 1"- ELECTRIC CONDUIT 3 TUBE MULTITUBE HEATER BLDG. 20'x26' 20'._+ , 4'L SCH40 OIL SUPPLY 2"-SCH 80 OIL RETURN I"-SCH80 DEHY WASTE LINE 3 TUBE MULTITUBE 12' x 24' DR Z).,,~. ,". CH ....... DR APP. ~_.~'/z:,'/_ ~,."'Z~, _ ENGR. /,<.,Z ,'~'/.~'. OPR'G. DEPT. APPROVED ENG'R. DEPT. SCALE GEN. BLDG. 20'x -I" ELECTRIC CONDUITS I" SCH. 80 FUEL GAS 4" SCH. 40 OIL SUPPLY 2"SCH. 80 OIL RETURN 4"SCH. 40 GAS LINE I" SCH. 80 FUEL GAS I" SCH 80 GLYCOL SUPPLY I" SCH 80 GLYCOL RETURN I" ELECTRICAL CONDUIT 3 TUBE MULTITUBE DEHYDRATOR BLDG. -- DATE 4" PIPELINE TO MAIN LINE BELUGA RIVER WELL 212 LOCATION LAYOUT FOR PRODUCTION FACILITIES W.O. Printed in U.S.A. AP-B-556-1 G O- 580.. E~ 1~ (CD-4..71~
