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Home My WebLink About162-001 • • LOF 7.4 0,1.„1,yy-sv THE STATE Alaska Oil and Gas ofALASKA Conservation Commission 244 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS¢' Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager N � Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99501 Re: Swanson River Field, Tyonek Gas Pool, SCU 243-08 Permit to Drill Number: 162-001 Sundry Number: 318-144 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this Jday of April, 2018. 5 � A,R � 1018 RBpMS 1` • RE'CEIVED 0 2018 STATE OF ALASKA 1 R/3 ( t Z ALASKA OIL AND GAS CONSERVATION COMMISSION 0C APPLICATION FOR SUNDRY APPROVALS AO GCC AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other:Install Cap String/Inj Methanol Q. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q• 162-001 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-10122-00 - 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 11No ❑� Soldotna Creek Unit(SCU)243-08 9. Property Designation(Lease Number): 10. Field/Pool(s): FEDA028996 . Swanson River/Tyonek Gas • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6,143' ` 6,143' • 5,875' 5,875' 2,670 psi 5,875' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 20" 29' 29' Surface 1,858' 9-5/8" 1,858' 1,858' 5,750psi 3,090psi Production 1,854' 7" 1,854' 1,854' 6,340psi 3,830psi Production 4,286' 5-1/2" 6,104' 6,104' 9,190psi 8,830psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-3/8" 4.7#/L-80 5,511' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Brown HS-16-1 Pkr;N/A 5,578'MD/5,578'TVD;N/A 12.Attachments: Proposal Summary 2 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development ❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: April 24,2018 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS Q • WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramert hilcorp.com /� Contact Phone: 777-8420 Authorized Signature: i Date: Yff//7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31'3- 1 LI '4 Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No 0 )�,T)Q Q 5 St Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /a •- V0 L( MOM 664 • APPROVED BY q 1-3i Approved by: COMMISSIONER THE COMMISSION Date: Y -�7e2Y ORIGINAL .�w,,,,,,,,-0 1,..z,./0..., Submit Form and d. ,,\4.0 Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • Well Prognosis Well: SCU 243-08 Hileorp Alaska,LU Date:04/02/2018 Well Name: SCU 243-08 API Number: 50-133-10122-00 Current Status: Flowing Gas Well Leg: N/A Estimated Start Date: April 24, 2018 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 162-001 First Call Engineer: Ted Kramer (907) 777-8420(0) (985) 867-0665 (M) Second Call Engineer: Taylor Nasse (907)777-8354 (0) (907) 227-5293 (M) AFE Number: Current Surface Pressure: 2,670 psi (SI) Current BHP: —3,244 psi @ 5,740' TVD (Calc'd using a 0.1 pressure grad.) Maximum Expected BHP: — 3,244 psi @ 5,740' TVD (Calc'd using a 0.1 pressure grad.) Max. Potential Surface Pressure: —2,670 psi (Assumed 0.10 psi/ft gas gradient) Brief Well Summary SCU 243-08 Recently had a bridge cleared and a 1.25"velocity string removed in February 2018. Since then the well has been brought on line at various rates(2MMSCFD—3 MMSCFD) in order to establish production. Hydrates have been observed when starting the well and freezing off at the well head has been observed. The purpose of this work/sundry is to install a cap string to inject methanol to prevent hydrate formation at startup. Capstring Procedure: 1. MIRU Cap String Truck, PT lubricator to 3,500 psi Hi 250 Low. 2. Install new wellhead packoff. 3. PU 3/8" capillary string. RIH and set at+/-5,500'. Note: The hydrate freezing appears to be a surface/near surface issue. A shallower set depth is being considered and may be tried initially. If the initial depth is not sufficient,then the capillary string will be lowered. 4. Set spool of remaining line near well. 5. Rig down Cap String Truck. 6. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic i I II Swanson River Field SCHEMATIC Well # SCU 243-8 HilcornAlaska,LLC Actual Completion 11/1991 RKB to TBG Hanger= 15 CASING AND TUBING DETAIL _ Tree connection: No Cap Size Wt Grade Conn Top Bottom c M C 1 20" Surf 29 T L e , 9-5/8" 40 N-80 8rd Surf 1858 — n' 7 23 N-80 Buttress Surf 1854 e 5-1/2" 20 N-80 Buttress 1854 6140 n t TUBING DETAIL _Z \ / , 2-3/8" 4.7 N-80 EUE 8rd Surf 5511 2-3/8" 4.6 N-80 EUE 8rd Surf 1804 htr strg 00 2 2-3/8"LONG STRING JEWELRY DETAIL No. Depth Item 3 1 15 2-3/8"Tubing Hanger 2 5528 Camco MM GLM (Empty)packed off X X 4 with 1" spacer pipe,ID=0.957" 3 5571 Brown"CC" safety joint [ - - 4 5578 Brown HS-16-1 Packer 5 5643 Brown Expansion Joint _ 6 5708 Camco MM GLM w/CEV Valve 7 5752 Camco "D"nipple 5 8 5785 Brown Safety Joint - 9 5795 Halliburton Sand Screen 6 10 5875 Bridge Plug N 7 8 E/ \ PERFORATION DATA E 9 Top Btm Zone SPF Date Comments C 5798 WSO 5610 5618 56-9 4 8/91 [ 5630 5640 56-9 5/89 Reperf 8/91 ix C 10 5834 5840 59-2 Sand Packed 5848 5856 59-2 Sand Packed . 5865 5871 59-2 Sand Packed 5882 5885 59-2 Plugged PBTD=5,875' TD=6,143' MAX HOLE ANGLE=Straight Updated by DMA 03-07-18 • fi. Swanson River Field 11 PROPOSED SCHEMATIC Well # SCU 243-8 HilcorpAlaska,LLC Actual Completion 11/1991 RKB to TBG Hanger=15 CASING AND TUBING DETAIL Tree connection: No Cap Size Wt Grade Conn Top Bottom M C 1 20" Surf 29 T z e , 9-5/8" 40 N-80 8rd Surf 1858 m 7 23 N-80 Buttress Surf 1854 e 5-1/2" 20 N-80 Buttress 1854 6140 n t TUBING DETAIL \ / 2-3/8" 4.7 N-80 EUE 8rd Surf 5511 —L , 2-3/8" 4.6 N-80 EUE 8rd Surf 1804 htr strg lA 0 2 2-3/8"LONG STRING JEWELRY DETAIL No. Depth Item 3 1 15 2-3/8"Tubing Hanger lA 5500 3/8" SS Cap String >< 4 2 5528 Camco MM GLM(Empty)packed off with 1" spacer pipe,ID=0.957" - - 3 5571 Brown"CC" safety joint –` — 4 5578 Brown HS-16-1 Packer C _ = 5 5643 Brown Expansion Joint 6 5708 Cameo MM GLM w/CEV Valve 5 7 5752 Camco"D"nipple ID8 5785 Brown Safety Joint 6 9 5795 Halliburton Sand Screen 11 7 10 5875 Bridge Plug 8 E/ \ PERFORATION DATA C 9 Top Btm Zone SPF Date Comments C 5798 WSO 5610 5618 56-9 4 8/91 5630 5640 56-9 5/89 Reperf 8/91 /� 10 5834 5840 59-2 Sand Packed 5848 5856 59-2 Sand Packed 5865 5871 59-2 Sand Packed 5882 5885 59-2 Plugged L PBTD=5,875' TD=6,143' MAX HOLE ANGLE=Straight Updated by DMA 04-03-18 STATE OF ALASKA • ALA OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations Li Fracture Stimulate U Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Sus Well g ❑✓ P ❑ Other: Pull V-string Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 162-001 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic El Service ❑ 6.API Number: AK 99503 50-133-10122-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028996 Soldotna Creek Unit(SCU)243-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Tyonek Gas 11.Present Well Condition Summary: Total Depth measured 6,143 Plugs measured 5,875 feet true vertical 6,143 feet Junk measured N/A feet Effective Depth measured 5,875 feet Packer measured 5,578 feet true vertical 5,875 feet true vertical 5,578 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 20" 29' 29' Surface 1,858' 9-5/8" 1,858' 1,858' 5,750psi 3,090psi Production 1,854' 7" 1,854' 1,854' 6,340psi 3,830psi Production 4,286' 5-1/2" 6,104' 6,104' 9,190psi 8,830psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.7#/L-80 5,511'MD 5,511'TVD N/A; N/A N/A Packers and SSSV(type,measured and true vertical depth) Brown HS-16-1 5,578'MD 5,578'TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 3938 65 400 1710 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory Developments Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-406 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerna.hilcoro.com Authorized Signature: ch/r.,4", Date: 31 i 3/l 8 Contact Phone: 777-8420 r Form 10-404 Revised 4/2017 _ t `lBDMS I V MAR L. 2018 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 243-8 S/Line 50-133-10122-00 162-001 9/18/17 3/2/18 Dail Operations; 09/18/2017- Monday Obtain PTW. Hold safety meeting. Discuss JSA and job procedure. RU CTU 13. 280 bbls of 3% KCL in supply tank. Start BOPE test. 24 hr BOPE test witness notification sent 9/17/17 @ 15:15 hrs. Witness waived by Jim Regg. 09/19/2017-Tuesday Crews on standby til 10 am. Check pressure on wellhead. Still 1400 psi SITP from previous night. Bleed all annuli off to tanks. Pressure bled down fast. 0 psi. Monitor return tanks for 3 hrs. No flow. Well appears to be dead. SLB crews on location. Permit to work. Hold safety meeting and review JSA. 220 bbls in supply tank of 3% KCL. Lined up down heater string. Pump 45 bbls and pressure starting to increase 1500 psi. Shut down pump. Pressure flat lined. Lined up pump down V string. Pressure up to 2500 psi. Slam choke wide open and bleed down pressure. Attempt to rock and shock wellbore. Do this three times. Fluid pressure bleed off to 0 psi. Attempt same on CTX2.375" tubing. Lined up down V string and v string x 2.375" Pressure up to 2500 psi and dump both strings to choke. Shut in tubing strings. Open CT v string. Bleed down to 0 psi. Shut in. Pollard SL on location. PTW. Hold JSA and safety meeting. RU slick line unit. RIH with 1" LIB to 2' and tagged.V shaped marks on LIB. RIH with 3/4" 5' long DD bailer. Small metal marks on bailer edge. No fill in bailer. RIH with 1" lib to 2' and tagged. Same marks as first run.V shaped. I believe someone attempted to close master valve on 1.25"velocity string and pinched coil shut. RDMO Pollard SL. Open 1.25"V stirng x 2.375" tubing annulus to return tank. Unload 5 bbls of fluid and gas pressure increasing at surface. Could have cleared sand bridge. Pressure increased and flat lined at 250 psi with wide open gut line on choke. 2" iron flowing gas to tank. Solid stream of sand into return tank.Attempt to bleed down gas pocket. Gas flowed steady at 250 psi wide open choke for 45 minutes. Re established communication with v string x 2.375"Tubing annulus. Shut in Choke. CTx2.375" SITP 2250 psi. Lined up down V string. Pump pressure increased to 2700 psi and then broke over. Bullhead 15 bbls down V string tubing. Re established communication with V string.V string fluid packed. Lined up down V string x 2.375" annulus. Online 5 bbls/min to bullhead and attempt to kill well. Injected 195 bbl.Shut down pump. 195 bbls pumped. Well head pressure bleed down from 2500 psi to 365 and broke over. Pressure still dropping but at a slower rate. Open to choke and pressure dropped to 0 psi and stopped flowing. Shut choke back in WHP climbed to 200 psi and then started dropping again. Decided to shut in choke with 200 psi at surface and see what the pressure looks like in the AM. 235 total bbls of 3% KCL pumped. 02/18/2018-Sunday Obtain PTW. Hold safety meeting. MIRU SLB CTU 13 with 1.25"gear. Injector head/stripper, BOPE dressed for 1.25", 1.5" CT reel set next to CTU. 200' of 1.5" CT whip installed on reel to assist spooling back the 1.25" CT. 1.5" x 1.25" double cold roll fabricated to assist in the velocity string recovery. Start BOPE test. 24 hr test witness notification sent to state 2/17/18 @ 13:39 hrs. Witness waived by Jim Regg 2/17/18 @ 14:13 hrs. Test all rams and valves to 250/4,500 psi. BOPE test complete. No failures. Secure location. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 243-8 S/Line 50-133-10122-00 162-001 9/18/17 3/2/18 Daily Operations: 02/19/2018- Monday Fill out PTW. Hold pre spud meeting in conference room at SRF. Lead op, Field foreman, SLB coil, Cruz crane involved. Fire equipment, pick injector head. Stab 9' and a 5' lubricator. Make up 1.25" slick stick trough injector head. Install Weatherford 2.25" series 10 overshot dressed with 1.25" grapple. Stab on well. Pressure test stack to 250/4,000 psi. Open well. WHP 170 psi. Pump 10 bbls down velocity string. 2.5 bbls/min 2,500 psi. Good indication that hanger seals compromised due to high pump rate through 1" ID v-string. Pump 30 bbls down 1.25"v-string x 2.375" tubing (IA) 2.5 bbls/min. Lined up down v-string and 2.375" tubing. Pump 30 bbls at 2.5 bbls/min. Shut down pump. Leave well closed in and monitor WHP for 30 minutes. SITP 850 psi. WHP dropped form 850 psi to 273 psi. Open v-string and 2.375" tubing(IA)to return tank. Flow at tank .5 bbls/min. Slowing down. 5 bbls returned before no flow with well and choke open to return tank monitor no flow for 30 minutes. Good no flow. RIH with slick sticks and overshot. Stack 3K down at hanger. Free pick up was 800 lbs. Pick up after stack was 3,200 lbs. Pick up 14 (putting know kink at master valve 1-2' above BOPE). Close pipe and slip rams. Manually lock rams for back up. Attempt push pull. RIH and coil is moving. PU coil is moving. Perform swab check 14 turns on swab valve indicating coil is not across valves. PU to coil zero. Close both swab valves. Pop off well. RIH and overshot control shows indentations from hanger lock down screws. Overshot packed full of valve grease. With overshot stacked out at hanger we should have had 3' of 1.25" v-string inside grapple wickers. Stand back and perform 5x5 to assess the situation for deviation in plan. Remove threaded bull plug from velocity string hanger spool . 48" pipe wrench and 2 people used to loosen bull plug. Look at coil below hanger. Found the 1.25" CT v-string flat/collapsed. Call town. Break flange above hanger. Still have 5" of 1.25" CT looking up. Groove marks on 3" of velocity string indicating a sign that coil was over v-string nubbin with grapple but slipped off.Talk with town and SLB . Could possibly be only a few feet of collapsed tubing. Shut down for the night as well as the following day 2/20/18 to locate lift sub coil clamps for flat pipe. Location walk around complete with SLB supervisor. Well site secure. SDFN. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 243-8 CTU 50-133-10122-00 162-001 9/19/17 3/2/18 Daily;Operations: 02/21/2018-Wednesday No activity to report. 02/22/2018-Thursday Fill out PTW and hot work permit. Hold safety meeting and review SLB MOC procedure. Fire equipment. SLB pump wont stay running more than 15 seconds. Call out SLB mechanic. Put control indicates low coolant level. Coolant level is fine. Could be bad sensor. SLB mechanic found broken wire. Pump back up and running. Lined up with 9.5 ppg brine down CT and back side (2.375"tubing). Initial WHP 75 psi. Online 2.5 bbls/min 2,200 psi. Bullhead 45 bbls down wellbore. Shut down pump. Open choke. formation charged up. Flowed back 6 bbls before no flow. Monitor No Flow for 30 minutes. Good 30 minute No Flow. Remove night cap. Break flange connection above hanger. Pick up 2x swab valves,x over spool and 4"SLB quad BOPE. Dress 1.25" CT velocity string. Hand file welded seam inside V-string. Stab coil roll on connector and roll. Deploy 5' 1.25" slick sticks through BOPE stack and make up to roll on coil connector. Flange up to well head hanger with new ring gasket. Close pipe and slip rams. Line up to pump down the top of BOPE into the slick sticks. Now that we have a good seal on V-string we will attempt to pump through string. Pump 6 bbls at 1 bbl/min 500 psi pump pressure. Pressure should be higher if pumping through 4,800'of 1" ID. Potentially have a hole in V-string close to surface. This would explain the low pump pressure. After 6 bbls pumped shut down and open choke. Let well flow back and stabilize. No flow indicated at surface. Open pipe and slip rams. Make up C plate on top of BOPE. Install slick stick x over to 1.5" MT 2.125"OD. Below x over make up SLB CTU clamp. Hook up crane block. Pull V-string in tension to 2K with crane. Back off wellhead lock down pins. Pick V-string up with crane. PU to 16K then breaking over to 12K. Moved about 3'then weight dropped off to block hanging weight. Looks like we lost V-string. Continue to pull out. V-string parted 40" down from slip marks at hanger. Hanger bolts to master valve is 40". Coil was severed from when master valve was closed on it. Drag weight while pulling with crane initially was thought to be V-string weight. After inspecting wellhead it looks like overpull was due to pulling flat 1.5"wide coil through 1.2" pack off assembly in hanger. The Break at 40" is not shiny. Doesn't look fresh. Good indication coil was parted and dropped down hole previous to intervention.Attempt to look down wellhead with flash light to see if coil is sitting 40"down or at the bottom of master valve. Could not see. Tie weight off to rope and lower it into the well. Rope went slack at 38.1'. Heard a small ting like hitting metal. POOH with depth indicator apparatus. Close master valve and re-install swab valves.Tighten lock down screw packing nut. Rig back SLB and secure location. Make calls to Pollard wire line. Meet with John Kersh and grab the alligator grab tool. Matched it up to the bottom of the 40" piece of 1.25" coil removed from hanger. Looks like alligator grab will latch parted coil at 38.1'. Make plans to swap out V-string hanger in the AM to get back to full drift wellhead. After wellhead spool swap call out Pollard slick line unit. Few options in the AM will be to remove V-string slip hanger inserts from current wellhead spool. Get different spool from Clint. Or get spool piece from SLB coil yard. • . Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 243-8 CTU 50-133-10122-00 162-001 _ 9/19/17 3/2/18 Daily Operations: 02/23/2018-Friday Make phone calls to Clint and SLB. Clint headed to shop to find crecent flange back to 2-9/16"spool.Arrive at Swanson and sign in. Prep location. Move Cruz crane, heater, man lift and metal dumpster from around wellhead. Hot bolt wellhead flanges. Pollard slick line arrive on location. Hold safety meeting and discuss job procedure. Rig up crane and slick line unil. Use crane to remove 2x swab valves and CT hanger. Make sure lock down screws are backed out and tap out CT velocity string pack off assembly. CT hanger is now full bore. Remove crecent flange x 2- 7/7"8rd threads from heater string side and stab on V-string side. Swedge into flange with SL con.Stab on wire line valves. Make up lubricator and tools string. Rope socket, 1.25"stem x 4 @ 5' each. GS spear, baited sub,x over, alligator grab. RIH with alligator grab. Hung up in wellhead. Sheared grab. Measured alligator cam mechanics when sheared. Measures 2" . Bring to mechanic shop and cut down cam shoulders. RIH with 1.88"gauge ring to 23' tag top of coil. RIH with alligator grab. Alligator set. PU 500 lbs, 800 lbs. 1,200 lbs. Hang spang off baited gs sub. At surface still have alligator grab. Grab slipped off coil. Re pin both. RIH and slipped off again. Re pin alligator grab. RIH,spend more time tapping down before attempting to sheer off baited sub. Sheared off at surface. Rig down slick line lubricator. Rig up crane to weight bar. PU moving coil 5,500 lbs. Picked up about 25'and pull to crane max of 7,500 lbs. Parted coil or GS possibly hanging up in tight spot in wellhead. Install 1.25" slick stick x 1.5" MT box. RIH and land in coil hanger secure x over with hanger pins. Reinstall both swab valves. Secure well. Rig down Pollard slick line and park at P&S yard. Well site secure. Crews off location. 02/24/2018-Saturday Hold safety meeting with SLB, Cruz and HAK field personnel. Obtain PTW. Fire equipment and check wellhead pressure. All strings 0 psi. Fluid pack with 9.5 ppg brine to return tank. Bullhead 40 bbls down 2.375"tubing. CT velocity string is hung off in hanger with 2 x 5'slick sticks,GS spear, baited GS profile, alligator grab latched to flat CT velocity string. Open well to choke. Flow back 5 bbls of fluid. well dead. Monitor well conditions for 30 minuts. Latch up CT velocity string. Work tool string. Picked up above wellhead. Cut 87' of collapsed coil velocity string. Back to good 1.25" round pipe. Make up roll on connector and install 2 slick sticks. Close pipe rams and slip rams to hold velocity string. Install 5' lubricator over string with night cap. Lock. Clean up tools and well site. Cut pipe disposed of in metal dumpster. CT Velocity string prepped and ready for removal in AM. i Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 243-8 CTU 50-133-10122-00 162-001 9/19/17 3/7/1 A Daily Operations: 02/25/2018-Sunday Obtain PTW. Hold safety meeting. Review procedure for pulling CT velocity string. Fire equipment. Put heater on SLB pump truck. Check well. All strings still dead 0 psi. Make up 1.25"slick sticks through injector head. Make up slick stick from BOP to slick stick in injector head. Strip down over slick stick connection and make up lubricator to BOPE stack. Push pull test connections. Open pipe/slips and manual locks. Pull V-string up through injector head breaking down slick sticks. Walk V-string tail to CT reel and secure on reel. Start spooling OOH. OOH with all of the V-string. Pop off injector head. Swing over and pick up cutter rams. Hang injector head over metal dumpster and cut in 20' sections. Set down injector head. Remove BOPE stack from well. Rig down and load trailers. Well site secure. Total fluid pumped prior to production attempting to flow back well was 316 bbls injected into formation for well kill. (9.5 ppg brine). Post production flow back 346 bbls pumped. No volume of flow back reported from production. Total fluid injected for complete job was 662 bbls. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 243-8 S/Line 50-133-10122-00 162-001 9/18/17 3/2/18 Daily Operations: 03/02/2018 - Friday Arrive at SR office sign in/ permit-JSA. Go over job scope with prod. On location, spot equipment- begin rig up. Pt lub 250 psi - low/ 2,000 psi high -test good. RIH w/ 1.90" gr to the tubing hanger- hand spanged could not pass. RIH w/ 1.72" GR to 5,523' KB tag the top of pack off. RIH w/ 1.80" GR to the tubing hanger wit could not pass. RIH w/ 1.80" swedge - could work tool through the TH. RIH w/ 1.90" swedge - could not work through TH. - had to spang out. RIH w/ 1.80" swedge to 500' kb-tag fluid at 465' KB. RIH w/ 1.9" lib tag tubing hanger-good impression of tubing edge on low side. RIH w/swab mandrel w/one cup - went through hanger and back up with no problem (see swab report). Well came on pushing fluid to tank, call Prod. Monitor well. Begin rig down, clean and secure area, mob equipment to PNS yard. Depart field. , .. S • Swanson River Field SCHEMATIC Well # SCU 243-8 HilcorpAlaska,LLC Actual Completion 11/1991 RKB to TBG Hanger=15 CASING AND TUBING DETAIL Tree connection: No Cap Size Wt Grade Conn Top Bottom M C 1 20" Surf 29 T z e , 9-5/8" 40 N-80 8rd Surf 1858 m 7 23 N-80 Buttress Surf 1854 e 5-1/2" 20 N-80 Buttress 1854 6140 n t TUBING DETAIL —L \ / , 2-3/8" 4.7 N-80 EUE 8rd Surf 5511 2-3/8" 4.6 N-80 EUE 8rd Surf 1804 htr strg 01(1 2 2-3/8"LONG STRING JEWELRY DETAIL No. Depth Item 3 1 15 2-3/8" Tubing Hanger 2 5528 Camco MM GLM(Empty)packed off 5Z X 4 with 1" spacer pipe, ID=0.957" 3 5571 Brown"CC"safety joint C - - 4 5578 Brown HS-16-1 Packer 5 5643 Brown Expansion Joint C = = 6 5708 Camco MM GLM w/CEV Valve 7 5752 Camco "D"nipple 5 8 5785 Brown Safety Joint 9 5795 Halliburton Sand Screen ID 6 10 5875 Bridge Plug 11 7 8 E / \ PERFORATION DATA E 9 Top Btm Zone SPF Date Comments C 5798 WSO 5610 5618 56-9 4 8/91 E 5630 5640 56-9 5/89 Reperf 8/91 10 5834 5840 59-2 Sand Packed 5848 5856 59-2 Sand Packed 5865 5871 59-2 Sand Packed 5882 5885 59-2 Plugged PBTD=5,875' TD=6,143' MAX HOLE ANGLE=Straight Updated by DMA 03-07-18 • • //� �w :,A THE STATE Alaska Oil and Gas ti n Conservation Commission _ LASKA �Win* _�- ` 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 (4'4tLASl‘14- Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC SCANNED S E p 0 1 7017 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Tyonek Gas Pool, SCU 243-08 Permit to Drill Number: 162-001 Sundry Number: 317-406 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on.a holiday or weekend. Sincerely, 0„..)4A7/09„.„ Cathy P. Foerster Commissioner DATED this day of August, 2017. RBDMS 1.t' Li 3 1 2017 • • RECEIVED STATE OF ALASKA AUG 2 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION OTS 8130 !›. APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend El Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other: Pull V-string/Set Tbg Plug ID- 2. ✓ •2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska, LLC Exploratory 0 Development Q. 162-001 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service 0 6.API Number: Anchorage Alaska 99503 50-133-10122-00 • 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 IDNo 2Soldotna Creek Unit(SCU)243-08 • 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996 • Swanson River/Tyonek Gas • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6,143' • 6,143' 6,090' 6,090' 1,936 psi 5,875' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 20" 29' 29' Surface 1,858' 9-5/8" 1,858' 1,858' 5,750psi 3,090psi Production 1,854' 7" 1,854' 1,854' 6,340psi 3,830psi Production 4,286' 5-1/2" 6,104' 6,104' 9,190psi 8,830psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-3/8" 4.7#/L-80 5,511' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Brown HS-16-1 Pkr;N/A 5,578'MD/5,578'TVD;N/A 12.Attachments: Proposal Summary Q Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory 0 Stratigraphic ❑ Development ❑✓ • Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: September 12,2017 OIL 0 WINJ ❑ WDSPL ❑ Suspended 16.Verbal Approval: Date: GAS 112(-( WAG ID GSTOR CI SPLUG ❑ Commission Representative: V tIs.1j'1 GINJ 0 Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcorp.com Contact Phone: 777-8420 Authorized Signature: 14//79:1‘.„ Date: Itty/17 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes El No Spacing Exception Required? Yes ❑ No Subsequent Form Required: 10 404- RBDMS 1,1, t.'."ri 3 1 2017 APPROVED BY Approved by: /9a4e, COMMISSIONER THE COMMISSION Date: 6 -36- / 7 FormAs an ® RIG IN .� �� Submit andForm 10-403 Revised 4/2017 a i valid for 12 months from the date of approval. Attachments inDu tate/ >�07x , • • Well Prognosis Well: SCU 243-08 Hilcorp Alaska,LI) Date:08/23/2017 Well Name: SCU 243-08 API Number: 50-133-10122-00 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: 09/12/17 Rig: Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 162-001 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number: Current Surface Pressure: 1,460 psi Current BHP: —2,510 psi @ 5,740' TVD (Calc'd using a 0.437 pressure grad.) Maximum Expected BHP: —2,510 psi @ 5,740' TVD (Calc'd using a 0.437 pressure grad.) Max. Potential Surface Pressure: — 1,936 psi (Assumed 0.10 psi/ft gas gradient) Brief Well Summary SCU 243-08 was drilled in February 1962. The well produced sand and water from the start and a screen was installed in June of 1963 in an effort to hold back the sand.The well was cleaned out with coil in August of 1987 • after which the well would only flow at low rates and it was believed that th well was forming hydrates snf• plugging down hole. In May of 1989 the well was re-perfed from 5,630 — 5,635' and the 5,610 to 5,618' perforations were added. In November of 1991 a 1.25" coil velocity string was installed in order to increase flow velocities. • The purpose of this work/sundry is to remove the velocity string, and set a tubing plug in order to comply with . BLM TA well status. An MIT will also be performed on the well. . Coiled Tubing Procedure: 1. Submit 24 hr.witness notification to AOGCC. 2. MIRU Coiled Tubing, PT BOPE to 250psi low/4,000 psi. high. 3. Rig up to kill the well. a. Bullhead 1.5X tubing volume with kill weight fluid (8.4 PPG produced water) down velocity string and CT by Tubing annulus. 4. Monitor the well for flow and ensure well conditions are static. a. Minimum 30 Minute no flow test must be performed. 5. Start making up slick sticks while injector is still on the back deck. Make up the amount of slick sticks needed to clear the length of the injector. Doing this will save time and reduce exposure to operators since the injector will not yet be hanging in the air. 6. Pick up injector head and 5' of lubricator. 7. Start inserting slick sticks into the top of the injector until a sufficient number of slick sticks have been made up to be zeroed at the bottom of the lubricator. a. Caution:this portion of the job will require operators to be in a man basket making up slick sticks into the injector while it is hanging from the crane.Slick stick sections will be short enough to clear rigging centered above the chains and will allow operators enough clearance to be able to make connections. 8. Make up crossover and 1.25" overshot to bottom slick stick. i • • • Well Prognosis Well: SCU 243-08 Hilcorp Alaska,LI) Date:08/23/2017 a. Overshot allows for well control to be maintained during fishing operations. b. Blind shears will act as contingency in the event of a kick. 9. Stab injector head onto well. 10. Open swab and run in hole while making up slick sticks until tagging up on the stub end of the velocity string. 11. Once OS is engaged, pull anticipated hanging weight of velocity string to confirm good bite on the velocity string. 12. Release slips in CT hanger 13. Slowly pull up hole to get velocity string inside CT BOPs. a. Break down slick sticks while pulling out of hole to avoid contact with injector head rigging. b. Measured amount of slick sticks will need to be removed to ensure sufficient clearance in CT BOPs 14. Close and manually lock CT BOP slips a. Light push/pull should be conducted against the slips to ensure good bite. 15. Close and Manually lock CT BOP pipe rams 16. Perform no-flow above pipe rams 17. Strip off injector head. 18. Cut off overshot from stub end of velocity string sticking out of BOPs 19. Remove 1.5" ammt by slick stick crossover and overshot from slick sticks. 20. Make up roll-on connection by slick stick box to lowest slick stick. 21. Prep stub end of the velocity string for roll-on connection a. Seem weld needs to be dressed prior to utilizing roll-on connection 22. Stab roll-on connection into the stub end of the velocity string and make up rolls. 23. Strip the injector back onto the BOP and make up the Otis connection. 24. Pull anticipated hanging weight ( 6,000 to 7,000 lbs) of string to verify good connection. 25. Manually unlock and open the pipe rams 26. Manually unlock and open the slips. 27. Start slowly pulling out of hole. 28. As slick sticks are being fed out of the top of the injector, break down connections to avoid contact with injector head rigging. 29. Once slick stick connections are rigged down and the V-String is exposed at the top of the injector, keep pulling out of hole guiding the end of the pipe away from the rigging. a. 1.25" pipe will be quite flexible and will be able to be easily guided away from the injector rigging. b. Once enough pipe has been pulled out of the injector and can make the radius of the gooseneck, secure the pipe to the gooseneck. 30. Continue pulling out of hole until end of pipe is near the reel. 31. Prep the reel, with a 1.5" rat tail with a 1.5" x 1.25" double roll-on connection already made up and clamped through the horses head. Make up the 1.25" pipe to the 1.25" by 1.5" roll-on connection. 32. Once double roll-on is made up, unclamp the pipe at the horses head and continue to pull out of hole. a. Caution and due diligence needs to be exercised while pulling out of hole.All string data pertaining to the velocity string is from 1991 and of unknown integrity. • S Well Prognosis Well: SCU 243-08 Hilcorp Alaska,LLI Date:08/23/2017 b. Area between reel and injector should be barricaded off. 33. Pull velocity string out of hole. 34. Close swab and secure the well. 35. Cool down SLB N2 unit and blow string dry to open top tank. 36. RDMO CTU. Slick-Line Procedure: 37. MIRU Slick-line, PT lubricator to 2,000 psi Hi 250 Low. 38. PU 2-3/8" AD2 tubing stop plug and setting tool. 39. RIH and set plug @ 5,520'+/- POOH w/setting tool. 40. Bleed down tbg.To pressure test plug (Negative Pressure Test). 41. RD MO Slickline Unit. Pump Truck 42. RU Pump to IA and pressure test lines to 2,000 psi. 43. Perform MIT—IA to 1,500 psi on chart. 44. Fill out MIT Paperwork and send to operations engineer and regulatory Technican for distribution. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Wellhead Diagram 4. CT BOPE Schematic 5. Blank RWO Change form Swanson River Field II Well # SCU 243-8 Hamra Alaska,LI.c Actual Completion 11/1991 RKB to TBG Hanger= 15 CASING AND TUBING DETAIL Tree connection: No Cap SIZE WT GRADE CONN TOP BOTTOM C C 1 20" Surf 29 T L e 9-5/8" 40 N-80 8rd Surf 1858 m 7 23 N-80 Buttress Surf 1854 e 5-1/2" 20 N-80 Buttress 1854 6140 n t Tubing: / 2-3/8" 4.7 N-80 EUE 8rd Surf 5511 —L 2-3/8" 4.6 N-80 EUE 8rd Surf 1804 htr strg 1-1/4" 1.1 coiled tubing velocity Surf 5480 I 1 la 0 2 2-3/8"LONG STRING JEWELRY DETAIL NO. Depth Item 3 1 15 2-3/8"tubing hanger la 5480 Bottom of 1-1/4" CT string, ->-< x 4 Pump out check valve was blown out on top of packed off GLM -- 2 5528 Camco MM glm (EMPTY)packed off — T with 1" spacer pipe, ID=0.957" 3 5571 Brown"CC" safety joint 4 5578 Brown HS-16-1 Packer 5 5 5643 Brown Expansion Joint 6 5708 Camco MM glm w/CEV valve ID 6 7 5752 Cameo"D"nipple iiimi 7 8 5785 Brown Safety Joint 8 9 5795 Halliburton Sand Screen 10 5875 Bridge Plug EX \ \ E 9 L 10 PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 5798 WSO ::„ 5610 5618 56-9 4 8/91 5630 5640 56-9 5/89 Reperf 8/91 5834 5840 59-2 Sand Packed ,:fi 5848 5856 59-2 Sand Packed PBTD=6090' TD=6143 5865 5871 59-2 Sand Pakced MAX HOLE ANGLE=Straight 5882 5885 59-2 Plugged SCU 243-08 Schematic 03-02-2004-HAK REVISED: 7/11/2017 DRAWN BY: TAB/JWS • •Swanson River Field II PROPOSED SCHEMATIC Well # SCU 243-8 Actual Completion 11/1991 Hilcori,Alaska,LLC RKB to TBG Hanger= 15 CASING AND TUBING DETAIL Tree connection: No Ca-3 Size Wt Grade Conn Top Bottom C C 1 20" Surf 29 M T L e 9-5/8" 40 N-80 8rd Surf 1858 m 7 23 N-80 Buttress Surf 1854 e 5-1/2" 20 N-80 Buttress 1854 6140 n t TUBING DETAIL X / 2-3/8" 4.7 N-80 EUE 8rd Surf 5511 _L , 2-3/8" 4.6 N-80 EUE 8rd Surf 1804 htr strg — 1a 2 2-3/8"LONG STRING JEWELRY DETAIL No. Depth Item 3 1 15 2-3/8" Tubing Hanger 1 a ±5520 2-3/8"AD2 Tubing Stop Plug >< >C 4 2 5528 Camco MM GLM(Empty)packed off with 1" spacer pipe,ID=0.957" L - - 3 5571 Brown"CC" safety joint 4 5578 Brown HS-16-1 Packer I : _ = 5 5643 Brown Expansion Joint 6 5708 Camco MM GLM w/CEV Valve 5 7 5752 Camco"D"nipple 8 5785 Brown Safety Joint MI 6 9 5795 Halliburton Sand Screen 7 10 5875 Bridge Plug 8 X / PERFORATION DATA 9 Top Btm Zone SPF Date Comments 5798 WSO 5610 5618 56-9 4 8/91 5630 5640 56-9 5/89 Reperf 8/91 X >� 10 5834 5840 59-2 Sand Packed 5848 5856 59-2 Sand Packed 5865 5871 59-2 Sand Packed 5882 5885 59-2 Plugged L PBTD=6,090' TD=6,143' MAX HOLE ANGLE=Straight SCU 243-08 Proposed Schematic 07-11-17 Updated by DMA 07-11-17 . • • Swanson River SCU 243-08 07/13/2017 llibnrp:«a.ka.III SRU 243-08 Tubing hanger,T-59AD, 7 X 95/8 X7X23/8X 23/8 liftandsuspX 2 3/8 X 1'A coil 2 3/8 lift and susp w/2" Cosasco back pressure valve preps MI �� o r _ Valve,CIW-FL (11,1r 4` 2 9/16 5M FE, HWO -,"� it Valve,CIW-FL 1 ,r 2 9/16 5M FE, HWO / / 6\ ".1 � riil Il( r =`� '.� Coil tubing head,WCI,RH-4,2 1/16 71 SM 5 bolt FE X 2 9/16 5M Top,w/ I1,,I� 2" po I Valve,wing, WKM-M -°s�) Valve,wing, CIW-F 2 1/16 5M FE, HWO _ .sinkriom 2 1/16 5M FE, HWO _ iI1' BE Pitt '''''''''til- I - if 111441;j On .e. ,..4,0 _. -, Valve, master, WKM-L, Valve, master,WKM-L, 2 1/16 5M 5 bolt FE, HWO - '... 2 1/16 5M 5 bolt FE, HWO Ion.®LA� ® Adapter,Shaffer dual, »� 7 1/16 5M stdd X Tubing head,Shaffer w 2 1/16 5M 5 bolt X -T ■ • 21/165M5bolt T-59D L1,11 3M X EEO •i a Ib Ilbis 71/165M, w/2-21/165M ' 'II SSO 1i�� —�� 7' 0mi �I _ Valve, plug, Rockwell, 2' LP -1-1011 + MMM 1 I !-!.-' 1"1:1. Ili 1 f Casinghead,Shaffer KD, 11 3M X 9 5/8 SOW, 1111 I Valve,plug, Rockwell,2"LP w/2-2" LPO III *MA on-h-, . • • II Swanson River SCU 243-08 07-11-2017 11.1.,..90 Va.&a,td.l: A \t R G1A_� Irmii_ i uiuI3_1.�i-_.I.�M �UH! I , Coiled Tubing HR580 Injector Head&Gooseneck .. �t f- Ii��f ��11 IIilli t Weight=12,850 lbs II it .7- uT_ll Ii.I.• t 4-1/16"10K Conventional Stripper I ibidl 5K C062 Lubricator Jill Port WH PSI 2"1502 x 2-1/16 10K Flanged Valve t 5K C062 x 4-1/16"10K Flange (Manual) 2-1/16 10K x2-1/16 4-1/16"10K Combi BOP — 10K Flanged Valve Top Set:Blind/Shear (Manual) -'--F9! . .7."' 4 Second Set:Pipe/Slip 4-1/16"10K Flow Cross Manual 2x2 Valve 1:2"1502 x 2-1/16"10K Flange PlOillileili Wir lti[Obi! 4 Manual 2x2 Valve 2:2-1/16"10K x2-1/16"10K Flange _ Manual 2x2 Valve 3:2-1/16"10K x2-1/16"10K Flange Manual 2x2 Valve 4:2"1502 x 2-1/16"10K Flange 4-1/16"10K x Wellhead Adapter Flange III 0=I0[141Ir Vi .) 4 Wellhead ' 0 0 � CD R �/ 2> ■/ & O 73 _ \ E 0o § U 2k ° § a/ « E � § ' 2 to 7_ § X Cif > E < L._ / � < � t- > = ' 2 .E 0 a g 7 § .D CO ■ ■ 2 Q2 # # o k/ el O 9 c 0 CL N k9- $ "0 0. - > CD a) _ @ C.) 90_ o n k $ U. ® '- a) 0 � � "0 0• 0 ■ . 0/ 15) J as § < ..c CD 2 E § % o k g k O 0_ ° S4 / C) »% 2 c §C / 2 . 2 2p 2 w -0 ■ I?) $ @ co § � 0 « O. o ti o.2 ) x CO O a 0 v) � Q ■ x 2a o >< E ' ■ 0 q .0 # $ 2 0 ii / co CJ 0 ci % f / e / k 2 \0 °0. o co 2 2 \ 9 < E Z1 (.) U) =o · ', · Form (JUNE 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WEllS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use 'APPLICATION FOR PERMIT-" for such proposals SUBMIT IN TRIPLICATE 1. Type of Well Oil Gas I~: Well ~ Well I'"] Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchoraqe, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit -- 14 Wells Soldotna Creek Unit -- 7 Wells FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Sedal No. 6. If Indian, Allottee or Tdbe Name 7. If Unit or CA, Agreement Designation Swanson River/ Soidotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field 11. County or Parish, State Kenai, Alaska 12. CHECKAPPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION [~ Notice of Intent [] Subsequent Report [] Final Abandonment 0 Abandonment I-] Change of Plans r'] Recompletion I-I New Construction [-1 Plugging Back ['-'] Non-Routine Fracturing ~ Casing Repair r-] Water Shut-Off I-] Altering Casing [-'] Conversion to Injection I~ Other Temporarily Abandon I'-] Dispose Water (Note: Report results of multiple conmpletion on Well Completion or I:{e(x)m~ Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give perlJnent dates, including estimated date of starting any ixoposed work. If well is directionally drilled, give subsurbce locations and measured and true vertical depths for all markers and zone pertinent to this work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1,1996 to March 31,1997: Soldotna Creek Unit (~' J ~ SCU 21-a .~IiSCU 34-9 (.o<~-) ~:~SRU 212-10 (O1" ~SCU34-8 f-~SCU41B-9 ~)'~RU 12-15 (e~" I SCU 243-81 ~U 14-3400-J z~SRU 14-15 S 1'gsscu 13-9 t.k~,.".,~ SRU41A-15 t7 SRU 2s-= * High GOR well that may be produced intermittently Swanson River Unit -2 SRU212-27 -/~{ .g SRU 23-27 SRU - oO ,_"o t t l::tV D SRU 34-2S 6,=3- 7_ SRU43-2S (,,I-' ~_ SBU 21-33WD & 3.-.~. APR 0 1 1~96 SRU 24-33 "/~,- '7 14. i hereby ceftifytt~the foregoing is tmeand correct. Dennis L. Groboske Petroleum Engineer Dam 3/29/96 Approved by Coeditions of approval, if am/: Dam T'~le 18 U.S.C. Section 1001, makes it a crime f(x any pemon knowingly and willfully to make to any department or agency of the United States any lalse, fictitious frau_~_,Left statements or represe~__'_,~ns as to any rr~-~ within its juriscicfion. *See Instruction on Reverse Side Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 21 Wells Twelve Month Period: April 1, 1996 to March 31, 1997 Shut-in Wells under Evaluation for Shut-in Wells during Field Blowdown Rate Potential SCU 34-8 SCU 243-8 SCU 13-9 SCU 41B-9 SRU 21-33WD SRU 34-28 SRU 43-28 P&A SRU 212-10 SRU 212-27 Shallow Gas Potential and 'Hemlock Only' P&A SRU 12-15 SRU 41A-15 SRU 23-27 SRU 331-27 SCU 14-34 Hemlock Producers Future Shallow Gas P~'oducer with the Hemlock Abandoned SCU 21-8 SCU 34-9* SRU 14-15 SRU 43A-15 SRU 14-22 SRU 23-22 SRU 24-33 7 Wells 2 Wells 5 Wells ~.$ ~.~lh GOR well that may be produced intermittently 2 Wells 5 Wells ATTACHMENT 2 SWANSON RIVER FIELD Wells with Temporarily Abandoned Status Change Removed from 1996 Temporarily Abandoned Status · SCU 34-4 Recompleted in Tyonek G1 and G2 zones · SCU 43A-4 Recompleted in Tyonek G1 and G2 zones · SCU 13-4 Workover to remove tubing fish. Currently producing from Hemlock · SCU 23B-3 Returned to full time production · SCU 314-3 Returned to full time production · SCU 43-9 Returned to full time production · SCU 23-15 Returned to full time production Additions to 1996 Temporarily Abandoned Status · SCU 13-9 Recompleted in Tyonek G2 zone Iow rate oil producer. APR 0 Uno~l North Ame~ Oil & Gas Division Unocal Corporation ~ 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region March 31, 1994 Re: Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 1994 Sundry Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 30 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Thirtieth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1994 to March 31, 1995. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells using the same. format as submitted last year. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses during field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Three wells SCU 24A-9, SCU 33-5, and SCU 21-3 were removed from the list while two wells SRU 12-15 and SRU 21- 33WD were added to the list. RECEIVED APR - 1 1994 Oil & Gas Cons. Commission Anchorage Mr. Joseph A. Dygas March 31, 1994 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. DLG:dma ~~,Dennis L.' ..~~,rd,~ske Petroleum Engineer Attachment CC' L. R. Dartez, Marathon Oil Company D. W. Johnston, Chairman, AOGCC Form 3160-5 (JUNE 1990) UNITE.~. ATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use 'APPUCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLICATE 1. Type of Well Oil Gas [] Well [~ Well ['] Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Sun/ey Description) Swanson River Unit --- 19 wells Soldotna Creek Unit --- 11 wells FORM APPROVED Budget Bureau No. 1004-0135 Explree: March 31t 1993 5. Lease Designation and Serial No. 6. If Indian, Allottee or Tribe Name . o 7. If Unit or CA, Agreement Deeignation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Reid and Pool, or Exploratory Area Swanson River Field 11. County or Parbh, State Kenal, Alaska 12. CHECKAPPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION r~ Notice of Intent ' ["] Subsequent Repo~ r-] Final Abandonment r-] Abandonment [-] Change of Plans I-] Recompletion [-] New Construction r-] Plugging Back 0 Non-Routine Fracturing O Casing Repair 0 Water Shut-Off O Altering Casing r'] Conversion to Injection [] Other Temporarily Abandon [-] Dispose Water If weft is directionall~ drilled, give subsuri~ce locations and measured and tree ~ del~he for all mmkem and zone pe~ner~ to thla wod(.)* As described in attached letter, Unocal requests that the folbwing wells have a temporarily abandoned status for the twelve month period, April 1994 to March 31, 1995: Soldotna Creek Unit ~ ~' * scu 23B-3 scu 243-a ~ I SCU 13-4 SCU 341-8 <J I * SCU 21A-4 SCU 13-9 ..%1 SCU 34-4 * SCU 34-9 5' I * SCU 43A-4 SCU 14-34 / -o//.-* SCU 21-8 *High GOR wells that may be produced intermittently. Swanson River Unit ~' ~ SRU 212-10 ./-"SRU 14-22 $ / SRU 43-28 % us SRU 14-15//-:/~:IU 12-15 ~ I SRU 14A-33 5~" SRU 23-15 ~J SRU 23-22~u3pSRU 24-33 ~u~I~SRU 34-15 ~1 SRU 23-27 ' 8RU 32-33WD S ~ % i~ SRU 41A-15ir~SRU 212-27 SRU 21-33WD ~ ~.~ ~ 5~5~ SRU 43A-15G~ SRU 331-27 ~ u.~ SRU 432-15 ~ ! SRU 34-28 14. I hereby cerUfy ll~lt the foregoing j~ lieF,ired correcL Conditions ot appro~l, Barn/: RECEIVED APR - 1 1994 VRle 18 U.$.C. Section 10m, makes ira crime for any person knowingly and willfully to make to any department or agef~y o~ the United Sla/~[f~,~il$' C0mmissi0r, fraudulert statements or representa~ as to any matter within ils jurisdiction. *See Instruction on Reverse Side Aneh0rage Atta~hm. ent No, !_ Swanson River Field Proposed Temporarily Abandoned Wells: Total 30 Wells Twelve Month Period: April 1, 1994 to March 31, 1995 Shut-in Wells under Evaluation for u , Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A -/~-tSSCU 13-4 ~ -~SCU 34-4 [e~-'~., SCU 341-8 ~--I~ SRU 212-10 L0[- o~ SRU 23-15 ~-~o SRU 41A-15 ~-'l SRU 34-28 ez~ SRU 14-22 ~ ~-~ SRU 43-28 (~-1.'~ SRU 23-22 ~o~'tt~ SRU 32-33WD/~I-5%SRU 212-27 (~--b~ SCU 243-8 ~o-~q~ SRU 331-27 (0~- Z SRU 21-33WD~-Z~SRU 12-15 Ioo-~&SCU 14-34 &o-qq SRU 23-27 SRU 14A-33 Shut-in Wells during Field Blowdown i I Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned SCU 21-8' ~D-Iqb SRU 14-15 SCU 13-9 (~0-u~t SRU 34-15 SCU 34-9' SRU 43A- 15 SCU 23B-3' %5-bb SRU 432-15 SCU 43A-4' -~_-o-~SRU 24-33 SCU 21A-4' 8 Wells 8 Wells 3 Wells 6 Wells 5 Wells *High GOR wells that may be produced intermittently RECEIVED AP/:{ - -/ 1994 Alaska Oil & Gas Cons. Commission Anchorage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change Additions to 1994 Temporarily Abandoned Status · SCU 12-15' · SCU 21-33WD: Shut-in gas lift producer with casing communication, Evaluate for repair or abandonment. Shut-in due to wireline fish in tubing. Workover candidate, Removed from 1994 Temporarily Abandoned Status · SRU 24A-9: · SRU 21-3' · SRU 33-5: Returned to full time production after workover. Returned to full time production due to commencement of Blowdown in field. Returned to full time production after workover. RECEIVED aPR - 1 1994 ~Jll & Gas Cons. Commission Anchorage ~j Alaska Region Oil & Gas Division Unocal Corporation P.O. Box 190247 O~O~U~ "~,~~ Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 COMM RES ENG ,~.L~ UNOCAL ) SR ENG '~NG ASST March 24, 1993 SR GB6L ~GEOL ASST - %~EOL ASST ~TAT TECH - ~~'Hq-- FILE -- Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re' 1993 Sundry Notice Request for TA Wells in SwansonRiver: FielcL Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 31 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the .Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Twenty-Ninth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1993 to March 31, 1994. These concurrent time periods will greatly simplify future TA Sundry Notice and Plan of Development and Operations preparation. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells using the same format as submitted last year by ARCO. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses under field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned Ust. Two wells, SCU 243-8 and SCU 21-8 were added to the list while three wells, SRU 21-22, SRU 12A-14 and SRU 211-15 were removed from the list. RECEIVED MAR 2,5 199, Alaska Oil & Gas Cons. Commission Anchorage Mr. Joseph A. Dygas March 18 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. Yours very truly, Petroleum Engineer DLG:sr Attachment cc: L.C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company RECEIVED MAR 2 § 199; Alaska 0/1 & Gas Cons. C0mmissiof~ Anchorage Form 3160-5 (June 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMITm" for such proposals SUBMIT IN TRIPLICATE !. Type of Well IX']Oil Gas Well ['~ F=-I Other Well 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone No. P. O. Box 196247, Anchorage, Alaska 99519 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit Soldotna Creek Unit 17 wells 14 wells (907) 276-7600 12. TYPE OF SUBMISSION TYPE OF ACTION FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31,1993 $. Lease Designation and Serial No. 6. If Indian, Alionee or Tribe Name 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field ! 1. County or Parish, State Kena i ~ A1 as ka OHEOK APPROPRIATE BOX(B) TO )ND)GATE NATURE OF NOT)OE, REPORT, OR OTHER DATA l-X] Notice of Intent ['-] Sub~uent Report r-'=] Fi~ Abandonment Notice -"]Abandonment --] Recompletion {~] Plugging Back O Casing Repair [X] omer Temporari 1 y Abandon --{Change of Plans O New Construction r-~ Non-Routine Fracturing -=] Watcr Shut-Off D Conversion to Injection -']Dispose Water {Note: Report result$ of multiplecompletionon Well Completion or Rccompletion Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1, 1993 to March 31, 1994' Swanson River Unit Swanson River Unit / SCU 21-3 SCU 21-8*/°~ SCU 23B-3!/ SRU 212-10 ~ SRU SCU 13-4 ~ ~~ SRU 14-15' SRU SCU 341-8'-' SRU 23-15/ SRU SCU 21A-4 SCU 13-9/ SRU 34-15 SRU SCU 34-4~ SCU 24A-9~ SRU 41A-15~ SRU SCU 43A-4y SCU 34-9'~ SRU 43A-15 SRU SCU 33-5~ SCU 14-34~-.' SRU 432-15 SRU SRU 14-22~ SRU SRU 23-22( 23-27 ~ 212-27~ 331-27 34-28~ 43-28 ~ 14A-33~ 24-33' 32-33WD RECEIV£D MAR 25199i5 Alaska 0il & 6as Cons. Gomm'tss'tor Anchorage * High G0R wells that may be produced intermittently. 14. ' hereby certify that~foregoing~.j~e~--t_ ~ Signed /q ?~,~';,/, ./"~-z:~'~.C-~ Tree Petroleum Engineer D~te , Approved by Title Date Conditions of approval, if any: Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements 'S~e in~Tuction on Rmm~le Side Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 31 Wells Twelve Month Period: April 1, 1993 to March 31, 1994 Shut-in Wells under Evaluation for Rate Potential P & A(1! Shallow Gas Potential and 'Hemlock Only' P & A Shut-in Wells until the Field Blowdown Hemlock Producers Future Shallow Gas Producer with the Hemlock Abandoned SCU 13-4 SRU 212-10 SCU 21A-4 SRU 23-15 SCU 34-4 SRU 41A-15 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SRU 341-8 SRU 212-27 SRU 34-28 SRU 331-27 SRU 43-28 SCU 32-33WD SCU 14-34 SRU 23-27 SRU 14A-33 SCU 21-8" SCU 13-9 SCU 24A-9 SCU 34-9· SCU 23B-3' SRU 14-15 SRU 34-15 SRU 43A- 15 SRU 432-15 SRU 24-33~2~ SCU 21-3 11 Wells 7 Wells 3 Wells 5 Wells 5 Wells ~ Does not include SRU 211-15. Scheduled full P & A in March-April, 1993 (2) Scheduled 'Hemlock Only' P & A in March-April, 1993. · High GOR wells that may be produced intermittently. RECEIVED Alaska Oil & Gas Cons. Commission ~ch0rage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1992's TA Status - December 27, 1991) Additions to 1993 Temporarily Abandoned Status · SCU 243-8: · SCU 21-3: Shallow gas producer (Tyonek). Shut-in due to mechanical problems. Workover candidate. Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Temporarily Abandoned Status · SRU 21-22: · SRU 12A-4: · SRU 211-15 Returned to production after flowline repair. Returned to full time production in 1992. Scheduled for full P & A March-April, 1993. Waiting on personnel and rig. RECEIVED MAR ~ 5 ~99~ Alaska Oil & Gas Cons. Oo~m~ss~o' Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 27, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Subsequent Report for SCU 243-8. Dear Mr, Smith: On 8/1/91 ARCO Alaska, Inc. successfully completed the perforation of SCU 243-8, D1 sands of the lower Chuitna. The intervals shot were from 5610'- 5618' and 5630'-5635' respectively. Please refer to the attached submittal of the Subsequent Report for details of this operation. If you require any further information in this regard, please do not hesitate to call Jim Zernell at 263-4107. Sincerely, Acting Regional Engineer JCW:DRH:czm:0124 Attachment CC: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED MAY- ' ~llt~i0rage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OP£R TIONS ORIGINAl. 1. Type of Request: Operation Shutdown ~ Stimulate Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service 21ZO' FSL and 1070' FEL, Sec. 8, T7N, R9W, SB&M Plugging Perforate X Pull tubing Other 6. Datum elevation (DF or KB) 156' KB 7, Unit or Property name Soldotna Creek Unit 8. Well number SCU 243-8 feet At top of productive interval Straight Hole At effective depth At total depth Straight Hole 9. Permit number/approval number 91-168/ 10. APl number so-] 33-1 O1 ?Z-O0 1 1. Field/Pool Swanson River-Lower Chuitna 1 Z. Present well condition summary Total Depth: measured true vertical 6143' feet Plugs (measured) 6143' feet 5875' - 5885' (cmt. plug) Effective depth: measured 6090' feet Junk (measured) true vertical 6090' feet Casing Length Size Cemented Measured depth Structural Conductor zg' ZO" yes 0-29' Surface 1858' 9-5/8" TOC-181Z' 0-1858' Intermediate Production 6140' 7"x5-1/2" TOC-5631' 0-6140' Liner 1804' Z-3/8" --- 0-1804' True vertical depth 0-29' 0-1858' 0-6140' O- 1804' 13. Perforation depth: measured 5610'-5618', 5630'-5640', 5834'-5840', 5848'-5856', 5865'-5871'MD true vertical 5610'-5618', 5630'-5640', 5834'-5840', 5848'-5856', 5865-5871 'TVD Tubing (size, grade, and measured depth) Z-3/8", N-80, 5796' Packers and SSSV (type and measured depth) Brown 5-1/Z" x ? 3/8", HS-16-1 Packer, 5578' MD Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure RECEIVED IVi/~ ! , Alaska Oil & Gas Cons. c0mmisSi0n :Anohorage 14. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Prior to well operation 0 198 0 Tubing Pressure 1010 Subsequent to operation 0 275 0 1500 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X__ 16. Status of well classification as: Oil Gas X Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed J~' -fi\ )~w;t~ Title Cook Inlet Regional Engineer Form 10-404 Rev 06/1 S/88 Date SUBMIT IN DUPLICATE AUG-02-'91 ~:10. ID:~NSON RIVER ? ~277 PO1 ARCO Alaska, Inc. Sublimity of Atl~tti~ Rir, hfl~ld C~mp~n¥ WELL CONTRACTOR REMARKS IPBDT WELL SERVICE REPORT IFIl;Lo. OISTRICT · STATE OP'E~PORT TIME l DAY~.~ lDATE //;~..~ ?/ R_I:jCEIV P Alaska Oil & t:,;.~ ', b,,,,~..bj~iCJl~-~-OB THIS BLOCK IF SUMMARY CONTINUED ON SACK i Ter~. l Oell Ftleter l Vlelblllty ..... I WInd Vel. Well- sou 243-8 Spud Date: 2/3/62 ')riginal RKB: 15' Arc¢~'laska Inc. - Swanson RiW~=ield APl#: 133-10122-00 Well Type: Gas Producer Completion Date: 2/24/62 Last Workover: 6/63 Hanger Type' Dual Hanger' Shaffer Max. Hole Angle: 2° Angle @'D' Sand' 1-3/4° All Depths are RKB MD to Top of Equipment. 10 11 12 13 L Jewelry I 5480' 2 5516' 3 5528' 4 5571' 5 5578' 6 5643' 7 5708' 8 5752' 9 5785' 10 5798' 11 5895' 12 5877' 13 5875' 14 6090' Pump out check valve (1.800" O.D.) Packoff w/1" spacer pipe (0.957" I.D.) 2-3/8" Camco MM Mandrel Assembly w/CEV VaNe(Packed-off) Brown "CC" Safety Joint Brown 5-1/2"x2-3/8" HS-16-1 Packer Brown Expansion Joint. 2-3/8" Camco MM Mandrel Assembly w/CEV VaNe Camco "D" Nipple Brown "CC' Safety Joint W.S.O. Halliburton Sand Screen Halliburton Sand Screen Anchor Shoe Top of Cement Bridge Plug Top of Plug Casing and Tubing IGA Bottom Deacrl_otlon 20" 94# 0 29' 9-5/8" 40# 0 1858' 7" 23# N-80 0 1854' 5-1/2" 20# N-80 1854' 6140' 2-3~8" 4.7# N-80 0 5511' 2-3~8" 4.6# N-80 0 1804' 1-1/4" 1.1# 0 5480' Conductor Pipe Surface Casing Production Casing Liner Tubing Heater String Injection string (coiled tubing) 6090' MD 6143' TVD Perforation Data 5610'-5618' D1 8' 4 8/91 5630'-5640' D1 10' 5/89 5834'-5840' D3 6' 5848'-5856' 8' 5865'-5871' 6' 5882'-5885' 3' RECEIVED MAY - 1 I-DB2 Alaska Oil .& Gas GonG. Cornmissir~r~ Anchorage 5630'-5635' Reped 8/91 GP GP GP Plugged JIB 12/31191 SCU 243-8 ~.~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering May 31, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is an Application for Sundry Approval to reperforate the current producing interval and add perforations in the D1 Sand in Well SCU 243-8. We propose to perforate ' 5 6 ' 8 of f'he U , 18, Z;,~L~ o ot tiae Middle D1 sand [5,630'- _ MD) and to re,~erfo-~-- -~ .... pper D 1 sand (5, 610'- 5,635 MD) with a 1-I i'/16 hollow carrier perforating gun. With your approval, we would like to begin this work as soon as possible. If you have any questions please contact Jim Zernell at 263-4107. Sincerely, T. Wellman Regional Engineer TW:JTZ:czm:0078 Attachment RECEIVED JUN - 3 1991 Alaska 0il & Gas Cons. ~;0mmission Anchorage Mr. W. Watson Mr.B.C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska,.Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND G/~ ~RVATION COI~MI~ APPLICATION FOR SUNDRY APPROVALS 1. Type of RequeSt: Abandon _ SL_~,~w~d_ __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well _ Plugging_ Change approved p _rogram Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development X Exploratory _ Stratigraphic _ 2120' FSL and 1070' FEL, Sec.8, T7N, R9W, SB&M At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole 12. Present well condition summary Total Depth: Effective depth: RECEIVED Casing Structural Conductor Surface Intermediate Production Heater String Perforation depth: JUN - 3 t991 h0raae ~asur~ 6143' feet Plugs (ffiea~r~) ~ue ve~l 6143' feet ~asur~ 6090' feet Junk (measure) true venial 60 9 O' f~t ~ S~e ~ 2 9' 2 0" yes 1858' 9-5/8" TOC-1812' Time extension _ Stimulate_ Variance _ Perforate ..~ Other_ 6. Datum elevation (DF or KB) 156' KB 7, Unit or Property name Soldotna Creek Unit 8. Well number SCU 243-8 9. Permit number 10. APl number ~o-1 33-1 01 22-00 11. Field/Pool feet )n Swanson River/Lower Chuitna 5875'- 5885' (cmt. plug) Measured depth True vertical depth 0-29' 0-29' 0-1858' 0-1858' 13. 6140' 1804' 2 - 3 / 8" - - - measured 5630'-5640', 5834'-5840', 5848'-5856', 5865'-5871'MD; true vertical 5630'-5640',5834'-5840', 5848'-5856', 5865-5871'TVD; Tubing (size, grade, and measured depth 2-3/8", N-80, 5796' Packers and SSSV (type and measured depth) Brown 5-1/2" x 2 3/8"~ HS-16-1 Packer~ 5578' MD Attachments 7"x5-1/2" TOC-5631' 0-6140' 0-6140' 0-1804' 0-1804' Proposed: 5610'-5618' MD 5630'-5640' MD (reperf) Proposed: 5610'-5618' TVD 5630'-5640' TVD (reperf) Description summary of proposal _ Detailed operation program X BOP sketch X 14. Estimated date for commencing operation ~ 15. December. 1990 i oi~ __ Gas X 16. If proposal was verbally approved Name of approver Dat_e app_roved Service Field Fuel Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~"~,~7..-,.~ Title Cook Inlet Regional Engr. FOR COMMISSDN USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance __ Mechanical Integrity Test _ Subsequent form require 10- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission Form 10-403 Rev 5/03/89 Status of well classification as: Suspended . IApproval No. n'-'' Commissioner Date ~ ~' 7~W SUBMIT IN TRIPLICATE SCU 243-8 D 1 Add Perfs Procedure SR 208 Ob_iective: To add perforations in the upper lobe and to reperforate the middle lobe of the D 1 interval to increase well production. ..Well Data: Completion: Tie-In Log: Minimum Restriction: Tubular Capacities: Pressure Data: 2-3/8" tbg to 5795'MD PDK 100 (5/24/89) Camco 'D' Nipple @ 5752'MD (1.813" ID) 2-3/8" tbg = .00387 bbl/ft Tbg = 2225 psi; PC = 1900 psi; SC = 0 psi Perforatin~ 1. MIRU E-line unit. Pressure test lubricator. 2, RIH w/ perforating guns/CCL. Tie-in and perforate the following intervals: Depth Footage Density 5610'-5618' MD 8' 4 SPF 5630'-5635' MD 5' 4 SPF All depths are referenced to the PDK 100 dated 5~24/89. Shots will be 0 degrees phasing, oriented to the bottom of the hole. Company Schlumberger Arias Wireline Gun _Type HyperDome dumbo der III Size 1-11/16" 1-11/16" 3. POOH and insure all shots fired. RDMO E-Line unit. RECEIVED JUN - ~ ~991 Alaska 0il & Gas Cons. Cornrnis~*un Anchorage Well, SCU 243-8, Spud Date: 2/3/62 Original RKB: 15' Arc~ ~.~laSk. Inc.- Swanson RIw_ Field ApI#:~ 133-10122-00 Well Type: Gas Producer Compl®tlon Date: 2/24/62 Last Worker®r: 6/63 Hanger Type: Dual Hanger: Shaffer Max. Hole Angle:. 2° Angle @'D' Sand- 1.3/4° All Depths are' RKB MD to Top of Equipment. J 5 6 7 8 9 10 11 12 L Jewelry I 5528' 2 5571' 3 5578' 4 5643' 5 5708' 6 5752' 7 5785' · 8 5798' 9 5895' 10 5877' 11 5875' 12 6090' 2-3/8' Camco MM Mandrel Assent~ w/CEV Valve Brown "CC' Safety Joint Brown 5-1/2"X2-3/8' HS-16-1 Packer Brown Expansion Joint. 2-3/8' Camco MM Mandrel Asser~ wi CEV Valve Camco 'D' Nipple Brown 'CC' Safety Joint W.S.O. Halliburton Sand Screen Halliburton Sand Screen Anchor Shoe Top of Cement Bridge Plug Top of Plug Casing and Tubing Bottom Description 20' 94# 0 29' 9-5/8' 40# 0 1858' 7' 23# N-80 0 1854' 5-112' 20# N-80 1854' 6140' 2-3/8' 4.7# N-80 0 5511' 2-3/8' 4.6# N-80 0 1804' Conductor Pipe Surface Casing Production Casing Liner Tubing Heater Stdng Perforation Data 5630'-5640' D1 10' 5834'-5840' D3 6' 5848'-5858' 8' 5865'-5871' 6' 5882'-5885' 3' 5/89 GP GP GP Plugged 6O90' MD 6143' TVD RECEIVED JUN - ~ t991 Alaska.Oil & I~as Cons. comm'~ss~°'JI-B 5/17/91 N~chorage SCU 243-8 E-Line BOPE's Grease Head/ Hydraulic Packoff ---- Lubricator Extension Manual Rams Swab Valve RECEIVED JUN - 3 t.99t Alaska Oil & (~as Cons. Commission ~,nchorage Double Master Valves Wellhead ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSMITTAL #340 TO: John Boyle COMPANY: AOGCC DATE: July 10, 1989 FROM: Tom Wellman COMPANY: ARCO Alaska, Inc WELL NAME: Listed Below Transmitted herewith are the following Blue Sepia Sepia Line Folded Rolled lMylar Tape PDK- 100 GR CCL SCU 243-8 2 1 1 ,,, , , Receipt Acknowledgement: Date: Remm reCiept t{~ ARCO ALASKA, Inc. : A~: Judy Boegler ATO I390A Post Office Box 100360 Anchorage, AK 99510-0360' ARCO Alaska, Inc." ~ Post Office bux 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures ORIGINA June 27, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Subsequent Sundry Notice of SCU 243-8 Dear Mr. Chatterton: Attached is a subsequent report of operations for the perforating of SCU 243-8. SCU 243-8 was perforated in the Lower Chuitna Sand from 5630' to 5640' MD on May 26, 1989. The well is currently producing approximately 700 MSCFD, with no detectable water production. Sincerely, T. S. McCorkle TSM:WMP:ch:0031 Attachment cc: G./~ Graham UNOCAL Corporation A. R. Kukla Marathon Oil Company RECEIVED JUN 2 91989 ~aska 0il & Gas Cons. Commissi~, Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 /'"'-,, STATE OF ALASKA AL ,GA OIL AND GAS CONSERVATION COMM 'ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging m Perforate X Pull tubing __ Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510 4. Location of well at surface 2120' FSL and 1070' At top of productive interval Straight hole. At effective depth Straight hole. At total depth Straight hole. FEL, Sec. 8, T7N, Repair well m Pull tubing __ Other J5. Type of Well: Development .~X Exploratory __ Stratigraphic ~ Service m 6. Datum elevation (DF or KB) 156' KB 7. Unit or Property name Soldotna Creek Unit 8, Well ~;r~b~43_8 R9W, SB&M 9. Permit number/approval number 10. APl number 50--N/A 11. Field/Pool Swanson feet River-Lower Chuitna 12. Present well condition summary Total depth: measured Effective depth' Casing Conductor 29 ' Surface 1858 ' Production 6140" Heater Str lng 1804' Perforation depth: measured 6143 feet true vertical Stra i ght Ho le feet measured 5875 feet true vertical Stra i ght Ho le feet Length Size Plugs(measured) Junk (measured) Cemented 20" Yes 9-5/8" TOC-1812' 7"x5-1/2" TOC-5631' 2-3/8" --- Current 5834-5840'; 5865-5871 ' true vertical 5848-5856 ' Straight Hole Tubing (size, grade, and measured depth) 2-3/8" N-80 5796' , Packers and SSSV (type and measured depth) Brown 5-1/2" x 2-3/8" 'HS-16-1 packer, 5578' MD Measured depth 0-29' 0-1858' 0-6140' 0-1804' Add Perfs 5630-5840' Straight Hole. True vertical depth Straight Hole RECEiVEDI JUN 2 9 t989 Alaska Oil & Gas Cons. Commi Anchorage 13. Stimulation or cement squeeze summary Intervalstreated(measured) Perforated 5630-5640' MD @ 4 SPF with 1-11/16 Jumbo Jet III @ 0° Pha 14. Treatment description including volumes used and final pressure Representative Daily Average Production or InjeCtion Data OiI-Bbl Gas, Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation ...... 900 1630 Subsequent to operation -- 700 -- 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations ~ Oil Gas X Suspended 17. I hereby certify that the foregoing istrue and correct t° the best of my knowledge. 810 2080 Service Signed ~. ¢- ~¢,~ ~ Form 10-404 Rev 06/15/88 Title Cook Inlet Engineering Mgr. SUBMIT IN DUPLICATE lng. ARCO Alaska, ln'c. 4) 5~o3.~,a~ of Al.ar! ~ R,¢nf;e~d ~EL~ CO'~TRACTOR _ iPBDT .... WELL SERV!CE FIF-LD. CISTIqlCT - STATE DAYS . ,;'AT~/., ~/~"~ 9 .... i ,~~_~ .~.,~_ ~,~~ . l ....' ._:. ~ ~-.... ~..~ ..... I OPERAT~ON AT REPORT TIME 4iaska Oil & ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp. j Chill l::~¢i Vlalblllty l Wlod Vel. Slgrled ~ .~.,~., .. . . --. . ............. ~ .,._~,_. .~. ',~.,~.,,~ -~_~___ /'~ ~, /; ~/~ dZ ~ ~ STATE OF ALASKA ~'~'". 0 Ab._.,A OIL AND GAS CONSERVATION COMMIb,.,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Alter casing m Change approved program __ Pull tubing Operation shutdown m Re-enter suspended well w Plugging ~ Time extension __ Stimulate w Variance __ Perforate X Other 2. Name of Operator ARCO Alaska, Inc. Suspend_ Repair well __ 3. Address Post Office Box 100360 Anchorage, AK I5. Type of Well: Development X Exploratory __ Stratigraphic 199510 Service 4. Location of well at surface 2120' FSL and 1070' FEL, Sec. 8, T7N, R9W, SB&M At top of productive interval Straight hole At effective depth Straight hole At total depth Straight hole 6. Datum elevation (DF or KB) 156' KB feet 7. Unit or Property name So ldotna Creek Unit 8. Well number SCU 243-8 9. Permit number 10. APl number 50-- N/A 11. Field/Pool Swanson River-Lower Chuitn 12. Present Well condition summary Total depth: measured true vertical 6143 feet Plugs (measured) Straight holgeet Effective depth: Casing Conductor Surface Production Heater Str lng measured 5875.~ feet true vertical straight holefeet Junk (measured) Length Size Cemented 29 ' 20" yes 1858' 9-5/8" TOC-1812' 6140' 7"x5- 1/2" TOC-5631 ' /~' 2-3/8" --- Perforation depth: measured Current 5834 - 5840', 5865 - 5871' 5848 - 5856' true vertical Straight Hole Tubing (size, grade, and measured depth) 2-3/8", N-80, 5796' Packers and SSSV (type and measured depth) Brown 5-1/2" x 2-3/8" HS-16-1 Packer, 5578' MD Measured depth 0-29 ' 0-1858' 0-6140' Add Perfs 5630 - 5840' Straight Hole True vertical depth straight hole RECEIVED MAY ! Naska .0ff. & Gas Cons,, .C0mi iS ch0rage 13. Attachments Description summary of proposal __ Detailed operations program ~ 'BOP sketch 14. Estimated date for commencing operation May, 1987 _. 16. If proposal was verbally approved Name of approver Dateappr°Ved Service F i e I d Fue I Gas 17. I hereby ce,rtify that the foregoing is true and correct to the best of my knowledge; Signed~,~,,,~2,:~;~~,. - --,... Title Cook I n let Eng i neer i ng Mgr. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- '~' :~.pproved Copy Returned !· Approved by order of the Commissioner ORIGINAL SIGNED Commissioner FOrm 10-403 Rev 06/15/88 15. Status of well classification as: Oil ~ Gas ~X Suspended IApprova' No. '? Date SUBMIT IN TRIPLICATE SCU 243-8 Perforate Additional Gas Sand SR 38 Objective: Perforate an additional gas sand through the tubing and casing. Pressures: Tubing: 1630 psig Shut in. Fluid level at 3069'. 3/25/89. Production Casing: 1120 psig Surface Casing: 0 psig Sa. fety Note: Have fire extinguishers on location. Slickline .Procedure: 1. RU slickline unit. Pressure test lubricator. 2. RIH with 1.8" gauge ting and tag fill. Note any tight spots. Make tubing scratcher runs as necessary. A 1.7" gauge ring was run to 5816' MD on February 23, 1989. RD slickline. Perforating Procedure: o Shoot robing fluid level and ensure that the well is in a balanced condition (static pressure 2711 psig in May, 1962). Verify that fluid is covering the proposed perforated interval and pressures roughly balance reservoir pressure of 2711 psi. 2. RU E-line unit and pressure test lubricator. Run PDK 100 log. Evaluate results and compare with open hole logs. 3. If results support perforating, RIH with CCL, sufficient weight bars, and 10' of 1-i 1/16" perforating guns. See perforating detail below. . Tie in to the packer at 5578' MD. Bleed off robing to obtain approximately 250 psi underbalance then SI. Perforate the tubing from 5630' to 5640' MD. POOH with guns and RD E-line. 5. Conduct flow test per procedure SR 19 (January 16, 1989) as soon as the E-line unit is rigged down. Use extreme caution in bringing well on to avoid producing sand. Peffomtine Detail: -- Gun Diameter: Shot Density Charge Weight. Gun Type Hole Diameter Penetration 1-11/16" 4 JSPF 3.0 grams Hollow steel carder, Jumbo Jet III 0.21" 2" to 4" formation penetration. Based on Atlas Wireline's Perforating Model using existing conditions. REEEIVED ARCO AIm~k~ Inc. is a subsidiary of Atlantic Richfield Company AR3B-6(X) I-A Naska Oil & Gas Cons..~ Commission , ~ ~nchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures May 10, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas COnservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Sundry Notice for SCU 243-8 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to add perforations in Well SCU 243-8. We proposed to perforate an additional gas interval to supplement the current field fuel gas supply. SCU 243-8 will be perforated in the Lower Chuitna sand from 5630' to 5640' MD with 1-11/16" hollow carrier guns, and the well will be tested. With your approval, we would like to begin this work as soon as possible. If you have any questions, please contact Wes Peirce at 263-4228. Sincerely, T. S. McCorkle TSM:WMP:ch:0027 Attachment cc; G. A. Graham A. R. Kukla UNOCAL Corporation Marathon Oil Company RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 ---- :;?el E-Line BOPE's GreaSe Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead RECEIVED MAY 1 5 tgg~ Alaska Oil f Gas Cons.., CorrlmlstffO~ Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12!5 Cook Inlet/New Ventures Engineering August 19, 1987 Joseph A. Dygas, Branch Chief United States Bureau of Land Management Post Office Box 230071 Anchorage, Alaska 99523 Dear 'Joseph: Attached is a Sundry Notice requesting approval to temporarily abandon 39 wells in the Swanson River Field for a periOd of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau of Land Management Regulations. All 39 of the wells mentioned in the attached Sundry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed in Table #1 were identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories- 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in - inefficient production 4. Shut in - save for blowdown Wells. in Categories #1 and #2 are currently under evaluation to determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, H. F. Blacker Regional Engineer Cook Inlet/New Ventures HFB'JWR:ch'O006 Attachment CC' C. V. Chatterton, Chairman ' Alaska Oil & Gas Conservation Commission Form 3160--5 {November 1983) (Formerly 9--331) UNITED STATES SUEM,T z. rs,size,Tn- (OtherInstructions on re- DEPARTMENT OF THE INTERIOR .reedb) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~ this form for proposals to drU! or to de. pen or plug hack t_o a. different rtl. voit. U# "APPLICATION FOR PERMIT--" for such proiw~lL) O~L ~-~ GAR ~ OTHER WELL .... WELL m 2. NAME Or OPRRATOI ARCO Alaska, Inc. 3. ADDIIIt or Oi'laiTOI P. O. Box 100360 Anchorage. AK gqSlO-N't~n 4. LOCATION OIP ',%'r-LL (Report location clearly and i'5 aicordance with any State ~airementa** See also space 17 bdow.) 14. FRRBIIT NO. Soldotn~ Form approved. Budget Bureau No. 1004-0135 Expires August 31, 1985 5. LIAII DIIIONAtlON AND lilt'iL IO. 6. Il' I#DI&I, ALLO'I~BB OB TRIBE NAME CreekTSwanson River Unit MO. 10. fIELD AND POOl,) 0u WILDCAT Swanson River Field At sq~a~ Soldotna Creek Unit - 15 Swanson River' Unit - 22 wells 16. E~VA~O~S (S~w whether Dr, ~. ~ ets.) lj. 8B~** t. B** M** 0u ELK. ~ JUBVI! O! dA Kenai J Alaska 16. Check Appropriate Box To Indicate Nature si Notice, Repod, or Other Data INTENTION TO: FRACTURE TREAT ~IULTIPLg COMPI.ET~ PRIORI TRBATMEIqT . ALTslIMO C&IIN0 8HOOT OB ACID~B ABAN~NO BB~TINO ins.: Re~rt resulm of m~flplo ~mpleUon on W~ (Other) Temporarily abandon __. Completion or R~mpletion Re.ri and ~ tom.) DESCRIUE I'ROPOSED OR CO~IPLETED OPERATION~ (Clearly state all pPrtlnelit details, and ~lve ~rttnent date~ lneludl~ propos~ work. I[ w~l h di~tion~y driU~ wive s~e l~tiuns and me..r~ and true vertl~ dept~ for ~1 merke~ .d Mna ~r~- neat ~ ~is work) · As described in the a~ached memo, ~C0 Alaska, Inc. requests the status o~ the following ~ells be changed to Temporarily Abandoned. SOLDOTNA CREEK UNIT SWANSONRIVERUNIT SCU 13-3 SCU243-8 SRU212-10. SCU12A-4 SCU 13-9 SRU 34-10 SCU 13-4 SCU12A-10 SRU 14-15 SCU323-4 SCU343-33 SRU 21-15 SCU43A-4 SCU 14-34 SRU 31-15 SCU 24-5 SCU 14-3 SRU 432-15 SCU 33-5 SCU23B-3 SRU 34-15 SCU341-8 SCU 34-4 SRU41A-15 SCU21A-4 SRU43A-15 SRU312-22 SRU 21-22 SRU 23-22 SRU 22-23WD SRU212-27 SRU314-27 SRU 23-27 SRU331-27 SRU 34-28 SRU14A-33 SRU 24-33 SRU 12-34 SRU 21-34 18. [ hereby cert~Ltb, at the for. q, oing l~/~ae and correct ~/~ / /~/ / .~ TITLE Region~! Engineer (This space for Federal or State office use) APPROVED BT CONDITION5 OF APPROVAL, IF A~f: TITLE DATE *See IndnPctJons on Revme Side Title 18 U.S.C. Section 1001, makes it a crime for any person kflowiflgl)' and willfully to make to any department or agency of the .................................. e~ *mt, mn~ m_q tn mmv m~tter within its Jurisdiction. TABLE Wells under Evaluation for Rate Potenti al 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future Uti 1 i tS 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 343-33 COMPLETION REPCRT - REMEDIAL ~DRK STANDARD OIL COMPANY OF CALIFORNIA~ ~STEP~N OPERATIONS, INC., - Operator AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND OFFICE: Anchorage PROPERTY: Soldotna Creek Unit Lease No: A-028996 WELL NO.: SCU 243-8 Section 8 T. 7 N., R. 9 W., Seward B & M LOCATION: Surface: 2120' North and 1070' West from Southeast corner of Section 8. K.B. is 16.7' above ground ELEVATION: 156' K. B. DATE: July 23, 1963 C :~ j CHATTERTON', District" 'Su'p~'~i~tendent'~ '~' CONTRACTOR: Santa Fe Drilling Company, Rig # 35 DATE COMMENCED REMEDIAL WORK: May 1, 1963 DATE COMPLETED BEMED~AL WORK: June 14, 1963 SUMMARY TOTAL DEPTH: 6143' PLUGS: 5875' . 5885' 6090' - 6140' CASING: 20" cemen%ed at 29' 5/8" cemented at 1858' 1/2" X 7" combination cemented at 614O' SOLDUTNA OEEEK DNIT~ ' 3-8'- Section 8 T. 7 N., i 9 W.~ Seward B & M STANDARD OIL COMPAN~ OF CALIFORNIA, ~'~ESTERN OPEPJtTiONS,~ INC - Operator May .l~ 1963 Commenced rigging up at 7:00P,M.. May 2,~ 1963 Conditioned Black Magic Mud and killed well. Removed x-mas tree and installed BOPE. Pulled heater string. May 3, 1963 Pulled packer loose and pulled 2 3/8" tubing. Ran bit and casing scraper and cleaned out to 5875'. Circulated and conditioned mud. Pulled and ran open ended drill pipe. May. 4a 1963 Circulated and pulled out. Reran 2 3/8" tubing equipped with Halliburton sand screens. Landed tubing at 5874'. Ran and landed heater string. May 5, ~ 1963 Removed BOPE & installed x-mas tree. After displacing B.M. Mud through MM mandrel below packer with plug in "D" Nipple, closed MM with CEV and let well produce up annulus to raise B.M. above packer and then set packer. Shub in and released rig at 4:00PM. May 7, 1963 Pulled plug out of "D" Nipple and flo~ed well clean throuEh sand screens. Produced well through 2 7/8" flare line. Bean size 64/64", 100-300 psi. T.P. at 1000 MCF/D rate. Rate gradually dropped off to 500-700 MCF/D. During l0 min. shut in pressure rose from lO0~ to 300~ psi. Reduced bean size to 32/64" and flared well. M~£ 9, 1963 Flared well over night on 32/64" bean without change. No change when changed to 64/64" bean. Occasional sprays of oil. Made feeler run to 5862'. O.K. Pulled CEV and flowed well through MM Mandrel, by passing sand screens at 7-8MMCF/D at 900#-1000~ pressure. Produced some B.M. and after 4% minutes lots of water with some B.M.. Flared well. Reinstalled CEV and produced through sand screens at 5000 MO~/D rate, 64/64" bea~. 600# 'T.P. Changed to 32/64" bean and flowed 3500-4000 MCF/D at 900# T.P. Somc H20. Put plug in "D" Nipple, and tubing bled down indicating CEV holding ~ud tubing O.K.. Pulled plug from "D"~ Nipple and flared well. Lost 36' of wireline in hole with sinker bar, jars and pulling tool. May, !!T..17, 1963 Fishing for wireline tools. Unsu¢oessfH1. SOLDOTNA CREEK UNIT ~3-8 S~ction 8 T. 7 N.~ R. 9 W., Seward B & M ~, ~r ~' ~ iNC. Operator STANDARD OIL COMPANY OF CALIFORNIA, ~.~STERN OP~R~rI~No, - May, 3,1~, ,1963_ Commenced rigging up Santa Fe Drilling Company, Rig #35 at 7:00AH. Filled tubing and casing with B.M. mud. Removed x-mas tree and installed BOPE. June. l, 196_3~ Pulled heater string. Backed off 2 3/8" tubing at the Safety joint and pulled out. Recovered wire line tools. Ran retrieving tool and pulled packer loose. Tubing parted at Halliburton tension sleeve. Pulled packer and remainder of tubing. Balance of Halliburton tension sleev$ one 2 3/8" pup joint and Halliburton sand screens left in hole. Jun~ 2, 196.3. Ran a Klustrite mill and milled on tension sleeve. No good - sleeve rotating. Pulled and ran bumper sub and overshot. Unable to get over tension sleeve. Pulled out and reran mill. Milled on tension sleeve 2 3/~ hour, no good, still turning. Pulled and ran one joint of wash pipe. Washed over fish 10'. Pulled above fish and circulated. June 4~ 1963 Pulled wash pipe and ran in with outside cutters. June. 5.,,. 196..3 Made cut below tension sleeve and recovered 18" of tension sleeve and 2 3/8" tubi~ Ran overshot and engaged fish. Unable to work fish loose, sand screens stuck in hole. Unlatched socket and pulled out. Ran 7~' of wash pipe and washed over sand screens ~O'. Pulled. June 6-9~ 1963, Washed over fish to 5848'. Ju~e, 10~ 1963. Ran overshot and attempted to pull fish loose. Releas~'.d overshot and pulled out. Reran wash pipe and washed over to 5861'. June 11, 1963 Washed over fish to 5874' ~bottom). Pulled and ran overshot. Engaged fish and pulled loose. Recovered fish. Ran bit and scraper. Pulled and ran in open ended. Circulated and conditoned hole. ~OLDOTNA CREEK Ui~IT /-~-8 Section 8 T. 7 N., ~TANDARE OIL coMPANY OF CALIFORNIA, WESTERN June 12, 196_3 , Ran Schlumberger Carrier gun and reperforated the intervals 5834'-5840' and 5848'-5856' with 2 - ½" holes per foot. Ran casing scraper to 5875'. Pulled and ran open ended drill pipe to 5875'. Circulated and~ conditioned mud. June 13 ~ 196~, Reran 2 3/8" tubing with new Halliburton sand screens. Ran Heater string. TUBING DETAIL K.B. Depth K.B. to donut Donut and pup joint 179 joints 2 3/8", 4.7#, N-80 EUE 8R Rg.2 Camco MM Mandrel ~/CEV 1 joint 2 3/8", 4.7# N-80 EUE 8R Rg.2 Brown CC Safety joint One 2 3/8'[ pup joint Brown 2 3/8" X 5½" HS-16-1 packer 2 joints 2 3/8", 4.7# N-80 EUE 8R Rg.2 Brown Expansion joint 2 joints 2 3/8", 4.7# N-80 EUE 8R Rg.2 Camco MM Mandrel w/CEW I joint 2 3/8", 4.7# N-80 EUE 8R Rg.2 Camco D Nipple i joint 2 3/8", 4.7# N-80 EUE 8R Rg 2 Brown CC Safety joint One 2 3/8" pup joint 8 Halliburton Sand Screens Shoe Tubing landed at 15.00' 2.18' .. · 17.18' 5510.64' 5527.82' 13.32 '/ 5541.14' ~92' ' ~'~.98'~ 5578.16' .95' 5582.11' 60.81' 5642.92 ' · ~ 3.78' 5646.70' /61.15' 5707.85' ~ 13~15 ' 5721.00' 31.40' 5752.40' "89' 5753.29' 31.~' 5784.48' .93'~ 5785.~ ' 10.19' 5795.60' 80.75' 5876.35' · 37' 5876.72' ~5876.72' Ran heater string .. HeaterString Detail K.B. Donut 15.00' Donut -- .80' 57 joints 2 3/8",4.6#, N-80 EUE 8R ~g.2 1787.75' Heater string landed at 1803.55' Removed. BOPE, reinstalled x-mas tree and tested with 5000~ O.K. Displaced mud with oil. Ju. ne.' .14, 1963 Set packer at 5578' and flowed well clean. Set plug in CEV and shut well.in. Rig released at 6:00 PM. ~ SRH/sat S.R. HANSEN UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURV?! LESSEE'S MONTHLY REPORT OF OPERATIONS .... , Kenai Peninsula C,o,t~-,,,y ........................... Swanson R~ver 8 7:~! 9w ...................... , C.::V ~" /7' ~EC. AND a ' f . .. J (3~L'ON'-, I']~},H~ : r)?' J ! -' I I~EI'OVERb. Dll0lli?, 30 S .ltl(') j ! t so~ c~ u~z~ ~3~8 ! ; Commence~i secbnd remeai~[ Job m~ 31, 1963. Kl~d wen, ~ved x-~s~ t~e and tne~ed~ ~PE. ~covm~d t~bi~ to 5761'. 8a~d sc~e~ ~le~ in hole. ~n ~sh pipe and ~d ~er t0 587~'. ~n so~ and e~ged and ~cove~d ~in~r of fish. 583~'~ ~n c~si~ sc~per. ~n 2 3/8'~ tubi~ with Jewel~ and new Mand Screens. ~n~d tubing a~ 58~7' in d~l ~11 h~d. ~nded~heater st~l~ at 1799'. ~ved ~PE, ~install- ed x-~s~ t~e~and ~~ced ~d with oil' Set packer at 5578'. i ~ state-~- R.~rshall [ Rie~iel~ - C; W. Pe~ ~ j , ~ R4 R. ~tte~ ~ ................................. ~ J , ,., ~ jUL 9 1963 ~ ~ '' ~ ~etroteum 6ranch Atm'= ~ept. o~ Hatur=l Re~urce~ NoT~,.--Thcrc were .................... : .................... runs (~r sales of off; ............... M cu. ft. of gas sold; ................................................. runs or sales of V, asoline during the munth. (Write "no" ~}~cre applicalflm) No'r~:.--I~eport on this form is required for each calendar month, rezardi~:ss of the :al'aLu,; of oper~tlions, and rutpt be tiled in duplicate with the superviso~ by the 6th of the .~uccceding month, unless otherwise ,lfreeted by the supcrvi-,u'. Form 9-;f~ (Jantlary 1950) !ti---~57~6 8 ~. s. :.ovto~,:.,, ,,-;,'~'~t- OFei~;g t.'.r~u I>. 7 · SUBMIT IN DUYLICATE* STATE OF ALASKA (se- off, er in- structions on revez'~e side ~, OIL AND GAS CONSERVATION COMMITTEE i i WELl_ cOMPLETION OR RECOMPLETION REPORT AND LOG* II ,~.~o~w~: o,,, ~ .~ ~ W ELL W ELL DR ~ Other b. TYPE OF COMPLE~ON: XVELI. OVER EN BACK ~ESVR. Other 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCaTiON 0¥ WELL-(Report location clearly and in accordance with a~.y State requiremettts)* At surface At top prod. interval reported below At total depth 13. DATE'SPUDD~ '-114. DATE T.D.: R~FLED' Ii5.. D~TE CO,M.P SUSP O~ ABAS. ~16. ~EVA~ONS (DF, RKB, 18. TOTAL DE.H, N~ & TVD ~9. PLUG, ~K MD & ~D~. ~ ~LT~LE CO~L., 21. ~OW ~Y* ROTARY TOOLS ~,~RODUCING !N~RVAL(S), OF ~IS CO~P~TIO~--TOP, BOSOM, NAME (~ AND :. 24. TYPE ELECTRIC AND OTHER LOGS RUN 5, API NUIVI.F,H/CAL CODE 6. LEASE DF~iGNATION AND SERIAL NO. 7. IF INDiA.N, ALLOTTEE OR TRIBE NAME 8. UNIT,FAI/A'i OR L~SE NAME 9. W~L NO. 10. FIE~ ~D POOL, OR WI~C&T 11. SEC., T., R., M., (BOTTOM HO~ O~E~IVE) 12. PERA'IIT N'O. ! RT, GR, ¢TC).117. ELEV, CASINGttEAD .. DRII, LED BY i CAB I.E TOOLS 23. ~,VAS DIRECTIONAL ) SURVEY MADE , Il I~,~, I -- II I CASING RECORD (~eport all Strings set in well) C G SIZE WEIGHT,, LB/FT, DEPTH SET (1VLD) HOLE SIZE 26. LINER ~CO~ 28. PERFORATIONS OP~ TO P~O~O~ (~n~erval, s~ze and number) m ii ii 30, PRODUCTION SCREEN (MD) SIZE CEMLNTING RECORD A3,IOUNT PULLED ii i TUBING REC Ol~hD DEPTH SEX' (MD) 29. ACID, Si!OT, F:~AC~ USE, CEa',IEN'T SQUE_~Z.~, ETC. DEP//i INTF~V.~L (MD) I AMOUN£ /~ND KIND OF MA~EXIAL USED ~ PACI{ER SET (MD) ii DATE FIRST PIKODUCTION 1 PRODUCTION MEi.[{OD (Flowii~g, gas lift, pumping--size and type of pump) DATE OF TEST, I4OURS TESTED "]CI-1OXE SiZE [pROD'N FOR OIL--EEL. ~--~6W~ TU~ING CA~iNG PRESSURE [dALCLrI.~TED OIL--BBL. GAS---MCF. r>~ss. · · l~-~~ 31. smrosnqos or s~s (Sold, used ~nr ~uel, ve~te~, etc.) - 32. LIST OF ATTACHMENTS I '~VELL STATUS (.Producing or u~mL-in) GAS--~ICF. ViATEPv--BBL. I GAS-OIL ILvrIO WATER--BBL. [ OIL GRAVITY-~I (CORR.) ] J , , TEST WITNESSED BY - 33. I hereby certify that the foregoing and attached tnforma'tlon is complete and correct as determined from ail-available re~'~)rds SIGNED __.~__~_~ ~. C6~ TITLE *(See Instructions and Spaces [or Additional Data on Reverse INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end Io9 on all types of lan:Is and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate prc~duction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the plcJuci~.~l interval, or ~ntervals, top(s), bottom(s) and name (s) (if any) for only the interv~]l ret)orled in item 30. Submit a separate report (page) on this form, adequately identified, for each additior~al intel val to be seperately produced, show- ing the ackiitional data pertinent lo such interval. It~m2~: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 2B: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ~' OF FORMATION TESTS INCLUI)IN(; INTERV^L TESTED. PRF_,F~SURE DATA. A.N'D P,,F_,CbVEH1ES' OF OIL. GAS. 35, G EOI.,OG IC M AHKEI:~ WATEII AND MUD NAME .~ , _ · i"AT^, ^~lq'^C~! l'~rtlE~' DE~SC~IpITI.0NS OI~ LITItOLOGY, PbnO~iTY. FIIAC~Rr~. APP~N~ m~S , , ,, ,, , , ~,r ,, , , UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATI~ .1~ . ka Petroleum, State .......... A~e.Ska Co~u Ken~ Penins~a ~e~a Swanson ~ ~?. ~ ~ .... ........................................................................... D~:- ;f ...... ~ella) 7o~ ~he m~tl~ or ........................... ~Z .......... m_~_, 8o~o~na greek Uni~ " ....................... , ...... ~n~~s__~~_a ................................ ~.~ _C_. _'. ' "~ ~ " "~ '"'- ' ~ ~.'~,~~ ..... . .... . ...... . ~o~ ..................... ~~~_~~! .................................. ~'~ ~ lil~l~_.!~t~l~t~,~} ........ ~o~ ~ CU. FT. OF GAS (In thousands) ~ork May 1, 1962 (~ALLON~ OF (] ASOLIN~', I~,ECOV ERE D · KLlle, I of hole. ]Ran casi~ Idea 2 3/8~ tub~ig ' '. Brown~ 3/8" X ~ter strin~ to 1804 Displaoed Black Ma [. So,stet iavsh~ll w. R. ~tter ~ Se~ice - J. S.'H~a [ BARRELS OF W~?za (I! none, ilo state) REMABKS iii drlllh~, depth| ii shut down. oat~e; daw and r~ul~ of t~t for ~,asoH~o ountent ,d ~) I well aid installed xg scraper and condi- ~ith Hal~iburten s~nd 1/2" HS-l$-l packer . Retook'ed BOPE ami ic mud ~ ith oil and NoT~.--There were ....................................... runs or sales of oil; ............................................. M cu, ft. of gas sold; ............................................. runs or ~1o~ of gasoline during the month. (Write "no" where applicable.) NoT~.--Report on this form is required fOr each calendar month, regardless of the status of operations, and mmqt be filed in duplicate with the supervisor by the 6th of the maccceding month, unless otherwise directed by the supervisor. Form 9-329 (January 19~0) ~6--~1~?o~--8 u.s. eowas~.r .~,,~laa O~FIC~ 8 TANDARD O I L C OMPANT OF C A L IF ORN IA WESTERN OPERA T IONS, INC. · Anchorage, Alaska Er. ~. _~H~ster, Re~i~r~i~or ~~al Survey Anchorag ~ Alaska ~'D' D. Bruce, Chief- Petroleum Branch state Department of Natural Resources P. O. Box 148 Anchorage, AlaSka Gentlemen: 'P, ECE]VECf jU~~;~62 Division of Mines and Minerals Alaska Dept. of Natural Resources CON FIDENT[AL We enclose herewith the ffoll~ .~.oforms.tion and well data for your files and infor~,ation: Yours very truly, STANDARD OIL COMPANY OF CALIF. OE~IA ~,~[estern Operations, Inc. C. V. CHATTERTON COMPLETION REPORT - NN~ WELL STANDARD OIL COMPANY OF CAD~ORNIA. - .WESTERN .OPERATIONS, .. .~ ., INC.. - . OPERATOR.. . ,.. AREA: PROPERTY: WELL NO, LOCATION: ~ATE: June 20, 1962 Kenai Peninsula - Cook Inlet Area, Alaska LAND OFFICE: Anchorage Lease No, A-02§996 Soldotna Creek Uuit · SCU 243-8 SEC. 8~ T. 7 Ne, R. 9 We, Seward B &M 2120~I North and 10?Ol West from Southeast Corner of Section ~8, .To. $ N, ~. 9 We,. Seward B & M. - / // /,A. B-" V', OI-'.ATTE~TON .' DIST, , ,, ,~ ,, ~ U ll DRILLEB BT: Reading & Bates Drilling Company, Rig #6 DATE COmmENCED DRILLING~ February 3' 1962. DATE COMPLETED DRILLING: February 24, 1962... DATE OF INITIAL PRODUCTION: None - Well Shut-in. ~- : ~-~ ' ' .... · .......... '...'.-:'. :., ~.~:.i -.;'.'~ '.'.: '. ::" ~ ,.~_, ,~_ ~ _. , , S~Y TOTAL DEPTH: 6143' PLUGS: 6090' - 6140' JUNK: None cAs ING: 20" conductor cemented at 29 ~. 9 5/8" cemented at 1858' with 700 sacks cement around shoe plus 565 sacks in top job. 5½" X 7" combination casing cemented at 6140' with 700 sacks cement around shoe. PEEF ORATIONS Page 2. 5 - ~" holes at 5605' 5 ~ ~" holes at 5798' 2-~" holes~_foot, interval 5834' - 5840' ~ 2'~" h°leS/foot~ interval 5848' - 5856' % 2-~" holes/foot, interVal 5865' - 5871' ~ 4- ½" holes/foot, interval 5882' - 5885' (squeezed) WELL SURVEYS: , 1, - ~ ~.- le Schlumberger Induction Electrical log, interval 100' - 2024' 2. Schlumberger Induction Electrical log, interval 1869' - 6143' 3. Schlumberger Sonic log, interval 1869 t . 6143' 4. Schlumberger Microlog-Caliper, interval 1869' - 6144' DRILL STEM TESTS: HCT #1 on perf'd interval 5882' - 5885' HCT ~2 on perforations at 5798' .WeS-.O~ HCT #3 on perforations at 5605' W.S.Oe HCT #4 on perf'd interval 5865' - 5871' · HCT #5 on perf'd intervals 5834' - 5840', 5848' - 5856', & 5865' - 5871'. COMPLETION REPORT SOLDOTNA CREEK UNIT 243'8 Page 3. Section 8~ T, 7,~N~ R 9 W~ Seward B & M STAND~ oil~ C6M~ANY OF cALI~'ORNI~ L. WESTERN' o~ERAT~O~S'i-'iNC.''- 'O~ERAT0-~ Feb ,~ua.r7 3~, 1962 Spudded at 11:00 A.M., Fenruary 3, 1962. Drilled 12¼" hole. O - 76' 76' Drilled Washed around conductor pipe in cellar. Cemented with 20 sacks cement and I sack Calseal. Washed out outside cellar. Cemented with 60 sacks cement. I sack CaC12 .and ½ sack Calseal. Stood cemented 3 hours. Washed out again. Cemented with 60 sacks cement and 3 Sa. ks Calseal. ~ebruar~ 4, Drilled out cement. Conditioned mud. Dried 12¼" hole... 76' - 510' 434' Drilled 71 pcf mud Fehr~,ar~ ~,, ,1962 Drilled 12¼" holee 510'~ - 2020' 1510 ' Drilled Attempted to run Induction Electrical log. February 6 - .7, ,19,62 Could not g,et to bottom. Reamed bridges from 844' - 2020". Circulated hole clean. Ran Schlumberger Induction Electrical log 2024' - 100f. Ran 46 joints 9 5/8" casing. Cemented 9 5/8" casing at 1858' in a single stage with 700 sacks of cement using Halliburton power eguipment. Used 1 top rubber plug. Pumped 50 bbls. of water ahead~ mixed 700 sacks cement in 30 mins. using Halliburton truck, displaced in 11 mins. using rig pumps. Average slurry weight 116~. Bumped plug with 12OO psi. Full circulation. Cement in place at 6:27 P.M. Casing froze at 1858'-. No cement returns, cemented in annulus through 1" pipe with 575 sacks cement. COMPLETION REPORT SOLDOTNA CREEK UNIT 243-8 ~pct~?n 8~ T 7 N, R 9 W, Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, W. O. I."- 6~ATOR Februa.r~ 6 - 7, 1962 continued.... CASING DETAIL: 46 joints or 1862.10' Above K.B. Casing cemented at K. B. to landing head Total Casing in Hole Welded landing head on ca sing. 3.75' 18.69' 41839.66 ' Page 4. 9 5/8", 40~, N-80, S8R, Rge 3 equipped with shoe and float collar. Tested with 40OO~ psi, O.K. and tested with 15OO~ - 18OO~ psi - O.K. Feb. r. uary 8, 1962~ Ran 8 3/4" bit. Located top of cement at 1812'. cleaned out to 2020'. 1891 ~ Drilled Drilled 8 3/4" hole. 2020 ' - 3911 ' February 10, 1962. Drilled 8 3/4" hole. 4321' - 4460'. Twisted off mandrel on bumper sub. Recovered all of fish. Drilled 8 3/4" hole. 4460' - 2506' Twisted off 6" drill collar. 139 t DriLled February,Il, 1962- Ran 7 7/8" overshot and engaged fish. Drilled 8 3/4" hole. 4506' - 4837' Installed BOPE Drilled out cement and 72-74 pcf mud Ran 7 7/8" overshot and engaged fish. 46' Drilled 70-74 pcf mud Recovered all of fish. 331~ Drilled 73-75 pcf mud COMPLETION REPORT SOLDOTNA CHEEK UNIT 243-8 Section 8, T 7 N,.. R 9 W, Seaward B& M STANDA~ OIL' COMPANY OF' CAL/}'OP~IA ' W,' 'O.'"i. ' OP~TOR Page 5. February.!_2- 14,. 1962 Drilled 8 3/4" hole. 4837' - 6000' 1163 ' Drilled 76-80 pcf mud Drilled 8 3/4" hole. 6000' - 6143' T.D. 143' Drilled Ran Schlumberger Induction Electrical log 6143' - 1869 '. Ran Schlumberger Sonic log 6143' - 1869I. Ran Schlumberger Microlog-caliper 6144' - 1869'. Circulated and condioned hole to run casing. Removed BOPE. 79-80 pcf mud February_ !6,_ 1962. Ran 5~" X 7" combination casing string. Cemented 5½" X 7" combination casing string at 6140' in a single stage. with 700 sacks of cement treated with 0.3% HR-4 using Halliburton power equipment. PumpeA 50 bbls. of water ahead mixed 700 sacks of cement in 35 ~inSe using Halliburton truck, displaced in 30 mins. using rig pumps. Average slurry weight 116~. Full circulation. Cement in place at 11:15 A.M. Hookload weight of casing ' before cementing 102~000~ after cementing before landing casing 108,000~ CASING DETAIL: 44 joints or Above K.B. X - over 104 joints or Casing cemented at 1863.89' of 7", 23#, B.T. N-80 11.13' 1.50' 4285.74'of 5½" 20~ B.T. N-80 Installed tubing head and reinstalled BOPE. Tested with 4000 psi, O.K. Picked up 2 7/8" drill pipe. COMPLETION REPCRT SOLDOTNA CREEK UNIT 243-8 Section 8. T 7 N, R 9 W, Seward STAND~' OIL COMPANY OF '~L~'ORN~ Page 6. Febr.,u~. ~ 17, 196~ Ran 6" bit and easing scraper t.o top of 5~"_casing at 1852'. Picked up 2 7/8" drill pipe.. Ran 4 5/8" bit and 5~" casing scraper. Located top of cement at 5631t. Drilled out cement to 6090'. Circulated and conditioned mud to log. 77 pcf mud ~ebru~.. ,ar~' ~8,1~ 1~2 Ran Schlumberger Cement Bond log 6087' - 2000'. Ran Neutron Collar log 6090' - 5400'. Ran Schlumberger Carrier Gun a~ shot with 4 - ~" holes/foot the interval '5882' - 5885'. HCT #1 on perforated interval 5882' - 5885'. Tool assembly: 2 outside BT recorders, 3' of perf'd tail pipe, 5½" type "C" Hookwall packer, VR safety joint, hydraulic Jars, 2 inside BT recorders, hydrospring tester and dual closed in valve. Ran on 5836' of 2 7/8" drill pipe. at 5860' with 16' of tail to 5876' Used no water cushion. Set packer Shut in tester at 2:45 P.M. for 20 rains. ISI pressure period. Opened tool to surface at 3:05 P.M. for 45 mins. flow test. Light steady blow throughc~t test. Gas to surface in,lO mins. Shut in tool at '3:50 PA. for 15 mins. FSI pressure. Pulled packer loose at 4:15 P.M. Recovered 800' of wate. ry mud, grading to slightly muddy water. 90' of sand above tool in 2 7/8" drill pipe., Resistivities of water 2.223 ohm/m and 2.340 ohm/m at 600 F. Final Pressure Data: Dep. t..h ,Gauge ~ ]BI IF FF FS~ ~ Top inside 5846' 3086 2662 168 482 505 3086 Bottom inside 5850' 3089 3669 172 488 512 3086 Top outside 5868' 3088 2671 521 2673 2674 3088 Bottom outside 5872' 3098 2681 529 2679 2682 3096 Conclusion: Charts indicate perf's partially plugged~ Tool open O.K. Made up squeeze tools. COMPLETION REPORT SOIDOTNA CREEK UNIT 243-8 Section 8, T..?..N, R .9 ST ~ANDAP~ OIL COMPANY OF CALIFORNIA, W. 'O'" 'i~ -'"~PE'RATOR Page 7. February 19, 1962 Set bridge plug at 5~836', Broke down formation with 4000 psi. Formation took fluid at 1 bbl/min, rate. Squeezed Perf's at 5882t - 5885' with 100 sacks cement. Final pressure 4800 psi. Ran Schlumberger Carrier Gun and shot % - ~" hole at %798'. NCT #2 (test of WSO) on 5 - ~" holes at 5798'. Tool assembly: 2 outside BT recorders, 3' of perf'd tail pipe, 5½" type "C" Hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydrospring tester and dual clOsed,in valve. Ran on 2 7/8" drtq! pipe. Set packer at 5773' with 16' of tail to 5789'. Opened tool to surface at 10:O0 A.M. for 60 ~ flow test. Light blow for 35 mins. dead for balance of test. Pulled packer loose at 11:00 A.M. covered lOl net rise, all drilling fluid. Final Pressure Data: Depth Gauge IH IF FF FH Top inside 5759' 3124 16 16 3124 Bottom inside 5763 ' 3129 21 21 3129 Top outside 5781 ' 3130 33 33 3130 Bottom outside 5785 ' 3136 31 31 3136 Conclusion: W.S.O. - O.K. Ran Schlumberger Carrier Gun and shot 5 - ½" holes at %605'. HCT #3 (test of W.S.O.) on 5 - ½" holes at 5605'. Tool assembly: 2 outside BT recorders, 3: of perf'd tail pipe, 5~" type "C" Hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydrosprtng tester and dual closed in valve. Ran on 2 7/8" drill pipe. Set packer at 556%' with 16' of tail to 5581'. Opened tool to surface at 7:48 P.M. for 60 min. flow test. Very light blow to dead. Pulled packer loose at 8:48 P.M. Recovered 10' net rise, all drilling fluid. Final Pressure Data: Top inside 55%1' 3Oll 33 25 3011 Bettom inside 5555 ' 3010 22 22 3010 Top outside 5573 ' 3013 27 27 3013 Bottom outside 5577' 3028 36 36 3028 COMPLETION REPORT SOLDOTNA CREEK UNIT 243-8 Section 8'.T 7 i~. R 9 W, SeWard B & M S'T~ARD oIL c'~M~A~ OF CALIFORNIA, W. O, :i' -' oP~TOR Feb~ru.a~. 19, 1962 continued..... Page 8. Conclusion: W.S.O. - O.K. Ran 4~" bit and casing scraper. 2O, Drilled out bridge plug at 5836'~ Drilled out cement to 5825'. Circulated and conditioned mud. Ran Schlumberger Carrier Gun and perforated interval 5865' - 5871' with 2 -½" holes/foot, using No-plug jets. HCT #4 on 2 - ½" holes/foot interval 5865' -~51871'. Tool assembly: 2 out- side BT recorders, 3' of Perf'd tail pipe, 5'2" type "C" Hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydrospring tester and dual closed in valve. Ran on 5779" of 2 7/8" drill Pipe. Used 300' of Drilling mud cushion. Set packer at 5804' with 16' of tail to 5820'. Opened tester at 2:14 P.M. for ~ min. pressure release. Shut in tester at 2:15 P.M. for 15 min~ ISI pressure period. Opened tool to surface at 2:30 P.M. for 25 min, flow test. Flowed gas at 7000 MCF/D rate. 180~ on side static wi~n z4 orifice. Recovered no rise - dry. Blew out mud cushion. Shut in tool at 2:55 P.M, for 30 min. FSI pressure. Pulled packer loose at 3:25 P,M. Final Pressure Data: Depth Gauge IH ~_! IF FF FSI, FH Top inside 5790' 3100 2667 1974 2569 2668 3100 Bottom inside 5794' 3098 2669 2015 -. 2577 2670 3098 Top outside 5812' 3101 2666 2204 2607 267% 3101 Bottom outside 5816' 3117 2679 2219 2622 2681 3117 Ran Schlumberger Carrier Gun and perforated the intervals 5834' - 5840' and 5848' - 5856' with 2 - ½" holes/foot using NO-plug Jets. 76 pcf mud Ran 4½" bit and casing scraper. Circulated and conditioned mud. :Ltl Ran HCT #5 on 2 ~ holes/foot 5834 ~ 5840', 5848' - 5856', 58~' - 5871', tool assembly: ~ outside BT recorders, 3' of per£'d tail pipe, 52" type "C" Hookwall packer, VR safety Joint, hydraulic jars, 2 inside BT recorders, hydrospring tester, and dual closed in valve. COMPLETION REPORT SOLDOTNA CREEK UNIT 243-8 SectiOn 8, T ..7. N~. R 9 W, Seward B & M STANDARD' 6iL COMPANY ~ CALi~'C~NI~', 'W'~i' '6. I'i' OpERATOA Page F?bruary' ~, 1962. continued...... Ran on 5779' of 27/8" drill pipe. Used 300' of drilling mud cushion. Set packer at 5804' with 16' of tail to 5820'e Opened tester at 10:25 A.Me for 2 mins. pressure release~ Shut in tester at 10:27 A'M. for 18 min. ~BI pressure period. Opened tool to surface at 10:45 A.M. for 120 min. flow tests Blew mud cushion and gas 10:45 until 11:00 A.M. Put out flares. Cleaned up by 11:00 A.M. ~" bean pluEged. (surface)~3/8" surface beanm- ½" subsurface 11:00~ to 11:15 3210 MCF . ened to ~" surface bean ~" subsurface at ~1:15 t? 12: /D - t 20 P~M. 6230 MCF~D to 7580 MCF/D. (acted like bean was cutting ou ) Open- ed to 1" surface be~ blew out flares - flow line began to move, At ~2:20 - unsafe. Placed on 1/8" surface bean at 12:30 P.M~ (~" Subsurface) Flowed 379 MCF/D rate. Placed on ~" surface bean at 12:32 P~M. - 1060 MCF/D rate. Placed on 3/8" surface bean at 12:39 P.M. - 3210 MCF/D rate. Shut in tool at 12:45 P.eM. for 33 min. FSI pressure. Pulled packer loose ~.t 1:18 P,M. with 10,0~ Final Pressure Data: Depth Gauge ]/{ ISI IF FF FSI FH Top inside 5790' 3165 267023982647 26713156 Bottom inside 5794' 3163 267424722652 26733163 Bottom outSide 5816' 3183 2683~61 ~675260~3263~ 2682 3171 Ran open ended dr~ll pipe. cirCulated. 79-80 pcf mud Februar.y 22 - 23, 1962~_ Ran 23/8" tubing as follows: K.B. to top of hanger Difference - fl ~ange to tubing landing mandrel 178 joints 23/8" tubing Camco sleeve valve 1 .joint 25/8" tubing Brown safety joint Pup Joint Brown HS-16-1~ packer 2 joints 23/8" tubing Camco "D" nipple 8 Joints 23/8" tubing Venturi shoe Tubing hung at 15.40, elO~ 5476.46 ' 2.47' 31.67' .94' 9.72' 4.08' 60.91 ' .90~ 244°90' .60' Removed BOPE, installed X-mas tree.. Pressure tested X-mas tree with 3500~ psi - O'K. Set packer w/2000 psi. Pressure tested tubing w/40OO psi and casing with 2000 psi. O.K. Opened Camco sleeve valve. Displaced mud with oil. DEVIATION DATA Depth 3361 ' 4036' 4221 ' 5o45~ 53~o' 568o' 5836' 60O0' Degrees oo45' 2o00~ 2o0C ' 0045' 1900 ' 1°45' 2000, 2 °00 ~ COMPLETION REPORT SO~DOTNA CmmK UN~ 243'8 Section 8, T ? N, R 9 W, Seward B & M STAND'A~ OIL c'OM~ANY OF cAL~OR~, W''~' 0'-I," ", 'OPERATOR Page 10. ~ebruar~ 24, .l~ Closed sleeve valve. Flowed well clean. Installed cosasoo plug. Rig released at 1:55 P.M. February 24, 1962. ~ROI:::'O S E D LOCAT 16N ~,OL DOI'NA CRE~K, _ ST~NO~RI) OIL COHP~H¥ OF ¢~Lilr~Rlll~ l($TEII Of[llTlOlIS. IgC. 'RECEIVED MA 3 1962 Petroll~um Branch Division o{ Mines ond Minerals UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY REPORT OF OPERATIONS State ......... .A_~a_~.a_ ............... Co'~nty ..... .ge__ .ng_ ~.._ _Penin s_ .u~. __a_ Field ..... Tke following is a correct report of operation,~ at~cl productior~ (inclt,'~din2' drillirc~ arid prod~cing wells) for the month of ....... F_e~.~ ..................... 1~62 ............. S~otna Creek ,gni~ ........................... .tgent's address .... Po O. Box 7-8~ ~ Stinting.Oil ,O~y of, California Phone ~f~e~Fs WE'LI DA~,a _ ~ r,. ......... [ G&LLoNS 0~' { BARRI,IL,',q Or REMARKS ~ O~ ~ TWP. ] D~ed 1~ h~e 0-~6'. Washdd out ~=d ce]$a~. Cemented SE ~ t~e~ ti~s ~i~ a t)tal of 1~0 sacks cSmnt be%re 0.~, Drilled ~ l~]hole 76' ! 2020~. Reared4 ~ I-Es 1~' , 2024'. Ce~ntea ~ 9 ~/O" casi~ at 18~' ~sre ~oze withl 7~ sacks. No cement to w/l~O - 1800 ~t - p.K~ Loca~ top o~ cement ~at 1812'. D,ill~ out ~sment ~d ~rilled 8 3/h" ~ole 2020~' - ~60~. ~sted off. 7/8. o n,a hole~ ~60' - ~0~'o ~s%ed ~ff. g~)oversho$. Engaged .and and ~o~c log ¢~9':,- 61h3'. ~ ~ eement,d 15'~" x ?".comb- i~t~on casing Btring at 61[0' J~th 7~i s~ok~ eomento Located top Of cement ~ ~63~. D~ll~d out ce~nt to 6090'. R~ CBL. ' . hol,~/foot 5882 - ~8~' got HCT ~1. PhcRer atig860'o Light bl~,$t~ou~hout test. Recovered 8~' watery mu~. Squeezed oerf's at 5882' - 5885 ~th 100 sacks ce~nt.~ 3hot 5~- ~" holes at , ' [5798~ for HCT ~ ~o W$O, O.K. ~er~orated 5 - ~" holes at 5605' ~ lfor ~CT ~3. ~D O.K, Drilled ~ut cemen~ retainer at 5836' ~d Copies to~ ~c~edt to 5875'~ Perforated ~e interval 5865' - 5871' with 2 .~' ~'~ h~les/foot fbr HCT ~4. Flied dry g~s at 7000 MCF/D rate. ~~~~GIS'~ ~'GH'~ ~ter~Perf~rated the ~nter+als 5834~- 5840~aad 5848~- 5856, with C - ~ ]2 - ~" holes/f~t. ~ HCT ~5 on perf'~ integrals 583[' - 5~40~, ~ D ~Bm~e ~5848'~- 5856' ~d 5865' - 5871'. Set p~cker at~5804'. Used ~chfield ~1 o W. Per~y l at 6~30 - 7580 MCF/D~rate o~ dry gas through ~"~bean. 33 minutes Files: rodu.i~' .~tub~g at 5848'~ S~$ pacer at 5537'. $Instrll~d x-mas tree. /~d j [Test~ ~th 3500 psi. ~g ~lsased Feb~r~ 2~, 1962. . . No~r.~Them were runs or saI~ ~ oil; ................................................ M cu. gr. of g~s sold; .............................................. runs or ~ of gasoline during the month. (Wri[e "no" where applicable.) No~.--Report on duplicate with the sup~visor by ~he 8th of the suce~ing month, unl~s otherwise directed by the supervisor. Fo~ 9-B29 ' APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK NAME OF COMPANY OR DATE Address .... - ' ~' ~-~' - ~ ·: ' ? ~-~ ~ ~ ~ City - ' ' ~t~te Name of legsp ' ,Vell number ] Elevatio~und) , ,, Well location (~ive footage from section lino~) 8eetlon~townshiP~ran~o or block ..-~ ~~Field & resgr~vol~. (~f::~ldcat,~~o~:state) ~ ~'": .-_.~~~.:- ~ Distance, in miles, and direction from n~arest town or post office · ' ..:~?~ .~ -.- -'~ "~L; .'~',~ ~':'(%.~q..f;- d. '~- ~' ~ Nearest distance from-proposed location to property or'lease line: eet Proposed depth: Rotary or cable tools Number of acres in le~se: Distance from proposed location to nearest drilling, completed or applied--for well on the same lease: feet Approx. date work will starl Number of wells on lease, including this well, completed in or drilling to this reservoir: If lease, purchased with one or more wells drilled, from whom purchased: Name Address Status of bond Remarks: (If this is an application to deepen or plug back, briefly describe work to be done, giving present producing zone and expected new producing zone) RECEIVED JAN 4 196'2 Petroleum Branch Divk, i~n of M!nes ' ~'~grals (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. Permit Number: ~ ~ ~2 Approval Date: ~1~1'!11~'*~~ l&, ~J.:q~_ .--. , Notioe: ~efo~e sen~g ~ this ~o~ be sure that yo~ have aH ~formation requested. ~uch unnecessary correspoffd- ence will thus be avoided. See Instruction on Reverse Side of Form Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. I Effective October 1, 1958 ~~r !8, 1~61 %, ~eL~ ~li ~2-8., and will ~ ec~t~%~ in ~uch a manner ~ to all~ ~ig~ %l~e reeerv~ pit in ~u% ~a%e~al. · W~ ~~ ~/our ~prova! of ~$ surface !eca~i.~m in order to a~ ~img con~tr~ctlon ~.!c im~e~%ely. . ,. .... ... _. ,3~ ~l.esources,~ / T 54'8 , / ~ROPOSED LOCATION ~ELL Z4.~ -~ SOLDO1'NA CREEK UNIT 0IL C0ilPAtI¥ OF IESTEII OPEIATIOI$, IK, r Feb. (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT Of THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS 'ON WELLS NOTICE OF INTENTION 'FO DRILL ..... X i ......... ' SUB.~EOUENT REPORT OF WATER SHUT4)FI NOTICE OF INTENTION TO CHANGE PLANS ......... SUBSEQUENT REPORT OF SHOOFING NOTICE OF INTENTION TO TEST WAT£R SHUT-OFF ......... SUBSEQUENT REPORT OF ALTERING CAqlNG NOTICE OF INTENTION TO RE-DRILL OR REPAIR WELL__ I SUBSEQUEN[ REPORT OF RE-DRILLING OR REPAIR NOTICE OF INTEN] iON TO SHOOT OR ACIDIZE - - iiSUBS[QUEN~ REPORT OF ARANDONMI:.NT NOTICE OF INTENTION TO PULL OR A[.TER CASING ....... SUPPLEMENTARY WELL HISTORY NOTICE OF INTENTION TO ABANDON WELL tI~IDICATE ABOVE BY Ct~EC~ MARK ,~4A7 U~:I£ OF I~'PORT. NOTICE. OR O~/tJER DATA)· approxinately ,.,, Well No. SCU 21~3-8 is located/ 2120. . ft. from ~'~a~ line and 1.070 ft. from i.l~.; line of ~_. aa~ ~. ~'~1. _Sec. o _.. ~. 7 ~., a. i~ ~. _ ....... _Se~ra ~ (74 F,., and St, c. No) Twp.) {1{ ,,,g, (~fe1:.han) ~e.uson l~ve~, ~~ Pe~u~ F ,eld ) sec. 8 The elevation et the ~ above sea level is _ 172 ft. ~pproxtmatel4r. DETAILS OF WORK (State names of and expected depths to objective ~andsl show sizes, weiEhts, and lengths of proposed casings; is,dicate rnuddinl~ jobs, cement- ing points, and all other important proposed work) 1. 9rill to 2000', log and cement 9 ~/8" caaln8 to surface. 2. Install and test Ols. aa ~. llrill ahead to 610~'~ lo~ amd cement ~. Establish requlsit~j vater shsatooff's. ~. Selectively ~et perforate attractive sands o~A te~t as necessary. 6. ~n 2 ]/8" t~btns an~ ~mp~te. ! under, tend that this plan of work must receive approval in wrlt|nI by the Geological Survey before operations n~ay he commenced. Company ....~ OIL Address ..... P._ q~ ~_ 7~39 .......... ............... ~c~_~ae, ~~ ............. By Title 062040 Well Histow File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this. .nature is accumulated at the end of the file under APPE .N. DlXl .. No 'special'effort has been made to chronologically' organize this category of information. PROGRAM: LISCAN REViSI~ON: 5.1 PART NUMBER: W5790-PE32 S~a~Fr~ of e~ecu,tion: Mon 26 JUN 89 4:29p **** REEL HEADER **** LIS 89/24/05 ATLAS 01 'LIS CUSTOMER LIBRARY T~PE' **** TAP: H:ADER **** LIS 89/24/05 3844 , 01 ~'PDK-IO0: MAIN PASS AT 5780-2964 FT~ REPEAT AT 5785-5521 FILE # 1 MAI!N .001 **** FILE HEADER **** 1024 CN ~N FN COUN STAT -~i~]CO /~LASKA INC SCU 243-8 PRUDHOE 6AY NORTH SLOPE ALASKA , FORMAT RECORD (~TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 19 CURVES : NAME CODE SAMPLE# UNIT VOLT 3 LS 68 I CTS 4 SS 68 I CTS 5 G1 68 I CTS 6 GElS 68 1 CTS '7 G2 68 I CTS 8 GR 68 I API 9 MON 68 I CTS 10 MSD 68 I CTS 11 SGMA 68 I DIM 12 CSS 68 I CTS 13. ISS 68 I CTS I 4 BKL 68 I CTS I 5 BKS 68 I CTS 16 RATO 68 I DIM 17 RICS 68 I DIM I 8 RIN 68 I DIM 19 RBOR 68 I DIM BYTES 4 4 4 4 4 4 4 4 4 4 4 4 * DATA RECORD DEPTM G1 (!TYPE# O) CCL GElS 966 BYTES * SPD $2 LS GR SS MON ~KL 57~0,000 0,0000000 0,0000000 0,0000000 5730,000 15663,69 0,2995045 268,2319 5680.000 14969,93 0,2359501 337,1160 5630,000 19415,70 0,1783381 .367,4309 5580,000 8208,531 0,2455765 178,1190 5530.000 10655,82 0,2571021 229,0310 5480,000 11516,38 0,1216725 216.9350 5430,000 9683,746 0,3753021 297,2429 5380,000 11323,$4 0,2962121 284,5630 5330,000 9881,730 0,3749853 193,0490 5280.000 14449.68 0.2660877 265,9131 5230,000 10509,43 0.1991368 167,0840 5180,000 10262,52 0,3260725 195,2680 5130,000 12120,21 0.1340157 279,1741 300,0000 0,0000000 0,0000000 0,0000000 0.0000000 147079,5 15,02108 17.54625 735,5999 169886,4 23,36290 22,67.804 0,0000000 185328,3 20,10899 18,63196 0,0000000 81634,69 21,71484 27,61569 0,0000000 129761,6 22,83182 25,10965 0,0000000 132774,7 20,91164 23,01106 0,0000000 132474,2 24,41566 25,19279 0,0000000 135052,3 22,25262 23,42778 0,0000000 117725,3 22,97595 24,18135 0,0000000 137920,9 18,02415 20,50882 0,0000000 114743,6 21,82686 24,11353 0,0000000 132322,3 24,51157 26,01501 0.0000000 141217,9 22.53392 23,94157 0,0000000 0,0000000 0,0000000 0.0000000 13,99860 5905,316 30658,34 11,35155 13,99860 3270,226 34945,58 11,91203 13,99860 5176,762 40192,13 11.46816 13,99860 1953,824 17361,14 13,91011 13.99860 2376,401 25368,41 13,47107 14,99850 2902,979 26086,53 13,34805 14,99850 1981,938 24672,17 14,t2730 14,99850 2644,554 26754,29 13,87662 14,99850 2187,093 23172,35 13,94194 14,99850 4434,$52 29224,05 12,45381 14,99850 2548,484 23489.52 13,65591 14,99850 2052,896 25583,95 13,72224 14.99850 2781,976 27972,82 13,14289 0,0000000 0,0000000 0,0000000 5,000000 2579,568 47,96028 359476,3 12,98858 2537,122 51 ,27396 419471 .8 8.426418 3472,816 46,46019 453388,1 $,148136 1026,818 17,89433 240319,9 15,36366 1607.988 31,30302 341434,6 13,98450 1775,102 28,98798 348490,9 13.09440 1540,199 37,10143 349188,1 13,18981 1789,347 34,00046 358234,5 13,36786 1534,286 16,31448 310445,3 12,56372 2216,721 24,38690 360396,9 12.35760 1569,306 12,86864 315027,5 12,37115 1579,023 29,28514 348425,7 12,17906 1868,684 26,35739 370735.6 11,67827 0,0000000 0,0000000 0,0000000 -1,000000 45050.77 2001,850 t21.4710 I ,514145 57611,70 2003,249 130,9060 1,416860 64853,71 2003,207 118,8340 1,426453 28317,48 2002,356 33.81601 1,425908 40355,68 1999,556 45,91301 1,491625 40780,10 1998,801 57,55699 1,516120 38877,20 1993,199 85,37802 1,529972 41864,48 1998,763 66,28902 1,507770 37090,66 1998,510 29,93700 1,530674 45460,95 1999,089 69,67500 1,472992 37897,52 1997,543 34,80701 1,495526 41210,59 2001,164 67,06100 1,484586 44704,23 1999,508 63.66800 1,478393 ~N~N.NNN N.NNNNNNN 1~_1N77N I~N_&R1 XOTXN_I& 2'5 I 3. 97903 1 2,78878 1 · 502998 5030,000 10749,31 0,4652169 235,6570 4980,000 10214,34 0,3562921 290,506t 4930,000 12403,83 0,1601096 261 ,5830 4880,000 12381,72 0,2553449 270,3411 4830,000 9581,891 0,3781989 225,2t40 4780,000 12092,52 0,3402700 266,3391 4730,000 8374,484 0,2499745 271.5859 4680.000 11864,30 0,3377408 278,4741 4630,000 1.2345,77 0,3046625 309,2751 4580.000 10762.07 0,3400645 257,4690 4530.000 9438,535 0,2606644 243,8280 ~480,000 12277,26 0,2228449 255,9640 4430.000 11032,64 0.3078600 249,1240 4380,000 12002,69 0,2998881 278,4280 0,0000000 134065,5 22,73259 23,15099 u,O000000 129017,6 22,52348 24,47855 0,0000000 131305,7 18,96286 21,90573 0,0000000 126772,2 20,24995 21,98924 0.0000000 127367,1 24,14262 25,98425 0,0000000 126466,8 20,46698 22,48935 0,0000000 120154,4 25,12274 26.01535 0.0000000 128439,3 21,32959 23,36562 0,0000000 142197,9 21,2931i 21.53951 0.0000000 133391,2 23,44260 23,31165 0.0000000 128302-4 24,50717 25,00670 0.0000000 139717,6 21,00978 21,14993 504.0000 131388.1 21.12z, 28 2! ,38278 0.0000000 131774.1 19.82175 20.83698 15,88920 2419.045 25849,91 13,79340 I 5,99840 2386,494 24609,61 13,91853 15,65340 3606,446 26710,12 13,29034 15,99840 3341,194 26254,63 13,34901 14,99850 2050,568 24222,27 14,23273 16,99831 3206,785 26184,79 13,75975 16,99831 1653,298 22343,86 14,62750 16.99831 3032,768 26190,68 12,95903 16,9983t 3055,651 27983,46 13,48988 16,99831 2282,971 25933,87 14,27976 16,99831 1930,399 24133,80 14.10626 16.99831 3129,728 27655,67 13,08242 16,23421 2736,268 25417.94 13,32116 15.99840 3307,880 26321,17 13,21461 1757,996 30,91669 349937,2 12,52723 1562,855 25,45877 342142,8 12,82995 1894,945 26,47813 350871,9 12,66089 1875,786 20,91832 345142,0 12,53902 1490,179 28,50377 339393,1 13,07127 1836,755 22,95615 344622,1 12,80295 1373,096 30,97102 329052,9 13,15812 1755,781 26,68370 348231,9 12.60098 2033,187 25,94167 368348,8 I 2,96299 1777.857 30.70190 350653,9 12,57169 1521,499 29,35846 346778,9 12.72625 2052,104 24,92279 364371,8 12,48200 1846.686 21,81656 348950.6 12,98919 1949,385 17,70042 348546,4 12,49231 40807,23 2014,800 69,15300 1,523219 38298,~3 2015,362 61,75200 1,505627 41457,47 2013.790 79,52701 1,486340 413~7,20 2014,779 67,16701 1,504005 38650,35 2016,741 76,33601 1,500229 41479,34 2016,010 71,57201 1,473535 35684,63 2015.080 68,26700 1,487752 41718,95 2019,013 62,03600 1,477030 43763,98 2019.133 64,46001 1,525500 41674,60 66 900 I ,521365 38157,36 2018,829 80,11601 1.545368 43383,91 2018,501 61,70900 1,535021 39388,62 2019,663 55.26100 1,509292 40628.5O 2020,346 46,29601 1,506724 12015.11 0.2418425 272.0391 4280.000 11431,00 0,4515657 286.9460 4230,000 11448,09 0,1982589 232,8550 4180,00'0 10851.00 0,3204605 236,3320 4130,000 10774,46 0.2932149 234,8180 4080.000 11326,32 0.1787984 276,4011 4030.000 11724.05 0.1588380, 216,6570 3980,000 9035,113 0.32811752 265.8521 3930,000 8710,531 0.3691321 225.0170 3.880. 000 11318.02 0~17,72 3830.000 12237.99 0.3023241 285'6941 3780,000 10022.54 0,2697741 293,8059 3730,000 10821.38 0.3249441 303,5659 3680.000 8124,387 0.3046489 258.3010 3630.000 1 0086,6 8 126758.4 19,55623 21. 43532 0,0000000 137741.3 21.76482 22.08615 0.0000000 129248,6 22.02109 22.27208 0.0000000 129659.1 21.81120 22,74001 0.0000000 132267,6 22.59456 22,87062 0,0000000 130535,7 22,40878 22,69016 0,0000000 129092,7 21,07933 21,34071 0,0000000 123418.0 25,57402 26,06459 0,0000000 121399,7 25.24280 25,72650 0.0000000 127726,2 21. 7274 22.~5710 0,0000000 124546,5 20.15994 21,45952 0.0000000 123116,4 23.35847 22,42453 0,0000000 121969.0 20.85674 21,13312 0.0000000 124582,8 27.15543 24.65372 0.0000000 130162.5 3315,206 25686.35 13.22447 15.99840 2762,988 26842,69 13.46610 15.99840 2718.500 25903.93 13,35909 15,99840 2577.339 25435,75 13,49028 17,88901 2469.452 25525,03 13.83411 17.99820 2612.311 26064,22 13,42196 t7.99820 2874,889 25945.14 13,30020 17.34331 1660,849 23421,09 14,32556 17.23410 1 742. 403 22804.81 14.06206 16.99831 2723.592 2 58 16.99831 3305.386 25944.95 13.83314 16.99831 2182,118 24015,70 13.97541 16,99831 2800.036 24302,06 13.30573 16....99831 1384,239 22683,25 14,46848 1 6,99831 2163.579 342887.6 12.64417 1916.455 27.80974 361521,5 12.57895 1846.594 22.91530 345449.1 13.05667 1765.724 21.26358 343491.8 12.67575 1762.609 18,81926 345216.8 12.68602 1838.018 24,38776 350079.7 12.75466 1918.551 18.16800 342788.3 12.53170 1441,405 19.61856 332509,4 12.78229 1423.874 22.65463 330017.9 12,75978 1835,939 20,54494 342243.4 12.62826 1918.425 23,31339 340680,6 11,95506 1703.420 23.14508 335230.6 11.59325 1818.381 25.62195 337328.2 11.87896 1466.803 29.86420 330633.7 11.41147 1759.924 26.58113 ~020,906 31.26900 I ,504945 42405.67 2021,694 54.72101 1,532470 41137.01 2021.455 46.15501 1.487107 40117.32 2022,451 57.92101 1.493961 40273.83 2022,532 41.67000 1.505221 41732.84 2021.197 86.19200 1.478418 40941.59 2023,543 23.34801 1.500050 37656.19 2021.772 58.19699 1.481296 36593.73 2022.572 60.96201 1.529287 40633.43 2022.581 41258.85 202Z .048 59.90901 I .501101 38283.27 2019.970 54,53300 1.485645 38318.29 2023,256 60.16301 1.511606 36193.91 2021.054 74.72401 1.526547 39019.82 2021.528 3580.000 9135.992 0.4019468 269.6570 0.0000000 120307.0 24.12752 24.23923 16.99531 1865.624 22829.49 15.09508 1486.815 28.04675 333381.8 12.46828 36138.76 2019.048 78.88202 1.528032 3530.000 8584.781 0.2148620 319.5950 0.0000000 126139.4 26.55719 24.37003 16.99831 1529.479 23395.14 14.39625 1536.309 33.00880 337636.3 11.68554 37402.48 2022.402 78.39801 1.523149 3480.000 8164.559 0.5022485 302,8000 0.0000000 117493,6 27.33905 25.66522 16.99831 1358.809 22141.20 14.47204 1411.262 32.38507 321435.7 11.83601 36267.55 2020.467 86.32802 1.497168 3430.000 9974,586 0.2116616 272.1t91 0.0000000 121348.3 24.18423 22.90997 16.99831 2063.463 23887.74 13.93776 1678.695 30.41653 32740?.6 11.88816 38453.13 2021.295 64.55600 1.478624 3380.000 8122,789 0.3783645 239.5750 0.0000000 116979.6 26.72966 24.84590 16.99831 1408.266 Z2107.87 14.12740 1455.867 33.64232 309699.1 11.05680 36102.48 2021.898 76.14301 1.493873 3330.000 12903.44 0.1896289 312.2561 0.0000000 121614.2 20.20244 21.09683 16.99831 3472.372 26302.16 12.65130 2007.447 30.60045 331483.8 11.88878 42336.53 2022.442 59.87500 1.448108 3280.000 11316.63 0.25?5737 274.1460 0.0000000 121621.6 21.11362 21.88133 16.99831 2843.486 24826.28 13. 2801 5 1802.326 30.69341 329821.7 11.97823 39425.63 118 1.468375 3230.000 11164.60 0. 161 21 29 299.6650 0.0000000 116314.1 21.78165 22.33829 17.10750 2660.233 24274.36 12.99944 1754.429 27.17656 315696.3 12.02367 39243.49 2018.311 68.50902 t.464230 3180.000 12236.19 0,3282401 295.8940 0.0000000 123049.0 20.09300 20.87700 17.99820 3300,905 25650.43 13.77582 1931.094 26.18004 332835.6 12.39590 40495.98 2020.221 91.12402 1.476228 3t30.000 11475.27 0.3315744 253.8900 0.0000000 117053.3 20.35730 21-79152 17.99820 3031.120 24495.92 13.12910 oo. 76 27.04544 323284.6 11.93910 39172.94 2021.$$6 65.40401 1.465252 3080.000 11999.57 0.1409556 264.6389 0.0000000 120745.0 19.81732 20.93643 17.99820 3277.378 25295.86 12.96744 1922.611 28.18549 327433.4 11.71859 40266.80 2022.776 68.64900 1.483011 3030.000 11783,56 0.2900673 274.3140 0.0000000 117471.3 20.38008 21.20448 17.10750 3122.297 24845.25 13.30722 1873.711 25.20250 321599.9 12.40364 39767.83 2021.474 71.42401 I .481707 2980.000 0.0000000 0.0000000 0.0000000 0.0000000 0.0000000 0.0000000 0.0000000 0.0000000 0.0000000 0.0000000 0.0000000 0.0000000 29.67619 0.0000000 5.000000 0.0000000 0.0000000 0.0000000 -1.000000 TOTAL D~TA RECORDS STARTING TAPE DEPTH **** FILE TRAILER **** : 470 = 5780.00 ENDING DEPTH = 2964.00 1024 FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 19 C U R V E S : NAME COOE 1 CCL 68 2 SPO 68 3 LS 68 4 SS 68 5 G1 68 6 GE1 S 68 7 G2 68 8 GR 68 9 ~ON 68 10 MSD 68 11 SGMA 65 12 CSS 68 1 3 ISS 68 14 BKL 68 15 BKS 68 I 6 RATO 68 17 RICS 68 18 RIN 68 19 RBOR 68 SAMPLE# UNIT BY 1 VOLT 4 I FT 4 I C TS 4 I CTS 4 I CTS 4 I CTS 4 1 CTS 4 1 API 4 I CTS 4 I CTS 4 I DIM 4 I CT S 4 I CTS 4 I CTS 4 I CTS 4 I DIM 4 I DIM 4 I DIM 4 1 DIM 4 TES * DATA RECORD DEPTH G1 MSD 5785.000 0.0000000 0.0000000 0.0000000 5735,000 19005,65 0,1369032 743,1863 5685.000 15629,39 0,1489985 330,8789 5635,000 19033,54 0,2124033 259,7939 5585,000 5228,020 0,3767144 1:34,4990 5535.000 0.0000000 0.0000000 0.0000000 (TYPE# CCL GElS SGMA RATO 300.0000 0,0000000 0.0000000 0,0000000 0.0000000 1~56392,0 .16,68442 20,02219 0,0000000 159209,4 21,58015 19,87195 0.0000000 154865.0 t5,65484 14,33618 0,0000000 58349,04 21,68552 25,48709 494,0999 0,0000000 0,0000000 0,0000000 0~) 966 BYTES * SPD G2 CSS RtC S 0.0000000 0.0000000 0.0000000 0.0000000 13,10790 6349.398 35110,07 10,97372 12,99870 3793,657 33.807,36 11,89915 13,99860 6929,891 35200,50 10.97782 14,76270 1247,828 11706,85 18,03978 0.0000000 0.0000000 0.0000000 0.0000000 LS GR ISS RIN 0.0000000 0.0000000 0.0000000 5.000000 2706.400 225,9615 387093,4 11,63338 2775,271 33,71754 391412,6 8,231609 3753,064 23,98709 397393,7 7,925663 740,1611 4,046384 215459,0 19,28011 0.0000000 0,0000000 0,0000000 5.000000 SS MON BKL RBOR 0.0000000 0.0000000 0,0000000 -1,000000 54203,55 20!0,834 514,5210 1,465788 55300,80 2015,657 88.40302 1,419141 53934,72 2021,149 85.97601 1,413491 18782.28 2023,765 8,107000 1,512457 0.0000000 0.0000000 0.0000000 -1.000000 **** FILE.TRAILER **** **** TAPE TRAILER **** LIS 3844 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 525 **** REEL TRAILER **** LIS 89/24/05 ATLAS 01 TOTAL RECORDS iN THIS LOGICAL REEL : 526 TOTAL RECORDS IN THIS PHYSICAL REEL;: 526 En;~ of ex!ecution: Man 26 JUN 89 4:31p EIapsedl .e~ecu~i'on time = 2 minutes, 5.0 seconds. SYSTEM RETURN CODE = 0