Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
167-025
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6,498 feet N/A feet true vertical 6,007 feet N/A feet Effective Depth measured 6,311 feet 6,034 feet true vertical 5,833 feet 5,572 feet Perforation depth Measured depth 6,096 - 6,370 feet True Vertical depth 5,630 - 5,889 feet 6,034 MD 5,572 TVD Tubing (size, grade, measured and true vertical depth)2-7/8" 6.4 N-80 & 6.4 J-55 6,322 MD 5,843 TVD 6,034 (MD) 328 (MD) Packers and SSSV (type, measured and true vertical depth)Model S-2 Pkr 5,572 (TVD) Otis SSSV 328 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,540psi3,090psi 907 777-8376 3,150psi ~271 1,045 6,002 ~271 1,068 Conductor Surface 2,570psi 20" 13-3/8" 6,490 Size 695 Production Casing Structural Liner Length Intermediate N/A Junk 5. Permit to Drill Number: 101 Trading Bay Field / Hemlock Oil PoolN/A measured 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 82 Gas-Mcf 788 N/A Oil-Bbl 94 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-304 117 Authorized Signature with date: Authorized Name: 488 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 167-025 50-733-20020-00-00 Plugs ADL0018731 Trading Bay St A-06 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 55 Representative Daily Average Production or Injection Data 280181 Casing Pressure 6,490 MD ~271 1,068 TVD measured true vertical Packer 9-5/8" PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 12:55 pm, Aug 31, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.08.31 12:49:53 -08'00' Dan Marlowe (1267) SFD 9/8/2020DSR-8/31/2020 RBDMS HEW 8/31/2020 Tubing Patch gls 10-13-20 Updated by JLL: 08/26/20 Trading Bay Unit Well # A-06 Completed: 06/27/1967 PTD: 167-025 API: 50-733-20020-00 SCHEMATIC KB ELEV = 101’ PBTD = 6,425’ TD = 6,498’ ANGLE thru INTERVAL = 21.1q RKB: 38.23’ RKB to MLLW: 112’, RKB to Mudline: 174’ 1 3 4 5 2 7 6 Hemlock Tubing punch 6,205 – 6,215 Tagged fill 6,311 KB 08/04/20 8 TOC 4,800’ Tubing Patch 3,976 – 4,018 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20” Driven Conductor welded Surface ~271’ 13-3/8” 61 J-55 BTC 12.515 Surface 1,068’ 9-5/8” 40.0 J-55 BTC 8.835 Surface 6,490’ DV Collar 4,644’ Tubing: 2-7/8” 6.4 N-80 Armco SealLok 2.441 Surface 6,034’ 2-7/8” 6.4 J-55 Armco SealLok 2.441 6,038’ 6,322’ JEWELRY DETAIL NO Depth (MD) Depth (TVD)ID OD Item 38.23’ 38.23’ 10” Cameron 2-7/8” EUE 8rd Tubing hanger, 1 328’ 328’ 2.313 2-7/8” Otis, SSSV Nipple, w/ 2-1/2” Macco PB SSSV. Valve has an equalizing sub that takes a 27” long prong, including a 4”x.830 tip. 2 2,059’ 1,927’ GLV #1 Otis CX GLM Closed Sliding Sleeve, No GLV 3 4,076’ 3,767’ GLV #2 Otis CX GLM 4 5,994’ 5,534’ GLV #3 Otis CX GLM 5 6,034’ 5,572’ Baker Model “S-2” Hydraulic Packer 6,197’ 5,725’ 6spf tubing punch holes from 6,197’-6,217’, 60 total 6 6,222’ 5,749’ 2.313 2-7/8” Otis “XA” Sliding Sleeve 7 6,322’ 5,843’ 2.205 Otis “XN” Profile Nipple, 2.313 8 6,323’ 5,844’ Top of Hydrotrip Sub 9 6,324’ 5,845’ Bottom of Hydrotrip Sub PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status WSO 6,060' 6,061' 5,596' 5,597' 1' 6/67 Cmt Sqzd Hemlock 6,096' 6,145' 5,630' 5,676' 49' 6/67 Open f/ prod. Hemlock 6,155' 6,300' 5,686' 5,823' 145' 6/67 Open f/ prod. Hemlock 6,320' 6,370' 5,842' 5,889' 50' 6/67 Open f/ prod. WSO 6,375' 6,376' 5,893' 5,894' 1' 6/67 Cmt Sqzd Wireline Summary 08/01/2020 Broken AD-2 Stop Dog ±6,311 KB 01/27/1997 Unable to work a 2.17” GR thru “XN” nipple @ 6322’ 06/19/2003 Ran 2.25” GR to center-set valve. @ 4012’ 07/11/2016 2.29 GR to 6,314’ Well Name Rig API Number Well Permit Number Start Date End Date Trading Bay St A-06 Slickline 50-733-20020-00 167-025 7/31/2020 8/10/2020 Daily Operations: 08/02/20 - Sunday MORNING SAFETY MEETING. PERMIT/JSA, DISCUSS PLAN FORWARD FOR DAY. STANDBY FOR CHOPPER TO DELIVER MAGNET TOOL FOR FISHING. WEATHER DELAY FOR CHOPPER. RD. 08/03/20 - Monday MORNING MEETING, PERMIT/JSA, DISCUSS PLAN FORWARD. BEGIN RU SLI CKLINE. PT LUBRICATOR, CHANGE LEAKING O-RING, RE- TEST TO 2500 PSI, PASS. RIH W/2.23" MAGNET TO 5995KB, W/T GENTLY TWICE, POOH SLOWLY, OOH W/ NO BROKEN DOG. RIH W/2.5" GS TO SAME, W/T MULTIPLE TIMES AND GET 50# OVERPULLS, NO LATCH, POOH. PIN IS SHEARED. RIH W/SAME TO SAME, 50# OVERPULLS, NO LATCH, POOH, PIN NOT SHEARED, NO MARKS ON BTM. RIH W/1.75" MAGNET W/2.20" CENTRALZER TO SAME W/T LIGHTLY, POOH, NO METAL PIECE. RIH W/2.0" LIB TO SAME, POOH W/PICTURE OF CLEAN G-FISH NECK, COULD POSSIBLY BE SCALE BUILUP INSIDE FISHING NECK. RIH W/SLICKLINE SCRATCHER ON 3'x1.75" STEM TO SAME, W/T POOH. RIH W/1.75" MAGNET W/2.20" CENTRALZER TO SAME W/T LIGHTLY, POOH, NO METAL PIECE. RIH W/2.5" PR W/SERRATED DOGS TO SAME, NO LATCH, POOH PIN NOT SHEARED. RIH W/2.5" PR W/STNDRD DOGS TO SAME, CANNOT LATCH, BEAT DOWN HARD MULTIPLE TIMES POOH WITH MARKS FROM BROKEN DOG ON BOTTOM OF CORE. DOG STUCK INSIDE FISH NECK PREVENTING FULL LATCH CAPABILITY. BREAK FOR DINNER. RIH W/1.62 G-RING TO SAME, ATTEMPT TO BEAT BROKEN DOG DOWN INTO FISHING NECK FURTHER IN ORDER TO GET TOOLS TO LATCH. OOH, SECURE WELL. FINISH PAPERWORK. 07/31/20 - Friday ARRIVE @ PWL SHOP, GATHER CREW AND TOOLS, DEPART FOR OSK. ARRIVE @ OSK, HEALTH SCREENING, CHECK-IN, STANDBY FOR CHOPPER. ARRIVE ON MONOPOD, SIGN-IN, DRESS OUT, WIRELINE SAFETY MEETING/PERMIT/JSA. CONSULT WITH PRODUCTION AND TOWN ABOUT DAYS OPERATIONS. SPOT UNIT, RU SLICKLINE PT LUBRICATOR TO 1500 PSI, PASS. RIH W/2.5" GS TO 3985KB, LATCH AA-STOP, POOH W/STOP. RIH W/2.5" GS TO 3986KB, LATCH PACKOFF ON TOP OF PATCH, SPANG 3 TIMES AND LET SIT, SPANG AGAIN AND COMES FREE. POOH W/PATCH. REDRESS WEATHERFORD PACKOFF, ADD 9' 8" SPACER PIPE BELOW PACKOFF. RIH W/2.5" GS WITH WEATHERFORD PACKOFF (BRASS TOP PIN) AND 21' 10" SPACER PIPE TO 3976KB W/T TO SET. POOH, PATCH SET (T-PSI 555# / C-PSI 555#). RIH W/2.5" GS W/ AA-STOP TO 3974KB, SET STOP. POOH, PIN SHEARED. NITE-CAP LUBRICATOR, PRODUCTION WILL FLOW WELL OVERNIGHT TO DETERMINE IF PERFORMANCE HAS IMPROVED WITH NEW SECTION OF PATCH. 08/01/20 - Saturday MORNING SAFETY MEETING, PERMIT/JSA, DISCUSS DAYS OPERATIONS. STANDBY FOR PRODUCTION TO BRING WELL ON AND CHECK PERFORMANCE. WELL NOT PERFORMING, TUBING AND CASING PRESSURE BEGINNING TO EQUALIZE. RIH W/2.5" GS TO 3974KB, LATCH AA-STOP, POOH W/STOP. RIH W/2.5" GS TO 3975KB, LATCH PACKOFF, SPANG UP TO RELEASE, SIT AND LET ELEMENT RELAX. POOH W/PACKOFF AND 21' PATCH. RIH W/2.5" GS TO 3997KB, LATCH 2ND SECTION OF PATCH, PULL 150# OVER AND COMES FREE, POOH W/PATCH SECTION. RIH W/2.5" GS TO 4007KB, LATCH BOTTOM PACKOFF SECTION, POOH. RIH W/2.5" GS TO 4018KB, LATCH AD-2 STOP, POOH W/STOP AND ONE BROKEN DOG. SAW NO SIGN OF THIS HAPPENING WHILE PULLING OOH, POSSIBLY FELL THRU WELLHEAD OR LUBRICATOR. RIH W/2.5" GS TO 728KB, SET D OWN, W/T, CANNOT PASS, POOH, MARKS ON BOTTOM OF GS. TALK WITH PRODUCTION. RIH W/2.0" LIB TO 728KB, SET DOWN, POOH WITH IMPRESSION OF BROKEN AD-2 STOP DOG. CALL TOWN, DISCUSS PLAN FORWARD WITH PRODUCTION. RIH W/2-7/8 SLICKLI NE SCRATCHER W/3' x 1.75" STEM TO 728KB, SET DOWN, HAND SPANG AND GET SCRATCHER TO BITE DOG. PULL UP AND DOG FALLS 10FT, SET DOWN, HAND SPANG 1x AND FALL TO 863KB, POOH. RIH W/2.5" GS TO 5810KB, SET DOWN, W/T TO 5995KB, ATTEMPT TO LATCH FISHING NECK ON BTM GASLIFT MANDREL, COULD NOT LATCH. POOH W/ METAL MARKS ON GS, BROKEN DOG IS LAYING ACROSS THE FACE OF THE FISH NECK,POOH. SECURE WELL. Hilcorp Alaska, LLC Well Operations Summary fishing.... Well Name Rig API Number Well Permit Number Start Date End Date Trading Bay St A-06 Slickline 50-733-20020-00 167-025 7/31/2020 8/10/2020 Hilcorp Alaska, LLC Well Operations Summary 08/10/20 - Monday Morning Safety meeting. Talk w/ company man, sign permits, TGSM. Grind down bottom of GLV assembly. Rih to 330' kb, can't pass, pooh. Rih w/ 2 7/8 BLB to 330' kb, brush SSSV, pooh. Standby for tools flight. Flight arrives, CSGLV tha t we have will not go through an x-nipple. Re-build the Cetner set that was pulled out of the well. Rih w/ 2 7/8 X-line w/ 2 7/8 CSGLV to 5996' kb, set valve, pooh, ooh no valve. Rih w/ 2 7/8 Gs w/ 2 7/8 Ad-2 stop to 4018' kb, set stop, pooh. Ooh no stop. Rih w/ 2 7/8 Gs w/ 20.5' long patch w/ weatherford packoff on bottom (zeroed @ element) to 4017' kb, set patch. OOH no patch. Rih w/ 2 7/8 Gs w/ 20.5 Long patch w/ weatherford packoff on top (zeroed @ element) to 3977' kb, set patch POOH. OOH no patch. Rih w/ 2 7/8 Gs w/ AA-stop to 3976' kb, set AA-stop, pooh, ooh no stop. RDMO. No operations to report 08/08/20 - Saturday Arrive at location. Orientation, PJSM, and PTW. Spot equipment and rig-up. Troubleshoot electrical panel and sheaves. Pressure test lubricator to 500psi low / 1,500psi high - Test good. RIH with 1-9/16" tubing puncher 6 spf. Trouble shoot tugger holding top sheave. Unable to pass wireline through grea se, brand new grease tubes, POOH. Disarm tubing punch, change out grease tubes. Secure well and SDFN 08/09/20 - Sunday PJSM and PTW. RU, RIH with tubing punch, correlate with engineer, punch tubing from 6,205'-6,215', POOH. All shots fired. RD E-line. Tubing punch complete. 08/05/20 - Wednesday No operations to report 08/06/20 - Thursday No operations to report 08/07/20 - Friday MORNING MEETING, PERMIT/JSA, DISCUSS PLAN FORWARD. CLEAN AND ORGANIZE WORK AREA, CLEAN AND PREP TOOLS, WIRELINE UNIT MAINTENANCE. RIH W/2" LIB TO 5995KB, W/T POOH, SH OWS THAT FISHING NECK IS STILL CLEAR BUT APPEARS TO HAVE ROUGH EDGES. RIH W/2.5" PR W/1.75" SERRATED DOGS TO 5995KB, ABLE TO GET 500# - 600# OVERPULLS BUT TOOL KEEPS SLIPPING OFF. TALK W/PRODUCTION AND TOWN. RIH W/SAME W/1.772" S ERRATED DOGS TO 5995KB, W/T, LATCH UP AND 800# JAR LICK, HOLD, PULL 1000# JAR LICK, SLIPS OFF, PULL 900# JAR LICK, HOLDS, PULL 110# JAR LICK, COMES FREE AND POOH W/ CSV. CLEAN AND INSPECT ORIFICE VALVE AND X-LOCK, FISH-NECK IS WASHED OUT ON INSIDE, THREADS FOR CHECK VALVE IN ORIFICE ARE WASHED OUT. PRODUCTION TO CIRCULATE GAS THROUGH EMPTY MANDREL. RIH W/2" DD BAILER TO 6311KB, TAG BOTTOM, DID NOT SEE FLUID LEVEL AT ALL. OOH, RD SLICKLINE. 08/04/20 - Tuesday OOH no patch. Rih w/ 2 7/8 Gs w/ 20.5 Lon g patch w/ weatherford packoff on top (zeroed @ element) to 3977' kb, set patch POOH. OOH n o patch. Rih w/ 2 7/8 Gs w/ AA-stop to 3976' kb, set AA-stop, pooh, ooh no stop. RDMO. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): Trading Bay Field / Hemlock Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 6,498'N/A Casing Collapse Structural Conductor Surface 1,540 psi Intermediate Production 2,570 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.Oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size N/A COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018731 Burst 6,034 & 6,322 3,150 psi Tubing Size: 167-025 50-733-20020-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay St A-06 MD 3,090 psi ~271' 1,045' ~271' 1,068' TVD 20" 13-3/8" ~271' 1,068' Perforation Depth MD (ft): 6,096 - 6,370 6,490' 6,034 (MD) 5,572 (TVD) & 328 (MD) 328 (TVD) Tubing Grade:Tubing MD (ft): 5,630 - 5,889 Perforation Depth TVD (ft): 6.4# N-80 & 6.4# J-55 Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 8/1/2020 2-7/8" Daniel E. Marlowe Model S-2 Packer & Otis SSSV 6,002'9-5/8"6,490' Other: Tubing Patch N/A 6,007' 6,314' 5,836' 747 psi Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:43 pm, Jul 17, 2020 320-304 Daniel Marlowe I am approving this document 2020.07.17 13:06:19 -08'00' Daniel Marlowe DSR-7/20/2020SFD 7/20/2020 X 10-404 VTL 7/23/20 On behalf of dtseamount dts 7/23/2020 JLC 7/23/2020 ption Required? Yes ehalfofdtseamounCommCommst 7/24/2020 RBDMS HEW 7/24/2020 Well Prognosis Well Name:TRADING BAY ST A-06 API Number:50-733-20020-00 Current Status:Gas Lifted Producer Leg:Leg #1 Estimated Start Date:08/01/2020 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:167-025 First Call Engineer:Katherine O’Connor (907) 777-8376 (O) (214) 684-7400 (M) Second Call Engineer:Karson Kozub (907) 777-8384 (O) (907) 570-1801 (M) Current Bottom Hole Pressure:1,310 psi @ 5,630’ TVD 0.233 psi/ft (4.47 ppg) Maximum Expected BHP:1,310 psi @ 5,630’ TVD 0.233 psi/ft (4.47 ppg) Max Potential Surface Pressure (MPSP):747 psi Using 0.1psi/ft per 20AAC 25.280(b)(4) Brief Well Summary Well A-06 is a no flow, gaslift well completed in the Trading Bay Hemlock Oil Pools. Wellbore diagnostics indicated that there was a leak near the second mandrel. A patch was installed in 2018 but recent production trends indicate the patch failed or needs to be extended. Casing passed a pressure test to 2000 psi in 2018. This job entails extending the tubing patch in order to regain integrity. Procedure: 1. Rig up slick line and pressure test lubricator to 1,500 psi Hi, 250 psi low. 2. Pull tbg patch from 3995’-4019’ MD 3. RIH w/ tubing patch to ±3,885-±4,030’ (a hole finder will be ran prior to running the patch to determine actual depths). 4. Rig down slickline 5. Turn well over to production. Attachments: 1. Well Schematic - Current 2. Well Schematic - Proposed REVISED: 11/15/18 DRAWN BY: JLL Trading Bay Unit Well # A-06 Completed: 06/27/1967 PTD: 167-025 API: 50-733-20020-00 SCHEMATIC KB ELEV = 101’ PBTD = 6,425’ TD = 6,498’ ANGLE thru INTERVAL = 21.1q RKB: 38.23’ RKB to MLLW: 112’, RKB to Mudline: 174’ 1 3 4 5 2 7 6 Hemlock Tubing punch 8 TOC 4,800’ Tubing Patch 3,995 KB – 4,019 KB CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20” Driven Conductor welded Surface ~271’ 13-3/8” 61 J-55 BTC 12.515 Surface 1,068’ 9-5/8” 40.0 J-55 BTC 8.835 Surface 6,490’ DV Collar 4,644’ Tubing: 2-7/8” 6.4 N-80 Armco SealLok 2.441 Surface 6,034’ 2-7/8” 6.4 J-55 Armco SealLok 2.441 6,038’ 6,322’ JEWELRY DETAIL NO Depth (MD) Depth (TVD)ID OD Item 38.23’ 38.23’ 10” Cameron 2-7/8” EUE 8rd Tubing hanger, 1 328’ 328’ 2.313 2-7/8” Otis, SSSV Nipple, w/ 2-1/2” Macco PB SSSV. Valve has an equalizing sub that takes a 27” long prong, including a 4”x.830 tip. 2 2,059’ 1,927’ GLV #1 Otis CX GLM Closed Sliding Sleeve, No GLV 3 4,076’ 3,767’ GLV #2 Otis CX GLM 4 5,994’ 5,534’ GLV #3 Otis CX GLM 5 6,034’ 5,572’ Baker Model “S-2” Hydraulic Packer 6,197’ 5,725’ 6spf tubing punch holes from 6,197’-6,217’, 60 total 6 6,222’ 5,749’ 2.313 2-7/8” Otis “XA” Sliding Sleeve 7 6,322’ 5,843’ 2.205 Otis “XN” Profile Nipple, 2.313 8 6,323’ 5,844’ Top of Hydrotrip Sub 9 6,324’ 5,845’ Bottom of Hydrotrip Sub PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt. Accum. SPF Date Last Opr.Present Condition WSO 6,060' 6,061' 5,596' 5,597' 1' 12 6/67 Cmt Sqzd Hemlock 6,096' 6,145' 5,630' 5,676' 49' 12 6/67 Open f/ prod. Hemlock 6,155' 6,300' 5,686' 5,823' 145' 12 6/67 Open f/ prod. Hemlock 6,320' 6,370' 5,842' 5,889' 50' 8 6/67 Open f/ prod. WSO 6,375' 6,376' 5,893' 5,894' 1' 12 6/67 Cmt Sqzd Wireline Summary 01/27/1997 Unable to work a 2.17” GR thru “XN” nipple @ 6322’ 06/19/2003 Ran 2.25” GR to center-set valve. @ 4012’ 07/11/2016 2.29 GR to 6,314’ Updated: 07/17/20 by JLL Trading Bay Unit Well # A-06 Completed: 06/27/1967 PTD: 167-025 API: 50-733-20020-00 PROPOSED KB ELEV = 101’ PBTD = 6,425’ TD = 6,498’ ANGLE thru INTERVAL = 21.1q RKB: 38.23’ RKB to MLLW: 112’, RKB to Mudline: 174’ 1 3 4 5 2 7 6 Hemlock Tubing punch 8 TOC 4,800’ Tubing Patch ±3,885’ – ±4,030’ CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20” Driven Conductor welded Surface ~271’ 13-3/8” 61 J-55 BTC 12.515 Surface 1,068’ 9-5/8” 40.0 J-55 BTC 8.835 Surface 6,490’ DV Collar 4,644’ Tubing: 2-7/8” 6.4 N-80 Armco SealLok 2.441 Surface 6,034’ 2-7/8” 6.4 J-55 Armco SealLok 2.441 6,038’ 6,322’ JEWELRY DETAIL NO Depth (MD) Depth (TVD)ID OD Item 38.23’ 38.23’ 10” Cameron 2-7/8” EUE 8rd Tubing hanger, 1 328’ 328’ 2.313 2-7/8” Otis, SSSV Nipple, w/ 2-1/2” Macco PB SSSV. Valve has an equalizing sub that takes a 27” long prong, including a 4”x.830 tip. 2 2,059’ 1,927’ GLV #1 Otis CX GLM Closed Sliding Sleeve, No GLV 3 4,076’ 3,767’ GLV #2 Otis CX GLM 4 5,994’ 5,534’ GLV #3 Otis CX GLM 5 6,034’ 5,572’ Baker Model “S-2” Hydraulic Packer 6,197’ 5,725’ 6spf tubing punch holes from 6,197’-6,217’, 60 total 6 6,222’ 5,749’ 2.313 2-7/8” Otis “XA” Sliding Sleeve 7 6,322’ 5,843’ 2.205 Otis “XN” Profile Nipple, 2.313 8 6,323’ 5,844’ Top of Hydrotrip Sub 9 6,324’ 5,845’ Bottom of Hydrotrip Sub PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status WSO 6,060' 6,061' 5,596' 5,597' 1' 6/67 Cmt Sqzd Hemlock 6,096' 6,145' 5,630' 5,676' 49' 6/67 Open f/ prod. Hemlock 6,155' 6,300' 5,686' 5,823' 145' 6/67 Open f/ prod. Hemlock 6,320' 6,370' 5,842' 5,889' 50' 6/67 Open f/ prod. WSO 6,375' 6,376' 5,893' 5,894' 1' 6/67 Cmt Sqzd Wireline Summary 01/27/1997 Unable to work a 2.17” GR thru “XN” nipple @ 6322’ 06/19/2003 Ran 2.25” GR to center-set valve. @ 4012’ 07/11/2016 2.29 GR to 6,314’ STATE OF ALASKA R11FKA OIL AND GAS CONSERVATION CO SSION ORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change AADGgr ; Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Install Patch 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Exploratory Stratigraphic Service 167-025 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20020-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018731 Trading Bay St A-06 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Trading Bay Field / Hemlock Oil Pool 11. Present Well Condition Summary: Total Depth measured 6,498 feet Plugs measured N/A feet true vertical 6,007 feet Junk measured N/A feet Effective Depth measured 6,314 feet Packer measured 6,034 feet true vertical 5,836 feet true vertical 5,572 feet Casing Length Size MD TVD Burst Collapse Structural Conductor —271' 20" --271' —271' Surface 1,068' 13-3/8" 1,068' 1,045' 3,090 psi 1,540 psi Intermediate Production 6,490' 9-5/8" 6,490' 6,002' 3,150 psi 2,570 psi Liner Perforation depth Measured depth 6,096 - 6,370 feet SC41010°�)1j True Vertical depth 5,630 - 5,889 feet 2-7/8" 6.4# / N-80 6,034 (MD) 5,572 (TVD) Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.4# / J-55 6,322 (MD) 5,843 (TVD) 6,034 (MD) 328 (MD) Packers and SSSV (type, measured and true vertical depth) Model S Packer 5,572 (TVD) Otis SSSV 328 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 9 81 43 668 101 Subsequent to operation: 32 83 422 627 145 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ DevelopmentE2] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1318-414 Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Contact Email: dmarlowe()-hilcorp.com \\Manager Authorized Signature: (� Date: ► t (S l a Contact Phone: (907) 283-1329 Form 10-404 Revised 4/2017 VL.' �� ` 3BDMS1 Nov 19 2018 //' ///*/# Submit Original Only I u 0 40Trading Bay Unit SCHEMATIC Well #A-06 Completed: 06/27/1967 PTD: 167-025 API: 50-733-20020-00 RKB: 38.23' RKB to MLLW: 112', RKB to Mudline: 174' CASING AND TUBING DETAIL LI Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date I End Date A-06 Wireline 50-733-20020-00 167-025 10/26/2018 10/28/2018 Daily dperaidAl r K 10/26/18 - Friday �.'u.': Skid rig over A-06. Rig up on well. Pressure test 1500PSI- GOOD. Equalize well. Rih w/ 2 1/2 GS to 4007' kb w/t, latch CSV pooh. Ooh w/ 2 7/8 Dummy CSV. Rih w/ 2 1/2" Gs to 5991' kb, latch CSV, pooh. Ooh w/ CSV. Rih w/ 2 1/2" Gs w/ AD -2 stop w/ 2.25 G -ring on bottom to 6008' kb, set stop, pooh. Rih w/ 2 1/2" Gs w/ weatherford packoff plug to 6004' kb, set plug pooh, ooh no plug. Ooh lay down. End ticket. Crew Rest. Morning Safety meeting. Sign permits, discuss job scope. 10/27/18 -,Saturday Rig up and Pressure test tubing/casing to 2000 psig and chart for 1 hour. Rig up on well. PT lubricator to 1500 psig. Rih w/ 2" Jdc w/ DD hole finder (zero at packing element) to 4030' kb, pressure up on tubing- start testing at 4030' kb, work up to 3995' kb pass. Stop appeared to be slipping down to 4002' kb when working between 3097-4000' kb. Pooh. Rih w/ 6' 3/4 prong to 6004' kb, knock out kobe, pressure drops, pooh. Tubing and casing on vacuum. Rih w/ 2 1/2" Gs to 6004' kb, latch packoff, hit 2X 1200 Ib jar licks, won't come free due to well being on vacuum (fluid @ 600' kb going on hole shear off, pooh, re -attempt in morning. Ooh w/ tools, GS skirt and dog spring are damaged. Shut down for night. Morning safety meeting, sign permits. Rih w/ 2 1/2 Gs (fluid @ 3200) to 6004' kb, latch packoff, pooh. Ooh w/ packoff plug missing packoff element. 10/28/18 - Sunday (continued from prior days report) Rih w/ 2 1/2 Gs (fluid @ 3200) to 6004' kb, latch packoff, pooh. Ooh w/ packoff plug missing packoff element. Rih w/ 2 1/2 Gs to 6008' kb, latch AD -2 stop, pooh. 1/2 of packoff element in bottom of AD -2 stop. Rih w/ 2 7/8 Vine w/ CSV (orifice) to 5994' kb, pooh. Ooh no CSV. Rih w/ 2 1/2 Gs w/ 2 7/8 AD -2 Stop (zero at top of stop) to 4019' kb, pooh. Rih w/ 2 1/2 Gs w/ 11' stop w/ weatherford packoff on bottom. Packoff seal is 14 inches from bottom of plug. Tool is zero'd at bottom of packoff. Set @ 4018' kb, seal is set @ 4017' kb, pooh. Rih w/ 2 1/2 gs w/ 9' 11" space pipe. Pipe has stinger on bottom and receptacle on top. 11/4 " minimum ID. Bottom of spacer pipe is @ 4007' kb. Pooh. Ooh no stinger. Rih w/ gs w/ 12' 2"Patch w/ stinger on bottom and weatherford packoff on top. Set bottom of patch @ 3997'kb, top of packoff @ 3985'kb, pooh, ooh no patch. Rih w/ 2 1/2 Gs w/ A -stop to 3995' kb, set A -stop pooh. Rig down wireline and travel back to shop. THE STATE Alaska Oil and Gas o1ALAKA Conservation Commission GOVERNOR BILL WALKER Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Hemlock Oil Pool, Trading Bay St A-06 Permit to Drill Number: 167-025 Sundry Number: 318-414 Dear Mr. Golis: 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907 279 1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this 3 rday of October, 2018. Sincerely, 3 K Cathy P. Foerster Commissioner RBDMS. OCT 0 4 2018 V ALASKA OIL AND GAS CONSERVASTATE OF TION COMMISSION SEP 19 2018 APPLICATION FOR SUNDRY APPROVALS ��� 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well YT Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install Patch Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q- Stratigraphic ❑ Service ❑ 167-025 ' ' 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: ' Anchorage, AK 99503 50-733-20020-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No Q ITrading Bay St / A-06 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018731 I Trading Bay Field / Hemlock Oil Pool 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): 6,498 • 6,007 6,314 5,836 747 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor —271' 20" —271' —271' Surface 1,068' 13-3/8" 1,068' 1,045' 3,090 psi 1,540 psi Intermediate Production 16,490' 9-518" 6,490' 6,002' 3,150 psi 2,570 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,096 - 6,370 15,630 - 5,889 2-7/8" 16.4# / N-80 & J-55 6,034 & 6,322 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Model "S" Packer / Otis SSSV 6,034 (MD) 5,572 (TVD) & 328 (MD) 328 (TVD) 12. Attachments: Proposal Summary Wellbore schematic 4 13, Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/3/2018 OIL Q. WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowej hilCOr .COM Contact Phone: (907) 283-1329 Authorized Signature: � Date: O9 t'� �S COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I UX Plug Integrity ❑ BOP Test F] Mechanical Integrity Test ❑ Location Clearance ❑ Other: K -f' j. 4- t '%' r, `43 int„ 71B ��0 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: u ..APPROVED BY C Approved h : COMMISSIONER THE COMMISSION Date: ,iso ((���� ip pp `` 99��>as�z�Trl g' 2` �� 03 PWiledlaRofiN A roved a tic the date Of a royal f ubsiin Form and PP PP PP Attachments in Duplicate ,� - �f►- � ,x 0, oo h-1 h s H Hilcorn Alaeks, LL, Well Prognosis Well Name: TRADING BAY ST A-06 API Number: 50-733-20020-00 Current Status: Gas Lifted Producer Leg: Leg #1 Estimated Start Date: 10/03/2018 Rig: N/A Reg. Approval Re 'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 167-025 First Call Engineer: Dan Marlowe 907 283-1329 O 907 398-9904 M Second Call Engineer: Mike Quick 907 777-8442 O 907 317-2969 M Current Bottom Hole Pressure: 1,310 psi @ 5,630' TVD 0.233 psi/ft (4.47 ppg) Maximum Expected BHP: 1,310 psi @ 5,630' TVD 0.233 psi/ft (4.47 ppg) Max Potential Surface Pressure (MPSP): 747 psi Using 0.1psi/ft per 20AAC 25.280(b)(4) Brief Well Summary Well A-06 is a gaslift well completed in the Trading Bay Hemlock Oil Pools. Wellbore diagnostics indicates that there is a leak near the second mandrel. This job entails running a tubing patch to in order to regain integrity. Procedure: 1. Rig up slick line and pressure test lubricator to 1,500 psi. 2. RIH w/ tubing patch to ±4,025-4,070' (a hole finder will be ran prior to running the patch to determine actual depths). 3. Rig down slickline 4. Turn well over to production. S CIt1t i jrs4r( � ` C- Attachments: 1. Well Schematic - Current 2. Well Schematic - Proposed RKB: 38.23' RKB to MLLW: 112'. RKB to Mudline: 174' KB ELEV = 101' PBTD = 6,425' TD = 6,498' ANGLE thru INTERVAL = 21.10 SCHEMATIC CASING AND TUBING DETAIL Trading Bay Unit Well # A-06 Completed: 06/27/1967 PTD: 167-025 API: 50-733-20020-00 SIZE WT I GRADE CONN ID TOP BTM. 20" Driven Conductor welded 1 Surface -'271' 13-3/8" 61 J-55 BTC 12.515 Surface 1,068' 9-5/8" 40.0 J-55 BTC 8.835 Surface 6,490' DV Collar 145' GLV#3 Otis CX GLM 5 6,034' 5,572' 4,644' Tubing: 5889' 6,197' 5,725' 6/67 6spf tubing punch holes from 6,197'-6,217', 60 total 6 2-7/8" 6.4 N-80 Armco Seall-ok 2.441 Surface 6,034' 2-7/8" 6.4 1-55 Armco Seall-ok 2.441 6,038' 6,322' JEWELRY DETAIL NO - Depth MD Depth (TVD) ID - Item @ 4012' 38.23' 38.23' WSO 10" Cameron 2-7/8" EUE 8rd Tubing hanger, 1 328' 328' 2.313 2-7/8" Otis, SSSV Nipple, w/ 2-1/2' Macco PB SSSV. Valve has an equalizing sub that takes a 27" long prong, including a 4"x.830 tip. 2 2,059' 1,927' 5,630' GLV#1 Otis CX GLM Closed Sliding Sleeve, No GLV Y 3 4,076' 3,767' Oen f/ prod. GLV #2 Otis CX GIM 4 5,994' 5,534' 145' GLV#3 Otis CX GLM 5 6,034' 5,572' 6,320' 6,370' Baker Model "S-2" Hydraulic Packer 5889' 6,197' 5,725' 6/67 6spf tubing punch holes from 6,197'-6,217', 60 total 6 6,222' 5,749' 2.313 2-7/8" Otis "W Sliding Sleeve 7 6,322' 5,843' 2.205 O[is "X N" Profile Nipple, 2.313 8 6,323' 5,844' Top of Hydrotrip Sub 9 6,324' 5,845' Bottom of Hydrotrip Sub Hock Wireline Summary 01/27/1997 Unable to work a 2.17" GR thru "XN" nipple @ 6322' 06/19/2003 Ran 2.25" GR to center -set valve. @ 4012' 07/11/2016 2.29 GR to 6,314' WSO PERFORATION DATA Zone Top Btm (MD) (MD) Top (TVD) Btm (TVD) Amt. Accum. SPF Date Last Opr. Present Condition WSO 6060' 6,06" 5,596 5,597' 1' 12 6/67 CmtS zd Hemlock 6,096' 6,145' 5,630' 5676' 49' 12 6/67 Oen f/ prod. Hemlock 6,155' 6,300' 5,686' 5,823' 145' 12 6/67 Oen f/ prod. Hemlock 6,320' 6,370' 5.842' 5889' 50' 8 6/67 Oen f/ prod, WSO 6,375' 6,376' 5.893' 5,894' 1' 12 8/67 CmtS zd ()rt(,'' c� REVISED: 07/11/16 DRAWN BY: DEM RKB: 38.23' RKB to MLLW: 112', RKB to Mudline: 174' KB ELEV = 101' PBTD = 6,425' TD = 6,498' ANGLE thru INTERVAL = 21.1° PROPOSED CASING AND TUBING DETAIL Trading Bay Unit Well # A-06 Completed: 06/27/1967 PTD: 167-025 API: 50-733-20020-00 SIZE WT I GRADE CONN ID TOP BTM. 20" Driven Conductor welded 1 Surface ^271' 13-3/8" 61 J-55 BTC 12.515 Surface 1,068' 9-5/8" 40.0 J-55 BTC 8.835 Surface 6,490' DV Collar 145' GLV#3 Otis IXGLM 5 6,034' 5,572' 4,644' Tubing: 5889' 6,197' 5,725' 6/67 6spftubing punch holes from 6,197'-6,217', 60 total 6 2-7/8" 6.4 N-80 Armco SealLok 2.441 Surface 6,034' 2-7/8" 6.4 1-55 Armco SealLok 2.441 6,038' 6,322' JEWELRY DETAIL NO Depth MD Depth ITVD1 IDItem - - @ 4012' 38.23' 38.23' WSO 10" Cameron 2-7/8" EUE 8rd Tubing hanger, 1 328' 328' 2.313 2-7/8" Otis, SSSV Nipple, w/2-1/2" Macco PB SSSV. Valve has an equalizing sub that takes a 27" long prong, including a 4"x.830 tip. 2 2,059' 1,927' 5,630' GLV#1 Otis CX GLM Closed Sliding Sleeve, No GLV 3 4,076' 3,767' Oen f/ prod. GLV#2 Otis CX GLM 4 5,994' 5,534' 145' GLV#3 Otis IXGLM 5 6,034' 5,572' 6,320' 6,370 Baker Model "5-2" Hydraulic Packer 5889' 6,197' 5,725' 6/67 6spftubing punch holes from 6,197'-6,217', 60 total 6 6,222' 5,749' 2.313 2-7/8" Otis "XA" Sliding Sleeve 7 6,322' 5,843' 2.205 Otis "XN" Profile Nipple, 2.313 8 6,323' 5,844' Top of Hydrotrip Sub 9 6,324' 5,845' Bottom of Hydrotrip Sub flock Wireline Summary 01/27/1997 Unable to work a 2.17" GR thru "X N" nipple @ 6322' 06/19/2003 Ran 2.25" GR to center -set valve. @ 4012' 07/11/2016 2.29 GR to 6,314' WSO PERFORATION DATA Zone Top Btm (MD) (MD) Top (TVD) Btm (TVD) Amt. Accum. SPF Date Last Opr. Present Condition WSO 6060' 6061' 5,596' 5,597 1' 12 6/67 CmtG zd. Hemlock 6,096' 6,145' 5,630' 5,676' 49' 12 6/67 Oen f/ prod. Hemlock 6,155' 6,300' 5,686' 5,823' 145' 12 6/67 Oen f/ prod. Hemlock 6,320' 6,370 5,842' 5889' 50' 8 6/67 Oen f/ prod WSO 6,375' 6,376' 5,893' 5,894- 1' 12 6/67 Cmt 5 zd REVISED: 09/17/18 DRAWN BY: JILL • • Carlisle, Samantha J (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, October 01, 2015 2:51 PM To: Juanita Lovett Cc: Trudi Hallett; Dan Marlowe;Ted Kramer; Carlisle, Samantha J (DOA) Subject: RE: Withdraw Sundry# 314-586/ PTD: 167-025 Juanita, AOGCC will withdraw sundry 315-586 as requested for A-06 . RBDM$cStr"' 4 7015 Guy Schwartz EU 1 1 2-0.Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guv.schwartz@alaska.gov). From: Juanita Lovett [mailto:jlovett@hilcorp.com] Sent: Thursday, October 01, 2015 1:59 PM To: Schwartz, Guy L (DOA) Cc: Trudi Hallett; Dan Marlowe; Ted Kramer Subject: Withdraw Sundry # 314-586 / PTD: 167-025 Guy, Please withdraw the above mentioned sundry.The scope of work included pulling the existing completion, cleaning out the well to PBTD, re-perforating Hemlock formation and installing ESP completion. Regards, Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska,LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: jlovett@hilcorp.com 1 THE STATE Of GOVERNOR SEAN PARNELL Ted Kramer Senior Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 SCANN'EU NOVO 7 2014. Re: Trading Bay Field, Hemlock Oil Pool, Trading Bay St A-06 Sundry Number: 314-586 Dear Mr. Kramer: UV -7 - O' -s 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 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, Daniel T. Seamount, Jr. Commissioner DATED this ✓ day of November, 2014. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Nvl�' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 980 RECEIVED OCT 3 1 2014 AOGCC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ /(.5 14 r-0 11�3�11 /fi `��/Y G Form 10-403 (Revised 10/2012) 12 months from the date of approval. Rv j GI jN. AaLfor Suspend ❑ Plug Perforations ❑ Perforate M Pull Tubing F] Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Install ESP 2. Operator Name: 4. Current Well Gass: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development Stratigraphic ❑ Service ❑ 167-025 - 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-200220-00 ' 7. If perforating: 8. Weil Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 93B Will planned perforations require a spacing exception? Yes ❑ No I] Trading Bay St / A-06 - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018731 • I Trading Bay Field / Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6,498 6,007 • 6,425 5,941 6,490 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,068' 13-3/8" 1,068' 1,045' 3,090 psi 1,540 psi Intermediate Production 6,490' 9-5/8" 6,490' 6,002' 3,150 psi 2,570 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft72-7/8" ing Size: Tubing Grade: Tubing MD (ft): 6,060'- 6,376' 5,596'- 5,894' 6.4# N-80 & J-55 6,034' & 6,322' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Model "S" Packer / Otis SSSV 6,034' (MD) 5,572' (TVD) / 328' (MD) 328' (TVD) 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 121 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/20/2014 Oil 121 Gas ❑ WDSPL ❑ Suspended ❑ WINJ ElGINJ E]WAG ElAbandoned E]Commission 16. Verbal Approval: Date: Representative: GSTOR ❑ SPLUG El 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramertcrWhilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature ` �"' `�.'l Phone (907) 777-8420 Date 10/31/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \ �– 15C<S tQ Plug Integrity ❑ BOP Test ®/ Mechanical Integrity Test ❑ Clearance El ALocation Other: Z-15-60 S � /� & P l Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY /� /( / � I q— Date: / Approved by: COMMISSIONER THE COMMISSION Da Submit Form and Attachments in Duplicate Iiilcorp Alaska, LLI Well Prognosis Well: A-06 Date: 10/31/2014 Well Name: Monopod A-06 API Number: 50-733-20020-00 Current Status: Oil producer (Gas Lifted) Leg: N/A Estimated Start Date: 11/20/14 Rig: Monopod Rig #56 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 167-025 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) Current Bottom Hole Pressure: 1,340 psi @ 6,233' (5,759' TVD) From 1/17/2009 Static survey with 103 days of shut in time. Maximum Expected BHP: 1,340 psi @ 6,233' (5,759' TVD) Max. Anticipated Surface Pressure: 764 psi. (Using a 1,340 psi max. Expected BHP and a .01 psi/ft. gradient.) Brief Well Summary The A-06 well is currently completed as a gas lifted producer. The re -completion plan involves pulling the existing completion, cleaning out the well to the PBTD at 6,425 feet. The well will then re -perforated in the Hemlock formation: A new ESP completion will be ran.r Brief Procedure: 1. MIRU Monopod Platform Rig # 56. 2. RU Slickline. RIH and pull the SSSV at 328', and the Center set GLV's at 2,059', 4,076', and 5,994'. 3. RU E -line. RIH with cutter to 6,029'. Cut tubing and circulate well to remove hydrocarbon from top of packer. 4. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 5. POOH with tubing string and lay down the same. 6. PU RIH with burn shoe on work string and mill over packer at 6,034'. POOH. 7. PU spear/OS and run in well to latch, and remove packer. 8. PU RIH with 9-5/8" Clean Out Assembly, clean out to PBTD .425'). Circulate hole clean. POOH with same. 9. RU E -line. PU RIH with GR/CCL logging tool to 6,425' +/-. POH logging well up to 1,068'. RD E -line. 10. PU RTTS test packer. RIH to 6,050' and set. Pressure t_ est casing to 1,590 -psi_ for 30 minutes. Chart same. -- - c 11. ND BOP, Change out wellhead. NU BOP and She I Test. c(c 12. POOH with RTTS test Packer. L-+ 13. PU RIH with TCP perforating guns spacing out as per Final approved Perforation Request Form. RU E -line. Run tie in log. Place guns on depth. Fire guns. 14. PU on guns and circulate out perf gas. Monitor well for 1 hr shooting fluid levels to determine fluid loss. Fluid loss should diminish over time. 15. Once well is stable, POOH with TCP guns. 16. PU and run ESP with High set packer. Place bottom of ESP at 6,380'. 17. ND BOPS, NU Wellhead and test. 18. Turn well over to production. I H II icorp Alaska. LL, Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Proposed Wellhead. Well Prognosis Well: A-06 Date:10/31/2014 RKB to TBG Hngr = 38.23' Tree connection: ?? KB ELEV = 101' PBTD = 6,425' TD = 6,498' ANGLE thru INTERVAL = 21.1° Trading Bay Unit Well # A-6 Completed 06/67 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt 12.515 Surf. 10687- 9-5/9" 40.0 K-55 8rd LT&C 8.835 Surf 6490' DV Collar 12 GLV #3 Otis CX GLM 5 6034' 6,155' 4644' Tubing: 6222' 2.313 2-7/8" Otis "XA" Sliding Sleeve 7 6322' 2.205 2-7/8" 6.4 N-80 Butt 2.441 Surf 6034' 2-7/8" 6.4 J-55 Butt 2.441 6038' 6322' JEWELRY DETAIL NO. De th ID Item Zone 38.23' Btm 10" Cameron 2-7/8" EUE 8rd Tubing hanger, 1 328 2.313 2-7/8" Otis, SSSV Nipple, w/ 2-1/2" Macco PB SSSV. Valve has an equalizing sub that takes a 27" long prong, including a 4"x.830 tip. 2 2059' 1' GLV #1 Otis CX GLM Closed SIdg SI, No GLV 3 4076' Hemlock GLV #2 Otis CX GLM 4 5994' 12 GLV #3 Otis CX GLM 5 6034' 6,155' Baker Model "S 2" Hydraulic Packer 6 6222' 2.313 2-7/8" Otis "XA" Sliding Sleeve 7 6322' 2.205 Otis ")CK"Profile Nipple, 2.313 8 6323' btm 6324' Open f/ prod. Hydrotrip Sub dock Wireline Summary 1/27/97 Unable to work a 2.17" GR thru "XN" nipple @ 6322' 6/19/03 Ran 2.25" GR to center -set valve. @ 4012' A-06 Schematic 1967-06 REVISED: 9/27/00 DRAWN BY: SLT PERFORATION DATA Zone Top Btm Amt. Accum. SPF Date Last Opr. Present Condition wso 6,060' 6,061' 1' 12 6/67 Cmt S zd Hemlock 6,096' 6,145' 49 12 6/67 Oen f/ prod. Hemlock 6,155' 6,300' 145' 12 6/67 Open f/ prod. Hemlock 6,320' 6,370' S0' 6 6/67 Open f/ prod. wso 6,375' 6,376' 1' 12 6/67 Cmt S zd A-06 Schematic 1967-06 REVISED: 9/27/00 DRAWN BY: SLT RKB to TBG Hngr = 38.23' Tree connection: ?? Hemlock KB ELEV = 101' PBTD = 6,425' TD = 6,498' ANGLE thru INTERVAL = 21.1° PROPOSED Trading Bay Unit Well # A-6 Completed: 06/67 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt 12.515 Surf. 1068' 9-5/8" 40.0 K-55 8rd LT&C 8.835 Surf 6490' DV Collar ±325' Packer 4644' Tubing: X -Nipple 4 ±355' 2-7/8" 6.5 L-80 8rd EUE Surf ±6,280' JEWELRY DETAIL NO. Depth ID Item Top D 38.23' TBG Hanger SPF Date Present Condition 1 ±305' SSSV 2 ±325' Packer 3 ±340' X -Nipple 4 ±355' GLM 5 ±6,380' Bottom of ESP Perforation Data Zone Top MD Btm MD Top D Btm TVD Amt. SPF Date Present Condition WSO 6,060' 6,061' 5,596' 5,597' 1' 12 6/67 Cmt Sqzd Hemlock 6,096' 6,145' 5,630' 5,676' 49' 12 6/67 Open f/ prod. Hemlock ±6,096' ±6,300' ±5630' ±5823' ±204' Future Hemlock 6,155' 6,300' 5,686' 5,823' 145' 12 6/67 Open f/ prod. Hemlock 6,320' 6,370' 5,842' 5,889' 50' 8 6/67 Open f/ prod. WSO 6,375' 6,376' 5,893' 5,894' 1' 12 6/67 Cmt Sqzd Updated by: JLL 10/31/14 Hi4nrp Al."a, LLC Monopod Platform A-6 133/8X95/8X27/8 Tree assy, block, CIW Single master and sw 7 1/16 3M X 2 9/16 51� 2 1/16 5M, EE trim Tubing head, Shaffer type CS, 13 5/8 3M X 11 3M, w/ 2- 2 1/16 5M SSO Casing head, Shaffer KD, 135/83MX 13 3/8 SOW, w/ 2- 2" LPO, Casing bowl is kelly whooped w/ seal assy baker -locked and w/ cement on top to make seal barrier Monopod Platform A-06 Current 010/23/2014 Tubing hanger, Shaffer -05 - AJ -0, 11 X 2 7/8 EUE 8rd lift X 2 7/8 EUE bottom, w/ 2 1/2" Shaffer Type `A" BPV profile, 1/8 non cont control line port in hanger BHTA, 2 9/16 5M FE X 3" Bowen Quick Union ety, Willis C-20, 16 5M FE 3M Stdd )repped �r neck, exit 0 -8 Hilrnrp Alarka, LU: Monopod Platform A-06 133/8X95/8X27/8 Valve, Swat 3 1/8 5M FE, F Valve, Wing, WKM-M, 2 1/11 5M FE, HWO, DD trim Valve, Master, N 3 1/8 SM FE, HWC Tubing head, S-8, 13 5/8 x 11 5M, w/ 2- 2 1/16 5D SSO, w/ BG bottom / 1- 2 1/16 5M WKM- valves Casing head, Shaffer KD, 135/83MX 13 3/8 SOW, w/ 2- 2 LPO, Casing bowl is kelly whooped w/ seal as! baker -locked and w, cement on top to ma seal barrier Monopod Platform A-06 Proposed ESP 010/23/2014 Tubing hanger, Seaboard - ESP -EN, 11 X 3 1/2 EUE lift and Susp w/3" Type H BPV profile, 2- % CCL, Prepped for BIW penetrator BHTA, Bowen, 3 1/8 5M X 2.5 Bowen quick union WKM-M, 3 1/8 115" OMNI r, DD trim -ESP, ige x nge, w/ Y. CCL, orator l Y` Hilnirp Ainoku, LIA: I B Monopod Platform 2014 BOP Stack (Workover) 09/12/2014 Ideck ALAS~ OIL AND GAS CONSERYATION COPlPlISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 28, 2002 Dwight Johnson Chris Meyers UNOCAL Field Superintendents 260 Cavair Street Kenai, Alaska 99611 No-Flow Verification TBF Well A-06, PTD 167-025 Gentlemen: On April 14, 2002 our inspector Lou Grimaldi witnessed a "no-flow test" on UNOCAL's Trading Bay Field well A-06. Mr. Grimaldi arrived on Monopod Platform and found the well flowing at less than 180 scf/hr with no liquid observed. The well was shut-in and built to 14 psi in 1 hour. When subsequently opened, the initial gas rate was 500 scf/hr and declined to 250 scf/hr in 30 minutes. Two additional shut-in and bleed cycles were performed, with the gas flow observed to decline to "a whisper" with only a few psi observed surface pressure. No liquid production was ever observed. Trading Bay Field well A-06 (167-025) meets the criteria of a "no-flow" performance test and as such, is considered incapable of unassisted flow to the surface. As proscribed at 20 AAC 25.265 (A), it is not required to have a fail-safe automatic SSSV, hOwever, the pilot and SSV must be maintained in satisfactory operating condition. If for any reason the well again becomes capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well file on board Monopod. Sincerely, Thomas E. Maunder, Sr. Petroleum Engineer MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, Commissioner Tom Maunder, ~'~~ P. !. Supervisor o~1o%'° \ DATE: April 5, 2001 FROM: JeffJOnes, SUBJECT: Petroleum Inspector Safety Valve Tests Monopod Platform Trading Bay Field Thurs. diiy, Ar~ril 5. 2001: I traveled to UNOCAL's Monopod Platform and witnessed the semi annual safety valve system testing. Lead operator Gary Smith conducted the testing today; he did a thorough job and was a pleasure to work with. As the AOGCC Safety Valve System test report indicates I witnessed the testing of 18 .wells and 53 components, with four failures. The pilot on well A-02 tripped at 26 psi and was repaired and passed a retest. This well has had the SSSV removed for repair since 2/24/00 and has not been re-installed. Well A-11 has had the SSSV removed for repair since 11/7/99 and has not been re-installed./indicated to Mr. Smith that these SSSV's must be repaired and re-installed and successfully tested in a timely manner or the two wells shut in. Well A-06 SSSV failed to close and will require maintenance. Wells A-13 and A-21 have been certified as "no flow" status and do not have SSSV's installed. While on location ! inspected the platform and found it very clean and it appeared to be in excellent condition. Summary.: I witnessed the semi annual Safety Valve System testing at Unocal's _ Monopod Platform in the Trading Bay Field. Monopod Platform, 18 wells, 53 components. 4 failures, 7.5% failure rate. Platform inspection conducted. Attachment: SVS TBF Monopod Platform 4/5/01 JJ NO,,, ,N-CONF, IDENT,!AL SVS TBF Monopod Platform 4-5-01 JJ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: UNOCAL Operator Rep: Gary Smith AOGCC Rep: Jeff Jones Submitted By: Je, ffJones Date: Field/Unit/Pad:, .T,r,,a, ding Bay Field M0nopo,d Separator psi: LPS 65 HPS 4/5/01 :'"':"i'?':': :':':.: ' ';'" i~:i::~":: ~':':~ ~' :"!"!2", "~ ~"': ,:' '; ' . ' '~ .... ' Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLe: I I I I I I I I I II I A-01RD 190147'0 65 45 42' P P P OIL A.02 1660490 '65 45' 26 3' ' P'" ~43" 4/5/t}1 .... OIL A-03RD3' 1971300 65 45 42 i~ ' 'P' "P ' ' ' 0IL A-04 1670020 r~O6'''~: 1670250 6'5~ 45 45 P P ~43 OIL A-07 1670460 65 45 '42 P ' P'' P ' 'OIL A-09RD 1810360 A- 10 1670760 A-,t~I .... 1700~40 ' 65 "~5 ' 43 P"' P '"~3 ' ' ~ ...... OIL , , , A-13 1680020 65 45 41 P P OIL A- 14 1680270 A-15' '168033'0I' 65 45.... 45 ''P "P P " 'OiL A-16RD " 1880380 '" 65 ' ' 45 4i/42 P .... P 'P ........ OIL !A-17RD 1810670 65 45 43 P P P oIL A-18 1680760 65 "45 47 '~' 'P P .......... OIL A-21 17004'~0 65' ' 45 ' 46 P P .... A-22 17'003'i0 ' 65 45 ' 44 '~ P P ' P ...... 0iL' A-23 1700590 A-23DPN 1720200 ...... X-24RD 18i0400 65 45 ..... ~['1 P ' P 1b ' OIL A-27RD1 1970630 ' ' 6'5 45 43 ,. 'P ' P" P ........ oIL A-28RD 1890920 65 45 45 P P P OIL A-30 1730140 A-32 1770180 65 45 44 P P P ' oIL , , , Wells: ..... 1,8. Components: 53 Failures: .... 4 Failure Rate: 7.5% 1"190Day , , Remarks: A-13 & A-21 reported as No-Flow wells. SSSV's removed for rep.ak: A-02 out.sin, ce, 2./;2~/00, 'A-11 Out 'sin~e" 1 i'/5/99. ' '" A-02 pilot repaired and retested "OK". A-06 SSSV failed to close. A-16 RD is a dual completion. . ......... 4/9/01 Page 1 of 1 SVS TBF Monopod Platform 4-5-01 JJ ALASKA OIL AND GAS CONSERVATION CO IlSSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907)279-1433 FAX: (907) 276-7542 November 15, 1995 Chuck Beaucamp Field Superintendent UNOCAL 260 Caviar Street Kenai, Alaska 99611 Re: No-Flow Verification TBF Well A-06 Dear Mr. Bcaucamp: On October 25, 1995 our Inspector, Jerry Herring, witnessed "no-flow" tests on UNOCAL wells A-06 (PTD 67-025) and A-13 (PTD 68-002). The wells were tested for flow to atmospheric pressure. Our inspector observed that well A-13 produced no liquids and only a trace of gaS, he also noted that well A-06 did not bleed down belOw 10 psig. The Inspector concluded that while TBF well A-06 did not demonstrate "no-flow" characteristics, TBF well A-13 did c~ibitcd "no-flow" characteristics and should be accorded . "no-flow" status. TBF well A-13 (PTD 68-002) meets thc criteria of a "no-flow" performance test and as such is considered incapable of flow to the surface. Under the authority of 20 AAC 25.265(A) it is not required to have a fail safe automatic SSSV, however, the pilot and surface safety valve must be maintained in good condition and, if for any reason, thc well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be reinstalled and maintained in good working condition. Sincerely, Blair E. Wondzell PI Supervisor cc: Jerry Herring bew/nf-tbf2w MEMORANE 'M State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnst~ DATE: Chairman ~ October 26, 1995 THRU' Blair Wondzelll ~ ,~, FROM: Jerry Herring, ~t SUBJECT: Petroleum Insp~ctor FILE NO: 151kjycd.doc No Flow Test Unocal, Trading Bay Field Monopod Platform, A-06 & A-13 Wednes, dav,.October 25.1995: While on the monopod platform, I witnessed the testing of two wells, A-06 & A-13, to determine if the wells met no flow guidelines. On this day, well A-13 demonstrated good no flow characteristics. The tubing was bled down to atmospheric pressure and no liquids and a trace of gas flowed from the well. Well A-6 did not bleed down below 10 PSIG while ! witnessed the test and gas continued to flow at a rate greater than allowed in the no flow guidelines. ,S, ,ummary,: I witnessed a successful no flow test on Monopod well A-13. Unocal North Amerk Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. JohnsOn: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, GRea~~o nS ~~~1 ~rS~~.h~ 1 ~ i~ 7n~ag er GSB/lew CONDUCTOR 1 2 3 4 5 6 7 8 9· l0 ll 12 13 14 15 16 17 18 19 20, 21 22 .. ~. ~___ 24 25 26 27 28 29 30 31 32 "Y" = 2,523,126 "X" = 218,871 MONOPOD 'CENTER FROM SOUTHEAST CORNER, SECTION 4, TgN, R13W · 'qli L A T. - 6 0 ° 5 3 4 3.51 ~q'?"'~o/'a--*;~ ~°/#/l/.~/~ "Y" COORD. ,. 2,523,134.3 2,523,130.2 2,523,125.7 2,523,121.7 2,523,118.2 2,523,114.4 2,523,113.2 2,523,113.2~ - 2,523,114.8 2,523,117.7 2,523,121.8 2,523,126.4 2,523,130.3 2,523,133.8 2,523,137.6 2,523,138.8 2,523,138.8 2,523,137'.2 2,523,132.8 2,523,129.4 2,523,132,0 2,523,128.4 · ...2,523~.~4.R ... -. ~ 2,523,133.9 2,523,120.9 2,523,131.4 2,523,118.1 2,523,127.2 2,523,123.6 " 2,523,120.0 2,523,122.6 2,523,119,2 "X" COORD. 218,880.9 218,883.2 218,883.9 218,883.2 218,881.3 218,876.8 218,873.0 218,869.0 218,864.6 218,861.1 218,858.8 218,858.1 218,858.8 218,860.7 218,865.2 218,869.0 218,873.0 218,877.4 218,875.7 218,878.6 218,870.8 218,873.9 · ~.?~ ~. ~?.6-_~. 218,867.0 218,878.1 218,863.9 .218,875.0 218,865.1 218,868.1 218,871.1 218,863.4 218,866.3 WELL # A-28 A-25 A-30 A-27 A-23 A-21 A-22 A-14 A-13 A-17 A-8 A-15 and RD FSL FEL 1621 554 1617 551 1612 551 1608 551 1605 '553 1601 557 1600 561 1600 565 1601 570 1604 573 1608 576 1612 577 1616 577 A-24 and RD A-29 A-9 and RD A-19 A-18 A-11 A-3 A-1 A-7 A-4 A-6 A-32 A-12 and RD A-20 A-2 A-16 A-26 A-lO A-5 and RD l&2 1620 1624 1625 1625 1624 161g 1616 1618 1615 1611 1600 1607 1617 1604 1613 1610 1606 1609 1605 574 570 566 562 558 559 556 564 561 "568 556 571 559 570 566 563 571 568 PM- )2 Operator Lease No. o r Owns r ~'~P. t. CODE '50-133-20020 Release Date ,.-7_-28-69 = State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Petroleum Branch INDIVIDUAL WELL RECORD ,_ ~io~Pil ~-_pE Cal!~- Location (Surface) T. 9N R. 13W S Meridian _,._ , · Permit No. 67=25 Issued ..... 6-5-67 = . _ Conducto~ 24 Loc. (Bottom) .... 1980'NNL ,& :1980' PEL gee. ~ ,. Weli No. A-6 Area ~ading Bay ,, Spud Oatej,, 6-6-67 Dri I I lng Ceased 6-18-67 _-. = . :_... _ _ - ~ ,,,, , ~ ,_ / - --~uspen~ed ......... _ .... ~ ......... Abandoned Total Depth 6498 Elevation 112' Completed (F-GL-P), 6.~_28_='67 ,, IP 2223 B/D, Grav 30.2° APl _ ., -- ~lc ~, _~1., , _ , ~ , Gas 745 MCF/O, Bean 32 /64 CP psi, TP 500 psi Casing: Size ~ SxCmt Perf: ~ Squeeze Jobs Eot NSO: 300_ sx .... __ _,: 150 sx tOO_s×_. ..... GEOLOGIC FORt~ATIONS PRODUCTIVE HORIZONS Surface Lo~es t Tested Nan~ Depth Contents Yea r WELL STATUS Jan Feb., Mar Apr May June July Au9 Sept Oct No,v. Dec Rems r ks: Contr: Caldril Inc. .................... _ Form 9-330 (Rev. 5-68) WELL Ui~L~'£EDSTATES SUBMIT IN DUPLe. i:~ ' i (See other In- DePARTMeNT OF THE INTeRiOR ~ structionson reverse side) GEOLOGICAL SURVEY ~ ~'~' COMPLETION OR RECOMPLETION R~I:;~I AN~ LOg * la. TYPE_. O~._.W~ELL: ....... OIL .... [~-' ' WELL[]GAS ..; ................................... DRY[] ~ %VELL b. ~YPE OF COMPLE~ON: ~ELL OVE~ ~ DEEP- EN BACK nESVR. 2. I~AME OF OPERATOR Union 0il Co. of California 3. ADDRESS OF OPERATOR '" 507 W. Northern Li~ht:s Blvd., AnchOrage, ~A!~aska 4. L~CATION OF WELL (Report locatio~ clearly and in accorgance with any ~tatP requt~e~'(mt~ )* At su~ace [600~ N. & 568' ~. ~t top prod. interval reported below 1760' N & 1364' W o~ Suif' lodation ~t total ~ep~ 1865' ~ a 1429' 15. D~TE6_6_67~ SPUDDED 116.6__lS__67DATET.D. REACHED · 20. TOTAL DEPTH, MD & TVD ] 64~8 ND-6007 VD 6490 ltd 5. ADL 18731 6. IF INDiA~/, ALLOT..~I~E~.: OR tTR.!BE NAME 9. ':WELL ~Oa A-6 ~- (32-4) ~:~adifii . -. ~AELE TOOLS 21. PLUG, BACK T.D., MD & TVDI22' IF MULTIPLE COMPL'~HOW MANY*~i ' _.~'- ]!23' INTERvALSDRILLED~ BY 2~..~o.~c~ ~.~(.), o~ ~H~S co~o~ ~o., .o~o~, ~(~ ~. ~V.)* ::~ ~O' 5659 )96-6145, 6155-6300, 6320-6370 H~o~ . . ~ 26.:.T~PE ELECTRXC AND OTHER LOGS RUN ~ ~ ~ ~.~ . RECO~..~ ~ ~ ~ · '~Lk ' . ,~. 28J 106~ io o ~ 1/Z'? I:':~000 sacks ~: ~9 5/8' ] 40 649~. I :. 1)~ 1/4:~ 1~;¢;;850 sacks 29~j ~ LINER RECORD ~ ~ - .- ~ '' '~: ?: I 30. TUBING 31. PERFORATION RECORD ([~, ~g~e ~ - :[:~: -: ,:': 27. WAS WELL' CORI[D AM~)UN~ -PULLED · .' ' :None '- 6096-6145 · 6'-1--55-6300 .............. 4-t-/.2".-je~-hokes/foot -- 320-6370 ~2. ~'/' ACID, SHOT, FRACTURE~ CEME. N? SQUEEZE, .ETC.`' DEPTH; ~INTERyAL 4644-- 6375 AMOU~N'~ &ND KiND 0~_ MATERIAL USED 300 ia~!' ceuent. ,... , ' 150 sacks (-cement ,. - 100 .sa~ ::cem~t DATE ~FIRST PRODUCTION I PRODUCTION METHOD (.Flowing, gas lift, pumping--size ~a~.g type o! pu'mp) !OP TEST ] HOURS ' CHOKE SIZE PROD'N. FOR OI~BBL. ~ ~ 0AS--MCF. -29-67 I 24 I ~,s~ ~ ~ ~ ;.d i32/64 I ~;~ ff ~223 ~: J: 745 WELL STATUS (Produoing or Shut-in } -WATER ,--!--~BL. I ~GAS-OIL RATIO 34. D~S,~OSI~!PN. QF.QAS .(~.014, use4.]or.tuel,~ve~te4,.etc.) ............... '~ :. ~ ~ ~$~:~WlT~ESSiD Used for fuel and vented ~, : :.r'': M'' L* Br~tcher 35. LIST OF ATTACHMENTS ~ ~ 36. I~hereby eertffy~t~the E~attached information l~complet~and CorreCt 'a'~ determined from ali avatlabl~ re~ords- ' *(See Instructio,, and S~,.~or Ad~ional Data:On Reverse Side)" ,o-/~ - ~f~ .,,,, ........ PAc~iR INSTRUCTIONS Geneiah This form is designed for submitting a complete and correct well complebon report and log on all typesbf land~and leases to either a Federal agency or a State agency,' or~b~, pursuant to applicable Federal and/or State laws' and regulations. Any'necessary special instructions concern~.'~ the~.use of this~;form and the number of copies to be submitted, particularly with regard to local, area, or regional procedures and practices, either are-shown below or will bO>issued by, or ma~y be obtaine~l from, the local Federal ' and'~6~ State office... _~ See. instrfi~tions, on:. · items 22 and. 24, and'. 33, below regarding sepa~rate reports-for separate completio .n~.- If n..O..]~filed prior ~ the time tbi~ sn~mary record rs submitted, conies of all currenttv-%vo,,o~,~-^~ ' ...... : ....... tion ~i~d nressure~:ests 'and- i '~A~,o, .... . .... ~.~ ~ ..... ~-£~ ....... : ..- ~_~ ~,_, .... ~-~. ~.~-me .~., geo~ogis~s, sampie:ano core ahalysis, all t~:pes electric, etc.), forma- . ,. d r ............ ~.,,~o~.~,, o~ a~,,~u -credo, ~o me ex~en~ requirea-~y applicable Federal:.and/or State laws and reguTati0ns. All attachments shoirM be listed oE: this .~0rm,' see ite~ 35. -. ~F~;rIai_othffi%ef~%~cPP.~sC~rbulceti~st.e reqmr~e.~ locations on Federal or Indian land should_be described in acco~ance_~with Fede~.al r~q~tirerh.~nts. Consult locat.-Stato !.~m~: Indicate~which. elevation is-rased as ref~ere~!.c~ (where not otherwise shown) for depth measurements given~in o~ther. S'l~aces on th. is for.~, and '.m any attachmentsf) .... ,?em~ zz a~d 24: If this well is completed for separate production from more ~han one interval zone (multiple completion), so state in iten~22, and in ii~m 24 show the pro"~ucing for each . ~tibmit a separate ~~eport (pa~'~) on this f~illm, adequately identified, I,,. ,9: ~Cm~t ~%?at.r~.teAL%C~le~t oSnUPrPel;~%t~ tl~is~rSm.~;he~c~Inllt~rhvOaU~dtoS%~etoh~r~l~2j~.mu~Uple.smge ?.eul?..n. tin~and the lo~ation..~f the~emen~ing tool ISent 33: i : ~ . ._ ~, ~y prouucem ! ~ee ~nsrrucdo~'ror items 22 an6-'24 alive.) ~ i'-~. :~ ¢'? · · C .. -2-, .',.- 37. SUMMARY OF POROUS ZONES" ..~- SHOW ALL IMPORTA~ ZONES OF POROSITY AND CONTENTS THEREOF; CORED INTER~LE~ ~D ALL DRILL-STEM TESTS, INCLUD~'NG ~8. ' ~ ' ' h) ~ .- ~ - GEOLOGIC MAR~RS , ~ DE~H INTERVAL T~ED, CUSHION USED, TIME TOOL OPEN, PLOWING AND SHUT-IN PRESSURES, AND RECOVERIES ~ ~,~ ~ U ['¢ ;~ ' ~' ~] ~ ' ~ ~ ~ : ' ' - C = ~ !~ MEAS. DEPTH -:. c :' ~' ;<' ~ :-'~ ~ 'Sa stone, pos~ ~il 'not tested ~c~ ~'.. ' "' · -.Mille :Kenai 13~5 : .. '~ ~ ....... - " ~ 6096 5628 .. .... I~ : fl .... : . '" ,-'~ . ,, 3063 .:'J: 3804 ........ Sandstone, p0~sT ~il, not ~ested:: . .zu c =e .... :'=> .;..: '-' : 4448 to ', 'no - = ~ '~ -' · 4348.. :.. Sands ne, poss. oil t tested. : ,~ c .:.~. 60~6 '.: 6432 C~i~ ' ~ . . . [ealock r~ c. ~ oil~ produ n8 ~- ~ . .~ " ; L.' ~ : '; ' ' '" - ................ , ~ .¢ .. ' It~ 33 ' ' -. v: ~ ,:: ~j See c -~ ~ : ~ c> ~ . < ~. '.: .: .; .: ~ .~ :.- ~:. - .......... : t No'cores c .no BST's ran - , ,o ~ ~ 2 cz ., , :. . ~.... .. ~ ~., . . ., ' " ": ~: / ~ :~I' :' ' ~. ' ~ '~ , ~"~ " . : .. . . ~ ' - i : .... ~ .." ~ ~ .... '. ' . . . " . :. ~ .:. C, ;- ,~ '~ ~ ¢': : "~,~ L ~ ,% ,, .~. ~ ~ ~ ~ , .~ : ,:' ,., .. .~ ,~ ~ , . . U.S. GOVERNMENT PRINTING OFFICE: 1963--0':-683636 : / FORM 153 (REV 5/62) WELL NO. State A-6 Trading. Bay {FIELD; W~n~ Rnrn,,~h - <-COON¥~)--o SEC. 4 T. 9N R. 13W UNION OIL COMPANY DRILLING REPORT CAS! NG RECORD 13 3/8" 61// J @ 1068' Rotary (TOOLS) s.~M. June 27, 1967 (PERIOD ENDING) INOTE INEFFECTIVE CASING) NO. DEPTHS I INCLINATION DATE i ] :ORREIcT DETAILS OF OPERATIONS, DESCRIPTIONS AND RESULTS ~OURS FROM i TO DEPTH ANGLE ~, NOTE MAKE O~ INSTRUMENT) "II CONTRA( TOR: CALDRILL ALASKA, INC . · EQUIPMENT: OILWELL 860 ELECTRIC LOCATION: CONDUCTOR 24 1620 N - 568 W S. E. CORNER SEC. 4, T. 9N, R 13W, SM ELEVATIONS: WATER DEPTH 62' MLLW ! R.T. TO OCEAN FLOOR 174' i R.T. TO ~fLLW 112' ! R.T. TO DRILL DECK 22.07 R.T. TO PRODUCTION DECK 40.82 MEASUREMENTS: ALL DEPTHS FROM ROTARY TABLE. I RECEIVED AUG 1 1967 DIVISION OF MINES & MINERALS FORM i,')~) (REV WELL NO. A-6 TRADING BAY STATE (FIELD) _KENAI BOROUGH (COUNTY) sec. 4 T. 9N R. 13W B.&M. UNION OIL COMPANY DRILLING REPORT (TOOLS) (PERIOD CASING RECORD 13 3/8 61# c 1068 12 1/4" hole below 1080' {NOTE INEFFECTIVE CASING) . . CORRECT D fours 1967 FROM TO DEPTH ANGLE I i [NOTE MAKE O1' INSTRUMENT) 2 6-5 0 395 Moved ri~ @ 2:30 A Ran roug] pipe gui~ i of hole assembly~ Drilled 2 6-6 395 1080' Continue( 395' to Drill. 1080'. ] ran back O' to 51; 2 6-7 1080 1080 Continue¢ hole cle~ again. 26 j ts. and land( shoe @ 1( located 941' , 90( i cl'as's i mixed wit i wit.h rig i H.ad. lapp.rc Bumped pi floats hE ] Layed do~ I I cement· [ 13 3/8" c 2 6-8 ' Standing tested sa up and ir, cemented up drill1 and Hydr~ start dri ETAILS OF OPERATIONS, DESCRIPTIONS AND RESULTS from A-5 to A-6. Rig centered over conductor .M. Installed riser and spudded well @ 1:30 P.M. with 12 1/4" bit for 30' in area of conductor . Drilled 12-1/4" hole to 300'. Pulled out and picked up 6 1/2" Dyna Drill and drilling Ran in hole and oriented Dyna-Drill. Dyna- 12 1/4" hole from 300' to 395'. Dyna-Drilling and surveying 12 1/4" hole from 740'. Pulled out of hole and laid down Dyna- Ran back in hole and drilled 12 1/4" hole to Pulled out of hole, made up 17 1/2" hole opener, in and opened 12 1/4" hole to 17 1/2" from to open hole from 517' to 1080'. Circulated · Made short tmip and circulated hole clean Pulled out of hole with drilling assembly. Ran of 13 3/8" - 61# J-55 buttress thread casim~ casing.@ 1068' R.T. Positioned "Flexiflow" 1068' and "Flexiflow" collar @ 1024'. Fin Joint 39.00' and centralizer @ 1058'~. 103.8', 1025', '~ 85%'., and 818'. Mixed and pumped 1000 sacks cement preceded .by 50 cu. ft. water. Cement Inlet Water (118# slurry). Displaced cement pump. ~siing...914 cu. ft. mud at 56 cu. ft./min. )roximately 190 cu.ft, cement returns to surface· plug with 1800 psi., bled pressure back and held okay. Cement in place @ 4:00 P.M. 6/7/67. 2 7/8" tubing out of derrick while standing Also broke out riser assembly and cut off casing and began installing Shaffer K.D. head. cement, finished installing K.D. head and same O.K. to 3000 psi for 15 minutes. Nippled installed new choke assembly. Also while standing magnifluxed all drill collars and subs.. Made g assembly, ran in hole, and tested pipe rams ' to 1000 psi for 15 minutes. Preparad to .ng out cement and float equipment. RECEIVED AUG 15 1967 DIVISION OF MINES & MINERALB ANCHORAGE FORM I~$ {REV WELL NO. A-6 __ TRADING BAY STATE {FIELD} KENAI BOROUGH (COUNTY) SEC. 4 T. 9N R. 13W B.&M. UNION OIL COMPANY CASING RECORD DRILLING REPORT (TOOL$ ) (PERIOD ENDING) 12 1/4" hole below 1080' (NOTE INEFFECTIVE CASING} NO. t __.___ DEPTHS INCEINATION I -' TOURS CORRECT DETAILS Of OPERATIONS, DESCRIPTIONS AND RESULTS . -- ' ~ I I ' · ROM TO DEPTH ANGLE i INOTE MAKE OJ INSTRUMENTi 2 [ 6-9 Drilled out float collar @ 1024' ant Zloat shoe at ! 1068' Encountered cement stringers from 970' to top I ' i I of float collar. Drilled and surveyed 12 1/4" hole _t from 1080' to 1699' with a bit change @ 1600'. Pulled t . out of hole and changed near bit stabilizer from 12 1/4" i I to 11 1/2" sleeve. Ran in hole and drilled and surveyed 12 1/4" hole to 2050'. Pulled out of hole and changed near bit stabilizer back to 12 1/4" sleeve. Ran in ~ hole and drilled and surveyed 12 1/4" hole from 2050' j ~ to 2110' . 2 6-10i 2050 3213 Drilled and surveyed 12 1/4" hole from 2050' to 2550'. Pulled out of hole to pick up bit #4. Ran back in h01e and drilled and surveyed from 2550' to 3213'. Started I OUtof hole to pick up bit #5. 2 6-111 3213 4075 Finished trip out for bit #5 and ran back to bottom. ~ Drilled and surveyed 12 1/4" hole from 3213' to 4075' , with bit change @ 3819'. 2 6-12 4075 4769 Drilled and surveyed 12 1/4" hole from 4075' to 4769' i with bit changes @ 4355' and 4651'. 2 I 6-13 4769 5256 Drilled and surveyed 12 1/4" hole from 4769' to 5256' I with bit change @ 5178'. 2 I 6-14 5256 5655 Drilled and surveyed 12 1/4" hole from 5256' to 5655' with [ : bit change @ 5412'. Presently pulled out of hole for i i bit change. 2 i 6-15 5655 15975 Drilled and surveyed 12 !/4" hole from 5655' to 5975' I with bit changes at 5718' and. 5925'. 2 6-16 5975 ~6326 Drilled and surveyed 12 1/4" hole from 5975' to 6326' with : 'bit'changes at 6129' u.~:.i 6269'. 2 6-17 i 6326' 6498' Drilled and surveyed 22 i/4" hole from 6326' to 6498' i with bit changes @ 6353' and 6437: Circulated for logs ~ @ 6498' an:;i pd!led out of hole. RECEIVED ' , AU6 1 5 1967 ".................. DIVISION OF MINES & MINERA~ ANCHORAU~ FORM 153 (REV§/62) ~ WELL NO. A-6 TP~&DING BAY STATE (FIELD) KENAI BOROUGH (COUNTY) · EC. 4 T. 9N R.13W B.&M. UNION OIL COMPANY DRILLING REPORT (T 00LS ) (P~ I oD ENDIN(;) CASING RECORD i59 its. J 55 40¢/ casing landed @ 6940' with shoe @ 6490', Differential collar @ 6405.09. DV collar @ 4644.18. {NOTE INEFFECTIVE CASING) NO. tOURS DATE 1967 6-18 6-19 DEPTHS FROM TO 6498' 6498 (6490' ED) INCLINATION DEPTH NOTE I~AKE O; CORRECT ANGLE DETAILS OF OPERATIONS, DESCRIPTIONS AND RESULTS Rigged up Schlumberger. Ran Induction, Electric Log, Borehole, Compensated Sonic Log, with hole caliper, formation Density Log, Gamma Neutron Log, Continuous Dipmeter and shoe 30 sidewall samples. Rigged down Schlumberger and ran in hole with drill pipe to condition mud prior to running casing. Rigged t© run 9 5/8" casing. Ran and landed 158 its.. ~5/81'' J55 40# T & C buttress casing @ 6490'. Pumped.. 50 cu. ft. water ahead. Followed by 850 sacks Class G, CFR 2 Cement Blend. 'Displaced Bottom Plug with approx- imately 723 barrels..mud,, which calculated to be 50% more than needed. It was felt that'since there was no indication that the .plgg reached the self fill differential collar on bottom~ that the DV collar may have been opened by the bottom plug. 50 cu.ft, water was pumped, followed, by 820 sacks Class G, CFR 2 blend, displaced with 2050 Cu. ft. mud. Plug was bumped w~ ~ 900# and bled off. Had 30 cu.ft, fluid returns. Pressured plug again to 1000#, pressure bled off to 900# where it held after bleeding. Cement in place @ 8 P.M. At i0 P.M~,..1500# pressure was put on plug, and g.hen bled off. Plug_ holding O.K. Removed blow out plug. Landed casing with full pipe weight. Installed tubing head from A-1 on A-6 and tested it to 3000# for 15 minutes O.K. Re- installed choke manifold. Centralizers at 6488, 6445, 6407, 6082, 6042, 5917, 5793, 5548, 5465, .5344, 5014, 4809, 4684, 4644, 4111, 3742, and 3287.~ R£CEIV[D AUG 1 5 1967 DIVISION OF MINES & MINERALS ANCHORAGE FORM 1153 (REV 5/62) WELL NO. SEC. (COUNTY) R. UNION Oil COMPANY DRILLING REPORT (TOOLS) (PERt r': :;DING) CASING RECORD {NOTE INEFFECTIVE CASING) NO. TOURS DATE 6-19 DE PT HS Iii FR OM 6490.00 6488.00 6407.19 6405.09 4646.23 4644.18 61.03 38,23 TO 6488.0( 6407.1~. 6405.0~. 4646.2." 4644.1~ 61. O~ 38.2: INCLINATION CORRECT DEPTH ANGLE NOTE MAKEOIINSTRUM£N~ LEI ~GTH 2.00 80.81 2.10 '58.86 2.05 ;83.15 22.80 38.23 DETAILS OF OPERATIONS, DESCRIPTIONS AND RESULTS CASING DETAIL Howco float shoe 40# J55 T&C Buttress, Jts. 1 & 2 Howco side fill collar 40# J-55 T&C Buttress, Jts. 3 thru 45 Howco D.V. cementer 40# J-55 T&C Buttress Jts. 46 thru 157 40# J-55 T&C Buttress Jr. 158 (18.02 cut off) Below zero RECEIVED AUG 1 t 67 DIVISION OF MINES & MINERAl.8 ANCHORAGE RM 15a (REV~/02) WELL NO. A-6 TRADING BAY STATE KE, AI BOR0UCH (COUNTY) SEC. 4 T. 9N .. 13W B.&M. UNION OIL COMPANY DRILLING REPORT (TOOLS) (PERIOD ENDING) AUG 15 !967 DIVISION _('7)~ MINES & MINERAI~ ANCHOR. AGE {NOTE INEFFECTIVE CASING) NO. I DATE TOURS 6-20 6-21 ;-22 2 6-23 DEPTHS INC LINATION FR OM TO 6498 6425 EI 6498 6425 El 6498 6425 EI 6498 6425 E~ DEPTH NOTE MAKE 0 CORRECT ANGLE INSTR UMENI DETAILS OF OPERATIONS, DESCRIPTIONS AND RESULTS Landed casing, installed slips and packing. Ran in hole and displaced mud with Inlet water. Found top of cement at 4225.75. Drilled out dement, DV collar and side fill differential to 6425'. Circulated and pulled out of hole. Made up Howco RTTS tool. Ran in hoie and located a leak at 4644' . ,.ior between 4650' and 4630v Set RTTS tool at 4530'. Mixed 100 sacks class "GI' cement with CFR2 mix. Closed tool on cement 40 cu.ft, short. Cleared holes with 40 cu.ft. Inlet water. Unable to reach squeeze ~ressure. Build up 400#. Bled back 20 cu.ft. Pulled tool loose and backscuttled. Mixed 200 sacks class "G" ce cement and CFR2 with 1% CaC1. Closed tool after mixing. Followed cement with 384 cu.ft. Inlet water. Held 1500 # on annulus while sq.ue.ezing. Cement in place at 10:30 am. Final pressure'1400#. Pulled out of hole. Waiting on cement. Total 214 sacks cement behind casing. Waited on cement five hours. Ran in hole and found top of cement at 4535'. Drilled out cement from 4535' to 4664'. Closed pipe rams and pressure tested ok to 500# for 15 mins. Ran pipe to bottom and changed hole over to 70# Inlet water with sodium chromate. Pulled out of hole and rigged up Schlumberger. Ran cement bond and gamma ray coorelation logs from surface casing to total depth. Found.generally continuous poor bonding from 4800' to PBD at 6425'. Picked up and ran one foot carrier gun and perforated four holes at 6375'. Ran in hole with DP and RTTS tool to 5922'. Mixed and pumped 100 sacks regular cementL followed by 30 cu.ft. Inlet water plus 255 cu.ft, weighted Inlet water. Closed tool after mixing cement. After cleaning tool, staged squeezed for two hours. Injected theoretical 60 cu.ft, cement to form at 2000# and 3 cfm. Injected additional 14 cu.ft, to form in stages with pressure increase to 3200 psi (500# on annulus). Final build up to 3200# held steady. Cement in place at 5:30 am. Bled pressure, released packer and reversed. Pulled out of hole and rigged up Schlumberger to perforate fo~:: holes at 6060~. Couldn't get gun below 5975' so '~:~zlL. i~ p~.~'~L, cd same. Ran in hole with bit and tagged cement top cont'd. . . FORM 153 (RF'V WELL NO. A-6 UNION OIL COMPANY DRILLING REPORT CASING RECORD TRADING BAY STATE (FIELD) KENAI BOROUGH (COUNTY) (TOOLS) sec. 4 T. 9N R. 13W B.~M. (PERIOD ENDING) {NOTE INEFFECTIVE CASING) I DE PTH$ INC L IN a t ION NO, DATE - ~ I CORRECT DETAILS OF OPERATIONS, DESCRIPTIONS aND RESULTS TOURS I FROM i TO DEPTH ANGLE ! [NOTE MAKE OI INSTRUMENT) 6-23 (cont'di. at 5975'. Drilled cemen~ from 5975~ to 6206' then began i hitting only occasional stringers from 6206' to 6375' ! · Ran DP to 6425' and circulated hole clean. Pulled out of I .~ole, ,and picked up RTTS tool. Ran and set tool at 4980' I ,to pressure test squeezed perfqratio, ns at, 6375'., Set. packer,, pressured to 1000 ps,~ and perf. s bega,n,.,t,~king i fluid. Could pump in with maximum rate of 4cfm at 2000#. 6498 Released packer went on do~m hole and reset packer at 2 6-24 I 16425 E! 6300'. Mixed and pumped 50 sac.ks, of regular cement. ! F--°'llowed cement wit~ '385 cu.ft. Inlet water and closed tool. pumpe~ thio,rani,cai 35 cu.,,~t, cement into ' formation a_t._2.500#, t.he~ ,staged 6 cu.f~.i.q,~,~e,nt with final buil~ up tp. 2750# which he~d. Released pressure and bled back 20 cu.ft. Re-Staged 20 cu.ft, with build up to 2500#. Drill pipe pressure then rapidly decreased to 700# with corresponding increase from 0-700# in annulus. Released pressure and bled back 4 cu.ft. Cement in place at 2:30 am. Total time from mix - 2 hrs. I great difficulty and attempted to Released RTTS with ! reverse, but could pump only with iow rate without ! exceeding 500#. Changed over and pumped down drill pipe ii but still could only get 2-3 cfm. Discontinued pumping i 1 and started out of hole with wet string. Pulled 30 strands, found washed out joint, and laid down same. i [ Pulled additional 24 stands and found cement in drill pipe. Laid down 18 joints with cement in them. Next I- 29 joints immediately above RTTS tool and tool itself were completely free of any cement. Ran drill pipe back . I in hole wi~h bit and scraper. Went to 6425' with no indication of cement in casing.~:~Circulated hole clean, closed pipe rams, and pressure tested casing ok to 500# for 15 mins. Pulled out of hole and ran cement bond log i in two runs from 5950~ to 6425' (one run at 0# casing pressure and one run at 500# casing pressure). Both ~ runs indicated same bonding as shown on original cement I[ bond log. Pulled out, picked up carrier gun and !perforated four holes at 6060'. Picked up RTTS tool and. ran same to 5980'. Mixed and pumped 50 sacks cement followed ~ith 360 cu.ft. Inlet water then closed tool. Began s~aga squeezing perforations at 6060'. RECEIVED AUG 1 5 1967 UNION OIL COMPANY WELL NO. A-6 TRADING BAY STATE (FIELD} KENAI BOROUGH (COUNTY) (TOOLS) sec. 4 T. 9N DRILLING REPORT CASING RECORD {NOTE INEFFECTIVE CASING) NO. DATE ~' i ' i' LC O1~ R I~ ~:~T T OUtRSi F'IR O,'vt~ TO) DEPTH / ANGLE 2 6-25 ~6498 I Staged ~6425 EI 2700# ~ at 12: i i scuttl ~ single t tool· ~ bottom ~ Circul I RTTS t ~ : sacks i wate~. ~ with f pressu 2:30 F ~ of cem ~ I ~ ~ to for~ ~ Ran ba I , ~ cement i 6000' ~ to 612 bottom , 2 6-26 6~98 ~ Pulled 6~25 EI i bond 1, 6055~ [ squeez, ~ ~ appear: ~ forate, ' . to 614. ; Change, 1 6-27 ~ 6498 Finish, ' 6425 El landed 6033· 6: ~ diesel ~ ~ i~edi~ ~ ~ Rig re2 DETAILS OF' OPERATIONS, DESCRIPTIONS AND RESULTS squeezed for 1-1/2 hours with final build up to and holding. Bled back 8 cu.ft. Cement in place 30 am. Pulled tool loose, but unable to back- . Pulled out of hole and found cement in 23 of drill pipe located 17 singles above Howco Ran in hole with bit and scraper. Went to at 6425' with no trace of cement in pipe. bottoms up and pulled out of hole. Picked up ol and ran same to 5980'. Mixed and pumped 50 regular cement followed by 496 cu.ft. Inlet Closed tool and staged squeezed for 1-1/2 hours, final build up to 2700# and holding. Released and bled back 12 cu.ft. Cement in place at · Pulled tool loose and reversed with no trace returns. Total of 28 cu.ft, cement injected ~mation. Pulled out of hole with RTTS packer. in hole with bit and scraper and tagged top of at 5980'. Drilled soft cement from 5980' to then firm cement from 6000' to 6060'. From 6060' 0' hit two slight bridges then went freely to Circulated hole clean. out of hole after pressure testing ok to 500# for s. After 12 hours waiting on cement ran cement )g from 5900' to 6425'. Bonding from 6045' to indicated to be improved and satisfactory after Bonding from 6380' to 6405' not impaired and satisfactory. Rigged up Schlumberger and per- intervals 6320'-6370', 6155'-6300', and 6096' ' using 4" carrier guns and 4 shots per foot. rams and started running 2-7/8" tubing. running and hydro-testing 2-7/8" tubing. Tubing at 6324.37 RT with Baker permanent packer set at · Inlet water below packer was displaced with prior to setting packer. Well began flowing ately after being put to production at 9:55 am. released at 10:00 pm. RECEIVED AUG 5 1967 ........ ,Di'vi.b~um OP Mllt,,II~:S & MINP..RAL3 ANCHORAGE W~LL NO. A-6 TRADING BAY STATE [FIELD) KENAI BOROUGH (COUNTY) SEC. 4 T. 9N R. 13W B.&M. UNION OIL COMPANY DRILLING REPORT (t O OLS ) (PERIOD ENDING) CASING RECORD {NOTE INEFFECTIVE CASING) NO. TOURS DATE DEPTHS FROM INCLINATION TO 6498 TI 6425 El DEPTH [NOTE MAKE 0 CORRECT ANGLE INSTRUMENT DETAILS OF OPERATIONS, DESCRIPTIONS AND RESULTS COMPLETION RECORD 13-3/8" 61# J-55 T&C Buttress casing at 1068'. 9-5/8" 40# J-55 T&C Buttress casing at 6490'. Perforations: 6320' - 6370' 6i55' - 6300' 6096' - 6145' 4 holes per foot True Vertical Depth: 6008.18' 1865.41' North 1429.12' West RECEIVED 1 b 1 }67 DIVISION OF MINES & MINERALS ANCHORAGE FORM 155 '(REV 5/02) wmmm NO. State A-6 Tradin~ Bay ~FIELD) Kenai Borough (COUNTY) SEC. 4 r. 9N R. 13 W B.&M. UNION OiL COMPANY DRILLING REPORT (TOOLS) {PERIOD ENDING) CASING RECORD {NOTE INEFFECTIVE CASING) NO'I DATE TOURS DEPTHS fROM TO 6324 6323 6322 6225 6222 6038 6034 6000 5994 4081 4076 2064 2059 331 328 325 36 35 6323 6322 6225 6222 6038 6034 6000 5994 4081 4076 2064 2059 331 328 325 36 35 0 INCLINATION DEPTH CORRECT ANGLE INSTRUMENT DETAILS OF OPERATIONS, DESCRIPTIONS AND RESULTS TUBING DETAIL Trip Sub Otis "N" Nipple 2-7/8" Armco SealLok Tubing 6.4#, J-55 Otis "X" Sleeve 2-7/8" Armco SealLok Tubing 6.4#, J-55 Baker Model S-2 Hydraulic Packer 2-7/8" Armco SealLok Tubing 6.4#, N-80 Otis "CX" gas lift mandrel 2-7/8" Armco SealLok tubing 6.4#, N-80 Otis "CX" gas lift mandrel 2-7/8" Armco SealLok tubing 6.4#, N-80 Otis 'ICX" gas lift mandrel 2-7/8" Armco SealLok tubing 6.4#, N-80 Otis ball valve mandrel Otis flow coupling 2-7/8" Armco SealLok tubing 6.4#, N-80 Donut Zero RECEIVED AUG b 1967 DIVISION OF MINES & MINERAL~ ANCHORAGE , '~'~L_~ ALACAL DIRECTIONAL DRILLING CORP. Jo~ ~o. " ~-~:)'"~ 888 No. Main Street · Santa Ana, California 92701 , SHEET ~~ ~ ~967 X co~,~Y~ ~r~I0}~ 0IL C0~.~.A~ ADDRESS WELL Sm.~X A-6 LOCATION TRADING BAYCOUNTY...~AI BOROUO~ STATE A~gS~A ..... ~" "" , IJ ~ VERTICAL DEPTH COURS~ ~ DIRECTION TOTAL ;," : . . COURSE .......... " ! ! .... ' ' .... 2,,~7 ,,;~o ¢¢ ~7 oo . , ~ I ' 300 .... 0 00, 300 00 1 ~RmlC~ ., 395 .... 3 3.5 39& 85 5_39~ gfi ~] 0 b~ 5 37 ;If [~ ~ .... w~9~F b 3o g58 65 5 o2 N 6~ w 1 96 9 76 , ¢ ............ _ ,, . , , . hg0 g L5 ~89 5L 2~57 ~ 50 ~ 3_62 .... ~... 616 ~ .. 9 ~ .... 61E 18 10i LO N 61 ~ 12 02 .... 28 6~g .... ~_ 00 67~ 83~ 12 89 N 51 ~] ..., 20 13 .. . 38 05 7o9 ~1 ..... dA~,,. 765~0 6 7~ ~z> ¥~ .... 2~96 ........ ~2 7 i~.. 15 30 .... 783 15 21 65j N ~2 ~' .... El 05 57 19 ~ ................. [, , ..... , ........ . I I 886 19 00 873 92 31 25 N'~ ~'~ 6L 28 " 78 l0 - - ~, .... ' ' ~ . .... i ,, , .,, . ( 79 ~'; ~' 22~ 960 15 '3L 8Z~ ~ l~2 _~; 90 17 101' ' - ~'~ '" '" : ,. , ,,, :L080 _ .2j. 30 ...... 1051 3] ~3 l~8~ g0 ~ _ .. 123 ~8 ..... ,. 129 36 :~._ 26 3C ..'1136 3~ ~2~ 39~ 39 ~'~ 156 E2 ......'156 0~ 1269 _ 27~ ...1220 0~:~2 68 N 39 ~¥ . _18~....59 182 90 1363 ~ 27 3~ ..... 1'303 h~ g3 EC N 39 <~J .. 22~ 32 /< ; 210 21~ ,... ., .... ~ ..... :t~57 28 0C . ' 1386 4~ db l} N h0 V..~ 25;. 1.~_ 238 :5? ,., 1583 '_ ..... 28 3C ... 1~>97 19 60 13:~ 39 lt~ ._ ' .....30~ 86 ...... 276 , 1669 . <.29, 0C 1572 L1 ~.1 69 N 39. W i , ......... 33~ ..26 ......... ~ ' 302 6E ,, , , c'HEcKED BY TYPE OP" SUM,'VEY~ , ,, CALCULATED BY ........... , COMPANY ALACAL DIRECTIONAL DRILLING CORP. 888 No. Main Street · Santa Ana, California 92701 UNIOAT OIL C0~,~2X.TT ADDRESS JCl NO.. s,~, ,o. 2/~ WELL STA~ DEVIATION ANGLE 2170 255O. 27/~1 _ 3118 395~ - A-6 LOCATION TR ADTNO B A-v- COURSE DIRECTION DEVIATION DEVIATION COUNTY. !Cd~ N AZ BOROUGH VERTICAL DEPTH COURSE TOTAL 1657 1828 1915 2o2~+ 2206 2368 2541 3997 &19& ~288 COURSE TOTAL LATI T U DE DEPARTU R E LAT l T U DE NORTH SOUTH EAST .NORTH SOUTH DEPARTURE · TYPE OF SURVEY; CALCULATED BY ', CHECKED BY_~ COMPANY .... ALACAL DIRECTIONAL DRILLING CORP. 888 No. Main Street · Santa Ana, California 9270! UNION 0IL C0?,PAI,~ ADDRESS JOI~ NO. s.E~ .o. 3/3 , JUNE 1967 WELL Sm .'~TE A-6 __LOCAT,oN,TRADI~IC BAY __COUNTY. K~,NAI BOROUGH .STATE. DEPTH 4738 d9~ 5115 ~78r 5365 5612 5718 5925 i 6129 6269 6L~37 DEVIATION ANGLE VERTICAL DEPTH COURSE DIRECTION OF COURSE TOTAL DEVIATION DEVIATION d368 ~557 &713 &771 &9~& 5173 5272 5/~67 5659 5792 5950 6oo~" COURSE LAT! TU DE DEPARTURE SOUTH EAST TOTAL LATITUDE NORTH SOUTH EAST DEPARTURE TYPE OF SURVEY: ......... CALCULATED BY ~ CHECKED BY '"'"UNION OiL COMPANY TRADING BAY- STATE NO. A=6 Kenai Borou g h, ALACAL 6498' M.D. 6008.18' V. D. N. 1865.41' W. 14,29.12' SCA'LE: !"= 500' · FORM 369 4-63 TO AT .UNION OIL COMPANY OF CALIFORNIA Document Transmittal August 3, 1967 No, State oF Alaska FROM Union Oil Co. Al__ Anchorage TRANSMITTING THE FOLLOWING: 1 Directional Survey from Union Trading ;ay St;;te A-6 (247-6498') / ~' I&L ~LI V .... FORM 369 4-63 TO AT,, UNION OIL COMPANY OF CALIFORNIA Document Transmittal , ~uly ll, 1967 Mr. Tom Marshall 300T Porcupine Drive Anchorage, Alaska NO,_ FROM Graydon H. Laughbaum, Jr. AT, Anchorage TRANSMITTING THE FOLLOWING: TRADING BAY STATE A- 6: 2" IES, Run 1, One blUeline and one sep~.a ~/~x /:'--, / 9[7, ..... . , .... ...... Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Ef£ective: July 1, 1964 LAND {3F'FIOE LEASE NUHBEE LEASE DR UNIT NAb'IE LESSEE'S MONTHLY REPORT OF OPERATIONS The followin~ is a eorreot report of operations and production (inel~dinff drillinff and produein~ wells) for the month of ...... _J_g.n__e_ ............................ , 19_~_, ............................................................................ ~e~t' s address --}P~___~,___~9_~_g_h~r.~__~gh~a_.~!~,_ .... ~___ ' Company .... Pq!o~__0~!._~r~X__~__.~_~!~_~_ Phone 277-1401 ................................................................................... ............... ~ o~ ~ Tw A TRADING iY BARREI~ OF OIL ORA~ FT. OF OAS (In'thousands) · Spudded 6t hole to lC 61# casin direction casing c~ "DV" cemer 6096t - 62 Jet holes cemente 1 hole t ented at ter at 4 ,70' at i per fool GALLONS OF BARRELS 0r REMARKS (~ASOLINE WATER (If (If drillinz, depth; if shut down, oau~e; RECOVERED none, so state) d~te ~nd r~ult of trot for gasoline oontent of Sas) 6/67. Drilled l:.-1/4"dtrectional ~80' and ~pened tc 17-1/2". 13-3/8" at 1061'. Drilled 12-1/4" ~ 6498'. 9-5/8" 40# J-55 6490' .th HalZiburton $44'. Pi from atervals with four 1/2" Well ,ompleted 6/28/67. R CEIVED UL 10.1967 OF MINES & MINERA~ ANCHORAGE NOTE.--There were .................. ..~..0. ........................ runs or sales of oil; ............... 0. .............................. M cu. ft. of gas sold.' rio ............................................................ runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be liled in duplicate with the Division of Mines & Minerals by the 6th si the succeeding month, unless otherwise directed. FORM SA - I B 50M I/67 MEMORANDUM TO:I-- ~ Ii. Shepard Iada~Crial Safety Im~pec~o~ I~ar~e~ of Labor State of Alaska DATE : SUBJECT: T~adt~ ~ay it:ate ~A-6 (32~) ~ton Oil Co. o£ Calif., Operato~ FORM SA - lB 50M ~/67 MEMORANDUM State of Alaska FROM: DATE : SUBJECT: Form sTATE OF A'.ASKA OIL AND GAS CONSERVATION COMMITTEE \ SUBMIT IN TRI1 aTE* (Other instructions on reverse side) API 50-133-20020 Effective: July 1, 1964 5. LEASE DESIGNATION AND SERIAL NO .~DL 18731 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAM~ 8. FARM OR r-J~ASE NAME Tradtn9 BaY S~te APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 1a. TYPE OF WORK DRILL [] b. TYPE OFWELL WELL WELL OTHER ZONE ZONE 2. NAME OF OPERATOR Union Oil Co. of California · DEEPEN .I-I .. PLUG BACK [-1 S. ADDRESS OF OPERATOR 2805 Denali Street, Anchorage~ Alaska 99503.. 9. WELL NO, A-6 (~2-4) 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.*) At surface Trading Bay Monopod' ~C~nductor' 24, 1620'N'& 568'W At ?fop~s~d 9rg~.nz~nre Sec. 4, T 9N, R' t3W, SM. 1980' S & 1980'W of NE comer Sec. 4, T 9N, R 13W. 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICEs Approximately. 27 air miles NW of Kenai, Alaska iD. DISTANCE FROM PROPOSED 1~4-,~ 10')/%lO ,,4: 14,-~,-, J 16. NO. OF ACRES IN LEASE LOCATION TO NEAREST DIAIt 4, U/'L/ ~ ~2£ J.J. II~ J PROPERTY OR LEASE LINE, FT. J (Also to nearest drlg. unit line, if any) J ~ JJ~ U I8. DISTANCE FROM PROPOSED LOCATION* 1~.2n$ M TO NEAREST WELL, DRILLING, COMPLETED, o~ ~.~ ~., o~ .~,. ~.~, .~ading Bay St. A-2 6100 TVD 21. ~VAT~ONS (Show whe~er DF, RT, GR, e~.) Trading Bay, Hemlock 11. sec., T., R., M., OR BLK. AND SURVEY OE AREA Sec. 4, T 9N, R 13W, SM 12. B.OB. OUGH SHI 13. SPATE Ken~-i Penin.J Alaska 17.NO. OF ACRES ASSIONED TO THIS WELL 8O 20. ROTARY OR CABI,E TOOLS Rotarg 22. APPROX. DATE WORK WILL STARTS lit 101' above M SL Iune 1, 19 6 7 23. PROPOSED CASING AND CEMENTING PROGRAM QCANTITY OF CEMEN~ SIZE OF CASING WEIGHT PER FOOT 13 3/8" 1/4" vertical hole to 300' and SIZE OF HOLE 7 1. Drill 12 .~ETTING, _DEPTH 1100' 12 1/4" directional 1250 sx. hole to 1100'. Open 12 1/4" hole to 12 1/2'~:o 1100'. Run and cmt 13 3/8" 61~ 1-55 buttress csg to surf. 2. Install and test 12, 3000%~ Shaffer dbl hyd gate and GK Hydril. 3. Drill 12 1/4" directional hole to TD. Run elec. logs and evaluate for compl. 4. Run 9 5/8" slotted liner thru Hemlock zone and blank 9 5/8" csg above with CP on top of Hemlock zone and DV crntr where req. 5. Run correlation.log, jet perf where indicated for completion. Btm. hole location: Approximately 1820' S and 2140' W of NE corner Sec. 4, T 9N, R13W, SM. Deviated development well, no affected parties. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program, if any. SIGNE'D ~ ' ' TITL~District Development Geologt&~E M ay 31 1967 W. an--~''~ ' . , (This space for Federal or State office use) CONDITIONS OF APPROVAL, IF ANY: TITLE APPROVAL DATE THOMAS R. MARSHALL, JR. Executive Secretary Alaska Oil & Gas Conservation Committee RECEIVED *See Instructions On Reverse Side 5 4 UNION TEXACO TB#t I ~ I UNION T8'~3 ,,,~..TRADING BAY tUNIT UNION - M.ARATHON A DL- 18'75J ::'" Je J5 I R 13 W i i JO JO J5 T I0 N 35' UNION E. TB STATE T 9 N JJ UNION- MARATHON ADL-17596 RECEIVED glVl~tON U~ MINIMS & ANCHORAGE UNION OIL COMPANY OF CALIFORNIA ALASKA OlST.RICT LOCATION MAP TRADING BAY. STATE A-6
