Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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7. Property Designation (Lease Number):
1. Operations
Performed:
2. Operator Name:
3. Address:
4. Well Class Before Work:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
Susp Well Insp
Install Whipstock
Mod Artificial Lift Perforate New Pool
Perforate
Plug Perforations
Coiled Tubing Ops
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well Other:
Change Approved Program
Operations shutdown
11. Present Well Condition Summary:
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
16. Well Status after work:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
OIL GAS
WINJ WAG GINJ
WDSPL
GSTOR Suspended SPLUG
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
PBU 09-43A
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
222-156
50-029-22078-01-00
14264
Conductor
Surface
Scab Liner
Production
Liner
8839
80
4250
5551
12234
3268
14240
20"
10-3/4"
5-1/2"
7-5/8"
2-3/8"
8842
33 - 113
32 - 4282
6528 - 12079
30 - 12264
11008 - 14264
33 - 113
32 - 3508
4988 - 8674
30 - 8804
7949 - 8839
3789
470
2090
6280
4790
11780
none
1490
3580
7740
6890
11200
12244 - 14000
4-1/2" x 3-1/2" 13Cr80 28 - 6612
8790 - 8857
Structural
4-1/2" Baker S-3 Perm , 6513 , 4978
No SSSV
6513
4978
Bo York
Operations Manager
Dave Wages
David.Wages@hilcorp.com
(907) 564-4545
PRUDHOE BAY, PRUDHOE OIL
Total Depth
Effective Depth
measured
true vertical
feet
feet
feet
feet
measured
true vertical
measured
measured
feet
feet
feet
feet
measured
true vertical
Plugs
Junk
Packer
Measured depth
True Vertical depth
feet
feet
Perforation depth
Tubing (size, grade, measured and true vertical depth)
Packers and SSSV
(type, measured and true vertical depth)
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.Representative Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Exploratory Development Service StratigraphicDaily Report of Well Operations
Copies of Logs and Surveys Run
Electronic Fracture Stimulation Data
Sundry Number or N/A if C.O. Exempt:
ADL 0028327, 0028324 , 0028343
28 - 5043
12
62
0
0
2594
3005
1363
1343
284
259
N/A
13b. Pools active after work:PRUDHOE OIL
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Sr Pet Eng: Sr Pet Geo:
Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Sr Res Eng:
Due Within 30 days of Operations
By Grace Christianson at 1:16 pm, Jun 13, 2024
Digitally signed by Eric
Dickerman (4002)
DN: cn=Eric Dickerman (4002)
Date: 2024.06.12 15:57:31 -
08'00'
Eric Dickerman
(4002)
RBDMS JSB 061924
DSR-6/13/24WCB 8-30-2024
ACTIVITYDATE SUMMARY
2/5/2024
***WELL S/I ON ARRIVAL***
RAN 20' x 1.56" DUMMY GUNS w/ 1.72" SWELL RINGS, 1.50" BULL NOSE TO
12,368' SLM, NO ISSUES GOING INTO DEPLOYMENT SLEEVE @ 100 & 120
FPM.
***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS***
4/14/2024
***WELL S/I ON ARRIVAL****
PT PCE 250LP-3000HP
PERFORATE WITH 8 GRAM OWEN SHOGUN 6 SPF SPIRAL STRIP GUNS FROM
12255' - 12264' MD.
CCL STOP DEPTH=12247.8' MD, CCL TO TS=7.2', CORRELATED TO HES RCBL
DATED 04-MAR-2023
RIH AFTER FINISHING LOGGING PASS AND SIT DOWN AT 12254'
LAY DOWN UNIT FOR THE NIGHT.
***CONTINUED ON 15-APR-2024***
4/15/2024
***CONTINUED FROM 14-APR-2024***
T-BIRD FLUSHES 275 BBLS OF CRUDE DOWN TUBING TO CLEAR DEBRIS
FROM YESTERDAY.
PT PCE 250 LP-3000 HP(good)
UNABLE TO GET 1.69" OWEN SPIRAL GUNS THROUGH DEPLOYMENT SLEAVE
AT 110008' MD. ATTEMPTED MULTIPLE LINE SPEEDS.
TOOLS COVERED WITH ASPHALTINES, LOST 6 FT OF FRICTION TAPE. RIG
DOWN FOR SLICKLINE B&F
***WELL LEFT S/I, DSO NOTIFIED.
4/15/2024
*** WELL S/I ON ARRIVAL ***
RIG UP DS9-43
*** CONTINUE WSR ONTO 4/16/24 ***
4/15/2024
T/I/O=1878/1886/0 Temp= S/I (Assist E-line with Perforating) Pumped 250 BBLS
of crude down TBG for load. E-line unable to reach desired depth.
E-line in control of well upon departure.
Final WHPS=700/1250/0
4/15/2024
T/I/O = x/x/x LRS 76 - Assist Slickline (PERFORATING) ***Job Continued to 04-15-
2024***
4/16/2024
*** CONTINUED WSR FROM 4/15/24 ***
BRUSHED WITH 3-1/2" BRUSH DOWN TO DEPLOYMENT SLEEVE @11,008' MD
WHILE PUMPING 201-BBL HOT DIESEL
MADE 2 ATTEMPS RUNNING CENTRALIZED BRUSH INTO DEPLOYMENT
SLEEVE @ 11,008' MD (BOTH ATTEMPS FAILED)
RAN DOUBLE BOW SPRING BRUSH INTO DEPLOYMENT SLEEVE @ 11,008' MD
(NO ENTRY)
DRIFTED 21' X 1.56" DUMMY GUNS (1.72" SWELL) SAME SET UP AS LAST
SUCCESSFUL DRIFT TO DEPLOYMENT SLEEVE @ 11,008' MD (NO ENTRY)
MADE ENTRY INTO DEPLOYMENT SLEEVE (11,008' MD) WITH KNUCKLED
CENTRALIZED BRUSH (MADE ENTRY FLICKING TOOLS THROUGH) BRUSHED
DOWN TO 11,800' SLM
RAN BAR BELLED LIB TO DEPLOYMENT SLEEVE @ 11,008' MD (NO BEVEL TO
HELP IN ENTRY)
*** CONTIUE WSR ONTO 4/17/24 ***
Daily Report of Well Operations
PBU 09-43A
PERFORATE WITH 8 GRAM OWEN SHOGUN 6 SPF SPIRAL STRIP GUNS FROM
12255' - 12264' MD.
Daily Report of Well Operations
PBU 09-43A
4/16/2024
***Continue Job from 04-15-2024*** Assist Slickline w/ B&F. Pumped 201 bbls 180*
Diesel into TBG for B&F.
SL in control of well upon departure.
FWHPs= 200/1100/0
4/17/2024
*** CONTINUED WSR FROM 4/16/24 ***
DRIFTED 12,388' SLM W/ 21' X 1.56" DUMMY GUNS (1.72" SWELL) @ 150 FPM
(SUCCESSFUL ENTRY W/ BOW SPRING HOLDING BULLNOSE 1-1/2" OFF
LINER)
*** WELL S/I ON DEPARTURE ***
5/1/2024
*** WELL SI ON ARRIVAL***
STANDBY FOR SNOW REMOVAL BEFORE SPOTTING IN FOR JOB.
PT TO 250PSI LOW AND 2500PSI HIGH.
RIH. 1-7/16" CHD(1" FN, 7-2 WP) 10' X 1-11/16" WB, 1-11/16" MONO JARS, 1-
11/16" GUN GAMMA RAY, 9' 1-11/16 SPIRAL GUNS, 50" SLICKLINE
CENTRALIZER AND BULL NOSE. UNABLE TO GET INTO SLEEVE AT 11008'
AFTER 3 TRIES AR 30, 50 AND 100FPM.
*** JOB CONTINUED ON 5-2-2024 ***
5/2/2024
*** JOB CONTINUED FROM 01-MAY-24 WSR***
PT 250 LOW AND 3000 HIGH.
RIH WITH 1-7/16" CHD(1" FN, 7-2 WP) 10' X 1-11/16" WB, 1-11/16" MONO JARS, 1-
11/16" GUN GAMMA RAY, BOW SPRING, 9' 1-11/16 SPIRAL GUNS.
UNABLE TO GET DOWN PAST GLM#2 AT 3789' WITH TOOL STRING.
FIND THE BOTTOM 2.75" OF THE GUN STRIP HAS BROKEN OFF WHEN BACK
TO SURFACE.
RIH WITH 3.80" SLICKLINE CENTRALIZER TO DRIFT. SET DOWN AT 3789' GLM.
POOH RIG DOWN.
***JOB INCOMPLETE*** FISH IN HOLE, READY FOR SLICKLINE, PHOTOS IN
WELL PICTURES FOLDER
5/2/2024
Initial WHP T/I/O= 0/1100/0 (Assist E-Line) load TBG until fluid packed, unknown
fluid level in TBG, Pumped 30 BBLS crude to load well, FWHP=300/1100/0 Eline in
control of well upon departure
5/11/2024
T/I/O=137/1076/1 Assist SL ( fishing) Pump 70 bbls 30 * DSL down tbg *** job
continued to 05-12-24***
5/11/2024
***WELL S/I ON ARRIVAL***
ATTEMPTED TO RUN 2.81" X CATCHER; UNABLE TO PASS STA# 2 @ 3789' MD.
RAN DE-CENT AND 3.68" LIB TO 3772' SLM; LIB SHOWS PIECE OF STRIP GUN
@ 02:30.
RAN 4 1/2" BRUSH, 3 1/2" BRUSH, AND 2.61" 3 PRONGED WIRE GRAB. S/D IN
GLM's & BRUSHED UNTIL ABLE TO PASS. TAGGED XO @ 6497' SLM. (no
recovery).
RAN 3 1/2" BRUSH, AND 2.61" PRONGED WIRE GRAB; S/D IN XO @ 6497' SLM.
GENTLY WORK TO 6501' SLM. POOH & CHECK TOOLS (no recovery).
***CONTINUED ON 5-12-24***
5/12/2024
***job continued from 05-11-24*** LRS 72 Assist S/L (PERFORATING). Pumped 14
bbls of diesel into the TBG. Final T/I/O= 275/1065/0
Daily Report of Well Operations
PBU 09-43A
5/12/2024
***CONTINUED FROM 5-11-24***
RAN 3 1/2" BRUSH, AND 2.61" 3 PRONGED WIRE GRAB TO DEPLOYMENT
SLEEVE @ 10,991' SLM. NO RECOVERY OF MISSING STRIP GUN PIECE.
RAN 4 1/2" BRUSH, AND 3.80" GAUGE RING. BRUSHED & FLUSHED 4 1/2" TBG
TO 6517' MD.
RAN 21' x 1.56" DMY GUNS, 1.5" BOWSPRING, AND 1.25" BULLNOSE. CLEAN
ENTRY INTO DEP SLEEVE; S/D @ 11,023' SLM (32' INTO LINER).
RAN BOWSPRING CENTRALIZER & 1-1/2" SAMPLE BAILER TO DEVIATION @
12,420'
RAN 21' x 1.56" DMY GUNS, 1.5" BOWSPRING, AND 1.25" BULLNOSE, SAT
DOWN @ 11,023' SLM AGAIN....REMOVE KNUCKLE JOINT FROM SPANGS
RAN 21' x 1.56" DMY GUNS, 1.5" BOWSPRING, AND 1.25" BULLNOSE...CLEAN
DRIFT DOWN TO DEVIATION @ 12,405' SLM
***WELL LEFT S/I ON DEPARTURE***
5/25/2024
***WELL S/I ON ARRIVAL*** (Perforating)
RAN 4-1/2' BLB, 3.80" G-RING, BRUSH NIP @ 6492' MD
SET DREAM CATCHER IN X-NIP @ 6,492' MD
RAN 4-1/2" CHECK SET TO 6,492' MD(sheared)
****WELL LEFT S/I ON DEPARTRUE, DSO NOTIFIED OF STATUS****
Adperfs are shown correctly on WBS, below. -WCB
7. Property Designation (Lease Number):
1. Operations
Performed:
2. Operator Name:
3. Address:
4. Well Class Before Work:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
Susp Well Insp
Install Whipstock
Mod Artificial Lift Perforate New Pool
Perforate
Plug Perforations
Coiled Tubing Ops
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well Other:
Change Approved Program
Operations shutdown
11. Present Well Condition Summary:
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
16. Well Status after work:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
OIL GAS
WINJ WAG GINJ
WDSPL
GSTOR Suspended SPLUG
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
PBU 09-43A
Extended Perforating
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
222-156
50-029-22078-01-00
14264
Conductor
Surface
Scab Liner
Production
Liner
8839
80
4250
5551
12519
3268
14240
20"
10-3/4"
5-1/2"
7-5/8"
2-3/8"
8842
33 - 113
32 - 4282
6528 - 12079
30 - 12264
11008 - 14264
33 - 113
32 - 3508
4988 - 8674
30 - 8804
7949 - 8839
none
470
2090
6280
4790
11780
None
1490
3580
7740
6890
11200
12244 -14000
4-1/2" 12.6# x 3-1/2" 9.2# 13Cr80 28 - 6612
8790 - 8857
Structural
4-1/2" Baker S-3 Perm
6513
4978
Bo York
Operations Manager
Tyson Shriver
Tyson.Shriver@hilcorp.com
907.564.4545
PRUDHOE BAY / PRUDHOE OIL
Total Depth
Effective Depth
measured
true vertical
feet
feet
feet
feet
measured
true vertical
measured
measured
feet
feet
feet
feet
measured
true vertical
Plugs
Junk
Packer
Measured depth
True Vertical depth
feet
feet
Perforation depth
Tubing (size, grade, measured and true vertical depth)
Packers and SSSV
(type, measured and true vertical depth)
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.Representative Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Exploratory Development Service StratigraphicDaily Report of Well Operations
Copies of Logs and Surveys Run
Electronic Fracture Stimulation Data
Sundry Number or N/A if C.O. Exempt:
ADL 028327, 028324 , 028343
2
31
0
0
2
1775
1119
1310
250
265
323-150
13b. Pools active after work:PRUDHOE OIL
No SSSV
6513 / 4978
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Sr Pet Eng: Sr Pet Geo:
Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Sr Res Eng:
Due Within 30 days of Operations
28 - 5043
This 404 closes out
second 403 for second
batch of extended perfs.
By Grace Christianson at 1:39 pm, Jun 06, 2023
Digitally signed by Bo York (1248)
DN: cn=Bo York (1248)
Date: 2023.06.06 12:47:01 -08'00'
DSR-6/12/23WCB 1-31-2024
RBDMS JSB 071723
ACTIVITYDATE SUMMARY
3/9/2023
T/I/O = 1910/1920/10. Temp = SI. T FL (SL). AL open @ CV. T FL @ 6424' (sta #
1 SO).
SV, WV = C. SSV, MV = O. IA, OA = OTG. 20:00
3/9/2023
***WELL S/I ON ARRIVAL***
R/U POLLARD #57
***WSR CONT ON 3-10-23***
3/10/2023
T/I/O = 1910/1930/10. Temp = SI. IA FL (Assist SL). AL SI @ CV = 1940 psi. TBG
FL @ 7083' (659' below SO). SL in control of well at departure.
SV, SSV, MV = O. WV = C. IA & OA = OTG. 16:30.
3/10/2023
***WSR CONT FROM 3-9-23***
RAN KJ,KJ, 1.75" CENT, BOW SPRING CENT, 1.50" B. NOSE, DEVIATED OUT @
12,404' SLM
BRUSH X-NIP @ 6,482' SLM (6,492' MD)
SET 3.813 X-LOCK w/ IUD (=29" lih, 4 x 3/16" & 4 x 1/8" ports, .030" SHEAR DISC)
IN X-NIP @ 6,486' SLM (6,492' MD)
RAN 4-1/2" CHECKSET TO IUD, SD @6,489' SLM - SHEARED CHECKSET, GOOD
SET
ATTEMPT TO BRING WELL ONLINE, SHEAR IUD @580 PSI, DOESNT SURFACE
FLUID
PULL IUD FROM 6,492' MD
BRUSH 2.81" X-NIP @6,538' MD
SET 2.81" X-LOCK w/ IUD (=26" lih, 9 x 1/16" ports, .034" SHEAR DISC) IN X-NIP @
6,536' SLM (6,538' MD)
MADE 2 ATTEMPTS TO POP WELL, ~30MIN TO DRAW DOWN THE WELL FROM
1950PSI, COMMON LINE PRESSRUE IS ~220# TBG FLOWING PRESSURE IS
~254#, IUD DOES NOT APPEAR TO HAVE SHEARED (same out come both times)
DSO SWAPPED WELL TO TEST SEPARATOR FOR HOUR, THEN STACKED OUT
TBG ONCE MORE TO 1950PSI
3/11/2023
T/I/O = 500/1930/10. Temp = SI. IA FL (Assist SL). AL SI @ CV = 1940 psi. TBG
FL @ 6309' (115' above SO). SL in control of well at departure.
SV, SSV, MV = O. WV = C. IA & OA = OTG. 16:30.
3/11/2023
***WSR CONT FROM 3-10-23***
RAN 3-1/2" GR w/ EQ-PRONG (dogless) TO 2.813" X-LOCK / IUD @ 6,541 SLM /
6,538' MD
PULLED PULL 2.81" X-LOCK / IDU FROM 6,540' SLM / 6,538' MD
SET 2.81" X-LOCK w/ IUD (26" lih) (4 x 3/16", 4 x 3/32" ports .34" SHEAR DISC) IN
X-NIP @ 6,540' SLM / 6,538' MD
DSO POP WELL IN ATTEMPT TO SHEAR IUD & FLOW WELL - SHEARED @310
PSI
ATTEMPT TO PULL IUD, SITTING DOWN IN STA #1
RAN 3.74" CENT, 3' x 1-3/4" STEM, 3.76" LIB, SD @6,427' SLM - INCONCLUSIVE
MARKS ON LIB
RAN 3.68" CENT, 3' x 1-3/4" STEM, 3.74", 2.75" LIB, NO ISSUES PASSING STA #1,
CONT RIH & TAG X0 @6,519' SLM
RAN KJ, BLB, 2.79" GAUGE RING, NO ISSUES GOING THRU STA #1, SWEEP
MULTIPLE TIMES, CONT RIH & SD ON IUD @6,540' SLM
PULLED IUD FROM 6,540' SLM (6,538' MD)
DEPLOYED x2, SOAPSTICKS INTO WELL
***WELL S/I ON DEPARTURE***
Daily Report of Well Operations
PBU 09-43A
Daily Report of Well Operations
PBU 09-43A
3/12/2023
T/I/O = 450/400/0. Temp = SI. TBG FL (OE request). AL SI @ CV = 1940 psi. TBG
FL @ 4388' (2036' above sta#1 SO).
SV, WV, SSV = C. MV = O. IA & OA = OTG. 16:00.
3/13/2023
T/I/O = 200/400/0. Temp = SI. T FL (SL). ALP = 1900 psi, SI @ CV. T FL @ 4800'
(1624' above sta # 1 SO). Dropped 4 soap sticks @ 04:18 hrs.
SV, WV = C. SSV, MV = O. IA, OA = OTG. 04:30
3/13/2023
T/I/O = 300/400/Vac. Temp = SI. T FL (OE request). ALP = 1940 psi, SI @ CV. T
FL @ 3789' (sta # 2, Dome, 99 bbls).
SV, SSV, WV = C. MV = O. IA, OA = OTG. 16:30
3/14/2023
T/I/O = 330/400/0. Temp = SI. T FL (OE). ALP = 1900 psi, SI @ CV. T FL @ 3650'
(2774' above sta # 1 SO).
SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:00
3/17/2023
***WELL S/I ON ARRIVAL***(sbhp)
DRIFT W/ 1.85" CENT, 1.75" SAMPLE BAILER TO 12,336' SLM / 12,360' MD (+24'
correction, recover 1 cup of metal shavings and fine sand)
RAN DUAL SPARTEK SBHPS GAUGES IN CARRIER PER PROGRAM TO 12,360'
MD (see log for details)
***WELL LEFT S/I ON DEPARTURE***
3/20/2023
T/I/O = SSV/1900/0+. Temp = SI. Bleed IAP to 600 psi (coil req). ALP = 1890 psi,
SI @ CV. Hardline RU on well. IA FL @ 6424' (sta # 1 SO, 169 bbls). Bled IAP to
OT from 1900 psi to 600 psi in 1 hr. IA FL unchanged. OA went on VAC during IA
bleed. Did not monitor. Final WHPs = SSV/600/VAC.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 21:30.
3/21/2023
LRS Well Test Unit 1. Assit Coil. Begin WSR on 3/21/23. IL Well DS 9-43, OL Well
DS 9-36. Finish Unit Move, Standby. Continue WSR on 3/21/23
3/21/2023
Assist CTU (PERFORATING) Pumped 11 bbls 60/40 meth down IA. ***Job
Continued to 03-22-2023***
3/21/2023
LRS CTU 2, 1.5" Blue Coil, Job Objective: Extended Adperf, Acidize, N2 Lift
MIRU & RIH with 1.75" JSN. The tubing pressured up after 70 BBL's of KCL away.
Bleed KCL back, bleed the gas cap off. RIH to 3800' trickling 60/40. Dry drift down to
12424 and become detained. Attempt to circualet and only getting partial returns.
Line up to POP well via gas lift.
***Job Continued on 3/22/2023***
3/22/2023
LRS CTU 2, 1.5" Blue Coil, Job Objective: Extended Adperf, Acidize, N2 Lift
POP well via gas lift and put well in pad separator. Well completely blow dry down to
the screened orifice. Cannot get free with pressure cycle in tension nor compression.
Pump hot diesel down the coil and cycle pipe after two coil volumes - no movement.
CLose wing valve and let well stack out, then surge the well, no luck. Have LRS
circulate 270 bbls crude down the IA thru Sta#1 S/O GLV to surface. Still no
movement. Pump diesel down Coil at 0.7bpm at ~ 5300psi. Getting minimal returns
at surface, appear to be mostly squeezing thru Perfs like something is packed around
the Coil. Pressure up Coil & backside & dump to tanks. No luck getting free. POP
well with Gaslift to unload Tbg x IA down to the S/O GLV. Unload the tbg and rig up
HES N2 to pump down the coil. vary rates from 500 to 1000scfm. Work pipe.
***Job Continued on 3/23/2023***
3/22/2023
***Job Continued from 03-21-2023*** Assist CTU (PERFORATING) Pumped 65 bbls
150* Diesel down TBG. Pumped 10 bbls crude, followed by 10 bbls 60/40 pumped
by coil, and 81 bbls crude to freeze protect the Flowline. Pumped 291 bbls crude
assisting CTU.
3/22/2023
LRS Well Test Unit 1. Assit Coil. Continue WSR from 3/21/23. IL Well DS 9-43, OL
Well DS 9-36. Standby. Continue WSR on 3/23/23
Daily Report of Well Operations
PBU 09-43A
3/23/2023
LRS CTU 2, 1.5" Blue Coil, Job Objective: Extended Adperf, Acidize, N2 Lift
Continue pumping N2 down the coil and work pipe. Vary th pump rates, no
movement. Swap to 60/40 down the coil. Load the IA and tubing with crude. IA and
tubing loaded. Pump 5/8" dissolvable ball. Successfully disconnect at ~ 6100psi.
Pull out of Liner. Noticed scars on the pipe. Park Coil and inspect Injector with
manlift. Injector looks good. Continue Pooh. Freeze Protect Flowline w/ Crude. Out
of hole w/ upper half of the Baker TJ Disconnect. Stack down & inspect Injector.
Trim 50' of pipe. RIH w/ 3ea 1.50" Stingers & 1.50" DJN (Slim BHA). Tagged liner
top and tried various pump ates and speeds to get in and could not. Made it beside
the deployment sleeve and tagged the TOC on the backside. POOH to change
nozzle configuration.
***Job Continued on 3/24/2023***
3/23/2023
LRS Well Test Unit 1. Assit Coil. Continue WSR from 3/22/23. IL Well DS 9-43, OL
Well DS 9-36. Standby, Spot in unit, Begin RU. Continue WSR on 3/24/23
3/24/2023
LRS CTU 2, 1.5" Blue Coil, Job Objective: Extended Adperf, Acidize, N2 Lift
POOH to change nozzle configuration. Swap to 1.5" JSN w/ 3ea 1.50" Stingers.
Made it through the deployment sleeve and performed a fill cleanout down to the top
of the fish at 12404CTM. Pump gel pills and chase ooh at 80%. Freeze Protect Coil
w/ Diesel. RIH w/ Baker 1.69" GS Spear Fishing BHA. No issues passing thru the
LTP. Tag Fish at 12404' ctm. Had to jet into fish to Latch. Hit 51 jar licks at 10k over
then straight pulling 30k over. Was seeing little movement in the first ~ 20 jar licks,
then no movement after that. Pump off fish. Pump pipe displacement while pooh
with diesel. Lay down GS and one of the collets is broken off. Trim 200' of pipe and
make up 1.800" venturi BHA. RIH.
***Job Continued on 3/25/2023***
3/24/2023
LRS Well Test Unit 1. Assit Coil. Continue WSR from 3/23/23. IL Well DS 9-43, OL
Well DS 9-36. Standby, Spot in unit, RU. Continue WSR on 3/25/23
Daily Report of Well Operations
PBU 09-43A
3/25/2023
LRS CTU 2, 1.5" Blue Coil, Job Objective: Extended Adperf, Acidize, N2 Lift
Continue RIH with 1.800" venturi BHA. Dry drift into liner and run venturi from 12280
to tag at 12404. Recip pipe above fish. POOH. OOH with venturi and recover the
ball seat from the disconnect, what is left of the dissolvable ball, and a very small
amount of metal shavings. RIH w/ 1.69" G-Spear Fishing BHA with 1.69" Tempress
(Using Quadco Logan Accelerator & Jars rated to 15k). Latch fish on 2nd attempt at
12404' ctm. Hit 9 Jar licks up & down. Seeing the fish move up & down ~ 2-8'. On
the 10th cycle, picked up free with no overpulls. Pooh to check BHA. Pump pipe
displacement down backside. No fish, G-spear is intact and in the catch position.
Appears the G-spear may have been held in the released position by metal debris
picking up on the last cycle. RIH w/ YJ G-Spear Fishing BHA with 1.69" Tempress
(Using Quadco Logan Accelerator & Jars rated to 15k). Tag Dep Slv. Unable to get
in dry or circulating. Pick up 1000' and Rbih and made it thru Dep Slv. Continue Rih.
Latched fish and fish is moving ~10'. Got a latch and (2) 7K overpulls 10' apart, then
dragging heavy for 300' in liner. POOH to check tools. No fish. Decent metal
marks/gouges in GS. Decision to RDMO and hand over to slickline. RIH with nozzle
BHA to freeze protect well. Lay in diesel freeze protect from 2773'. Begin rig down.
***Job in Progress***
LEFT IN HOLE: 1.69" X 1.04' TJ DISCONNECT (1.36" ID G-PROFILE LOOKING
UP), 1.5" X 4.0" WT BAR, 1.5" X 4.0' WT BAR, 1.75" X 4.0' WT BAR, 1.75" X 4.0'
WT BAR, 1.75" X .33' JSN, OAL: 17.37', Top of fish ~12396CTMD.
Above fish: .215" x .5" x .6" collet from GS - 3/24/2023
3/25/2023
LRS Well Test Unit 1. Assit Coil. Continue WSR from 3/23/23. IL Well DS 9-43, OL
Well DS 9-36. Standby for Coi, RDl. Continue WSR on 3/26/23
3/26/2023
LRS CTU 2, 1.5" Blue Coil, Job Objective: Extended Adperf, Acidize, N2 Lift
RDMO.
***Job Incomplete***
3/26/2023
LRS Well Test Unit #1. Cont. WSR from 3/25/23. IL DS 9-43, OL Well DS 9-36. Cont.
RD, Unit move to Z-pad. End WSR on 3/26/23.
3/27/2023
***WELL S/I ON ARRIVAL***
RAN 10' x 1.75" PUMP BAILER UNABLE TO WORK INTO DEPLOYMENT SLEEVE
@ 11,008' MD.
***WSR CONTINUED ON 3-28-23***
3/28/2023
***WSR CONTINUED FROM 3-27-23***
RAN BOWSPRING CENT w/ 1.75" MAGNET TO 11,014' SLM (unable to get deeper,
recovered metal shavings)
RAN BOWSPRING CENT w/ 1.75" SAMPLE BAILER TO 12,381' SLM (no recovery)
RAN BOWSPRING CENT w/ 7" EXT, 1.75" MAGNET TO 12,385' SLM (metal
shavings)
RAN 2-3/8" GR TO 12,385' SLM (unable to latch, lose spang action)
RAN BOWSPRING CENT w/ .175" MAGNET TO 11,010' SLM (bowspring missing 2 -
10" x 1/2" metal bands)
MADE MULTIPLE RUNS W/ 1.75" CENT, 3' 1-1/4" STEM, 1.75" MAGNET TO
12,385' SLM (recovered missing bands & metal shavings).
***WSR CONTINUED ON 3-29-23***
Daily Report of Well Operations
PBU 09-43A
3/29/2023
***WSR CONTINUED FROM 3-28-23***
MADE 5 MAGNET RUN, ONLY ON ABLE TO GET TO FISH (recovering metal
shavings, unable to pass deployment sleeve)
MADE ONE RUN w/ 5' x 1-3/4" PUMP BAILER TO TOP OF FISH @ 12,389' SLM (no
spang or pump action)
***WELL S/I ON DEPARTURE***
4/11/2023
LRS CTU #2 - 1.50" Blue Coil
Job Objective: Fish BHA, Extended AddPerf, Acidize and N2 Lift
MIRU CTU. Perform Weekly BOP Test. Make up Venturi BHA with 1.69" muleshoe.
Venturi across 5-1/2" liner from 7000' to liner top at 11022' CTMD (11008' MD).
Unable to enter liner after mutiple attempts. POOH.
...Continued on WSR 4-12-23...
4/12/2023
LRS CTU #2 - 1.50" Blue Coil ***Continued from WSR 4-11-23***
Job Objective: Fish BHA, Extended AddPerf, Acidize and N2 Lift
OOH with venturi and find metal marks tagging the leading tip of muleshoe. Add
knuckle and swivel and RBIH with 1.69" venturi BHA. Tagged liner top at similar
depth and cannot make it in. POOH and recovered the collet broken off from the GS
on the previous coil rig up. Added additional weight bar and removed knuckle/swivel.
RIH and tagged liner top again, but ultimately made it into the liner top dry after
multiple attempts. Reciprocated venturi multiple times from fish to 50' above. POOH
and rcover a very small quantity of metal shavings in venturi. Make up Yellow jacket
GS BHA. RIH and tag liner top and cannot make it in. POOH to inspect tools.
Freeze protect well from 4300' in preparation for next run. Curvature of the liner top
seen on the nose of the GS. Circ sub's burst disc was ruptured. Eratic pressures and
a sudden drop observed during freeze protect. Drop tempress and add two more
weigt bars for length. YJ machines a nozzle to make the tip more conical.
...Job Continued on 4/13/2023....
4/13/2023
LRS CTU #2 - 1.50" Blue Coil ***Continued from WSR 4-12-23***
Job Objective: Fish BHA, Extended AddPerf, Acidize and N2 Lift
RIH with modified GS BHA. Tag at deployment sleeve, could not get in after multiple
attempts. POOH. BD YJ tools. MU fishing BHA w/ hydraulic centralizer. RIH w/ 2"
Hyraulic GS Spear. Make it in deployment sleeve. Tagged the fish twice dry and
twice pumping. On the 4th tag we got it to move down hole freely 50'. POOH
puming pipe displacement. Entire fish recovered. Numerous pieces of steel and
chunks of cement recovered from inside the fish. Make up and RIH with 1.800"
venturi BHA.
...Job Continued on 4/14/2023....
Daily Report of Well Operations
PBU 09-43A
4/14/2023
LRS CTU #2 - 1.50" Blue Coil ***Continued from WSR 4-13-23***
Job Objective: Fish BHA, Extended AddPerf, Acidize and N2 Lift
Continue RIH with 1.800" venturi BHA. Tagged at 11047 CTMD, likely getting beside
the liner and tagging TOC. Multiple attempts made to get into liner, unsuccessfully.
POOH to re-configure tools. Lay in freeze protect on the way out of hole. OOH with
ventui and the muleshoe is completely packed off with cement. Add swivel and
knuckle to tool string. RIH w/ 1.800" venturi BHA. Multiple attempts made to get into
liner, unsuccessfully. POOH to re-configure tools. OOH with ventui and the
muleshoe has small amount a metal shavings. LD accelerator & PU hyraulic
centralizer. RIH w/ 1.800" venturi BHA. Multiple attempts made to get into liner,
unsuccessfully. OOH with ventui and the muleshoe has small amount a metal
shavings. RIH w/ Motor and venturi burnshoe (1.84" OD). Tagged liner top and tried
to spin into it, unsuccessfully. POOH for newly machined Venturi w/ 1.75" nozzle
configuration.
***Job Continued on 4/14/2023***
4/15/2023
LRS CTU #2 - 1.50" Blue Coil ***Continued from WSR 4-14-23***
Job Objective: Fish BHA, Extended AddPerf, Acidize and N2 Lift
OOH with 1.84" Venturi/burnshoe BHA. Make up venturi w/ 1.75" nozzle
configuration. Surge pump and pipe speed and get into liner. Venturi 2.375" LNR
down to a hard tag at 12449. POOH and make up 1.875" diamond parabolic milling
BHA. Spin to get into liner and then mill/dress off at 12464 CTMD. Dry drift 2.375"
Liner to PBTD and POOH for logging tools. Make up and RIH with HES 1.69" logging
BHA with knuckle joint, 3 stingers, and 1.75" nozzle below. Tagged deployment
sleeve and cannot get in. POOH and reconfigure logging tools.
***Job in Progress***
4/15/2023
LRS Test Unit 6, Begin WSR on 4/15/23, IL DS9-43 / OL DS9-?, Post CTU Acid/ N2
Flowback, Begin Schedule STBY. Continue WSR on 4/16/23
4/16/2023
LRS Test Unit 6, Cont WSR from 4/15/23, IL DS9-43 / OL DS9-52, Assist CTU Acid/
N2 Flowback, Spot in Unit, Continue STBY for CTU. Continue WSR on 4/17/23
4/16/2023
LRS CTU #2 - 1.50" Blue Coil ***Continued from WSR 4-15-23***
Job Objective: Fish BHA, Extended AddPerf, Acidize and N2 Lift
OOH with logging tools. No marks on tools. Reconfigure tools to be straight with a
1.75" nozzle on the end. RIH. Tag repreadtedly at deployment sleeve. POOH. OOH
- No marks on tools. PU extra weight bars and swap 1.75" nozzle for a 1.77" tapered
bull nose on the end. RIH. Make it in the liner. Tag PBTD & log up from
compression to 10,800' CTMD. Repeat liner entry with bullnose - no issue. Circulate
well to seawater. Lay in freeze protect form 4300MD. Lay down logging BHA and
have a -8' correction, making corrected EOP at flag = 12953.41'. Deploy perf gun #1
272' of HES 1.56" GEO RAZORS, 6SPF, 60DEG PHASED with tapered bullnose.
RIH and tag deployment sleeve.
***Job Continued on 4/17/2023***
4/17/2023
LRS Test Unit 6, Cont WSR from 4/16/23, IL DS9-43 / OL DS9-52, Assist CTU Acid/
N2 Flowback, RU and Cont Schedule STBY. Continue WSR on 4/18/23
Daily Report of Well Operations
PBU 09-43A
4/17/2023
LRS CTU #2 - 1.50" Blue Coil ***Continued from WSR 4-16-23***
Job Objective: Fish BHA, Extended AddPerf, Acidize and N2 Lift
Cycle pipe at deployment sleeve. Jog pipe vaious distances ranging from 100' to
2000' in between tags. Did not get into liner. Flow check well and POOH pumping
pipe displacement.Lay down gun #1. Re-configure gun wth a knuckle, 1.5" bowspring
and 1.77" tapered bullnose and RIH with gun #1. Perforate 13,278-14000 with HES
1.56" GEO Razors, 6SPF, 60DEG PHASED. POOH pumping pipe displacement and
flow check well at surface. Retrieve gun #1 and deploy gun #2 with same
knuckle/bowspring/1.77" tapered bullnose. Perforate 13107-13287 & 13387-13582
with HES 1.56" GEO Razors, 6spf, 60DEG PHASED. Pull out of liner and flow check
well. POOH pumping pipe displacement.
***Job Continued on 4/18/23***
4/18/2023
LRS CTU #2 - 1.50" Blue Coil ***Continued from WSR 4-17-23***
Job Objective: Fish BHA, Extended AddPerf, Acidize and N2 Lift
Continue POOH pumping pipe displacement. Flow check well and lay down perf gun
#2. Remove scaffolding from wellhouse. Perform weekly BOP test. MU & RIH w/
knuckle, bowspring, and tapered bullnose. Unable to get in deployment sleeve X6.
Discussed with OE - Decided to bullhead acid from just above liner top. Pumped 15
bbls 15% HCl. POOH. At surface, change to 1.75" OD 1/2" ball drop for N2 lift. Stab
back on - with swab closed. Bring AL online and begin flowing back well through test
unit - with swab closed. Stand by while WB unloads to depth of GLM #1.
***Job Continued on 4/19/23***
4/18/2023
LRS Test Unit 6, Cont WSR from 4/17/23, IL DS9-43 / OL DS9-50, Assist CTU Acid/
N2 Flowback, STBY for Acid to be pumped, Initiate GL, POP/ Flow Fluids to Tanks.
Continue WSR on 4/19/23
4/19/2023
LRS CTU #2 - 1.50" Blue Coil
Job Objective: Fish BHA, Extended AddPerf, Acidize and N2 Lift
Continue unloading to depth of GLM #1. Well begins to cycle AL gas. RIH pumping
N2 and begin lifting. Take bites down to 10800'. Lift well at 500 and 1000scfm.
Once perforations produced 280bbl of fluid, reduce N2 rate in incriments, and slowly
PUH. Fluid rate began dropping once N2 was offline from 600 to 200 BFPD. RBIH
and bring N2 back online at 500 scfd.
***Continued on 04/20/23***
4/19/2023
LRS Test Unit 6, Cont WSR from 4/18/23, IL DS9-43 / OL DS9-50, Assist CTU Acid/
N2 Flowback, Cont to Flow Fluids to Tanks, CTU Injecting N2 lift, Acid @ surface
(neutralized at tanks), Increased GLR to 3.0 mmscf/d, Shut down N2 Lift, Rates died
off begin pumping N2 again. Continue WSR on 4/20/23
4/20/2023
LRS Test Unit 6, Cont WSR from 4/19/23, IL DS9-43 / OL DS9-50, Assist CTU Acid/
N2 Flowback, Cont Flowing while injecting N2, CTU Offline w/ N2, Divert 09-43 down
own FL, BD, RD.
4/20/2023
LRS CTU #2 - 1.50" Blue Coil ***Continued from WSR 4-18-23***
Job Objective: Fish BHA, Extended AddPerf, Acidize and N2 Lift
Continue to N2 lift at 500 scf. Well produced a total of 451bbl. N2 shut down and
PUH slowly to SO. IAP falls and liquid rate goes to zero at portable test separator.
Pull into lubricator and monitor for flow. Begining to show signs of flow. Roll well into
its own flowline and freeze protect the outlet well. RDMO to maintenance. DSO
notified of well status.
***Job Complete***
5/8/2023 Called out to assist SL. Not needed.
Daily Report of Well Operations
PBU 09-43A
5/8/2023
***WELL S/I ON ARRIVAL***
RAN 2.76" CENT, 2.60" DE-CENT, AND 2.69" LIB, FALL SLOW FROM 4200' -
4700'.
RAN 3 1/2" BRUSH, 2.70" G RING; CLEANED AREA FROM 4200' TO 5300'.
TAGGED DEP SLEEVE @ 11,008' MD.
RAN KJ, 2.76" CENT, 2.60" DECENT, 2.69" LIB TO DEP SLEEVE @ 11,009' SLM
(11,008' MD). PICTURE OF F/N, SLIGHTLY TO 4:00.
RAN 20' x 1.56" DMY GUNS (1.72" rings) W/ 1.5" BULLNOSE TO 12,398' SLM.
ABLE TO EASILY ENTER DEP SLEEVE @ 150 FPM; DIFFICULTIES @ SLOWER
SPEEDS.
RAN 10' x 1.56" DMY GUNS (1.72" rings) W/ 1.49" BULLNOSE; NO ISSUES
THROUGH DEP SLEEVE. STALL OUT @ 12,387' SLM.
***WELL LEFT S/I ON DEPARTURE***
5/19/2023
***WELL S/I ON ARRIVAL***
PRESSURE TEST PCE 200#LP-3,000#HP
RIH W/ 1-7/16" CHD (1" FN), 2 X 1-11/16" WB, 1-11/16" GR/CCL, 10' X 1.56"
DUMMY GUN (1.72" MAX OD, 29' OAL)
DRIFT TO 12,372' ELMD
RIH W/ 1-7/16" CHD (1" FN), 2 X 1-11/16" WB, 1-11/16" GR/CCL, 1-11/16" WB,
1.56" PERF GUN (LOADED 6' W/ 3.2 GRAM RAZOR XDP CHARGES)
PERF DEPTH=12,328'-12,334'
job continued 5/20/2023
5/20/2023
job continued from 5/19/2023
PRESSURE TEST PCE 200#LP-3,000#HP
RIH W/ 1-7/16" CHD (1" FN), 2 X 1-11/16" WB, 1-11/16" GR/CCL, 21' X 1.56" PERF
GUN (LOADED 15' W/ 3.2 GRAM RAZOR CHARGES, 40' OAL)
PERF DEPTH=12,289'-12,304'
RIH W/ 1-7/16" CHD (1" FN), 2 X 1-11/16" WB, 1-11/16" GR/CCL, 15' X 1.56" PERF
GUN (LOADED 12' W/ 3.2 GRAM RAZOR CHARGES, 36' OAL)
PERF DEPTH=12,272'-12,284'
RIH W/ 1-7/16" CHD (1" FN), 2 X 1-11/16" WB, 1-11/16" GR/CCL, 21' X 1.56" PERF
GUN (LOADED 19' W/ 3.2 GRAM RAZOR CHARGES, 40' OAL)
PERF DEPTH=12,244'-12,263'
TREE CAP INSTALLED & PRESSURE TESTED
***WELL LEFT S/I***
6/1/2023
T/I/O=SI/1300/100. Tree companion RD. RD 4" CIW temp #84 and installed 4"
tapped blind with chemical jewelry. Torque flange to API spec. Pressure tested blind
against SSV /SV to 500/4250psi. Pass. ***Job Complete*** Final WHP's SI/1300/100.
(
PERF DEPTH=12,272'-12,284'
(
PERF DEPTH=12,244'-12,263'
(
PERF DEPTH=12,289'-12,304'
(
PERF DEPTH=12,328'-12,334'
1500 sx CS III, 350 sx G, 100 sx CS II
x 3-1/2" 9.2# 13Cr80
6612'
By James Brooks at 9:40 am, Apr 06, 2023
Completed
3/5/2023
JSB
RBDMS JSB 040623
GDSR-4/14/23
4.5.2023
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2023.04.05 14:35:52 -08'00'
Monty M
Myers
Activity Date Ops Summary
2/11/2023 Move sub and pit module from 09-09A to 09-43A. Back over well and set modules down. Accept rig at 00:00. Safe out rig. R/U cellar and steam lines. Take on rig
water. Continue working on MIRU checklist
2/12/2023 RU checklists. Safe out cellar. LTT swab/ master to 3500#. Nipple down tree cap. Nipple up BOPE. Nipple up MPD line. Service stack and choke manifold. Fluid
pack rig. PT new MPD line to 250/5000 psi. Pass. Shell test BOP to 250/5000 psi. Pass. Begin Initial BOPE Test. Test 1: IRV, Packoff, C7, C9, C10, C11. Test 2:
Blind/Shears, R2, B2, C15. M/U and Install test joint. Test 3: Annular (3700 psi). Test 4: TIW #1, B1, B4. Test 5: Upper 2" Pipe/Slips, TIW #2, B2, B3. - Test 6:
Lower 2" Pipe/Slips, C5, C6, C8, TV2. Test 7: Choke A, Choke C. Drawdown Test on Accumulator. Record closing times and N2 bottle pressures. Test 8: C1, C4,
TV1. Test 9: 2-3/8" Pipe/Slips, C2, C3. N/D Test Riser. N/U drilling riser. Test Rig H2S and Methane Gas Alarms - Pass. Install BHI Floats. PT PDL's to 3500 psi.
Pass. Thaw frozen lines on rig. Fluid pack coil reel with 10 bbls neat methanol spear. Follow with 140 degree slick 1% KCL w/0.6% safe lube. Shut down pumping
when methanol at nozzle. Open well to a closed choke and record WHP. 0 psi on well. 1 bbl to fill. Flow check well.
2/13/2023 Complete extended flow check. Well static. PJSM, Discuss open hole deployment of BHA. Make up BHA# Cement pilot hole. RIH with BHA #1 Cement pilot hole.
Rate: 1.01 bpm in, 1.33 bpm out. Circ pressure: 637 psi. Mud Weight: 8.44 ppg in, 8.44 ppg out. Log down for tie-in from 10,760' to 10836.24 MD (HRZ) with -9
correction. Rih and tag at 11969' MD. PU and bring pumps up to rate. Mill down. Stalling as soon as we touch down on 11973. On third stall trying to time drill. Bit
stuck. PU to max on HOT. PU to neutral and bring pumps on. PU clean. Pump 10 bbls HiVis Jet on bottom with pill. Chase out of hole. Pump 20 bbls HiVis. Rih
above TD and time mill to get a pattern started. Slight motor work increase at 11973.6'. Stalled and stuck at 11974.64' Free coil. Pump sweep up hole. Send second
sweep. Stage bit off bottom. Jet on bottom. POOH. Continue POOH for mill change. Rate: 2.63 bpm in, 2.38 bpm out. Circ pressure: 3030 psi. - Mud Weight: 8.31
ppg in, 8.41 ppg out. OOH - Flow Check well and confirm no flow. L/D mill and M/U new mill with side cutters. Replace leaking hydraulic hose on injector cart. M/U
injector to well - PT QTS. RIH with BHA #2. Rate: .94 bpm in, 1.25 bpm out. Circ pressure: 730 psi. Mud Weight: 8.31 ppg in, 8.41 ppg out. IA = 47, OA = 0. Log
Tie In from 10760' @ 5 fpm. Correct -8.5'. PUW = 48k, RIW 25k. - Rate: 1.79 bpm in, 1.87 bpm out. Circ pressure: 2122 psi. Mud Weight: 8.31 ppg in, 8.41 ppg
out. Take weight at 11,976' and milled off. Continue milling 2.80" cement pilot hole from 12,000' to 12,035'. Rate: 1.79 bpm in, 1.87 bpm out. Circ pressure: 2122
psi. Mud Weight: 8.31 ppg in, 8.41 ppg out. ROP = 25 - 35 fph, WOB = 1.2 - 1.9k. Mill 2.80" cement pilot hole from 12,035' to 12,095'. PUW = 47k, Pump 5 bbl
high vis sweeps as necessary. Rate: 1.78 bpm in, 1.91 bpm out. Circ pressure: 2373 psi. Mud Weight: 8.31 ppg in, 8.41 ppg out. ROP = 25 - 40 fph, WOB = 1.2 -
1.9k.
2/14/2023 Mill 2.80" cement pilot hole from 12,095' to 12168'. PUW = 48k, Pump 5 bbl high vis sweeps as necessary. Rate: 1.83 bpm in, 1.86 bpm out. Circ pressure: 2356
psi free spin. Mud Weight: 8.32 ppg in, 8.42 ppg out. ROP = 40-60 fph, WOB = 0.8- 1.2k.Stalled and took weight at 12168' MD. Mill 2.80" cement pilot hole from
12,168' to 12226'. PUW = 50k, Pump 5 bbl high vis sweeps as necessary. Rate: 1.83 bpm in, 1.86 bpm out. Circ pressure: 2320 psi free spin . Mud Weight: 8.32
ppg in, 8.43 ppg out, ROP = 30-40 fph, WOB = 0.8- 1.2k. Stalled at 12182' MD. Clean PU. Mill 2.80" cement pilot hole from 12226' to 12238'.PUW = 52k, Pump 5
bbl high vis sweeps as necessary. Rate: 1.89 bpm in, 1.83 bpm out. Circ pressure: 2418 psi free spin. Mud Weight: 8.32 ppg in, 8.43 ppg out. ROP = 30-40 fph,
WOB = 0.8- 1.2k. Pump 10 bbl HiVis. Chase to surface. Open EDC and chase up to tie in depth. Log tie in with -1' correction. Rih and finish pumping bottoms up.
Increase in cement returns of 20%. Sample given to Geologist. 99% cement with trace pipe scale and shavings. Close EDC. Min rate through pilot hole. Mill 2.80"
cement pilot hole from 12238' to 12284'. PUW = 52k, Pump 5 bbl high vis sweeps as necessary. Rate: 1.83 bpm in, 1.86 bpm out. Circ pressure: 2413 psi free
spin. Mud Weight: 8.32 ppg in, 8.43 ppg out. ROP = 20-30 fph, WOB = 0.8- 1.0k. 12,242' Stalled. 12,282-84' Stalled x 4. Mill 2.80" cement pilot hole from 12284' to
12287'. PUW = 52k, Pump 5 bbl high vis sweeps as necessary. Rate: 1.83 bpm in, 1.86 bpm out. Circ pressure: 2503 psi free spin. Mud Weight: 8.32 ppg in, 8.43
ppg out. ROP = 10 fph, WOB = 0.8- 1.0k. Mill 2.80" cement pilot hole from 12287' to 12292'. Rate: 1.83 bpm in, 1.89 bpm out. Circ pressure: 2368 psi free spin .
Mud Weight: 8.33 ppg in, 8.42 ppg out. ROP = 10 fph, WOB = 0.8- 1.0k. Back ream 7-5/8" contact point from 12,100' to 12,060' @ 1 fpm. 45R, 45L, 180, 180. Drift
pilot hole at min rate from 11,950' to TD @ 12,293'. Clean drift. Pump 23 bbl high vis sweep off bottom. Rate: 1.72 bpm in, 1.72 bpm out. Circ pressure: 3229. Mud
Weight: 8.33 ppg in, 8.43 ppg out. POOH from 12,294'. Open EDC at 11,950' and POOH pumping max rate. Rate: 2.43 bpm in, 2.36 bpm out. Circ pressure: 3229.
Mud Weight: 8.33 ppg in, 8.43 ppg out. Reverse jog at surface. OOH - Flow check and confirm no flow. L/D BHA #2 Mill gauged 2.80" GO, 2.79" NOGO. M/U BHA
#3 w/2.75" whipstock drift and READ 24 finger caliper. Confirm caliper arms function at surface. RIH. Caliper arms programmed to open in 4.5 hrs (08:34). RIH with
BHA #3 - Drift and caliper. Rate: .60 bpm in, .85 bpm out. Circ pressure: 546. Mud Weight: 8.32 ppg in, 8.43 ppg out. IA = 131, OA = 0.
2/15/2023 RIH with BHA #3 - Drift and caliper. Rate: .58 bpm in, .92 bpm out. Circ pressure: 555. Mud Weight: 8.33 ppg in, 8.44 ppg out. IA = 140, OA = 0. Wait on caliper
arms to open at 12,287'. Log up from 12,287' to 10,800' at 50 fpm per READ logging specialist. Rate: .43 bpm in, .24 bpm out. Circ pressure: 413. Mud Weight:
8.33 ppg in, 8.44 ppg out. Stop coil and wait for caliper arms to collapse. POOH from 10,800'. Rate: .58 bpm in, .29 bpm out. Circ pressure: 476. Mud Weight: 8.34
ppg in, 8.43 ppg out. OOH, flow check well. Good no flow, pull & LD BHA. Verify good data, good data, call out BOT to MU and run WS while processing data for
WS set. MU the WS BHA. BHA MU, RIH with open EDC. 10,790' Log tie in, correct depth -13'. RIH and drift WS to TD @ 12,293'. PUH to logging depth. Log CCL
and GR from 11,900' to 12,290' @ 15 fpm. Confirm setting depth with town team. Close EDC and pressure up to 3400 psi. Set top of whipstock at 12,262'. Slack off
6.5k and confirm good set. POOH. POOH from 12,272.5'. Rate: 1.24 bpm in, .92 bpm out. Circ pressure: 1095. Mud Weight: 8.34 ppg in, 8.45 ppg out. OOH - flow
check well and confirm no flow. Inspect last 30' of coil and L/D BHA #4. M/U swizzle stick and jet stack and return lines. M/U BHA #5 - Window Milling BHA. RIH
with BHA #5. Rate: 1.15 bpm in, .92 bpm out. Circ pressure: 1103. Mud Weight: 8.35 ppg in, 8.44 ppg out. IA = 81, OA = 0. Log tie in from 10,850' @ 5 fpm.
Correct -13'. Close EDC and RIH to begin window milling.
50-029-22078-01-00API #:
Well Name:
Field:
County/State:
PBE 09-43A
Prudhoe Bay East
Hilcorp Energy Company Composite Report
, Alaska
2/16/2023Spud Date:
2/16/2023 Begin milling window at 12,263.0', establish a lip then apply max WOB for the first 1'. In Rate = 1.83, Out Rate = 1.80. Mud weight in = 8.35, Out = 8.45. IA = 57,
OA = 0. Circ pressure = 2455 psi. 3 stalls before we were able to establish a starting point for a lip. Lip established start working up to max WOB for the first
1'. CSG appears to be soft, WOB at 1.5k no movement on TF, stop moving and WOB drills off, BOT hand wants to slow down a little to keep from popping out to
soon. Milled 1' in 30 minutes, WOB is not drilling off as fast, WOB at 1.83k, start 1 FPH time milling at 12,264.0'. Milling window at 12,265.0'. In Rate = 1.80, Out
Rate = 1.81. Mud weight in = 8.33, Out = 8.44. IA = 184, OA = 0. Circ pressure = 2651 psi, WOB = 2.01k. Milling window at 12,267.0'. In Rate = 1.80, Out Rate =
1.83. Mud weight in = 8.33, Out = 8.45. IA = 246, OA = 0. Circ pressure = 2542 psi, WOB = 1.65k. 12270.0' Window mill should be at the bottom of the window,
continue, milling at 1 FPH to dress the bottom of the window with the string mill. In Rate = 1.81, Out Rate = 1.84. Mud weight in = 8.33, Out = 8.44. IA = 296, OA =
0. Circ pressure = 2661 psi, WOB = 0.5k. 12270.85' WOB dropped off, string mill should be out, start milling Rat Hole. In Rate = 1.82, Out Rate = 1.82. Mud weight
in = 8.34, Out = 8.45. IA = 337, OA = 0. Circ pressure = 2851 psi, WOB = 0.02k. Mill to 12,280' bottom of rat hole. Begin back reaming passes. In Rate = 1.85, Out
Rate = 1.88. Mud weight in = 8.34, Out = 8.45. IA = 371, OA = 0. Circ pressure = 2920 psi, WOB = 1.3k. Complete back reaming passes. Confirm 10% formation
sand in bottoms up sample. Dry drift window and rat hole clean. Pump high vis sweep from TD. POOH from 12,280' pumping min rate through cement pilot hole.
Open EDC at 11,938'. POOH from 11,938' pumping max rate. In Rate = 1.85, Out Rate = 1.88. Mud weight in = 8.34, Out = 8.45. OOH - Flow check well and
confirm no flow. Inspect last 30' of coil. L/D BHA#5. Mill and reamer gauged 2.81" GO, 2.80" NOGO. M/U swizzle stick and jet stack and surface lines. M/U and RIH
with BHA #6 - Build BHA. In Rate = .32 bpm, Out Rate = .76 bpm. Mud weight in = 8.30 ppg, Out = 8.45 ppg. IA = 91 psi, OA = 0. Log tie in from 10795' @ 5 fpm.
Correct -13'. Begin displacing to new PowerPro mud system. In Rate = 1.04 bpm, Out Rate = .99 bpm. Mud weight in = 8.54 ppg, Out = 8.44 ppg. IA = 121 psi, OA
= 0. Close EDC and RIH through cmt pilot hole and window. Drill build section from 12,280' to 12,285'. In Rate = 1.75 bpm, Out Rate = 1.80 bpm. Mud weight in =
8.60 ppg, Out = 8.45 ppg.
2/17/2023 On bottom drilling at 12285' ROP is a little slow, Geo's said we are kicking off in a shale. In Rate = 1.82 bpm, Out Rate = 1.82 bpm. MWT In = 8.62 ppg, Out MWT
= 8.45 ppg (swapping well over to mud). ROP = 5 FPH, ECD = 9.15 ECD. IAP = 190 psi, OAP = 0 psi. Drilled to 12390', started losing ~0.2 bpm and ROP dropped
from 40 fph to <10 FPH. In Rate = 1.79 bpm, Out Rate = 1.60 bpm. MWT In = 8.58 ppg, Out MWT = 8.69 ppg. ROP = 8 FPH, ECD = 9.40 ECD. IAP = 391 psi,
OAP = 0 psi. Pump Low & High Vis Pills as needed. Build landed at 12502', POOH on MPD maintaining 9.8 ECD at the window. Jog in at the window, PU to 12300
(circ ports above the window and open the EDC. Wash across the WS tray and POOH at max rate. PUD BHA #6 - bit graded 2-1. Pressure deploy BHA #7 -
Lateral. RIH with BHA #7 In Rate = .55 bpm, Out Rate = .81 bpm. MWT In = 8.61 ppg, Out MWT = 8.73 ppg. IA = 126, OA = 0, Circ pressure = 1202. Log tie in and
correct -13'. Close EDC and RIH through pilot hole and window. Drill lateral from 12,502' to 12,684' pumping sweeps as necessary. In Rate = 1.72 bpm, Out Rate =
1.67 bpm. Mud WT In = 8.61 ppg, Out = 8.72 ppg. Circ pressure = 3534 psi. Pump Lo/High Vis sweep @ 12,684' and free coil. Drill from 12,684' to 12,753'. Wiper
trip to window and resume drilling. In Rate = 1.82 bpm, Out Rate = 1.69 bpm. Mud WT In = 8.61 ppg, Out = 8.77 ppg. ROP 40 - 90 fph, WOB .7 - 2.4k.
2/18/2023 Drilling lateral section at 12765'. In Rate = 1.79 bpm, Out Rate = 1.76 bpm. MWT In = 8.63 ppg, Out MWT = 8.78 ppg. ROP = 73 FPH, ECD = 9.72 ECD. IAP =
549 psi, OAP = 0 psi. Pump Low & High Vis Pills as needed. Drilled 450', wiper trip to window chasing pills. Jog below the window, pull EDC above the window,
open the EDC and wash the WS tray. POOH to the TOC, chasing pills at max rate. Log tie in at 10,790', correct depth +8.5' and RIH. Back on bottom drilling. In
Rate = 1.81 bpm, Out Rate = 1.80 bpm. MWT In = 8.64 ppg, Out MWT = 8.76 ppg. ROP = 60 FPH, ECD = 9.71 ECD. IAP = 647 psi, OAP = 0 psi. On bottom
drilling at 13,200' to 13,303'. In Rate = 1.82 bpm, Out Rate = 1.81 bpm. MWT In = 8.65 ppg, Out MWT = 8.81 ppg. ROP = 80 FPH, ECD = 9.91 ECD. IAP = 665
psi, OAP = 0 psi. Long wiper trip to window and clean 5 1/2" scab liner. In Rate = 1.82 bpm, Out Rate = 1.65 bpm. MWT In = 8.68 ppg, Out MWT = 8.79 ppg. Jog
below window at full rate. Open EDC above window and pump full rate. Jet WS tray and POOH through pilot hole. RIH from 6600' at 80 fpm pumping max rate
through open EDC. In Rate = 2.64 bpm, Out Rate = 2.91 bpm. MWT In = 8.65 ppg, Out MWT = 8.81 ppg. Log tie in from 10,795' @ 5 fpm. Correct +5'. Close EDC
above window and RIH min rate through window. Drill 3.25" lateral from 13,303' to 13,385'. In Rate = 1.81 bpm, Out Rate = 1.80 bpm. MWT In = 8.64 ppg, Out
MWT = 8.76 ppg. ROP = 20 - 40 FPH, ECD = 9.87 ECD. IAP = 783 psi, OAP = 0 psi.
2/19/2023 On bottom drilling at 13420'. In Rate = 1.79 bpm, Out Rate = 1.80 bpm. MWT In = 8.65 ppg, Out MWT = 8.81 ppg. ROP = 90 FPH, ECD = 9.83 ECD. IAP = 774
psi, OAP = 0 psi. Drilling ahead at 13600'. In Rate = 1.81 bpm, Out Rate = 1.83 bpm. MWT In = 8.67 ppg, Out MWT = 8.82 ppg. ROP = 80 FPH, ECD = 9.85 ECD.
IAP = 753 psi, OAP = 0 psi. Surface weight has deteriorated from 18k down to 5k drilling in 100+ api dirty sand. Add 1% lube 776 to Low and high vis pills and
pump to see if surface weight improves. Surface weight went from 5k to 14k as pill was pumped out and around the BHA but no change to WOB or ROP, just
surface weight. Continue drilling 'to 13750' for our next long wiper then plan on swapping to new mud to drill to TD and for the liner run. Drilled 450' to 13,750', pull
wiper to the window then TT to clean 5-1/2 to the TT. Pump max rate to 6600'. RIH at full rate. Log tie in from 10795' @ 5 fpm. Correct +4' RIH. PUW before pilot
hole 45k. RIH from 11,882' through cement pilot hole. Close EDC and RIH through window. RIH to TD. Drill 3.25" lateral from 13,746' while swapping to new 8.6
ppg Power Vis system. In Rate = 1.75 bpm, Out Rate = 1.76 bpm. MWT In = 8.60 ppg, Out MWT = 8.84 ppg. ROP = 20 - 60 FPH, ECD = 9.71 ECD. IAP = 530 psi,
OAP = 0 psi. Drill 3.25" lateral from 14,006' to 14,018'. In Rate = 1.75 bpm, Out Rate = 1.78 bpm. MWT In = 8.63 ppg, Out MWT = 8.77 ppg. ROP = 20 - 60 FPH,
ECD = 9.82 ECD. IAP = 591 psi, OAP = 0 psi.
2/20/2023 Drilling lateral section at 14,020' struggling to keep WOB. In Rate = 1.78 bpm, Out Rate = 1.79 bpm. MWT In = 8.62 ppg, Out MWT = 8.78 ppg. ROP = 20 FPH,
ECD = 9.77 ECD. IAP = 614 psi, OAP = 0 psi. Pump Low & High Vis Pills as needed. 14,055', still struggling to keep WOB and have to PU every 3-5', add 0.5% of
Lube776 to mud system and see if it improves weight transfer. 0.5% lube776 started working as it came around the BHA and we are able to drill without having to
PU. Drilling lateral section at 14,160'. In Rate = 1.77 bpm, Out Rate = 1.78 bpm. MWT In = 8.63 ppg, Out MWT = 8.78 ppg. ROP = 35 FPH, ECD = 9.78 ECD. IAP
= 621 psi, OAP = 0 psi. 14,255' Differentially stuck on bottom, work pipe with no WOB change (diff stuck on coil) shut down pumps, pull to max WT and pulled free.
Online with pumps circulating LHV Pills and continue PUH to verify we are pulling clean. RIH to continue drilling and Geo's called TD, start wiper to window. At the
window, jog in hole, PUH with EDC above the WS, open EDC and jet WS tray then POOH to TOC chasing pills. In Rate = 2.61 bpm, Out Rate = 2.34 bpm. MWT In
= 8.61 ppg, Out MWT = 8.75 ppg. Jog in hole 500' at surface to clear BHA. Function test BOP's. 2" pipe/slips. 2" pipe/slips. 2 3/8" pipe slips. Will complete testing
of annular, blind/shears and on next trip out of hole. Tag up and space out. RIH with BHA #7 to confirm TD. Log tie in from 10795' @ 5 fpm. Correct - 13'. Close
EDC and RIH through window and build section. RIH to confirm TD - pumping sweeps. Clean trip with only minor bobbles. In Rate = 1.42 bpm, Out Rate = 1.49
bpm. MWT In = 8.63 ppg, Out MWT = 8.75 ppg. Tag corrected TD at 14,264'. Pump 40 bbls liner running pill with Alpine Drilling Beads. Lay in from TD to heel of
well at 12,500'. In Rate = .72 bpm, Out Rate = .58 bpm. MWT In = 9.70 ppg, Out MWT = 8.76 ppg. Circulate 9.8 ppg NaBr from 12,500' to surface. In Rate = 2.20
bpm, Out Rate = 2.23 bpm. MWT In = 9.73 ppg, Out MWT = 8.78 ppg. Confirm 9.8 ppg KWF at surface. Flow check well and confirm no flow. POOH and paint
EOP flags for TD and Window.
2/21/2023 Continue POOH at 9555' to PU liner. Flow check above the window 3 bph loss rate. 60' from surface, online with pumps to test agitator, 1.5 bpm & 1.85 bpm good
tests. Shut down pumps and flow check well. Lost 1 bbl on the TOOH. Good no flow, PU injector and LD the BHA. Complete Function test with Blind Shear and
Annular function. Prep rig floor to MU liner. MU and run 2-3/8" Liner with ORCA Valve filling liner every 10 jts. Perform KWT Drill with Enfield's Crew, Safety Joint
MU, deployed and well secured in 2:20. All hands reported in from their stations in 3:05. No deficiencies to report. Continue running liner on jt 92 of 102. Complete
running 102 joints of 2 3/8" L-80 solid liner. M/U NS 2.70" Deployment sleeve. M/U Injector and test QTS. RIH with 2 3/8" L-80 solid liner and 2.70" deployment
sleeve. In Rate = .50 bpm, Out Rate = .63 bpm. In MM = 9.84 ppg, Out MM = 9.85 ppg. WT CK 48k above cmt pilot hole @ 11,900'. RIH through pilot hole and
window. Correct - 20.3' at window flag. Circulate 9.8 ppg KWF out of well. 8.6 ppg mud back to surface. RIH with liner from 12,665'. Work down from 13,740' to
14,261' and set 6k down. 55k PUW. Repeat and confirm TD. Circulate 1 bpm through liner @ 3260 psi and confirm circulation. Pump off liner with 40k. Correct
BHA length to BHI. Log GR tie in. Log GR tie in from 10,770' @ 5 fpm. Correct +8'. Tag TOL @ 11,010' with 4k down. Flow check well and confirm no flow. 2 bbl
per hour loss rate. POOH. POOH from 11,000'. In Rate = 1.06 bpm, Out Rate = .71 bpm. In Mud WT = 8.76 ppg, Out Mud WT = 8.91 ppg. OOH - Flow check well
and confirm no flow. Inspect last 50' of coil. L/D liner running tool. Prep to pump eline slack out of reel.
2/22/2023 RU & pump slack out. Pumped out 189' of 251' out. Prep to pump 5/8" disconnect drift ball through coil. Load and pump 5/8" drift ball. Pumped 48 bbls PU injector
and check fort ball, ball on seat, LD nozzle BHA and RU to run 1" work string. MU the NS ORCA Snap Latch BHA w/1" CSH. Joints 1-89 have been clean, joint 90
won't pass the drift. Brush and vac out the remaining 18 joints and run. RU head pin and circ CSH work string to verify scale won't plug off the work string then MU
upper BHA. BHA MU, MU injector to the BHA. RIH with the CMT BHA pump min rate. Up wt at liner top is 37k, RIH wt 19k. 1.5 bpm = 4200 psi. RIH slowly through
liner top, nothing seen. Continue RIH past 12000' to verify inside liner. Stop at flag from previous run, correct -20'. RIH wt ck at 14140' is 46k up 21k down. Pump 1
bpm = 2700 psi. 1.5 bpm = 4900 psi. Open pump bleeders and RIH 0 pump to engage Snap Latch into ORCA cmt valve. Start taking wt at 14240' continue RIH set
7k down. Pressure up to 3600 psi shear pressure drops to 3100 psi. Pump 1 bpm circ pressure now 3200 psi. Circ well to 1 % KCl 1.2 / 1.2 bpm 3400 psi keep 7-
8k down wt. Rig up HES cmt van. KCl back, shuffle trucks to spot vacs for cmt job. Send 2 trucks of mud back to MI for storage. PJSM with HES and Nabors crew
for pumping cement. Pump 31.3 bbls cmt into reel, shut down and clear lines. Displace cement with rig. Circ pressure coming up near the end of the displacement
bypass In MM go to 0.3 bpm / 5500 psi. With 3.5 bbls left in CT Unable to move fluid, unsting from ORCA. Pump remaining cement out of 1" CSH POOH to string it
out and contaminate. RIH and circ excess cement out. Total of 26.4 bbls behind pipe.
2/23/2023 POOH to 11,100' circulating CMT to surface. Out density increased to 8.75 ppg for ~30 bbls then dropped back down. Bottoms up is clean, shut down pump to flow
check well then POOH jetting across the jewelry. OOH, flow check well, good no flow. Remove the injector and LD the CMT BHA. BHA OOH, it looks like the rupture
disk did not shear all the way and was causing the high circ pressures. Hold a PJSM with LRS to pump diesel into the coil for FP. MU Nozzle BHA, jet BOPE then
RIH to 2500' TVD while LRS loads the coil with diesel. At 2800', let 3 bbls out then POOH 1:1. 45 bbls diesel pumped into coil swap to 10 bbls of 60/40 Meth Water.
Tag up, Leave MeOH across stack. RDMO LRS, MIRU N2 unit. Pump inhibitor and MeOH into reel while cooling N2 and PT lines. Purge reel with 1500 scfm until
N2 at the nozzle. Bleed off N2 pressure. Service tree valves. LO/TO on injector and reel, remove reel iron and bulkhead. Remove pump in sub. Pin counter wheel
back for unstab. Install grapple and pull test. Pull CT out of injector, secure it at shipping reel. Install lift slings on reel. Remove reel bay door, spot truck.
2/24/2023 Install nozzle, M/U injector to well. Pump reel volume forward at 3 bpm. Purge surface lines and reel w/ air. Vac out stack down to MV. Hook up MeOH to wing and
fill stack. Leak tight test on MV, SV, good. Remove BOPs. RDMO 06:00.
With 3.5 bbls left in CT Unable to move fluid, unsting from ORCA Pump remaining cement out of 1" CSH POOH to string it
out and contaminate. RIH and circ excess cement out. Total of 26.4 bbls behind pipe
ACTIVITYDATE SUMMARY
2/24/2023 Weather Standby
2/27/2023
T/I/O=0/0/0. Post CDR2. Removed managed pressure line and install 4" tapped blind
with chemical jewelry. Removed 7x4 x-over from swab and install 4" tree cap
assembly. Torque flanges to API spec. Pressure test upper tree against SSV to
300/5000 psi. Pass. Replace 8" 1500 production lateral valve and connect production
and AL piping, set wellhouse and floor kit. ***Job Complete*** Final WHP's 0/0/0.
2/28/2023
Flowline Freeze Protect Pre SL Pumped 95 BBLS crude, Pumped 10 BBLS NEAT
meth to FP the FL
2/28/2023
****WELL S/I ON ARRIVAL**** (perforating)
PULL BK-DGLV AT STA# 1 (6,424' md) & STA# 2 (3,789' md)
***CONTINUE ON 3/1/23 WSR***
3/1/2023
***CONTINUED FROM 2/28/23 WSR*** (perforating)
SET BK-LGLV AT STA# 2 (3,789' md) & BK-OGLV AT STA# 1 (6,424' md)
PULL 4-1/2" WHIDDON AT 6,517' MD (empty)
***WELL S/I ON DEPARTURE***
3/1/2023
** MIT T** T/I/O= 327/278/0 Pumped 2.9 bbls diesel down TBG to get to test
pressure of 1523 psi. T lost 34 psi. in 1st 15 min and 7 psi. in 2nd 15 min. Bled back
to starting pressures. FWHP's= 327/275/0 Hung tag on MV. SV SSV WV closed MV
open CV's OTG's. DSO notified of well status upon departure.
3/2/2023
LRS CTU #2 - 1.50" Coil
Job Objective: CBL, Initial AddPerf
MIRU CTU.
...Continued on WSR 3-3-23...
3/3/2023
LRS CTU #2 -- 1.50" Blue Coil
Job Objective: CBL, Initial AddPerf
Rig up CTU. MU & RIH w/ 1.75" Drift BHA with Bowspring Centalizer on Bottom. Tag
Dep Slv at 11026' ctm 3 times. Circulate down Coil at 0.9bpm and drift thru clean.
Continue drifting thru liner. Tag PBTD at 14258'. Flag Pipe 50' from weight back.
Circulate wellbore to Slick Seawater w/ Safelube while pooh. Attempt to drift into Dep
Slv w/o pumping with no success. Pooh while circulating wellbore to SW. Freeze
Protect Coil to Meth & lay in FP in Tbg. MU & RIH w/ HES RBT Bond Logging Tools.
Tag up on Stripper. RIH but unable to enter liner top. POOH and lay down tools,
secure well and standby for low temps.
...Continued on WSR 3-4-23....
3/4/2023
LRS CTU #2 - 1.50" Blue Coil ***Cont. from WSR 3-3-23***
Job Objective: CBL, Inital Perforations
Weather standby due to low temps. Come off Weather Hold at 1:30pm. MU & RIH
w/ HES Centralized RBT Logging Tools w/ SL Knuckle Joint, 3 Stingers & 1.75"
Nozzle on the bottom to lay on low side to get inside Dep Slv. RIH and enter liner top.
Log from TD to 10700', painting green tie-in flag at 12,400'. POOH and lay down
tools.
...Continued on 3-5-23....
Daily Report of Well Operations
PBU 09-43A
Daily Report of Well Operations
PBU 09-43A
3/5/2023
LRS CTU #2 - 1.50" Blue Coil ***Cont. from WSR 3-4-23***
Job Objective: CBL, Initial Perforations
Confirm good data from log, -29.5' correction. Corrected PBTD of 14252'. Make up
straight drift BHA with 1.75" JSN. RIH and drift cleanly through deployment sleeve.
POOH. At surface, perform good no flow test. Begin circulating 60/40 meth from
Trip Tank. POP off well. Break down drift BHA. Install Swivel & PT MHA to 3500psi.
Trolly in & Raise the T-Bar to make room for Boom Truck Crane. Perform Drill w/
Crew & TIW/Safety Joint make up. Deploy 1.56" Perf guns while circulating KWF
across the Top. MU MHA/Swivel to Firing Head. Stab on & Test QTS. RIH w/ 1.56"
x 409' of Geo Razor Perf Guns. Correct depth to Top Shot at Flag. Perforate
Interval: 12462' - 12871'. Pooh keeping the hole full. Confirm well is dead - Good No
Flow Test. Undeploy Perf Guns while circulating KWF across the Top. All shots
fired. Ball Recovered. Tbg is Freeze Protected w/ 47 bbls 60/40 Methanol. Rig
Down CTU.
***Job Complete / Turnover to Ops to POP***
WELL NAME
Date :
Shoe @ :FC @ :Top Liner @ :
Type:
Type :
Type :
Type :
Type :
Yes No
Yes X No Yes X No
X Yes No X Yes No
Date :
Volume lost during displacement (bbls) :
Density (ppg) : 8.4 Volume pumped (bbls) :
09-43A CEMENT REPORT
23-Feb-23 Hole Size :3.25"Casing Size :2.375"
Lead Slurry
Density (ppg) :
Tail Slurry
Volume (bbls) : Density (ppg) :
Yield : Sacks : Mixing / Pumping Rate (bpm) :
Post Flush (Spacer)
1.5 ppb Geovis Density (ppg) : 8.4 Rate (bpm) :
Bump press :
Volume : 183
Displacement :
1.5 ppb Geovis Density (ppg) : 8.4 Rate (bpm) : 0.9 Volume (actual / calculated) :
0.9
Method Used To Determine TOC : Calculated
Casing Rotated? Reciprocated? % Returns during job : 84%
Cement returns to surface? Spacer returns? Vol to Sur :
FCP (psi) : Pump used for disp : GD Plug Bumped?
Cement In Place At : 04:30 2/23/2023 Estimated TOC : 11053'
4.90
Remarks: ORCA Valve (Cement Retainer) @ 14264' - Closed
FI
R
S
T
S
T
A
G
E
14264' 14252', 14263' 11008'
Preflush (Spacer)
1% KCL w/ safelube
Class G Volume (bbls): 31.3 15.3
Yield : 1.24 Sacks : 142 Mixing / Pumping Rate (bpm) : 0.9
11053'
84%
Calculated
7. If perforating:
1. Type of Request:
2. Operator Name:
3. Address:
4. Current Well Class:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Property Designation (Lease Number):10. Field:
Abandon
Suspend
Plug for Redrill Perforate New Pool
Perforate
Plug Perforations
Re-enter Susp Well
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well
Other:
Change Approved Program
Operations shutdown
What Regulation or Conservation Order governs well spacing in thes pool?
Will planned perforations require a spacing exception?Yes No
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
PRESENT WELL CONDITION SUMMARY
Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft):
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
12. Attachments:
14. Estimated Date for
Commencing Operations:
13. Well Class after proposed work:
15. Well Status after proposed work:
16. Verbal Approval:
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal.
Proposal Summary Wellbore schematic
BOP SketchDetailed Operations Program
OIL
GAS
WINJ
WAG
GINJ
WDSPL
GSTOR
Op Shutdown
Suspended
SPLUG
Abandoned
ServiceDevelopmentStrastigraphicExploratory
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
AOGCC USE ONLY
Commission Representative:
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Location ClearanceMechanical Integrity TestBOP TestPlug Integrity
Other:
Post Initial Injection MIT Req'd?
Spacing Exception Required?Yes
Yes No
No Subsequent Form Required:
Approved By:Date:
APPROVED BY
THE AOGCCCOMMISSIONER
PBU 09-43A
Extended Perforating
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK
99503
222-156
50-029-22078-01-00
ADL 028327, 028324 , 028343
14264
Conductor
Surface
Scab Liner
Production
Liner
8839
80
4250
5551
12519
3268
14240
20"
10-3/4"
5-1/2"
7-5/8"
2-3/8"
8842
33 - 113
32 - 4282
6528 - 12079
30 - 12264
11008 - 14264
2461
33 - 113
32 - 3508
4988 - 8674
30 - 8804
7949 - 8839
none
470
2090
6280
4790
11780
None
1490
3580
7740
6890
11200
12462 -12871 4-1/2" 12.6# x 3-1/2" 9.2# 13Cr80 28 - 66128889 - 8885
Structural
4-1/2" Baker S-3 Perm
No SSSV
6513 / 4978
No SSSV Installed
Date:
Bo York
Operations Manager
Tyson Shriver
Tyson.Shriver@hilcorp.com
907-564-4545
PRUDHOE BAY
03/17/2023
Current Pools:
PRUDHOE OIL
Proposed Pools:
PRUDHOE OIL
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng
Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Samantha Carlisle at 7:18 am, Mar 13, 2023
323-150
Digitally signed by Bo York (1248)
DN: cn=Bo York (1248), ou=Users
Date: 2023.03.10 16:41:51 -09'00'
MGR15MAR23 DSR-3/14/23
CO 341J
X 10-404
MDG 3/13/2023
RBDMS JSB 032123
Well: 09-43A
PTD: 222-156
API: 50-029-22078-01-00
Well Name:09-43A API Number:50-029-22078-01-00
Current Status:Shut in Rig:Coil
Estimated Start Date:Mar 2023 Estimated Duration:3 days
Regulatory Contact:Carrie Janowski Revision:1
First Call Engineer:Tyson Shriver (907) 564-4542 (O)(406) 690-6385 (M)
Second Call Engineer:Dave Bjork (907) 564-4672 (O)(907) 440-0331 (M)
Current Bottom Hole Pressure:3,165 psi @ 8,760’ TVD 7.0 PPGE | Taken 1/1/2023
Maximum Expected BHP:3,350 psi @ 8,800’ TVD 7.4 PPGE | Average Ivishak BHP
Max. Anticipated Surface Pressure:2,470psi Based on 0.1 psi/ft. gas gradient
Last SI WHP: 200psi Taken on 1/2/2023
Min ID:1.995” ID ID of 2-3/8” liner
Max Angle:91 Deg @ 12,925’md taken from well plan
Tie In Log:LWD from drilling 09-43A sidetrack
Brief Well Summary:
09-43A is planned to be a horizontal Zone 1 producer from the Ivishak formation. The rig is expected to be
moving off the well March 6, 2023, at which time service coil will move in and perform an extended add perf
operation.409’ of initial perforations were shot by coiled tubing on 3/5. Operations attempted to POP the 3/6
without success. Slickline intervened and set multiple downhole shear discs in an attempt to clean up the
perforations and promote flow from the reservoir. These efforts were also unsuccessful. Plan forward is to have
coil shoot the remainder of the net pay to gain additional access to the Zone 1 reservoir.
Objectives:
The objective of this procedure is to shoot Extended Addperfs for the initial perforations post sidetrack.The
objective of this procedure is to shoot additional extended add perfs to increase the amount of reservoir open
to flow and perform an N2 lift to help kick the well off.
Procedure:
Coiled Tubing (Executed 3/1 – 3/5)
Notes:
Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS
coverage is required.
The well will be killed and monitored before making up the initial perfs guns. This is generally done
during the drift/logging run. This will provide guidance as to whether the well will be killed by
bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after
perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the
same port that opened to shear the firing head.
1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through
the brass upon POOH with guns.
2. MU and RIH with drift nozzle to TD.
3. MU and RIH with GR/CCL/CBL and drift nozzle and log from TD toabove top of 2-3/8” liner (~10,800’).
4. Flag pipe as appropriate per WSS for addperf runs.
5. Well should be a closed system. Ensure well is dead before POOH, and circulate a kill with 8.4ppg
1% KCl as necessary. Max tubing pressure 2500 psi. (This step can be performed any time prior to
open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.)
a. Wellbore volume to estimated PBTD of 12,365’ = 215 bbls
Well: 09-43A
PTD: 222-156
API: 50-029-22078-01-00
b. 4-1/2” Tubing – (6,517’ – surface) X 0.0152bpf = 99 bbl
c. 3-1/2” Tubing - (6,612’ – 6,517’) X 0.0087 bpf = 1 bbl
d. 5-1/2” Scab - (11,000’ – 6,612’) x 0.0232 bpf = 102 bbl
e. 2-3/8” Liner – (14,276’ – 11,000’) X 0.0039bpf = 13 bbl
6. POOH pumping pipe displacement and freeze protect tubing as needed.
7. Confirm good log data.
8. At surface, prepare for deployment of TCP guns.
9. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5
ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established.
Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed
and there is no excess flow.
10. *Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well
control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun
string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve
readily accessible near the working platform for quick deployment if necessary.
f. At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns
one time to confirm the threads are compatible.
11.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly
monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed
while deploying perf guns to ensure the well remains killed and there is no excess flow.
Perf Schedule
*Planned for 1.56” Halliburton Perfecta charges, max swell 1.74”, 3.62#/ft loaded weight.
Perf Interval Perf Length
Gun
Length Weight of Gun (lbs)
Comments
Run 1 12,462’ – 12,871’ 409’ 409’1,481 lbs (3.62ppf)
Final lengths TBD after
analyzing open hole and
cement log data. BHAs
will be limited to 500’ for
any individual run.Total 409’ 409’
12. RIH with perf gun and tie-in to coil flag correlation. Pick up and perforate interval per Perf Schedule
above.
g. Note any tubing pressure change in WSR.
13. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and
stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface.
14. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary.
15. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and
commencing breakdown of TCP gun string.
16. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA.
17. Repeat steps 8 through 16 for subsequent runs to complete the desired perforated footage.
18. RDMO CTU.
19. RTP or FP well.
Well: 09-43A
PTD: 222-156
API: 50-029-22078-01-00
Coiled Tubing
Notes:
Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS
coverage is required.
The well will be killed and monitored before making up the initial perfs guns. This is generally done
during the drift/logging run. This will provide guidance as to whether the well will be killed by
bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after
perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the
same port that opened to shear the firing head.
1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through
the brass upon POOH with guns.
2. At WSS discretion, MU and RIH with drift nozzle to TD.
3. MU and RIH with GR/CCL and drift nozzle and log from TD to above top of 2-3/8” liner (~10,800’).
4. Flag pipe as appropriate per WSS for addperf runs.
5. Ensure well is dead before POOH, and circulate a kill with 8.4ppg 1% KCl as necessary. Max tubing
pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf
guns. Timing of the well kill is at the discretion of the WSS.)
a. Wellbore volume to estimated PBTD of 14,240 = 215 bbls
b. 4-1/2” Tubing – (6,517’ – surface) X 0.0152bpf = 99 bbl
c. 3-1/2” Tubing - (6,612’ – 6,517’) X 0.0087 bpf = 1 bbl
d. 5-1/2” Scab - (11,008’ – 6,612’) x 0.0232 bpf = 102 bbl
e. 2-3/8” Liner – (14,240’ – 11,008’) X 0.0039bpf = 13 bbl
6. POOH pumping pipe displacement and freeze protect tubing as needed.
7. Confirm good log data.
8. At surface, prepare for deployment of TCP guns.
9. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5
ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established.
Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed
and there is no excess flow.
10. Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well
control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun
string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve
readily accessible near the working platform for quick deployment if necessary.
f. At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns
one time to confirm the threads are compatible.
11.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly
monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed
while deploying perf guns to ensure the well remains killed and there is no excess flow.
Well: 09-43A
PTD: 222-156
API: 50-029-22078-01-00
Perf Schedule
*Planned for 1.56” Halliburton Perfecta charges, max swell 1.74”, 3.62#/ft loaded weight.
Perf Interval Perf Length Gun Length
Weight of Gun
(lbs)
Comments
Run 1 13,728’ – 14,000’ 272’ 272’
985 lbs
(3.62ppf)
BHAs will be limited to
500’ for any individual run.
Run 2 13,107’ – 13,287’
Blank
13,387’ – 13,582’
375’375’ guns
100’ blank
1,720 lbs
(3.62ppf)
Total 647’ 747’
12. MU lubricator connection at QTS.
13. RIH with perf gun and tie-in to coil flag correlation. Pick up and perforate interval per Perf Schedule
above.
g. Note any tubing pressure change in WSR.
14. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and
stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface.
15. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary.
16. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and
commencing breakdown of TCP gun string.
17. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA.
18. Repeat steps 8 through 16 for subsequent runs to complete the desired perforated footage.
19. RIH with nozzle BHA to just above TOL and perform N2 lift.
20. RDMO CTU.
21. RTP or FP well.
Attachments:
1. Current Wellbore Schematic
2. Proposed Schematic
3. Coil Tubing BOPE Schematic
4. Standing Orders for Open Hole Well Control during Perf Gun Deployment
5. Equipment Layout Diagram
6. Sundry Change Form
Well: 09-43A
PTD: 222-156
API: 50-029-22078-01-00
Current Wellbore Schematic
Well: 09-43A
PTD: 222-156
API: 50-029-22078-01-00
Proposed Wellbore Schematic
Well: 09-43A
PTD: 222-156
API: 50-029-22078-01-00
Coiled Tubing BOPs
Standing Orders for Open Hole Well Control during Perf Gun Deployment
Well: 09-43A
PTD: 222-156
API: 50-029-22078-01-00
Well: 09-43A
PTD: 222-156
API: 50-029-22078-01-00
Equipment Layout Diagram
Well: 09-43A
PTD: 222-156
API: 50-029-22078-01-00
Sundry Change Form
Changes to Approved Sundry Procedure
Date:
Subject:
Sundry #:
Any modifications to an approved sundry will be documented and approved below. Changes to an approved
sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change
is required before implementing the change.
Step Page Date Procedure Change
HAK
Prepared
By
(Initials)
HAK
Approve
d
By
(Initials)
AOGCC Written
Approval
Received
(Person and
Date)
Approval:
Operations Manager Date
Prepared:
Operations Engineer Date
Kyle Wiseman Hilcorp Alaska, LLC
Geo Tech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: Kyle.Wiseman@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 03/08/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20230308
Well API #PTD #Log Date Log Company Log Type AOGCC
Eset#
PBU 09-09A 50029202320100 222157 2/19/2023 HALLIBURTON COILFLAG-RBT
PBU 09-43A 50029220780100 222156 3/4/2023 HALLIBURTON RBT
PBU Z-223 50029237200000 222080 2/28/2023 HALLIBURTON IPROF
PBU 11-40 50029235530000 215122 2/20/2023 READ
MULTIPLEARRAYPRODUCTION
PROFILE
Please include current contact information if different from above.
PBU 09-43A 50029220780100 222156 3/4/2023 HALLIBURTON RBT
David Douglas Hilcorp North Slope, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Hilcorp North Slope, LLC
Date: 03/02/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: PBU 09-43A
PTD: 222-156
API: 50-029-22078-01-00
FINAL LWD FORMATION EVALUATION LOGS (02/16/2023 to 02/21/2023)
Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs)
Pressure While Drilling (PWD)
Final Definitive Directional Surveys
SFTP Transfer - Data Folders:
Please include current contact information if different from above.
7. If perforating:
1. Type of Request:
2. Operator Name:
3. Address:
4. Current Well Class:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Property Designation (Lease Number):10. Field:
Abandon
Suspend
Plug for Redrill Perforate New Pool
Perforate
Plug Perforations
Re-enter Susp Well
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well
Other:
Change Approved Program
Operations shutdown
What Regulation or Conservation Order governs well spacing in thes pool?
Will planned perforations require a spacing exception?Yes No
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
PRESENT WELL CONDITION SUMMARY
Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft):
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
12. Attachments:
14. Estimated Date for
Commencing Operations:
13. Well Class after proposed work:
15. Well Status after proposed work:
16. Verbal Approval:
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal.
Proposal Summary Wellbore schematic
BOP SketchDetailed Operations Program
OIL
GAS
WINJ
WAG
GINJ
WDSPL
GSTOR
Op Shutdown
Suspended
SPLUG
Abandoned
ServiceDevelopmentStrastigraphicExploratory
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
AOGCC USE ONLY
Commission Representative:
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Location ClearanceMechanical Integrity TestBOP TestPlug Integrity
Other:
Post Initial Injection MIT Req'd?
Spacing Exception Required?Yes
Yes No
No Subsequent Form Required:
Approved By:Date:
APPROVED BY
THE AOGCCCOMMISSIONER
PBU 09-43A
Extended Perforating
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK
99503
222-156
50-029-22078-01-00
ADL 028327, 028324 & 028343
~14276
Conductor
Surface
Scab Liner
Production
Liner
~8870
80
4250
5551
12519
~3276
~14276
20"
10-3/4"
5-1/2"
7-5/8"
2-3/8"
~8870
33 - 113
32 - 4282
6528 - 12079
30 ~ 12262
~11000 - 14276
2461
33 - 113
32 - 3508
4988 - 8674
30 - 8995
~7944 - 8870
none
470
2090
6280
4790
11780
None
1490
3580
7740
6890
11200
n/a 4-1/2" 12.6# x 3-1/2" 9.2# 13Cr80 28 - 6612
Structural
4-1/2" Baker S-3 Perm
No SSSV
6513 / 4978
No SSSV Installed
Date:
Bo York
Operations Manager
Eric Dickerman
Eric.Dickerman@hilcorp.com
907.564.4061
PRUDHOE BAY
Current Pools:
PRUDHOE OIL
Proposed Pools:
PRUDHOE OIL
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng
Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov
3/7/23
By Samantha Carlisle at 9:04 am, Jan 19, 2023
323-029
Digitally signed by Bo York (1248)
DN: cn=Bo York (1248), ou=Users
Date: 2023.01.18 17:48:38 -09'00'
DLB 01/19/2023MGR02FEB23
2461
DSR-1/20/23
X 10-404
GCW 02/06/23JLC 2/6/2023
2/6/23Brett W. Huber, Sr.
Digitally signed by Brett W. Huber,
Sr.
Date: 2023.02.06 13:12:57 -09'00'
RBDMS JSB 020723
Well: 09-43A
PTD: 222-156
API:50-029-20232-01-00
Well Name:09-43A API Number:50-029-22078-01-00
Current Status:Shut in Rig:Coil
Estimated Start Date:Mar 2023 Estimated Duration:3 days
Regulatory Contact:Carrie Janowski
First Call Engineer:Eric Dickerman (907) 564-4061 (O)(307) 250-4013 (M)
Second Call Engineer:Dave Bjork (907) 564-4672 (O)(907) 440-0331 (M)
Current Bottom Hole Pressure:3,165 psi @ 8,760’ TVD 7.0 PPGE | Taken 1/1/2023
Maximum Expected BHP:3,350 psi @ 8,800’ TVD 7.4 PPGE | Average Ivishak BHP
Max. Anticipated Surface Pressure:2,470psi Based on 0.1 psi/ft. gas gradient
Last SI WHP: 200psi Taken on 1/2/2023
Min ID:1.995” ID ID of 2-3/8” liner
Max Angle:91 Deg @ 12,925’md taken from well plan
Tie In Log:LWD from drilling 09-43A sidetrack
Brief Well Summary:
09-43A is planned to be a horizontal Zone 1 producer from the Ivishak formation. The rig is expected to be
moving off the well March 6, 2023, at which time service coil will move in and perform an extended add perf
operation.
Objectives:
The objective of this procedure is to shoot Extended Addperfs for the initial perforations post sidetrack.
Procedure:
Coiled Tubing
Notes:
x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS
coverage is required.
x The well will be killed and monitored before making up the initial perfs guns. This is generally done
during the drift/logging run. This will provide guidance as to whether the well will be killed by
bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after
perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the
same port that opened to shear the firing head.
1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through
the brass upon POOH with guns.
2. MU and RIH with drift nozzle to TD.
3. MU and RIH with GR/CCL/CBL and drift nozzle and log from TD toabove top of 2-3/8” liner (~10,800’).
4. Flag pipe as appropriate per WSS for addperf runs.
5. Well should be a closed system. Ensure well is dead before POOH, and circulate a kill with 8.4ppg
1% KCl as necessary. Max tubing pressure 2500 psi. (This step can be performed any time prior to
open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.)
a. Wellbore volume to estimated PBTD of 12,365’ = 215 bbls
b. 4-1/2” Tubing – (6,517’ – surface) X 0.0152bpf = 99 bbl
c. 3-1/2” Tubing - (6,612’ – 6,517’) X 0.0087 bpf = 1 bbl
d. 5-1/2” Scab - (11,000’ – 6,612’) x 0.0232 bpf = 102 bbl
e. 2-3/8” Liner – (14,276’ – 11,000’) X 0.0039bpf = 13 bbl
6. POOH pumping pipe displacement and freeze protect tubing as needed.
Well: 09-43A
PTD: 222-156
API:50-029-20232-01-00
7. Confirm good log data.
8. At surface, prepare for deployment of TCP guns.
9. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5
ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established.
Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed
and there is no excess flow.
10.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well
control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun
string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve
readily accessible near the working platform for quick deployment if necessary.
f.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns
one time to confirm the threads are compatible.
11.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly
monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed
while deploying perf guns to ensure the well remains killed and there is no excess flow.
Perf Schedule
*Planned for 1.56” Halliburton Perfecta charges, max swell 1.74”, 3.62#/ft loaded weight.
Perf
Interval Perf Length Gun Length Weight of Gun (lbs)
Comments
Run 1 TBD ~500’500’1810 lbs (3.62ppf)Final lengths TBD
after analyzing open
hole and cement log
data. BHAs will be
limited to 500’ for
any individual run.
Run 2 TBD ~500’500’1810 lbs (3.62ppf)
Run 3 TBD ~200’200’724 lbs (3.62ppf)
Total
~1200’ 1200’
12. RIH with perf gun and tie-in to coil flag correlation. Pick up and perforate interval per Perf Schedule
above.
g. Note any tubing pressure change in WSR.
13. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and
stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface.
14. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary.
15. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and
commencing breakdown of TCP gun string.
16. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA.
17. Repeat steps 8 through 16 for subsequent runs to complete the desired perforated footage.
18. RDMO CTU.
19. RTP or FP well.
Attachments:
1. Current Wellbore Schematic
2. Proposed Schematic
3. Coil Tubing BOPE Schematic
4. Standing Orders for Open Hole Well Control during Perf Gun Deployment
5. Equipment Layout Diagram
6. Sundry Change Form
Make up PCE.
Well: 09-43A
PTD: 222-156
API:50-029-20232-01-00
Current Wellbore Schematic
Well: 09-43A
PTD: 222-156
API:50-029-20232-01-00
Proposed Wellbore Schematic
Well: 09-43A
PTD: 222-156
API:50-029-20232-01-00
Coiled Tubing BOPs
Standing Orders for Open Hole Well Control during Perf Gun Deployment
Well: 09-43A
PTD: 222-156
API:50-029-20232-01-00
Well: 09-43A
PTD: 222-156
API:50-029-20232-01-00
Equipment Layout Diagram
Well: 09-43A
PTD: 222-156
API:50-029-20232-01-00
Sundry Change Form
Changes to Approved Sundry Procedure
Date:
Subject:
Sundry #:
Any modifications to an approved sundry will be documented and approved below. Changes to an approved
sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change
is required before implementing the change.
Step Page Date Procedure Change
HAK
Prepared
By
(Initials)
HAK
Approve
d
By
(Initials)
AOGCC Written
Approval
Received
(Person and
Date)
Approval:
Operations Manager Date
Prepared:
Operations Engineer Date
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Rixse, Melvin G (OGC)
To:AOGCC Records (CED sponsored)
Subject:2022011201108 Remedial Cement Update PBU 09-43A - Sundry: 322-714 & PTD: 222-156 - Wellbore Exit
Modification
Date:Thursday, January 12, 2023 11:24:07 AM
From: Rixse, Melvin G (OGC)
Sent: Thursday, January 12, 2023 11:08 AM
To: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>
Subject: RE: HAK PBU 09-43A - Sundry: 322-714 & PTD: 222-156 - Wellbore Exit Modification
Trevor,
Thanks for the update. I don’t need anything else.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov).
From: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>
Sent: Thursday, January 12, 2023 10:03 AM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Eric Dickerman <Eric.Dickerman@hilcorp.com>
Subject: HAK PBU 09-43A - Sundry: 322-714 & PTD: 222-156 - Wellbore Exit Modification
Mel,
We ran a caliper log in 09-43 and decided we need to perform a cement pilot hole exit for 09-43A.
We don’t believe we can run the planned whipstock past some casing irregularities to its setting
depth. See below for details on old vs new plan.
Original Plan:
CDR2 Rig Operations:
1. Set 3-1/2”x7-5/8” HEW (whipsock)
o Set top of whipstock at 12,262’ MD
o 0° ROHS (High Side)
2. Contingency per Caliper – Cement HEW in place
o Make up cementing BHA, RIH to HEW. Swap the well over to 2% KCl.
o Cement Squeeze HEW with ~20 bbls - 15.3 ppg Class G cement (TOC to top of HEW)*
3. Mill 2.80” single string window (out of 7-5/8”) plus 10’ of rathole.
o Top of window (whipstock pinch point) at 12,266’ MD.
New Plan:
Pre-Rig Service Coil Operations (Plan to begin work January 17th):
1. Cement Wellbore for Pilot Hole
o Lay in and squeeze a cement plug in the 7-5/8” casing up into 5-1/2” scab liner
o 12,000’ MD cement top
o 20 bbls 15.8 ppg Class cement
2. Mill Starter Hole for Pilot Hole
o Confirm top of cement is in 5-1/2” scab liner (if not, lay in cement again for a top of cement
inside the 5-1/2”)
o Mill first ~20’ of pilot hole with 2.80” mill and underreamer (to create sloped entry into pilot
hole)
CDR2 Operations:
3. Mill Cement Pilot Hole
o 2.80” mill with bent motor
o Mill high side down to ~12,280’ MD.
4. Caliper Log Pilot Hole
o Run caliper to bottom of pilot hole
o Confirm casing exit location with caliper results
5. Set Whipstock in Cement Pilot Hole
o 3-3/16” Monobore Whipstock
o Set top of whipstock at ~12,264’ MD
o 0° ROHS (High Side)
6. Mill Window
o 2.80” single string window (out of 7-5/8”) plus 10’ of rathole
o Top of window (whipstock pinch point) at 12,264’ MD.
Please let us know what you think and if you need anything else.
Thank you for your time!
Trevor Hyatt
Hilcorp Alaska, LLC
Drilling Engineer
Trevor.Hyatt@hilcorp.com
Cell: 907-223-3087
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Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Monty Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 CenterPoint Drive, Suite 1400
Anchorage Alaska 99503
Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 09-43A
Hilcorp, LLC
Permit to Drill Number: 222-156
Surface Location: 1992' FSL, 62' FEL, Sec. 02, T10N, R15E, UM, AK
Bottomhole Location: 521' FNL, 263' FWL, Sec. 31, T11N, R16E, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs
run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment
of this well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required by
law from other governmental agencies and does not authorize conducting drilling operations until all
other required permits and approvals have been issued. In addition, the AOGCC reserves the right to
withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an
applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an
AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension
of the permit.
Sincerely,
Jessie L. Chmielowski
Commissioner
DATED this ___ day of January, 2023. 5
Jessie L.
Chmielowski
Digitally signed by
Jessie L. Chmielowski
Date: 2023.01.05
13:49:14 -09'00'
1a.
Contact Name:Trevor Hyatt
Contact Email:trevor.hyatt@hilcorp.comAuthorized Name: Monty Myers
Authorized Title:Drilling Manager
Authorized Signature:
Contact Phone:907-777-8396
Approved by:COMMISSIONER
APPROVED BY
THE COMMISSION Date:
21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated
from without prior written approval.
Drill
Type of Work:
Redrill 5
Lateral
1b.Proposed Well Class:Exploratory - Gas
5
Service - WAG
5
1c. Specify if well is proposed for:
Development - Oil Service - Winj
Multiple Zone Exploratory - Oil
Gas Hydrates
Geothermal
Hilcorp North Slope, LLC Bond No. 107205344
11.Well Name and Number:
PBU 09-43A
TVD:14276'8870'
12. Field/Pool(s):
PRUDHOE BAY, PRUDHOE OILMD:
ADL 028327, 028324 & 028343
74-017 February 1, 2023
4a.
Surface:
Top of Productive Horizon:
Total Depth:
1992' FSL, 62' FEL, Sec. 02, T10N, R15E, UM, AK
2391' FNL, 274' FEL, Sec. 36, T11N, R15E, UM, AK
Kickoff Depth:12266'feet
Maximum Hole Angle: 92 degrees
Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Downhole:Surface:3341 2461
17.Deviated wells:16.
Surface: x-y- Zone -718301 5943457 4
10. KB Elevation above MSL:
GL Elevation above MSL:
feet
feet
51.0'
19.4'
15.Distance to Nearest Well
Open to Same Pool:
Cement Quantity, c.f. or sacks
MD
Casing Program:
11000'7944'
19.PRESENT WELL CONDITION SUMMARY
Production
80 55 sx AS Cmt
12575 9012 None 12460 8936
33 - 113
Surface 1500 sx CS III, 350 sx Class G, 100 sx CS II
8781 - 8888
Seabed Report Drilling Fluid Program 5 20 AAC 25.050 requirements
Shallow Hazard Analysis
5
Commission Use Only
See cover letter for other
requirements:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes No
H2S measures Yes No
Spacing exception req'd: Yes No
Mud log req'd: Yes No
Directional svy req'd: Yes No
Inclination-only svy req'd: Yes No
Other:
Date:
Address:
Location of Well (State Base Plane Coordinates - NAD 27):
4.6#
4250
12230 - 12388
50-029-22078-01-00
495 sx Class G
Intermediate
Conductor/Structural
Single Zone
Service - Disp
No YesPost initial injection MIT req'd:
No Yes 5
Diverter Sketch
Comm.
TVD
API Number:
MD
Sr Pet Geo
521' FNL, 263' FWL, Sec. 31, T11N, R16E, UM, AK
Time v. Depth Plot 5 5 Drilling Program
3800'
(To be completed for Redrill and Re-Entry Operations)
20"
10-3/4"
Hyd 511
5551 4988 - 8674
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
Stratigraphic Test
Development - Gas Service - Supply
Coalbed Gas
Shale Gas
2.Operator Name:5.Bond Blanket 5 Single Well
3.
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
6. Proposed Depth:
7. Property Designation (Lease Number):
8. DNR Approval Number:13.Approximate spud date:
9.Acres in Property: 14. Distance to Nearest Property:
Location of Well (Governmental Section):
4b.
7611
200'
18.Specifications Top - Setting Depth - Bottom
Casing Weight Grade TVDHole Coupling Length TVD (including stage data)
Total Depth MD (ft): Total Depth TVD (ft):
Plugs (measured):Effect. Depth MD (ft): Effect. Depth TVD (ft):Junk (measured):
Casing Length Size MD
33 - 113
32 - 4282 32 - 3508
12519 7-5/8"500 sx ARC 30 - 12549 30 - 8995
Scab Liner 5-1/2"6528 - 12079
Perforation Depth MD (ft):Perforation Depth TVD (ft):
20. Attachments Property Plat BOP Sketch
Permit to Drill
Number:
Permit Approval
Date:
Reentry
Hydraulic Fracture planned?
Sr Pet Eng Sr Res Eng
Cement Volume
Comm.
14276'8870'204 sx Class G3-1/4"2-3/8"13Cr80 3276'
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g))
12260 x 2, 12234, 12301
12.21.2022
By Anne Prysunka at 2:14 pm, Dec 21, 2022
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2022.12.21 13:47:58 -09'00'
Monty M
Myers
DLB 12/29/2022
* BOPE test to 3500 psi.
Concur DLB
DSR-1/3/23
X
X
X
222-156
X
X
* Variance to 20 AAC 25.112(i) Alternate plug
placement approved for P&A of parent.
X
MGR29DEC2022
X
GCW 12/05/23
Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski
Date: 2023.01.05 13:49:33 -09'00'
To: Alaska Oil & Gas Conservation Commission
From: Trevor Hyatt
Drilling Engineer
Date: December 21, 2022
Re: PBU 09-43A Permit to Drill
Approval is requested for drilling a CTD sidetrack lateral from well PBU 09-43 with the
Nabors CDR2 Coil Tubing Drilling Rig.
Proposed plan for 09-43A Producer:
See 09-43 Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to
drift for whipstock, caliper and MIT. E-line or service coil will mill XN nipple.
A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the
well. A 3-1/2"x7-5/8" HEW whipstock will be set with the rig. Contingency cement squeeze HEW in place (to be
determined per calliper run). A 2.80" window +10’ of formation will be milled out of the 7-5/8” casing. The well will
kick off drilling in the Ivishak Zone 2 and land in the Ivishak Zone 1. The lateral will continue in Zone 1 to TD. The
proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner and cemented in place. The well will be
selectively perforated post rig (see future perf sundry). This completion will completely isolate and abandon the
parent Ivishak perfs.
The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is
attached for reference.
Pre-Rig Work:
x Reference 09-43 Sundry submitted in concert with this request for full details.
x General work scope of Pre-Rig work:
1. Slickline: Dummy WS drift and Caliper
2. Fullbore: MITs
3. E-line or Coil: Mill XN nipple
Rig Work - (Estimated to start February 2023):
1. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,461 psi
a. Give AOGCC 24hr notice prior to BOPE test
b. Test against swab and master valves (No TWC)
c. Load pits with drilling fluid
d. Open well and ensure zero pressure
2. Set 3-1/2”x7-5/8” HEW (whipsock)
a. Set top of whipstock at 12,262’ MD
b. 0° ROHS (High Side)
3. Contingency per Caliper – Cement HEW in place
a. Make up cementing BHA, RIH to HEW. Swap the well over to 2% KCl.
b. Cement Squeeze HEW with ~20 bbls - 15.3 ppg Class G cement (TOC to top of HEW)*
4. Mill 2.80” single string window (out of 7-5/8”) plus 10’ of rathole.
a. Top of window (whipstock pinch point) at 12,266’ MD.
5. Drill – Build & Lateral
a. 2-3/8” BHA with GR/RES / Bi-center Bit (3.25”)
b. 35° DLS build section – 210’ MD / Planned TD 12,476’ MD
c. 12° DLS lateral section – 1,800’ MD / Planned TD 14,276’ MD
d. Drill with a constant bottom hole pressure for entire sidetrack
e. Pressure deployment will be utilized
f. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run
g. No flow test prior to laying down drilling BHA. Assure well is dead prior to picking up liner.
Sundry 322-714
PTD 222-157
6. Run and Cement Liner
a. Run 2-3/8” 13Cr solid liner to TD
b. Have 2” safety joint with TIW valve ready to be picked up while running liner
c. Release from liner and come out of hole.
d. Make up cementing BHA, RIH and sting into liner shoe. Swap the well over to 2% KCl.
e. Cement Liner with 45 bbls - 15.3 ppg Class G cement (TOC to TOL)*
f. Only if not able to do with service coil extended perf post rig) - Perforate well ~1200’
g. Freeze protect well from ~2200’ TVD (min)
h. RDMO
Post Rig:
1. V: Valve & tree work
2. S: Set LTP* (if necessary)
3. C: Post rig perforate ~1200’ (if done post rig - see future Extended Perf Sundry)
4. T: Portable Test Separator Flowback
* Approved alternate plug placement per 20 AAC 25.112(i)
Managed Pressure Drilling:
Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole
pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface
pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying
annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or
fracturing at the end of the long well bores. A MPD choke for regulating surface pressure and is independent of
the WC choke.
Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will
be accomplished utilizing 3” (bighole) & 2-3/8” (slimhole) pipe/slip rams (see attached BOP configurations). The
annular preventer will act as a secondary containment during deployment and not as a stripper.
Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements
while drilling and shale behavior. The following scenario is expected:
MPD Pressure at the Planned Window (12,266’ MD - 8,805’ TVD)
Pumps On Pumps Off
A Target BHP at Window (ppg)4,487 psi 4,487 psi
9.8
B Annular friction - ECD (psi/ft)429 psi 0 psi
0.035
C Mud Hydrostatic (ppg)3,938 psi 3,938 psi
8.6
B+C Mud + ECD Combined 4,367 psi 3,938 psi
(no choke pressure)
A-(B+C)Choke Pressure Required to Maintain 120 psi 549 psi
Target BHP at window and deeper
Managed Pressure Drilling:gg
Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom holegp g q py p
pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface
pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability.
p y g ppg g p
MPD Pressure at the Planned Window (12,266’ MD - 8,805’ TVD)
DLB
Operation Details:
Reservoir Pressure:
x The estimated reservoir pressure is expected to be 3,341 psi at 8,800’ TVD (7.3 ppg equivalent).
x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,461 psi (from estimated
reservoir pressure).
Mud Program:
x Drilling: Minimum MW of 8.4 ppg KCL with Geovis for drilling. Managed pressure used to maintain
constant BHP.
x KWF will be stored on location. The tankage will contain 1.5 wellbore volumes of KWF to exceed the
maximum possible BHP to be encountered as the lateral is drilled. Adjust with real time BHP monitoring.
x Completion: A minimum MW 8.6 ppg KWF to be used for liner deployment. Will target 9.8 ppg to match
managed pressure target.
Disposal:
x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4.
x Fluids >1% hydrocarbons or flammables must go to GNI.
x Fluids >15% solids by volume must go to GNI.
x Fluids with solids that will not pass through 1/4” screen must go to GNI.
x Fluids with PH >11 must go to GNI.
Hole Size:
x 3.25” hole for the entirety of the production hole section.
Liner Program:
x 2-3/8”, 4.6#, 13Cr solid/cemented liner: 11,000’ MD – 14,276’ MD (3,276’ liner)
x The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary
x A X-over shall be made up to a 2” safety joint including a TIW valve for all tubulars ran in hole.
Well Control:
x BOP diagram is attached. MPD and pressure deployment is planned.
x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi.
x The annular preventer will be tested to 250 psi and 2,500 psi.
x 1.5 wellbore volumes of KWF will be on location at all times during drilling operations.
x A X-over shall be made up to a 2” safety joint including a TIW valve for all tubulars ran in hole.
x 2” safety joint will be utilized while running 2-3/8” solid or slotted liner. The desire is to keep the same
standing orders for the entire liner run and not change shut in techniques from well to well (run safety joint
with pre-installed TIW valve). When closing on a 2” safety joint, 2 sets of pipe/slip rams will be available,
above and below the flow cross providing better well control option.
Directional:
x Directional plan attached. Maximum planned hole angle is 92°. Inclination at kick off point is 46°.
x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
x Distance to nearest property line – 3,800’
x Distance to nearest well within pool – 200’
Logging:
x MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section.
x Real time bore pressure to aid in MPD and ECD management.
Perforating:
x ~1200’ perforated post rig (See future perforating sundry request – if extended perforating is used)
x 1.56” perf guns, 6 SPF, 60 deg phasing
x If extended perforating is not an option, the well will be perforated with the rig under this PTD.
Anti-Collision Failures:
x 04-39 fails WP11 AC scan in the existing 5-1/2” liner (in target reservoir) at 14,500’ MD.
x Well has been shut in since 1997 and no plans to get online. Will remain shut in during drilling of
09-43A.
Hazards:
x PBU DS09 is an H2S pad.
o The highest recorded H2S well on the pad was from 09-05A (1,361 ppm) in 2000.
o Last recorded H2S on 09-43 was 400 ppm in 2022
x No fault crossings expected.
x Low lost circulation risk.
Trevor Hyatt CC: Well File
Drilling Engineer Joseph Lastufka
907-223-3087
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82008300840085008600870088008900True Vertical Depth (200 usft/in)7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8900 9000 9100 9200 9300 9400 9500 9600 9700 9800 9900Vertical Section at 34.82° (200 usft/in)09-43A wp10 tgt309-43A wp10 tgt109-43A wp10 tgt209-43A wp10 tgt409-43A wp11 polygon1250009-437 5/8" TOW2 3/8" x 4 1/4"12500
13000
13500
140001427609-43A wp11Start Dir 8.99º/100' : 12266' MD, 8805.52'TVD : 0.09° RT TFStart Dir 35.01º/100' : 12286' MD, 8819.08'TVDStart Dir 35º/100' : 12396' MD, 8880.12'TVDStart Dir 12º/100' : 12476' MD, 8895.76'TVDTotal Depth : 14276' MD, 8869.84' TVDHilcorp North Slope, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: 09-43Ground Level: 19.40+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.005943457.350718300.56070° 14' 53.1888 N 148° 14' 10.5204 WSURVEY PROGRAMDepth From Depth To Survey/Plan Tool100.00 12266.00 09-43 GCT-MS (09-43) 3_Gyro-CT_pre-1998_Csg12266.00 14276.00 09-43A wp11 (09-43A) 3_MWDFORMATION TOP DETAILSNo formation data is availableREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: 09-43, True NorthVertical (TVD) Reference:Kelly Bushing / Rotary Table @ 51.00usftMeasured Depth Reference:Kelly Bushing / Rotary Table @ 51.00usftCalculation Method:Minimum CurvatureProject:Prudhoe BaySite:09Well:Plan: 09-43Wellbore:09-43ADesign:09-43A wp11CASING DETAILSTVD TVDSS MD SizeName8805.53 8754.53 12266.01 7-5/8 7 5/8" TOW8869.84 8818.84 14276.00 2-3/8 2 3/8" x 4 1/4"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 12266.00 46.41 49.89 8805.52 6194.92 5082.78 0.00 0.00 7988.03 Start Dir 8.99º/100' : 12266' MD, 8805.52'TVD : 0.09° RT TF2 12286.00 48.21 49.89 8819.08 6204.39 5094.02 8.99 0.09 8002.23 Start Dir 35.01º/100' : 12286' MD, 8819.08'TVD3 12396.00 66.34 8.85 8880.12 6283.59 5134.68 35.01 -75.00 8090.46 Start Dir 35º/100' : 12396' MD, 8880.12'TVD4 12476.00 91.03 22.43 8895.76 6358.25 5156.00 35.00 30.01 8163.92 Start Dir 12º/100' : 12476' MD, 8895.76'TVD5 12651.00 90.96 43.43 8892.69 6504.29 5250.58 12.00 90.00 8337.826 12976.00 91.22 4.43 8886.26 6795.60 5379.86 12.00 -89.25 8650.787 13151.00 91.14 25.43 8882.61 6963.71 5424.68 12.00 90.00 8814.388 13426.00 90.52 352.43 8878.52 7231.60 5466.77 12.00 -90.80 9058.349 13626.00 90.47 16.43 8876.76 7429.545482.11 12.00 90.01 9229.5910 13851.00 90.67 349.43 8874.48 7652.17 5493.50 12.00 -89.45 9418.8511 14001.00 90.64 7.43 8872.75 7801.48 5489.41 12.00 89.99 9539.0912 14276.00 90.54 40.44 8869.84 8049.36 5599.44 12.00 89.99 9805.40 Total Depth : 14276' MD, 8869.84' TVD
5850
6000
6150
6300
6450
6600
6750
6900
7050
7200
7350
7500
7650
7800
7950
8100
8250
8400
South(-)/North(+) (300 usft/in)4350 4500 4650 4800 4950 5100 5250 5400 5550 5700 5850 6000 6150 6300 6450
West(-)/East(+) (300 usft/in)
09-43A wp11 polygon
09-43A wp10 tgt4
09-43A wp10 tgt2
09-43A wp10 tgt1
09-43A wp10 tgt3
8
5
0
0
8
7
5
0
9
0
1
2
0
9
-
4
3
7 5/8" TOW
2 3/8" x 4 1/4"
88
7
0
0
9-43
A
w
p
11
Start Dir 8.99º/100' : 12266' MD, 8805.52'TVD : 0.09° RT TF
Start Dir 35.01º/100' : 12286' MD, 8819.08'TVD
Start Dir 35º/100' : 12396' MD, 8880.12'TVD
Start Dir 12º/100' : 12476' MD, 8895.76'TVD
Total Depth : 14276' MD, 8869.84' TVD
CASING DETAILS
TVD TVDSS MD Size Name
8805.53 8754.53 12266.01 7-5/8 7 5/8" TOW
8869.84 8818.84 14276.00 2-3/8 2 3/8" x 4 1/4"
Project: Prudhoe Bay
Site: 09
Well: Plan: 09-43
Wellbore: 09-43A
Plan: 09-43A wp11
WELL DETAILS: Plan: 09-43
Ground Level: 19.40
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00
5943457.350 718300.560 70° 14' 53.1888 N 148° 14' 10.5204 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: 09-43, True North
Vertical (TVD) Reference: Kelly Bushing / Rotary Table @ 51.00usft
Measured Depth Reference:Kelly Bushing / Rotary Table @ 51.00usft
Calculation Method:Minimum Curvature
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0.001.002.003.004.00Separation Factor12250 12375 12500 12625 12750 12875 13000 13125 13250 13375 13500 13625 13750 13875 14000 14125 14250 14375 14500 14625Measured Depth (250 usft/in)04-3909-4009-43No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: 09-43 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 19.40+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005943457.350718300.56070° 14' 53.1888 N148° 14' 10.5204 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: 09-43, True NorthVertical (TVD) Reference: Kelly Bushing / Rotary Table @ 51.00usftMeasured Depth Reference:Kelly Bushing / Rotary Table @ 51.00usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-12-19T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool100.00 12266.00 09-43 GCT-MS (09-43) 3_Gyro-CT_pre-1998_Csg12266.00 14276.00 09-43A wp11 (09-43A) 3_MWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)12250 12375 12500 12625 12750 12875 13000 13125 13250 13375 13500 13625 13750 13875 14000 14125 14250 14375 14500 14625Measured Depth (250 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference12266.00 To 14276.00Project: Prudhoe BaySite: 09Well: Plan: 09-43Wellbore: 09-43APlan: 09-43A wp11CASING DETAILSTVD TVDSS MD Size Name8805.53 8754.53 12266.01 7-5/8 7 5/8" TOW8869.84 8818.84 14276.00 2-3/8 2 3/8" x 4 1/4"
Well Date
Quick Test Sub to Otis -1.1 ft
Top of 7" Otis 0.0 ft
Distances from top of riser
Excluding quick-test sub
Top of Annular 2.75 ft
C L Annular 3.40 ft
Bottom Annular 4.75 ft
CL Blind/Shears 6.09 ft
CL 2.0" Pipe / Slips 6.95 ft B3 B4
B1 B2
Kill Line Choke Line
CL 2-3/8" Pipe / Slip 9.54 ft
CL 2.0" Pipe / Slips 10.40 ft
TV1 TV2
T1 T2
Flow Tee
Master
Master
LDS
IA
OA
LDS
Ground Level
3" LP hose open ended to Flowline
CDR2-AC BOP Schematic
CDR2 Rig's Drip Pan
Fill Line from HF2
Normally Disconnected
3" HP hose to Micromotion
Hydril 7 1/16"
Annular
Blind/Shear
2.0" Pipe/Slips
2 3/8" Pipe/Slips
2 3/8" Pipe/Slips
7-1/16"
5k Mud
Cross
2.0" Pipe/Slips
2-3/8" Pipe /
Slip
HF
nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee
Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME:______________________________________
PTD:_____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD:__________________________POOL:____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in nogreater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
PBU 09-43A
Prudhoe Oil
X
222-156
X
Prudhoe Bay Unit
X
WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT 09-43AInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2221560PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes2 Lease number appropriateYes3 Unique well name and numberYes4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes Directional plan view included, no land plat.8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For sNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes Inzone sidetrack from existing parent grass roots well.18 Conductor string providedYes Inzone sidetrack from existing parent grass roots well.19 Surface casing protects all known USDWsYes Inzone sidetrack from existing parent grass roots well.20 CMT vol adequate to circulate on conductor & surf csgYes Inzone sidetrack from existing parent grass roots well.21 CMT vol adequate to tie-in long string to surf csgYes Inzone sidetrack from existing parent grass roots well.22 CMT will cover all known productive horizonsYes 2-3/8" production liner resides all in zone. Fully cemented to window.23 Casing designs adequate for C, T, B & permafrostYes CDR2 has adequate tankage and good trucking support.24 Adequate tankage or reserve pitYes Sundry 322-714 plug for redrill25 If a re-drill, has a 10-403 for abandonment been approvedYes Halliburton collision scan identifies PBU 04-39 in collision scan. Offset has been shut in since 1997.26 Adequate wellbore separation proposedNA Inzone sidetrack from existing parent grass roots well.27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes 1 CT packoff, 1 annular, 4 ram stack tested to 3500 psi.29 BOPEs, do they meet regulationYes 5000 psi stack.30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownYes PBU DS9 is an H2S pad. Monitoring will be required.33 Is presence of H2S gas probableNA This sidetrack will be a producer.34 Mechanical condition of wells within AOR verified (For service well only)No DS 09 wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measuresYes36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate12/29/2022ApprMGRDate12/29/2022Appr DateAdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateDLB 12/29/2022JLC 1/5/2023
