Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout217-1527. 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/Pool(s):
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:
Authorized Title:
Authorized Signature: Date:
Contact Name:
Contact Email:
Contact Phone:
COMMISSION 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 COMMISSIONCOMMISSIONER
PBU 09-51A
Convert WAG to GI
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400,
Anchorage, AK 99503
217-152
50-029-22320-01-00
N/A
ADL 0028346, 028327, 028332, 028346
16165
Conductor
Surface
Intermediate
Liner
Liner
8988
80
3884
5445
5706
5305
16015
20"
13-3/8"
9-5/8"
7"
4-1/2"
8995
48 - 128
47 - 3931
44 - 5489
5322 -11028
10858 - 16163
3040
48 - 128
47 - 3709
44 - 4769
4656 - 8806
8679 - 8988
None
470
2260
4760
5410
7500
16015
1490
5020
6870
7240
8430
14575 - 14643 4-1/2"12.6# 13Cr85 42 - 108679035 - 9036
Structural
4-1/2" HES TNT Perm Packer
Red Spider
10747, 2004
8596, 2004
Date:
Bo York
Sr. Area Operations Manager
Oliver Sternicki
Oliver.Sternicki@hilcorp.com
907.564.4891
PRUDHOE BAY, PRUDHOE OIL
10/11/2021
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 3/2020 Approved application is valid for 12 months from the date of approval.
By Meredith Guhl at 1:29 pm, Sep 30, 2021
321-521
Digitally signed by Bo York
DN: cn=Bo York, c=US, o=HIlcorp
Alaska LLC, ou=Alaska North
Slope, email=byork@hilcorp.com
Date: 2021.09.29 10:11:55 -08'00'
Bo York
MGR11OCT2021
10-404
028345
DSR-9/30/21
SFD 10/8/2021
X
DLB 10/01/2021
dts 10/11/2021 JLC 10/11/2021
Jeremy
Price
Digitally signed
by Jeremy Price
Date: 2021.10.11
13:37:44 -08'00'
RBDMS HEW 10/12/2021
Operator Name:2.
Exploratory Development
Service
5
Permit to Drill Number:217-152
6.API Number:50-029-22320-01-00
PRUDHOE BAY, PRUDHOE OIL
BP Exploration (Alaska), Inc 5.
Field/Pools:9.
Well Name and Number:
ADL 028327, 028332 & 028345
Property Designation (Lease Number):10.
8.
PBU 09-51A
7.If perforating:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require a spacing exception?
Stratigraphic
Current Well Class:4.
Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well
Operations shutdown
Acid Stimulation
Op Shutdown
GAS
GSTOR WAG
SPLUG
Abandoned
Oil WINJ
Exploratory Development Stratigraphic 5Service
WDSPL
12. Attachments:
PRESENT WELL CONDITION SUMMARY
16165
Effective Depth MD:
13Cr85
11.
6/19/2020
Commission Representative:
15.
Suspended
Contact Name: Schultz, Kirsten L
Contact Email: Kirsten.Schultz@bp.com
Authorized Name: Schultz, Kirsten L
Authorized Title:Petroleum Engineer
Authorized Signature:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Yes No Spacing Exception Required?Subsequent Form Required:
Approved by:COMMISSIONER
APPROVED BYTHE
COMMISSION Date:
5OtherAlter Casing
Pull Tubing
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
COMMISSION USE ONLY
17. I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Detailed Operations Program
Packers and SSSV Type:
No SSSV Installed
Packers and SSSV MD (ft) and TVD (ft):
Perforation Depth MD (ft):Tubing Size:
Size
Total Depth MD (ft):Total Depth TVD(ft):
8988
Effective Depth TVD:Plugs (MD):Junk (MD):
5Other Stimulate
Re-enter Susp Well
Suspend
Plug for Redrill
Perforate
Perforate New Pool
10747 / 8596
No SSSV Installed
Date:
Liner 5305 4-1/2" 10858 - 16163 8679 - 8988 8430 7500
Well Status after proposed work:
16. Verbal Approval:
Change Approved Program
47 - 39347 - 37
14. Estimated Date for Commencing Operations:
BOP Sketch
48 - 128
Structural
6870
Proposal Summary 13. Well Class after proposed work:
4-1/2" HES TNT Perm Packer
11606 - 16053 9009 - 8993 4-1/2" 12.6# 13Cr85 42 - 10867
Liner
16072 8992 None None
48 - 128 470
13-3/8"
9-5/8"
Contact Phone:+1 907 564 5105
Date:
4760
80 149020"Conductor
2260
GINJ
5
Post Initial Injection MIT Req'd? Yes No
5
Comm.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
Surface 3890 5020
Intermediate 5445 44 - 5489 44 - 4769
5706 7"5322 - 11028 4656 - 8806 7240 5410
Address:P.O. Box 196612 Anchorage, AK
99519-6612
3.
No 5Yes
Casing Length MD TVD Burst
Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):
Collapse
MPSP (psi):
Wellbore Schematic
Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng
Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval.
By Samantha Carlisle at 8:56 am, Jun 04, 2020
320-240
Kirsten Schultz Digitally signed by Kirsten Schultz
Date: 2020.06.03 11:04:56 -08'00'
SFD 6/4/2020
MGR05JUN20 SFD 6/4/2020 DSR-6/4/2020
ADL 028346
10-404Yes equired?
C
6/10/2020
dts 6/10/2020 JLC 6/10/2020
RBDMS HEW 6/12/2020
10-403 Sundry Application for Well PBU 09-51A PTD #217-152
BP Exploration (Alaska) , Inc.
P.O. Box 196612 Anchorage, AK 99519-6612
Expected Start Date: June 19, 2020
Current condition of well:Gas Injection Well, Operable, Offline:
Gas Injection Rate:0 Mscf/Day
Injection Pressure:3040 psi
Reservoir Pressure:3366 psi
Program Objective(s):
09-51 is a MIST injector completed with 20 sleeves. The well has been injecting through sleeves 1 & 2
since early 2018. The well has already surpassed the optimum injection volume for MIST wells, and
offset producer response indicate it is time for us to change the MIST injection location. We would like
to close sleeves 1 & 2, and we would like to open sleeves 11 & 12. The target injection rate will be 12
MMscfd, so we should confirm 09-51can take that rate after the sleeves are opened.
200 IOR is based on the Value of MI * anticipated MI injection rate (~0.022 * 12MM SCFD = 264 IOR) * 6
month injector ramp-up factor.
We decided to move to sleeves 11 & 12 as it is expected the producers offset to those sleeves will
respond better to the MI than the producers offset the sleeves 3 & 4 at this time.
9-51A CT Procedure
Notes:
x All aqueous based intervention fluids should be friction reduced 1% KCl or as specified on the
pump schedule.
x Recent MIT data:
03/20/2018: MIT-IA passed to 3470 psi
02/05/2018: MIT-T passed to 4080 psi and MIT-IA passed to 4095 psi
x Wellbore volume to bottom perf/slot = 256 bbls (tubing volume = 173 bbls, liner volume = 83
bbls).
x Plan for 2” coil. 2” Coil was used to shift sleeves 1 & 2 in 2018 with the well swapped over to 2%
KCL with no issues.
Scope of Work:
x Shift Sleeves 1 & 2 closed
x Shift Sleeve 11 open; establish injectivity
x Shift sleeve 12 open; steablish injectivity
10-403 Sundry Application for Well PBU 09-51A PTD #217-152
BP Exploration (Alaska) , Inc.
P.O. Box 196612 Anchorage, AK 99519-6612
Acid Design Details:
x The goal is to obtain pre-acid injection test then circulate 20 bbls of HCl down the coil while taking
returns. Once acid is at BHA, the backside is shut in and 10 bbls of acid is forced into the sleeve.
After 10 bbls of HCl is pumped, a mid-acid injection test is obtained then the remainder of the
acid is injected and a post acid injection test is obtained.
x 15% HCL Acid: 2 stages per sleeve-10 bbl/stage
o Total 1% KCl Requirement: ~750 bbls
Standard inhibited 1% KCl with 1 gal/1000gal F103 (surfactant) or similar
o Total 15% HCl Requirement: 40 bbls
Loading for HCl 15% HCl
Product Code:Function:per Mgal
A264 ACI 6
A201 Inhibitor Aid 40
A153 Intensifier 5
F103 Flowback aid 2
L058 Iron Control 20
W054 Antiemulsifier 5
1. Drift to PBTD for NCS shifting tool.
2. At bottom, circulate well to 1% KCL by pumping 300 bbls down CT taking returns through the
choke.
3. MU NCS BHA per attached, discuss any changes with NCS Reps.
4. RIH and shift sleeves 1 & 2 closed.
5. Pressure test tubing to 1000 psi to confirm the sleeves are full closed.
6. RIH to sleeve #11 @ 13,586’, shift open per NCS and acidize per below:
x Record time, rate, well head pressure, treating pressure, and annulus pressures in the
WSR throughout the job.
x Keep injection pressures below 4000 psi.
10-403 Sundry Application for Well PBU 09-51A PTD #217-152
BP Exploration (Alaska) , Inc.
P.O. Box 196612 Anchorage, AK 99519-6612
7. POH to sleeve #12 @ 13,518’, shift open per NCS and acidize per below:
x Record time, rate, well head pressure, treating pressure, and annulus pressures in the
WSR throughout the job.
x Keep injection pressure below 4000 psi.
Stage #
Fluid Volume (bbl)
Min Rate
(bpm)
Max Rate
(bpm)Fluid
Volume
(bbl)
Rate
(bpm)Description
1% KCL 50 max
pre-acid injection. Shut down the pumps once 50 bbls
away, and then begin injectivity test.
1% KCL 5 0.5
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1% KCL 10 1
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1% KCL 20 2
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1% KCL 30 3
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
21% KCL 5max max take returns to choke
3 15% HCL 10 3 max take returns to choke
41% KCL 5 3max take returns to choke
5 15% HCL 10 3 max take returns to choke
61% KCL (coil vol) - (25 bbls)3 max displace acid to coil BHA
71% KCL 10 1 3
81% KCL50maxmid-acid injection
91% KCL 15 1 3
1% KCL 50 max
post-acid injection. Shut down the pumps once 50 bbls
away, and then begin injectivity test.
1% KCL 5 0.5
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1% KCL 10 1
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1% KCL 20 2
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1% KCL 30 3
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1
Coil Tubing Coil Annulus
acid treatment: back side shut in
acid treatment: back side shut in
10
10-403 Sundry Application for Well PBU 09-51A PTD #217-152
BP Exploration (Alaska) , Inc.
P.O. Box 196612 Anchorage, AK 99519-6612
1. Unseat NCS packer and RIH below sleeve #11 to obtain final injectivity test per below pumping
down the coil annulus.
a. Goal is to have >2 bpm injectivity at 2000 psi. If this is not achievable, contact APE to
discuss plan forward. See risks/mitigations section of SoR for some options.
8. POH and lay down NCS BHA
Fluid Volume Rate
Comments
1% KCL 50.5If required, adjust volumes so length of test is 10 min.
1% KCL 10 1 If required, adjust volumes so length of test is 10 min.
1% KCL 15 1.5 If required, adjust volumes so length of test is 10 min.
1% KCL 20 2 If required, adjust volumes so length of test is 10 min.
1% KCL 25 2.5 If required, adjust volumes so length of test is 10 min.
1% KCL 30 3
If required, adjust volumes so length of test is 10 min.
Stage #
Fluid Volume (bbl)
Min Rate
(bpm)
Max Rate
(bpm)Fluid
Volume
(bbl)
Rate
(bpm)Description
1% KCL 50 max
pre-acid injection. Shut down the pumps once 50 bbls
away, and then begin injectivity test.
1% KCL 5 0.5
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1% KCL 10 1
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1% KCL 20 2
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1% KCL 30 3
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
21% KCL 5max max take returns to choke
3 15% HCL 10 3 max take returns to choke
41% KCL 5 3max take returns to choke
5 15% HCL 10 3 max take returns to choke
61% KCL (coil vol) - (25 bbls)3 max displace acid to coil BHA
71% KCL 10 1 3
81% KCL50maxmid-acid injection
91% KCL 15 1 3
1% KCL 50 max
post-acid injection. Shut down the pumps once 50 bbls
away, and then begin injectivity test.
1% KCL 5 0.5
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1% KCL 10 1
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1% KCL 20 2
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1% KCL 30 3
pre-acid injection. Goal is to inject until stabilized rate is
achieved. If required, adjust volumes to ensure stabilized
rate is achieved.
1
Coil Tubing Coil Annulus
acid treatment: back side shut in
acid treatment: back side shut in
10
10-403 Sundry Application for Well PBU 09-51A PTD #217-152
BP Exploration (Alaska) , Inc.
P.O. Box 196612 Anchorage, AK 99519-6612
APPENDIX B
Approx NCS BHA for shifting sleeves
10-403 Sundry Application for Well PBU 09-51A PTD #217-152
BP Exploration (Alaska) , Inc.
P.O. Box 196612 Anchorage, AK 99519-6612
Schematic:
Operator Name:2.
Development Exploratory
Service
5
Permit to Drill Number:217-152
6.50-029-22320-01-00
PRUDHOE BAY, PRUDHOE OIL
Hilcorp North Slope, LLC 5.
Well Name and Number:8.
10.Field/Pools:
Well Class Before Work4.
Present Well Condition Summary:11.
Total Depth: measured feet
feet
Plugs measured feet
feet
Effective Depth: measured feet
feet
Packer measured feet
feettrue vertical true vertical
16165
16015
8995
10747
none
16015
8596
Casing: Length: Size: MD: TVD: Burst: Collapse:
Structural
Conductor 80 20" 48 - 128 48 - 128 1490 470
Surface 3884 13-3/8" 47 - 3931 47 - 3709 5020 2260
Intermediate 5445 9-5/8" 44 - 5489 44 - 4769 6870 4760
Liner 5706 7" 5322 - 11028 4656 - 8806 7240 5410
Perforation Depth: Measured depth: 11606 - 16053
feet
True vertical depth:9009 - 8993 feet
Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr85 42 - 10867 42 - 8686
10747 8596Packers and SSSV (type, measured and
true vertical depth)
4-1/2" HES TNT Perm Packer
Liner 5305 4-1/2" 10858 - 16163 8679 - 8988 8430 7500
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
0000
00 0
0
0 0
Representative Daily Average Production or Injection Data
Prior to well operation:
Subsequent to operation:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name:
Contact Email:
Torin Roschinger
Torin.Roschinger@hilcorp.com
Authorized Name:Bo York
Authorized Title:
Authorized Signature with Date:Contact Phone:(907) 654-4887
Treatment descriptions including volumes used and final pressure:
13.
Operations Manager
Operations Performed1.
Abandon Plug Perforations Fracture Stimulate Pull Tubing
GSTOR WINJ WAG 5 GINJ SUSP SPLUG
16. Well Status after work:Oil Gas
Exploratory Development Stratigraphic
15. Well Class after work:
5Service
WDSPL
14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283)
Daily Report of Well Operations
Copies of Logs and Surveys Run
true vertical measured8988
Sundry Number or N/A if C.O. Exempt:
320-240
No SSSV
Junk
Packer
Printed and Electronic Fracture Stimulation Data
5
Acid Stimulation
Operations shutdown
Change Approved Program
5
Senior Pet Engineer:Senior Res. Engineer:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Suspend Perforate Other Stimulate Alter Casing
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well
3.Address: 3800 Centerpoint Dr, Suite
1400, Anchorage, AK 99503
7.Property Designation (Lease Number):PBU 09-51A
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):
Stratigraphic
Other:
API Number:
Form 10-404 Revised 03/2020 Submit Within 30 days of Operations
ADL 028327, 028332, 028345, 028346
55
Sleeve 8 @ 14600'
Sleeve 7 @ 14663'
Digitally signed by Bo York
DN: cn=Bo York, c=US, o=HIlcorp
Alaska LLC, ou=Alaska North
Slope, email=byork@hilcorp.com
Date: 2021.04.22 15:39:57 -08'00'
Bo York
Sleeve 8 treated with ~23 bbls of 15% HCl Acid. Final treating pressure 613psi.
Sleeve 7 treated with ~ 18.5 bbls of 15% HCL Acid. Final treating pressure 1750psi.
By Samantha Carlisle at 9:09 am, Apr 23, 2021
RBDMS HEW 4/23/2021
MGR30JUL2021
3713
SFD 4/23/2021
3937
SFD 4/23/2021
DSR-4/26/21
ACTIVITYDATE SUMMARY
3/26/2021
***WELL S/I ON ARRIVAL*** (profile mod)
EQUALIZED & PULLED 4-1/2" MCX FROM X-NIP @ 2,004' MD.
DRIFT CLEANLY W/ NCS DRIFT (MAX OD: 3.79", OAL: 275") TO 11,245' SLM
(STALL DUE TO DEVIATION).
***WELL LEFT S/I ON DEPARTURE***
3/27/2021
CTU#9 2.0" CT. Job Scope: Close Slv's 1 & 2. Open/Acidize Slv's 7 & 8.
MIRU CTU. Bullhead 267 bbls 1% KCL w/ Safelube. RIH w/ NCS Sleeve Shifting
BHA. Function Test Packer at 150' - good. Continue RIH. Locate Slv's #20 & #19.
Correct depth to put the locator sub on depth by adding 35'. PT to 1000psi above all
Slv's - Good Test. Continue RIH. Locate Slv's #4 & #3. Correct depth by adding
another 9.5'. Attempt to RIH below Slv #1. Tag at 16053'. Appears there is fill/trash
at Slv #1. Verify depths by locating up to Slv #4. Attempt to close Slv #2 several
times with no success, all PT's failed at 1000psi. Not able to see the locator profile
which indicates the Slv is still open. Circulate while pulling up to Slv #2. Close Slv
#2. PT to 1000psi - PASSED. Tag Fill/Trash at 16051'. There is Zero room to move
down to release the Slips/Packer if we shift Slv #1 closed, we will be in a Tagged
depth. Discuss with OE. Continue on with Program to Shift 7 & 8 and stimulate.
Locate Slv #3 and Flag Pipe. Corrected EOP @ Flag = 15650.20'. Park at 14870''
below Slv #7. Perform Injectivity Test into Slv #1: 0.5 bpm @ 670psi. 1bpm @
1400psi.
***In Progress***cp
3/28/2021
CTU#9 2.0" CT. Job Scope: Close Slv's 1 & 2. Open/Acidize Slv's 7 & 8.
Continue Injectivity Test into Slv #1. 1.5 bpm @ 1750psi. 2 bpm @ ~ 3000psi and
slowly climbing. Open Slv #7. Pre Acid Injection: 0.5 bpm @ ~ 2975psi. Circulate
20 bbls HCl. Circulate 10 bbls Acid out Coil. Pump down backside & squeeze 10
bbls Acid into Slv #7. Mid Acid Injectivity = 3bpm @ ~ 1900psi. Circulate remaining
10 bbls Acid out Coil. Pump down backside & squeeze away into Slv #7. Post Acid
Injectivity = 0.5 bpm @ 100psi, 1bpm @ 385psi, 2bpm @ 940psi, 3bpm @ 1150 psi.
Open Slv #8. Pre acid injection at 1701psi. Inject 18.5 bbls of 15% HCL acid in two
stages. Post Acid Injectivity = 0.5 bpm @ 300psi, 1bpm @ 820psi, 2bpm @ 1504psi,
3bpm @ 1841 psi, 4.7bpm @ 2325psi. Final Injection Rates through sleeves #7, #8 &
#1 using 1% KCL + F103. 0.5 bpm @ 40psi / 1bpm @ 297psi / 1.5 bpm @ 594psi / 2
bpm @ 865psi / 2.5 bpm @ 1102psi / 3 bpm @ 1228psi. POOH. Freeze Protect Coil
w/ diesel. Lay down NCS Tools. MU & RIH w/ Baker 4.5" CIBP BHA. Correct depth
at Flag.
***In Progress***cp
3/29/2021
CTU#9 2.0" CT. Job Scope: Close Slv's 1 & 2. Open/Acidize Slv's 7 & 8.
Set Top of CIBP in middle of 41' joint above Slv #1 at 16015'. Pooh. Final Injectivity
into Slv's 7 & 8: 0.5 bpm @ 370psi / 1 bpm @ 780psi / 1.5 bpm @ 1050psi / 2.0 bpm
@ 1400psi / 2.5 bpm @ 1650psi / 3.0 bpm @ 1750psi. Freeze Protect Tbg w/ 38
bbls 60/40 Meth due to DSO not knowing for certain when well will be POI. Break
down BHA. Ball recovered. Rig Down CTU.
***Job Complete / Turn over to DSO to POI***
Daily Report of Well Operations
PBU 09-51A
128
3937
SFD 4/23/2021
