Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout2025_10_14_325-6307. 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 perfs require a spacing exception due to property boundaries?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
ServiceDevelopmentStratigraphicExploratory
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
AOGCC USE ONLY
Commission Representative:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Location ClearanceMechanical Integrity TestBOP TestPlug Integrity
Other Conditions of Approval:
Post Initial Injection MIT Req'd?Yes No
Subsequent Form Required:
Approved By:Date:
APPROVED BY
THE AOGCCCOMMISSIONER
PBU 15-32C
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage,
AK 99503
217-104
50-029-22462-03-00
ADL 0028306
11277
Conductor
Surface
Intermediate
Liner
Liner
8906
80
3492
8292
370
2843
8160
20"
13-3/8"
9-5/8"
7"
3-1/2" x 3-1/4" x 2-7/8"
8156
38 - 118
38 - 3530
35 - 8327
8165 - 8535
8434 - 11277
2700
38 - 118
38 - 3530
35 - 8319
8161 - 8514
8421 - 8906
10857
470
2260
4760
5410
10530
9405, 10150,
10810, 10857,
11208, 11235
1490
5020
6870
7240
10160
7951 - 11234 4-1/2" 12.6# 13Cr80 41 - 79447949 - 8906
Structural
4-1/2" HES TNT , 7819 , 7817
No SSSV
Date:
Bo York
Operations Manager
Jerry Lau
Jerry.Lau@hilcorp.com
(907) 564-5280
PRUDHOE BAY
11/01/2025
Current Pools:
PUT RIVER
Proposed Pools:
PUT RIVER
Suspension Expiration Date:
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 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 4:15 pm, Oct 14, 2025
Digitally signed by Bo York
(1248)
DN: cn=Bo York (1248)
Date: 2025.10.14 16:01:26 -
08'00'
Bo York
(1248)
325-630
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03-00
Well Name:15-32C Permit to Drill:217-104
Current Status:Operable, Producer API Number:50-029-22462-03-00
Estimated Start Date:November 1
th, 2025 Estimated Duration:7days
IOR:524 Rig:EL, Frac, CT, SL, Test
AFE:252-00614 Cost:$650,000
Regulatory Contact:Carrie Janowski Sundry Number:
First Call Engineer:Jerry Lau (907) 564-5280 (O)(907) 360-6233 (M)
Second Call Engineer:Leif Knatterud (907) 564-4667 (O)(432) 227-4342 (M)
Program Revision:Original
Current Bottom Hole Pressure:4025 psi @ 7900’ TVDss From 15-32C on 8/13/25
Max Anticipated Surface Pressure:2700 psi Based on 0.168 psi/ft gas gradient
Put River Western Lobe KWF: 9.80 ppg
Last SI WHP:2600 psi (09/24/2025)
Min ID:3.725” XN Nip @ 7932’ MD (After dropping TCP assembly)
Max Angle:5 deg @ 7932’ MD
Brief Well Summary:
A reservoir P&A was completed in July 2025. In July 2025, a UHRC RWO was performed to place production
packer above the Western Lobe of the Put River and run new 4-1/2” TBG. Post rig, the packer was set and well
was MIT’d. TCP guns hanging from the completion on the TBG tail were pressure actuated to perforate the target
interval.
Objectives:
Perform pre Frac MIT-T
Cut to drop TCP guns into the rat hole and below bottom perforation
Frac Put River Western Lobe sands in 15-32C
Perform FCO and Flowback via portable test separator
Current Status:
Operable
Well Completion Information:
Wellhead: FMC, 13-1/2” x 4-1/2” TC-II tubing hanger
Recent Integrity:
¾8/02/2025 – MIT-T Passed to 3802 psi (We will get a passing test to 4500 psi or greater prior to frac)
¾08/02/2025 – MIT-IA Passed to 3155 psi
¾02/24/2025 – PPPOT-IC Passed to 3500 psi
¾02/24/2025 – PPPOT-T Passed to 5000 psi
E-Line
1. Perform mechanical cut to drop TCP assembly fish into rat hole.
a. The 70’ fish will fall 84’ and land atop TBG stub at 8100’. This will put the top of fish at 8030’,
which is 19’ below the bottom perf at 8011’. GR/CCL logs from TBG cut and completion space out
were used to correlate depths.
b. Northern solutions designed a cut to release triple connection with the single upper connection
hanging off the upper completion and two connections facing down. The outer downfacing
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
connection is hanging off a 5.5” joint with a muleshoe and the inner downfacing connection is
hanging off a 4.5” joint with the TCP assembly. Welltech will space-out a no-go collar on their
cutter BHA to land on the XN nip to ensure the inner string is cut at the target depth.
Slickline + Fullbore
1. Set DGLVs, Set a BHP gauge in bottom mandrel.
2. MIT-T to 4500 psi
Frac
1. Spot water tanks and fill with fresh water
a. Heat water to 90 degF
b. Minimum pumping temp for water: 80 degF
2. Pull water from each tank and have SLB lab test our water quality:
a. pH - ~7
i. Higher pH delays the hydration of the gel and delays break
b. Calcium/magnesium <500 mg/l
i. Mg/Ca Negative side effects in the formation such as carbonate deposits, which tend to
be insoluble
c. Bicarbonate - <400 mg/l
i. High bicarbonate levels will cause slow hydration times and elevated delay times with X-
linking fluids. If we have elevated bicarbonate levels and have introduced delay agents, it
could have an exponential effect in delay times.
d. Chlorides-<10,000 mg/l
i. This fluid system should be able to cope with elevated Chloride levels
e. Iron (Fe+3) - <5 mg/l
i. Elevated Iron concentrations exist, the ammonium persulfate (breaker) can have an
accelerated effect. Can cause viscosity degradation in linear gels (especially if batch
mixed). Also can interfere with X-linking b/c iron will tie up the X-linking sites.
f. TDS – minimal/<5000
i. Effects depend on the solids that are dissolved in the fluid.
3. RU and set tree saver
4. RU SLB Frac
5. Ensure frac fluid QAQC has been agreed on with OE
6. Perform pressure tests prior to performing hydraulic fracture stimulation.
a. Pressure test surface lines and tree saver to 7,790 psi.
b. Pressure test pump kick outs to 6,450 psi.
c. Pressure test IA Pop-Off system to ensure functioning properly. IA Pop-Offs to be set at 2,995 psi.
d. Bring IA pressure up and hold at 2,700 psi.
7. Pump the hydraulic fracture stimulation per the proposed pump schedule below. Maximum allowable
treating pressure is 6,790 psi.
8. RDMO SLB frac, flowback equipment, and tree saver.
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Pump Schedule
Pressures
MIT-T 4,500 psi
MIT-IA 3,155 psi
Maximum Anticipated Treating Pressure:5,600 psi @ 25 BPM
IA Pop-off Set Pressure (~95% of MIT-IA):2,995 psi
IA Minimum Hold Pressure (POP-off – ~300 psi):2,700 psi
Maximum Allowable Treating Pressure (MATP =
Ann hold + MIT-T/1.1):
6,790 psi w/ 2,700 psi on IA
Stagger Pump Kickouts Between 90 – 95% of MATP:6,110 psi – 6,450 psi
N2 POP-off set pressure (MATP):6,790 psi
Treating Line Test Pressure (MATP + 1000 psi):7,790 psi
OA Pressure:Maintain open bleed on OA
Max Anticipated Proppant Loading:6 PPA
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Coil
1. Contingent Post Frac FCO
Slickline
1. Install LGLVs
2. Swap out BHPG
Testers:
1.MIRU portable testers and line heater
2.Utilize poor boy gas lift if needed
3.Flowback into LP via adjacent flowline.
4.Slow bean up
5.Continue flowing back until production is less than 0.5% solids and 1% WC
Attachments –
Current Wellbore Schematic
Wellbore Schematic after dropping TCP assembly
Reference Log for Put River Perforations and Formation Tops
Sundry Revision Change Form
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Current Wellbore Schematic:
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Wellbore Schematic after dropping TCP assembly
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Reference Log for Put River Perforations and Formation Tops
FR
A
C
–
P
u
t
R
i
v
e
r
W
e
s
t
e
r
n
L
o
b
e
We
l
l
:
1
5
-
3
2
C
PT
D
:
2
1
7
-
1
0
4
AP
I
:
5
0
-
0
2
9
-
2
2
4
6
2
-
0
3
Su
n
d
r
y
R
e
v
i
s
i
o
n
C
h
a
n
g
e
F
o
r
m
:
Ch
a
n
g
e
s
t
o
A
p
p
r
o
v
e
d
S
u
n
d
r
y
P
r
o
c
e
d
u
r
e
Da
t
e
:
Su
b
j
e
c
t
:
Su
n
d
r
y
#
:
An
y
m
o
d
i
f
i
c
a
t
i
o
n
s
t
o
a
n
a
p
p
r
o
v
e
d
s
u
n
d
r
y
w
i
l
l
b
e
d
o
c
u
m
e
n
t
e
d
a
n
d
a
p
p
r
o
v
e
d
b
e
l
o
w
.
C
h
a
n
g
e
s
t
o
a
n
a
p
p
r
o
v
e
d
s
u
n
d
r
y
w
i
l
l
b
e
c
o
m
m
u
n
i
c
a
te
d
t
o
t
h
e
AO
G
C
C
b
y
t
h
e
“
f
i
r
s
t
c
a
l
l
”
e
n
g
i
n
e
e
r
.
A
O
G
C
C
w
r
i
t
t
e
n
a
p
p
r
o
v
a
l
o
f
t
h
e
c
h
a
n
g
e
i
s
r
e
q
u
i
r
e
d
b
e
f
o
r
e
i
m
p
l
e
m
e
n
t
i
n
g
t
h
e
c
h
a
n
g
e
.
St
e
p
Pa
g
e
Da
t
e
Pr
o
c
e
d
u
r
e
C
h
a
n
g
e
HA
K
Pr
e
p
a
r
e
d
By
(I
n
i
t
i
a
l
s
)
HA
K
Ap
p
r
o
v
e
d
By
(I
n
i
t
i
a
l
s
)
AO
G
C
C
W
r
i
t
t
e
n
Ap
p
r
o
v
a
l
Re
c
e
i
v
e
d
(
P
e
r
s
o
n
an
d
D
a
t
e
)
Ap
p
r
o
v
a
l
:
Op
e
r
a
t
i
o
n
s
M
a
n
a
g
e
r
D
a
t
e
Pr
e
p
a
r
e
d
:
Op
e
r
a
t
i
o
n
s
E
n
g
i
n
e
e
r
D
a
t
e
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 1
Date: October 14, 2025
Subject: 15-32CC Fracture Stimulation
From: Jerry Lau
O: (907) 564-5280
C: (907) 360-6233
To: AOGCC
Estimated Start Date: 11/01/2025
Attached is Hilcorp’s proposal and supporting documents to perform a fracture stimulation on well
15-32C (PTD #217-104) in the Western Lobe of the Put River Reservoir of the Prudhoe Bay Unit.
The objective of this program is to perform a single stage fracture stimulation to the existing Put River
perforations to improve well performance.
15-32C was recently recompleted as a Put River Western Lobe producer, previously an Ivishak producer.
The Ivishak perforations were plugged on 7/16/2025 with cement filling the Ivishak production liner.
Isolation from the Ivishak was demonstrated with a state witnessed passing MIT-T on 7/20/2025. The
Put River interval was recompleted and perforated on 07/01/2025.
Hilcorp requests a variance to sections 20 AAC 25. 283, a, 3- 4 which require identification of fresh -
water aquifers and a plan for base-water sampling.
Please direct questions or comments to Jerry Lau.
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 2
SECTION 1 - AFFIDAVIT (20 AAC 25.283, a, 1):
Below is an affidavit stating that the owners, landowners, surface owners and operators identified on a
plat within one-half mile radius of the current or proposed wellbore trajectory have been provided
notice of operations in compliance with 20 AAC 25.283, a 1
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 3
SIGNED AFFIDAVIT:
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 4
COPY OF NOTIFICATION SENT VIA EMAIL:
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 5
SECTION 2 - PLAT IDENTIFYING ALL WELLS WITHIN ½ MILE (20 AAC 25.283, a, 2):
Plat of wells within one-half mile at surface. This includes the entirety of Drillsite 15. There are no additional wells from
other drillsites within the one-half mile radius.
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 6
LIST OF WELLS IN PLAT WITHIN ½ MILES ON SURFACE (20 AAC 25.283, a, 2, C):
®϶ba( ®([[϶ [ ®([[϶ ®϶ba( ®([[϶ [ ®([[϶ ®϶ba(®([[϶ [ ®([[϶
͔͐ϱ͏͐ "(« æÍIJîĺIJôî ͔͐ϱ͓͒ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͓͐ "(« iĖīώŘĺîŪèôŘώ>īĺſĖIJČ
͔͐ϱ͏͐ "(« æÍIJîĺIJôî ͔͐ϱ͔͒ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͏͐ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͏͑ "(« æÍIJîĺIJôî ͔͐ϱ͕͒ "(« æÍIJîĺIJôî ͔͐ϱ͏͗ [͐ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͏͑ "(« æÍIJîĺIJôî ͔͐ϱ͖͒ "(« æÍIJîĺIJôî ͔͐ϱ͒͐ "(« iĖīώŘĺîŪèôŘώ>īĺſĖIJČ
͔͐ϱ͏͑͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͖͒ "(« æÍIJîĺIJôî ͔͐ϱ͑͏ "(«iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͏͒ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͖͒͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͏͓ "(« iĖīώŘĺîŪèôŘώ>īĺſĖIJČ
͔͐ϱ͏͓ "(« æÍIJîĺIJôî ͔͐ϱ͒͗ "(« æÍIJîĺIJôî ͔͐ϱ͏͓͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͏͔ "(« æÍIJîĺIJôî ͔͐ϱ͒͘ "(« æÍIJîĺIJôî ͔͐ϱ͓͔ "(« æÍIJîĺIJôî
͔͐ϱ͏͔ "(« æÍIJîĺIJôî ͔͐ϱ͓͏ "(« æÍIJîĺIJôî ͔͐ϱ͓͔͐ "(« īŪČČôîώÍèħώ>ĺŘ ώôîŘĖīī
͔͐ϱ͏͔͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͓͏ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͔͑ "(« iĖīώŘĺîŪèôŘώ>īĺſĖIJČ
͔͐ϱ͏͕ "(« æÍIJîĺIJôî ͔͐ϱ͓͏͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͐͗ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͏͕ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͓͏͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͐͑͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͏͕͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͓͏͑ "(« īŪČČôîώÍèħώ>ĺŘ ώôîŘĖīī ͔͐ϱ͓͑͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͏͖ "(« æÍIJîĺIJôî ͔͐ϱ͓͐ "(« æÍIJîĺIJôî ͔͐ϱ͓͑ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͏͖ "(« æÍIJîĺIJôî ͔͐ϱ͓͑ "(« æÍIJîĺIJôî ͔͐ϱ͕͐͐ "(« īŪČČôîώÍèħώ>ĺŘ ώôîŘĖīī
͔͐ϱ͏͖ "(« æÍIJîĺIJôî ͔͐ϱ͓͑͐ (« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͕͐ "(«æÍIJîĺIJôî
͔͐ϱ͏͗ "(« æÍIJîĺIJôî ͔͐ϱ͓͑͑ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͖͑͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͏͗ "(« æÍIJîĺIJôî ͔͐ϱ͓͑͒ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͖͑ "(« æÍIJîĺIJôî
͔͐ϱ͏͗͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͓͒ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͒͏ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͏͗ "(« æÍIJîĺIJôî ͔͐ϱ͓͓ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͏͖ [͐ "(« æÍIJîĺ IJôî
͔͐ϱ͏͗͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͓͔ "(« æÍIJîĺIJôî ͔͐ϱ͖͒ "(« iĖīώŘĺîŪèôŘώ>īĺſĖIJČ
͔͐ϱ͏͘ "(« æÍIJîĺIJôî ͔͐ϱ͓͔ "(« æÍIJîĺIJôî ͔͐ϱ͒͑͐ "(« īŪČČôîώÍèħώ>ĺŘ ώôîŘĖīī
͔͐ϱ͏͘ "(« æÍIJîĺIJôî ͔͐ϱ͓͔͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͒͑ "(«æÍIJîĺIJôî
͔͐ϱ͐͏ "(« æÍIJîĺIJôî ͔͐ϱ͓͔͑ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͏͘ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͐͏ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͓͔͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͐͐ ͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͐͐ "(« æÍIJîĺIJôî ͔͐ϱ͓͕ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͐͐ "(« iĖīώŘĺîŪ èôŘώ>īĺſĖIJČ
͔͐ϱ͐͐ "(« æÍIJîĺIJôî ͔͐ϱ͓͖ "(« ŪŜŕôIJîôî ͔͐ϱ͓͗ "(« ŪŜŕôIJîôî
͔͐ϱ͐͑ "(« æÍIJîĺIJôî ͔͐ϱ͓͗ "(« æÍIJîĺIJôî ͔͐ϱ͏͔͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͐͑ "(« æÍIJîĺIJôî ͔͐ϱ͓͘ "(« æÍIJîĺIJôî ͔͐ϱ͏͔ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͐͑͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͓͘ "(« æÍIJîĺIJôî ͔͐ϱ͔͐ ͐"(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͐͒ "(« æÍIJîĺIJôî ͔͐ϱ͓͐͘ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͔͐ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͐͒ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͓͐͘ (« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͑͘ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͓͐ "(« æÍIJîĺIJôî ͔͐ϱ͏͗͑ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͑͐͘ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͔͐ "(« æÍIJîĺIJôî ͔͐ϱ͒͑͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͓͘ "(« æÍIJîĺIJôî
͔͐ϱ͔͐ "(« æÍIJîĺIJôî ͔͐ϱ͓͑ "(« æÍIJîĺIJôî ͔͐ϱ͑͗͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͕͐ "(« æÍIJîĺIJôî ͔͐ϱ͕͒͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͑͗͑ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͖͐ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͒͐ "(« æÍIJîĺIJôî ͔͐ϱ͑͗ "(« iĖīώŘĺîŪèôŘώ>īĺſĖIJČ
͔͐ϱ͐͗ "(« æÍIJîĺIJôî ͔͐ϱ͒͏͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͓͔ ͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͐͘ "(« æÍIJîĺIJôî ͔͐ϱ͔͐ "(« æÍIJîĺIJôî ͔͐ϱ͓͔ "(« æÍIJîĺIJôî
͔͐ϱ͐͘ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͒͗͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͓͘ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͑͏ "(« æÍIJîĺIJôî ͔͐ϱ͒͗ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͏͖"͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͑͏ "(« æÍIJîĺIJôî ͔͐ϱ͒͏ "(« æÍIJîĺIJôî ͔͐ϱ͏͖" "(« iĖīώŘĺîŪèôŘώēŪťϱ IIJ
͔͐ϱ͑͏͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͓͗ "(« æÍIJîĺIJôî ͔͐ϱ͏͖"͑"(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͑͐ "(« æÍIJîĺIJôî ͔͐ϱ͏͖ "(« æÍIJîĺIJôî ͔͐ϱ͓͔"͐ "(« īŪČČôîώÍèħώ>ĺŘ ώôîŘĖīī
͔͐ϱ͑͐ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͑͒ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͓͔" "(« iĖīώŘĺîŪèôŘώ>īĺſĖIJČ
͔͐ϱ͑͑ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͏͗ "(« iĖīώŘĺîŪèôŘώ>īĺſĖIJČ ͔͐ϱ͏͐͘ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͑͒ "(« æÍIJîĺIJôî ͔͐ϱ͑͏ "(« æÍIJîĺIJôî ͔͐ϱ͏͓͐ "(« īŪČČôîώÍèħώ>ĺŘώ ôîŘĖīī
͔͐ϱ͓͑ "(« æÍIJîĺIJôî ͔͐ϱ͑͗ "(« æÍIJîĺIJôî ͔͐ϱ͏͓͑ "(« īŪČČôîώÍèħώ>ĺŘώ ôîŘĖīī
͔͐ϱ͔͑ "(« æÍIJîĺIJôî ͔͐ϱ͒͒ "(« æÍIJîĺIJôî ͔͐ϱ͓͑͐ "(« īŪČČôîώÍèħώ>ĺŘώ ôîŘĖīī
͔͐ϱ͔͑ "(« æÍIJîĺIJôî ͔͐ϱ͏͓ "(« æÍIJîĺIJôî ͔͐ϱ͒͒ "(« iĖīώŘĺîŪèôŘώēŪťϱ IIJ
͔͐ϱ͔͑͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͖͒ "(« æÍIJîĺIJôî ͔͐ϱ͕͐ ͑"(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͕͑ "(« æÍIJîĺIJôî ͔͐ϱ͓͕[͐͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͕͐ ͐"(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͕͑ "(« æÍIJîĺIJôî ͔͐ϱ͓͕[͐ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͕͐ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͖͑ "(« æÍIJîĺIJôî ͔͐ϱ͐͐ "(« æÍIJîĺIJôî ͔͐ϱ͒͑ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͑͗ "(« æÍIJîĺIJôî ͔͐ϱ͕͑ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͖͑ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͑͘ "(« æÍIJîĺIJôî ͔͐ϱ͓͗ "(« æÍIJîĺIJôî ͔͐ϱ͕͒ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͒͏ "(« æÍIJîĺIJôî ͔͐ϱ͏͑ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͓͐ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ
͔͐ϱ͒͐ "(« æÍIJîĺIJôî ͔͐ϱ͏͑͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͓͐͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͒͑ "(« æÍIJîĺIJôî ͔͐ϱ͏͑͑ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͕͐ "(« æÍIJîĺIJôî
͔͐ϱ͒͒ "(« æÍIJîĺIJôî ͔͐ϱ͕͒ "(« æÍIJîĺIJôî ͔͐ϱ͒͑ "(« æÍIJîĺIJôî
͔͐ϱ͒͒ "(« æÍIJîĺIJôî ͔͐ϱ͕͒͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͕͒ "(«æÍIJîĺIJôî
͔͐ϱ͒͒͐ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͕͒͑ "(« īŪČČôîώÍèħώ>ĺŘ ώôîŘĖīī ͔͐ϱ͑͘ "(« æÍIJîĺIJôî
͔͐ϱ͒͒͑ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī ͔͐ϱ͐͑ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͑͐͘ "(« īŪČČôîώÍèħώ>ĺŘώôîŘĖīī
͔͐ϱ͓͒ "(« æÍIJîĺIJôî ͔͐ϱ͒͘ "(« iĖīώŘĺîŪèôŘώēŪťϱIIJ ͔͐ϱ͓͐ "(« æÍIJîĺIJôî
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 7
SECTION 3 and 4 - EXEMPTION FOR FRESWATER AQUIFERS and PLAN FOR BASELINE WATER
SAMPLING FOR WATER WELLS (20 AAC 25.283, a, 3-4):
Well 15-32C is located in the Eastern Operating Area of Prudhoe Bay (AIO 4G, 2015). Conclusion #10
(Area Injection Order 4A, August 12, 1993, Page 5) states that “No underground sources of drinking
water (USDWs) are known to exist in the Eastern Operating Area of the Prudhoe Bay Unit.”
Area Injection Order 4G, October 15, 2015, Page 3 states that “All information related to AIO 4, AIO 4A,
AIO 413, AIO 4C, AIO 4D, AIO 4E and AIO 4F is hereby incorporated by reference into the record for this
order.”
Based on the Area Injection Order sections referenced above, Hilcorp requests exemption from 20 AAC
25. 283, a, 3- 4 which require identification of freshwater aquifers and establishing a plan for base-water
sampling.
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 8
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 9
SECTION 5 - DETAILED CEMENTING AND CASING INFORMATION (20 AAC 25.283, a, 5):
All casing is cemented and tested in accordance with 20 AAC 25.030, g when completed.
See wellbore schematic for casing details:
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 10
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 11
SECTION 6 - ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE
PERFORMED TO CONSTRUCT OR REPAIR THE WELL (20 AAC 25.283, a, 6):
Summary:
9-5/8” Production CSG:
The original completion documents indicate that the primary cement job on the 9-5/8” casing went as
followed: 241 bbls of cement were pumped, plug did not bump, floats held. Tagged CMT 125’ above
float collar. After backing out 125’ of cement from tag and 82’ of shoe tract for a total of 207’, it was
determined that 226 bbls made it behind pipe. The volumetric TOC including 30% washout calculates
TOC at 5210’ behind 9-5/8” CSG. This calculation was previously verified by AOGCC during the 15-32C
sundry #325-353 approval process. The CSG was pressure tested to 3500 psi after cementing.
7” Production LNR:
Cemented with 57 bbls of Class G cement, 33% excess when backing out liner lap volume. The original
completion documents report circulating out 25 bbls of cement returns after pumping primary job.
Estimated TOC at 8165’ top of liner. The LNR was pressure tested to 3500 psi after cementing.
4-1/2” x 7” Annulus Cement Squeeze
In preparation for a dual string exit for the 15-32C sidetrack, service coil squeezed the 4-1/2” x 7”
annulus from tubing punch holes at 8176’ to beneath the 15-32C KOP of 8535’. A 5/27/25 CBL found
excellent cement coverage from the top of 3-1/2” 15-32C sidetrack CTD liner at 8427’ up to TOC at
8157’, which is 8’ above the 7” top of production liner.
15-32C CTD LNR
2017 CTD sidetrack exited parent bore at 8,535’, not affecting isolation within confining zones of job
scope.
Ivishak Reservoir Abandonment – 2-7/8” – 4-1/2” Cement plug
Coiled Tubing downsqueezed 12 bbls 15.3 ppg Class G cement through retainer at 8225’, 2 bbls excess
on 7/16/25 to cement wellbore from retainer to 9405’ with 3000 psi of squeeze pressure then laid 2 bbls
atop retainer. Final TOC was 8160’ MD, slickline tagged at 8129’ SLM with AOGCC witness on 7/20/25
Prior wellbores – 15-32 parent 7” LNR perforations, 15-32A CTD sidetrack and 15-32B sidetrack were
previously P&A’d and are further isolated by the completed Ivishak Reservoir Abandonment of the 15-
32C sidetrack cement plug.
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 12
SECTION 7 - PRESSURE TEST INFORMATION AND PLANS TO PRESSURE TEST CASINGS AND
TUBING INSTALLED IN THE WELL (20 AAC 25.283, a, 7):
Post RWO, the tubing was pressure tested to 3,802 psi with a MIT-T and the IA was pressure tested to
3,155 psi with a MIT-IA. Anticipated pressures in the table below assume a passing MIT-T of 4500 psi or
more, which will be performed prior to pumping a hydraulic fracturing stimulation.
The production casing annulus pressure will be monitored during the frac, if any change of pressure is
seen outside of thermal expansion, the job will be flushed and the pressure source diagnosed before
frac operations continue.
Anticipated Pressures:
MIT-T 4,500 psi
MIT-IA 3,155 psi
Maximum Anticipated Treating Pressure:5,600 psi @ 25 BPM
IA Pop-off Set Pressure (~95% of MIT-IA):2,995 psi
IA Minimum Hold Pressure (POP-off – ~300 psi):2,700 psi
Maximum Allowable Treating Pressure (MATP =
Ann hold + MIT-T/1.1):
6,790 psi w/ 2,700 psi on IA
Stagger Pump Kickouts Between 90 – 95% of MATP:6,110 psi – 6,450 psi
N2 POP-off set pressure (MATP):6,790 psi
Treating Line Test Pressure (MATP + 1000 psi):7,790 psi
OA Pressure:Maintain open bleed on OA
Max Anticipated Proppant Loading:6 PPA
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 13
SECTION 8 - PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE
AND TREATING HEAD (20 AAC 25.283, a, 8):
Wellbore Tubular Ratings
Size/Name Weight Grade Burst, psi Collapse, psi
13-3/8” Surface Casing 68#L-80 5,020 2,260
9-5/8” Production Casing 47#L-80 6,870 4,760
4-1/2” Production Tubing 12.6#L-80 8,430 7,500
Wellhead
FMC manufactured wellhead 5,000 psi.
Tubing head adaptor: 13-5/8" 5,000 psi x 4-1/16" 5,000 psi
Tubing Spool: 13-5/8” 5,000psi w/ 2-1/16” side outlets
Casing Spool: 13-5/8” 5,000psi w/ 2-1/16” side outlets
Tree: CIW 4-1/16” 5,000psi
-A 10,000-psi rated TreeSaver will be used during the fracturing operation.
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 14
SECTION 9 - DATA FOR FRACTURING ZONE AND CONFINING ZONES (20 AAC 25.283, a, 9):
*Depths are taken from 15-32C
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 15
SECTION 10 – LOCATION, ORIENTATION, AND A REPORT ON MECHANICAL CONDITION OF
EACH WELL THAT MAY TRANSECT CONFINING ZONE (20 AAC 25.283, a, 10):
The map shows a gold one-half mile radius around the 15-32C transection of Put River formation. All
wells transections of the Put River formation within the area of review are shown in Purple. These wells
show the Put River formation within logs with the exception of 15-03. The Proposed frac is modeled
with 281’ half lengths. A 281’ radius circle in light purple shows the modeled half length radius. A black
line within the half length radius shows the most likely orientation of the frac, which is 10 deg W of N.
No seismic faults were identified within the area of review.
15-01
15-01A
15-01B
15-03
15-04B15-04BPB1
15-06A
15-06APB1
15-08APB1
15-08APB2
15-08CL1
15-12
15-12A
15-12APB
15-12BPB1
15-13
15-14A
15-19
15-20
15-20A
15-20APB1
15-20B
15-20C
15-2415-24PB1
15-32
15-32A
15-32B
15-32BPB1
15-32C
15-32PB1
15-39
15-39A
15-43
8
15-48A
15-48B
15-49A
15-06
15-05 15-27
15-43
15-19
15-08A
15-26
15-20
15-20B15-39-04 1515-03 15-48 15-39A
15-32
15-2315-23A
15-31
15-24
15-47
15-13 15-38 15-1215-01
5-02
15-02B
15-12B
673500 674000 674500 675000 675500 676000 676500 677000 677500 678000 678500 679000 679500
673500 674000 674500 675000 675500 676000 676500 677000 677500 678000 678500 679000 679500
0 1000 2000 3000 4000 5000ftUS
1:8389
1 5 -3 2C 1/2 Mi le AOI Su rface Map
Scale
1:8389
Date
10/08/2025
Proposed frac location in white
square. Brown circle has 1/2 mile
radius around frac location.
FR
A
C
–
P
u
t
R
i
v
e
r
W
e
s
t
e
r
n
L
o
b
e
We
l
l
:
1
5
-
3
2
C
PT
D
:
2
1
7
-
1
0
4
AP
I
:
5
0
-
0
2
9
-
2
2
4
6
2
-
0
3
Pa
g
e
1
6
Ca
s
i
n
g
a
n
d
C
e
m
e
n
t
a
s
s
e
s
s
m
e
n
t
s
f
o
r
a
l
l
w
e
l
l
s
t
h
a
t
t
r
a
n
s
e
c
t
t
h
e
c
o
n
f
i
n
i
n
g
z
o
n
e
(
A
O
R
)
:
We
l
l
Na
m
e
PT
D
A
P
I
Di
s
t
a
n
c
e
/
St
a
t
u
s
To
p
P
u
t
MD
f
e
e
t
To
p
P
u
t
TV
D
s
s
f
e
e
t
TO
C
MD
f
e
e
t
TO
C
TV
D
s
s
f
e
e
t
Zo
n
a
l
Is
o
l
a
t
i
o
n
Co
m
m
e
n
t
s
15
-
0
1
18
2
-
0
0
6
5
0
-
0
2
9
-
2
0
6
9
6
-
0
0
-
0
0
2
2
4
0
'
/
P
&
A
'
d
8
,
4
5
2
-
7
,
8
1
3
7
,
5
7
1
-
7
,
0
0
6
C
l
o
s
e
d
D
r
i
l
l
e
d
1
2
-
1
/
4
"
h
o
l
e
.
L
a
n
d
e
d
9
-
5
/
8
"
C
S
G
a
t
8
9
1
4
'
.
1
0
2
b
b
l
s
c
e
me
n
t
p
u
m
p
e
d
,
9
7
b
b
l
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
15
-
0
3
18
2
-
0
3
0
5
0
-
0
2
9
-
2
0
7
2
2
-
0
0
-
0
0
1
6
1
0
'
/
L
T
S
I
8
,
2
5
0
-
7
,
8
5
5
7
,
2
2
1
-
6
,
8
3
7
C
l
o
s
e
d
Pu
t
R
i
v
e
r
f
o
r
m
a
t
i
o
n
n
o
t
s
e
e
n
o
n
w
e
l
l
l
o
g
s
.
U
s
e
d
a
d
j
a
c
e
n
t
w
e
l
l
1
5
-
2
3
P
u
t
R
i
v
e
r
T
V
D
s
s
f
o
r
r
e
f
e
r
e
n
c
e
.
D
r
i
l
l
e
d
1
2
-
1
/
4
"
h
o
l
e
.
La
n
d
e
d
9
-
5
/
8
"
C
S
G
a
t
9
3
0
2
'
.
1
6
0
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
1
5
1
b
b
l
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
L
T
S
I
s
t
a
t
u
s
w
i
t
h
P
C
le
a
k
a
t
5
8
0
0
'
/
-
5
5
4
7
T
V
D
s
s
.
15
-
0
8
A
19
3
-
1
3
4
5
0
-
0
2
9
-
2
1
1
8
0
-
0
1
-
0
0
2
1
2
0
'
/
P
&
A
'
d
8
,
3
7
0
-
7
,
9
3
2
7
,
4
4
8
-
7
,
1
2
9
C
l
o
s
e
d
Dr
i
l
l
e
d
8
-
1
/
2
"
h
o
l
e
.
L
a
n
d
e
d
7
"
C
S
G
a
t
9
8
2
5
'
.
1
1
0
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
1
0
7
b
b
l
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
C
e
m
e
n
t
re
t
u
r
n
s
s
e
e
n
a
t
s
u
r
f
a
c
e
w
h
e
n
C
B
U
a
f
t
e
r
s
e
t
t
i
n
g
7
"
L
T
P
i
n
9
-
5
/
8
"
,
w
h
i
c
h
m
e
a
n
s
t
h
e
t
h
e
c
e
m
e
n
t
m
a
d
e
i
t
a
b
o
v
e
t
h
e
9
-
5
/
8
"
w
i
n
d
o
w
o
f
1
5
-
0
8
p
a
r
e
n
t
w
e
l
l
b
o
r
e
a
t
7
4
4
8
'
.
W
e
a
r
e
c
a
l
l
i
n
g
T
O
C
a
t
t
h
e
w
i
n
d
o
w
a
t
7
4
4
8
'
w
h
e
r
e
1
5
-
0
8
A
i
n
t
e
r
s
e
c
t
s
1
5
-
0
8
p
a
r
e
n
t
9-
5
/
8
"
C
S
G
15
-
1
3
18
1
-
1
2
4
5
0
-
0
2
9
-
2
0
6
4
5
-
0
0
-
0
0
20
5
0
'
/
N
o
t
Op
e
r
a
b
l
e
8,
3
2
0
-
7
,
9
2
4
7
,
3
3
2
-
7
,
0
5
6
C
l
o
s
e
d
Dr
i
l
l
e
d
1
2
-
1
/
4
"
h
o
l
e
.
L
a
n
d
e
d
9
-
5
/
8
"
C
S
G
a
t
8
6
4
3
'
.
1
0
2
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
9
5
b
b
l
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
1
5
-
13
a
n
d
1
5
-
1
3
A
s
h
a
r
e
t
h
e
s
a
m
e
p
a
r
e
n
t
b
o
r
e
a
c
r
o
s
s
p
u
t
r
i
v
e
r
i
n
t
e
r
v
a
l
.
1
5
-
1
3
A
i
s
a
N
o
t
O
p
e
r
a
b
l
e
P
r
o
d
u
c
e
r
w
i
t
h
s
m
a
l
l
P
K
R
l
e
a
k
an
d
T
x
I
A
,
s
e
c
u
r
e
d
w
i
t
h
T
T
P
.
15
-
1
9
18
8
-
0
6
5
5
0
-
0
2
9
-
2
1
8
2
9
-
0
0
-
0
0
1
5
4
0
'
/
O
p
e
r
a
b
l
e
8
,
0
0
8
-
7
,
8
5
5
4
,
9
6
5
-
4
,
9
0
0
C
l
o
s
e
d
Dr
i
l
l
e
d
9
-
7
/
8
"
h
o
l
e
.
L
a
n
d
e
d
7
-
5
/
8
"
C
S
G
a
t
9
1
5
4
'
.
2
1
2
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
2
1
2
b
b
l
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
T
h
e
Pr
u
d
h
o
e
O
i
l
P
o
o
l
w
a
s
P
&
A
'
d
i
n
p
r
e
p
a
r
a
t
i
o
n
f
o
r
1
5
-
1
9
A
C
T
D
S
T
.
1
5
-
1
9
a
n
d
1
5
-
1
9
A
s
h
a
r
e
s
a
m
e
p
a
r
e
n
t
b
o
r
e
a
c
r
o
s
s
P
u
t
R
i
v
e
r
in
t
e
r
v
a
l
.
1
5
-
1
9
A
i
s
o
p
e
r
a
b
l
e
.
15
-
2
0
18
4
-
0
9
8
5
0
-
0
2
9
-
2
1
1
3
3
-
0
0
-
0
0
1
3
0
0
'
/
P
&
A
'
d
8
,
0
0
0
-
7
,
9
2
4
7
,
0
1
3
-
6
,
9
3
7
C
l
o
s
e
d
Dr
i
l
l
e
d
1
2
-
1
/
4
"
h
o
l
e
.
L
a
n
d
e
d
9
-
5
/
8
"
C
S
G
a
t
8
3
3
8
'
.
1
0
2
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
9
6
b
b
l
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
1
5
-
20
A
s
h
a
r
e
s
t
h
e
s
a
m
e
p
a
r
e
n
t
w
e
l
l
b
o
r
e
a
s
1
5
-
2
0
a
c
r
o
s
s
t
h
e
p
u
t
r
i
v
e
r
i
n
t
e
r
v
a
l
a
n
d
w
e
r
e
P
&
A
'
d
i
n
p
r
e
p
a
r
a
t
i
o
n
f
o
r
1
5
-
2
0
B
r
o
t
a
r
y
si
d
e
t
r
a
c
k
i
n
A
u
g
u
s
t
2
0
0
6
.
15
-
2
0
B
20
3
-
1
3
6
5
0
-
0
2
9
-
2
1
1
3
3
-
0
2
-
0
0
12
4
0
'
/
N
o
t
Op
e
r
a
b
l
e
7,
9
9
4
-
7
,
9
2
6
7
,
8
5
3
-
7
,
7
8
9
C
l
o
s
e
d
7"
P
r
o
d
u
c
t
i
o
n
C
S
G
T
O
C
i
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
e
s
t
i
m
a
t
e
d
t
o
b
e
1
4
1
'
a
b
o
v
e
t
h
e
t
o
p
o
f
t
h
e
P
u
t
R
i
v
e
r
.
D
r
i
l
l
e
d
8
.
5
"
h
o
l
e
a
n
d
l
a
n
d
e
d
7
"
CS
G
a
t
8
2
7
5
'
3
6
.
5
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
3
3
.
2
5
b
b
l
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
S
h
a
r
e
s
s
a
m
e
p
a
r
e
n
t
w
i
t
h
1
5
-
2
0
C
ac
r
o
s
s
p
u
t
r
i
v
e
r
i
n
t
e
r
v
a
l
.
1
5
-
2
0
C
i
s
c
l
a
s
s
i
f
i
e
d
a
s
n
o
t
o
p
e
r
a
b
l
e
d
u
e
t
o
T
x
I
A
a
n
d
i
s
s
e
c
u
r
e
d
w
i
t
h
a
T
T
P
.
15
-
2
3
19
1
-
1
3
5
5
0
-
0
2
9
-
2
2
2
2
5
-
0
0
-
0
0
1
1
4
0
'
/
P
&
A
'
d
8
,
1
3
6
-
7
,
8
5
5
2
,
9
8
9
-
2
,
9
2
8
C
l
o
s
e
d
Vo
l
u
m
e
t
r
i
c
T
O
C
f
o
r
9
-
5
/
8
"
P
r
o
d
u
c
t
i
o
n
C
S
G
p
r
i
m
a
r
y
j
o
b
a
p
p
e
a
r
s
t
o
h
a
v
e
c
l
o
s
e
d
t
h
e
1
3
-
3
/
8
"
S
u
r
f
a
c
e
C
S
G
s
h
o
e
-
s
u
p
p
o
r
t
e
d
m
y
pa
s
s
i
n
g
M
I
T
-
O
A
'
s
.
D
r
i
l
l
e
d
1
2
-
1
/
4
"
h
o
l
e
.
L
a
n
d
e
d
C
S
G
a
t
8
7
2
0
'
.
4
2
4
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
4
1
6
v
o
l
u
m
e
n
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
pi
p
e
.
P
a
r
e
n
t
w
e
l
l
b
o
r
e
c
o
n
t
a
i
n
i
n
g
P
u
t
R
i
v
e
r
w
a
s
P
&
A
'
d
i
n
p
r
e
p
a
r
a
t
i
o
n
f
o
r
J
u
l
y
2
0
0
3
1
5
-
2
3
A
r
o
t
a
r
y
s
i
d
e
t
r
a
c
k
.
15
-
2
3
A
20
3
-
1
1
1
5
0
-
0
2
9
-
2
2
2
2
5
-
0
1
-
0
0
1
9
2
0
'
/
O
p
e
r
a
b
l
e
8
,
4
6
2
-
7
,
7
9
1
3
,
6
5
6
-
3
,
5
9
5
C
l
o
s
e
d
7"
P
r
o
d
u
c
t
i
o
n
L
N
R
f
r
o
m
1
5
-
2
3
A
s
i
d
e
t
r
a
c
k
p
r
i
m
a
r
y
j
o
b
s
a
w
c
e
m
e
n
t
r
e
t
u
r
n
s
t
o
t
o
p
o
f
l
i
n
e
r
-
c
o
n
f
i
r
m
e
d
a
f
t
e
r
C
B
U
r
e
c
o
v
e
r
e
d
ce
m
e
n
t
a
t
s
u
r
f
a
c
e
a
f
t
e
r
s
e
t
t
i
n
g
l
i
n
e
r
h
a
n
g
e
r
.
T
h
i
s
c
o
n
f
i
r
m
s
t
h
a
t
t
h
e
r
e
i
s
c
e
m
e
n
t
i
s
o
l
a
t
i
o
n
f
r
o
m
t
h
e
7
"
p
r
o
d
u
c
t
i
o
n
C
S
G
s
h
o
e
ba
c
k
t
o
t
h
e
w
i
n
d
o
w
.
T
h
e
p
a
r
e
n
t
w
e
l
l
9
-
5
/
8
"
P
r
o
d
u
c
t
i
o
n
C
S
G
j
o
b
w
a
s
c
o
n
f
i
r
m
e
d
s
e
p
e
r
a
t
e
l
y
o
n
r
o
w
a
b
o
v
e
.
D
r
i
l
l
e
d
8
.
5
"
h
o
l
e
.
La
n
d
e
d
7
"
C
S
G
a
t
8
9
8
5
.
1
7
5
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
1
7
0
v
o
l
u
m
e
n
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
O
p
e
r
a
b
l
e
P
r
o
d
u
c
e
r
.
FR
A
C
–
P
u
t
R
i
v
e
r
W
e
s
t
e
r
n
L
o
b
e
We
l
l
:
1
5
-
3
2
C
PT
D
:
2
1
7
-
1
0
4
AP
I
:
5
0
-
0
2
9
-
2
2
4
6
2
-
0
3
Pa
g
e
1
7
We
l
l
Na
m
e
PT
D
A
P
I
Di
s
t
a
n
c
e
/
St
a
t
u
s
To
p
P
u
t
MD
f
e
e
t
To
p
P
u
t
TV
D
s
s
f
e
e
t
TO
C
MD
f
e
e
t
TO
C
TV
D
s
s
f
e
e
t
Zo
n
a
l
Is
o
l
a
t
i
o
n
Co
m
m
e
n
t
s
15
-
2
4
19
1
-
1
2
8
5
0
-
0
2
9
-
2
2
2
2
3
-
0
0
-
0
0
9
4
0
'
/
P
&
A
'
d
8
,
0
7
6
-
7
,
8
6
6
3
,
5
3
0
-
3
,
4
5
9
C
l
o
s
e
d
Dr
i
l
l
e
d
8
-
1
/
2
"
h
o
l
e
.
L
a
n
d
e
d
7
"
C
S
G
a
t
8
3
4
4
'
.
1
5
9
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
1
5
6
b
b
l
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
C
e
m
e
n
t
br
o
u
g
h
t
u
p
a
v
o
e
9
-
5
/
8
"
C
S
G
s
h
o
e
.
C
a
l
l
i
n
g
T
O
C
a
t
9
-
5
/
8
"
C
S
G
s
h
o
e
a
t
3
5
3
0
'
.
F
u
l
l
P
&
A
c
o
m
p
l
e
t
e
d
4
/
1
/
2
1
.
15
-
2
6
19
1
-
1
5
0
5
0
-
0
2
9
-
2
2
2
3
5
-
0
0
-
0
0
9
3
0
'
/
O
p
e
r
a
b
l
e
8
,
0
1
4
-
7
,
8
6
1
2
,
1
2
3
-
2
,
0
5
4
C
l
o
s
e
d
Vo
l
u
m
e
t
r
i
c
T
O
C
f
o
r
9
-
5
/
8
"
P
r
o
d
u
c
t
i
o
n
C
S
G
p
r
i
m
a
r
y
j
o
b
a
p
p
e
a
r
s
t
o
h
a
v
e
c
l
o
s
e
d
t
h
e
1
3
-
3
/
8
"
S
u
r
f
a
c
e
C
S
G
s
h
o
e
-
s
u
p
p
o
r
t
e
d
m
y
pa
s
s
i
n
g
M
I
T
-
O
A
'
s
.
B
a
c
k
e
d
o
u
t
2
2
.
5
b
b
l
s
f
r
o
m
P
r
i
m
a
r
y
b
e
h
i
n
d
p
i
p
e
T
O
C
c
a
l
c
s
b
a
s
e
d
o
f
f
o
f
w
o
r
k
s
t
r
i
n
g
t
a
g
o
f
8
2
5
0
'
i
n
s
i
d
e
9
-
5/
8
"
C
S
G
.
1
2
.
2
5
"
h
o
l
e
d
r
i
l
l
e
d
.
L
a
n
d
e
d
C
S
G
a
t
8
5
5
7
.
4
8
9
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
4
6
6
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
Sh
a
r
e
s
s
a
m
e
p
a
r
e
n
t
w
e
l
l
b
o
r
e
a
c
r
o
s
s
P
u
t
R
i
v
e
r
i
n
t
e
r
v
a
l
w
i
t
h
1
5
-
2
6
A
a
n
d
1
5
-
2
6
B
.
1
5
-
2
6
B
i
s
a
n
o
p
e
r
a
b
l
e
p
r
o
d
u
c
e
r
.
15
-
2
7
19
2
-
0
0
6
5
0
-
0
2
9
-
2
2
2
4
3
-
0
0
-
0
0
2
2
6
0
'
/
P
&
A
'
d
8
,
1
5
7
-
7
,
8
7
6
2
,
1
8
2
-
2
,
1
2
1
C
l
o
s
e
d
Vo
l
u
m
e
t
r
i
c
T
O
C
f
o
r
9
-
5
/
8
"
P
r
o
d
u
c
t
i
o
n
C
S
G
p
r
i
m
a
r
y
j
o
b
a
p
p
e
a
r
s
t
o
h
a
v
e
c
l
o
s
e
d
t
h
e
1
3
-
3
/
8
"
S
u
r
f
a
c
e
C
S
G
s
h
o
e
-
s
u
p
p
o
r
t
e
d
m
y
pa
s
s
i
n
g
M
I
T
-
O
A
'
s
.
1
2
.
2
5
"
h
o
l
e
d
r
i
l
l
e
d
.
L
a
n
d
e
d
C
S
G
a
t
8
6
1
0
'
.
4
7
4
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
4
6
6
b
b
l
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
be
h
i
n
d
p
i
p
e
.
P
a
r
e
n
t
w
e
l
l
b
o
r
e
c
o
n
t
a
i
n
i
n
g
P
u
t
R
i
v
e
r
w
a
s
P
&
A
'
d
i
n
p
r
e
p
a
r
a
t
i
o
n
f
o
r
M
a
y
2
0
1
0
1
5
-
2
7
A
r
o
t
a
r
y
s
i
d
e
t
r
a
c
k
.
15
-
3
2
19
4
-
0
4
7
5
0
-
0
2
9
-
2
2
4
6
2
-
0
0
-
0
0
0
'
/
O
p
e
r
a
b
l
e
7
,
9
5
1
-
7
,
8
7
8
5
,
2
1
0
-
5
,
1
4
1
C
l
o
s
e
d
Dr
i
l
l
e
d
1
2
-
1
/
2
"
H
o
l
e
.
L
a
n
d
e
d
C
S
G
a
t
8
2
3
7
'
.
P
u
m
p
e
d
2
4
1
b
b
l
s
c
e
m
e
n
t
,
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
2
2
6
b
b
l
s
b
e
h
i
n
d
p
i
p
e
.
1
5
-
3
2
sh
a
r
e
s
t
h
e
s
a
m
e
p
a
r
e
n
t
w
e
l
l
b
o
r
e
a
c
r
o
s
s
t
h
e
P
u
t
R
i
v
e
r
i
n
t
e
r
v
a
l
a
s
1
5
-
3
2
A
,
1
5
-
3
2
B
,
a
n
d
1
5
-
3
2
C
.
1
5
-
3
2
C
i
s
t
h
e
w
e
l
l
b
o
r
e
t
h
a
t
w
e
a
r
e
f
r
a
c
t
u
r
i
n
g
.
T
h
e
i
v
i
s
h
a
k
i
s
P
&
A
'
d
.
O
p
e
r
a
b
l
e
p
r
o
d
u
c
e
r
.
15
-
3
9
19
4
-
1
1
5
5
0
-
0
2
9
-
2
2
5
0
3
-
0
0
-
0
0
6
6
0
'
/
P
&
A
'
d
7
,
9
6
8
-
7
,
8
5
7
6
,
4
3
8
-
6
,
3
4
2
C
l
o
s
e
d
Dr
i
l
l
e
d
1
2
-
1
/
4
"
h
o
l
e
.
L
a
n
d
e
d
9
-
5
/
8
"
C
S
G
a
t
8
3
2
6
'
.
1
4
3
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
1
3
7
b
b
l
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
1
5
-
13
w
a
s
P
&
A
'
d
i
n
p
r
e
p
f
o
r
1
5
-
3
9
A
r
i
g
s
i
d
e
t
r
a
c
k
.
15
-
3
9
A
20
6
-
0
8
6
5
0
-
0
2
9
-
2
2
5
0
3
-
0
1
-
0
0
8
9
0
'
/
O
p
e
r
a
b
l
e
8
,
0
5
9
-
7
,
9
4
3
4
,
3
0
7
-
4
,
2
4
2
C
l
o
s
e
d
Dr
i
l
l
e
d
8
.
5
"
h
o
l
e
.
L
a
n
d
e
d
c
a
s
i
n
g
a
t
8
3
2
0
'
.
P
u
m
p
e
d
1
5
0
b
b
l
s
c
e
m
e
n
t
,
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
1
4
8
b
b
l
s
b
e
h
i
n
d
p
i
p
e
.
1
1
8
b
b
l
vo
l
u
m
e
n
e
e
d
e
d
t
o
1
5
-
3
9
p
a
r
e
n
t
w
i
n
d
o
w
a
t
4
3
0
7
'
.
C
e
m
e
n
t
r
e
t
u
r
n
s
s
e
e
n
a
t
s
u
r
f
a
c
e
w
h
e
n
C
B
U
a
f
t
e
r
s
e
t
t
i
n
g
7
"
L
T
P
.
C
a
l
l
i
n
g
T
O
C
at
w
i
n
d
o
w
.
1
5
-
3
9
A
i
s
a
n
O
p
e
r
a
b
l
e
p
r
o
d
u
c
e
r
.
15
-
4
3
19
6
-
0
8
3
5
0
-
0
2
9
-
2
2
6
7
6
-
0
0
-
0
0
19
5
0
'
/
N
o
t
Op
e
r
a
b
l
e
8,
2
9
3
-
7
,
9
4
0
7
,
2
8
1
-
7
,
0
0
5
C
l
o
s
e
d
Dr
i
l
l
e
d
8
.
5
"
h
o
l
e
.
L
a
n
d
e
d
C
S
G
a
t
8
,
6
0
5
'
.
P
u
m
p
e
d
4
2
b
b
l
s
c
e
m
e
n
t
,
3
9
b
b
l
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
1
5
-
4
3
i
s
cl
a
s
s
i
f
i
e
d
a
s
N
o
t
O
p
e
r
a
b
l
e
.
I
t
h
a
s
a
k
n
o
w
n
P
C
l
e
a
k
t
h
a
t
d
u
m
p
f
l
o
o
d
e
d
C
r
e
t
e
c
o
u
s
i
n
t
o
t
h
e
I
v
i
s
h
a
k
l
a
t
e
r
a
l
t
h
r
u
a
w
a
s
h
e
d
o
u
t
GL
M
.
T
h
e
w
e
l
l
s
t
o
p
p
e
d
d
u
m
p
f
l
o
o
d
i
n
g
a
f
t
e
r
e
n
o
u
g
h
s
a
n
d
f
i
l
l
e
d
u
p
t
h
e
w
e
l
l
b
o
r
e
.
I
t
'
s
t
e
m
p
r
a
r
i
l
y
i
s
o
l
a
t
e
d
w
i
t
h
a
C
B
P
a
n
d
t
h
e
r
e
i
s
a
su
n
d
r
y
h
a
s
b
e
e
n
s
u
b
m
i
t
t
e
d
t
o
p
e
r
f
o
r
m
a
f
u
l
l
P
&
A
a
s
p
a
r
t
o
f
t
h
e
t
h
e
2
0
2
6
P
&
A
c
a
m
p
a
i
g
n
l
i
s
t
f
o
r
P
r
u
d
h
o
e
.
15
-
4
7
19
5
-
1
7
4
5
0
-
0
2
9
-
2
2
6
1
7
-
0
0
-
0
0
11
5
0
'
/
Su
s
p
e
n
d
e
d
8,
2
6
1
-
7
,
8
7
5
5
,
9
5
9
-
5
,
8
5
6
C
l
o
s
e
d
Dr
i
l
l
e
d
8
.
5
"
h
o
l
e
.
L
a
n
d
e
d
C
S
G
a
t
8
7
3
4
.
8
5
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
8
1
b
b
l
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
S
u
s
p
e
n
d
e
d
.
P&
A
'
d
t
o
4
4
6
8
'
M
D
.
15
-
4
8
19
5
-
2
0
8
5
0
-
0
2
9
-
2
2
6
3
5
-
0
0
-
0
0
6
9
0
'
/
S
u
s
p
e
n
d
e
d
8
,
0
7
6
-
7
,
8
5
8
7
,
0
3
9
-
6
,
9
4
7
C
l
o
s
e
d
Dr
i
l
l
e
d
8
.
5
"
h
o
l
e
.
L
a
n
d
e
d
C
S
G
a
t
8
5
5
4
'
.
8
5
b
b
l
s
c
e
m
e
n
t
p
u
m
p
e
d
,
8
4
.
5
b
b
l
s
v
o
l
u
m
e
t
r
i
c
a
l
l
y
c
a
l
c
u
l
a
t
e
d
b
e
h
i
n
d
p
i
p
e
.
S
u
s
p
e
n
d
e
d
.
We
l
l
h
a
s
a
r
e
s
e
r
v
o
i
r
P
&
A
.
A
n
e
x
t
e
n
d
e
d
l
i
n
e
r
t
o
p
o
f
3
-
1
/
2
c
h
r
o
m
e
f
l
u
s
h
j
o
i
n
t
p
i
p
e
w
a
s
a
l
s
o
r
u
n
f
r
o
m
t
h
e
l
i
n
e
r
t
o
p
u
p
t
o
~
4
0
0
0
MD
t
o
c
o
v
e
r
a
l
l
t
h
e
k
n
o
w
n
t
u
b
i
n
g
d
a
m
a
g
e
.
A
P
C
l
e
a
k
a
t
5
2
7
3
'
w
a
s
f
o
u
n
d
i
n
2
0
1
6
,
a
n
I
A
C
M
T
p
l
u
g
w
a
s
p
u
m
p
e
d
i
n
2
0
2
1
t
o
co
v
e
r
t
h
e
P
C
l
e
a
k
f
r
o
m
2
7
6
0
'
-
6
6
6
0
'
.
Vo
l
u
m
t
e
r
i
c
T
O
C
c
a
l
c
u
l
a
t
e
d
u
s
i
n
g
3
0
%
w
a
s
h
o
u
t
a
n
d
b
y
r
e
m
o
v
i
n
g
s
h
o
e
t
r
a
c
t
a
n
d
c
e
m
e
n
t
t
a
g
d
e
p
t
h
f
r
o
m
t
o
t
a
l
s
l
u
r
r
y
p
u
m
p
e
d
.
A
l
l
w
e
l
l
s
o
n
l
i
s
t
a
r
e
p
r
o
d
u
c
e
r
s
,
n
o
i
n
j
e
c
t
o
r
s
w
i
t
h
i
n
A
O
R
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 18
SECTION 11 - LOCATION OF, ORIENTATION OF, AND GEOLOGICAL DATA FOR FAULTS AND
FRACTURES THAT MAY TRANSECT THE CONFING ZONES (20 AAC 25.283, a, 11):
Hilcorp’s technical analysis based on seismic, well, and other subsurface information available indicated
that there are no faults transecting the confining zones within the area of review.
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 19
SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM (20 AAC 25.283, a, 12):
Proposed Procedure:
1. Conduct safety meeting, inspect location, and review 10-403.
2. Ensure all pre-frac well work has been completed, and the tubing & IA are freeze protected.
3. MIRU frac equipment and associated frac tanks.
4. Pressure test surface lines to at least 7,790 psi.
5. Test IA Pop-off system to ensure functioning properly. IA Pop-off to be set at 2,995 psi.
6. Bring IA pressure up to a hold pressure of 2,700 psi.
7. Pump the fracture stimulation per the proposed pump schedule below. Maximum allowable
treating pressure is 6,790 psi.
8. RDMO frac equipment. Ensure tubing is freeze protected.
9. Return the well to production / flowback post slickline gas lift and contingent coiled tubing
cleanout.
Fracture Stimulation Pump Schedule:
There are two overpressure devices that protect the surface equipment and wellbore from
overpressure. 1) Each individual frac pump has an electronic kickout that will shift the pumps into
neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are
staggered between 90% and 95% of the maximum allowable treating pressure. 2) There is a manual
kickout that is controlled from the frac van that can shift all pumps into neutral. All three of these
shutdown systems will be individually tested prior to high pressure pumping operations. Additionally,
the treating pressure, IA pressure and OA pressure will be monitored in the frac van.
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 20
Frac Dimensions:
Frac #MD Location, ft TVDss top, ft TVDss Bottom, ft Frac Half-Length, ft
1 7,960’-7,995’-7,887 -7,922 ~281’
Frac Modelling:
Maximum Anticipated Treating Pressure: ~5,600 psi
Surface pressure and fracture dimensions were modeled using 15-47 logs
Disclaimer Notice:
This model was generated using commercially available modeling software and is based on engineering
estimates of reservoir properties. Hilcorp is providing these model results as an informed prediction of
actual results. Because of the inherent limitations in assumptions required to generate this model, and
for other reasons, actual results may differ from the model results.
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 21
Pre-Job Anticipated Chemicals to be pumped:
Additive Additive Description
F103 Surfactant 1.0 Gal/mGal 71.9 gal
J475 Breaker J475 6.0 lb/mGal 431.4 lbm
J511 Stabilizing Agent 2.0 lb/mGal 143.8 lbm
J532 Crosslinker 2.5 Gal/mGal 179.8 gal
J580 Gel J580 30.0 lb/mGal 2,157.1 lbm
L065 Scale Inhibitor 1.0 Gal/mGal 71.9 gal
L071 Clay Control Agent 2.0 Gal/mGal 143.8 gal
M275 Bactericide 0.5 lb/mGal 36.0 lbm
S522-1620 Propping Agent varied concentrations 60,000.0 lbm
S526-1620 Propping Agent varied concentrations 95,000.0 lbm
~ 79 %
~ 21 %
< 1 %
< 1 %
< 0.1 %
< 0.1 %
< 0.1 %
< 0.1 %
< 0.1 %
< 0.1 %
< 0.1 %
< 0.1 %
< 0.1 %
< 0.1 %
< 0.01 %
< 0.01 %
< 0.01 %
< 0.01 %
< 0.01 %
< 0.001 %
< 0.001 %
< 0.001 %
< 0.001 %
< 0.001 %
< 0.001 %
< 0.001 %
< 0.0001 %
< 0.0001 %
< 0.0001 %
< 0.0001 %
< 0.0001 %
< 0.0001 %
100 %
64-19-7 Acetic acid (impurity)
Total
* M ix water is supplied by the client. Schlumberger has performed no analysis of the water and cannot provide a breakdown of co mponents that may have been added to the water by third-
parties.
* The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to GRC - Chemicals as of
the date of the document was produced. Any new updates will not be reflected in this document.
14464-46-1 Cristobalite
14808-60-7 Quartz, Crystalline silica
127-08-2 Acetic acid, potassium salt (impurity)
111-46-6 2,2''-oxydiethanol (impurity)
1310-73-2 Sodium hydroxide (impurity)
7447-40-7 Potassium chloride (impurity)
14807-96-6 Magnesium silicate hydrate (talc)
9002-84-0 poly(tetrafluoroethylene)
7786-30-3 Magnesium chloride
7631-86-9 Silicon Dioxide (Impurity)
10377-60-3 Magnesium nitrate
55965-84-9 5-chloro-2-methyl-4-isothiazolin-3-one and 2-methyl-4-isothiazolin-3-one
91053-39-3 Diatomaceous earth, calcined
10043-52-4 Calcium chloride
112-42-5 1-undecanol (impurity)
25038-72-6 Vinylidene chloride/methylacrylate copolymer
68131-39-5 Ethoxylated Alcohol
7647-14-5 Sodium chloride
67-63-0 Propan-2-ol
111-76-2 2-butoxyethanol
34398-01-1 Ethoxylated C11 Alcohol
50-70-4 Sorbitol
107-21-1 Ethylene Glycol
129898-01-7 2-Propenoic acid, polymer with sodium phosphinate
56-81-5 1, 2, 3 - Propanetriol
7727-54-0 Diammonium peroxodisulphate
1303-96-4 Sodium tetraborate decahydrate
66402-68-4 Ceramic materials and wares, chemicals
9000-30-0 Guar gum
67-48-1 2-hydroxy-N,N,N-trimethylethanaminium chloride
CAS Number Chemical Name Mass Fraction
-Water (Including Mix Water Supplied by Client)*
YF130ST:WF130 71,904 gal
† Proprietary Technology
The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client.
Fluid Name & Volume Concentration Volume
FRAC – Put River Western Lobe
Well: 15-32C
PTD: 217-104
API: 50-029-22462-03
Page 22
SECTION 13 - POST FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN (20 AAC
25.283, a, 13):
After the fracture stimulation and potentially during the post frac coil fill cleanout, the well will be put
on production through a portable well test separator. All liquids will be captured and either sent to
production facilities or diverted to flowback tanks if solids percentage becomes too high for our
production facility to manage.
The initial flowback period is intended to produce back the fracture fluids to tanks as quickly as possible,
until the well is produced less than 0.5% solids, at which time the produced fluids meet the FS3
acceptance criteria for start-up. There will be a tank farm on pad to store the produced fluids from
flowback operations.
The flowback fluids not suitable for FS3 processing will be hauled to another facility’s slop tank for
additional settling time and/or disposal. Hilcorp will work to separate and recover fluid that meets the
facility specification for the flowback fluids. A fluid manifest form will be completed for each load
trucked offsite.
