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HomeMy WebLinkAbout223-059From:Guhl, Meredith D (OGC)
To:"Joseph Lastufka"
Subject:Permit Expired: PBU S-103A, TPD 223-059
Date:Wednesday, December 10, 2025 2:39:00 PM
Hello Joe,
The following Permit to Drill, issued to Hilcorp, has expired under Regulation 20 AAC 25.005
(g). The PTD will be marked expired in the AOGCC database.
PBU S-103A, PTD 223-059, Issued 28 Aug 2023
Please let me know if you have any questions or concerns.
Thank you,
Meredith
Meredith Guhl (she/her)
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
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 Meredith Guhl
at 907-793-1235 or meredith.guhl@alaska.gov.
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 M. Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK, 99503
Re: Prudhoe Bay, Aurora Oil Pool, PBU S-103A
Hilcorp Alaska, LLC
Permit to Drill Number: 223-059
Surface Location: 4581' FSL, 4497' FEL, Sec. 35, T12N, R12E, UM, AK
Bottomhole Location: 1077' FNL, 1378' FWL, Sec. 27, T12N, R12E, 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,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this ___ day of August 2023.
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.08.28 15:32:09
-08'00'
1a.
Contact Name:Trevor Hyatt
Contact Email:trevor.hyatt@hilcorp.comAuthorized Name: Monty Myers
Authorized Title:Drilling Manager
Authorized Signature:
Contact Phone:907-777-8395
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
Service - WAG
5
1c. Specify if well is proposed for:
Development - Oil Service - Winj
Multiple Zone Exploratory - Oil
5
Gas Hydrates
Geothermal
Hilcorp North Slope, LLC Bond No. 107205344
11.Well Name and Number:
PBU S-103A
TVD:12155'6755'
12. Field/Pool(s):
PRUDHOE BAY, AURORA OILMD:
ADL 028257 & 028258
83-47 September 15, 2023
4a.
Surface:
Top of Productive Horizon:
Total Depth:
4581' FSL, 4497' FEL, Sec. 35, T12N, R12E, UM, AK
933' FNL, 2421' FEL, Sec. 27, T12N, R12E, UM, AK
Kickoff Depth:9558 feet
Maximum Hole Angle: 94 degrees
Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Downhole:Surface:2951 2292
17.Deviated wells:16.
Surface: x-y- Zone -618930 5980775 4
10. KB Elevation above MSL:
GL Elevation above MSL:
feet
feet
64.61
36
15.Distance to Nearest Well
Open to Same Pool:
Cement Quantity, c.f. or sacks
MD
Casing Program:
9400'6572'
19.PRESENT WELL CONDITION SUMMARY
Production
80 ~260 sx Arctic Set
10078 7008 None 9972 6940 None
29 - 109
Surface 562 sx AS Lite III, 260 sx Class G
6652 - 6850
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#
3059
9524 - 9832
50-029-22981-01-00
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
1077' FNL, 1378' FWL, Sec. 27, T12N, R12E, UM, AK
Time v. Depth Plot 5 5 Drilling Program
5430
(To be completed for Redrill and Re-Entry Operations)
20"
9-5/8"
Hyd 511
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.
5120
1220
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
29 - 109
28 - 3087 28 - 2830
10030 7"582 sx Class G 27 - 10057 27 - 6994
Liner
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.
12155'6755'97 sx Class G3-1/4"2-3/8"L-80 2755'
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g))
7.7.2023
By Grace Christianson at 2:20 pm, Jul 10, 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: 2023.07.07 10:47:00 -08'00'
Monty M
Myers
2292
223-059
BOPE test to 3500 psi.
Variance to 20 AAC 25.112(i) Approved for alternate plug
placement with fully cemented production liner in
upcoming sidetrack.
A.Dewhurst 15 AUG 2023
DSR-7/12/23MGR31JULY2023A.Dewhurst 16 AUG 2023*&:
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.08.28 15:32:48 -08'00'
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To: Alaska Oil & Gas Conservation Commission
From: Trevor Hyatt
Drilling Engineer
Date: July 6, 2023
Re: PBU S-103A Permit to Drill
Approval is requested for drilling a CTD sidetrack lateral from well PBU S-103 with the
Nabors CDR2 Coiled Tubing Drilling.
Proposed plan for S-103A Injector:
See S-103 Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to
drift for whipstock, caliper and MIT. Service coil or Eline will mill four XN nipples to 2.80". E-Line will set a 3-
1/2"x7" HEW (whipstock) with the DPU (for slow set).
A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the
well. If unable to set pre-rig, a 3-1/2"x7" HEW whipstock will be set with the rig. A 2.80" window +10’ of formation
will be milled out of the 7” casing. The well will kick off drilling and land in the Kuparuk. The lateral will continue in
the Kuparuk to TD. The proposed sidetrack will be completed with a 2-3/8” L-80 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 Kuparuk perfs.
Hilcorp requests to pre-produce S-103A for up to 30 days.
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 S-103 Sundry submitted in concert with this request for full details.
x General work scope of Pre-Rig work:
1. Coil or E-Line: Mill four XN nipples
2. Slickline: Dummy WS drift and Caliper
3. Fullbore: MITs
4. E-line: Set Whipstock
Rig Work - (Estimated to start in September 2023):
1. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,292 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” HEW (whipstock) – only if not set pre-rig
a. Set top of whipstock at 9,554’ MD
b. Set highside (0° ROHS)
3. Mill 2.80” single string window (out of 7”) plus 10’ of rathole
a. Top of window (whipstock pinch point) at 9,558’ MD.
b. Hold 11.0 ppg MPD while milling window
4. Drill – Lateral
a. 2-3/8” BHA with GR/RES / Bi-center Bit (3.25”)
b. 15° DLS lateral section – 2,597’ MD / Planned TD 12,155’ MD
c. Drill with a constant bottom hole pressure for entire sidetrack
d. Pressure deployment will be utilized
e. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run
pre-produce S-103A for up to 30 days.
PTD 223-059
Sundry 323-377
f. No flow test prior to laying down drilling BHA
5. Run and Cement 2-3/8” L-80 solid liner
a. Have 2” safety joint with TIW valve ready to be picked up while running liner
b. Release from liner and come out of hole.
c. Make up cementing BHA and sting into liner shoe. Swap the well over to 2% KCl.
d. Cement liner with 21.5 bbls, 15.3 ppg Class G (TOC to TOL).*
e. Freeze protect well from ~2200’ TVD (min)
f. RDMO
Post Rig:
1. V: Valve & tree work
2. C: Post rig perforate ~500’ (see future perf sundry – only if extended perforating is utilized)
3. S: Set live LGLVs (if necessary)
4. S: Set LTP* (if necessary)
5. 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 (9,558’ MD - 6,675’ TVD)
Pumps On Pumps Off
A Target BHP at Window (ppg)3,818 psi 3,818 psi
11
B Annular friction - ECD (psi/ft)822 psi 0 psi
0.09
C Mud Hydrostatic (ppg)2,985 psi 2,985 psi
8.6
B+C Mud + ECD Combined 3,807 psi 2,985 psi
(no choke pressure)
A-(B+C)Choke Pressure Required to Maintain 11 psi 833 psi
Target BHP at window and deeper
Operation Details:
Reservoir Pressure:
x The estimated reservoir pressure is expected to be 2,951 psi at 6,600’ TVD (8.6 ppg equivalent).
x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,292 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 8.4 ppg KWF to be used for liner deployment. Will target 11.0 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#, L-80 solid/cemented liner: 9,400’ MD – 12,155’ MD (2,755’ 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 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 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 94°. Inclination at kick off point is 50°.
x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
x Distance to nearest property line – 5,340’
x Distance to nearest well within pool – 1220’
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 ~500’ perforated post rig (See future perforating sundry request – only if extended perforating is used)
x 1-11/16” Perf Guns at 6 spf
x If post rig extended perforating with service coil is not an option, the well will be perforated with the rig or
post rig under this PTD.
x The well will be perforated between the whipstock and TD of the newly drilled CTD well, completely in the
Kuparuk pool.
Anti-Collision Failures:
x No failures on WP04
Hazards:
x PBU S-pad is an H2S pad. The highest recorded H2S well on the pad was from S-27B (140 ppm) in
2012. Last recorded H2S on S-103 was 40 ppm in 2023.
x Two fault crossing expected.
x Medium lost circulation risk.
Trevor Hyatt CC: Well File
Drilling Engineer Joseph Lastufka
907-223-3087
200-168
2-3/8"LNR, 4.7#, L-80, Hyd 511 12155'
Milled to 2.80"
3-1/2" x 7" FLOTHRU WS (__, __, __)
MILLOUT WINDOW (S-103A) 9558' - ____
A
___-___
-01-00
9556'
9400'2-3/8" Top of Liner / Cement
PROPOSED A
200-168
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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
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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 S-103A
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e
d
p
r
o
p
e
r
d
i
s
t
a
n
c
e
f
r
o
m
d
r
i
l
l
i
n
g
u
n
i
t
b
o
u
n
d
a
r
y
NA
6
W
e
l
l
l
o
c
a
t
e
d
p
r
o
p
e
r
d
i
s
t
a
n
c
e
f
r
o
m
o
t
h
e
r
w
e
l
l
s
Ye
s
7
S
u
f
f
i
c
i
e
n
t
a
c
r
e
a
g
e
a
v
a
i
l
a
b
l
e
i
n
d
r
i
l
l
i
n
g
u
n
i
t
Ye
s
8
I
f
d
e
v
i
a
t
e
d
,
i
s
w
e
l
l
b
o
r
e
p
l
a
t
i
n
c
l
u
d
e
d
Ye
s
9
O
p
e
r
a
t
o
r
o
n
l
y
a
f
f
e
c
t
e
d
p
a
r
t
y
Ye
s
10
O
p
e
r
a
t
o
r
h
a
s
a
p
p
r
o
p
r
i
a
t
e
b
o
n
d
i
n
f
o
r
c
e
Ye
s
11
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
i
t
h
o
u
t
c
o
n
s
e
r
v
a
t
i
o
n
o
r
d
e
r
Ye
s
12
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
i
t
h
o
u
t
a
d
m
i
n
i
s
t
r
a
t
i
v
e
a
p
p
r
o
v
a
l
Ye
s
13
C
a
n
p
e
r
m
i
t
b
e
a
p
p
r
o
v
e
d
b
e
f
o
r
e
1
5
-
d
a
y
w
a
i
t
Ye
s
A
I
O
2
2
F
14
W
e
l
l
l
o
c
a
t
e
d
w
i
t
h
i
n
a
r
e
a
a
n
d
s
t
r
a
t
a
a
u
t
h
o
r
i
z
e
d
b
y
I
n
j
e
c
t
i
o
n
O
r
d
e
r
#
(
p
u
t
I
O
#
i
n
c
o
m
m
e
n
t
s
)
(
F
o
r
s
Ye
s
15
A
l
l
w
e
l
l
s
w
i
t
h
i
n
1
/
4
m
i
l
e
a
r
e
a
o
f
r
e
v
i
e
w
i
d
e
n
t
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
Ye
s
T
o
b
e
p
r
e
-
p
r
o
d
u
c
e
d
f
o
r
u
p
t
o
3
0
d
a
y
s
16
P
r
e
-
p
r
o
d
u
c
e
d
i
n
j
e
c
t
o
r
:
d
u
r
a
t
i
o
n
o
f
p
r
e
-
p
r
o
d
u
c
t
i
o
n
l
e
s
s
t
h
a
n
3
m
o
n
t
h
s
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
NA
17
N
o
n
c
o
n
v
e
n
.
g
a
s
c
o
n
f
o
r
m
s
t
o
A
S
3
1
.
0
5
.
0
3
0
(
j
.
1
.
A
)
,
(
j
.
2
.
A
-
D
)
Ye
s
T
h
i
s
w
e
l
l
i
s
a
i
n
z
o
n
e
C
T
D
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
e
s
s
u
r
e
i
n
t
e
g
r
i
t
y
.
18
C
o
n
d
u
c
t
o
r
s
t
r
i
n
g
p
r
o
v
i
d
e
d
Ye
s
T
h
i
s
w
e
l
l
i
s
a
i
n
z
o
n
e
C
T
D
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
e
s
s
u
r
e
i
n
t
e
g
r
i
t
y
.
19
S
u
r
f
a
c
e
c
a
s
i
n
g
p
r
o
t
e
c
t
s
a
l
l
k
n
o
w
n
U
S
D
W
s
Ye
s
T
h
i
s
w
e
l
l
i
s
a
i
n
z
o
n
e
C
T
D
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
e
s
s
u
r
e
i
n
t
e
g
r
i
t
y
.
20
C
M
T
v
o
l
a
d
e
q
u
a
t
e
t
o
c
i
r
c
u
l
a
t
e
o
n
c
o
n
d
u
c
t
o
r
&
s
u
r
f
c
s
g
Ye
s
T
h
i
s
w
e
l
l
i
s
a
i
n
z
o
n
e
C
T
D
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
e
s
s
u
r
e
i
n
t
e
g
r
i
t
y
.
21
C
M
T
v
o
l
a
d
e
q
u
a
t
e
t
o
t
i
e
-
i
n
l
o
n
g
s
t
r
i
n
g
t
o
s
u
r
f
c
s
g
Ye
s
T
h
i
s
w
e
l
l
i
s
a
i
n
z
o
n
e
C
T
D
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
e
s
s
u
r
e
i
n
t
e
g
r
i
t
y
.
22
C
M
T
w
i
l
l
c
o
v
e
r
a
l
l
k
n
o
w
n
p
r
o
d
u
c
t
i
v
e
h
o
r
i
z
o
n
s
Ye
s
F
u
l
l
y
c
e
m
e
n
t
e
d
p
r
o
d
u
c
t
i
o
n
l
i
n
e
r
.
P
a
r
e
n
t
w
e
l
l
i
s
o
l
a
t
e
s
t
h
e
r
e
s
e
r
v
o
i
r
.
23
C
a
s
i
n
g
d
e
s
i
g
n
s
a
d
e
q
u
a
t
e
f
o
r
C
,
T
,
B
&
p
e
r
m
a
f
r
o
s
t
Ye
s
C
D
R
2
h
a
s
a
d
e
q
u
a
t
e
t
a
n
k
a
g
e
a
n
d
g
o
o
d
t
r
u
c
k
i
n
g
s
u
p
p
o
r
t
.
24
A
d
e
q
u
a
t
e
t
a
n
k
a
g
e
o
r
r
e
s
e
r
v
e
p
i
t
Ye
s
S
u
n
d
r
y
3
2
3
-
3
7
7
25
I
f
a
r
e
-
d
r
i
l
l
,
h
a
s
a
1
0
-
4
0
3
f
o
r
a
b
a
n
d
o
n
m
e
n
t
b
e
e
n
a
p
p
r
o
v
e
d
Ye
s
H
a
l
l
i
b
u
r
t
o
n
C
o
l
l
i
s
i
o
n
s
c
a
n
i
d
e
n
t
i
f
i
e
s
n
o
c
l
o
s
e
a
p
p
r
o
a
c
h
e
s
.
26
A
d
e
q
u
a
t
e
w
e
l
l
b
o
r
e
s
e
p
a
r
a
t
i
o
n
p
r
o
p
o
s
e
d
Ye
s
T
h
i
s
w
e
l
l
i
s
a
i
n
z
o
n
e
C
T
D
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
e
s
s
u
r
e
i
n
t
e
g
r
i
t
y
.
27
I
f
d
i
v
e
r
t
e
r
r
e
q
u
i
r
e
d
,
d
o
e
s
i
t
m
e
e
t
r
e
g
u
l
a
t
i
o
n
s
Ye
s
M
P
D
b
u
t
r
e
s
e
r
v
o
i
r
p
r
e
s
s
u
r
e
b
e
l
o
w
w
a
t
e
r
g
r
a
d
i
e
n
t
.
28
D
r
i
l
l
i
n
g
f
l
u
i
d
p
r
o
g
r
a
m
s
c
h
e
m
a
t
i
c
&
e
q
u
i
p
l
i
s
t
a
d
e
q
u
a
t
e
Ye
s
C
T
P
a
c
k
o
f
f
,
f
l
o
w
c
r
o
s
s
,
a
n
n
u
l
a
r
,
b
l
i
n
d
s
h
e
a
r
,
C
T
p
i
p
e
s
l
i
p
s
,
f
l
o
w
c
r
o
s
s
,
B
H
A
p
i
p
e
s
l
i
p
s
,
C
T
p
i
p
e
s
l
i
p
s
29
B
O
P
E
s
,
d
o
t
h
e
y
m
e
e
t
r
e
g
u
l
a
t
i
o
n
Ye
s
7
-
1
/
1
6
"
5
0
0
0
p
s
i
s
t
a
c
k
p
r
e
s
s
u
r
e
t
e
s
t
e
d
t
o
3
5
0
0
p
s
i
.
30
B
O
P
E
p
r
e
s
s
r
a
t
i
n
g
a
p
p
r
o
p
r
i
a
t
e
;
t
e
s
t
t
o
(
p
u
t
p
s
i
g
i
n
c
o
m
m
e
n
t
s
)
Ye
s
F
l
a
n
g
e
d
c
h
o
k
e
a
n
d
k
i
l
l
l
i
n
e
s
b
e
t
w
e
e
n
d
u
a
l
c
o
m
b
i
'
s
w
r
e
m
o
t
e
c
h
o
k
e
31
C
h
o
k
e
m
a
n
i
f
o
l
d
c
o
m
p
l
i
e
s
w
/
A
P
I
R
P
-
5
3
(
M
a
y
8
4
)
Ye
s
32
W
o
r
k
w
i
l
l
o
c
c
u
r
w
i
t
h
o
u
t
o
p
e
r
a
t
i
o
n
s
h
u
t
d
o
w
n
Ye
s
P
B
U
S
-
p
a
d
i
s
a
n
d
H
2
S
p
a
d
>
1
0
0
p
p
m
.
M
o
n
i
t
o
r
i
n
g
w
i
l
l
b
e
r
e
q
u
i
r
e
d
.
33
I
s
p
r
e
s
e
n
c
e
o
f
H
2
S
g
a
s
p
r
o
b
a
b
l
e
Ye
s
34
M
e
c
h
a
n
i
c
a
l
c
o
n
d
i
t
i
o
n
o
f
w
e
l
l
s
w
i
t
h
i
n
A
O
R
v
e
r
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
No
H
2
S
m
e
a
s
u
r
e
s
r
e
q
u
i
r
e
d
.
S
-
P
a
d
i
s
a
n
H
2
S
s
i
t
e
.
S
e
e
C
o
m
m
e
n
t
s
.
35
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
/
o
h
y
d
r
o
g
e
n
s
u
l
f
i
d
e
m
e
a
s
u
r
e
s
Ye
s
E
s
t
i
m
a
t
e
d
r
e
s
e
r
v
o
i
r
p
r
e
s
s
u
r
e
e
x
p
e
c
t
e
d
a
t
8
.
6
p
p
g
e
q
u
i
v
a
l
e
n
t
.
M
P
D
t
o
b
e
e
m
p
l
o
y
e
d
.
36
D
a
t
a
p
r
e
s
e
n
t
e
d
o
n
p
o
t
e
n
t
i
a
l
o
v
e
r
p
r
e
s
s
u
r
e
z
o
n
e
s
NA
37
S
e
i
s
m
i
c
a
n
a
l
y
s
i
s
o
f
s
h
a
l
l
o
w
g
a
s
z
o
n
e
s
NA
38
S
e
a
b
e
d
c
o
n
d
i
t
i
o
n
s
u
r
v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
C
o
n
t
a
c
t
n
a
m
e
/
p
h
o
n
e
f
o
r
w
e
e
k
l
y
p
r
o
g
r
e
s
s
r
e
p
o
r
t
s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
AD
D
Da
t
e
8/
1
5
/
2
0
2
3
Ap
p
r
MG
R
Da
t
e
8/
1
0
/
2
0
2
3
Ap
p
r
AD
D
Da
t
e
8/
1
6
/
2
0
2
3
Ad
m
i
n
i
s
t
r
a
t
i
o
n
En
g
i
n
e
e
r
i
n
g
Ge
o
l
o
g
y
Ge
o
l
o
g
i
c
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
:
En
g
i
n
e
e
r
i
n
g
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
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b
l
i
c
Co
m
m
i
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s
i
o
n
e
r
Da
t
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Hi
g
h
e
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t
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d
e
d
H
2
S
o
n
p
a
d
w
a
s
f
r
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S
-
2
7
B
(
1
4
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p
p
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)
i
n
2
0
1
2
.
L
a
s
t
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c
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d
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-
1
0
3
w
a
s
4
0
p
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n
2
0
2
3
.
*&
:
