Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout201-244FROM: Sandra D. Lemke, ATO -704
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage AK 99510-0360
RE: Core Photo well list
DATE: 11/15/2019
North Slope,
tJ_me
RECEIVED;,ol-zy q
Ct noc Phillips NOV 15 2019 i o�y
TRANSMITTAL AOGCC
TO: Meredith Guhl
AOGCC
222 W. Th Ave., Suite 100
Anchorage, Alaska 99501
Transmitted:
;01-
2P-417 Core photos 3 1 4 4 5
103-
04-
3S-16 Core Photos 31444,
)01-C
5q
Atlas 1 Core photos 3 1 4 4 3
DI -0'15
CO2 -24 Core Photos 3 1 4 4 2
001-2
At4
Cirque 3 Care photos -Tko-W-F-
!ob-4
12
Meltwater North 1 UV WL photos—T2_5(9(00
tl-I(p
51
Shark Tooth 1 Core photos — 17-t{Ili 1
'cb- C
120
1004025B35_Meltwater-N-l.pdf-T25"Z)
9
4_,�
1004278632 35-16.pdf 3 1 4 4 4
3D_0
y c
U04282603_Rendezvous-A.pdf 3 1 4 4 6
please promptly sign, scan, and e-mail to Sandra. D. Lemke(dconocophillios com
Receipt: V Y V Date: I I I I g l
Alaska/IT-GGRE I Co ocoft s Alaska I Office: 907 265 6947, Mobile 907.440.4511
j-~ ~.L ù-U - t..t
DATA SUBMITTAL COMPLIANCE REPORT
2/26/2004
~ ¿'lJ~ ~ð~
API No. 50-103-20399-00-00
Permit to Drill
Well Name/No. CIRQUE 3
Operator CONOCOPHILLIPS ALASKA INC
2012440
MD
TVD
Completion Date 2/1/2002 --
Completion Status
Current Status P&A
UIC N
6677 -
6096 -
P&A
REQUIRED INFORMATION
Mud Log Yes
Samples No
Directional Survey
Yes
DATA INFORMATION
Types Electric or Other Logs Run:
Well Log Information:
Log/ Electr
Data. Digital Dataset
Type Med/Frmt Number Name
~~ C ~ 7S~ø Nòt~ <
! ~ C to752f111åiJr~~?~~Spné)h~
1: ~ ; E~e::~:.sq~~ri~;
I --
~C
¡
Log Log
Scale Media
Run
No
1
1
1
1
1
JD151
1
,
.---- ~_.-.,
Well Cores/Samples Information:
Name
Cuttings
Interval
Start Stop
11 0 6660
Received
Sent
Core Chips
6123
6214
----
ADDITIONAL INFORMATION
Well Cored?
(l)N
C/N
~N
Formation Tops
Daily History Received?
Chips Received?
Analysis
Received?
(data taken from Logs Portion of Master Well Data Maint)
Interval
Start Stop
6123 6215
2316 6668
105 6677
2169 6675
4670
108
~
6250
OH/
CH Received Comments
Open 4/5/2002 Digital Core Photos
Open 3/11/2002 CMR DSI MSI (Field)
Open 3/11/2002 Final Well Report
Open 3/11/2002
Open 3/11/2002
)
!
6677
Open 3/11/2002
Processed CMR Data and
Displays
LIS Data, Digital Log
Images
Sample
Set
Number Comments
1056 Cores and/or Samples are required to be
submitted. This record automatically created
t ~ 'i ~ from Permit to Drill Module on: 12/18/2001.
~
~/N
ú)N
~-
Comments:
t
----- \.
. .
-,
DATA SUBMITTAL COMPLIANCE REPORT
2/26/2004
Permit to Drill 2012440
Well Name/No. CIRQUE 3
Operator CONOCOPHILLIPS ALASKA INC
API No. 50-103-20399-00-00
MD 6677 TVD 6096 c~on Date 211/2002
Compliance Reviewed By:
Completion Status
P&A
Current Status P&A UIC N
Date: '-t ~ÁM- i
.--.
--.
PT --G~í' -G ,.. t
-~U-~~~j- ~ LO~\TION CL~~_~~CE REPORT
State of Alaska
AUSlC;. o¡~ ~ GAS C::NSERVATION COMMISSION
Spud: l ' (j . ð,2-
?~ ~o. dD I - À ~ cf .
:ease ~L- ~315 íY7¡
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:'ccati.c¡¡ ~ ?-f?,:r:91\J I 1<. 1 t:: I f{Jv¡
Ab:c.é. Date ~.c \ -" a "2
C~leted ;:Lf (-. (J'~
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~ev~ew ~~e ."e" ;~'ø
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PHlmps PHILLIPS Alaska, Inc!
m A Subsidiary of PHilLIPS PETROLEUM COMPANY
dOJ-d),-/ if
TRANSMITT AL
CONFIDENTIAL DATA
FROM:
Sandra D. Lemke, ATO1486
Phillips Alaska, Inc.
P.O. Box 100360
Anchorage AK 99510-0360
TO:
Lisa Weepie
AOGCC
777 W, 7th, Suite 100
Anchorage, Alaska 99501
RE: Cirque 3
DATE: 04/23/02
Hand carried
Transmitted herewith is the followinQ:
~ue 3 50 ¡ 032039900
Core Labs
Reports
V Core Analysis Results, CL file 57111-02018; final report 4/18/2002
Please check off each item as received, sign and return one of the two transmittals enclosed to address below.
The other copy is for your records.
All data to be held confidential until State of Alaska designated AOGCC release date
CC: Laurel Alexander, PAl Geologist
Approved for transmittal by: S. Lemke
Receipt:
Return receipt to:
Date:
4-ð~~Ò~
hillips Alaska, Inc.
ATTN: S. Lemke, ATO-1486
700 G. Street
Anchorage, AK 99501
Prepared by: Sandra D, Lemke
Phillips Alaska IT Technical Databases
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Anchoral)e
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[ore Lab
PETRDLEUH SERVICES
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'I
CORE ANALYSIS RESULTS
PHilliPS ALASKA, INC.
"CIRQUE" 3
KUPARUK FIELD
ALASKA
CL FILE #57111-02018
Performed by:
Core Laboratories
3430 Unicorn Road
Bakersfield, CA 93308
(661) 392-8600
Final Report Presented
. April 18, 2002
a 0 /-ê)Lj L/
(
Petroleum Services
3430 Unicorn Road
Bakersfield, California 93308
Tel: 805-392-8600
Fax: 805-392-0824
WWIN.corelab.com
ClB
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NYSE
,~
.
~.
TABLE OF CONTENTS
DESCRIPTION OF SERVICES
CORE ANALYSIS DATA.. TABULATED RESULTS
HYDRAULIC UNIT ANALYSIS RESULTS
PROFILE PERMEAMETER RESULTS
CORE INVENTORY
,:
,
SECTION
1
2
3
4
5
~
1
,I'
\
{'
INTRODUCTION
Core Laboratories was selected by Phillips Alaska Inc. to perform a core analysis study upon
samples recovered from the Kuparuk Field, Alaska. Conventional aluminum inner barrel cores were
submitted. Presented herein are the results of analysis.
This report is divided into five sections. The first section provides a description of services. The
second section contains tabulated results of standard PKS analysis. Hydraulic unit classifications in
tabular presentation are included in the third section, the fourth section contains results of pressure-
decay profite permeameter measurements performed upon the stabbed core and the final section
contains the core inventory.
"
r
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Core Processing
Core Laboratories personnel from our Anchorage office performed all field handling and initial
core processing.
Core Gamma Suñace Log
Each core was scanned for natural gamma radiation utilizing Core lab's gamma spectrometer.
Total gamma radiation is reported in API units.
Core Sampling and Slabbing
After the gamma measurement, a sample segment approximately three tenths of a foot long was
taken from each foot of core for horizontal and vertical plug sampling. The remaining core from each foot
was slabbed parallel to the core axis utilizing a one/third - two/thirds cut. Isopar mineral oil was used as
the blade coolant and lubricant. For photography, viewing, description and additional sample selection
by Phillips' representatives the one-third sections were placed into slab boxes with Styrofoam inserts.
Sample Preparation
Both horizontally and vertically oriented one-inch diameter plugs were drilled from each of the
three-tenth foot core sections taken for sampling. Isopar mineral oil was used as the bit coolant and
lubricant. Each plug was weighed, wrapped with Saran wrap and aluminum foil, and sealed in a sample
jar as drilling was completed. After all of the samples were taken, the plugs were packaged and shipped
to our Bakersfield California facility.
,
v
t
(
Analysis Techniques
Fluid Extraction
Samples taken with horizontal orientation were weighed and placed into tared extraction
thimbles. Water and the oil were extracted from the samples by Dean Stark methods with toluene as the
solvent. The samples were held in the Dean Stark extractors for a minimum of sixteen hours after which
the receiving tubes were periodically checked to determine when the samples ceased to produce water.
The plugs were removed from the Dean-Stark extractors after stable water readings had been obtained.
Complete hydrocarbon extraction was conducted using soxhlet extractors with methylene chloride as the
solvent. Cleaned samples were removed from the soxhlets and dried in a convection oven at 2300F for
a minimum of forty-eight hours and were removed once their weights had stabilized. The dried samples
were cooled to laboratory temperature in a desiccator prior to analysis.
Samples designated for vertical permeability determinations were "batch" cleaned in large Dean
Stark extractors with toluene to remove water and then transferred to soxhlet extractors for batch
cleaning with methylene chloride. Drying was performed as for the horizontal plugs prior to permeability
measurements.
Grain Density Determinations
Grain volumes were determined using a Boyle's Law extended range helíum porosimeter. Metal
jacket and end~screen weight and volume corrections were applied to any jacketed samples. Grain
densities were calculated using Equation 1.
Õma
=
Mg
Vg
(1 )
Where: ðma = Matrix I grain density (glee)
Mg = Grain mass (g)
Vg = Grain volume (cc)
, r
If
(
Confining Pressure for Porosity and Permeability Measurements
Following grain volume determinations, the plug samples were placed into a Hassler-type holder
and a confining pressure of 400 psig was applied. Measurements made with a confining pressure of 400
psig are considered to be essentially "ambient" condition measurements. The minimal pressure acts to
prevent gas by-pass during measurements but does not compress the samples.
Porosity Determination
Direct pore volume measurements were made upon confined samples utilizing Boyle's Law
double-cell methods. Porosity values were calculated using Equation 2.
ø
=
[-( Vp )] . 100
Vp + Vg
(2)
Where: ø = Porosity (%)
Vp = Pore volume (cc)
Vg = Grain volume (cc)
Fluid Saturation Calculations
Oil and water saturation results were calculated using Equations 3 and 4.
So
-
-
[(Mf-~:-Mw } UJ} 100
(3)
Sw
=
[~: } 100
(4)
t r
('
(
Where: So = Oil saturation (%)
Sw = Water saturation (%)
Mj = Fresh sample mass (9)
Md = Extracted and dried sample mass (g)
Mw = Extracted water mass (9)
Vw = Extracted water volume (cc)
00 = Density of oil
Vp = Pore volume (cc)
Permeability to Air
Permeability determinations were made following the pore volume determinations again using
Hassler-type core holders. The permeability values were calculated utilizing Darcy's Equation for
compressible fluids, Equation 5.
Ka
=
[(pa. vg.1 000)]. [Qa . L 2]
M.P V¡,
(5)
Where: Ka = Permeability to air (md)
Pa = Atmospheric pressure
vg = Gas viscosity (cp)
ð.P = Differential pressure
p = Mean pressure
Qa = Flow rate (cc/sec)
L = Length (em)
Vb = Bulk volume (cc)
'T
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il
Hydraulic Unit Analysis
After rock property measurements had been completed, a hydraulic unit analysis was performed.
Reservoir quality index (average pore throat size) and pore ratio values were calculated for each of the
horizontal samples using Equations 6 and 7.
RQI
=
(Ka
0.0314 . V--q)
(6)
PR
=
<Þ
[1- <Þ ]
(7)
Where: RQI = Reservoir quality index
Ka = Permeability to air (md)
ø = Fractional porosity
PR = Pore ratio
RQI and PR values were used to group the samples into hydraulic units. Each hydraulic unit
represents a unique pore geometry relationship and provides the foundation for the integration of core
and electric log data. The results are presented sorted by sample depth, and by hydraulic unit; to
facilitate selection of representative samples for any additional testing.
Pressure-decay Profile Permeameter (PDPK)
The PDPK determines permeability by unsteady-state methods using a transient "blowdown"
technique. A tank of known volume is first filled with nitrogen and then the gas is discharged through the
core sample to atmosphere.
The decaying tank pressure is monitored versus time, which allows
determination of gas flow rate and pressure drop across the sample at any given time. The automated
recording of flow rate versus pressure differential. provides the data necessary for calculation of a
Klinkenberg-corrected permeability as well as the permeability to air. The results of analysis are
reported in tabular format and on diskette in Excel format.
I .
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Sample Disposition
Upon completion of the analysis, all sample plugs and remnants were shipped to Phillips' Bay
View Storage facility in Anchorage, Alaska.
Phillips Petroleum Co., AK
"Cirque" 3
Core Lab Kuparuk Field
Sàmple
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
Depth
6123.2
6124.3
6125.1
6126.1
6127.1
6128.1
6129.1
6129.8
6130.2
6131.2
6132.3
6133. 1
6134.1
6135.2
6136.1
6137.1
6137.8
6139.1
6140.3
6140.9
6142.0
6143.1
6143.9
6144.9
6146.1
6146.9
,
CL File No. : 57111 - 02018
...
ft
0.039
0.292
5.42
5.81
0.026
0.048
0.089
0.153
0.109
0.093
0.015
0.059
0.024
0.061
0.026
0.107
0.042
0.110
0.011
0.045
0.006
0.051
0.034
0.040
0.034
0.033
0.010
0.035
2.86
0.944
0.015
0.010
0.055
0.035
0.030
0.009
0.008
0.016
0.009
0.010
0.036
0.007
0.035
0.608
0.031
0.010
0.019
0.019
0.016
0.005
CORE ANALYSIS RESULTS
d I. . . 1"I~i~ì;,~~;tlJojšcr!PI¡¡'n .
-- - %_- - ~'-'/% >0:.-- . -:-~âtJO<~~:: ,:::.::gJçc-:-- .
1 - Vertical sample depths do not coincide exactly with horizontal sample depths.
12.1
14.3
16.4
19.0
13.6
12.8
14.5
15.3
14.9
15.0
13.2
14.3
13.1
13.0
12.9
13.4
13.3
14.4
6.6
7.5
7.7
12.7
12.5
10.9
8.0
13.0
15.0
8.1
39.0
41.5
0.0
0.0
0.0
12.4
15.2
3.3
11.8
0.0
0.0
0.0
0.0
0.0
0.0
19.7
16.4
19.1
0.0
0.0
0.0
0.0
0.0
0.0
:è'$äI_urâti§~s -
70.6
74.6
37.7
34.8
88.4
92.3
94.0
59.6
69.0
78.2
79.5
84.3
93.9
86.1
87.6
90.0
84.4
41.4
72.4
80.2
78.1
89.1
93.9
90.6
85.5
92.4
85.6
82.7
76.7
76.3
88.4
92.3
94.0
72.0
84.2
81.5
91.3
84.3
93.9
86.1
87.6
90.0
84.4
61.1
88.8
99.3
78.1
89.1
93.9
90.6
85.5
92.4
0.21
0.11
1.03
1.19
0.00
0.00
0.00
0.21
0.22
0.04
0.15
0.00
0.00
0.00
0.00
0.00
0.00
0.48
0.23
0.24
0.00
0.00
0.00
0.00
0.00
0.00
2.64
2.63
2.66
2.72
2.67
2.59
2.63
2.62
2.63
2.61
2.68
2.62
2.67
2.67
2.67
2.58
2.64
2.62
2.60
2.63
2.57
2.60
2.58
2.56
2.66
2.56
Comments
--
81t5t gry-It tan vfgr sd sh Itstr sin yel-gld flu
8st gry-It tan vfgr vslty earb Itstr sin yel-gld flu
Sst It brn vfgr vslty sh mstn gld flu
Sst It bm vfgr vslty mstn gld flu
Sh gry vslty earb no sin no flu
81tst gry vfgr sd sh earb no stn no flu
Sst gry vfgr vstty no stn no flu
8st It tan vfgr vslty It sin yel-gld flu
Sst It tan-gry vfgr vslty earb Itstr sin yel-gld flu
Sst It tan-gry vfgr vslty earb Itstr sin yel-gld flu
81tst gry-It tan vfgr sd strk lisp sin yel-gld flu
Sitst gry vfgr sd sh no sin no flu
Sitst gry vfgr sd sh no sin no flu
Sh gry vfgr sd strk vslty earb no sin no flu
Sh gry vfgr sd strk vslty earb no sin no flu
Sst gry vfgr vslty carb no sin no flu
Sst gry vfgr vslty sh no sin no flu
8st It tan vfgr vslty It sin yel-gld flu
Sst gry-It tan vfgr vslty lisp stn yel-gld flu
8st tan-gry vfgr vslty Itstr sin yel-gld flu
Sst gry vfgr vslty no stn no flu
Sst gry vfgr vslty no s1n no flu
Sst gry vfgr vslty no sin no flu
Sst gry vfgr vslty no sin no flu
Sitst gry vfgr sd sh no sin no flu
Sst gry vfgr vslty carb no sin no flu
Phillips Petroleum Co., AK CL File No. : 57111 - 02018
"Cirque" 3
Core Lab Kuparuk Field
CORE ANALYSIS RESUL TS
" '.. , " oescryption .'
Sample Perm~,{Kair) porosity " , Saturatiöns Comments
No.
I
ft " J' - c' , 'I' , 'n "I .~' 'I ' c,-~,'-,",'I' a'-- I I I
. . .
1 - Vertical sample depths do not coincide exactly with horizontal sample depths. ~
6147.6 0.030 55t gry vfgr vslty carb no sin no flu
27 6148.1 0.037 0.019 12.7 0.0 99.6 99.6 0.00 2.62 55t gry vfgr vslty earb no sin no flu
28 6149.1 0.100 0.030 13.8 0.0 99.8 99.8 0.00 2.64 Sst gry vfgr vslty earb no sin no flu
29 6150.2 0.062 0.027 13.0 0.0 98.5 98.5 0.00 2.59 5st gry vfgr vslty carb no sin no flu
30 6151.1 0.513 0.315 14.0 30.2 40.3 70.5 0.75 2.67 5st tan vfgr vslty carb mstn yel-gld flu
31 6152.6 7.62 20.1 41.4 29.8 71.2 1.39 2.70 5st It bm vfgr slty m5tn yel-gld flu sl fractured
32 6154.1 5.79 0.928 18.0 21.6 54.8 76.4 0.39 2.70 5st tan vfgr vslty carb m5tn yel-gld flu sl fractured
33 6154.9 1.50 0.009 17.8 19.9 52.3 72.2 0.38 2.69 5st tan vfgr vslty earb mstn yel-gld flu 51 fractured
34 6156.1 ,0.169 0.025 16.0 10.2 66.2 76.4 0.15 2.69 5st tan-gry vfgr vslty Itstr stn yel-gld flu
35 6157.1 2.47 0.170 17.7 28.5 49.6 78.1 0.57 2.69 5st It bm vfgr vslty mstn yel-gld flu 51 fractured
36 6158.0 0.747 0.031 18.3 28.6 46.8 75.4 0.61 2.80 5st tan vfgr vslty earb mstn yel-gld flu
37 6158.9 0.294 15.5 18.8 60.6 79.4 0.31 2.67 5st tan vfgr vslty carb mstn yel-gld flu
38 6159.2 0.367 0.034 16.8 16.8 59.2 76.0 0.28 2.67 55t tan vfgr vslty carb mstn yel-gld flu
39 6160.2 0.321 0.072 16.2 13.4 61.6 75.0 0.22 2.65 5st tan vfgr vslty carb mstn yel-gld flu
40 6161.0 0.045 0.062 14.6 0.0 89.9 89.9 0.00 2.68 5st gry vfgr vslty sh no stn no flu -,
41 6162.1 0.133 0.089 15.8 0.0 84.8 84.8 0.00 2.65 5st gry vfgr vslty earb no sin no flu
42 6163.5 0.094 0.101 16.7 0.0 78.4 78.4 0.00 2.66 5st gry vfgr vslty earb no sin no flu
43 6164.4 0.092 0.065 15.4 0.0 83.8 83.8 0.00 2.63 5st gry vfgr vslty earb no sin no flu
44 6165.1 0.213 0.031 14.7 6.9 74.7 81.6 0.09 2.67 5st gry-It tan vfgr vslty lisp sin yel-gld flu
45 6166.4 0.411 0.070 15.6 15.4 56.1 71.5 0.27 2.68 5st tan vfgr vslty earb mstn yel-gld flu
46 6167.1 0.476 0.121 16.3 19.7 54.9 74.6 0.36 2.68 5st tan vfgr vslty carb mstn yet-gld flu
47 6168.2 0.315 0.073 16.5 15.8 54.1 69.9 0.29 2.66 5st tan vfgr vslty earb mstn yet-girl flu
48 6169.1 0.395 0.084 15.1 15.8 57.3 73.1 0.28 2.66 5st tan vfgr vslty mstn yel-gtd flu
49 6170.1 0.118 0.054 15.3 0.0 80.8 80.8 0.00 2.65 5st gry vfgr vslty carb no stn no flu
50 6171.1 0.295 0.098 15.4 13.2 65.9 79.1 0.20 2.63 5st It tan vfgr vslty earb It stn yel-gld flu
51 6172.1 0.153 0.028 16.1 7.8 70.3 78.1 0.11 2.65 5st gry-It tan vfgr vslty carb Itstr sin yel-gld flu
Phillips Petroleum Co., AK CL File No. : 57111 - 02018
"Cirque" 3
Core Lab Kuparuk Field
CORE ANALYSIS RESUL TS
Sample' Perm/(Kair} . . Saturàtions . Grain It1E!šcription I Comments
. n_.. ..
'. .. -'.
No. I I
I I r'~.~"'l '~. -'I...~-~~).tF>,~-.~~..~t.. .~ -, I . -7-~1. 8-n. I
ft md
1 - Vertical sample depths do not coincide exactly with horizontal sample depths. .-
.
52 6173.1 0.414 0.335 17.4 12.7 54.7 67.4 0.23 2.70 5st It tan vfgr Yslty It stn yel-gld flu
53 6174.1 0.165 0.038 15.1 7.5 72.6 80.1 0.10 2.65 5st gry-It tan vfgr vslty earb Itstr sIn yel-gld flu
54 6175.1 0.043 0.022 13.6 0.0 90.9 90.9 0.00 2.67 5st gry vfgr yslty earb sh no sIn no flu
55 6176.3 0.206 0.044 15.5 11.3 65.1 76.4 0.17 2.67 5st It tan-gry vfgr vslty earb sh Itstr sin yel-gld flu
56 6177.1 0.063 0.059 13.1 0.0 92.8 92.8 0.00 2.63 5st gry vfgr yslty earb no sIn no flu
57 6178.0 0.226 0.195 13.6 14.6 60.7 75.3 0.24 2.66 5st It tan vfgr vslty carb sh It stn yel-gld flu
58 6179.0 0.216 0.060 15.3 21.5 63.0 84.5 0.34 2.69 5st gry-It tan vfgr vslty earb Itstr sIn yel-gld flu
59 6180.0 0.164 0.085 14.9 18.2 70.4 88.6 0.26 2.68 5st gry-It tan vfgr vslty earb sh Itstr sin yel-gld flu
6180.9 0.090 5st gry-It tan vfgr vslty carb sh Itstr sin yel-gld flu
60 6181.6 1.15 0.139 17.1 21.2 52.9 74.1 0.40 2.84 5st It bm vfgr vslty mstn yel-gld flu
61 6182.0 0.153 15.8 6.0 72.5 78.5 0.08 2.66 5st gry-It tan vfgr Yslty earb Itstr sin yel-gld flu
62 6184.2 0.539 0.058 16.7 11.2 64.2 75.4 0.17 2.66 5st tan vfgr vslty earb mstn yel-gld flu
63 6185.1 0.064 0.020 13.2 0.0 87.8 87.8 0.00 2.67 5st gry vfgr vslty earb shs no sin no flu
64 6186.1 0.208 0.066 16.1 11.1 64.7 75.8 0.17 2.70 5st tan vfgr vslty earb sh mstn yel-gld flu
65 6186.8 0.096 15.3 0.0 79.2 79.2 0.00 2.56 5st gry vfgr vsl1y earb no sin no flu -,
66 6188.0 0.084 0.046 14.1 0.0 88.3 88.3 0.00 2.60 5st gry vfgr vslty earb no sin no flu
67 6189.1 0.080 0.069 15.0 0.0 77.6 77.6 0.00 2.57 5st gry vfgr vsl1y earb no s1n no flu
68 6190.0 0.076 0.075 15.2 0.0 78.3 78.3 0.00 2.64 5st gry vfgr vslty earb no sIn no flu
69 6190.9 2.05 0.033 17.9 24.0 48.8 72.8 0.49 2.70 5st It bm vfgr vslty sh mstn yel-gld flu
70 6192.1 0.304 0.067 15.9 9.8 66.2 76.0 0.15 2.60 5st gry-It tan vfgr vslty earb Itstr sIn yel-gld flu
71 6193.2 5.02 1.57 20.3 33.6 36.3 69.9 0.93 2.71 5st It bm vfgr vslty earb mstn yel-gld flu
72 6194.1 5.90 3.24 19.0 40.1 32.3 72.4 1.24 2.70 5st It bm vfgr vslty earb mstn yel-gld flu
73 6195.1 0.006 0.007 9.3 0.0 99.4 99.4 0.00 2.67 Sitst gry sh no sIn no flu
74 6196.2 0.402 0.189 15.9 19.4 50.2 69.6 0.39 2.71 5st It bm vfgr vslty mstn yel-gld flu
75 6197.1 5.04 0.381 14.2 29.0 40.9 69.9 0.71 2.71 5st tan vfgr vslty mstn yel-gld flu
76 6198.1 3.84 1.49 17.8 36.6 34.0 70.6 1.08 2.70 5st It bm vfgr vslty mstn yel-gld flu
Phillips Petroleum C-o" AK CL File No. : 57111 - 02018
"Cirque" 3
Core LaI:Ì _Kuparuk Field
CORE ANALYSIS RESUL 1S
, '0 0 .
Comments
,,(, Horiz,' ~f-ve~o1'.. .'1, - -(ff~lP~-",.I.i~il;.l;V'l~t;r'l/r~t-aÎ~l~~()i~~J-~~n~ijyp'l. I
1t
0 0 0' ' , , -. 0,' ,~ .0 , .' 0,.. ".0 - ' . . 0 . o .
1 - Vertical sample depths do not coincide exactly with horizontal sample depths. -~
77 6198.9 0.634 0.027 16.7 18.8 60.2 79.0 0.31 2.64 5st It bm vfgr vslty earb lam mstn yel-gld flu
78 6200. 1 3.83 1.75 18.4 16.4 43.6 60.0 0.38 2.70 5st tan vfgr vslty mstn yet-gtd flu
79 6201.1 6.44 0.179 19.5 33.4 34.9 68.3 0.96 2.73 5st It bm vfgr vslty mstn yel-gld flu
80 6202.0 6.10 2.55 19.2 36.5 31.1 67.6 1.17 2.68 55t It brn vfgr vslty earb mstn yel-gld flu
81 6203.0 0.003 0.015 6.6 0.0 99.3 99.3 0.00 2.68 Mudst gry slty no sin no flu
82 6204.2 0.092 0.019 16.8 0.0 99.4 99.4 0.00 2.68 5st gry vfgr vslty no sin no flu
83 6204.7 0.026 13.3 0.0 98.9 98.9 0.00 2.56 5st gry vfgr vslty no sin no flu
6205.0 0.014 Sst gry vfgr vslty no sin no flu
84 6205.9 0.016 0.012 13.7 0.0 89.5 89.5 0.00 2.51 5st gry vfgr vslty no sin no flu
85 6206.2 0.006 8.3 0.0 95.6 95.6 0.00 2.49 5st gry vfgr v51ty no sin no flu
86 6207.1 0.040 0.060 18.6 0.0 86.7 86.7 0.00 2.54 5st gry vfgr vslty no sin no flu
87 6208.1 0.028 0.019 13.9 0.0 74.4 74.4 0.00 2.50 5st gry vfgr vslty no sin no flu
88 6209.1 0.027 0.029 11.3 0.0 92.4 92.4 0.00 2.53 5st gry vfgr vslty no sin no flu
89 6210.1 0.069 0.096 18.2 0.0 77.5 77.5 0.00 2.51 5st gry vfgr vslty no sin no flu
90 6211.1 0.080 0.110 19.0 0.0 72.6 72.6 0.00 2.49 5st gry vfgr vslty no sin no flu ~~.
91 6212.4 0.024 0.044 14.2 0.0 73.6 73.6 0.00 2.51 5st gry vfgr vslty no sin no flu
92 6213.2 0.016 0.036 10.6 0.0 95.6 95.6 0.00 2.49 58t gry vfgr vslty no sin no flu
93 6214.0 0.057 15.7 0.0 79.7 79.7 0.00 2.51 5st gry vfgr vslty no sin no flu
94 6214.9 0.005 16.1 0.0 42.3 42.3 0.00 2.50 Sst gry vfgr vslty no sin no flu
I .
10.000
1.000
-
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--
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0.100
0.010
0.001
i'
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Horizontal Permeability vs Porosity
,
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L "",,',,:'.'. "",'
c,: .. :,",'
:"",:","i"""","'"""",,,',,;" ,,'," """"""':"::"";":':";'"" I 'i,;"::
, , ':""" ",'" .. " 'c'"',, "c ' '"",, ,:c "'",i:.','" ,..;, \ ','" Î ' .. ' ;;:~" "",", -,' :: ",'" c;,,:,,' ,
:', ","c,,', """""" ~", c"~~,,",,, """," ..""",".."i"":""i""""':,:,','"":,,,~,,,'c,:,,:,.',:,::c:"","""
",..;::i'.<',':'"""",,:;';F ,::""""", ---~/,"':',""':'::?',:' :"":"':""""':c".":",";:;"',"':'-"~'::",,,:I'" '"..:'::,,', ,'<i'i:",'
,( "", ,:',"";,',';,,, :' ;', "",', '":",:,,"',,,:,,"" ,,:, ,,' ,', "'.':' , """'~I ,"'\:'
:;:<,"',,:'CIP~-:; ~IT,> ""c,,:,,""",,:, ,',"":"",",\,~,}8J,:,,,,,,', ','" "',,' '",', ,:
,:",:, "":'/"177"";-:J"p~",':c ':> """".... ',',," .,~'" >.¡::f",;",:,:'> I:'(:~:---":,'~,', "',,','"~ :'"",,"",:',:~:
''i:':,:"", ¡':/,> ",,":"" :;":""""",\,:"",':¡T:":'~'::"~""~::i':>I',"':""""'"i,,:~3
""",,:,:,," " -"-,,"
Ii;,':':'}":,:","',::; "[; "":;P:i: :;"""">!!:.,,..:~ ,,:i:;;!; "," <;': ',::,:::",,/¿:
:':i, "":"<':"',::: "":?",<:",;:,~,:,~'(c,,:,:::,;,,,,:c,,; "T,':' 'ii\:'
::i,"""::; :,,:,,:: ~~',', "::",1","'.",'""::""",:""",,::,,,:
.. "':.',.',.',.::,"::': ',t,'::",".',:;ii 'i;:X:,:'",'" '.' }:,":': ,I","",',"",:,,"',:
":':;i;~:"~~".:':¡:~'::';::/', """':':""",',i' ;""i":"""""".','<,/': """""""", /:':1:':;,""""""',"',,"/ :'"
""',,', "c', , "'::' "'"i:-,i",:",:,:'"" ,',-"" _":",,,,";";'i'" ::",", ," "
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........ ....
....
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""""""""":"""""'""",..,,,'" ,?T"~c"" '",->"'"","" "",".. '"," """"":,:"'""",",':':"""",,"".,,"..'."',,,,,"
i""i,':':,"::':"":"':"',':'" """"""""""",:>:.".'::,'"""",:,::¡-" ", .", ','
""i""',:,,,:,-, ".-eC",','77""'" ",::"" ';"7~".:>,,\':,:",",
,":' ""', .".".':""":":' I" ':,'..".,",.,"',> ";:i.. ',',," ,,","" '':' ' ','
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"
0.0
10.0
20.0
30.0
Porosity (%)
Phillips Petroleum Co., AK
"Cirque" 3
M Kuparuk Field
Core Lab
- Samp'~
-No~. --
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
Vertical Permeability
- -
. --IP'n1i~~bjU~ -..
IVert.- - ---
rrid
6123.0
6124.0
6125.0
6126.0
6127.0
6128.0
6129.0
6130.0
6131.2
6132.4
6133.0
6134.0
6135.2
6136.0
6137.0
6138.0
6139.0
6140.0
6141.3
6142.0
6143.0
6144.2
6144.9
6146.0
6147.6
6148.0
6149.0
6150.0
6151.1
0.010
0.035
2.86
0.944
0.015
0.010
0.055
0.035
0.030
0.009
0.008
0.016
0.009
0.010
0.036
0.007
0.035
0.608
0.031
0.010
0.019
0.019
0.016
0.005
0.030
0.019
0.030
0.027
0.315
Sst gry vfgr vslty earb strl< no stn no flu
Sst It tan vfgr vslty earb strl< It sin yel-gld flu
Sst It tan vfgr vslty earb strk It sin yel-gld flu
Sst gry-It tan vfgr vslty earb strl< It strl< stn yel-gld flu
Sst gry-It tan vfgr vslty earb strk It strk sin yel-gld flu
Sst It tan vfgr vslty It stn yel-gld flu
Sst It tan vfgr vslty It stn yel-gld flu
Sst gry-It tan vfgr vslty earb strk It strk stn yel-gld flu
Sst gry-It tan vfgr vslty earb strk It strl< sin yel-gld flu
Sst gry vfgr vslty earb strl< sh lam no sin no flu
Sst gry vfgr vslty earb strk sh lam no sin no flu
Sst It tan-gry vfgr vslty earb strl< sh lam It strk sin yel-gld flu
Sst It tan-gry vfgr vslty earb strk sh lam It strk sin yel-gld flu
Sst gry vfgr vslty carb strl< no sin no flu
Sst gry vfgr vslty earb strk no sin no flu
Sst It tan vfgr vslty earb strk sh lam It sin yel-gld flu
Sst It tan vfgr vslty earb strl< sh lam It sin yel-gld flu
Sst gry-It tan vfgr vslty earb strl< It strl< sin yel-gld flu
Sst gry-It tan vfgr vslty carb strl< It strk sin yel-gld flu
Sst gry-It tan vfgr vslty carb strk sh lam It strl< sin yel-gld flu
Sst gry-It tan vfgr vslty earb strl< sh lam It strl< sin yel-gld flu
Sst gry-It tan vfgr vslty carb strl< sh lam It strk sin yel-gld flu
Sst Itbrn vfgr vslty m sin yel-gld flu
Sst gry-It tan vfgr vslty earb strk It strl< sin yel-gld flu
Sst gry-It tan vfgr vslty earb strl< It strl< sin yel-gld flu
Sst tan vfgr vslty carb strl< m sin yel-gld flu
Sst tan vfgr vslty earb strk m sin yel-gld flu
Sst gry vfgr vslty earb strl< sh lams no sin no flu
Sst gry vfgr vslty earb strk sh lams no stn no flu
CL File No. : 57111 - 02018
--.
--
Phillips Petroleum Co., AK
nCirque" 3
- Kuparuk Field
Core Lab
CL File No. : 57111 ~ 02018
Vertical Permeability
30 6154.0 0.928 Sst tan vfgr vslty earb sh lam m sin yet-sid flu_,
31 6155.2 0.009 Sst tan vfgr vslty earb sh lam m sin yel-gld flu
32 6156.0 0.025 Sst gry vfgr vslty earb no sin no flu
33 6157.2 0.170 Sst gry vfgr vslty earb sirl< no sin no flu
34 6158.1 0.031 Sst gry vfgr vslty earb strl< no sin no flu
35 6159.2 0.034 Sst gry vfgr vslty earb strl< no sin no flu
36 6160.0 0.072 Sst gry vfgr vslty earb no sin no flu
37 6161.3 0.062 Sst gry vfgr vslty earb no sin no flu
38 6162.1 0.089 Sst gry vfgr vslty earb no sin no flu
39 6162.8 0.101 Sst It bm vfgr vslty sh jnel m sin yel-gld flu
40 6164.2 0.065 Sst gry-It tan vfgr vslty earb It strk sin yel-gld flu
41 6165.0 0.031 Sst gry-It tan vfgr vslty earb It strk sin yet-sid flu
42 6166.2 0.070 Sst gry-It tan vfgr vslty Garb It strl< sin yel-gld flu
43 6167.3 0.121 Sst It bm vfgr vslty earb m sin yel-gld flu
44 6168.2 0.073 Sst It brn vfgr vslty earb m sin yel-gld flu
45 6168.8 0.084 Sst It brn vfgr vslty earb m stn yel-gld flu
~~-
46 6170.0 0.054 Sst Jt brn vfgr vslty earb m stn yel-gld flu -
47 6171.0 0.098 Sitst gry sh no sin no flu
48 6172.0 0.028 Sitst gry sh no sin no flu
49 6173.0 0.335 Sst It bm vfgr vslty m sin yel-gld flu
50 6174.0 0.038 Sst It brn vfgr vslty m sin yel-gld flu
51 6175.0 0.022 Sst tan vfgr vslty m sin yel-gld flu
52 6176.0 0.044 Sst tan vfgr vslty m sin yel-gJd flu
53 6177.1 0.059 5st tan vfgr vslty m sin yel-gld flu
54 6177.8 0.195 Sst It bm vfgr vslty m sin yel-gld flu
55 6178.9 0.060 Sst It brn vfgr vslty earb lam m sin yel-gld flu
56 6180.1 0.085 Sst It bm vfgr vslty earb lam m sin yel-gld flu
57 6180.9 0.090 5st tan vfgr vslty m stn yel-gld flu
58 6181.6 0.139 Sst tan vfgr vslty m stn yet-sid flu
CL File No. : 57111 - 02018
Phillips Petroleum Co., AK
"Cirque" 3
'" Kuparuk Field
Core Lab
Vertical Permeability
~ ~ - ~
\~~~ßD,~çl"Îpti(),n ~~~:.
59 6184.1 0.058 55t It bm vfgr V51ty m stn yel-gld flu r'-.
60 6185.0 0.020 55t It brn vfgr vslty m sin yel-gld flu
61 6186.0 0.066 55t It bm vfgr vslty earb incl m sin yel-gld flu
62 6188.0 0.046 55t It bm vfgr vslty carb jnel m 5tn yel-gld flu
63 6189.0 0.069 Mudst gry 51ty no sin no flu
64 6190.1 0.075 Mudst gry slty no sin no flu
65 6191.1 0.033 Mudst gry slty no 5tn no flu
66 6192.0 0.067 55t gry vfgr vslty no sin no flu
67 6193.1 1.57 55t gry vfgr v51ty no 5tn no flu
68 6194.0 3.24 5st gry vfgr vslty no sin no flu
69 6195.0 0.007 5st gry vfgr v5Jty no sin no flu
70 6196.1 0.189 5st gry vfgr vslty no sin no flu
71 6197.0 0.381 5st gry vfgr vslty no stn no flu
72 6198.0 1.49 5st gry vfgr vslty no sin no flu
73 6199.0 0.027 5st gry vfgr vslty no s1n no flu
74 6200.0 1.75 55t gry vfgr vslty no stn no flu
-~~
75 6201.0 0.179 5st gry vfgr v51ty no sin no flu
76 6202.0 2.55 5st gry vfgr v51ty no sin no flu
77 6203.2 0.015 5st gry vfgr vslty no 5tn no flu
78 6204.1 0.019 5st gry vfgr vslty no stn no flu
79 6205.0 0.014 5st gry vfgr v51ty no sin no flu .
80 6206.0 0.012 55t gry vfgr v51ty no 5tn no flu
81 6207.0 0.060 Sst gry vfgr v51ty no 5tn no flu
82 6208.0 0.019 5st gry vfgr vslty no 51n no flu
83 6209.0 0.029 Sst gry vfgr v51ty no 5tn no flu
84 6210.0 0.096 Sst gry vfgr v5Jty no 5tn no flu
85 6211.0 0.110 Sst gry vfgr vslty no 5tn no flu
86 6212.0 0.044 Sst gry vfgr vslty no stn no flu
87 6213.0 0.036 Sst gry vfgr vslty no stn no flu
. .
10.000
1.000
-
"C
E
-
g
CD
D-
c¡
u
:e
CD
>
0.100
0.010
0.001
0.001
(
"
I(
Horizontal Permeability vs Vertical Permeability
, ,
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"
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I ,'4 ,;
, ',' ': " "
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,", '" , "':":"'" ,:'," ",', . :' ,
,,' , " ,:' ~ ",' ,
' " "
" , "',, " : " " : ",,' ,,',ii' , ",
:,,", I:'", ';':, ' ' I' ::,, " ,\ ': ,'""""", ..<'~ ',,':
:...." ','",',:, '" ",' ' .:' .'.,':,,' "'"
" ", ~ ,', ", "',""", , ,'," " ',", . ,; ;", ..::, ,', :¡':'"
'i,:,':",:", ,::,':,' :':" ',:i" ' " .' :," ,', ' .
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" ",'
....
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+
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.
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~.. . .. ~ " ~
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.
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',' " ':, I" " ":'r,, "
'" :, ,,' , "'"
, ,~I " ":c' " ,", ,;, ",'" ',"'," ,':' ;:'" ,
,",'" ':: ,:' , :" , , ,,' " ", "",
'", ""', ,,' ",::, , ">, """"'" "," I:' ",', I,,! , L:'
" ,' ,':' " ',: "" , ':, I, " ,' I:> ','
¡, ,',',' : ',:,: ' I: ",',' : ' '1,1
" ':. I', ', ',: "," ','
'. ',:",,: "'" ,',
"", I~', I ' ",', , "',, ",,'
",'" ".. ' ,', I':" I: ",,' , ,"I: '
<, ' , ,t,' :."",' I, .. I:, I
c' " ", ,", ,,', "
0.010
0.100
Horizontal Perm. (md)
1.000
10.000
Phillips Petroleum Co., AK
"Cirque" 3
~ Kuparuk Field
Core Lab
6123.2
6124.3
6125.1
6126.1
6127.1
6128.1
6129.1
6129.8
6130.2
6131.2
6132.3
6133.1
6134.1
6135.2
6136.1
6137.1
6137.8
6139.1
6140.3
6140.9
6142.0
6143.1
6143.9
6144.9
6146.1
6146.9
6148.1
6149.1
Hydraulic Unit Classifications
. 'SO1'teCfaY~~I't1P.Ie,Q~ptlt":.
,;:t::}. . .~;~=~~~.,~a~~~~~
Indicåt(Jt.. '. Jl'lde~....
0.1299
0.2697
0.9248
0.7389
0.0875
0.1300
0.1441
0.1736
0.1535
0.1399
0.0686
0.1211
0.0903
0.1443
0.0949
0.1816
0.1158
0.1637
0.1839
0.3039
0.1007
0.1356
0.1144
0.1555
0.2349
0.1067
0.1167
0.1660
0.018
0.045
0.181
0.174
0.014
0.019
0.025
0.031
0.027
0.025
0.010
0.020
0.014
0.021
0.014
0.028
0.018
0.027
0.013
0.024
0.008
0.020
0.016
0.019
0.021
0.016
0.017
0.027
7
8
10
10
6
7
7
7
7
7
5
6
6
7
6
7
6
7
7
8
6
7
6
7
8
6
6
7
6214.9
6132.3
6205.9
6207.1
6127.1
6133.1
6134.1
6136.1
6137.8
6142.0
6143.9
6146.9
6148.1
6161.0
6163.5
6175.1
6190.0
6195.1
6203.0
6204.2
6204.7
6206.2
6208.1
6209.1
6210.1
6211.1
6212.4
6213.2
0.0298
0.0686
0.0669
0.0641
0.0875
0.1211
0.0903
0.0949
0.1158
0.1007
0.1144
0.1067
0.1167
0.1018
0.1168
0.1127
0.1247
0.0762
0.0961
0.1151
0.0896
0.0885
0.0879
0.1188
0.0863
0.0869
0.0783
0.1014
0.006
0.010
0.011
0.015
0.014
0.020
0.014
0.014
0.018
0.008
0.016
0.016
0.017
0.017
0.023
0.018
0.022
0.008
0.007
0.023
0.014
0.008
0.014
0.015
0.019
0.020
0.013
0.012
CL File No. : 57111 .. 02018
Hydraulic
Unit
......."',
4
5
5
5
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
~"
~
Phillips Petroleum Co., AK CL File No. : 57111 - 02018
"Cirque" 3
Core t.a6 Kuparuk Field
Hydraulic Unit Classifications
Sorted By Hydraulic Unit
D4!pthl ...Flow. . r ..Rêseryoir 1 Flydnu.t1iC'.r r. Depth I ¡:Iow Reservoir I Hydraulic
Zone. Quality Unit
Indiêator Index
~
6150.2 0.1452 0.022 7 6214.0 0.1015 0.019 6
6151.1 0.3703 0.060 9 6123.2 0.1299 0.018 7
6152.6 0.7654 0.193 10 6128.1 0.1300 0.019 7
6154.1 0.8137 0.178 10 6129.1 0.1441 0.025 7
6154.9 0.4218 0.091 9 6129.8 0.1736 0.031 7
6156.1 O. 1705 0.032 7 6130.2 0.1535 0.027 7
6157.1 0.5433 0.117 9 6131.2 0.1399 0.025 7
6158.0 0.2828 0.063 8 6135.2 0.1443 0.021 7
6158.9 0.2357 0.043 8 6137.1 0.1816 0.028 7
6159.2 0.2308 0.046 8 6139.1 0.1637 0.027 7
6160.2 0.2290 0.044 8 6140.3 0.1839 0.013 7
6161.0 0.1018 0.017 6 6143.1 0.1356 0.020 7
6162.1 0.1539 0.029 7 6144.9 0.1555 0.019 7
6163.5 0.1168 0.023 6 6149.1 O. 1660 0.027 7
6164.4 0.1332 0.024 7 6150.2 O. 1452 0.022 7
6165.1 0.2184 0.038 8 6156.1 0.1705 0.032 7 -,~
6166.4 0.2748 0.051 8 6162.1 0.1539 0.029 7
6167.1 0.2766 0.054 8 6164.4 0.1332 0.024 7
6168.2 0.2191 0.043 8 6170.1 0.1534 0.028 7
6169.1 0.2847 0.051 8 6172.1 0.1597 0.031 7
6170.1 0.1534 0.028 7 6174.1 0.1841 0.033 7
6171.1 0.2395 0.043 8 6176.3 0.1966 0,036 7
6172.1 0.1597 0.031 7 6177.1 0.1442 0.022 7
6173.1 0.2292 0.048 8 6179.0 0.2069 0.037 7
6174.1 0.1841 0.033 7 6180.0 0.1883 0.033 7
6175.1 0.1127 0.018 6 6182.0 0.1646 0.031 7
6176.3 0.1966 0.036 7 6185.1 0.1436 0.022 7
6177.1 0.1442 0.022 7 6186.1 0.1868 0.036 7
...
Phillips Petroleum Co., AK
"Cirque" 3
'" Kuparuk Field
Core Lab
CL File No. : 57111 - 02018
Hydraulic Unit Classifications
Sorted~ay.$ârtrpleQeJ)~ ~.'
.Flow. "l~eSf!ryoi'" Hydraulic
Zone "'. . .Qu~.fi!yu Unit
Indicator Index
6178.0 0.2557 0.040 8 6186.8 0.1375 0.025 7
6179.0 0.2069 0.037 7 6188.0 0.1486 0.024 7
6180.0 0.1883 0.033 7 6189.1 0.1294 0.023 7
6181.6 0.3949 0.081 9 6124.3 0.2697 0.045 8
6182.0 O. 1646 0.031 7 6140.9 0.3039 0.024 8
6184.2 0.2820 0.056 8 6146.1 0.2349 0.021 8
6185.1 O. 1436 0.022 7 6158.0 0.2828 0.063 8
6186.1 0.1868 0.036 7 6158.9 0.2357 0.043 8
6186.8 0.1375 0.025 7 6159.2 0.2308 0.046 8
6188.0 0.1486 0.024 7 6160.2 0.2290 0.044 8
6189.1 0.1294 0.023 7 6165.1 0.2184 0.038 8
6190.0 0.1247 0.022 6 6166.4 0.2748 0.051 8
6190.9 0.4884 0.106 9 6167.1 0.2766 0.054 8
6192.1 0.2297 0.043 8 6168.2 0.2191 0.043 8
6193.2 0.6141 0.156 10 6169.1 0.2847 0.051 8
6194.1 0.7463 0.175 10 6171.1 0.2395 0.043 8
6195.1 0.0762 0.008 6 6173.1 0.2292 0.048 8
6196.2 0.2628 0.050 8 6178.0 0.2557 0.040 8
6197.1 1.1350 0.187 11 6184.2 0.2820 0.056 8
6198.1 0.6751 0.146 10 6192.1 0.2297 0.043 8
6198.9 0.3056 0.061 8 6196.2 0.2628 0.050 8
6200.1 0.6327 0.143 10 6198.9 0.3056 0.061 8
6201.1 0.7445 0.180 10 6151.1 0.3703 0.060 9
6202.0 0.7459 0.177 10 6154.9 0.4218 0.091 9
6203.0 0.0961 0.007 6 6157.1 0.5433 0.117 9
6204.2 0.1151 0.023 6 6181.6 0.3949 0.081 9
6204.7 0.0896 0.014 6 6190.9 0.4884 0.106 9
6205.9 0.0669 0.011 5 6125.1 0.9248 0.181 10
~-
-.,.
CL File No. : 57111 .. 02018
Phillips Petroleum Co., AK
"Cirque" 3
.. Kuparuk Field
Core Lab
Hydraulic Unit Classifications
.S()rtedèySalÍtple~~h ..
Depth. . r . Flow.. . . Re~érvöi.r'
.Zone... Quality
(ft) . Indicator . . Index
6206.2 0.0885 0.008 6
6207. 1 0.0641 0.015 5
6208.1 0.0879 0.014 6
6209.1 0.1188 0.015 6
6210.1 0.0863 0.019 6
6211.1 0.0869 0.020 6
6212.4 0.0783 0.013 6
6213.2 0.1014 0.012 6
6214.0 0.1015 0.019 6
6214.9 0.0298 0.006 4
. Sorted By. Hydraulic Unit
:Flow Rèservoir ) Hydraulic
Zone . Quality Unit
. Indicator.. Index
6126.1 0.7389 0.174 10 _.
6152.6 0.7654 0.193 10
6154.1 0.8137 0.178 10
6193.2 0.6141 0.156 10
6194.1 0.7463 0.175 10
6198.1 0.6751 0.146 10
6200.1 0.6327 0.143 10
6201.1 0.7445 0.180 10
6202.0 0.7459 0.177 10
6197.1 1 .1350 0.187 11
-~~.
(
aA Phillips Petroleum Co., AK
"Cirque" 3
àiiit
Core Lab Kuparuk Field
IlESElYÐIR ØPrDOZA11U
..
(
CL File No. : 57111 - 02018
Profile Permeameter Results
4.0" diameter Core - Standard Probe Tip
Depth Penneability Comment
Ka KI
(tt) (md) (met)
6123.20
6123.30
6123.40
6123.52
6123.60
6123.70
6123.80
6123.94
6124.03
6124.13
6124.23
6124.32
6124.42
6124.51
6124.63
6124.73
6124.83
6124.92
6125.03
6125.16
6125.23
6125.33
6125.43
6125.53
6125.63
6125.73
6125.83
6125.88
6126.04
6126.11
6126.20
6126.30
6126.39
6126.51
6126.61
6126.70
6126.80
6126.91
6126.99
6127.00
6127.11
6127.18
6127.30
6127.50
6123.2 - 6127.5
0.134 0.0595
0.0176 0.0039
0.809 0.517
4.66 3.57
2.47 1.80
5.07 3.91
1.06 0.700
2.75 2.02
6.43 5.04
9.88 8.02
4.01 3.05
3.39 2.54
5.35 4.16
1.43 0.978
123 0.828
1.63 1.14
1.77 1.24
1.25 0.849
1.73 1.21
1.91 1.35
1.36 0.927
1.27 0.862
1.60 1.11
0.409 0.232
1.66 1.16
2.58 1.88
1.27 0.861
1.91 1.35
11.4 9.38
8.52 6.82
5.70 4.45
3.02 2.24
4.94 3.81
4.81 3.69
0.122 0.0528
0.305 0.163
0.0117 0.0022
0.727 0.456
2.97 2.20
2.87 2.11
0.734 0.461
0.779 0.494
1.53 1.05
0.496 0.291
Depth Permeability Comment
Ka .. KI
(ft) (md) . (met)
6127.6 - 6131.8
6127.60 1.75 1.23
6127.70 1.28 0.870
6127.80 1.46 1.00
6127.91 1.38 0.939
6128.00 0.877 0.562
6128.11 1.66 1.16
6128.20 1.42 0.964
6128.30 1.20 0.803
6128.39 1.46 1.00
6128.50 1.42 0.972
6128.61 6.43 5.04
6128.71 8.94 7.20
6128.81 4.40 3.37
6128.89 7.19 5.70
6129.04 14.1 11.7
6129.11 4.40 3.35
6129.21 2.61 1.90
6129.31 5.35 4.15
6129.40 3.91 2.96
6129.51 1.62 1.13
6129.60 2.98 2.20
6129.70 2.83 2.08
6129.80 1.21 0.810
6129.93 9.35 7.53
6130.00 1.74 1.21
6130.10 6.04 4.70
6130.20 5.23 4.05
6130.30 11.0 8.99
6130.39 4.40 3.37
6130.50 1.59 1.10
6130.60 1.96 1.39
6130.69 0.508 0.301
6130.80 2.87 2.11
6130.82 11.2 9.21 lam
6130.91 1.63 1.13
6131.02 2.90 2.14 lam
6131.11 1.90 1.34 lam
6131.25 1.88 1.32
6131.31 3.35 2.51
6131.40 1.24 0.841
6131.50 1.67 1.16
6131.60 1.88 1.32
6131.74 6.65 5.23
6131.81 0.468 0.272
, . "
(
&.. . Phillips Petroleum Co., AK
~~ "Cirque" 3
CoreLab Kuparuk Field
:mnnlll OPTOOWIII
~
CL File No. : 57111 - 02018
Profile Permeameter Results
4.0" diameter Core. Standard Probe Tip
Depth Permeability Comment
Kà 1<1.
(ft) (md) (md)
6131.9 - 6136.2
6131.89 2.40 1.73
6132.03 1.70 1.19
6132.11 0.455 0.263
6132.18 4.10 3.12
6132.30 0.957 0.623
6132.40 0.879 0.564
6132.51 0.854 0.546
6132.60 1.44 0.987
6132.71 1.27 0.856
6132.80 0.893 0.575
6132.90 1.34 0.909
6133.01 1.68 1.18
6133.11 0.650 0.400 .
6133.20 0.831 0.533
6133.30 0.697 0.434
6133.41 2.06 1.47
6133.50 0.495 0.291
6133.60 0.632 0.387
6133.70 0.489 0.286
6133.81 1.55 1.07
6133.91 1.85 1.30
6134.00 1.70 1.19
6134.09 2.19 1.57
6134.20 4.76 3.65
6134.31 4.27 3.27
6134.40 1.61 1.12
6134.50 0.436 0.251
6134.61 1.20 0.806
6134.70 0.775 0.492
6134.80 0.509 0.300
6134.87 0.540 0.322
6135.03 2.88 2.12
6135.15 0.614 0.374
6135.20 1.53 1.06
6135.31 1.95 1.37
6135.40 1.75 1.23
6135.50 1.56 1.08
6135.61 1.24 0.840
6135.70 2.72 1.99
6135.80 3.41 2.55
6135.90 1.24 0.836
6136.00 0.864 0.554
6136.10 2.25 1.62 lam
6136.21 0.0734 0.0277
Depth Permeability Comment
Ka KI
(ft) (met) (md)
6136.3 - 6140.7
6136.30 0.317 0.172
6136.40 0.971 0.634
6136.50 0.306 0.165
6136.60 1.47 1.01
6136.70 3.35 2.51
6136.80 2.14 1.53
6136.90 0.398 0.225
6137.00 1.97 1.39
6137.10 3.51 2.63
6137.21 2.16 1.55
6137.30 4.84 3.72
6137.40 4.88 3.76
6137.56 3.11 2.31
6137.61 3.68 2.77
6137.70 6.91 5.45
6137.80 0.411 0.233
6137.89 0.536 0.319
6138.06 0.213 0.106
6138.20 0.433 0.249
6138.30 0.198 0.0972
6138.40 0.969 0.632
6138.50 0.312 0.168
6138.60 1.52 1.05 lam
6138.70 1.80 1.26
6138.80 4.28 3.25
6138.90 1.79 1.26
6139.00 0.681 0.422
6139.10 0.649 0.400
6139.20 0.829 0.531
6139.30 1.15 0.771
6139.39 3.47 2.60 lam
6139.50 1.07 0.705
6139.60 1.77 1.23
6139.70 0.460 0.266
6139.80 1.23 0.824
6139.90 4.21 3.21
6140.00 1.76 1.23
6140.10 0.159 0.0742
6140.20 4.71 3.61
6140.30 11.1 9.13
6140.40 7.46 5.90
6140.50 1.11 0.738
6140.60 1.32 0.894
6140.70 3.01 2.22
,i
,~
If
I ' . ,.
Î.... Phillips Petroleum Co., AK
8"\ "Cirque" 3
Con! Lab Kuparuk Field
IIlSDYIIIII D\"tD!lZAJ1JI
CL File No. : 57111 - 02018
Profile Permeameter Results
4.0" diameter Core - Standard Probe Tip
Depth ,Permeability Comment
Ka KI
(ft) (md) (md)
Depth Permeability Comment
Ka KI,
(ft) (md) (md)
6145.1 - 6149.5
1.35 0.919
4.96 3.83
16.8 14.2
17.8 15.1
2.80 2.06
0.760 0.480
0.127 0.0559
0.284 0.150
0.260 0.135
1.06 0.698
0.471 0.274
4.46 3.42
1.53 1.05
0.582 0.352
0.430 0.246
0.778 0.494
1.38 0.937
1.77 1.25
4.83 3.71
11.2 9.15
9.18 7.41
8.60 6.89
7.87 6.25
26.4 22.9
4.56 3.48
25.5 22.1
14.9 12.4
33.8 29.6
12.9 10.7
26.9 23.3
41.0 36.3
10.2 8.34
12.8 10.6
73.5 66.6
83.1 75.6
36.3 32.0
53.5 47.9,
52.9 47.4
56.9 51.1
20.9 17.8
41.9 37.1
32.0 28.0
54.8 49.1
51.1 45.6
6140.8 - 6145.0
0.957 0.622
1.61 1.12
7.44 5.92
3.66 2.76
20.4 17.4
2.20 1.58
0.793 0.504
5.10 3.94
4.32 3.31
0.0978 0.0400
9.88 8.02
1.27 0.859
0.275 0.145
0.438 0.251
0.493 0.289
3.83 2.90
7.05 5.57
7.21 5.71
4.19 3.18
6.82 5.38
0.783 0.497
7.92 6.30
8.14 6.48
7.60 6.02
6.62 5.21
5.52 4.29
2.34 1.69
1.01 0.664
3.97 3.01
1.19 0.798
1.55 1.07
0.593 0.359
1.23 0.823
17.1 14.4
1.62 1.12
3.98 3.02
6.79 5.36
5.07 3.91
6.92 5.46
26.4 22.8
13.8 11.4
2.99 2.21
2.18 1.56
8.97 7.23
6140.80
6140.90
6141.05
6141.14
6141.25
6141.32
6141.40
6141.50
6141.60
6141.70
6141.70
6141.80
6141.90
6142.00
6142.10
6142.21
6142.30
6142.40
6142.50
6142.61
6142.70
6142.81
6142.90
6143.00
6143.10
6143.20
6143.30
6143.40
6143.52
6143.60
6143.70
6143.80
6143.89
6144.07
6144.10
6144.21
6144.30
6144.40
6144.50
6144.60
6144.70
6144.81
6144.90
6145.00
6145.10
6145.20
6145.30
6145.40
6145.50
6145.60
6145.70
6145.81
6145.90
6146.00
6146.10
6146.20
6146.30
6146.40
6146.50
6146.60
6146.70
6146.80
6146.89
6147.03
6147.11
6147.27
6147.40
6147.50
6147.61
6147.70
6147.80
6147.90
6148.00
6148.10
6148.20
6148.30
6148.41
6148.51
6148.60
6148.70
6148.83
6148.90
6149.00
6149.10
6149.20
6149.29
6149.40
6149.51
(
Â~. Phillips Petroleum Co., AK
ð' "Cirque" 3
I:ore Lab Kuparuk Field
!lEUaRIA ØI'TD!I!ArIU
(
CL File No. : 57111 - 02018
Profile Permeameter Results
4.0" diameter Core - Standard Probe Tip
Depth penneability . Comment
Ka KI
(ft) (md) (md)
6149.6 - 6154.2
6149.61 93.6 85.5
6149.70 14.2 11.9
6149.80 28.2 24.5
6149.88 31.8 27.8
6150.07 47.2 42.1
6150.11 26.0 22.5
6150.21 32.4 28.4
6150.30 21.4 18.3
6150.40 48.5 43.2
6150.52 6.21 4.88
6150.62 69.3 62.7 lam
6150.70 5.76 4.50
6150.80 8.27 6.62
6150.90 1.10 0.734
6151.00 77.8 10.6
6151.11 6.63 5.22
6151.20 2.71 1.99
6151.32 8.37 6.70
6151.51 0.796 0.508
6151.60 2.60 1.89
6151.70 1.65 1.15
6151.80 0.694 0.431
6151.90 3.99 3.03
6152.01 0.704 0.439
6152.30 1.47 1.01
6152.41 1.47 1.01
6152.50 4.54 3.49
6152.60 5.58 4.35
6152.70 6.65 5.23
6152.79 2.85 2.09
6152.90 1.65 1.14
6153.06 13.2 11.0
6153.11 16.1 13.5
6153.20 1.82 1.28
6153.30 13.1 10.9
6153.40 4.19 3.20
6153.50 4.98 3.84
6153.60 1.70 1.19
6153.70 7.72 6.14
6153.80 7.31 5.80
6153.90 6.65 5.24
6154.02 4.41 3.38
6154.10 10.1 8.22
6154.20 13.0 10.8
Depth
Penneability
Ka . KI
(md) (rrid)
Comment
(ft)
6154.3 - 6158.6
6154.30 13.0 10.8
6154.40 10.4 8.45
6154.50 11.7 9.62
6154.60 3.96 3.01
6154.70 13.5 11.2
6154.60 7.41 5.89
6154.90 12.7 10.5
6155.00 0.684 0.421
6155.11 36.5 32.1
6155.22 0.574 0.345
6155.30 2.57 1.87
6155.40 1.54 1.06
6155.50 2.01 1.43
6155.60 12.3 10.2
6155.70 6.93 5.47
6155.80 9.23 7.46
6155.69 7.75 6.15
6156.05 8.64 6.94
6156.11 8.35 6.69
6156.20 10.6 8.63
6156.31 19.6 16.7
6156.40 0.470 0.273
6156.51 7.13 5.64
6156.61 5.71 4.43
6156.70 22.0 18.9
6156.80 24.3 20.9
6156.90 10.8 8.84
6157.00 6.98 5.51
6157.11 5.94 4.63
6157.21 4.87 3.73
6157.30 19.7 16.8 lam
6157.40 11.8 9.73
6157.50 22.2 19.1
6157.60 11.6 9.49
6157.70 14.5 12.1
6157.80 18.6 15.8
6157.90 8.46 6.78
6158.00 18.0 15.2
6158.10 9.33 7.54
6158.20 37.1 32.7
6158.30 93.9 85.8
6158.40 51.2 45.8
6158.49 96.1 88.0
6158.60 8.17 6.53
. , . ,.
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,{
I(
Â~.. Phillips Petroleum Co., AK
8' "Cirque" 3
Core Lab Kuparuk Field
WllnlR !PT1KJWIt
CL File No. : 57111 - 02018
Profile Permeameter Results
4.0" diameter Core - Standard Probe Tip
Depth Penneability Comment
Ka KI
..
(It) (md) (md)
Depth Penneability Comment
Ka KI
(ft) (md) (md)
6158.7 - 6162.9 6163.0 - 6168.0
6158.70 30.0 26.1 6163.01 37.7 33.3
6158.80 53.6 48.0 6163.14 60.5 54.4
6158.90 24.1 20.7 6163.59 99.4 91.0
6159.03 4.12 3.14 6163.72 92.8 84.7
6159.11 7.04 5.55 6163.81 42.8 37.9
6159.22 8.37 6.69 6163.91 65.3 58.9
6159.32 2.15 1.54 6164.00 50.7 45.3
6159.41 1.61 1.12 6164.11 22.5 19.3
6159.51 9.48 7.68 6164.21 25.9 22.4
6159.60 2.50 1.81 6164.37 15.4 12.9
6159.70 6.76 5.33 6164.48 19.1 16.2
6159.80 3.03 2.24 . 6164.61 36.3 31.9
6159.90 1.48 1.02 6164.72 30.3 26.4
6160.02 9.01 7.27 6164.84 47.9 42.7
6160.11 7.36 5.82 6164.90 16.6 14.0
6160.22 4.44 3.39 6165.06 23.5 20.2
6160.30 2.00 1.42 6165.11 43.7 38.8
6160.40 9.17 7.38 lam 6165.20 21.3 18.1
6160.50 10.6 8.64 6165.31 66.2 59.7
6160.60 4.13 3.15 6165.40 45.3 40.3
6160.70 3.19 2.38 6165.49 37.1 32.7
6160.80 12.6 10.4 sh lam 6165.59 3.38 2.53
6160.90 7.58 6.01 6165.71 22.3 19.0
6161.00 5.13 3.96 6165.80 21.3 18.3
6161.10 7.64 6.06 6165.90 16.9 14.2
6161.21 21.1 18.0 lams 6166.00 9.27 7.46
6161.30 8.57 6.88 6166.07 2.61 1.90
6161.40 2.73 2.00 6166.20 7.17 5.66
6161.50 5.96 4.65 6166.31 9.92 8.04
6161.60 6.98 5.52 6166.40 23.2 20.0
6161.70 10.6 8.66 6166.51 3.49 2.62
6161.80 13.6 11.3 6166.62 5.58 4.33
6161.90 26.1 22.6 6166.76 26.7 23.1
6162.00 7.41 5.88 6166.90 17.1 14.4
6162.11 29.9 26.1 6167.00 48.8 43.5
6162.20 60.5 54.5 6167.09 6.22 4.86
6162.30 0.939 0.574 6167.20 7.05 5.58
6162.40 3.37 2.53 6167.36 9.95 8.07
616~.40 21.8 18.6 6167.44 11.9 9.80
6162.50 14.1 11.7 6167.59 3.22 2.40
6162.60 7.22 5.72 6167.71 16.8 14.2
6162.70 6.30 4.94 6167.80 5.99 4.67
6162.82 9.46 7.63 6167.90 10.5 8.59
6162.91 18.9 16.0 6168.01 1.22 0.821
.. ,". ",'
('
¿., Phillips Petroleum Co., AK
~, "Cirque" 3
Core Lab Kuparuk Field
WDVnR 8Pl'DO%AJ1R
,,'
"~
CL File No. : 57111 - 02018
. Profile Permeameter Results
4.0" diameter Core - Standard Probe Tip
Depth , Penneability Comment
Ka 1(1
(ft) (md) (md)
6168.1 - 6172.4
6168.12 12.8 10.5
6168.20 2.35 1.70
6168.29 14.0 11.7
6168.38 23.7 20.4
6168.50 47.4 42.2
6168.60 2.28 1.64
6168.71 68.2 61.6
6168.79 50.8 45.4
6168.92 2.70 1.97
6168.99 7.93 6.30
6169.10 6.30 4.94
6169.20 6.05 4.72
6169.30 17.5 14.8
6169.40 14.8 12.4
6169.49 24.4 21.0
6169.60 11.4 9.34
6169.74 51.3 45.8
6169.83 4.37 3.34
6169.89 70.4 63.6
6169.99 8.15 6.50
6170.11 24.3 21.0
6170.18 9.39 7.58
6170.34 18.0 15.2
6170.40 7.31 5.77
6170.51 9.08 7.33
6170.60 7.94 6.32
6170.71 9.91 8.06
6170.79 13.3 11.1
6170.90 24.6 21.2 lams
6171.04 3.54 2.66
6171.11 2.37 1.72
6171.20 1.03 0.675
6171.30 0.894 0.576
6171.41 3.44 2.58
6171.51 3.40 2.54
6171.60 8.19 6.55
6171.70 1.76 1.23
6171.79 1.18 0.788
6171.89 0.508 0.300
6172.03 6.10 4.76
6172.11 16.1 13.5
6172.20 12.2 10.0
6172.30 14.1 11.7
6172.41 7.36 5.84
Deþth Penneability Comment
Ka KI
(ft) (md) (md)
6172.51
6172.60
6172.71
6172.81
6172.88
6172.99
6173.10
6173.21
6173.28
6173.40
6173.50
6173.61
6173.71
6173.80
6173.95
6174.03
6174.11
6174.20
6174.30
6174.40
6174.49
6174.60
6174.71
6174.79
6174.91
6175.01
6175.10
6175.17
6175.30
6175.40
6175.50
6175.60
6175.71
6175.81
6175.88
6176.01
6176.11
6176.21
6176.30
6176.40
6176.52
6176.62
6176.72
6176.80
6172.5 - 6176.8
11.7 9.62
4.76 3.66
14.1 11.7
9.74 7.90
29.1 25.3
24.6 21.2
51.7 46.3
96.1 88.0
39.1 34.6
101. 92.9
33.3 29.2
6.86 5.42
7.45 5.91
9.70 7.86
21.3 18.2
10.8 8.83
20.1 17.2
12,9 10.6
5.62 4.38
3.04 2.25
2.80 2.06
1.51 1.03
14.0 11.7
9.63 7.80
8.56 6.87
26.4 22.8
3.25 2.42
7.17 5.65
5.52 4.27
9.46 7.65
7.85 6.25
8.94 7.21
11.2 9.23
1.59 1.10
3.05 2.26
9.55 7.73
18.1 15.3
11.9 9.77
33.5 29.3
36.0 31.6
19.1 16.2
12.2 10.0
19.2 16,3
43.0 38.1
.,-
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"' " , ..,
6.. Phillips Petroleum Co., AK
~~ "Cirque" 3
Cort! Lab Kuparuk Field
mDVOIII onooz.utu
CL File No. : 57111 - 02018
Profile Permeameter Results
4.0" diameter Core - Standard Probe Tip
Depth Permeability Comment
Kå . KI
(it) (md) (md)
Depth Penneability Comment
Ka KI.
(ft) (md) (md)
6184.7- 6189.2
9.52 7.69
12.5 10.3
14.3 11.9
21.2 18.1
15.5 13.0
6.03 4.71
8.10 6.46
13.1 10.9
6.08 4.74
6.19 4.85
6.29 4.92
7.80 6.19
11.5 9.41
4.92 3.79
9.54 7.72
17.6 14.9
4.36 3.34
11.7 9.59
7.30 5.76
10.5 8.52
9.32 7.54
27.0 23.3
0.0170 0.0038
11.4 9.32
13.3 11.1
15.2 12.7
4.28 3.28
4.43 3.37
24.3 21.0
14.4 12.0
10.1 8.24
4.42 3.39
18.6 15.7
22.5 19.3
17.6 14.9
14.2 11.8
3.91 2.97
2.32 1.68
4.30 3.27
6.96 5.50
7.63 6.07
12.0 9.84
9.10 7.35
9.37 7.58
6176.9 - 6184.6
29.5 25.7
13.1 10.9
3.94 2.99
5.41 4.20
11.7 9.61
3.51 2.63
13.4 11.1
3.77 2.85
7.62 6.05
3.40 2.54
9.78 7.92
1.72 1.20
6.57 5.16
7.00 5.53
20.0 17.1
7.23 5.72
24.7 21.3
12.4 10.2
21.7 18.6
23.0 19.8
3.78 2.86
18.2 15.4
26.8 23.3
7.18 5.69
479. 456.
6.29 4.92
6.66 5.24
5.39 4.18
13.3 11.0
82.4 75.0
101. 92.4
28.5 24.7
$0.5 26.6
3.48 2.60
10.7 8.73
6.05 4.75
32.1 28.1
38.8 34.2
2.79 2.05
7.38 5.84
6.13 4.79
3.13 2.32
18.4 15.6
7.86 6.27
6184.70
6184.78
6184.89
6185.02
6185.22
6185.32
6185.51
6185.58
6185.71
6185.81
6185.88
6186.03
6186.13
6186.21
6186.31
6186.41
6186.50
6186.60
6186.72
6186.80
6186.91
6187.06
6187.17
6187.21
6187.31
6187.41
6187.53
6187.61
6187.72
6187.81
6187.92
6188.00
6188.09
6188.24
6188.30
6188.41
6188.51
6188.61
6188.70
6188.80
6188.89
6189.04
6189.11
6189.21
6176.91
6177.08
6177.20
6177.30
6177.41
6177.50
6177.60
6177.71
6177.81
6177.90
6178.01
6178.09
6178.22
6178.32
6178.39
6178.49
6178.61
6178.75
6178.82
6178.93
6179.00
6179.10
6179.72
6179.90
6179.92
6180.03
6180.09
6180.21
6180.63
6180.73
6180.80
6181.65
6181.79
6181.90
6181.99
6183.07
6183.80
6184.02
6184.11
6184.21
6184.30
6184.41
6184.50
6184.63
,~
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I"
,
.6.. Phillips Petroleum Co., AK
~~ "Cirque" 3
Core Lab Kuparuk Field
w[JveD! ØJ'1'IMJZAJtII
{
CL File No. : 57111 - 02018
Profile Permeameter Results
4.0" diameter Core - Standard Probe Tip
Depth Penneability Comment
Ka KI
(ft) (md) (md) ,
6189.3 - 6193.7
6189.30 6.54 5.14
6189.41 8.91 7.16
6189.51 24.5 21.1
6189.60 18.5 15.7
6189.71 15.7 13.2
6189.80 12.2 10.1
6189.91 12.6 10.4
6190.02 12.4 10.3
6190.18 8.24 6.58
6190.30 6.50 5.10
6190.40 6.37 4.99
6190.51 13.6 11.3
6190.61 13.6 11.3
6190.71 14.4 12.0
6190.81 4.56 3.49
6190.90 4.13 3.15
6191.02 7.32 5.79
6191.10 0.495 0.290
6191.25 25.0 21.6
6191.32 17.5 14.8
6191.44 14.1 11.8
6191.51 16.5 13.9
6191.60 6.60 5.18
6191.70 6.88 5.43
6191.80 7.18 5.69
6191.91 11.4 9.40
6192.05 13.0 10.7
6192.12 27.9 24.2
6192.21 19.2 16.3
6192.33 20.9 17.9
6192.41 23.2 20.0
6192.50 21.2 18.1
6192.61 1.28 0.867 shale
6192.69 5.05 3.90
6192.79 5.09 3.93
6192.90 11.1 9.07
6193.01 5.86 4.56
6193.11 7.67 6.09
6193.21 11.8 9.70
6193.31 8.05 6.42
6193.41 8.21 6.55
6193.51 7.06 5.59
6193.60 4.26 3.26
6193.71 6.36 4.99
Depth Permeability Comment
Ka KI
(tt) (md) (md)
6193.81
6193.91
6194.00
6194.10
6194.21
6194.30
6194.40
6194.50
6194.62
6194.70
6194.81
6195.05
6195.11
6195.21
6195.29
6195.42
6195.50
6195.60
6195.71
6195.80
6195.90
6196.00
6196.11
6196.20
6196.31
6196.41
6196.51
6196.61
6196.71
6196.90
6197.05
6197.10
6197.20
6197.30
6197.41
6197.50
6197.61
6197.80
6197.90
6198.03
6198.10
6198.21
6198.32
6198.40
6193.8 - 6198.4
10.3 8.39
9.76 7.92
8.12 6.47
5.32 4.12
5.12 3.96
10.2 8.29
5.93 4.62
9.20 7.40
4.05 3.08
5.43 4.22
6.81 5.34
0.476 0.277
0.727 0.455
0.218 0.109
1.23 0.820
3.81 2.88
9.91 8.05
9.75 7.91
4.99 3.84
8.24 6.58
3.65 2.74
14.2 11.9
6.79 5.35
1.76 1.23
1.47 1.01
1.30 0.878
1.17 0.786
0.305 0.164
0.530 0.315
1.91 1.35
2.09 1.49
2.88 2.12
3.96 3.01
2.47 1.79
3.54 2.67
2.90 2.14
7.82 6.23
3.77 2.85
2.90 2.14
8.84 7.10
3.86 2.93
3.41 2.56
6.62 5.22
7.74 6.16
,. . " I~' (
. Phillips Petroleum Co., AK CL File No. : 57111 - 02018
. . "Cirque" 3
Core Lab Kuparuk Field
wnnJII 8mMJZmØ
Profile Permeameter Results
4.0" diameter Core - Standard Probe Tip
Depth Permeability Comment Depth Penneability Comment
Ka KI Ka .. KI
(It) (met) (md) crt) (met) (md)
6198.5 - 6202.9 6203.0 - 6207.5
6198.50 3.63 2.74 6203.00 0.134 0.0598
6198.58 6.06 4.74 6203.10 0.0648 0.0234
6198.70 8.55 6.85 6203.20 0.108 0.0455
6198.81 5.67 4.42 6203.30 0.0916 0.0368
6198.93 1.95 1.39 6203.40 0.138 0.0619
6199.01 1.36 0.929 6203.50 0.477 0.278
6199.12 12.7 10.5 6203.84 53.2 47.6
6199.23 14.5 12.1 6203.94 76.8 69.7
6199.31 5.81 4.52 6204.05 37.3 32.9
6199.40 5.31 4.12 6204.11 96.8 88.6
6199.50 3.38 2.54 6204.21 30.4 26.5
6199.62 3.18 2.37 6204.29 56.4 50.6
6199.70 1.73 1.21 6204.42 8.99 7.22
6199.81 1.90 1.34 6204.52 0.970 0.633
6199.90 3.18 2.37 6204.62 35.4 31.2
6200.00 3.42 2.56 6204.71 5.17 4.00
6200.11 3.05 2.26 6204.78 0.182 0.0874
6200.20 2.74 2.01 6204.83 0.565 0.340
6200.40 3.37 2.52 6204.92 17.9 15.1
6200.50 1.64 1.14 6205.01 3.06 2.28
6200.60 1.28 0.860 6205.10 3.07 2.28
6200.70 3.55 2.67 6205.27 4.24 3.24
6200.82 3.23 2.41 6205.40 5.65 4.38
6200.90 3.14 2.33 6205.51 10.2 8.28
6201.02 3.03 2.25 6205.60 1.53 1.06
6201.11 3.03 2.25 6205.70 0.810 0.517
620'1.20 2.61 1.91 6205.80 0.469 0.273'
6201.31 3.05 2.26 6205.90 0.422 0.241
6201.40 4.55 3.48 6206.03 1.08 0.717
6201.50 3.26 2.43 6206.11 0.245 0.126
6201.60 3.96 3.01 6206.20 0.338 0.185
6201.70 3.22 2.40 6206.30 2.02 1.44
6201.80 3.36 2.51 6206.41 0.0941 0.{)381
6201.90 2.76 2.02 6206.50 0.139 0.0629
6202.00 2.77 2.04 6206.58 0.996 0.652
6202.13 3.08 2.29 6206.70 1.54 1.07
6202.20 3.85 2.92 6206.80 0.807 0.515
6202.30 1.16 0.779 6206.90 1.10 0.734
6202.40 0.0773 0.0296 clast 6207.06 2.13 1.52
6202.50 0.557 0.334 6207.11 2.48 1.80
6202.61 0.254 0.132 6207.21 1.70 1.19
6202.71 0.172 0.0819 sh 6207.30 1.08 0.716
6202.83 0.174 0.0828 6207.40 1.70 1.18
6202.91 0.0708 0.0263 6207.50 1.49 1.03
".' .~.
It
~ Phillips Petroleum Co., AK
,,:.a'l "Cirque" 3
Core Lab Kuparuk Field
JIlsnYtIR ðPmllZA%ltll
(
CL File No. : 57111 - 02018
Profile Permeameter Results
4.0" diameter Core - Standard Probe Tip
Depth Permeability Comment
Ka KI
(1t) (md) (md) .
6207.6 - 6212.0
6207.60 1.14 0.763
6207.71 0.895 0.577
6207.80 1.75 1.22
6207.90 1.87 1.32
6208.01 1.30 0.883
6208.10 1.89 1.34
6208.25 1.35 0.917
6208.38 2.91 2.15
6208.50 2.06 1.47
6208.61 8.46 6.77
6208.70 2.57 1.87
6208.80 4.55 3.48
6208.90 1.07 0.706
6209.02 1.82 1.23
6209.10 10.2 8.33
6209.20 2.78 2.04
6209.30 3.20 2.39
6209.40 4.28 3.28
6209.50 3.48 2.61
6209.60 1.98 1.40
6209.70 2.41 1.75
6209.80 2.50 1.82
6209.90 1.80 1.26
6210.03 1.60 1.11
6210.10 4.37 3.35
6210.20 2.82 2.07
6210.30 3.34 2.50
6210.40 3.50 2.62
6210.50 2.07 1.47
6210.60 3.23 2.41
6210.70 1.53 1.06
6210.80 1.16 0.777
6210.90 1.60 1.11
6211.02 1.17 0.782
6211.10 1.33 0.901
6211.20 1.53 1.05
6211.29 1.44 0.984
6211.40 0.816 0.522
6211.50 0.956 0.623
6211.60 1.41 0.967
6211.70 1.38 0.939
6211.78 3.34 2.50
6211.92 1.18 0.795
6212.02 0.918 0.594
Depth Penneability Comment.
Ka KI
(ft) (md) (md)
6212.11
6212.20
6212.31
6212.40
6212.50
6212.60
6212.70
6212.78
6212.91
6213.04
6213.10
6213.20
6213.30
6213.40
6213.50
6213.60
6213.70
6213.80
6213.90
6214.00
6214.11
6214.16
6214.40
6214.50
6214.60
6214.70
6214.80
6214.90
6215.01
6212.1 - 6215.0
2.46 1.79
2.18 1.56
4.94 3.81
0.646 0.397
0.510 0.301
0.145 0.0658 sh
0.0960 0.0391
0.397 0.224
0.171 0.0811
0.918 0.594
0.818 0.523
0.776 0.492
0.619 0.377
1.56 1 .08
2.19 1.57
2.30 1.66
1.67 1.17
2.53 1.84
1.41 0.967
2.06 1.47
8.79 7.05
19.1 16.2
0.431 0.247
0.497 0.292
1.24 0.834
0.323 0.176
0.799 0.509
0.143 0.0648
0.186 0.0901
~
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Â, ',' Phillips Petroleum Co., AK
ð\ "Cirque" 3
Core LaI:Ï Kuparuk Field
I e;x I
C-1
1
2 .
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
Core Inventory
Depth
Interval
6123.0. 6215.0
6123.0 - 6129.0
6129.0 - 6135.0
6135.0 - 6141.0
6141.0 - 6147.0
6147.0 - 6152.0
6152.0 - 6158.0
6158.0 - 6164.0
6164.0 - 6170.0
6170.0 - 6176.0
6176.0 - 6182.0
6182.0 . 6184.0
6184.0 - 6190.0
6190.0 - 6196.0
6196.0 - 6202.0
6202.0 - 6208.0
6208.0 - 6214.0
6214.0 - 6215.0
"
!,
~
CL File No. : 57111 - 02018
Core Chip Description Described By R. A. Levinson
Cirque # 3 API 50-103-20399-00 Date --
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VO <:l:J. «.o Vo e:,° ~o'ii ~<:' ð qf 4- ~0 <lot' e:,"" Q"" if v-t <ö cP
al chip ex, vg. g. I,
MD ex,g,l,p w,m,p ex,g,l.p,n scale ex, vg, g, I, P. vP vs,s,m,w,vw,n y,n p, vp
20% qtz, 65% carb Irags, grains
sub r - ~hic+feld, muscov~e, altered 10 parallel Lot of carb frags on
15 6164 Bermuda 9 w P lam silty ss med gray uvfgr-si~ mod sang 15%biot~<H<:lay gr glauc wMe clay sl calc vlhin lams p vw lams, v. fn gr. no show
20 % qtz, 65% carb Irags, 100% abdnl carb frags on
sub r - ~hic+leld, muscov~e, parallel 98% brig hi instant lams, good show in lam
16 6167 Bermuda 9 w P ss gray Ian ufn-uvfn mod-well sang 15'Y.biot~<H<:lay gr glauc sl calc Ihin lams I vs Ian yellow blue-wMe y ex sd
grains
altered 10
20% qtz, 650% carb Irags, wMe clay,
sub r- ~hic+feld, muscov~e, rust colored parallel
17 6170 Bermuda 9 w f 55 ~ gray uvfn well sang 15%biol~e-H:lay gr glauc wispy lams calc thin lams l-p w no show
20'Y. qtz, 65% carb frags. grains 100% -,
sub r- ~hic+leld, muscov~e, a~ered 10 100%~bright instant
18 6173 Bermuda g w fog lam ss ~ gray uvfn well sang 15'Y.biot~e-H:lay gr glauc wh~e clay sl calc carb lams f vs Ian yellow blue-wh~e y ex ok sd. great show
20% qtz, 65% carb frags, grains low angle 100%
sub r - ~hic+feld, muscov~e, a~eredto pinch and 75'Y. ~ bright instant
19 6176 Bermuda g w fog lamss ~ gray uvfn well sang 15%biot~<H<:lay gr glauc wh~e clay sl calc swell carb lams I s tan yellow blue-wh~e y ex ok sd, greal show
25'Y. qtz, 65% carb Irags, grains 25%
sub r - ~hic+feld, muscov~e, a~ered 10 carb cross 25'Y.1I bright milky blue.
20 6179 Bermuda 9 w fop lam ss ~ gray uv fn-Mn mod-well sang 10%biom<H<:lay gr glauc wh~e clay sl calc thin lams I-p w Ian yellow wh~e p
25% qtz, 65% grains lainl lam is lam is abdnl carb frags on
sub r - IIhic+leld. a~ered to parallel carb Ian on brighl milky blue. lams, lam with show is 2
21 6182 Bermuda 9 w p lam ss II gray Mn-uvfn-sm mod-well sang 1 O%biom<H<:lay gr carb Irags wh~e clay sl calc Ihin lams p m lam yellow wh~e f mm thick
25% qtz, 65% carb frags, grains broken 100%
~ gray- sub r- ~hic+leld, muscov~e. allered to lams. shale pale brighl instant
22 6184 Bermuda 9 w f lamss Ian mn-Mn mod-well sang 10%biol~<H<:lay gr glauc wh~e clay sl calc rip-ups f s tan yellow milky blue y ex shale rip-ups
some lams are
25'Y. qtz, 65'Y. carb frags. grains v calc, some Ihin, broken abdnt organic material in
lam ss and carb med gray sub r - ~hic+feld, muscov~e, allered to lams are sl pinch and lams. shale lams. Sd60'Y. sarb lams
23 6187 Bermuda 9 w I shale brown uvfn-sill mod sang 10%biot~<H<:lay gr glauc wh~e clay calc swell rip-ups p w 40%.
15% qtz, 75% carb frags, grains abdnl organic material in
lam 55 and carb med gray subr- IIhic+feld, muscov~e, allered 10 lams. Sd60% sarb lams
24 6190 Bermuda g w f shale brown uvfn-sill mod sang 1 O'Yobiol~<H<:lay gr glauc wh~e clay calc thin cross lams p vw 40%.
20% qtz, 70% carb frags. grains 100%
sub r - IIhic+leld,l O%bioti muscov~e, altered to subtle cross 100% brighl inslant ~'-
25 6193 Bermuda 9 w fog ss Ian upfn-upvfn mod-well sang te-H:lay gr glauc wh~e clay sl calc lams vs tan yellow blue wh~e y ex fair reservoir, great show
20% qtz, 70% grains subtle
sub r - ~hic+feld, carb Irags, altered 10 graded 90% 9O%brigh instant ok reservoir, very good
26 6196 Bermuda 9 w I ss gray-Ian IIn-Mn mod-well sang 1 O%biol~<H<:lay gr glauc wh~e clay calc bddg no lams! g-I s tan I yellow blue milky y vg show
15% qtz, 75% grains
sub r - IIhic+feld, carb frags, allered 10 v subtle some carb Irags. no
27 6199 Bermuda g w I ss II gray uvfn-sll mod-well sang 10%biot~<H<:lay gr glauc wh~e clay calc carb lams I-g vw show
25'Y. qtz. 65% clay frags, grains
sub r - ~hic+feld,1 O%bioti carb frags, aile red 10 v_subtle v fn gr reservoir, no
28 6202 Bermuda 9 w I-g sclst II gray uvfn-Mn well sang 1<H<:lay gr glauc wh~e clay sl calc cross lams fop vw show
25% qtz, 65% clay frags, grains 95'Y.
sub r - IIhic+feld, carb frags, allered 10 sublle cross 95% bright inslant nice strong pelro odor.
29 6205 Bermuda g w I-g sclsl dktan IIn-Mn mod-well sang 10'Y.biom<H<:lay gr glauc, pyrite wh~e clay v. calc lams I-g s tan yellow blue milky y vg great show
ash wI abdnt 15'Y.
biome, other bright
opaques, floating probably a silica?, zeal? yellow in slow blue I~hology change from
30 6208 Bermuda 9 w, hard n sandy luff II gray Mn-clay qtz grains few non calc none nr vw plchs milky vp rocks above--v. ashy
Core Chip Description Described By R A. levinson
Cirque # 3 API 5()'103-20399-00 Date -
.. B-~o~ -~ $' 0~~ J.0~ ,j~ ,s.
ú'tQ. ~o~ -þ'it ~o{> ~ <b4-0 # 0\0 ~'" ~.f r;>.J>;,§:\ ~ ~ 0' 0'
ú<F' ~ B-~~ #0'd>°' ~O #of' ~
~ ,<o~ è§' -.:.° -.:.° <;,0' ç:l~ -.:.~~ ;::.ò'" 0~ ",&'" o' o# -i$>'" x-.'ii x-.'ii
~0 <:)0Q. ú'tQ. úO~'? 4,{,'f ,};-O ~o~ «p'ii ~'" ð ~l <1'" r!'d>~ ~t' ~,'Þ' <:)~ ~ ú~ ~'f' úO
úO C; C; q;.0
at chip ex, vg. g. f,
MD ex,g,I,p w,m,p ex,g,I,p,n scale ex, vg, g, I, p, vp vs,s,m,w,vw,n y,n p, vp
ash wI abdnt 100/0
biot~e, other bright
opaques, floating probably a silica?, zeol? yellow in slow blue
31 6211 Bermuda g w, hard n sandy-slly tuff ~ gray IIn-clay qtz grains few non calc none nr vw ptchs milky vp ashy
ash wI abdnt
biot~e, other
opaques, floating probably a silica?, zeol? ashy, fracture filled with
32 6214 Bermuda I w, hard n sdy-slly tuff ~ gray uvln-clay qtz grains few non calc none nr clear qtz
ash wI abdnt probably a silica?, zeol?
33 6215 Bermuda I w, hard n sdy-slly tuff ~ gray Ivn-clay biot~e. other few non calc none or ashy
~-.
~,
"
(,
("
PHILLIPS PHilliPS Alaska, Inc.
m A Subsidiary of PHilLIPS PETROLEUM COMPANY
TRANSMITT AL
CONFIDENTIAL DATA
FROM:
Sandra D. Lemke, ATO1486
Phillips Alaska, Inc.
P.O. Box 100360
Anchorage AK 99510-0360
TO:
Lisa Weepie
AOGCC
333 W. 7th, Suite 100
Anchorage, Alaska 99501
RE: Cirque 3
PERMIT 201-244
DATE: 04/04/02
Delivery: Hand carried
Transmitted herewith is the followinQ:
Qrn!de 3 50 tQJ2039900
Core Labs
~/CD ROM- Core Labs Digital core Photos, CL Job 020230, 3/2002, UVand Natural light
Please check off each item as received, sign and return one of the two transmittals enclosed to address below.
The other copy is for your records.
All data to be held confidential until State of Alaska designated AOGCC release date
CC: Laurel Alexander, PAl Geologist
Approved for transmittal by: S. Lemke
(~~
Phillips Alaska, Inc.
AlTN: S. Lemke, ATO-1486
700 G. Street
Anchorage, AK 99501
RECEIVED
Receipt:
Return receipt to:
A PR :) 2002
Date:
AIiiiiœ&=~
Prepared by: Sandra D. Lemke
Phillips Alaska IT Technical Databases
.'
)
(
TRANSMITT AL
CONFIDENTIAL DATA
FROM:
Sandra D. Lemke, ATO1486
Phillips Alaska, Inc.
P.O. Box 100360
Anchorage AK 99510-0360
TO:
Lisa Weepie
AOGCC
333 W. ih, Suite 100
Anchorage, Alaska 99501
RE: Cirque 3
PERMIT 201-244
DATE: 03/11/02
Delivery: Hand carried
Transmitted herewith is the folloWlnQ:
Qrgye 3 SQJ.O32039900
Schlumberger
CD ROMS
V'" Open Hole edits; logged 1/29/2002; Job 22081; comments: CMR DSI FMI (field data)
,// Dipole Sonic; logged 1/29/2002; Job 22052; comments Processed Dipole Sonic DT's and FMI
directional/Caliper/field DSI in DLIS files (Answer CD)
~/ Processed CMR Data; logged 1/29/2002; Job 22053; comments: contains CMR data and displays
Blueline prints
v" Sonic Log Dipole Shear 1/29/2002
v" Combinable Magnetic Resonance Tool 1/29/2002
Color Logs
~Fullbore Formation Micro Imager 1/29/2002 (field data)
--LCMR DMRP Processing, Job 22053, logged 1/29/02; processed 2/4/2002
Sperry Sun
CD ROM
VMWD EWR/ROP/DGR and DGR/CNP/SLD LIS Data and digital log images
Disk
1/ MWD directional survey data; Survey 9837;
Bll!eline prints
¡/ MWD ROP/DGR/EWR TVD 2" & 5"
1MWD ROP/DGR/EWR MD 2" & 5"
~MWD DGR/CNP/SLD MD 2" & 5"
LMWD DGR/CNP/SLD TVD 2" & 5"
1/29/2002; w/ printout
~
",.
\
("
Epoch Mud logging Data
---LEnd of well report with color logs of Formation Log MD/Formation log TVD/ Drilling Dynamics/DML-MWD Combo
~~eport CD ROM containing LAS data; Final well report, morning reports, drilling and lithology remarks files
/
I
~Sepia paper- Formation log 2"=100'
Please check off each item as receivect sign and return one of the two transmittals enclosed to address below.
The other copy is for your records.
All data to be held confidential until State of Alaska designated AOGCC release date
CC: Laurel Alexander, PAI Geologist
Approved for transmittal by: S. Lemke
RECEIVED
Receipt:
Return receipt to:
(>f~ Cc~~"J
Phillips Alaska, Inc.
ATTN: S. Lemke, ATO-1486
700 G. Street
Anchorage, AK 99501
Date:
r~j\R 1 '1 2002
Alaska Oil & Gas Cons. COIIIIIiIion
Anchorage
Prepared by: Sandra D. Lemke
Phillips Alaska IT Technical Databases
.".
('
('
PHilliPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
Post Office Box 100360
Anchorage, Alaska 99510-0360
P. Mazzolini
Phone (907) 263~603
Fax: (907) 265-6224
February 20,2002
Commissioner Cammy Oechsli Taylor
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Subject: Cirque #3 (201-244/302-046) Completion Report
Dear Commissioner:
Phillips Alaska, Inc., as operator of the Cirque #3 exploration well, submits the attached "Well
Completion Report" (AOGCC form 10-407). Other attachments to the completion report include
the directional survey, report of daily well operations, core description and P&A summary. We will
send under separate cover the logs, the mud logs, and other well data and reports.
The Commission is requested to keep confidential the enclosed information due to the exploratory
nature of this well. If you have any questions regarding this matter, please contact me at 263-4603
or Mark Chambers at 265-1319
Sincerely,
?-J!q~
P. Mazzolini
Exploration Drilling Team Leader
P AI Drilling
RECE\VED
fEB 2 1 2002
Alaska Oil &. Gas Cons. Commission
Anchorage
PM/MC/skad
OR I Gf NAL
( STATE OF ALASKA (
ALASKA OIL AND GAS CONSERVATION GlJlVlMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of well Classification of Service Well
Oil D Gas 0 Suspended 0 Abandoned 0 Service D
2. Name of Operator 7. Pennit Number
Phillips Alaska, Inc. 201-244 1 302-046
3. Address 8. API Number
P. O. Box 100360, Anchorage, AK 99510-0360 ; I I 50-103-20399-00
4. location of well at surface . :;"-::::;'~:":~~"~:,~;~': -, ~1DC:A.P*~~1J 9. Unit or lease Name
378' FNL, 486' FEL, Sec. 28, T9N, A7E, UM "-';I"r~:"'_:' ,. . '(ASP: 455748,5890540) I...... ~..... Exploration
At Top pr~dUCing Interval ~, :z. . ~(~-:~~. ; 1'~~' 10. Well Number
Cirque #3
Not applicable . -,,-,. -,-" i I ~ ~ '"'
) 1;",.'." ,~,.. ~I '~....""""'-"......-.-:r"i-~
At Total Depth J -h-------: .:;~-,,-..,..-,,-~.........~~ 11. Field and Pool
1969' FSL, 1385' FEL, Sec. 21, T9N, A7E, UM"",--------,.w--""(ASP: 454859, 5892891)
5. Elevation in feet (indicate KB, DF, etc.) 6. lease Designation and Serial No. Exploration
28' AKB ADL 375077 ALK 4295
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions
January 19, 2002 January 29, 2002 February 1 , 2002 (P&A'd) N/A feet MSL 0
17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost
6677' MD / 6096' TVD surface YES 0 No 0 N/A feet MD 1330'
22. Type Electric or Other logs Run
GRlAes/NeutlDens, Sonic, CMA
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PUllED
16" 62.5# H-40 Surface 108' 24" 213 sx AS 1
9.625" 40# L-80 Surface 2412' 12-1/4" 410 sx AS Lite, 251 sx LiteCrete
Plug #1: 6677' - 5896'
Plug #2: 4833'- 4480',4691' - 4466'
Plug #3: 2512' - 2287'
Plug #4: 300' to surface
24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
N/A N/A N/A
None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
Plug 1: 6677' - 5896' 108 sx LiteCrete
Plug 2: 4833' - 4480', 4691' - 4466' 199 sx Class G
Plug 3: 2512' - 2287' 82 sx Class G
Plug 4: 300' to surface 139 sx AS 1
27. PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
N/A Plugged & Abandoned
Date of Test Hours Tested Production for Oll-BBl GAS-MCF WATER-BBl CHOKE SIZE GAS-Oil RATIO
N/A Test Period>
Flow Tubing Casing Pressure Calculated Oll-BBl GAS-MCF W A TER-BBl Oil GRAVITY - API (corr)
Press. 24-Hour Rate>
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.
RECEIVED
See Attachment
FEB 2 1. 200Z
Alaska Oil & Gas Coos. Commission
,Ancoorage
Form 10-407 Rev. 7-1-80
CONTINUED ON REVERSE SIDE
()RIGI¡~t\L
R B n ~~ S R F l
MAR
Submit in duplicate
5 2002 (, F
29.
GEOLOGIC M'A~I\t..MS
30.(
FORMATION TESTS
MEAS.DEPTH
TRUE VERT. DEPTH
Include interval tested, pressure data, all fluids recovered and gravity.
GOR, and time of each phase.
NAME
Base West Sak
Iceberg
Base Iceberg
Top Bermuda
Base Bermuda
2049'
4680'
4732'
6096'
6247'
N/A
.
31. LIST OF ATTACHMENTS
Summary of Operations, Directional Survey, Core Description, P&A Summary
32. I hereby certify that the following is true and correct to the best of my knowledge.
Questions? Call Mark Chambers 265-1319
Signed fLJ. J11~~
Paul Mazzolim
Title
Drillina Team Leader
02/
. . Ie¡ IZo::;2-
Date
Prepared by Sharon Allsup-Drake
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and
leases in Alaska.
Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water
supply for injection, observation, injection for in.situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other
spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in
item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each
additional interval to be separately produced, showing the data pertinent to such interval.
Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location
of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection,
Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
RECEIVED
Form 10-407
FEB 2; 1 2002
"'J' t""'\~ \ ~~"". . \ ~.'\l.' A', l
f ' ,I ,I
\, , ,,',' ~ ..,.¡
l'I\I~J!t,:1 .-
Alaska Oil &; Gas Cons. Gommissiol1
.Anchorage
,(
,
Page 1 of 6
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name: Cirque #3
Common Well Name: Cirque #3
Event Name: ROT - DRILLING
Contractor Name: Doyon
Rig Name: Doyon 141
Date From - To Hours Code Sub Phase
Code
1/17/2002 00:00 - 18:30 18.50 MOVE RURD MOBMIR
18:30 - 21 :00 2.50 DRILL RIRD SURFAC
21 :00 - 00:00 3.00 DRILL RIRD SURFAC
1/18/2002 00:00 - 01 :00 1.00 DRILL SFTY SURFAC
01 :00 - 18:00 17.00 DRILL PULD SURFAC
1/19/2002
18:00 - 00:00
00:00 - 10:00
10:00 - 11 :00
11 :00 - 00:00
6.00 WAlTON WOW SURFAC
10.00 WAlTON WOW SURFAC
1.00 DRILL
13.00 DRILL
RIRD SURFAC
DRLG SURFAC
1/20/2002 00:00 - 07:00 7.00 DRILL DRLG SURFAC
07:00 - 08:00 1.00 DRILL CIRC SURFAC
08:00 - 11 :00 3.00 DRILL WIPR SURFAC
11 :00 - 12:00
12:00 - 12:30
12:30 - 13:30
13:30 - 20:30
20:30 - 00:00
1.00 DRILL
CIRC
SURFAC
0.50 DRILL
1.00 DRILL
WIPR SURFAC
CIRC SURFAC
7.00 DRILL
DRLG SURFAC
3.50 DRILL
CIRC
SURFAC
Spud Date: 1/19/2002
End: 2/2/2002
Group:
Start: 1/16/2002
Rig Release: 2/2/2002
Rig Number: 141
Description of Operations
Move rig from 2P-448 to Cirque #3, R/U Doy
on rig 141 to drill Cirque #3 well.
R/U Diverter system and test. AOGCC inspec
tor Chuck Cheve witnessed test Rig was ac
cepted at 2100 hrs 01/17/2002
Load pipe shed with DP and BHA, Mix spud
mud
Pre-spud and safety meeting with all crews
and service personal.
P/U 5" DP, 5 HWDP, 4" DP, 3 1/2" HWDP an
d stand back in derrick, P/U non mag DC's,
stabilizers, MWD, Mud motor and associated
BHA needed to drill with. Test MWD and Mo
tor and make sure everything is ready to dri
II ahead. Spud mud is mixed and ready.
Operations on hold due to phase 3 weather c
onditions, we have no logistical support to r
ig. While waiting we are getting all the requ
ired drills completed.
Waiting on phase 3 weather conditions to dr
op in order to get support to rig.
Initialize MWD tool
Spud well at 1100 hrs. 01/19/02, Drill from
108' to 1210' MD, 1202 TVD, seen hydrates
at 1115' = 868 units gas, 1145' = 1358 unit
s gas, 1175' = 1379 units gas, also seen ga
s zone from 1185' to 1270' = max 1744 units
gas. ART = 6.3 hrs AST = 2.2 hrs
Drill from 1210' to 1832' MD, 1786' TVD AR
T=3.3 AST::::1.7
Circulate hole clean with reciprocation and
100 rpm rotation.
Wiper trip, pull free first 2 stands to 1643',
started pulling tight on third stand, run stan
d in, break circ and attempt to back ream ou
t of hole, lost returns due to pack off at 146
0'. Attempt to regain circ working and rotati
ng pipe. Hole wouldn't circ., but stayed full
static. Continue POOH filling hole down drill
string while pulling. Found free area at 95
0', most likely a washout area and regained
circulation. Circ. out until 820' before getti
ng full returns. Total fluid lost to formation
58 bbls
Circ. hole clean, getting large amounts of cl
ay over the shakers
RIH to 1739'
Circ. hole clean washing last stand to botto
m, large amounts of clay coming over shake
rs
Drill from 1832' to 2422' MD, 2310' TVD AR
T = 4.5 hrs AST = .5 hrs
Circ. sample to confirm TD, pump sweep and
Printed: 2/12/2002 2:34: 10 PM
(
Page 2 of 6
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
1/20/2002
1/21/2002
Cirque #3
Cirque #3
ROT - DRILLING
Doyon
Doyon 141
From - To Hours
Sub
Code Code
Phase
20:30 - 00:00
3.50 DRILL
SURFAC
CIRC
00:00 - 02:00
2.00 DRILL
WIPR SURFAC
02:00 - 03:00
CIRC
SURFAC
1.00 DRILL
03:00 - 05:00
2.00 DRILL
REAM SURFAC
05:00 - 05:30 0.50 DRILL CIRC SURFAC
05:30 - 06:00 0.50 DRILL REAM SURFAC
06:00 - 07:30 1.50 DRILL WIPR SURFAC
07:30 - 10:30 3.00 DRILL PULD SURFAC
10:30 - 11 :00 0.50 DRILL PULD SURFAC
11 :00 - 11 :30 0.50 RIGMNT RSRV SURFAC
11 :30 - 13:00 1.50 DRILL WIPR SURFAC
13:00 - 16:00
3.00 DRILL
SURFAC
CIRC
16:00 - 17:30 1.50 DRILL TRIP SURFAC
17:30 - 19:00 1.50 DRILL TRIP SURFAC
19:00 - 21 :00 2.00 CASE RURD SURFAC
21 :00 - 23:30 2.50 CASE RUNC SURFAC
23:30 - 00:00 0.50 CASE CIRC SURFAC
1/22/2002 00:00 - 02:00 2.00 CASE RUNC SURFAC
02:00 - 13:30
11.50 CEMEN CIRC
SURFAC
13:30 - 16:00
2.50 CEMEN PUMP SURFAC
Spud Date: 1/19/2002
End: 2/2/2002
Group:
Start: 1/16/2002
Rig Release: 2/2/2002
Rig Number: 141
Description of Operations
circ 2 bottoms up with pipe reciprocation a
nd rpm at 120, fair amounts of clay still co
ming over shakers, pump sweep and circ. un
til shakers cleaned up
Wiper trip, POOH to 1750',
3rd stand out and at 1750'
to 50k over and swabbing,
om.
Pump sweep and circ until shakers cleaned
up. Recovered large amounts of clay, max B
/U gas 820 units coming from lag depth of 1
1 00' .
Back ream out of hole to 1550', pumping at
550 gpm with 60 rpm's. PWD tool seeing cut
tings building up.
Circ. hole clean, heavy clay returns on bott
oms up.
Back ream out of hole to 1092', hole lost its
torque and drag,
POOH without pump or rotation
L/D MWD equipment and Mud motor
P/U 12 1/4" hole opener
Rig service, service top drive
TIH to 2372', had one tight spot at 600', at
the start of our build, fell through and never
seen again.
Wash to 2422', no fill on bottom, Circ and c
ond hole, pumping sweeps until hole cleane
d up. Recovered large amounts of clay.Chec
k for flow, blow down top drive, pump dry jo
b.
POOH to BHA (1000'), no tight spot
Stand back HWDP, L/D non-mag DC's and ho
Ie opener assembly
R/U to run 9 5/8" casing
Run 95/8" casing to 1100', no tight hole.
Circ. bottoms up, 350 units b/u gas
Run in hole with 9 5/8" casing, set at 2412'
no hole problems Total jts run = 56 its 9 5/
8" 40# L-80 BTC
Circ and cond mud, bringing PV - YD point f
rom20 - 50 to 11 - 21 before cementing
Hold pre-job safety meeting, pump 5 bbls C
W-100, test cement lines to 3500 psi, pump
25 bbls CW-100, drop bottom plug, pump 50
bbls 10.5 ppg Mudpush, mix and pump 324 b
bls 10.7 ppg lead cement, followed by 106.5
bbls 12 ppg tail cement, drop top plug, pum
p 10 bbls fresh water, let rig take over displ
acement with 10 ppg mud, bump plug with ca
Iculated strokes, check floats and held ok.
Reciprocate pipe until cement was seen at s
urface. Recovered 150 bbls 10.7 ppg ceme
hole got tight on
it was pulling up
run back to bott
Printed: 2/12/2002 2:34: 10 PM
.... ..............
~'PHILLlPS)
(~)
~
"V'
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
1/22/2002
1/23/2002
1/24/2002
1/25/2002
1/26/2002
('
-
t
Page 3 of 6
PHILLIPS ALASKA INC.
Operations Summary Report
Cirque #3
Cirque #3
ROT - DRILLING
Doyon
Doyon 141
Sub
From - To Hours Code Code Phase
13:30 - 16:00
16:00 - 17:30
17:30 - 19:30
19:30 - 21:00
21 :00 - 00:00
00:00 - 05:00
05:00 - 05:30
05:30 - 09:00
09:00 - 10:30
10:30 - 12:00
12:00 - 12:30
12:30 - 13:00
13:00 - 14:00
14:00 - 16:30
16:30 - 17:00
17:00 - 17:30
17:30 - 00:00
00:00 - 00:00
00:00 - 01 :00
01 :00 - 02:30
02:30 - 05:30
05:30 - 06:00
06:00 - 07:00
07:00 - 00:00
00:00 - 08:30
08:30 - 10:00
10:00 - 13:00
13:00 - 16:30
16:30 - 19:30
Spud Date: 1/19/2002
End: 2/2/2002
Group:
Start: 1/16/2002
Rig Release: 2/2/2002
Rig Number: 141
Description of Operations
2.50 CEMEN' PUMP SURFAC
1.50 CEMENl RURD SURFAC
2.00 WELCTL NUND SURFAC
1.50 WELCTL NUND SURFAC
nt to surface
R/D cement head, LID landing jt., clear floo
r of casing and cementing equipment.
N/D Diverter
N/U casing head and tubing spool and test t
01000 psi
N/U BOP's, change saver sub and grabbers
on top drive to 4" HT-38 connection
Test BOP's 250 psi low and 5000 psi high, t
est annular to 3500 psi high. AOGCC rep. w
as present for test ( Chuck Cheve)
Pull test plug, run wear bushing
P/U BHA and test motor and MWD, load Radi
oactive source
TIH to 2180'
Slip and Cut drill line
TIH to top of float collar, 2379'
Circ. botttoms up
Test casing to 2500 psi for 30 min.
Drill out Float equipment, cement and 20' of
new hole to 2442'. Weight mud from a 10 pp
g to a 10.2 ppg while drilling out.
Perform FIT test to a solid 16.3 PPG, using
10.2 ppg mud.
Establish PWD base line
Drilling from 2442' to 2854' MD, 2697' TVD
ART = 5.0 hrs. AST = 0.3 hrs.
Drilling from 2854' to 4427' MD, 4092 TVD
ART = 14.9 hrs AST = 03.8 hrs
Drill from 4427' to 4487' MD
Circ. and condo hole pumping sweeps, recipr
ocating and rotating at 120 rpm
Wiper trip to the shoe at 2412'. Pulled 3 sta
nds with no drag, stand 4 started to get tigh
t and by stand 6 it was pulling 30k over and
swabbing. Run back 3 stands to good hole
and break circ, back ream out 12 stands with
100 rpm and 500 gpm. Pipe then pulled free
with intermitent tight spots to shoe.
Circ. bottoms up, loads of clay came up.
TIH to bottom, no drag or fill
Drill from 4487' to 5421' MD, 4974' TVD AR
T = 12.7 in 24 hrs AST = 02.1 in 24 hrs
Drilling from 5421' to 5928' ART = 5.5 hrs
AST = 1.5 hrs
Circ. hole, pump high vis sweep
POOH to BHA, had tight spot on 7th and 14t
h stand, everything else pulled with normal
drag, no swabbing, check for flow at shoe.
Pull BHA, stand back HWDP, download MWD,
down load radio active sources, L/D bit an
d mud motor
P/U new BHA for rotary drilling, load MWD, I
3.00 WELCTL NUND SURFAC
5.00 WELCTL BOPE PROD
0.50 WELCTL NUND PROD
3.50 DRILL PULD PROD
1.50 DRILL TRIP
1.50 RIGMNT RSRV
0.50 DRILL TRIP
0.50 DRILL CIRC
1.00 CASE DEOT
2.50 CEMENl DSHO
0.50 CEMENl FIT
0.50 DRILL
6.50 DRILL
PROD
PROD
PROD
PROD
PROD
PROD
PROD
DEOT PROD
DRLG PROD
24.00 DRILL
DRLG PROD
1.00 DRILL
1.50 DRILL
DRLG PROD
CIRC PROD
3.00 DRILL
WIPR PROD
0.50 DRILL
1.00 DRILL
17.00 DRILL
CIRC PROD
WIPR PROD
DRLG PROD
8.50 DRILL
DRLG PROD
1.50 DRILL
3.00 DRILL
CIRC
TRIP
3.50 DRILL
PROD
PROD
PULD PROD
3.00 DRILL
PULD PROD
Printed: 2/12/2002 2:34: 10 PM
f
(
Page 4 of 6
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name: Cirque #3
Common Well Name: Cirque #3
Event Name: ROT - DRILLING
Contractor Name: Doyon
Rig Name: Doyon 141
Date From - To Hours Code Sub Phase
Code
1/26/2002 16:30 - 19:30 3.00 DRILL PULD PROD
19:30 - 20:30 1.00 DRILL TRIP PROD
20:30 - 21 :00 0.50 DRILL CIRC PROD
21 :00 - 22:30 1.50 DRILL TRIP PROD
22:30 - 23:30 1.00 DRILL CIRC PROD
23:30 - 00:00 0.50 DRILL DRLG PROD
1/27/2002 00:00 - 06:30 6.50 DRILL DRLG PROD
06:30 - 07:00 0.50 DRILL CIRC PROD
07:00 - 07:30 0.50 DRILL DRLG PROD
07:30 - 10:30 3.00 DRILL CIRC PROD
10:30 - 11 :00 0.50 DRILL OBSV PROD
11 :00 - 12:00 1.00 DRILL TRIP PROD
12:00 - 17:30 5.50 DRILL TRIP PROD
17:30 - 20:00 2.50 DRILL PULD PROD
20:00 - 23:00 3.00 DRILL TRIP PROD
23:00 - 00:00 1.00 DRILL CIRC PROD
1/28/2002 00:00 - 00:30 0.50 CORE CIRC PROD
00:30 - 03:00 2.50 CORE CORE PROD
03:00 - 03:30 0.50 CORE CIRC PROD
03:30 - 04:00 0.50 CORE OTHR PROD
04:00 - 04:30 0.50 CORE TRIP PROD
04:30 - 05:30 1.00 CORE OTHR PROD
05:30 - 06:00 0.50 CORE CIRC PROD
06:00 - 06:30 0.50 CORE OTHR PROD
06:30 - 09:30 3.00 CORE TRIP PROD
09:30 - 12:00 2.50 CORE TRIP PROD
12:00 - 12:30 0.50 CORE PULD PROD
12:30 - 16:30 4.00 CORE OTHR PROD
16:30 - 17:00 0.50 CORE PULD PROD
17:00-19:30 2.50 DRILL PULD PROD
19:30 - 21 :00 1.50 DRILL TRIP PROD
21 :00 - 21 :30 0.50 DRILL CIRC PROD
Spud Date: 1/19/2002
End: 2/2/2002
Group:
Start: 1/16/2002
Rig Release: 2/2/2002
Rig Number: 141
Description of Operations
oad radio active sources, RIH with BHA, sha
lIow test MWD tools.
TIH to 3100'
Circ. bottoms up
TIH to 5778'
Circ. bottoms up and until shakers cleaned
up, wash to 5928', Made mad pass with loggi
ng tools from 5878' to 5928'
Rotary drill from 5928' to 5932'
Drilled f/5932-6117', ART 5.4 HR, losing mu
d @-36 bbllhr.
Circulate bottoms up and add LCM to system
(BAROSEAL & BAROFIBER).
Drilled f/6117-6123', ART .3 HR.
Circulate and condition mud adding LCM to
system, cut mud weight to 10.0 ppg.
Observe well, 1.2 bbl flowback in 112 hr.
POH 10 stds, observe well every 5 stds, min
imal flowback. Lost total of 290 bbl since mi
dnight.
Finish poh f/coring assy, download mwd & la
y down.
M/U core bbl assy, PJSM, rih.
RIH w/bha #5 to 6100', p/u 15' pups, wash t
0 6118'.
Circulate bottoms up, no mud losses, backgr
ound gas 20 units.
Finish circulating bottoms up and drop ball.
Core f/6123-6215'.
Circulate bottoms up, losing mud @ 1 bbllmi
n.
monitor well,
POH to 5914'
monitor well,
ill.
Open PBL bypass and spot 30 bbl, 25 ppb B
aroseal & Barofiber LCM, pill @ 5914'.
Monitor well, losing @ 6 bbl/hr. Total losses
of 150 bbl.
POH to bha @ prescribed pulling Ide com pres
sion speeds.
POH to core bbl.
Lay down inner core bbls, cut 92', recovered
92'= 100%.
Cut, appraise and package 92' cores, servic
e top drive.
Lay down outer core bbl and coring tools.
M/U bha #6, scribe, upload, initiate & id sou
r c e s.
RIH below shoe, test LWD.
Circulate and condition mud, cutting mud we
ight to 9.8 ppg to prevent mud loss.
losses continue @ 1 bbl/min
above loss zone.
lost 20 bbl/1 hour., mix LCM p
..,..
/'
Printed: 2/12/2002 2:34: 10 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1/28/2002
1/29/2002
1/30/2002
1/31/2002
Date
(
(
Page 5 of 6
PHILLIPS ALASKA INC.
Operations Summary Report
Cirque #3
Cirque #3
ROT - DRILLING
Doyon
Doyon 141
From - To Hours
Sub
Code Code Phase
21 :30 - 23:00
23:00 - 00:00
00:00 - 08:00
08:00 - 10:30
10:30 - 11 :00
11 :00 - 12:00
1.50 DRILL
1.00 DRILL
TRI P PROD
OTHR PROD
PROD
12:00 - 12:30 0.50 DRILL OBSV PROD
12:30 - 13:30 1.00 DRILL TRIP PROD
13:30 - 14:00 0.50 DRILL OBSV PROD
14:00 - 16:00 2.00 DRILL TRIP PROD
16:00 -16:30 0.50 DRILL OBSV PROD
16:30 - 18:00 1.50 DRILL TRIP PROD
18:00 - 20:30 2.50 DRILL PULD PROD
20:30 - 21 :30 1.00 LOG PULD PROD
21 :30 - 00:00 2,50 LOG ELOG PROD
00:00 - 03:00 3.00 LOG ELOG PROD
03:00 - 09:00 6.00 LOG ELOG PROD
09:00 - 12:00 3.00 ABAND PULD PROD
12:00 - 13:00 1.00 ABAND OTHR PROD
13:00 - 17:00 4.00 ABAND PULD PROD
17:00 - 18:00 1.00 ABAND PULD PROD
18:00 - 20:30 2.50 ABAND PULD PROD
20:30 - 23:00 2.50 ABAND TRIP PROD
23:00 - 23:30 0.50 ABAND PULD PROD
23:30 - 00:00 0.50 ABAND CIRC PROD
00:00 - 03:30 3.50 ABAND CIRC ABANDN
03:30 - 05:30 2.00 ABAND OTHR ABANDN
8.00 DRILL
2,50 DRILL
DRLG PROD
CIRC PROD
05:30 - 06:30 1.00 ABAND TRIP ABANDN
06:30 - 07:00 0.50 ABAND CIRC ABANDN
07:00 - 07:30 0.50 ABAND TRIP ABANDN
07:30 - 08:30 1.00 ABAND OTHR ABANDN
08:30 - 09:00 0.50 ABAND TRIP ABANDN
09:00 - 09:30 0.50 ABAND CIRC ABANDN
09:30 - 12:00 2.50 ABAND TRIP ABANDN
12:00 - 12:30 0.50 ABAND TRIP ABANDN
12:30 - 16:00 3.50 ABAND TRIP ABANDN
0.50 DRILL
WIPR PROD
1.00 DRILL
CIRC
Spud Date: 1/19/2002
End: 2/2/2002
Group:
Start: 1/16/2002
Rig Release: 2/2/2002
Rig Number: 141
Description of Operations
Continue RIH to 6100'.
Ream & MAD pass core hole, displace well w
/9.8 ppg mud, 20 bbl mud loss when displaci
ng. No bottoms up gas.
Drilled fl6215-6677', ART 7.0 hrs.
Circulate bottoms up, slight flow w/pumps of
f, circulate and raise mud weight to 9.9+ pp
g, observe well.
Wiper trip to 6200', mud gain 5 bbl, RIH to t
. d.,
Circulate & raise mud weight to 10.0+ ppg, t
otal mud loss fl12 hrs =119 bbls. Slight well
flow.
Observe well, 10 bbl/hr gain.
POH to 5700'.
Monitor well, 2.4 bbl/hr loss, pump slug.
POH to 2400'.
Monitor well, 6 bbl/hr loss.
Continue poh fie-line logging.
Lay down bha, download & remove sources.
PJSM, R/U Schlumberger.
Log run #1,Dipole Sonic/FMI, Total mud loss
fl12 hr 50 bbl, total flday 150 bbl.
Continue running log run #1, Dipole Sonic/F
MI.
Log run #2. CMR.
LID 5" drillpipe & 5" HWDP.
Slip and cut drlg line.
Continue L/D 3-1/2 & 5" HWDP flderrick.
Load pipe shed w/2-7/8 tbg stinger & 4" drill
pipe.
Rig up & p/u 2-7/8 tbg stinger for P & A & ri
h.
RIH w/4" DP in derrick.
P/U 15 its DP & wash 30' to bottom.
Establish circulation and stage up pump rat
e.
Circulate and condition mud flcementing, PJ
SM flcementing.
Pump & displace
ecrete cement @
n two stages. No
g or displacing.
POH slowly to 5218'.
Spot hi-vis pill f/5218-4833.
POH slowly to 4833'.
Pump & displace balanced plug 24.8 bbl cia
ss G cement @15.8 ppg fl4833-4480'.
POH slowly to 4352'.
Reverse circ. until clean returns observed.
POOH for drilling assembly.
Lay down 300' 2 7/8" tubing
Pick up 12 its. HWDP, TIH with DP and tag
balanced plug of 55 bbl lit
11.0 ppg f/6677' to 5896' i
mud losses while circulatin
Printed: 2/12/2002 2:34: 10 PM
(
Page 6 of 6
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Cirque #3
Cirque #3
ROT - DRILLING
Doyon
Doyon 141
Date From. To Hours Code Sub Phase
Code
1/31/2002 12:30 - 16:00 3.50 ABAND TRIP ABANDN
16:00 - 18:30 2.50 ABAND TRIP ABANDN
18:30 - 20:30 2.00 ABAND TRIP ABANDN
20:30 - 23:00 2.50 ABAND OTHR ABANDN
23:00 - 00:00 1.00 ABAND CIRC ABANDN
2/1/2002 00:00 - 03:30 3.50 ABAND PULD ABANDN
03:30 - 05:30 2.00 ABAND PLUG ABANDN
05:30 - 07:30 2.00 ABAND OTHR ABANDN
07:30 - 08:00
08:00 - 09:00
09:00 - 10:00
10:00 - 12:30
0.50 ABAND TRIP ABANDN
1.00 ABAND DPST ABANDN
1.00 ABAND TRIP ABANDN
2.50 ABAND OTHR ABANDN
12:30 - 14:30
14:30 - 16:30
2.00 ABAND PULD ABANDN
2.00 ABAND TRIP ABANDN
16:30 - 18:00 1.50 ABAND OTHR ABANDN
18:00 - 18:30 0.50 ABAND PULD ABANDN
18:30 - 19:30 1.00 ABAND OTHR ABANDN
19:30 - 20:00 0.50 ABAND PULD ABANDN
20:00 - 22:00 2.00 ABAND ABANDN
22:00 - 23:00 1.00 ABAND ABANDN
23:00 - 00:00 1.00 ABAND ABANDN
2/2/2002 00:00 - 04:00 4.00 ABAND ABANDN
04:00 - 00:00
20.00 MOVE
DMOB MOVE
Spud Date: 1/19/2002
End: 2/2/2002
Group:
Start: 1/16/2002
Rig Release: 2/2/2002
Rig Number: 141
Description of Operations
cement at 4691' with 15k. Tag witnessed by
Jeff Jones w/AOGCC.
POOH. Lay down HWDP.
Pick up 4 stds. 2 7/8" tubing and RIH on DP
t04691'
Lay 16.5 bbls on top of existing plug at 469
1'. Pullout of cement slow to 4400'. Calcula
ted top of plug at 4466'.
Circulate to clean up DP and well. Pull 5 st
ands of DP.
POH lId 1400' drillpipe, poh fIretainer.
M/U baker K-1 cement retainer and rih on dr
ill pipe to 2337'.
Set cement retainer @ 2337', unsting, displ
ace 17 bbl class G 15.8 ppg cement to retai
ner, sting in, bullhead 13.5 bbl cement belo
w retainer (175'+), unsting and poh slowly I
aying down 3.5 bbl (50') cement on top of re
tainer.
POH TO 2114'
R/U & test plug to 1500 psi f/30 min. ok.
POH to 1505'.
R/U and freeze protect to surface using Hot
Oil Services to reverse circulate diesel dow
n annulus and up dp (110 bbl).
POH laying down drillpipe.
RIH w/9-5/8" wiper top plug pushed ahead of
2-7/8" cementing stinger to 300' (wiper plu
g to hopefully prevent cement plug fIsliding
downhole in diesel).
PJSM, Pump 22 bbl Arctic Set I 15.7 ppg ce
ment taking returns in cellar.
POH slowly to 25' KB, & top off surface w/1
bbl cement.
Wash cement fIstack and wellhead, clean flo
or of cementing lines.
LID tubing in mousehole. Lower powerline a
nd matt line fItruck crossing.
Nipple down BOPE.
Nipple down wellhead.
Pick up in cellar, clean pits.
CLEANING PITS, UNABLE TO GET TRUCKS F
IFINAL PIT CLEANING AND RIG MOVE TRUC
KS DUE TO 16E CAMP MOVE TO MELTWATE
R.
BLOW DOWN CAMP AND RIG, PREPARING FI
MOVE, RIG RELEASED @ 0400 HR, 02/02/20
02.
Printed: 2/12/2002 2:34: 10 PM
(
"
~,
CIRQUE #3 PLUG & ABANDONMENT
02/01/2002
The well was plugged and abandoned with Doyon 141 on 02-01-2002. A
9-5/8"cement retainer was set at 2337'. 13.5 bbls(175') of Class"G" @ 15.8
ppg was bullheaded below the retainer and 3.5 bbls(50') was left on top of the
retainer. Pooh to 2114'. Tested the retainer to 1500 psi for 30 minutes.
Freeze protected casing with Hot Oil. Pooh lId drill pipe. Rih with 9-5/8
casing wiper plug (prevent cement plug from going down hole) ahead of 2-7/8"
cementing stinger to 300'.
PJSM. Mix and pump 22 bbls ASI @ 15.7 ppg. Cement returns were taken
into the cellar. Pooh slow to 25' and top off with cement. Cement to surface.
Nipple bope's and rig down. (see drilling report # 16 dated 2-01-2002)
02/11/2002-02/13/2002
The base plate and the cellar box were cut removed by GBR and Drilling Tool
House. The 16" conductor and 9-5/8" surface casing were cut three feet
below the tundra per AOGCC requirements. A three foot void was filled
with cement. Lou Grimaldi with AOGCC witnessed the cement and the cap
was welded in place with Phillips Alaska, Inc., Cirque #3, API #50-103-
20399-00. After the cap was welded, the hole was backfilled per Lou's
suggestion.
IC Pyron 2/13/2002
{
\.
(
CIRQUE #3 P&A SUMMARY
The following summarizes, with attachments, plug and abandonment cementing details of Cirque #3.
Plug #1: 6677'-5896',8-112" open hole,1/31/2002, rih w/2-7/8" tbg stinger on 4" drillpipe, pump &
displaced balanced plug of 55 bbl(108 sx) @ 11.0 ppg Litecrete w/celloflake for LCM. Plug layed fff.D.
OF 6677' to 5896' in two stages. No mud losses while circulating or displacing. POH slowly to 5218'.
Plug #2: 4833'-4480', 8-1/2" open hole, 1/31/2002, spot hi-vis pill f/5218-4833', pump and displaced
balanced plug of 24.8 bbl(119 sx) 15.8 ppg "G" cement. Plug f/5218-4833' calculated in one stage. POH
slowly to 4352' and reverse circulate until clean returns observed. POH f/drilling assembly. RIH w/8-1/2"
bit on HWDP and tag cement @ 4691' w/15k weight. Plug had fallen to top of iceberg interval. Plug tag
witnessed by Jeff Jones-AOGCC. POH, rih w/tbg stinger to top of plug @ 4691'. Pump and displace
balanced plug of 16.5 bbl (80sx) @15.8 ppg "G" f/top of plug @4691-4466'. POH slowly to 4400' and
circulate to condition mud. POH f/retainer.
Plug #3: 2512'-2287', 8-1/2" open hole and 9-5/8" Casing, 2/1/2002, RIH w/Baker K-1 retainer on
drillpipe to 2337', set retainer, unsting, displace 17 bbl (82sx) class "G" @15.8 ppg, sting-in bullhead 13.5
bbl below retainer (175'+), un sting and poh slowly laying down 3.5 bbl (50') cement on top of retainer.
POH to 2114' and test csg/retainer to 1500 psi f/30 minutes. POH to 1505' and displace mud in hole to
diesel. POH lId drillpipe.
Plug #4: 300'-surface, 9-5/8" Casing, 2/1/2002, rih w/9-5/8" top plug (attempt to keep cement plug
f/slipping downhole) pushing to 300' w/tubing, pump 22 bbl Arctic Set 1 cement to surface cellar, POH
slowly to 25' KB, & top off surface w/1 bbl cement. Used total of 23 bbl (139 sx) Arctic Set 1 cement.
Rig down and move to 2L-03: final cutting of conductor and placement of P & A marker plate remains to
be done weather permitting.
Ray W. Springer
Drlg Supervisor
Doyon 141
,I
/
i
,l/
,~.
i(
If
\,
a,i""':;":"'O+:jti!~"7:~:"::'¡"~::';¡:',""ì',q"i',:",:;,¡:,: ;,\,':::'1;,:,> ,;"",
, ""II '
- 7
12-Feb-O2
AOGCC
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
Definitive
Re: Distribution of Survey Data for Well Cirque 3
Dear Dear Sir/Madam:
Enclosed are two su rvey hard copies and 1 disk
Tie-on Survey:
Window / Kickoff Survey
Projected Survey:
0.00' MD
'MD
6,677.00' MD
(if applicable)
Please call me at 273-3545 if you have any questions or concerns.
Regards,
William T. Allen
Survey Manager
Attachment(s)
RECE\VED
r EB 2. 0 2002
AlaSka Oi' & Gas Con8. commi8on
Ancb0f896
D EFI N ITIVE
'.
Kuparuk River Unit
North Slope, Alaska
EXPLORA TION_NON-PAD, Slot Cirque 3
CIRQUE-O3
Job No. AKMW22010, Surveyed: 29 January, 2002
{
SURVEY REPORT
11 February, 2002
Your Ref: API 501032039900
Surface Coordinates: 5890539.82 N, 455748.28 E (70006' 42.5278" N, 1500 21' 18.4934" W)
Kelly Bushing: 180.90ft above Mean Sea Level
(
Survey Ref: svy9837
A Halliburton Company
"Sperry-Sun Drilling Services .
Survey Report for CIRQUE-O3
0 E Your Ref: API 501032039900 .
FIN' T I VE No. AKMW22010, Surveyed: 29 January, 2002
North Slope, Alaska
Kuparuk River Unit EXPLORATION NON-PAD
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) ~
0.00 0.000 0.000 -180.90 0.00 O.OON O.OOE 5890539.82 N 455748.28 E 0.00 MWD Magnetic
108.00 0.000 0.000 -72.90 108.00 O.OON O.OOE 5890539.82 N 455748.28 E 0.000 0.00
198.07 0.160 76.470 17.17 198.07 0.03N 0.12 E 5890539.85 N 455748.40 E 0.178 -0.02
284.85 0.360 110.700 103.95 284.85 O.O4S 0.50E 5890539.78 N 455748.77 E 0.282 -0.21
381.03 0.560 103.000 200.13 381.03 0.25S 1.24 E 5890539.56 N 455749.51 E 0.217 -0.68
472.08 0.520 74.900 291.17 472.07 0.24S 2.07 E 5890539.56 N 455750.35 E 0.291 -0.97
564.41 1.970 341.860 383.48 564.38 1.37 N 1.98 E 5890541.18 N 455750.27 E 2.235 0.57
654.67 3.860 339.280 473.62 654.52 5.69N 0.42 E 5890545.51 N 455748.73 E 2.098 5.15
745.29 5.380 337.170 563.94 744.84 12.46 N 2.31 W 5890552.29 N 455746.05 E 1.688 12.45
835.75 7.030 330.580 653.87 834.77 21.19 N 6.67W 5890561.05 N 455741.73 E 1.984 22.17
926.43 8.580 331.580 743.71 924.61 31.97 N 12.62W 5890571.87 N 455735.85 E 1.716 34.37
1016.72 10.710 334.010 832.72 1013.62 45.44 N 19.50 W 5890585.37 N 455729.04 E 2.401 49.42
1110.05 12.560 336.440 924.13 1105.03 62.54 N 27.36 W 5890602.52 N 455721.29 E 2.050 68.20
1202.63 13.920 339.270 1014.25 1195.15 82.18 N 35.32 W 5890622.21 N 455713.44 E 1.627 89.39
1296.01 15.610 340.180 1104.54 1285.44 104.51 N 43.56 W 5890644.58 N 455705.33 E 1.827 113.19
1388.70 17.160 339.780 1193.46 1374.36 129.07 N 52.51 W 5890669.20 N 455696.52 E 1.677 139.33 -,
1482.05 18.4 70 338.890 1282.33 1463.23 155.79 N 62.60 W 5890695.97 N 455686.59 E 1.433 167.88
1574.54 20.330 339.560 1369.57 1550.47 184.52 N 73.49 W 5890724.76 N 455675.87 E 2.025 198.60
1667.53 22.570 340.570 1456.11 1637.01 216.49 N 85.07 W 5890756.80 N 455664.48 E 2.441 232.60
1759.89 25.140 338.800 1540.58 1721.48 251.50 N 98.06 W 5890791.89 N 455651.69 E 2.888 269.94
1852.66 27.690 339.730 1623.66 1804.56 290.10 N 112.66 W 5890830.57 N 455637.32 E 2.785 311.20
1944.87 27.830 339.630 1705.25 1886.15 330.37 N 127.57 W 5890870.93 N 455622.64 E 0.160 354.15
2038.02 27.400 338.520 1787.79 1968.69 370.70 N 142.99 W 5890911.35 N 455607.45 E 0.720 397.32
2128.85 27.110 339.140 1868.54 2049.44 409.49 N 158.01 W 5890950.22 N 455592.66 E 0.447 438.92
2224.43 26.830 338.020 1953.72 2134.62 449.84 N 173.84 W 5890990.67 N 455577.07 E 0.607 482.26
2316.88 27.640 338.660 2035.92 2216.82 489.16 N 189.45 W 5891030.08 N 455561.68 E 0.932 524.57
2347.97 27.520 337.810 2063.48" 2244.38 502.53 N 194.79 W 5891043.48 N 455556.42 E 1.323 538.96
2494.28 27.280 337.140 2193.38 2374.28 564.73 N 220.58 W 5891105.82 N 455530.99 E 0.267 606.28
2590.70 26.430 337.310 2279.40 2460.30 604.89 N 237.44 W 5891146.08 N 455514.37 E 0.885 649.81
2687.13 26.180 339.550 2365.84 2546.74 644.62 N 253.15 W 5891185.90 N 455498.89 E 1.061 692.54
.. --'._~
11 February, 2002 - 13:18
Page 2 of 5
DrillQlIest 2.00.08.005
DEFINITIVE
Sperry-Sun Drilling Services
Survey Report for CIRQUE-03
Your Ref: AP/501032039900
Job No. A KMW2201 0, Surveyed: 29 January, 2002
.
Kuparuk River Unit
Measured
Depth
(ft)
""-"
2782.89
2879.24
2975.20
3071.09
3167.62
3262.60
3358.29
3454 .45
3550.71
3646.50
3741.95
3838.56
3934.27
4030.83
4126.42
4222.84
4318.99
4413.55
4511.30
4607.22
4703.20
4799.52
4895.56
4992.38
5083.28
5183.71
5278.88
5376.07
5471.60
5568.38
Inct.
25.580
26.650
26.110
27.400
26.870
27.830
26.930
28.020
27.370
28.090
27.430
27.840
27.480
28.440
27.730
28.390
27.820
27.040
28.310
28.000
28.030
27.310
27.870
27.310
26.570
27.250
26.810
26.500
27.510
26.880
Azim.
339.790
338.940
339.100
339.190
339.630
338.500
338.160
338.300
337.090
339.210
338.750
339.590
340.960
341.480
342.050
340.060
339.930
339.160
340.010
341.220
339.190
339.210
338.110
338.400
338.730
336.880
336.460
338.970
339.150
338.900
11 February, 2002 - 13:18
Sub-Sea
Depth
(ft)
2452.00
2538.51
2624.48
2710.10
2796.01
2880.37
2965.34
3050.65
3135.88
3220.67
3305.14
3390.73
3475.50
3560.79
3645.12
3730.21
3815.02
3898.95
3985.52
4070.09
4154.82
4240.13
4325.25
4411.06
4492.09
4581.65
4666.42
4753.28
4838.40
4924.48
Vertical
Depth
eft)
2632.90
2719.41
2805.38
2891.00
2976.91
3061.27
3146.24
3231.55
3316.78
3401.57
3486.04
3571.63
3656.40
3741.69
3826.02
3911.11
3995.92
4079.85
4166.42
4250.99
4335.72
4421.03
4506.15
4591.96
4672.99
4762.55
4847.32
4934.18
5019.30
5105.38
Local Coordinates
Northlngs Eastlngs
(ft) (ft)
683.81 N
723.50 N
763.31 N
803.65 N
844.86 N
885.61 N
926.51 N
967.71 N
1009.10 N
1050.47 N
1091.96 N
1133.85 N
1175.67 N
1218.53 N
1261.27 N
1304.16 N
1346.72 N
1387.54 N
1430.09 N
1472.78 N
1515.19 N
1557.00 N
1598.43 N
1640.08 N
1678.41 N
1720.49 N
1760.21 N
1800.54 N
1841.05 N
1882.35 N
267.68 W
282.63 W
297.89 W
313.26 W
328.75 W
344.34 W
360.59 W
377.04 W
394.02 W
410.59 W
426.54 W
442.47 W
457.47 W
472.04 W
486.12 W
500.86 W
516.35 W
531.57 W
547.40 W
562.42 W
577.69 W
593.57 W
609.76W
626.38 W
641.43 W
658.60 W
675.73 W
692.27 W
707.77 W
723.60 W
-- - --
Page 3 of 5
Global Coordinates
Northlng~ Eastlngs
(ft) (ft)
5891225.18 N
5891264.95 N
5891304.85 N
5891345.28 N
5891386.58 N
5891427.42 N
5891468.41 N
5891509.71 N
5891551.20 N
5891592.66 N
5891634.25 N
5891676.23 N
5891718.13 N
5891761.08 N
5891803.90 N
5891846.88 N
5891889.53 N
5891930.43 N
5891973.07 N
5892015.85 N
5892058.35 N
5892100.26 N
5892141.78 N
5892183.52 N
5892221.94 N
5892264.12 N
5892303.93 N
5892344.36 N
5892384.97 N
5892426.36 N
455484.59 E
455469.87 E
455454.84 E
455439.71 E
455424.46 E
455409.10 E
455393.10 E
455376.88 E
455360.15 E
455343.82 E
455328.11 E
455312.42 E
455297.67 E
455283.35 E
455269.52 E
455255.03 E
455239.79 E
455224.81 E
455209.23 E
455194.45 E
455179.43 E
455163.79 E
455147.84 E
455131.47 E
455116.65 E
455099.72 E
455082.82 E
455066.52 E
455051.26 E
455035.66 E
.
.
North Slope, Alaska
EXPLORATION NON-PAD
Dogleg
Rate
(o/100ft)
0.636
1.176
0.568
1.346
0;587
1.149
0.955
1.136
0.893
1.275
0.727
0.585
0.764
1.026
0.794
1.188
0.596
0.906
1.361
0.677
0.994
0.748
0.788
0.595
0.831
1.074
0.504
1.202
1.061
0.662
Vertical
Section
734.33
776.74
819.38
862.54
906.57
950.20
994.20
1038.56
1083.29
1127.85
1172.31
1217.12
1261.53
1306.77
1351.71
1397.02
1442.31
1485.86
1531.26
1576.49
1621.56
1666.28
1710.76
1755.60
1796.78
1842.22
1885.44
1929.03
1972.40
2016.63
Comment
~.
-',
DriliQuest 2.00.08.005
Sperry-Sun Drilling Services .
~ Survey Report for C/RQUE-O3
Your Ref: AP/SO1032039900
. D E FIN I T I V E Job No. A~MW2201 0, Surveyed: 29 January, 2002
North Slope, Alaska
Kuparuk River Unit EXPLORATION NON-PAD
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Inel. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) .-.
5663.73 27.550 338.940 5009.27 5190.17 1923.04 N 739.28 W 5892467.14 N 455020.22 E 0.703 2060.24
5760.02 28.300 337.610 5094.35 5275.25 1964.93 N 755.98 W 5892509.12 N 455003.77 E 1.012 2105.33
5855.45 27.550 337.430 5178.67 5359.57 2006.22 N 773.07 W 5892550.51 N 454986.92 E 0.791 2150.01
5932.46 27.200 338.680 5247.06 5427.96 2039.06 N 786.30 W 5892583.43 N 454973.88 E 0.874 2185.41
6029.28 27.230 338.270 5333.16 5514.06 2080.25 N 802.55 W 5892624.72 N 454957.87 E 0.196 2229.69
6083.51 27.190 339.870 5381.39 5562.29 2103.41 N 811.41 W 5892647.93 N 454949.15 E 1.351 2254.49
6126.19 27.180 338.670 5419.35 5600.25 2121.65 N 818.31 W 5892666.20 N 454942.35 E 1.285 2273.98
6219.95 27.060 338.930 5502.80 5683.70 2161.50 N 833.76 W 5892706.14 N 454927.13 E 0.180 2316.72
6316.59 26.430 339.120 5589.10 5770.00 2202.10 N 849.33 W 5892746.84 N 454911.80 E 0.658 2360.21
6413,34 25.660 339.270 5676.03 5856.93 2241.81 N 864.42 W 5892786.63 N 454896.94 E 0.799 2402.69
6508.83 25.220 339.850 5762.26 5943.16 2280.25 N 878.75 W 5892825.15 N 454882.84 E 0.530 2443.71
6602.19 24.570 339.610 5846.94 6027.84 2317.12 N 892.36 W 5892862.10 N 454869.44 E 0.705 2483.00
6677.00 24.570 339.610 5914.98 6095.88 2346.27 N 903.20 W 5892891.32 N 454858.77 E 0.000 2514.11 Projected Survey
All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well. Northings and Eastings are relative to Well.
.-c~
Magnetic Declination at Surface is 25.417° (17 -Jan-O2)
The Dogleg Severity is in Degrees per 100 feet (US).
Vertical Section is from Well and calculated along an Azimuth of 338.810° (True).
Based upon Minimum Curvature type calculations, at a Measured Depth of 6677.00ft.,
The Bottom Hole Displacement is 2514.11ft., in the Direction of 338.946° (True).
11 February, 2002 - 13:18
Page 4 of 5
DrillQlIest 2.00.08.005
\
.
.
Sperry-Sun Drilling Services
Survey Report for CIRQUE-03
Your Ref: API 501032039900
D E F, N 'T I V EJOb No. A~MW22010, Surveyed: 29 January, 2002
..
Kuparuk River Unit
North Slope, Alaska
EXPLORATION NON-PAD
Comments
...--.. .
',,--
Measured
Depth
(ft)
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
Comment
6677.00
6095.88
2346.27 N
903.20 W
Projected Survey
Survey tool program for CIRQUE-03
Fro m
Measured Vertical
Depth. Depth
(ft) (ft)
To
Measured Vertical
Depth Depth
(ft) (ft)
Survey Tool Description
0.00
0.00
6677.00
6095.88 MWD Magnetic
'-"'-
-'--
11 February, 2002 - 13:18
Page 5 of 5
DrillQuest 2.00.08.005
,. r&ii8
BAKER I
, HUGHES
INTEQ
IIJ
II]
(
CORING SUMMARY NOTl~
~
.raRE RUN #1 :
,!ICKED UP 90' OF CORE BARRELS RAN IN THE HOLE.
;HEY HAD BEEN LOSING CIRCULATION AND MIXED SOME LCM.
~E RAN INTO BOTTOM AND WASHED THE LAST STAND TO BOTTOM.
,XE STARTED CORING & CUT 92 FEET OF CORE IN 2 HOURS AND 37 MINUTES
vvE NEVER LOST ANY MUD WHILE CORING
~s SOON AS WE BROKE THE CORE OF WE STARTED TO LOSE MUD. THEY PUMPED DOWN A SLUG
.ND CIRCULATED BOTTOMS UP THEN TRIPPED OUT OF THE HOLE.
vE RECOVERED THE CORE THEN WAITED ABOUT 3 HOURS ON ORDERS FROM THE GEOLOGIST
THEN GOT THE WORD TO LAY DOWN THE CORE BBLS.
8/E GOT FULL RECOVERY & EVERYTHING WENT GOOD.
"LL TOOLS WERE BOXED UP AND WERE READY FOR SHIPPING.
II
II
III
III
II
II
III
~
II
~
HJNTEQREPRESENTATIVE: FRED ANTONSEN
Core Chip Description Described By R. A Levinson
Cirque. 3 API 50-103-20399-00 Dale _##
¡t°<:- .~ 0~'" ~0'" .~
~ ~<f ,p" "p'" qo
O~ç ,p<:- Oo~ -.;.ò" ~o ~ <#0 ~~ ~ ~ii'.>::\ ~ -.;.<:-0, «;o,p' 0' o"i)-ìß,¿.~
iJ.'f' ,I' .# -.;.0 -.;.01:$ £1><:-0, ~ò~ 0~ 0' ~ -.;.<:-0, <:;,-f .p.0'd>°' «;0" ~ r:I'~
,0 &ç 00<:- ~ $° -.;.0' ø~<:- ,?-ov ~~ ",#" 0# q¡P1$ ~. 0" <;j>of c:;l Q~ O~ if <:;,"f
0° if' ,<° 0° <:;,° rjS' c; ~ ~ø'
at chip ex, vg, g, "
MD ex,g,I,p W,m,p ex,g,I,p,n scale ex, vg, g, I, p, vp VS,S,m,w,vw,n y,n p, vp
lorss 800/.
portion,25%qtz. 75 grains n bright
Interlam os. sns, % altered 10 calc"e and brown milky insl dull Bedded sample. Shows
1 6123 Bermuda g w p clst, carb med gray Mn-uvfn well sub a mhic+leld+biol"e carbo pyr"e wMe clay clay Ihin bdd ripple lams vp s spols yellow milky y g described lor ss and slls.
25% qtz.60% 100%
nhic+leld, grains bright best res quality ans
15%biot"e+glauc+ carb Irags, altered 10 clay ri-up milky instant show of the entire core
2 6126 Bermuda vg w g ss Ian Mn-ufn mod suba clay gr pyr"e, glauc wMe clay calc carb lams frags vg vs Ian yellow blue-white y ex chip collection
25% qtz.65% carb Irags, 10%
IIhic+feld, pyrite, grains brighl
sub a-sub 10%biome+glauc+ muscov"e, anered 10 10% milky slow dull
3 6129 Bermuda vg w p ss med gray Mn-uvfn well r claygr glauc wh"e clay clay or zeol p vw spotty yellow blue-wh"e vp well cemented, v.fgr ss
25% qtz.65% 100% .-,
IIhic+leld, brighl
sub a-sub 10%biot"e+glauc+ rare calc, clay or milky instanl
4 6132 Bermuda g w fog ss gray-Ian flgr (ufn-uvfn mod r clay gr muscov"e calcgr zeal parallel g s tan yellow blue-wh"e y g good show, ok 4>
sl blue-
25% qtz.65% sllensing, wh"e in
IIhic+feld, muscov"e, rippl;e carb and 15% some
5 6135 Bermuda g w p ss med gray uvfn-ufn mod-well sub a 1œ'obiol"e pyrite, glauc calc gr zeol, sl calc lams clay lam p s spotty lams p sill and carb lams
moslly clay 25% qtz. 65% rare ss 100% in instant
w/uvfn-fln sd IIhic+feld, muscov"e, injected ss blue-wh"e gin ss
6 6138 Bermuda g w p sh with ss patches dk gray in patches mod-well sub r 100/obiot"e carb Irags calc gr clay,zeol inlosh sh rip-ups? vp vw patches in palches y patches 80% sh, 20% sdsl
25% qtz. 65% bright
nhic+feld, grains milky
10%biom..."lay sin, carb altered 10 sd and sill 10% yellow in blue-wh"e
7 6141 Bermuda g w p ss II gray Mn-uvfn well sub a gr+glauc Irags, pyrite wh"e clay cafc parallel lams p vw patch patch in patch sl p
bright
25% qtz. 65% grains milky
sub a- IIhic+leld, glauc, carb anered 10 10% yellow in blue-wh"e
8 6144 Bermuda 9 w fop ss n gray Mn-sn well subr 10%biot"..."lay gr Irags wh"e clay cl calc zeol cross lams p vw palch palch in patch sl vp tighl
abdnl rust wispy lams
25% qtz.650/0 colored look like brighl
sub a- nhic+feld, carb Irags. wispy lams rootlets but 50% milky milky blue.
9 6147 Bermuda g w I ss n gray fln-uvfn well-mod sub r 10%biom..."lay gr muscov"e carb? clay? zeol, v- sl calc aren~ I m patch yellow wh"e y 9
25% qtz. 65% 100%
IIhic+feld, grains 100% n bright
sub r - s 10%biol"e+sin+ela anered to graded sd brown yellow in inslant bleeding oil blebs friable
10 6150 Bermuda I friable l-g lam sd and sh med gray fin-sill mod ang y gr muscov"e wh"e clay sl calc 10 clay gin sd s in sd sd blue-wh"e y ex sd
-
grains
25% qtz. 65% anered 10 100%
IIhic+leld, wh"e clay, sdd clay bright inslant
claysl with ss med-dk sub r - 10%biot"e+sm+ela carb Irags, rusl colored lams and tan in yellow in blue-while
11 6153 Bermuda I w fog in sd lams gray uvfn-Mn well 5 ang ygr muscov"e wispy lams calc low angle cross lams I in sd m sand sd in sd 85% claystone, 15% sd
25% qtz. 65% 100%
nhic+leld, grains bright 75% sd, 25% sh,
sub r - 10%biol"e+sm+ela carb Irags, anered 10 ripple lams, patchy yellow in inslant beautiful bddg features,
12 6155 Bermuda g w g-I shaley sdst dk gray Mn-uvfn mod-well 5 ang ygr muscov"e wh"e clay calc, clay Ihin scour gin sd s Ian sd blue-wh"e y ex sands have great show
25% qtz. 65% anered 10 100%
IIhic+leld, wh"e clay. bright
inlbdd sh and ss dkandn sub r- 10%biol"e+sm+ela carb Irags, rusl colored parallel in hi 4> yellow in instanl
13 6158 Bermuda' g w g-I with sm lams gray fin-win mod-well sang ygr muscov"e wispy lams calc Ihin lams gin sd s beds sd blue-wMe y vg 55% sh, 45% sd
15% qtz. 60%
IIhic+leld, 100% organic malerial in micro
sand with carb 1œ'obiol"e+sin+ela grains bright lams, concoidal and
lams and med-n sub r - y gr, 20% black carb Irags, anered to parallel 10% yellow in soft, sometimes fibrous
14 6161 Bermuda 9 w I microlams gray ufn-Mn mod sang orgmatl muscov"e wh"e clay sl calc vlhin lams I in sds vw palchy sd p and needley
~
...
('
(
f"
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO:
Camille O. Taylor, CO'\ DATE: February 13, 2002
Chair .\ 'r1
Tom Maunder, ff;:fYÝ/.~ð-
P. I. Supervisor ~O-,'L~
Lou Grimaldi, SUBJECT: Surface Abandonment
Petroleum Inspector Cirque #3
.~þj!Jip,,§,l\I~S~ê Inc. ," '~
J:~'!""; :-Þ'ê'rri,if#':201" ~244' - .
Exploratory
Confidential"
THRU:
FROM:
Tuesdav. Februarv 12. 2002; I witnessed the evidence of the surface plug and
subsurface abandonment marker plate on PAl exploratory well "Cirque #3".
I arrived the location to find the well ready to have the marker plate welded on.
There was cement to surface in the conductor with no other strings of casing
visible. The cement, although still "Green", seemed to be setting up quite nicely. I
allowed for the plate to be welded on. The following info had been bead welded to
the marker plate in the following fashion;
This location has Cirque #4 on it that also had the marker plate attached today (see
Cirque #4 2-12-02 LG.doc). A locationdearance inspection should be performed
when the location is cleaned up this summer.
SUMMARY: I witnessed the capping of Cirque #3, No problems observed.
Attachments: Surf abandonment Cirque 3 2-12-02 LG.xls
Cirque 3 cellar 2-12-02 LG.jpg
Cirque 3 monument 2-12-02 LG.jpg
Cirque 3 welded cap 2-12-02 LG.jpg
CONFIDENTIAL
020212-Surf Abandonement Cirque #3 LG.doc
..
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STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Surface Abandonment I Location Clearance I Suspended Well
(Title 20 AAC 25.170)
FILE INFORMATION:
Operator: Phillips Alaska Inc. Well Name: Cirque #3
Address: P.O. Box 100360, PTD No.: 201-244
Anchorage, Alaska 99510-0360 API No. 50- 103-20399-00
Surface Location (From Sec. Line): Unit or Lease Name: Exploration
North/South 377 FNL EastlWest 487 FEL Field and Pool: Exploration
Section: ~ Township: 9N Range: 7E Meridian: UM Downhole P&A Date: 01/31/2002 (J.J. Insp.)
20 AAC 25.120 - ABANDONMENT MARKER:
Insp. Date: I Suñace Monument T Approval Date:
Post OD: (4" min) " Length: ft. Set on (Wellhead, Csg , In Cmt)
- -
Height above final grade (4' min.): ft. Casing stub - ft. below final grade
Top of Marker Post Closed? - All openings closed?
Inspector:
Insp. Date: 2/12/02 I Subsuñace Monument I Approval Date:
Marker Plate Diameter: 16" " Distance below final grade Level: 5'
Thickness: 1/2 " Side Outlets removed or closed: Yes
Marker Plate Attached To Conductor ~(Y/N) Cement to surface (all strings)? Yes
Inspector: Lou grimaldi
Exact Information Beadwelded Directly to Marker Post or Blind Marker Plate:
Insp. Date: 2/12/02 I T Approval Date:
Phillips
ALasKa Inc.
APD#20 1-244
CIRQUE#3
API#50-1 03
20399-00
Inspector: Lou Grimaldi
Insp. Date: I 20 AAC 25.170 - LOCATION CLEANUP: I Approval Date:
Pit's filled in? Liners Removed or Buried? Debris Removed:
Notes:
General condition of pad/location: ( Rough, Smooth, Contoured, Flat, Natural)
Notes:
Type of area surrounding location: ( Wooded,Tundra,Grass,Brush,Dirt,Gravel,Sand)
Debris on surrounding area:
Notes:
Access road present? Type road: ( Dirt, Gravel, Ice, Other) Condition:
Condition of road:
Notes:
Cellar filled in? Type offill: Height above grade:
Notes:
Type work needed at this location:
Inspector:
RECOMMENDED FOR APPROVAL OF ABANDONMENT Yes
No
( If "No" See Reason)
Distribution:
orig - Well file
c - Operator
c - Database
c - Inspector
Reason:
Final Inspection performed? Yes
No
Final Approval By:
Title:
DATE:
Sheet by loG. 8/5/00
Surf abandonement Cirque 3 2-12-02 LG.xls
3/7/02
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,----.-
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From-Doyon tt141
(
901263301=
{ (
I
T-154 P. 001l006! F-4B9
I
;La \ ~ d- '-\ ~\
Aðb é-L
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RECEIVED
FEB 6 2002
Alaska Oil & Gas Cons. Comrnl5Sh.H.
AnchoraQß
:~eb~06-Z002 09:44
From~Doyon 11141
/t-
( f
90726SSr¡:
T-754
P.DO2/DOG
F-46Q
('
CIR UE #3 P&A SUMMARY
The following summarizes, with attachment~ plug and abc1ndonrnent cementing deUüls of CiTque #3.
Plug #1: 6677'-5896',8-1/2" open holc" 11 3 1/2002, .rill w/2-7/8" tbg stinger on 4" drillpìpe~ pump &
displaced balanced pIng of 55 bbl(lO8 sx) @ 11.0 ppg Litecftte w/cellotlake for LCM. Plug layed fIT.D.
OF 6677~ to 5896' in two Stages. No mud losses while circulating or displadng. POll slowly to 52) 8'.
Plug #2: 4833~-4480', 1-1/2" open hoJ~ 1/31/2002, spot hi-vis pill fl5218-4833', pump and displaced
b31anccd plug of 24.8 bbl(ll' sx) 15.8 ppg "G" cement. Plug f/52 18-4833' calcuJated in one stage. POH
slowly to 4352' and reverse circu13te unûI cleanretnms observed. POR fldrilling assembly. RIH w/8-1/2"
bit on HWDP and tag cement @ 4691' w/15k weight. Plng bad fa11en to top of iceberg intelva1. Plng tag
witnessed by Jeff Jones-AOGCC. POH, rib w/tbg stil1ger to top of plug @ 4691', Pump and displace
balallœd plug of 16.5 bid (80$x) @IS.8 ppg "G" fltop ofplug @46914466'. POR sJow1y to 4400' and
circulate to condition mud. POH fIret3Ïner.
Plug #3; 2512'-2287't 8..112" open hole and 9-518'" Ca8in~ 2/1/2002, RJH wlBakcr K-l retainer on
drillpipe to 2337'. ~l rot:ainer. nnsting. displace 17 bbl (82ss:) e'as:s "G" @lS.ß ~pg, sting-in bullh~:ad 13.5
bbl below retainer (175'-;-), unSling and poh slowly laying down 3.5 bbl (50') cement on top of retainer.
POH to 2114' and test csglrerainer to 1500 psi fl30 uùnutes. ?OR to ] 50S' and displace mud in hole to
dieseL POR lId dril1pipe.
Plug #4: 300'-s"ñace, 9-5l8tt Ca.c¡ìag, 2/1/2002. rib w/9..5/8" top plug (attempt to keep cement pl1.1g
£'slipping downhole) pus1rlng to 300' w/tubing, pump 22 bbl Arctic Set 1 cement to surface cellar, POll
slowly to 25 KB. & top off surface wIt bbl cement. Used total of 23 bbl (139 sx) Arçtic Set 1 cement.
Rig down and move to 21-03: final cutting of conductor and placement oIP & A market plate remains to
be done weatber permitting.
Ray W. Splinger
Drlg Supervisor
Doyon 141
:~eb-O6-2~O2 09:44
" ~.:::~,,/,r,~.~,~~or.on 11141
'f;~.':":;:' ,
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,', ,; '.-
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, ,~:'" ','
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Fluid No: pak plug315
Company : PhiIlJ~$ .
Well tJatil :
Job Type
BHST
Starting Temperature
Stanlng pressl¡re
Composition
Coda
Dry phase (;vntents
G
D045
0055
5001
-,feb-06-2002 09:46
From-Doyon 11141
'II"'",' . ,
~" ~~,- ,~Q,(A~,ii:-:S
PL-4'~ #3
; " '(" '
'~b~l:-L{'-1~6' '
( C S~. :'5 6l-cç f<e?1#~~ Test Report
, ',' . . Plug #3
90726330)= T-754 P,0041006 F-469
P e, A( I( JODlDepg.,
,f "
eq uested by : Kevin 1. I..oclñian : Doyon' 4
Well Name: CI ue #3 . Field ': Wlldca1
~~ ~
FI~L.D aLEND ,
casing
58 degF
80 degF
484 psi
: Depth 2412.0 ft TVD ;M12.0 ft
BHCT 65 degF :, ,BHþ, ",' '3974 þ~i' ,
lime to Temperature 00:35 hr:rnn' .'. " f.I~aiing Rate': " : ':.: ' : :::~
Time to Pressure 00:35 ht:mn " ",'. ',: , "
Lot Number
Cønc.
0.20 %I3WOC
0.30 %BWOC
2.00 %BWOC
, .~~ <~ ~,: ~I { ~.
. . ., .r: I'
I.f .",
WIt phase contents) ~
FreSh water
~I UI " IJ~I l:::In"
Base Fluid Cone.
Rh I
eo ogy
Filnn Readings MeO degF I At 65 degF /
(tom) (deg) , 'Cdeg)"'
300 61 105
200 51 92 ., " ..
100 41 79
50 36 71
30 33 62
a 24 32
3 19 25
110-
1 min
10 min
';J.~U IU~111
5.D92 gallsk
""UIU::U~Y
Mb( Fluid
;:¡ob.u "I/:J
5.092 gal/sk
, ' /I n.:l/sli "
J
T U:tlQ
¡.~ - I
I
I
..-
I Pv : 31.154 eFt '
Ty; 30.09Ibf/1 DDft2
p" : 41,570 cp ,
Ty 63.92 Ibf/1COft2
Thickening TImu
Consistency
306c
70 Be
100 Be
POD:
Batch MI" TIme:
1 ~ cI
Time
01:10 tu:mn
'02:21 hr:mn
02;55 hr:mn
at
, ,
SCHLUMaeRaE~ OOWELL OONFIDENTJAL
~~I'I~ ~C t~ uer
I
-'eb-06-Z002 09:46
From-Ton Q1(~ ( R q ~ E ~ ~T26f" ~thIU;;.~;;
f>~u.Co ~.2-
.Jr('11>33 - '5<69b
F-469
. .
Cement Test Report
Requested by : Kevin T,
Well Name' : CI u& #3
Location: Doyon 141
Apld : Wildcat
I 01130/02
FÆLD BLEND
j
J
cas "9
104 degF
80 degF
484 psI
Papth 4600,0 ft TVD 4600.0 ft
BHCT BO degF . ~I:iP" n' '. . ,.,' "~~~~, p~.1
lime to Temperature 00:35 hr.mn " Iï$atfnq Rate,'. ,~. ," :, ';, :: J '."
Time to Pressure DO~35 hr.mn ' ,. . ... " ' ' ,:',' "',f' ,.
Numr
I
Cone.
0.20 %BWOC
0.30 %BWOC
2.00 %BWOC
-
> 1
't . . ~ ; '\ ': '. :' ~ ~ '. .
, :.: :~, ~. ~ ..} p n ('.:,
Rheology
(t1Im) (d~g) (dëg)
300 61 ,111
200 : 51 ÐB . ,.,' ",
100 41 84
eo 36 7&
30 33 10
6 24 4,0
3 19 31 -
~ I
15,80' 98
5,092 allsk '
pOl'Ofilty
Mix Fluid
68.0
5.092 gpI/lil<
Ylold 1. 1 ft3/slt
.~~=]
I"
-~..:;
Pv ; 41 ,224 cp
TY: 70, 111bf/1 OOft2
Tlma
OO:P9 hr:mn
02:01 hr:mn
02;24 tlr:mn
, .. ..
vß"~ ~ ').¡
SCHLUMßE:RGER DOWELL CONFIDI:NT'AL
'1=eb;oQS-2Q02 09 :47
From-Doyon 11141
('
F-469
Fluid No : pak pfug3 3
CoM an : Phillips
wen Data
Jo ype
BHST
Starting Temperature
Starting Pressure
Cømpositlon
Code
Dry phase confflnts
G
CemPlu& Blend
0065
D167
D046
D800
OQ29
I ~:~~~~;r co,.tttnts
\lrl')' Dens tv
Base Fluid Oone;,
9072633p,n: , T-754 P. 006/006
(' Jl ~Q~E#-::S ~ <ï.' 1.
° SChlunibep.1P
8é)-Ho~ fL ~
-t-! (ob'T~ -'58'(0
Cement Test Report
~
L.ocatlon: oyon 141
FfÐI~ ~ Wildcat
~!ON
FIELD END
Casing
130 degF
80 deQF
484 81
Depth 6677.0 tt TVO 6077.0 -'J
BHCT 108 degF SHP. ' ':'",;. " J;~q,!.",.p'~1
1ime to Temperature 00:35 hr:l"nn. ~~a~i~1l ~~:.:' ¡: "Cj:,:.-r.,8',d: : gF/mln
Time to Presflure 00:36 hr;mo '
"at Number
Cone.
-
0.75 %ÞWOC
O.3ß %8WOC
0.20 %8WOC
0.10 %SWOC
0.64 %BWOC
~ -- '
"
2.851t3 s --~''''''''-'-'-'J
~ I ",-,--,~'._"R"'_""
11.00 I Iga'
10.219 al/ak
PorQS Y
Mb< Fluid
laid
Rheology
Fann RéadJngs At 80 degF ( At 108 degF I -,
(rpm) (deg) (dag) . t,.: ',I. .
300 67 117
200 50 67
100 \ 31 56
60 I 24 43
30 16 33
e 11 25
- - . ,." ".:'-,.
r fv : 56.557 tP Pv ; 93.217 cP
Tv: 11 40 Ibf/1 00ft2 Ty; 24.36 IÞf/100ft2
FluId Lotti
32 mlln 30 rriln at 108 M~ 1000 I
degF psi
API Fluid Loss 64 mL
, "
\~I i,~ ;1': : ~ \ :
r. ~ .
Ime
03:03 hr:mn
04:QO hr:mn
04;11) nr:mn
Compan~ Man Copy
°ICHUlMI'If:RG¡;R DOWJ:I.~ CONFIDENTIAl.
(
PHILLIPS PHilliPS Alaska, Inc.
~ A Subsidiary of PHILLIPS PETROLEUM COMPANY
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
TRANSMITTAL
TO:
AOGCC
333 W 7TH AVE
Anchorage, AK 99501
OPERATOR: PAl
SAMPLE TYPE: DRIES
SAMPLES SENT:
~IRQUE 3
140-6660
SENT BY: Mike .McCracken
~l
DA TE: 02-05-02
AIRBILL: NIA
ABV#: PBV 02-02-05-04
CHARGE CODE#: 42374
WELL: CIRQUE 3
A () I - À vi i
) 0 )-~
:/Þ
NUMBER OF BOXES: 1 Bundle (5 boxes)
UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL
A SIGNED COpy OF THIS FORM TO:
RECEIVED BY:
/L-l D~
Phillips Alasl<:a, Inc.
619 E. Ship Creel{ Ave
Anchorage, AK. 99510
Attn: Dan Przywojski
DATE:)/?& Á ~~:1--
~' !-t
C()f~
Re: Cirque 3 P&A Plug
(
(
Subject: Re: Cirque 3 P&A Plug
Date: Fri, 01 Feb 2002 06:52:24 -0900
From: Tom Maunder <tom_maunder@admin.state.ak.us>
To: Mark A Chambers <mchambe2@ppco.com>
CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us>
Jill ~J-¿(L(
Mark,
This confirms our discussion regarding setting the additional plug and not
needing to tag it. Jeff witnessed a solid tag and the additional cement is not
going to go downhole. Good luck with the remaining operations.
Tom Maunder, PE
AOGCC
Mark A Chambers wrote:
> Ray:
>
> I spoke wI Tom Maunder at the AOGCC and explained that we tagged to top of
> our second isolation plug 211' below the expected location (11' below Top
> Iceberg) and that we set 20k Ibs on the plug without movement as witnessed
> by Jeff Jones. I outlined our plan to spot an additional 225' of cement on
> top of the plug and Tom agreed no further tags would be required.
>
> Call me if there are any questions.
>
> Mark
Tom Maunder <tom maunder@admin.state.ak.us>
Sr. Petroleum Engineer
Alaska Oil and Gas Conservation Commission
------
----
1 of 1
211/027:49 AM
Re: Cirque 3 (PTO 201-244) P&A Procedure and Schematic
(
.f
~.
Subject: Re: Cirque 3 (PTD 201..244) P&A Procedure and Schematic
Date: Wed, 30 Jan 2002 16:36:11 -0900
From: Tom Maunder <tom_maunder@admin.state.ak.us>
To: Mark A Chambers <mchambe2@ppco.com>
CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us>
Mark,
I have looked at the procedure you have provided for the proposed P&A. The planned setting depths of
the plugs is acceptable. The only requirements we will add is that you should plan to tag the plug
being set across the Iceberg. Please have your Rig Supervisor notify the Inspector at 659-2714 so
that he may be present to witness the tag. Also have the Inspector contacted when everything is cut
off prior to welding on the abandonment plate.
I have received the sundry notice and will forward it for approval. Since it is likely that plugging
operations will begin tonight, you have approval to proceed as planned and as modified by this
email. Good luck.
Tom Maunder, PE
AOGCC
Mark A Chambers wrote:
> Tom:
>
> I have attached a copy of the general procedure and planned P&A schematic
> for your review (Original and 403 will follow by courier). Call me when
> you receive and we can discuss before proceed. Thanks.
>
> Mark Chambers
> Exploration Drilling Engineer
>
> (See attached file: Cirque 3 P&A Schematic v1. vsd)(See attached file:
> Cirque 3 Agency P&A Procedure 01 30 02.doc)
>
> ------------------------------------------------------------------------
>
>
>
>
>
>
>
Name: Cirque 3 P&A Schematic v1. vsd
Cirque 3 P&A Schematic v1.vsd Type: unspecified type (application/octet-stream)
Encoding: base64
Name: Cirque 3 Agency P&A Procedure 01 30 02.doc
Cirque 3 Agency P&A Procedure 01 30 02. doc Type: WINWORD File (application/msword)
Encoding: base64
r::;:;.::::::::::::::=;;;::=::=:::::::::::::::::::::::=:::~..w".""",::::::::::::::==:::::::::==:::::::::::;::::::::::::::::::::::::::=::::::::::::::::::::::::::;;:::::::::::::~,:::::::::::::::::::==,,:::::::::==:::::::::.:==::::::\
I
I
Tom Maunder <tom_maunder@admin.state.ak.us> '
Sr. Petroleum Engineer
Alaska Oil and Gas Conservation Commission
1 of 1
1/30/024:37 PM
( STATE OF ALASKA (
ALASKA Oil AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
t \/-.. \
JMH- 1/~,loz-
Description summary of proposal _X Detailed operations program - BOP sketch - Schematic _X
I Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic -
14. Estimated date for commencing operation 15. Status of well classification as:
January 30, 2002
16. If proTfSas ver~ally apprfved Oil -
Name~o~~ \('!.\)-~t~approved Service-
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed P'U/~: err¡ ~ - , Title: Drilling Team Leader
FOR COMMISSION USE ONLY
Conditions of approval: Notify Com!l}ission so representative may witness "
Plug integrity b BOP Test - Location clearance .£!t
Mechanical Integrity Test - Subsequent form required 10- \....\0 ~
.,.
, .
1. Type of request:
Abandon _X Suspend -
Alter casing - Repair well -
Change approved program -
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P. O. Box 100360
Anchorage, AK 99510-0360
4. Location of well at surface
378' FNl, 486' FEl, Sec.28, T9N, R7E, UM
At top of productive interval
1662' FSl, 1273' FEl, Sec. 21, T9N, R7E, UM
At effective depth
At total depth
1934'FSl, 1378'FEl,Sec.21,T9N, R7E,UM
12. Present well condition summary
Total depth: measured
true vertical
6677
6096
Effective depth:
surface
measured
true vertical
Length
80'
2384'
Casing
Conductor
Surface
Production
Liner
Size
16"
9.625"
Perforation depth:
measured
No perforations
true vertical
No Perforations
Tubing (size, grade, and measured depth
No tubing run
Packers & SSSV (type & measured depth)
No packers, No SSSV
13. Attachments
Operational shutdown -
Plugging -
Pull tubing -
5. Type of Well:
Development -
Exploratory _X
Stratigraphic -
Service -
(asp's: 455748, 5890540)
(as proposed)
(as proposed)
feet
feet
feet
feet
Plugs (measured)
Junk (measured)
Cemented
213 sx AS 1
410 sx AS Lite, 251 sx LiteCrete
Approved by order of the Commission
Original Signed By
I,;ammy ueChsll
Form 10-403 Rev 06/15/88 .
OR\G\NAL
Re-enter suspended well -
Time extension - Stimulate -
Variance - Perforate -
6. Datum elevation (DF or KB feet)
28' RKB feet
7. Unit or Property name
Exploratory
Other -
8. Well number
Cirque #3
9. Permit number I approval number
201-244
10. API number
50-103-20399-00
11. Field I Pool
Exploration /
Measured Depth
108'
2412'
True vertical Depth
108'
2412'
RECEIVED
JAN 3 0 2002
Alaska Oil & Gas COOl. {'~_:..
Anchorage ¥WI,......,n
Gas-
Suspended -
Questions? Call Mark Chambers 265-1319
Date () '/30 102-
Prepared bv Sharon Allsup-Drake
APproval~ - OL\ (0
Commissioner
Date \ ~ 110 J
,
.
SUBMIT IN TRIPLICATE
....
Lrque 3
Proposed Cement P&A Schematic
Exploration Well - Confidential
PHilliPS Alaska, Inc.
A Subsidiary of PHilLIPS PETROLEUM COMPANY
Conductor:
16",62.58#
Set @ +1- 108' MD
Cement
300' Cement Plug Set From Surface to 300' MD
. . . . . . . . . . . . . .. . . . . . . . . . . . . .
137 sacks Arctic Set 1
Slurry Weight
Slurry Yield
Thickening Time
BHST
15.7 ppg
0.93 cu-ftIsk
2 Hrs 5 Min
32 Deg F
TAM Port Collar:
9-5/8" BTC Box x Pin
Set @ +1- 1000' MD
~ ~a'~'
~..~~J ~ \:~
X-- 'JCt.~\ ìft.'Y\\(~
Surface Casing
9-5/8" 40# L-80 BTC
Set @ +1- 2412' MD
Cement
225' Cement Plug Set From 2287' MD to 2512' MD
(50' Above and 175' Below Baker K-1 Cement Retainer)
9-5/8" Casing Cemented to
Surface with 410 sx 10.7 ppg
ARCTICSET Lite and 251 sx
12.0 ppg LiteCRETE
79 sacks Class G + Additives
Slurry Weight
Slurry Yield
Thickening Time
BHST
15.8 ppg
1.17 cu-ftIsk
3 Hrs 57 Min
54 Deg F
353' Cement Plug Set From 4833' MD to 4480' MD
8- W' Open Hole
CerTlent
Top Iceberg @ 4680' MD
Base Iceberg @ 4733' MD
Open Hole Caliper Log
Indicates Gage Hole
(8-W') from 9-5/8"
Casing Shoe to TD.
This Data Was Utilized
to Calculate Cement
Volumes for Open Hole
~
119 sacks Class G + Additives
Slurry Weight' 15.8 ppg
Slurry Yield 1.17 cu-ftIsk
Thickening Time 3 Hrs 20 Min
BHST 100 Deg F
10.0 ppg Mud Between
Cement Plugs
781' Cement Plua Set From 6677' MD to 5896' MD
(Plan to Set Cement plug in 2 Stages).
Cement
108 sacks LiteCRETE
Slurry Weight
Slurry Yield
Thickening Time
BHST
11.0 ppg
2.84 cu-ftIsk
4 Hrs 10 Min
130 Deg F
Top Bermuda @ 6096' MD
Base Bermuda @ 6247' MD
TD 8-1/2" Hole @ 6677' MD 16096' TVD
Cirque 3 P&A Schematic
prepared by Mark Chambers
01/30/02
{
Cirque #3 PM Procedure (
Exploration Well - Confidential
1. Notify AOGCC 24 hours in advance of all pressure testing and well suspension
operations. Hold pre-job meeting with all personnel to discuss objectives, as well as
safety and environmental issues.
2. Mobilize and rig up DjS for well PM operation.
3. Spot a balanced cement plug #1 from TD @ 6677' MD to 5896'MD (approx. 200'
above top of the Bermuda at 6096' MD). This plug can be laid in two sections as
needed. Total interval is approximately 781' in length.
4. Spot a balanced cement plug #2 from 4883' MD to 4480' MD (approx. 200' above top
of Iceberg at 4680' MD and 100' below base of Iceberg at 4733' MD). Total interval is
approximately 353' in length. Lay 15-25 bbl high vise pill below the plug before
cementing.
5. By the down squeeze method through a retainer set 75' above the shoe (or approx.
2337') pump cement plug #3 as per AOGCC regulations. Pump sufficient cement
through the retainer to extend 175' below (75' of casing volume plus 100' of open
hole) and lay a 50' cement cap on top of the retainer. Weight test retainer before
pumping cement. Leave 10.0 ppg mud above and below the plug (Weight of mud
needed to TD the hole) Pressure test plug to 1500 psi for 30 minutes.
6. While POOH, stop and displace a sufficient volume of diesel to freeze protect top
1500' of well bore (Base Permafrost @ 1312' MD). Continue POOH.
7. Spot a balanced Arctic Set 1 cement plug #4 from 300' to surface.
8. Clear lines and shut down pumps. Rig down cementing unit and clean up.
9. Cut off wellhead and all casing strings at 3 feet below ground level. Send casing head
with stub to Materials for repair j re-dressing.
10. Weld cover plate (at least 18" in diameter) over all casing strings with the following
information bead welded into the top:
PHILLIPS ALASKA, INC
CIRQUE #3
PTD# 201-244
API# 50-103-20399-00
11. Remove cellar. Back fill cellar with gravel as needed. Back fill remaining hole to
ground level with gravel. Clear ice pad location and demob all materials and
equipment.
MAC 01/30/02
{
PHilliPS Alaska Inc.
Cirque #3
(
See 28- T9N-R7E UM
North Slope Borough Alaska
January 19 2002
John Morris Sr. Logging Geologist
Brady Kilmer Sr. Logging Geologist
Fletcher England Logging Geologist
~ EPOCH
,. "
(
ð,OJ-aL/L/
TABLE OF CONTENTS
("
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Phillips Alaska Inc.
Cirque #3
North Slope Borough
TABLE OF CONTENTS ... .................. ......... .... ... ....... ..... ................ ................. ..... ...........2
WELL RESUME.............................................................................................................. 3
LITHOLOGY AND REMARKS... """ ..... ...... .,., ... ....... ........ .... ........ ......... .............. ........... 4
(
RIG ACTIVITIES.......,....................................................................................................~:!
MUD RECORD. ...... .......... ... .,... ........ ....... ..... .... ..... ..... ..... ........... ...... .... ..... ..... ......... ......24
SURVEY RECORD.............................................................. ......................................... ~5
BIT RECORD ................................................................................................................~II
DAYS VS. DEPTH. .......... .,.......... ........,.. ......... ...... ...... ...... ........... ...... ..... ... ....... ...... ... ...29
MORNING REPORTS ...... ....... ....................... ...... .... .......... ... ...... ........ ....... ..APPENDIX 1
FINAL LOGS......................... ...... ........ ........................................................ .APPEN DIX :!
\
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2
PHilliPS Alaska, Inc.
œ
m
( Cirque #3
WELL RESUME
Operator Phillips Alaska Inc.
Well Name: Cirque #3
Location: Sec. 28 T9N R7E UM
Coordinates: 377' FNL 487' FEL
Elevation: RKB: 178'
County: North Slope Borough
State: Alaska
AFE No.: AX 2169
Spud Date: January 192002
Contractor: Doyon Drilling
(
" Don Presnell Ray Springer
Foremen:
Rig: #141 - Land
Logging Unit: MLOA3
Geologists: John Morris
Brady Kilmer
Fletcher England
Co. Geologist: Rick Levinson
Laurel Alexander
Log Interval: 108' to 6677'
Dates: 1/19/2002 to 1/29/2002
Mud Types: Spud Mud to 2422'
LSND to 6677'
Casing Data: 9 5/8" at 2412'
( Hole Size: 12 %" to 2422' 8 Y2" to 6677'
(J EPOCH 3
(
PHILLIPS Alaska, Inc.
~
~
Cirque #3
LITHOLOGY AND REMARKS
110' MD 110' TVD
Gravel/conglomeratic sand = Variety of colors and lithologies including white olive
grays dark greenish grays browns and shades of green; grain size ranges from very
coarse sand to granules to pebbles coming over the shakers; grains are rounded to well
rounded with occasional sub-angular to angular clasts; moderate to poor sorting; low to
moderate sphericity; frosted to polished surface texture with common impacts visible;
lithologies include massive quartz chert claystone limestone dolomite volcanics and
igneous lithics.
185' MD 184' TVD
~conglomeratic und/sand = Variety of colors and lithologies including white
olive grays dark greenish grays browns and shades of green; grain size ranges from
coarse sand to granules to pebbles coming over the shakers; grains are rounded to well
rounded with occasional sub-angular to angular clasts; moderate to poor sorting;
moderate to low sphericity; frosted to polished surface texture with common impacts
visible; lithologies include massive quartz chert claystone dolomite limestone volcanics
and igneous lithics with scattered tuff.
(,
265' MD 265' TVD
ravel/con lomeratic sand/sand = Variety of colors and lithologies including white
olive grays dark greenish grays browns and shades of green; grain size ranges from
coarse sand to granules to pebbles coming over the shakers; grains are rounded to well
rounded with occasional sub-angular to angular clasts; moderate to poor sorting;
moderate to low sphericity; frosted to polished surface texture with common impacts
visible; lithologies include massive quartz chert claystone limestone dolomite volcanic
and igneous lithic clasts; scattered tuff; increasing clay in samples with depth.
370' MD 370' TVD
Gravel/con lomeratic sand/sand = Variety of colors and lithologies including white
olive grays dark greenish grays browns and shades of green; grain size ranges from
coarse sand to granules to pebbles coming over the shakers; grains are rounded to well
rounded with occasional sub-angular to angular clasts; moderate to poor sorting;
moderate to low sphericity; frosted to polished surface texture with common impacts
visible; lithologies include massive quartz chert claystone limestone dolomite volcanic
and igneous lithic clasts; scattered tuff; increasing clay in samples with depth.
(
455' TVD 454' TVD
Gravel/con lomeratic sand/sand = Variety of colors and lithologies including white
olive grays dark greenish grays browns and shades of green; grain size ranges from
coarse sand to granules to pebbles coming over the shakers; grains are rounded to well
rounded with occasional sub-angular to angular clasts; moderate to poor sorting;
n EPOCH
4
".,
~
(
PHilliPS Alaska, Inc.
~
~
Cirque #3
moderate to low sphericity; frosted to polished surface texture with common impacts
visible; lithologies include massive quartz chert sandstone claystone limestone dolomite
quartzite scattered tuff and igneous lithics trace schist clasts and coal.
540' MD 539' TVD
Gravel/con lomeratic sand/sand = Variety of colors and lithologies including white
olive grays dark greenish grays browns and shades of green; grain size ranges from
coarse sand to granules to pebbles coming over the shakers; grains are rounded to well
rounded with occasional sub-angular to angular clasts; moderate to poor sorting;
moderate to low sphericity; frosted to polished surface texture with common impacts
visible; lithologies include massive quartz chert sandstone claystone limestone dolomite
quartzite scattered tuff and igneous lithics trace schist clasts and coal.
625' MD 624' TVD
Coal = Brownish black to black; crumbly to crunchy rare brittle tenacity; blocky to
irregular to hackly fracture; irregular to blocky cuttings habit; earthy to dull luster;
smooth to slightly mottled surface texture; variable thin/thick laminations.
(
665' MD 664' TVD
Gravel/con lomeratic sand/sand = Variety of colors and lithologies including white
olive grays dark greenish grays browns and shades of green; grain size ranges from
coarse sand to granules to pebbles coming over the shakers; grains are rounded to well
rounded with occasional sub-angular to angular clasts; moderate to poor sorting;
moderate to low sphericity; frosted to polished surface texture with common impacts
visible; lithologies include massive quartz chert sandstone claystone limestone dolomite
quartzite scattered tuff and igneous lithics trace schist clasts and coal.
750' MD 749' TVD
Cla~ = Brownish gray to olive gray; lumpy to clotted; sub..sectile to no tenacity; no noted
fracture; nodular to massive equant cuttings habit; dull to earthy luster; clayey to silty
and sandy texture associated with conglomeratic sands; thick structure interbedded by
conglomeratic sands; non calcareous.
795' MD 794' TVD
Gravel/con lomeratic sand/sand = Variety of colors and lithologies including white
olive grays dark greenish grays browns and shades of green; grain size ranges from
coarse sand to granules to pebbles coming over the shakers; grains are rounded to well
rounded with occasional sub-angular to angular clasts; moderate to poor sorting;
moderate to low sphericity; frosted to polished surface texture with common impacts
visible; lithologies include massive quartz chert sandstone claystone limestone dolomite
quartzite scattered tuff and igneous lithics trace schist clasts and coal.
880' MD
878' TVD
(
~ EPOCH
5
f
(
PHilliPS Alaska, Inc.
~
~
Cirque #3
Claystone = Light brownish gray to brownish gray to olive gray and light olive gray;
lumpy to clotted to punky consistency; sub-sectile to no tenacity; no noted fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to silty and sandy
texture associated with conglomeratic sands; thick structure interbedded by
conglomeratic sands; non calcareous.
935' MD 933' TVD
Conglomeratic sand/sand = Varied colors from translucent white to black to dusky
yellow green to olive gray; grains range in size from coarse sand to medium sand to
pebbles; grains exhibit high energy environment with subrounded to sub-angular with
occasional bit broken angular; poor to moderate sorting; high sphericity; some frosted
surface abrasion but predominantly no surface texture; thinly bedded; non calcareous;
no hydrocarbon indicator.
1000' MD 997' TVD
~ = Light brownish gray to brownish gray to olive gray and light olive gray;
lumpy to clotted to punky consistency; sub-sectile to no tenacity; no noted fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to silty and sandy
texture associated with conglomeratic sands; thick structure interbedded by
conglomeratic sands; non calcareous.
(
1055' MD 1051' TVD
Con lomeratic sand/sand = Varied colors from translucent white to black to dusky
yellow green to olive gray; grains range in size from coarse sand to medium sand to
pebbles; grains exhibit high energy environment with subrounded to sub-angular with
occasional bit broken angular; poor to moderate sorting; high sphericity; some frosted
surface abrasion but predominantly no surface texture; thinly bedded; non calcareous;
no hydrocarbon indicator.
1120' MD 1115' TVe
Siltstone = Medium dark gray; silt grain size with occasional lower very fine grain sand;
pasty to mushy consistency; stiff to sectile tenacity; irregular to no fracture; nodular to
equant cuttings habit; dull to earthy luster to slightly sparkling; silty to gritty texture;
thinly bedded.
1165' Me 1159' TVD
~ = Light brownish gray to brownish gray to olive gray and light olive gray;
lumpy to clotted to punky consistency; sub-sectile to no tenacity; no noted fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to silty and sandy
texture associated with conglomeratic sands; thick structure interbedded by
conglomeratic sands; non calcareous.
t
U EPOCH
6
(
PHilliPS Alaska, Inc.
~
~
Cirque #3
1240' MD 1231' TVD
Sand = Clear to translucent to light brown to black; fine to medium grain; moderately
sorted; 80% quartz 20% lithics and coal; sub-angular to angular to subround; moderate
sphericity; low frosted surface abrasion; traces to 10% sea shell fragment;
predominately unconsolidated with some graded to very fine grained sandstone with
clay matrix; no hydrocarbon indicators.
1295' MD 1284' TVD
Siltstone = Medium dark gray; silt grain size with occasional lower very fine grain sand;
pasty to mushy consistency; stiff to sectile tenacity; clasts contain fine carbon
inclusions; irregular to no fracture; nodular to equant cuttings habit; dull to earthy luster
to slightly sparkling; silty to gritty texture; thinly bedded.
1298' MD 1290.00' TVD
To of the West Sak Sand
1312' MD 1300.80' TVD
Base of the Permafrost
(
1345' MD 1332' TVD
Cla'l§.tone = Light brownish gray to brownish gray to olive gray and light olive gray;
lumpy to clotted to punky consistency; sub-sectile to no tenacity; no noted fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to silty and sandy
texture associated with conglomeratic sands; thick structure interbedded by
conglomeratic sands; non calcareous.
1400' MD 1385' TVD
Siltstone = Medium dark gray; silt grain size with occasional lower very fine grain sand;
pasty to mushy consistency; stiff to sectile tenacity; clasts contain fine carbon
inclusions; irregular to no fracture; nodular to equant cuttings habit; dull to earthy luster
to slightly sparkling; silty to gritty texture; thinly bedded.
1450' MD 1432' TVD
~ = Light brownish gray to brownish gray to olive gray and light olive gray;
lumpy to clotted to punky consistency; sub-sectile to no tenacity; no noted fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to silty and sandy
texture associated with conglomeratic sands; thick structure interbedded by
conglomeratic sands; non calcareous.
1505' MD 1484' TVD
Sand = Clear to translucent to light brown to black; fine to medium grain; moderately
sorted; 80% quartz 20% lithics and coal; sub-angular to angular to subround; moderate
sphericity; low frosted surface abrasion; traces to 10% sea shell fragment;
t
g EPOCH
7
(
PHilliPS Alaska, Inc.
~
~
Cirque #3
predominately unconsolidated with some graded to very fine grained sandstone with
clay matrix; no hydrocarbon indicators.
1560' MD 1537' TVD
CI@.ystol1,! = Light brownish gray to brownish gray to olive gray and light olive gray;
lumpy to clotted to punky consistency; sub-sectile to no tenacity; no noted fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to silty and sandy
texture associated with conglomeratic sands; thick structure interbedded by
conglomeratic sands; non calcareous.
1615' MD 1588' TVD
Siltstone = Olive gray to medium dark gray; pasty to mushy consistency; sub-sectile to
stiff tenacity; irregular to earthy to no fracture; massive to elongated to nodular cuttings
habit; dull to earthy luster; variable surface texture from silty to gritty with occasional
smooth cuttings; thinly bedded structure commonly grading to claystone or very fine
grained sandstone interbeds; non-calcareous.
(
1675' MD 1644' TVD
~ = Light brownish gray to brownish gray to olive gray and light olive gray;
lumpy to clotted to punky consistency; sub-sectile to no tenacity; no noted fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to silty and sandy
texture associated with conglomeratic sands; thick structure interbedded by
conglomeratic sands; non calcareous.
1730' MD 1694' TVD
Sand = Clear to translucent to light brown to black; fine to medium grain; moderately
sorted; 800/0 quartz 200/0 lithics and coal; sub-angular to angular to subround; moderate
sphericity; low frosted surface abrasion; traces to 10% sea shell fragment;
predominately unconsolidated with some graded to very fine grained sandstone with
clay matrix; no hydrocarbon indicators.
1785' MD 1744' TVD
~ = Light brownish gray to brownish gray to olive gray and light olive gray;
lumpy to clotted to punky consistency; sub-sectile to no tenacity; no noted fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to silty and sandy
texture associated with conglomeratic sands; thick structure interbedded by
conglomeratic sands; non calcareous.
(
1840' MD 1793' TVD
~ = Light brownish gray to brownish gray to olive gray and light olive gray;
lumpy to clotted to punky consistency; sub-sectile to no tenacity; no noted fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to silty and sandy
texture associated with conglomeratic sands; thick structure interbedded by
conglomeratic sands; non calcareous; continue trace to 1 % shell fragments in samples.
n EPOCH
8
{
PHilliPS Alaska, Inc.
~
~
Cirque #3
1900' MD 1846' TVD
Siltstone = Olive gray to medium dark gray; pasty to mushy consistency; sub sectile to
stiff tenacity; irregular to earthy to no fracture; massive to elongated to nodular cuttings
habit; dull to earthy luster; variable surface texture from silty to gritty with occasional
smooth cuttings; thinly bedded structure commonly grading to claystone or very fine
grained sandstone interbeds; non-calcareous; trace shell fragments scattered in
samples.
1965' MD 1904' TVD
Sandstone = Olive gray overall individual grains vary from clear to translucent shades
of green and yellow to dark gray to black; cuttings are very hard and brittle; fine lower to
fine upper with trace medium lower grain size; well to moderately well sorted; sub-
angular to angular occasional subround grains; moderate to low sphericity; polished
and frosted surface textures on individual grains; silty matrix; matrix support with
calcareous cement; estimate90% quartz 10% assorted green chert lithics micas and
shell fragments; no hydrocarbon indicators.
(
2045' MD 1975' TVD
~ = Olive gray to medium dark gray; pasty to mushy consistency; sub seetHe to
stiff tenacity; irregular to earthy to no fracture; massive to elongated to nodular cuttings
habit; dull to earthy luster; variable surface texture from silty to gritty with occasional
smooth cuttings; thinly bedded structure commonly grading to claystone Of very fine
grained sandstone interbeds; non-calcareous; trace shell fragments scattered in
samples.
2048' MD 1977' TVD
Base of the West Sak Sand
2110' MD 2033' TVD
~ = Light brownish gray to brownish gray to olive gray and light live gray;
lumpy to clotted to punky consistency; sub-sectile to no tenacity; no noted fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to silty and sandy
texture associated with conglomeratic sands; thick structure interbedded by
conglomeratic sands; non calcareous; continue trace to 1 % shell fragments in samples.
2170' MD 2086' TVD
Sand = Clear to translucent to light brown to black; fine to medium grain; moderately
sorted; 80% quartz 20% lithics; sub-angular to angular to subround; moderate to low
sphericity; low frosted surface abrasion; traces to 100/0 sea shell fragment;
predominately unconsolidated with some graded to siltstone with soft clay matrix; no
hydrocarbon indicators.
(
2225' MD
2135' TVD
[:I EPOCH
9
(
PHilliPS Alaska, Inc.
~
~
Cirque #3
CI@.Vstone = Light brownish gray to brownish gray to olive gray and light olive gray;
lumpy to clotted to punky consistency; sub-sectile to malleable tenacity; earthy fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to slightly silty
texture associated with sands; thick structure interbedded by conglomeratic sands; non
calcareous.
2280' MD 2184' TVD
Clf!vstone = Light brownish gray to brownish gray to olive gray and light olive gray;
lumpy to clotted to punky consistency; sub-sectile to malleable tenacity; earthy fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to slightly silty
texture associated with sands; thick structure interbedded by conglomeratic sands; non
calcareous.
2335' MD 2232' TVD
Sandstone = Very pale orange to yellowish gray overall; individual grains transparent to
translucent to black and green; fine to medium grain moderately sorted; crunchy to
brittle tenacity; blocky fracture; nodular to blocky cuttings habits; sub-vitreous luster;
granular to sucrosic texture; thin bedding; no visible hydrocarbons; calcareous tuff
matrix material.
/
\
2412' MD
9 5/8" Casin
2301' TVD
oint.
2440' MD 2326' TVD
~ = Light brownish gray to brownish gray to olive gray and light olive gray;
lumpy to clotted to punky consistency; sub-sectile to malleable tenacity; earthy fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to slightly silty
texture associated with sands; thick structure interbedded by conglomerate sands; non
calcareous.
2495' MD 2374' TVD
Siltstone = Medium light gray to medium gray to olive gray; some graded to very fine
upper sandstone; brittle to crunchy tenacity; fine carbonaceous inclusions; irregular
fracture; nodular to equant cuttings habit; sparkling luster; gritty to silty texture; thin to
laminae bedding; no hydrocarbon indicators.
(
2545' MD 2419' TVD
Sandstone = Medium gray to olive gray; individual grains vary from clear to translucent;
cuttings are very hard and brittle; fine lower to fine upper with trace medium lower grain
size; well to moderately well sorted; sub-angular to angular occasionally subround
grains; moderate to low sphericity; polished surface abrasion on individual grains; silty
matrix; matrix support with calcareous cement; estimate 90% quartz 10% assorted
chert and lithics; no hydrocarbon indicators.
n EPOCH
10
(
PHILLIPS Alaska, Inc.
~
~
Cirque #3
2615' MD 2483' TVD
Clay~one = Light medium gray to medium gray to olive gray and light olive gray; lumpy
to clotted to punky consistency; sub-sectile to malleable tenacity; earthy fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to silty texture;
some graded to siltstone; thick structure bedding.
2665' MD 2526' TVD
Siltstone = Medium light gray to medium gray to olive gray; some graded to very fine
upper sandstone; brittle to crunchy tenacity; fine carbonaceous inclusions; irregular
fracture; nodular to equant cuttings habit; sparkling luster; gritty to silty texture; thin to
laminae bedding; no hydrocarbon indicators.
2735' MD 2589' TVD
Sand = Clear to translucent with abundant black chert green glauconite and chlorite or
other metalithics; 75% quartz 15% chert and assorted lithics; very fine to fine to
occasionally medium grains; moderately sorted; sub-angular to sub-round; low
sphericity; low surface abrasion; traces pyrite seashell fragments; traces bright yellow
mineral fluorescence slight slow leach cut from siltstones; no staining or residual rings.
(
2795' MD 2643' TVD
Ash fall tuff:: White to yellowish gray to moderate orange pink to light brown; firm
consistency; sub- brittle to dense tenacity; hackly to mottled fracture; nodular to equant
cuttings habit; earthy to dull luster; smooth to clayey texture; thinly bedded.
2860' MD 2702' TVD
~ = Light medium gray to medium gray to olive gray and light olive gray; lumpy
to clotted to punky consistency; sub-sectile to malleable tenacity; earthy fracture;
nodular to massive equant cuttings habit; dull to earthy luster; clayey to silty texture;
some graded to siltstone; thick structure bedding.
2910' MD 2748' TVD
Ash fall tuff = White to very light gray; black carbonaceous inclusions; firm
consistency; sub-brittle to dense tenacity; hackly to planar and flaky to mottled fracture;
nodular to equant cuttings habit; earthy to dull luster; smooth to clayey texture; thinly
interbedded with clays and carbonaceous materials.
(
2960' MD 2791' TVD
Sandstone = Medium gray to olive gray; individual grains vary from clear to translucent;
cuttings are very hard and brittle; fine lower to fine upper and some medium lower grain
size; moderately well sorted; sub-angular to angular occasionally sub-round grains;
moderate to low sphericity; undetermined surface abrasion; ashy matrix material; matrix
support with calcareous cement; estimate 900/0 quartz 10% assorted chert and
carbonaceous materials; abundant pyrite 100/0 calcite and carbonaceous materials; no
hydrocarbon indicators.
(j EPOCH
11
(
PHilliPS Alaska, Inc.
~
~
Cirque #3
3040' MD 2863' TVD
Siltstone = Medium light gray to medium gray; traces are graded to very fine upper
sandstone; brittle to crunchy tenacity; fine carbonaceous inclusions; irregular fracture;
nodular to equant cuttings habit; sparkling luster; gritty to silty texture; thin to laminae
bedding; ashy matrix material and graded to tuffaceous siltstone; no hydrocarbon
indicators.
3100' MD 2916' TVD
~ = Light medium gray to medium gray to olive gray and light olive gray; lumpy
to clotted to punky consistency; sub-sectile to malleable tenacity; earthy fracture;
nodular to massive equant cuttings habit; dull to earthy luster; silty to clayey texture;
some graded to siltstone; thin bedding with thinly interbedded siltstones.
3150' MD 2961' TVD
Ash = White to yellowish gray; firm consistency; sub- brittle to dense tenacity; hackly to
mottled fracture; nodular to equant cuttings habit; earthy to dull luster; smooth to clayey
texture; thinly bedded.
(
3190' MD 2996' TVD
~ = Light medium gray to medium gray to olive gray and light olive gray; lumpy
to clotted to punky consistency; sub-seetHe to malleable tenacity; earthy fracture;
nodular to massive equant cuttings habit; dull to earthy luster; silty to clayey texture;
some graded to siltstone; thin bedding with thinly interbedded siltstones.
3240' MD 3041' TVD
Siltstone = Medium light gray to medium gray; traces are graded to very fine lower
sandstone with scattered very fine upper to medium lower individual sand grains;
crumbly to crunchy tenacity fine carbonaceous clasts and micas commonly oriented
along thinly laminated bedding; irregular to blocky fracture; nodular to blocky to equant
cuttings habit; earthy to slightly sparkling luster; gritty to silty texture with occasional
smooth ash or clay interbeds; thinly laminated overall; occasionally grading to
tuffaceous siltstone.
3315' MD 3107' TVD
~ = Olive gray to light olive gray with trace yellowish gray and light gray
secondary hues; mushy to stiff consistency; sub-sectile to slightly malleable to crumbly
tenacity; irregular to blocky fracture with occasional sub-planar partings; nodular to
equant cuttings habit; dull earthy luster with occasional slightly waxy areas where
associated with ash; smooth clayey to slightly silty texture; massive to laminated
structure; reacts with Hal where ashy; commonly grading to siltstone in part.
3390' MD
3174' TVD
(
~ EPOC:H
12
(
PHilliPS Alaska, Inc.
~
~
Cirque #3
Siltstone = Medium light gray to medium gray; traces are graded to very fine lower
sandstone with scattered very fine upper to medium lower individual sand grains;
crumbly to crunchy tenacity fine carbonaceous clasts and micas commonly oriented
along thinly laminated bedding; irregular to blocky fracture; nodular to blocky to equant
cuttings habit; earthy to slightly sparkling luster; gritty to silty texture with occasional
smooth ash or clay interbeds; thinly laminated overall; occasionally grading to
tuffaceous siltstone.
3465' MD 3240' TVD
~ = Olive gray to light olive gray with trace yellowish gray and light gray
secondary hues; mushy to stiff consistency; sub-sectile to slightly malleable to crumbly
tenacity; irregular to blocky fracture with occasional sub-planar partings; nodular to
equant cuttings habit; dull earthy luster with occasional slightly waxy areas where
associated with ash; smooth clayey to slightly silty texture; massive to laminated
structure; reacts with Hal where ashy; commonly grading to siltstone in part.
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3560' MD 3325' TVD
Ash = White to yellowish gray to pale yellowish brown; mushy to firm consistency;
dense to crumbly to occasionally brittle when not mushy; hackly to mottled fracture;
nodular to equant cuttings habit; dull earthy to slightly waxy luster; smooth texture
overall with scattered silty cuttings; thinly laminated in part; rare cuttings of siltstone or
claystone with visible ash interbeds; calcareous.
3620' MD 3378' TVD
Siltstone = Medium light gray to medium gray; traces are graded to very fine lower
sandstone with scattered very fine upper to medium lower individual sand grains;
crumbly to crunchy tenacity fine carbonaceous clasts and micas commonly oriented
along thinly laminated bedding; irregular to blocky fracture; nodular to blocky to equant
cuttings habit; earthy to slightly sparkling luster; gritty to silty texture with occasional
smooth ash or clay interbeds; thinly laminated overall; occasionally grading to
tuffaceous siltstone.
3695' MD 3444' TVD
Sand = Clear to translucent white with rare green grayish orange and black hues; very
fine to medium grain size; moderate sorting; angular to sub-angular; very low to
moderate sphericity; better rounding and sphericity in very fine grain fraction with trace
rounded high sphericity grains; scattered individual grains have frosted surface texture
sand is present as unconsolidated grains in sample; estimate 950/0 quartz 5% green
chert and assorted black lithic clasts; no sample fluorescence.
(
3765' MD 3506' TVD
Siltstone = Medium light gray to olive gray; traces are graded to very fine lower
sandstone with scattered very fine upper to medium lower individual sand grains;
crumbly to crunchy tenacity fine carbonaceous clasts and micas commonly oriented
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Cirque #3
along thinly laminated bedding; irregular to blocky fracture; nodular to blocky to equant
cuttings habit; earthy to slightly sparkling luster; gritty to silty texture with occasional
smooth ash or clay interbeds; thinly laminated overall; occasionally grading to
tuffaceous siltstone.
3840' MD 3572' TVD
Clays~one = Olive gray to light olive gray with trace yellowish gray and light gray
secondary hues; mushy to stiff consistency; sub-sectile to slightly malleable to crumbly
tenacity; irregular to blocky fracture with occasional sub-planar partings; nodular to
equant cuttings habit; dull earthy luster with occasional slightly waxy areas where
associated with ash; smooth clayey to slightly silty texture; massive to laminated
structure; reacts with Hal where ashy; commonly grading to siltstone in part.
3915' MD 3639' TVD
Siltstone = Medium light gray to olive gray; crumbly to crunchy tenacity; fine
carbonaceous clasts and micas commonly oriented along thinly laminate bedding;
irregular to blocky fracture with occasional sub-planar partings; nodular to blocky
occasionally elongate cuttings habit; dull earthy luster; silty texture with occasional
smooth ash or clay interbeds; thinly laminated overall with continued tuffaceous
siltstone cuttings.
(
3980' MD 3696' TVD
Ash = White to yellowish gray to pale yellowish brown; mushy to firm consistency;
dense to crumbly to mushy; hackly to mottled fracture; nodular to equant cuttings habit;
dull earthy to slightly waxy luster; smooth texture overall with scattered silty cuttings;
thinly laminated in part; rare cuttings of siltstone or claystone with visible ash interbeds;
calcareous.
4035' MD 3745' TVD
~ = Medium light gray to olive gray; crumbly to crunchy tenacity; fine
carbonaceous clasts and micas commonly oriented along thinly laminate bedding;
irregular to blocky fracture with occasional sub-planar partings; nodular to blocky
occasionally elongated cuttings habit; dull earthy luster; silty texture with occasional
smooth ash or clay interbeds; thinly laminated overall with continued tuffaceous
siltstone cuttings.
4100' MD 3802' TVD
Shale = Dark gray to medium dark gray; firm to moderately hard; brittle tenacity; planar
to blocky fracture; tabular to sub-wedge cuttings habit; dull to earthy luster; clayey to
slightly silty texture; thick bedding; sea shell fragments (inoc) found in assoc with shale.
(
4150' MD 3846' TVD
~ = Olive gray to light olive gray with light gray; mushy to stiff consistency;
sub-sectile to slightly malleable to crumbly tenacity; irregular to blocky with occasional
g EPOCH
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PHilliPS Alaska, Inc.
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Cirque #3
sub-planar fracture; nodular to equant cuttings habit; dull earthy luster; smooth to clayey
to slightly silty texture; massive to laminae structure; graded to siltstone in part;
moderately calcareous; large traces of inoc shell fragments; 10% pyrite in samples.
4215' MD 3904' TVD
Siltstone = Medium light gray to olive gray; crumbly to crunchy tenacity; fine
carbonaceous clasts and micas commonly oriented along thinly laminate bedding;
irregular to blocky fracture with occasional sub-planar partings; nodular to blocky
occasionally elongated cuttings habit; dull earthy luster; silty texture with occasional
smooth ash or clay interbeds; thinly laminated overall with continued tuffaceous
siltstone cuttings.
4280' MD 3961' TVD
~ = Olive gray to light olive gray with light gray; mushy to stiff consistency;
sub-sectile to slightly malleable to crumbly tenacity; irregular to blocky with occasional
sub-planar fracture; nodular to equant cuttings habit; dull earthy luster; smooth to clayey
to slightly silty texture; massive to laminae structure; graded to siltstone in part;
moderately calcareous.
(
4340' MD 4014' rVD
Siltstone = Medium light gray to olive gray; crumbly to crunchy tenacity; fine
carbonaceous layers thinly laminated; irregular to blocky fracture with occasional sub-
planar separations; nodular to blocky occasionally elongated cuttings habit; dull earthy
luster; silty texture; thinly laminated overall with continued tuffaceous siltstone cuttings.
4415' MD 4081' TVD
~ = Olive gray to light olive gray with light gray; mushy to stiff consistency;
sub-malleable tenacity; irregular fracture; nodular to equant cuttings habit; dull earthy
luster; smooth to clayey to slightly silty texture; massive to laminae structure; graded to
siltstone in part; moderately calcareous.
4465' MD 4125' TVD
Ash fall tuff = Light gray to white; very soft; mushy to crumbly; irregular to occasionally
sub-blocky cuttings habit; earthy to chalky luster; slightly gritty texture; slightly to very
calcareous; scattered to common very fine to fine sand rarely grades to very ashy
sandstone; moderately bright light yellow mineral fluorescence; no visible oil indicators.
4520' MD
Siltstone = Medium brownish gray; soft to occasionally moderately firm; sub-blocky
cuttings; earthy luster with common microsparkles; gritty grainy texture; non to slightly
calcareous; locally common very fine to fine sand grains; common black streaks and
specks; scattered thin laminations of ash fall tuff and claystone.
(
4570' MD
4218' rVD
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Cirque #3
Claystone = Light gray to olive gray; very soft to soft; mushy to crumbly; irregular and
sub-blocky cuttings with rounded edges; matte earthy luster; moderately gritty texture;
locally very ashy; scattered to common ashy laminations and blebs; occasionally silty
grading in part to siltstone.
4615' MD 4257' TVD
Shale = Medium to dark brownish gray; soft to slightly firm; crumbly to rarely
moderately tough; small sub-blocky cuttings with rounded edges; dull luster; smooth to
slightly grainy texture; non to occasionally slightly calcareous; locally common fine
laminations of ashy material.
4660' MD 4297' TVD
Ash fall tuff = Very light gray to white; soft; crumbly; amorphous cuttings; chalky to
waxy luster; smooth to gritty texture; locally moderately calcareous; common glass
shards; appears to be thinly interbedded with claystones.
(
4700' MD 4332' TVD
Sand = Light gray overall; dominantly clear and frosted scattered medium to dark gray
rare reddish orange; clasts range from very fine lower to medium lower; dominantly very
fine to fine range; angular to rounded dominantly sub-angular to subround; moderately
sorted in the fine range; composed of quartz with minor igneous lithics; trace clusters of
microcrystalline pyrite; 10 to 70% dull to moderately bright light yellow sample
fluorescence; instant dull to moderately bright light yellow translucent cut fluorescence.
4775' MD 4399' TVD
Clawone = Olive gray to medium brownish gray; very soft to soft; mushy to crumbly;
irregular and sub-blocky cuttings; matte luster; moderately gritty texture; non to rarely
slightly calcareous; scattered to common ashy laminations and blebs; locally silty
grading in part to argillaceous siltstone.
4825' MD 4443' TVD
Shale = Medium to dark brownish gray; soft to slightly firm; crumbly to rarely
moderately tough; tabular to sub-blocky cuttings; matte earthy luster; smooth to slightly
grainy texture; non to occasionally slightly calcareous; locally common fine laminations
of ashy material.
4870' MD 4483' TVD
Sand = Dominantly clear white light to medium gray rarely reddish orange; clasts range
from very fine lower to medium lower; angular to rounded dominantly sub-angular to
subround; moderately sorted in the fine range; composed of 800/0 quartz 20% igneous
minerals trace clusters of microcrystalline pyrite; disaggregated in samples; clay matrix
is inferred.
(
4925' MD
4532' rVD
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Ç!@,Yston~/tuffaceo8:!!> clayst2!!! = Light gray to olive gray; very soft to soft; mushy;
amorphous to occasionally sub-blocky; matte earthy luster; slightly gritty; variable ash
content; scattered to common volcanic glass shards; scattered to common black
pinpoint inclusions; common ashy laminations and blebs; also appears clean with
minimal ash content.
4980' MD 4580' TVD
Ash fall tuff = Light gray to white; soft to rarely moderately firm; crumbly to occasionally
slightly brittle; matte chalky and waxy luster; slightly gritty texture; amorphous to platy to
sub-blocky; dominantly non calcareous occasionally gives vigorous acid reaction;
common streaks and laminations of claystone.
5030' MD 4625' TVD
Cia stone/tuffaceous cia stone = Light gray to olive gray; very soft to soft; mushy;
sub-blocky to irregular fracture; matte to earthy luster; slightly gritty; variable ash
content; traces to scattered volcanic glass shards; scattered to common black
carbonaceous inclusions; common ashy laminae; moderate true claystone laminated
with slight ashy stringers.
(
5085' MD 4674' TVD
Tuffaceous cia stone = Light gray to medium light gray; very soft to soft; mushy; sub-
blocky to irregular fracture; nodular to equant cuttings habit; matte to earthy luster;
slightly gritty to silty in part; scattered to common black carbonaceous inclusions; ash
laminae; thick bedding with thinly interbedded ash and silt stringers.
5140' MD 4723' TVD
Siltstone = Medium brownish gray; soft to occasionally moderately firm; sub-blocky
cuttings; earthy to micro- sparkling luster; gritty to silty texture; non to slightly
calcareous; ashy clay matrix to clay matrix; locally common very fine to fine sand
grains; common black streaks and specks; scattered thin laminations of ash fall tuff and
claystone; locally graded to sandstone; no hydrocarbon indicators.
5200' MD 4777' TVD
Tuffaceous cia stone = Light gray to medium light gray; very soft to soft; mushy; sub-
blocky to irregular fracture; nodular to equant cuttings habit; matte to earthy luster;
slightly gritty to silty in part; scattered to common black carbonaceous inclusions; thick
bedding with thinly interbedded ash and siltstones.
(
5250' MD 4821' TVD
Siltstone = Medium brownish gray; soft to occasionally moderately firm; sub-blocky
cuttings; earthy luster with common microsparkles; gritty grainy texture; non to slightly
calcareous; locally common very fine to fine sand grains; common black streaks and
specks; scattered thin laminations of ash fall tuff and claystone.
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5300' MD 4866' TVD
Cia stone/tuffaceous cia stone = Light gray to olive gray; very soft to soft; mushy;
sub-blocky to irregular fracture; matte to earthy luster; slightly gritty; variable ash
content; traces to scattered volcanic glass shards; scattered to common black
carbonaceous inclusions; common ashy laminae; moderate true claystone laminated
with slight ashy stringers.
5355' MD 4915' TVD
Tuffaceous siltstone = Very light gray to light gray; grains range from silt to very fine
lower; clasts are firm and brittle; ashy and calcareous clay matrix material; mottled
fracture; nodular to equant and uneven cuttings habit; black pinpoint carbonaceous
material and micaceous inclusions; dull to earthy luster and traces of sparkling luster;
silty to gritty texture; thinly inter- bedded with clay and tuffaceous claystone; no visible
hydrocarbon indicators.
5425' MD 4977' TVD
~ = Light gray to light olive gray to olive gray; very soft to soft; mushy; sub..
blocky to irregular fracture; matte to earthy luster; slightly gritty; variable ash content;
scattered to common black carbonaceous inclusions; common ashy laminae.
(
5470' MD 5017' TVD
Ash fall tuff = Light gray to white; soft to rarely moderately firm; crumbly to occasionally
slightly brittle; matte chalky and waxy luster; slightly gritty texture; amorphous to platy to
sub-blocky; dominantly non calcareous occasionally gives vigorous acid reaction;
common streaks and laminations of claystone.
5520' MD 5062' rVD
Sandstone = Very light gray to yellowish gray to light gray; predominantly quartz
composed with pinpoint black carbonaceous inclusions; very calcareous ashy matrix;
brittle tenacity; hard to moderately hard clasts; irregular fracture; nodular to equant
cuttings habit; dull to sparkling luster; gritty to granular and occasionally sucrosic
texture; thin bedding; no hydrocarbon indicators.
5575' MD 5111' rVD
~ = Light gray to light olive gray to olive gray; very soft to soft; mushy to pasty;
sub-blocky to irregular fracture; matte to dull luster; slightly to very gritty; variable ash
content; scattered to black carbonaceous inclusions; common ash laminae; very
calcareous associated with the ash.
5620' MD 5151' rVD
Cia stone/tuffaceous cia stone = Light gray to olive gray; very soft to soft; mushy;
sub-blocky to irregular fracture; matte to earthy luster; slightly gritty; variable ash
content; traces to scattered volcanic glass shards; scattered to common black
(
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Cirque #3
carbonaceous inclusions; common ashy laminae; moderate true claystone laminated
with slight ashy stringers.
5675' MD 5194' TVD
Clayston..! = Light gray to light olive gray to olive gray; very soft to soft; mushy to pasty;
sub-blocky to irregular fracture; matte to dull luster; slightly to very gritty; variable ash
content; scattered to black carbonaceous inclusions; common ash laminae; very
calcareous associated with the ash.
5720' MD 5234' TVD
Ash fall tuff = White light gray occasionally pale yellowish brown; very soft to soft rarely
firm; 2 to 4 millimeter cuttings with irregular tabular and sub-blocky habit; matte chalky
occasionally waxy luster; smooth to moderately gritty texture; mostly non calcareous
occasionally vigorous acid reaction; apparently thinly interbedded with surrounding
claystones.
(
5780' MD 5293' TVD
Siltstone = Olive gray light gray medium brownish gray; soft to moderately firm;
crumbly to occasionally brittle; matte luster with common sparkles; small irregular and
sub-blocky cuttings; variable ash content from minor to extremely ashy; locally common
very fine to fine sand grains; common black pinpoint specks; interbedded with and
grading to claystone in part.
5835' MD 5342' TVD
Tuffaceous cia tone = Olive gray light to medium gray; very soft to soft rarely slightly
firm; mushy to crumbly; irregular blocky and tabular cuttings; matte earthy luster;
smooth to commonly gritty texture; locally moderately calcareous; ashy appearance;
scattered to common glass shards; interbedded with and grading to tuffaceous siltstone
in part.
5925' MD 5421' TVD
Shale = Medium dark gray to medium gray; firm to moderately hard; brittle tenacity;
blocky to sub-planar fracture; blocky to sub-wedgelike cuttings habit; earthy to matte
luster; clayey to silty texture; thick to thin bedding.
(
5960' MD 5452' TVD
Sandstone/siltstone = Light gray medium brownish gray; moderately firm; crumbly to
occasionally brittle; matte luster with common carbon inclusions; small irregular and
sub-blocky cuttings; variable ash content from minor to extremely ashy; locally very fine
to fine sand grains; common black pinpoint specks; interbedded with and grading to
sandstone in part.
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6015' MD 5501' TVD
Clays~one = Light gray to light olive gray to olive gray; very soft to soft; mushy to pasty;
sub-blocky to irregular fracture; matte to dull luster; slightly to very gritty; variable ash
content; scattered to black carbonaceous Inclusions; common ash laminae; moderately
calcareous associated with the ash.
6060' MD 5540' TVD
Cla'lstone = Olive gray brownish gray; very soft to firm; crumbly to rarely slightly tough;
sub-blocky cuttings; matte luster; smooth to slightly gritty texture; locally silty; ashy in
part.
6090' MD 5567' TVD
Sand/sandstone = Light gray overall; friable when consolidated; very fine lower to
coarse lower; angular to rounded dominantly sub-angular to subround; moderately
sorted in the fine to medium range; quartz rich minor lithics; ashy clay matrix; variable
matrix/grain support; moderately cemented with calcite; up to 800/0 moderately bright
light yellow sample fluorescence; instant pale yellow translucent cut fluorescence.
(
6150' MD 5621' TVD
Sand/sandstone = Light gray to very light gray overall; friable to slightly hard clasts;
very fine lower to lower coarse; subround to angular to round; moderately sorted;
predominantly quartz composition with associated lithics; calcareous ashy matrix; matrix
variable to grain supported locally; 60-700/0 bright light yellow sample fluorescence;
flash and streaming bright pale yellow cut; dull yellow ring residue,
6195' MD 5661' TVD
Tuffaceous cia stone = Light gray to very light gray; very soft to soft; mushy; earthy to
irregular fracture; matte to earthy luster; slightly gritty; high ash content; traces to
scattered volcanic glass shards; scattered to common black carbonaceous inclusions;
common ash fall tuff laminae.
6265' MD 5723' TVD
Ash fall tuff = White light gray occasionally pale yellowish brown; very soft to soft rarely
firm; 2 to 4 millimeter cuttings with irregular tabular and sub-blocky habit; matte chalky
occasionally waxy luster; smooth to moderately gritty texture; mostly non calcareous
occasionally with vigorous acid reaction; apparently thinly interbedded with surrounding
claystones.
6325' MD 5777' TVD
Sandstone = Light gray to medium light gray; friable to hard clasts; very fine lower to
medium grain; sub-round to angular to round; moderately sorted; 80% quartz 20%
lithics and carbonaceous material; predominately clay matrix some siliceous sand grain
supported; moderately calcareous; mineral fluorescence; no hydrocarbon indicators.
(
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6375' MD 5822' TVD
Shale = medium gray to medium dark gray; moderately hard; brittle; blocky to platy
fracture; blocky cuttings habit; dull to earthy luster; smooth to clayey texture; thick
bedding; non-calcareous.
6405' MD 5847' TVD
~ = Brownish gray to medium dark gray; soft to slightly firm; mushy
consistency; sectile tenacity; no fracture; nodular to equant cuttings habit; dull to earthy
luster; clayey to silty and occasional gritty texture; thinly bedded; non to slightly
calcareous.
6445' MD 5883' TVD
Siltstone = Brownish gray to medium gray to medium dark gray; firm to friable; silt to
very fine lower grains and; common pinpoint carbon inclusions; crumbly tenacity; earthy
fracture; nodular to equant cuttings habit; dull to slightly sparkling luster; silty to granular
texture; thinly bedded; slightly calcareous.
(
6495' MD 5927' TVD
Tuff = Light gray; hard; brittle; sharp angular fracture; matte to slightly resinous luster;
smooth to slightly gritty texture; slightly calcareous; appears to be silicified ash with thin
laminations of quartz; common black pinpoint inclusions; apparently at slowest rop
intervals.
6540' MD 5967' TVD
Tuffaceous cia ato e = Light to medium brownish gray; soft to rare moderately firm;
small irregular and sub-blocky cuttings; matte earthy luster with scattered sparkles;
moderately gritty texture; ashy appearance; common volcanic glass shards; common
black pinpoint inclusions.
6585' MD 6007' TVD
Coal = black to dusky brownish black; firm; brittle; 2 to 3 mm blocky cuttings; slightly
resinous luster; smooth surface texture; thinly interlaminated with ash and claystone.
6615'MD 6034' TVD
Sandstone = Light gray overall with slight salt and pepper appearance; friable to firm;
clasts range from very fine lower to medium lower; angular to rounded dominantly
subangular to subround; moderately sorted in the fine range; 80% quartz 20% lithics;
ashy clay matrix; light calcite cement; variable matrix/grain supported; silty in part; trace
faint pale yellow cut from a few crushed cuttings.
6615'MD
End Of Well
6034' TVD
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RIG ACTIVITIES
1/18/02
Pre-spud meeting pick up 5" drill pipe (48 joints) and HWDP (29 joints) to derrick pick
up 4" drill pipe and 3.5" HWDP to derrick pick up BHA (stabilizer crossover's and bit) to
floor pick up motor and bit make up stabilizer L WD MWD float sub scride motor load
and test MWD suspended operations at 1800 hrs due to Phase 3 weather conditions.
1/19/02
Continue suspended operations due to Phase 3 weather conditions at 1000 hrs resume
operations initialize MWD drill from 108' to 1210' encounter gas hydrates at 1130' to
1210' maximum gas = 1800 units.
f
"
1/20/02
Drill from 1210' to 1832'MD (1786 TVD) circulate two bottom's up monitor well blow
down top drive short trip to 820' [note: pulled to 1643' pumped out 1643' to 1460' lost
returns @ 1460' due to packoff (unrestricted movement up down and around)
continued pumping out of hole until circulation was reestablished at 950' 50 Bbls lost to
formation] circulate and condition hole at 820' until clean run in hole to 1739' circulate
and condition wash and ream to bottom at 1832' drill from 1832' to 2422' circulate up
formation sample pump high viscosity sweep circulate two bottom's up pump high
viscosity sweep circulate until clean monitor well blow down Kelly.
1/21/02
Trip out to 1750' tight (50k over) and swabbing in spots pump sweep circulate until
clean maximum gas on circulation 820 units at lag depth of 1100' pump out to 1550' at
550 gpm 60 rpm circulate until clean (heavy returns on bottoms up) pump out to 1092
at 550 gpm 60 rpm trip out of hole BHA - stand back NMDC break bit drain motor read
MWD lay down MWD stabilizer mud motor pick up and make up hole opener near bit
stabilizer run in hole with one stand NMDC service top drive trip in hole to 2372' wash
and ream to 2422' pump bottom's up pump high viscosity sweep pump bottom's up
pump high viscosity sweep pump bottom's up circulate until clean observe well pump
dry job blow down top drive pull out of hole BHA - stand back 10 stands HWDP lay
down crossover 3 NMDC's float sub and hole opener clear floor rig up to run casing run
casing to 1100' circulate bottom's up.
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1/22/02
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Continue running 9-5/8" casing to 2412' circulate and condition mud at 2412' test
cement lines to 3500 psi cement as per cement program chase with 1648 strokes rig
pump cement in place at 1600 hrs rig down cement head lay down landing joint clear
floor of casing equipment nipple down diverter system flush hydril orient and nipple up
casing head-tubing spool and test same at 1000 psi for 10 minutes nipple up BOPE
change out bells grabbers and saver sub on top drive.
1/23/02
Test BOP make up new bit and BHA #3 trip in hole to 2180' slip and cut drilling line trip
in hole to 2379' circulate bottoms up test casing to 2500 psi for 30 minutes drill float
equipment and cement and 20' new formation to 2442' FIT test to 16.0 ppg EMW
establish PWD baseline drill ahead.
1/24/02
Drill ahead from 2442' to 4427'
1/25/02
Finished Short Trip drilled from 4487' to 5711' at report time.
(
1/26/02
Drilled from 5711' to 5928' Pulled out of hole to lay down mud motor tripped in to hole
and began control drilling while searching for the top of the Bermuda sand to begin
coring run drilled to 6096' at report time.
1/27/02
Trip in hole drill to core point at 6123' . Encountered sever seepage loss. Build 200
bbls of new mud. Lower mud weight to 10.00 ppg. Pull out of hole.
1/28/02
Trip in hole with core barrel core from 6123' to 6215'. Encountered severe seepage
loss at last of fottage. T atal of approximately 100 bbls loss. Pull 3 stands open PBL
sub. Spot LCM pill and pull out of hole. Laid down core barrel. Picked up drill assembly
and tripped in hole. Drill ahead
1/29/02
Drill from 6215' to 6677' TO.
(,
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MUD RECORD
.
r:m Phillips
Cirque #3 DAILY MUD REPORTS
DATE DEPTH WEIGHT VIS PV YP GELS FILTRATE CAKE SOLIDS SAND pH Pm Pf/Mf CI Ca
1/18/02 110 8.35 26 0 0 0/0/0 0.0
1/19/02 110 10.00 77 19 40 13/15/15 6.0 2.0/0.0 5.6 0.00 8.80 0.30 0.20/0.80 30000 120
1/20/02 365 10.00 93 22 50 18/21/22 4.0 2.0/0.0 6.6 2.50 8.80 0.20 0.20/0.80 30000 160
1/20/02 1210 10.00 82 21 47 17/22/23 3.8 2.0/0.0 7.0 4.50 8.90 0.25 0.25/1.10 26000 280
1/21/02 1832 10.00 100 21 48 18/23/23 4.0 2.010.0 7.5 4.50 9.20 0.35 0.25/1.30 26000 320
1/21/02 2422 10.00 57 17 33 11/20/24 4.2 2.0/0.0 7.5 3.00 8.70 0.20 0.20/1.40 26.000 280
1/21/02 2422 10.10 71 20 35 12/19/21 5.4 2.010.0 8.5 0.30 8.50 0.10 0.10/0.60 26000 400
1/22/02 2422 10.00 47 11 21 7/12/14 5.6 2.0/0.0 8.1 2.50 8.40 0.00 0.10/1.05 18000 248
1/23/02 2422 10.20 47 11 21 6/13/16 5.0 2.0/0.0 8.5 1.50 9.60 0.25 0.30/1.35 32000 240
1/23/02 2854 10.25 43 12 18 4/13/16 5.3 2.0/0.0 8.5 1.50 9.00 0.25 0.25/1.45 32000 220
1/24/02 3557 10.20 47 14 25 5/14/19 5.6 2.0/0.0 9.5 1.50 9.10 0.35 0.35/1.40 32500 160
1/24/02 4427 10.20 48 16 24 5/14/20 5.4 2.0/0.0 9.6 1.00 9.40 0.50 0.30/1.30 30500 180
1/25/02 5150 10.20 48 11 21 7/15/19 5.2 2.0/0.0 9.6 0.75 9.00 0.40 0.30/1.30 31000 240
1/26/02 5421 10.20 50 16 28 7/11/16 5.0 2.0/0.0 11.7 0.75 9.00 0.40 0.30/1.30 31000 240
1/26/02 5921 10.20 50 16 27 6/11/16 5.0 2.0/0.0 11.7 0.75 9.00 0.45 0.30/1.40 31000 220
1/27/02 6123 10.00 48 17 22 6/12/16 5.5 2.0/0.0 10.1 0.75 8.80 0.40 0.30/1.40 32000 200
1/28/02 6215 9.70 46 14 25 5/12/17 4.5 2.0/0.0 7.7 0.50 9.30 0.30 0.20/1.20 30000 0
1/29/02 6677 9.70 46 14 25 5/12/17 4.5 2.0/0.0 7.7 0.50 9.30 0.30 0.20/1.20 30000 0
~ EPOCH
24
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PHilliPS Alaska, Inc.
~
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Cirque #3
SURVEY RECORD
Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dog Leg
feet deqrees degrees feet feet feet feet degrees/100 feet
108.00 - - 108.00 0.00 N 0.00 E - TIE-IN
198.07 0.16 76.47 198.07 0.03 N 0.12 E -0.02 0.18
284.85 0.36 110.70 284.85 0.048 0.50 E -0.22 0.28
381 .03 0.56 103.00 381.03 0.258 1.25E -0.69 0.22
472.08 0.52 74.90 472.07 0.258 2.09E -0.98 0.29
564.41 1.97 341.86 564.38 1.37 N 2.00 E 0.56 2.24
654.67 3.86 339.28 654.52 5.69 N 0.44 E 5.14 2.09
745.29 5.38 337.17 744.84 12.46 N 2.28W 12.44 1.69
835.75 7.03 330.58 834.77 21.19 N 6.65W 22.16 1.98
926.43 8.58 331.58 924.61 31.97 N 12.59 W 34.36 1.72
1110.05 12.56 336.44 1105.03 62.54 N 27.33 W 68.19 2.05
1202.63 13.92 339.27 1195.15 82.18 N 35.30 W 89.38 1.62
1296.01 15.61 340.18 1285.44 104.50 N 43.53 W 113.17 1.83
1388.70 17.16 339.78 1374.36 129.07 N 52.49 W 139.31 1.67
1482.05 18.47 338.89 1463.24 155.78 N 62.57 W 167.87 1.43
1574.54 20.33 339.56 1550.47 184.50 N 73.46 W 198.58 2.02
1667.53 22.57 340.57 1637.02 216.47 N 85.04 W 232.58 2.45
1759.89 25.14 338.80 1721.48 251.49 N 98.03 W 269.92 2.89
1852.66 27.69 339.73 1804.55 290.09 N 112.63 W 311.19 2.78
1944.87 27.83 339.63 1886.15 330.36 N 127.54 W 354.13 0.15
2038.02 27.40 338.52 1968.69 370.69 N 142.96 W 397.30 0.72
2128.85 27.11 339.14 2049.44 409.47 N 157.99 W 438.89 0.45
2224.43 26.83 338.02 2134.63 449.82 N 173.81 W 482.24 0.61
2316.88 27.64 338.66 2216.83 489.14 N 189.43 W 524.54 0.93
2347.97 27.52 337.81 2244.39 502.51 N 194.77 W 538.93 1.31
Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dog Leg
~ EPOCH
25
.'-
. '-..-/
,~
feet dearees degrees feet feet feet feet degreesl100 feet
2422.00 27.52 337.81 2310.04 534.18 N 207.68 W 573.13 -
2347.97 27.52 337.81 2244.39 502.51 N 194.77W 538.93 1.31
2494.28 27.28 337.14 2374.29 564.70 N 220.55 W 606.24 0.27
2590.70 26.43 337.31 2460.31 604.86 N 237.41 W 649.78 0.88
2687.13 26.18 339.55 2546.75 644.59 N 253.12W 692.50 1.06
2782.89 25.58 339.79 2632.91 683.79 N 267.64 W 734.30 0.63
2879.24 26.65 338.94 2719.42 723.47 N 282.60 W 776.70 1.17
2975.20 26.11 339.10 2805.39 763.28 N 297.86 W 819.34 0.56
3071.09 27.40 339.19 2891.01 803.63 N 313.23 W 862.52 1.35
3167.62 26.87 339.63 2976.91 844.84 N 328.72 W 906.54 0.59
3262.60 27.83 338.50 3061.27 885.60 N 344.32 W 950. 18 1.16
3358.29 26.93 338.16 3146.24 926.50 N 360.57 W 994.18 0.96
3454.45 28.02 338.30 3231.56 967.69 N 377.02 W 1038.54 1.13
3550.71 27.37 337.09 3316.79 1009.08 N 393.99 W 1083.27 0.89
3646.50 28.09 339.21 3401.58 1050.45 N 410.57W 1127.83 1.27
3741.95 27.43 338.75 3486.04 1091.95 N 426.51 W 1172.29 0.72
3838.56 27.84 339.59 3571.63 1133.83 N 442.45 W 1217.09 0.58
3934.27 27.48 340.96 3656.41 1175.65 N 457.45 W 1261.51 0.76
4030.83 28.44 341.48 3741.69 1218.51 N 472.02 W 1306.74 1.03
4126.42 27.73 342.05 3826.03 1261.25 N 486.10 W 1351.68 0.79
4222.84 28.39 340.06 3911.11 1304.15 N 500.83 W 1397.00 1.19
4318.99 27.82 339.93 3995.92 1346.71 N 516.33 W 1442.29 0.60
4413.55 27.04 339.16 4079.85 1387.53 N 531.55 W 1485.85 0.91
4511.30 28.31 340.01 4166.42 1430.07 N 547.38 W 1531.24 1.36
4607.22 28.00 341.22 4250.99 1472.76 N 562.41 W 1576.47 0.68
4703.20 28.03 339.19 4335.73 1515.17N 577.67 W 1621.53 0.99
4799.52 27.31 339.21 4421.03 1556.98 N 593.55 W 1666.26 0.75
4895.56 27.87 338.11 4506.15 1598.41 N 609.74 W 1710.74 0.79
PHilliPS Alaska, Inc.
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Cirque #3
~ EPOCH
26
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4992.38 27.31 338.40 4591.96 1640.06 N 626.36 W 1755.58 0.60
5083.28 26.57 338.73 4673.00 1678.39 N 641.41 W 1796.76 0.83
5183.71 27.25 336.88 4762.55 1720.47 N 658.59 W 1842.20 1.07
5278.88 26.81 336.46 4847.33 1760.19 N 675.72 W 1885.42 0.51
5376.07 26.50 338.97 4934.19 1800.52 N 692.26 W 1929.01 1.20
5471.60 27.51 339.15 5019.30 1841.03 N 707.76 W 1972.38 1.06
5568.38 26.88 338.90 5105.38 1882.33 N 723.59 W 2016.61 0.66
5663.73 27.55 338.94 5190.18 1923.02 N 739.27 W 2060.22 0.70
5760.02 28.30 337.61 5275.25 1964.91 N 755.96 W 2105.31 1.02
5855.45 27.55 337.43 5359.57 2006.21 N 773.05 W 2149.99 0.79
5932.46 27.20 338.68 5427.96 2039.05 N 786.29 W 2185.40 0.88
6029.28 27.23 338.27 5514.05 2080.25 N 802.54 W 2229.68 0.20
6083.51 27.19 339.87 5562.28 2103.41 N 811.39 W 2254.48 1.36
6219.95 27.06 338.93 5683.72 2161.64 N 833.28 W 2316.68 0.33
6316.59 26.43 339.12 5770.02 2202.24 N 848.85 W 2360.17 0.66
6413.34 25.66 339.27 5856.93 2241.80 N 864.41 W 2402.68 0.80
6508.83 25.22 339.85 5943.16 2280.23 N 878.73 W 2443.69 0.53
6602.19 24.57 339.61 6027.85 2317.10 N 892.34 W 2482.98 0.70
6677.00 24.57 339.61 6095.89 2346.25 N 903.18 W 2514.08 0.00
PHILLIPS Alaska, Inc.
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CirQue #3
~ EPOCH
27
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PHilliPS Alaska, Inc.
~
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Cirque #3
BIT RECORD
U EPOCH
BIT GRADING
Z 0 c ~ ~
c: ï m
z -t c: 0 m G) ::I:
m m ï £ » » ~ -<
:U :::a ï :u c: "'tJ
:::a :::a 0 Z G) ~ c:
~ ::I: 0 ï
~ » G) m ï
:::a z en m
JETS TOTAL AVG :ú c
BIT SERIAL SIZE (in 32nds) DEPTH DEPTH FEET BIT AVG AVG AVG PUM
P
NUMBER NUMBER INCHES MAKE TYPE 1 234 IN POOH DRILLE HOURS FT/HR WOB RP PSI
D M
1 X39DB 12 Vi' HC MXC1 14 20 20 20 108' 2422' 2314' 18.5 125.31 9.2 70 1153 CASING
2 750017 12 V4" STC Hole 24 24 24 24 2422' 2422' 2314' Drill
Opener - - - - -
3 JS062 8 %" STC S88HPX 8 x 12 2422' 5928' 3506' 45.8 76.55 5.3 85 2611 Mudmotor
4 7F68JE 8 %" HC MXC1 12 15 15 f15 5928' 6123' 195' 6.2 31.45 7.1 165 1800 Core Point
5 7100484 8 %" HC ARC425C3 - - - - 6123' 6215' 92' 2.5 36.8 5.2 60 1200 Cores
3R1 JS062 8 %" STC S88HPX 8 x 12 6215' 6677' 462' 7 66 8.2 105 2400 TD
U EPOCH
28
-.."..-'
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Depth
1
0
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
5500
6000
6500
7000
"-'
2
3
4
5
PHILLIPS Alaska, Inc.
~
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Cirque #3
DAYS VS. DEPTH
6
9
14
10
12
13
7
8
11
U EPOCH
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15
I
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I
j 1-..- Depth I
i
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6a77
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Phillips Alaska
North Slope DAILY WELLSITE REPORT [~ EPOCH
Cirque #3
REPORT FOR Rick Levinson
DATE Jan 20, 2002 DEPTH 1600 PRESENT OPERATION= Drilling Ahead
TIME 05:00:00 YESTERDAY 1
24 Hour Footage 1599
CASING INFORMATION
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
SURVEY DATA
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 722.7 @ 818 18.9 @ 179 143,7 152.0 ftlhr
SURFACE TORQUE 2971 @ 869 0 @ 1115 293.8 164.7 amps
WEIGHT ON BIT 44 @ 1185 0 @ 1559 7.8 0.0 Klbs
ROTARY RPM 100 @ 1122 1 @ 1557 59.7 99 RPM
PUMP PRESSURE 1373 @ 1019 -45 @ 730 971.6 1175 psi
DRILLING MUD REPORT DEPTH:
MW VIS PV YP FL Gels CL-
FC SOL SO OIL MBL pH Ca+ CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY(unlts) HIGH LOW AVERAGE
DITCH GAS 1744 @ 1212 0 @ 794 57.5 TRIP GAS= N/A
CUTTING GAS 0 @ 1600 0 @ 1600 0.0 WIPER GAS= N/A
CHROMA TOGRAPHY(ppm) SURVEY= N/A
METHANE(C-1) 348820 @ 1212 -1 @ 914 11441.6 CONNECTION GAS HIGH= au
ETHANE(C-2) 0 @ 1600 -1 @ 914 -0.5 AVG= au
PROPANE(C-3) 0 @ 1600 -1 @ 914 -0.5 CURRENT au
BUTANE(C-4) 0 @ 1600 -2 @ 914 -1.0 CURRENT BACKGROUND/AVG 2,5u
PENTANE(C-5) 0 @ 1600 -2 @ 914 -1.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY IREMARKS GAS DESCRIPTION
LITHOLOGY Siltstone, Claystone, Sand
PRESENT LITHOLOGY 30% Sand, 10% Seashell Frag, 20% Siltstone, 40% Claystone
DAILY ACTIVITY SUMMARY Spudded well and drilled to 1729' @ report time (05:00)
Epoch Personal On Board= 4 Daily Cost $2,420.00
Report by: Brady Kilmer
Phillips Alaska
North Slope
I fXl EPOCH LOGO
]
DAILY WELLSITE REPORT
(
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Cirque #3
REPORT FOR Rick Levinson
DATE Jan 21, 2002
TIME 05:00:00
DEPTH 2422
YESTERDAY 1601
24 Hour Footage 821
CASING INFORMATION
DEPTH
INCLINATION
SURVEY DATA
BIT INFORMATION
NO. SIZE TYPE
JETS
INTERVAL
IN OUT
SIN
(
DRILLING PARAMETERS
RATE OF PENETRATION
SURFACE TORQUE
WEIGHT ON BIT
ROTARY RPM
PUMP PRESSURE
DRILLING MUD REPORT
MW 10.00 VIS 82 PV
FC 2.0/0.0 SOL 7.0 SD
2117
2388
2325
2119
2215
HIGH
396.2 @
381 @
25 @
103 @
1537 @
FOOTAGE
LOW
4.9 @ 1964
0 @ 2315
0 @ 1833
2 @ 1745
-18 @ 1834
DEPTH:
21 YP 47 API 3.8 Gels
4.5 OIL 1.0 MBL 3.0 pH
HIGH LOW
74 @ 2252 0 @ 2364
0 @ 2422 0 @ 2422
CHROMA TOGRAPHY(ppm)
13630 @ 2390 200 @ 2364 4277.8
0 @ 2422 0 @ 2422 0.0
0 @ 2422 0 @ 2422 0.0
0 @ 2422 0 @ 2422 0.0
0 @ 2422 0 @ 2422 0.0
MWD SUMMARY
INTERVAL
TO
TOOLS
GAS SUMMARY(units)
DITCH GAS
CUTTING GAS
METHANE(C-1)
ETHANE(C-2)
PROPANE(C-3)
BUTANE(C-4)
PENT ANE(C-5)
HYDROCARBON SHOWS
INTERVAL
AVERAGE
30.3
0.0
LlTHOLOGY/REMARKS
(
LITHOLOGY
PRESENT LITHOLOGY 30% Sand, 10% Siltstone, 60% Claystone
DAILY ACTIVITY SUMMARY Drilled from 1600' to 2422' (Casing Point)
Epoch Personel On Board= 4 Daily Cost $ 2,540.00
Report by: Brady Kilmer
PRESENT OPERATION= Tripping for Casing
AZIMUTH
VERTICAL DEPTH
HOURS
CONDITION
T/B/C
REASON
PULLED
AVERAGE
148.9
178.6
10.4
81.1
1256.9
CURRENT AVG
153.7
256.4
11.8
100
1368
psi
ftIhr
amps
Klbs
RPM
17/22/23
8.90
CL-
Ca+
26,000
280
ALK MUD
.25
TRIP GAS= n/a
WIPER GAS= 100u @ 1833'
SURVEY= n/a
CONNECTION GAS HIGH= Ou
AVG= Ou
CURRENT Ou
CURRENT BACKGROUNDIAVG 20u
GAS
DESCRIPTION
("
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Phillips Alaska
North Slope DAILY WELLSITE REPORT ~ EPOCH
Cirque #3
REPORT FOR Rick Levinson
DATE Jan 22, 2002 DEPTH 2422 PRESENT OPERATION= Circulating after running casing
TIME 05:00:00 YESTERDAY 2422
24 Hour Footage 0
CASING INFORMATION 95/8" @ 2412'
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
SURVEY DATA 2347.97' 27.52 337.81 2244.39'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED
1 121/4" MXC1 X39DB 1x14/3x20 105' 2422' 2317' 18,49 casing
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 153,7 @ 2422 153.7 @ 2422 - 153.7 ftIh r
SURFACE TORQUE 256 @ 2422 256 @ 2422 - 256.4 amps
WEIGHT ON BIT 11 @ 2422 11 @ 2422 - 11.8 Klbs
ROTARY RPM 100 @ 2422 100 @ 2422 - 100 RPM
PUMP PRESSURE 1368 @ 2422 1368 @ 2422 - 1368 psi
DRILLING MUD REPORT DEPTH: 2422'
MW 10.00 VIS 57 PV 17 YP 33 FL Gels 11/20/24 CL- 26,000
FC 2.010.0 SOL 7.5 SD 3.00 OIL MBL 6.0 pH 8.70 Ca+ 280 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY(units) HIGH LOW AVERAGE
DITCH GAS 48 @ 2422 48 @ 2422 - TRIP GAS= 970u @ 2422'
CUTTING GAS 0 @ 2422 0 @ 2422 - WIPER GAS= 840u @ 2422'
CHROMA TOGRAPHY(ppm) SURVEY= nla
METHANE(C-1) 9760 @ 2422 9760 @ 2422 - CONNECTION GAS HIGH= nla
ETHANE(C-2) 0 @ 2422 0 @ 2422 - AVG= nla
PROPANE(C-3) 0 @ 2422 0 @ 2422 - CURRENT nla
BUTANE(C-4) 0 @ 2422 0 @ 2422 - CURRENT BACKGROUND/AVG 37u
PENTANE(C-5) 0 @ 2422 0 @ 2422 -
HYDROCARBON SHOWS
INTERVAL LITHOLOGY IREMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY 30% Sand, 10% Siltstone, 60% Claystone
DAILY ACTIVITY SUMMARY staged down to td, ci re/cond , pooh, run in casing, circ at report time to cond mud
Epoch Personal On Board= 4 Daily Cost $2,540.00
Report by: Brady Kilmer
(
(
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Phillips Alaska
North Slope DAI L Y WELLSITE REPORT ~ EPOCH
Cirque #3
REPORT FOR Rick Levinson
DATE Jan 23, 2002 DEPTH 2422 PRESENT OPERATION= Waiting on cement
TIME 05:00:00 YESTERDAY 2422
24 Hour Footage 0
CASING INFORMATION 95/8" @ 2,412'
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
SURVEY DATA
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED
1 121/4" MXC1 X39DB 1X14/3X20 105' 2422' 2317' 18.49 CASING
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 153.7 @ 2422 153.7 @ 2422 - 153,7 ftlhr
SURFACE TORQUE 256 @ 2422 256 @ 2422 - 256.4 amps
WEIGHT ON BIT 11 @ 2422 11 @ 2422 - 11.8 Klbs
ROTARY RPM 100 @ 2422 100 @ 2422 - 100 RPM
PUMP PRESSURE 1368 @ 2422 1368 @ 2422 - 1368 psi
DRILLING MUD REPORT DEPTH: 2422'
MW 10.00 VIS 47 PV 11 YP 21 FL Gels 7/12/14 CL- 18,000
FC 2.010.0 SOL 8.1 SD 2.50 OIL MBL 6.3 pH 8.40 Ca+ 248 eci
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY(units) HIGH LOW AVERAGE
DITCH GAS 48 @ 2422 48 @ 2422 - TRIP GAS= 330u @ 2422'
CUTIING GAS 0 @ 2422 0 @ 2422 - WIPER GAS= N/A
CHROMATOGRAPHY(ppm) SURVEY= N/A
METHANE(C-1) 9760 @ 2422 9760 @ 2422 - CONNECTION GAS HIGH= N/A
ETHANE(C-2) 0 @ 2422 0 @ 2422 - AVG= N/A
PROPANE(C-3) 0 @ 2422 0 @ 2422 - CURRENT N/A
BUTANE(C-4) 0 @ 2422 0 @ 2422 - CURRENT BACKGROUND/AVG Ou
PENTANE(C-5) 0 @ 2422 0 @ 2422 -
HYDROCARBON SHOWS
INTERVAL LITHOLOGY IREMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY 30% SAND, 10% SILTSTONE, 60% CLAYSTONE
DAILY ACTIVITY SUMMARY CIRCULATED, PUMPED CEMENT, WAIT ON CEMENT, WAITING ON CEMENT AT REPORT TIME.
Epoch Personel On Board= 4 Daily Cost $ 2,640.00
Report by: Brady Kilmer
(
(
(
Phillips Alaska
North Slope DAILY WELLSITE REPORT ~ EPOCH
Cirque #3
REPORT FOR Rick Levinson
DATE Jan 24, 2002 DEPTH 3085 PRESENT OPERATION= Drilling Ahead
TIME 05:00:00 YESTERDAY 2422
24 Hour Footage 663
CASING INFORMATION 95/8" @ 2412'
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
SURVEY DATA 3071.09' 27.40 339.19 2891.01'
BIT INFORMATION INTERVAL CONDITION REASON
NO, SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED
3 81/2" S88HPX JS062 8x12 2422
2 Hole Opener
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 253.0 @ 2504 16.2 @ 2580 102.7 146.4 ftlhr
SURFACE TORQUE 256 @ 2422 0 @ 3068 79.5 143.7 amps
WEIGHT ON BIT 14 @ 2872 0 @ 2962 2.9 0.3 Klbs
ROTARY RPM 100 @ 2422 1 @ 3053 81,0 98 RPM
PUMP PRESSURE 2442 @ 2827 1316 @ 2470 2114,7 2261 psi
DRILLING MUD REPORT DEPTH: 2422'
MW 10.00 VIS 47 PV 11 YP 21 FL Gels 7/12/14 CL- 18,000
FC 2,0/0.0 SOL 8.1 SO 2.50 OIL MBL 6.3 pH 8.40 Ca+ 248 eci
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY(unlts) HIGH LOW AVERAGE
DITCH GAS 48 @ 2422 1 @ 2446 15.4 TRIP GAS= 15u @ 2422'
CUTTING GAS 0 @ 3085 0 @ 3085 0.0 WIPER GAS= nla
CHROMATOGRAPHY(ppm) SURVEY= nla
METHANE(C-1) 9760 @ 2422 134 @ 2446 3043.4 CONNECTION GAS HIGH= Ou
ETHANE(C-2) 0 @ 3085 0 @ 3085 0.0 AVG= Ou
PROPANE(C-3) 0 @ 3085 0 @ 3085 0.0 CURRENT Ou
BUTANE(C-4) 0 @ 3085 0 @ 3085 0.0 CURRENT BACKGROUNDIAVG 13u
PENTANE(C-5) 0 @ 3085 0 @ 3085 0.0
HYDROCARBONSHO~
INTERVAL LITHOLOGY IREMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY 40% Claystone, 20% Tuffaceous Siltstone, 20% Siltstone
DAILY ACTIVITY SUMMARY Began drilling after casing, drilling at report time.
Epoch Personel On Board= 4 Daily Cost $ 2,640.00
Report by: Brady Kilmer
('
(
(
Phillips Alaska
North Slope DAI L Y WELLSITE REPORT ~ EPOCH
Cirque #3
REPORT FOR Rick Levinson
DATE Jan 25, 2002 DEPTH 4487 PRESENT OPERATION= Short Trip before Iceberg Sand
TIME 05:00:00 YESTERDAY 3085
24 Hour Footage 1402
CASING INFORMATION
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
SURVEY DATA 4413.55' 27.04 339.16 4079.85
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED
3 81/2" S88HPX JS062 8x12 2422'
2 Hole Opener
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 263.4 @ 3852 12.7 @ 3187 99.9 59.0 ftlhr
SURFACE TORQUE 253 @ 3932 0 @ 4220 133,2 145.0 amps
WEIGHT ON BIT 21 @ 4218 1 @ 4481 4.9 0.9 Klbs
ROTARY RPM 99 @ 3848 44 @ 3835 87.3 97 RPM
PUMP PRESSURE 2929 @ 4390 1859 @ 3145 2532.7 2788 psi
DRILLING MUD REPORT DEPTH: 2854
MW 10.25 VIS 43 PV 12 YP 18 FL Gels 4/13/16 CL- 32,000
FC 2,0/0.0 SOL 8.5 SD 1.50 OIL MBL 5.0 pH 9.00 Ca+ 220 eci
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY{units) HIGH LOW AVERAGE
DITCH GAS 31 @ 4414 4 @ 4110 14.3 TRIP GAS= n/a
CUlTlNG GAS 0 @ 4487 0 @ 4487 0,0 WIPER GAS= n/a
CHROMATOGRAPHY{ppm) SURVEY:=: n/a
METHANE{C-1) 5810 @ 4414 380 @ 4110 1930.5 CONNECTION GAS HIGH= 19u
ETHANE{C-2) 124 @ 4473 2 @ 4000 13.8 AVG= au
PROPANE(C-3) 67 @ 4464 1 @ 4213 4.0 CURRENT Ou
BUTANE(C.4) 50 @ 4464 1 @ 4428 0.9 CURRENT BACKGROUND/AVG 25u
PENTANE{C-5) 0 @ 4487 0 @ 4487 0.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY IREMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY 20% Siltstone, 80% Claystone
DAILY ACTIVITY SUMMARY Drilled to 4487', short trip to clean hole before drilling Iceberg Sand, Short tripping at report time.
Epoch Personal On Board= 4 Daily Cost $ 2,640.00
Report by: Brady Kilmer
(
(
(
Phillips Alaska
North Slope DAILY WELLSITE REPORT ~ EPOCH
Cirque #3
REPORT FOR Rick Levinson
DATE Jan 26, 2002 DEPTH 5633 PRESENT OPERATION= Drilling Ahead
TIME 05:00:00 YESTERDAY 4488
24 Hour Footage 1145
CASING INFORMATION 95/8" @ 2412'
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
SURVEY DATA 5568.38' 26.88 338.90 5105.38
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE lYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED
3 81/2" S88HPX JS062 8x12 2422'
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 205.1 @ 4729 10.5 @ 4495 83.5 64.3 ftIhr
SURFACE TORQUE 377 @ 5188 0 @ 5543 208.0 259.8 amps
WEIGHT ON BIT 31 @ 4693 0 @ 4894 7.0 3,7 Klbs
ROTARY RPM 101 @ 4777 21 @ 5198 85.5 99 RPM
PUMP PRESSURE 3292 @ 5283 1409 @ 5543 2877.9 3165 psi
DRilLING MUD REPORT DEPTH: 4427'
MW 10.20 VIS 48 PV 16 YP 24 FL Gels 5/14/20 CL- 30,500
FC 2.0/0.0 SOL 9.6 SD 1.00 Oil MBl 8.8 pH 9.40 Ca+ 180 eel
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY(units) HIGH lOW AVERAGE
DITCH GAS 119 @ 4727 3 @ 5321 15.0 TRIP GAS=
CUTTING GAS 0 @ 5633 0 @ 5633 0.0 WIPER GAS= 64u @ 4487"
CHROMA TOGRAPHY(ppm) SURVEY= n/a
METHANE(C-1) 8308 @ 4727 313 @ 5138 1229.5 CONNECTION GAS HIGH= 25u @ 4583'
ETHANE(C-2) 767 @ 4728 7 @ 5321 59.7 AVG= 5u
PROPANE(C-3) 386 @ 4728 1 @ 5359 26.3 CURRENT OU
BUTANE(C-4) 181 @ 4728 1 @ 4989 12.2 CURRENT BACKGROUND/AVG 15u
PENTANE(C-5) 58 @ 4580 1 @ 4864 2.7
HYDROCARBON Iceberg Sand
SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
4695' 4735' 80% Sand 10% Siltstone 10% 120u total c1 8308 c2 757 c3 376 ic4 52 nc4 127 ic5 21 nc5 See Log for Sand
Tuff 32 Description
LITHOLOGY
PRESENT LITHOLOGY 20% Tuffaceous Claystone, 50% Claystone, 10% Tuffaceous Siltstone, 10% Siltstone, 10%
DAilY ACTIVllY SUMMARY Finished Short Trip, drilled from 4487' to 5711' at report time.
Epoch Personel On Board= 4 Daily Cost $ 2,540.00
Report by: Brady Kilmer
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Phillips Alaska
North Slope DAILY WELLSITE REPORT [~ EPOCH
Cirque #3
REPORT FOR Rick Levinson
DATE Jan 27,2002 DEPTH 6025 PRESENT OPERA TION= Drilling ahead in search of core point
TIME 05:00:00 YESTERDAY 5634
24 Hour Footage 391
CASING INFORMATION 95/8" @ 2412'
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
SURVEY DATA 5932.46' 27.20 338.68 5427.96'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED
4 81/2" MXC1 F68JE 1x12/3x15 5928
3 81/2" MXC1 JS062 8x12 2422' 5928' 3506' 45.8 BHA
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 175.5 @ 5833 7.8 @ 5931 72.9 31.1 fUhr
SURFACE TORQUE 386 @ 5836 0 @ 5755 249.6 282.3 amps
WEIGHT ON BIT 30 @ 6014 1 @ 5809 11.4 30.2 Klbs
ROTARY RPM 166 @ 5973 45 @ 5736 102.5 165 RPM
PUMP PRESSURE 3245 @ 5930 2346 @ 5943 3063.1 2423 psi
DRILLING MUD REPORT DEPTH: No Report
MW VIS PV YP FL Gels CL-
FC SOL SD OIL MBL pH Ca+ CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY(unlts) HIGH LOW AVERAGE
DITCH GAS 23 @ 5828 2 @ 5942 13.8 TRIP GAS= 45u @ 5928'
CUTTING GAS 0 @ 6025 0 @ 6025 0.0 WIPER GAS= nla
CHROMATOGRAPHY(ppm) SURVEY::: nla
METHANE(C-1) 3250 @ 5943 207 @ 5940 1215,2 CONNECTION GAS HIGH= 5u
ETHANE(C-2) 53 @ 5828 3 @ 5942 33.9 AVG= 2u
PROPANE(C-3) 35 @ 5960 1 @ 5940 14.2 CURRENT Ou
BUTANE(C-4) 6 @ 5969 1 @ 5982 0.1 CURRENT BACKGROUND/AVG 4u
PENTANE(C-5) 0 @ 6025 0 @ 6025 0.0
HYDROCARBON SHOWS
INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY Claystone60%, Shale 10%, Siltstone 20%, Tuffaceous Siltstone 10%
DAILY ACTIVITY SUMMARY Drilled to 5928', tripped out to laydown Mudmotor, tripped in to drill ahead for coring point
Epoch Personel On Board::: 4 Daily Cost $ 2,540.00
Report by: Brady Kilmer
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Philips Alaska
North Slope DAILY WELLSITE REPORT ~ EPOCH
Cirque #3
REPORT FOR Rick Levinson
DATE Jan 28, 2002 DEPTH 6215 PRESENT OPERA TION= Tripping for Core Barrel
TIME 05:00:00 YESTERDAY 6026
24 Hour Footage 189
CASING INFORMATION 95/8" @ 2412'
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
SURVEY DATA 6083.51 27.19 339.87 5562.28
BIT INFORMATION INTERVAL CONDITION REASON
NO, SIZE lYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED
5 81/2" ARC425C3 7100484 .75 6123 6215 92 Cores
4 81/2" MXC1 7F68JE 1x12/3x15 5928 6123 195 Core Point
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 134.4 @ 6102 10.2 @ 6206 48.1 10.2 ftlhr
SURFACE TORQUE 637 @ 6132 164 @ 6068 414,1 431.3 amps
WEIGHT ON BIT 30 @ 6026 0 @ 6124 18,2 7.5 Klbs
ROTARY RPM 165 @ 6026 49 @ 6124 117.1 63 RPM
PUMP PRESSURE 2424 @ 6035 1007 @ 6197 1742.5 1047 psi
DRILLING MUD REPORT DEPTH: 5921
MW 10.20 VIS 50 PV 16 YP 27 FL 5.0 Gels 6/10/16 CL- 31000
FC 2,0/0.0 SOL 11.7 SD 0.75 OIL MBL 7.5 pH 9.00 Ca+ 220 eci
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY(unlts) HIGH LOW AVERAGE
DITCH GAS 87 @ 6113 2 @ 6060 19.4 TRIP GAS= 25u @ 6123'
CUTTING GAS 0 @ 6206 0 @ 6206 0.0 WIPER GAS= NIA
CHROMA TOGRAPHY(ppm) SURVEY= NIA
METHANE(C-1) 12676 @ 6113 178 @ 6060 2305.3 CONNECTION GAS HIGH= Ou
ETHANE(C-2) 1027 @ 6113 7 @ 6060 154.1 AVG= Ou
PROPANE(C-3) 666 @ 6113 4 @ 6060 106.2 CURRENT OU
BUTANE(C-4) 300 @ 6123 1 @ 6091 50.5 CURRENT BACKGROUND/AVG 2u
PENTANE(C-5) 143 @ 6123 1 @ 6188 18,1
HYDROCARBON SHOWS Bermuda Sand
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
6092' 6180' Sand I Sandstone 87 total, 12676 c1, 1027 02, 666 c3, 73 ic4, 218 nc4, 46 Ic5, 56 nc5 See Log Remarks
LITHOLOGY
PRESENT LITHOLOGY Sand 20%, Sandstone 30%, Shale 10%, Tuffaceous Claystone 30%, Tuffaceous Siltstone 10%
DAILY ACTIVllY SUMMARY Tripped back to bottom with core barrels, drilled from 6123' to 6215', tripping out with cores at report time.
Epoch Personel On Board= 4 Daily Cost $ 2,540.00
Report by: Brady Kilmer
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Phillips Alaska
North Slope DAILY WELLSITE REPORT [~ EPOCH
Cirque #3
REPORT FOR Rick Levinson
DATE Jan 29, 2002 DEPTH 6390 PRESENT OPERATION= Drill Ahead
TIME 05:00:00 YESTERDAY 6215
24 Hour Footage 175
CASING INFORMATION 95/8" @ 2412'
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
SURVEY DATA 6316,59 26.43 339.12 5770.02
BIT INFORMATION INTERVAL CONDITION REASON
NO, SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED
6 6215
5 61/2" ARC425C3 7100464 .75 6123 6215 92 8 cores
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 181.9 @ 6248 17.0 @ 6216 69.4 79.6 ftlhr
SURFACE TORQUE 583 @ 6215 113 @ 6216 437.6 425,0 amps
WEIGHT ON BIT 10 @ 6215 6 @ 6284 7.3 7.0 Klbs
ROTARY RPM 105 @ 6240 43 @ 6216 103.3 103 RPM
PUMP PRESSURE 2691 @ 6310 966 @ 6215 2503.9 2551 psi
DRILLING MUD REPORT DEPTH: 5921
MW 10.2 VIS 50 PV 16 YP 27 FL Gels 6/10/16 CL- 31,000
FC 2.0/0.0 SOL 11.7 SD .75 Oil MBl 7.5 pH 9,00 Ca+ 220 eci
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY(unlts) HIGH lOW AVERAGE
DITCH GAS 10 @ 6294 2 @ 6220 6.2 TRIP GAS= 15u @ 6215'
CUlÏlNG GAS 0 @ 6390 0 @ 6390 0.0 WIPER GAS= nla
CHROMATOGRAPHY(ppm) SURVEY= nla
METHANE(C-1) 1674 @ 6294 156 @ 6216 469.7 CONNECTION GAS HIGH= 19u @ 6293'
ETHANE(C.2) 73 @ 6294 10 @ 6220 26.9 AVG= Ou
PROPANE(C-3) 67 @ 6252 9 @ 6220 22.0 CURRENT Ou
BUTANE(C-4) 44 @ 6252 3 @ 6390 12.6 CURRENT BACKGROUND/AVG 8u
PENTANE(C-5) 19 @ 6252 1 @ 6291 2.3
HYDROCARBON SHOWS
INTERVAL LITHOLOGY IREMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY 10% Sandstone, 20% Siltstone, 30% Claystone, 40% Shale
DAILY ACTIVITY SUMMARY Tripped back to bottom, drilled from 6215' to 6486' at report time,
Epoch Personel On Board= 4 Daily Cost $ 2,540.00
Report by: Brady Kilmer
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Phillips Alaska
North Slope DAI L Y WELLSITE REPORT ~ EPOCH
Cirque #3
REPORT FOR Rick Levinson
DATE Jan 58. 2002 DEPTH 8677 PRESENT OPERATION= Logging hole
TIME 05:00:00 YESTERDAY 6390
24 Hour Footage 287
CASING INFORMATION 95/8" @ 2412'
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
SURVEY DATA 6677.00' 24.57 339.61 8095.89'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 162.4 @ 6517 13.9 @ 6494 83,8 80.0 ftlh r
SURFACE TORQUE 520 @ 6815 390 @ 6481 441.2 464.1 amps
WEIGHT ON BIT 15 @ 6494 0 @ 6591 5.0 5.0 KIbs
ROTARY RPM 105 @ 6489 95 @ 8488 102.6 104 RPM
PUMP PRESSURE 2929 @ 6585 2489 @ 6493 2704.4 2791 psi
DRILLING MUD REPORT DEPTH: 6215
MW 9.70 VIS 46 PV 14 YP 25 FL Gels 5/12/17 CL- 30,000
FC 2.0/0.0 SOL 7.7 SD 0.50 OIL 1.0 MBL 4.0 pH 9.30 Ca+ 0 CCI
MwD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY(units) HIGH LOW AVERAGE
DITCH GAS 10 @ 6667 2 @ 6645 5.1 TRIP GAS= nIB
CUTTING GAS 0 @ 6677 0 @ 6677 0.0 WIPER GAS= 42u @ 6677'
CHROMATOGRAPHY(ppm) SURVEY= nIB
METHANE(C-1) 1922 @ 6668 129 @ 6631 527,1 CONNECTION GAS HIGH= 12u @ 6390'
ETHANE(C-2) 86 @ 6668 4 @ 6637 27.9 AVG= 2u
PROPANE(C-3) 41 @ 6391 1 @ 6637 12.6 CURRENT OU
BUTANE(C-4) 8 @ 6391 1 @ 6654 1.7 CURRENTBACKGROUND/AVG OU
PENTANE(C-5) 0 @ 6677 0 @ 6677 0.0
HYDROCARBONSHO~
INTERVAL LlTHOLOGYIREMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY 20% Siltstone, 30% Claystone, 20% Tuffaceous Claystone, 10% Shale, ~O% Ash
DAILY ACTIVITY SUMMARY Drilled to 6677', tripped out to run wlrellne, running wlrellne at report
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Epoch Personel On Board= 2 Daily Cost $ 1,920.00
Report by: Brady Kilmer
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~V~VΠ(ffi~ 1A\~1A\~~1A\
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ALAS IiA. 0 IL AND GAS
CONSERVATI ON COMMISSION
TONY KNOWLES, GOVERNOR
333 W. "JTH AVENUE. SUITE 100
ANCHORAGE. ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Paul Mazzolini
Exploration/CI Team Leader
Phillips Alaska, Inc
PO Box 100360
. Anchorage AK 99510
Re:
Cirque #3
Phillips Alaska, Inc
Permit No: 201-244
Sur.Loc.377'F~,487,FEL,Sec.28,T9N,R7E,~
Btmhole Loc. 1934' FSL, 1378' FEL, Sec. 21, T9N, R7E, UM
Dear Mr. Mazzolini:
Enclosed is the approved application for permit to drill the above referenced well.
The permit to drill does not exempt you from obtaining additional permits required by law from other
governmental agencies, and does not authorize conducting drilling operations until all other required
permitting determinations are made. A weekly status report is required from the time the well is spudded
until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the
week's activities and is exclusively for the Commission's internal use.
Annular disposal has not been requested as part of the Permit to Drill application for Cirque #3.
All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals
from below the permafrost or from where samples are first caught and 10' sample intervals through target
zones.
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient
notice (approximately 24 hours) of the BOPE test perlormed before drilling below the surface casing shoe
must be given so that a representative of the Commission may witness the test. Notice may be given by
contacting the Commission petroleum field inspector on the North Slope pager at 659-3607.
Sincerely,
b^
().uU ¥ /
Cammy echsli Taylor vf
Chair
BY ORDER OF THE COlVlMISSION
. DATED this 15th day of January, 2002
jj c/Enclosures
cc:
Department ofFish & Game, Habitat Section wlo encl.
Department of Environmental Conservation wlo encl.
(' STATE OF ALASKA ("
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
'Nr;,A: 1}7/0 L
If1. "M (1\\ I a ø-
d'M t+ \ 11':>1 D:J--
20 AAC 25.005
1 a. Type of work: Drill 0 Redrill 0 1 b. Type of well. Exploratory 0 Stratigraphic Test 0 Development Oil 0
Re-entry DDeepen 0 SeNice 0 Development Gas 0 Single Zone 0 Multiple Zone 0
2. Name of Operator 5. Datum elevation (OF or KB) 10. Field and Pool
Phillips Alaska, Inc. AMSL 178 feet
3. Address 6. Property Designation 37~ðB6 k Exploration
P.O. Box 100360 Anchorage, AK 99510-0360 ADL 375077 ALK 4295
4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251)
377' FNL, 487' FEL, Sec. 28, T9N, R7E, UM Exploration Statewide
At top of productive inteNal 8. Well number Number
166Z FSL,127~FEL,Sec.21,T9N, R7E, UM Cirque #3 #59-52-180
At total depth 9. Approximate spud date Amount
1934' FSL, 1378' FEL, Sec. 21, T9N, R7E, UM January 10, 2002 $200,000
12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
1662' @ TARGET feet None 2560 6567 ' MD I 5991 I TVD
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2))
Kickoff depth: 500 MD Maximum hole angle 27° Maximum surface 2674 psig At total depth (TVD) 3414 psig
18. Casing program Setting Depth
size Soecifications Top Bottom Quantity of Cement
Hole Casina Weiaht Grade Couolina Lenath MD TVD MD TVD (include staç¡e data)
42" 16" 62.5# B PEB 80' Surf. Surf. 115' 115' PRE-INSTALLED
12.25" 9.625" 40.0# L-80 BTC 2402' Surf. Surf. 2432' 2318' 410 sx Class G, 220 sx Class G
8.50" 7.0" 26.0# L-80 BTC 6537' Surf. Surf. 6567' 5991' 160 sx Class G, 280 sx Class G
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total Depth: measured feet Plugs (measured)
true vertical feet
Effective Depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented Measured depth True Vertical depth
Conductor
Surface
Production RECEIVED
Liner
Perforation depth: measured DEC 11 2001
true vertical Alaska Oil & Gas Cons. Commission
Anchorage
20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0
Drilling fluid program 0Time vs depth plot C2:Þefraction analysis 0 Seabed report 020 AAC 25,050 requirements 0
21. I hereby certify that the foregoing is true and correct to the best of my knowledge QuestIons? Mark Chambers, 265-1319
Signed ?~ ~ Title: Exp/o,"/ionICl Teem L..de' IZ11'7/ð I
Date
Paul Mazzo/ini ~ . hll ,.....
Commission Use Onlv
Permit Number / . t/ lj" API number '?tJ1: ~ ') Approval date \' \t1 ()~ See cover letter
7-C:> - 2- 50- /03 - 2£)-:) ,. r, for other requirements
Conditions of approval Samples'required ~ Yes 0 No Mud log required r~ Yes D No
Hydrogen sulfide measures 0 Yes ~ No Directional suNey required Þ.a Yes 0 No
Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M; 0 0
Other: 'Te~+ Bo (> E Orimal i6'RehV ç¿ . J{;1IJIi '{\A
by order of \ ,(/ Or
Approved by Cammy Oed1d Commissioner the commission Date
I
Form 10-401 Rev. 12/1/8S.
ORIGINAL
Submit in triplicate
@~&~~ @1- &r1Æ@~
DIVISION OF OIL AND GAS
TONY KNOWLES, GOVERNOR
DEPARTMENT OF NATURAL RESOURCES
3601 C STREET, SUITE 1380
ANCHORAGE, ALASKA .~fJ5.°3-5948
PHONE: (907) 269-8800
FAX: (907) 562-3852
January 8, 2002
Paul Wharton
Senior Landman
Phillips Alaska, Inc.
P.O. Box 100360
Anchorage, Alaska 99510-0360
ì 'v~\
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Re: Kuparuk River Unit
Cirque #3 Tract Operations, ADL 375077 (KRU Tract 138)
Dear Mr. Wharton:
By letter dated December 18, 2001, Phillips Alaska, Inc. applied for approval to drill the Cirque #3
("Well") exploratory well and to commingle test production generated from the Well with production
from the Kuparuk River Unit (KRU). The Well will have a bottomhole location in ADL 375077.
I approve the request to drill the Well. I also approve the commingling of the test fluids from the
Well with other KRU production. Since the Well will be drilled and tested from an ice pad, this
approval is only until June 15, 2002 or the conclusion of Tundra Travel, whichever is later. A status
report of the testing operations must be provided to the Division of Oil and Gas on or before August
15. 2002 unless the Division grants an extension. The status report should list the spud date of the
well, the start and stop dates of each testing period, and state whether the well is capable of producing
or contributing to production of hydrocarbons in paying quantities.
All test production from the Well shall be allocated to ADL 375077. The lessees of ADL 375077, in
the percentages specified in your December 18th letter, shall individually account for the production
allocated to the lease and commingled with other KRU production on their monthly royalty report.
The monthly KRU Operator's Report provided to the Division should separately account for the
Well's test production commingled with the KRU production. The royalty accounting code for
reporting the Well's production is KU07.
Sincerely,
~o~
KRU .Cirque#3 .TractOps.doc
:~C€"IV~D
A IVOo
~~,f'a Oil & v ~
GasQ
41?f'J- OIls. C
""'O/'.:J", OllJltJi
. ....f/e 's.~¡OIï'
Mark D. Myers
Director
"Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans."
(
f
PHILLIPS PETROLEUM COMPANY
To:
Greg Keith
Laurel Alexander
Mark Chambers
From:
Kathy Heinlein
ATO-1458
ATO-1456
A TO-1566
A TO-1346
Subject:
Pre-Drill Seismic Pore Pressure Prediction for Proposed Well
Location: Cirque #3
Date:
December 18, 2001
CONFIDENTIAL
Summary
Seismic velocity data was used to predict pore pressures likely to be encountered at the
Cirque #3 proposed well location (main trajectory and sidetrack). A local compaction
trend and a local velocity to pressure gradient translation trend model was established
using control from the Cirque #2 offset well. The trends calculated at Cirque #2 were
compared to trends observed at Tarn and Meltwater and found to be similar.
The local compaction trend and translation trend model established from the existing
wells was applied to velocities from 3D seismic data to predict pore pressures. The
predictions show no apparent shallow hazards or large pressure anomalies at the
proposed well location.
Seismic Processing:.
The accuracy of seismic geopressure analysis depends critically on the accuracy of the
input velocity field. The velocities used were generated using Phillips' AVEL program,
an automated high-resolution velocity analysis program developed by ARCO
Exploration and Production Technology. This process produces a very accurate velocity
field defined at every sample in time and laterally along each seismic line. The output
RMS velocities were smoothed over 9 CDPs to minimize instabilities in the velocity field
that might result from noise, lack of signal or variations in CDP fold.
RECEIVED
JAN 0 7 2002.
AI. Oil & Gas Cons. GommissiIMI
Anchorage .
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Pressure Prediction Procedure:
The Cirque #2 offset well was used to establish both a local normal compaction trend
line and local velocity vs. pressure translation trend model. This model is similar to the
regional models used previously at Tarn and Meltwater.
Procedure
1.) Normal Compaction Trend Lines (NCTL) were calculated for a series of 3D seismic
lines from the Merged Tarn-Midtarn-Meltwater 3D seismic dataset. The slope of the
individual seismic NCTLs matched the slope calculated at Cirque #2, but the
intercepts varied slightly from the Cirque #2 NCTL. This is not unexpected as the
seismic velocity measures a larger component of horizontal velocity vs the well sonic
log which measures primarily vertical velocity. The NCTL calculated from the Cirque
#2 sonic log has an intercept of 148; the 3D seismic lines have an average intercept
of 160. It was verified that the slope of 160 on the seismic NCTL gave the most
accurate pressure prediction from seismic velocities at the Cirque #2 well. The slope
of the NCTL line (for both sonic log and seismic data) is -4.5e-5.
2.) The difference between interval transit times (ITT), recorded by wireline sonic logs
(Ll T) in the existing wells or by seismic velocities in the proposed wells, and the
interval transit times predicted by a downward extension of the NCTL were
measured. These values are the travel time differences, LlLl T.
3.) A translation trend model was established by comparing transit time differences
(LlLl T) to mud weights. This model calculates pressure gradients (PP) using the
equation
PP = C2* LlLl T**2 + C1 * LlLl T + CO
Where C2 = -1.34-5, C1 = .0062, CO = .465
4.) Fracture gradients were calculated using the Eaton Method. Inputs are the bulk
density, the calculated pore pressure gradient profile, and a Poisson's Ratio profile
(from a West Cameron model).
RECEIVED
JAN 0 ? lUU:,~
Alaska Oil & Gas Cons. Commissiol!
Anchorage
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Cirque #2:
Figure #1 is the pore pressure gradient calculation for Cirque #2. The left side is the
wireline sonic DT (black curve) with the NCTL (red line). The right side is the pore
pressure gradient calculation (blue curve), actual mud weight (green curve), and the
calculated fracture gradient (red curve). Casing points, areas of hole problems,
formation tops, and lithology changes are as labeled.
A thin zone of over-pressured gas-charged sand was encountered in the Cirque #2 well
at 2171 ft SSTVD (K-10). Similar shallow gas-bearing zones below the permafrost layer
are the suspected cause of the blow-out at the Cirque #1 well. Over-pressured free gas
may have been encountered in approximately this same interval below permafrost, and
additionally gas hydrates may have melted within the permafrost layer as a result of the
gas returns from this interval.
A false pressure increase is noted at approximately 6532 ft SSTVD. This apparent
pressure increase is actually due to a change in lithology which results in slower
velocity.
Seismic Pore Pressure Prediction (No Shallow Hazards Observed)..;,
Pressure gradients were predicted from seismic velocities in a 3D cube surrounding the
proposed Cirque #3 well location.
This report includes displays in time and depth of pressure gradient predictions on 3D
inlines and 3D crosslines at the surface and bottom hole locations, in addition to time
and depth displays of pressure along the proposed deviated borepath.
Predicted Pore Pressure Gradient Displays in De~
Figure # Seismic Line Well Name
2 IL 4993 Cirque #3 Surface Location
4 3D Traverse Cirque #3 Borepath
6 3D Traverse Cirque #3 Sidetrack Borepath
Predicted Pore Pressure Gradient Displays in Time:
Figure # Seismic Line Well Name
3 IL 4993 Cirque #3 Surface Location
5 3D Traverse Cirque #3 Borepath
7 3D Traverse Cirque #3 Sidetrack Borepath
Warmer colors indicate higher predicted mud weights (pore pressure gr~~eEIVED
No shallow hazards or areas of high pressure at depth were observed.
JAN 0 7 ZDn)
Alaska Oil & Gas Coos. Commission
Anchorage
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Pore Pressure Gradient Prediction at Proposed Well Location:
Figure # Seismic Line Well Name
8 3D Seismic Traverse Cirque #3 Deviated Borepath
9 3D Seismic Traverse Cirque #3 Sidetrack Deviated Borepath
The Potential for the Presence of Gas Hydrates and Seismic Pressure Prediction:
Gas-charged sands within the permafrost zone are thought to have contributed to the
blow-out at the Cirque #1 well. A thin-zone of over-pressured gas-charged sands was
observed at the base of permafrost in the Cirque #2 well. Previous analysis (Heinlein,
2000) shows that there is no apparent indication of the presence of gas hydrates within
the permafrost layer on either the 20 or the 3D seismic data in the area surrounding the
Cirque wells, and that gas-charged sands sitting immediately below the permafrost (in
the K-10 interval) may not appear as a potential pressure anomaly on 3D seismic.
Conclusions:
1.) There are no apparent shallow hazards at the proposed Cirque #3 well location
(main trajectory and sidetrack).
2.) The NCTL and Translational Trend Model calculated at the Cirque #2 well are
similar to NCTLs and Translational Trend Models calculated at Tarn and Meltwater.
3.) A thin zone of overpressured gas-charged sands was encountered below permafrost
at the Cirque #2 well. There is the possibility that gas-charged sands exist in this
interval in the vicinity of the proposed Cirque #3 well location, but may not be
apparent on pressure sections predicted from seismic data.
If there are any further questions, please contact me at (907) 263-4761 or via email at
kheinle@ppco.com.
Kathy Heinlein
REceiVED
JAN 0 7 200Z
Alaska Oil & Gas Coos Corm. " .
AnChoragè TlISSlon
Project: Cirque
Well: Cirque 2
NCTL: 148-4.5e-5
12/18/01
K. Heinlein
2
DEPTH (Daium settD MSL)
-170
I'm
-170
2000
3000
4000
5000
5000
7000
7577
40 60 80 100 120 140
NCTllntereept at GL " 1~
LogarMmic Slope" -Ue-85
iii.. Caaing Depth !<E Kick 1 Flow
+ Repeat Formation Teet ){ Orin Stem Tellt
tJ. Production Pressure ~ LeM-off Teet
ø Loet Circulation Zones - Formation Top
... Stuell Pipe Loeation .. Sidetrack Loealion
Z Freeform
13
16
7577
20
14
illiG
15
Figure 1
Method: Trend Curve
NCTL: 1
Model: Pleistocene
Cross Section: IL4993
12/18/01
K. Heinlein
1U-4$-SPL_PP@
w
1111111111111111111111111111111111111111111111111 1111 1 11 1 11111111111111111111111111111111111111
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,""F 4 4 4 4 4 4. 4. 4. 4 4. 4 4 4 4. 4. 4. 4. 4. 4. 4. 5. H n n- 5 5 5 5. 5. 5. 5. 5. 5. 5. 5. 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5. 5. 5. 5. 5. 5. 5. 5. 5. 5. 5. 5. 6. 6. 6 6. 6 6. 6 6 6. 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6
666667777788888999990 - 111222223333344444 55666667777888889999900000111112222233333444445
MSLO,O 02 46 8 0 2 4 68 0 2 4 680 2 4 6 8 0 4 6 8 024 6 8 0 2 46 8 6 8024 6 80 3 6802 4 6 8 0 24 6 8 0 2 46802 4 680 2 4 68 0 2 4 6 80 2 4 6 8 0
D
E
I' 3000,0
T
Ii
!flj
E
m
8.00
8.50
9,00
9,50
10,00
10,50
11,00
11.50
12,00
12,50
13,00
13,50
14,00
14,50
15,00
15.50
16,00
16,50
17,00
17,50
18,00
18,50
19,00
2
Cirque
Cross Section: IL4993
Method: Trend Curve
NCTL: 160-4.5-5
Model: Pleistocene
12/18/01
K. Heinlein
~1~UUt, ~U~rAIJt
w
E
111111111111111111111111111111111111111111111111111 1 11 11 1 11111111111111111111111111111111111111
CD!' ~~~n~~nn~~~n~n~n~nnH~HH~n~Hnn~~Hn~Hn~ ~ nnH~H~Hn~~~nnnn~~~n~~~~~~~~
6666B7777788888999990000011111222223333344444555556666B7 777888889999900000111112222233333444445
0,002468024680246802463024630246802468024B302468024B30246303680246802468024B3024B802468024B8024680
3
8.00
8.50
9.00
9,50
10,00
10,50
11,00
11 ,50
12.00
12,50
13,00
13.50
14,00
14,50
15,00
15.50
16.00
1B.50
17.00
17,50
18,00
18,50
19,00
Cross Section: 3D Traverse
Method: Trend Curve
NCTL: 1
Model: Pleistocene
3
8
4
Cross Section: 3D Traverse
12/18/01
K. Heinlein
3
Method: Trend Curve
NCTL: 1
Model: Pleistocene
8
6
10.4
10.2
10
9.8
t?
CI..
CI..
"0
( )
....
()
'6
( )
L-
a..
9.6
9.4
9.2
9
12/18/01
K- Heinlein
ue 3
icted
1000
5000
6000
2000
3000
4000
SSTVD
Cirque
Well: Cirque 3
NCTL: 160-4.5e-5
7000
8
10.4
10-2
10
9.8
t?
a..
a..
"0
.£: 9.6
()
'6
( )
L-
a..
9.4
9.2
9
Project: Cirque
Well: Cirque 3 Sidetrack
NCTL: 160-4.5e-5
12/18/01
K. Heinlein
Cirque 3 Sidetrack Predicted PPG
Predicted PPG
1000
2000
3000
SSTVD (ft)
4000
5000
6000
Figure 9
(
(
PHilliPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
Post Office Box 100360
Anchorage, Alaska 99510-0360
Mark Chambers
Phone: (907)265-1319
Fax: (907) 265-1336
Email: mchambe2@ppco.com
December 07, 2001
Cammy Oechsli Taylor, Chair
Alaska Oil and Gas Conservation Commission
333 West ih Avenue
Suite 100
Anchorage, Alaska 99501
(907) 279-1433
Re:
Application for Permit to Drill:
Cirque #3 (Exploratory Test)
Surface Location:
Target Location:
Bottom Hole Location:
377'FNL,487'FEL,Sec. 28, T9N, R7E, UM
1662' FSL, 1273' FEL, Sec. 21, T9N, R7E, UM
1934' FSL, 1378' FEL, Sec. 21, T9N, R7E, UM
Dear Ms. Taylor:
Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory test well, the Cirque #3,
from the referenced location located approximately 4.75 miles North East of the Kuparuk River Unit's 2P
Pad. This well will be accessed via ice road originating from the gravel road running between 2N and 2P
Pad and drilled using Doyon Rig #141.
Phillips plans to drill a pilot hole, which will be logged, plugged back and open hole sidetracked to one of
several proposed locations. If successful the sidetrack would than be completed and tested. This
application is for the pilot hole only. A separate permit application for the planned sidetrack will follow at
a later date.
There is a remote possibility that Phillips would complete and test the pilot hole. Therefore a Proposed
Completion Schematic for the pilot hole has been included with this application.
Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent
information attached to this application includes the following:
1)
2)
Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a).
Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1).
ORIGINAL
f
(
3)
A directional plat showing the surface and bottom hole locations proposed for the well per 20
AAC 25.005 (c) (2).
Diagrams and descriptions of the BOP and diverter equipment to be used (Doyon 141) as
required by 20 AAC 25.035 (a) (1) and (b) are on file at the AOGCC office.
A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A
wellbore schematic is also attached visually depicting the proposed well.
The drilling fluid program, in addition to the requirements set forth in 20 MC 25.033 are
attached in this APD package.
Seismic refraction or reflection analysis as required by 20 AAC 25.061(a) are attached in this
APD package.
PHILLIPS does not anticipate the presence of H2S in the formations to be encountered in this
well. However, H2S monitoring equipment will be functioning on the rigs as is the standard
operating procedure in the Kuparuk River Unit drilling operation.
4)
5)
6)
7)
8)
Complete mudlogging operations such as type log generation and sample catching are planned. The
following are PHILLIP's designated contacts for reporting responsibilities to the Commission:
1) Completion Report Sharon Allsup-Drake, Drilling Technologist
(20 AAC 25.070) 263-4612
2) Geologic Data and Logs Laurel Alexander, Geologist
(20 AAC 25.071) 263-4236
The anticipated spud date for this well is January 10, 2002. If you have any questions or require further
information, please contact Mark Chambers at (907) 265-1319 or Paul Mazzolini at (907) 263-4603
Sincerely,
/-t¡)~
Mark Chambers
Exploration Drilling Engineer
cc:
CONFIDENTIAL
Paul Mazzolini
Mark Chambers
Mike Morgan
Cirque #3 Well File
ATO-1570
A TO-1566
ATO-1438
ORIGINAL
(
Phillips Alaska, Inc.
f
General Drillin Procedure
Cirque #3
1.
MIRU Doyon Rig #141 over pre-installed 16" conductor casing. Weld landing ring on conductor.
2.
NU Diverter and function test same. Notify regulatory agencies 48 hours prior to test.
3.
PU Directional BHA and prepare to spud.
4.
Spud well and directionally drill 12-1/4" hole to 9-5/8" surface casing point at 2432' MD / 2318' TVD as
outlined in directional plan. Run MWD / LWD logging tools in drill string as required for directional
monitoring and formation data gathering.
5.
Circulate and condition well bore. Perform short trip. POOH to Run Casing.
6.
Run and cement 9-5/8" 40# L -80 BTC casing string to surface.
Note: Light weight permafrost cement lead slurry and Dowell LiteCrete high compressive, lightweight
tail slurry will be utilized to assure cement returns to the surface i~9 one-stage job:' Ad:quate
excess cement will ,be pumped to ensure cement reaches the surface during the cement Job.
/
A TAM Port Collar will be placed in the 9-5/8" casing at approximately 1000' MD below the
surface. Port collar will only be utilized if cement does not circulate to surface. As an
alternative, if observations at surface indicate cement top is above the Port Collar, a top job may
be performed in lieu of utilizing the port collar. This will be based on the cement thickening time
and time required to trip in hole and open Port Collar to perform second stage cement job. A
Top Job may only be performed after consulting with the AOGCC ./'
,/
ND Diverter System. Install and test BOPE to 5,000 psi. Test casing to 3000 psi. Notify regulatory
agencies 48 hours prior to test.
7.
8.
PU Directional BHA. RIH and drill out sement, float collar, float shoe and 20' to 50' of new hole.
Perform LOT / FIT not to exceed 16.0 ppg EMW. These test results must demonstrate that the integrity
of the casing shoe will be sufficient to contain the anticipated wellbore pressures.
9.
Directionally drill 8-1/2" hole to TD (7" production casing point) at 6567' MD / 5991' TVD as outlined in
directional plan (Coring as Required). Run MWD / LWD logging tools in drill string as required for
directional monitoring and formation data gathering.
10. Circulate and condition well bore. Perform short trip. POOH to run open hole Logs.
11. RU E-Line Unit. RIH and Log Well as required. RD E-Line Unit.
12. PU Drill Pipe Conveyed Logging Tools. RIH and Log Well as required. POOH and LD Drill Pipe Conveyed
Logging Tools
IF PILOT HOLE IS TO BE TESTED
13. RIH to TD.
14. Circulate and condition well bore. Perform short trip. POOH to Run Casing
15. Run and cement 7" 26# L-80 BTC Casing.
ORIGINAL
('
Phillips Alaska, Inc.
.f
I{
16. RIH with Cleanout Bit and Casing Scraper. Clean out to top of cement and displace well to seawater or
kill weight brine. Test casing to 3000 psi.-/' Notify regulatory agencies 48 hours prior to test.
./
17. RU E-Line Unit. RIH and obtain Bond Log (USIT). RD E-Line Unit.
18. RIH and install 3-1/2" 9.3# L-80 EUE 8rd Completion Assembly.
19. ND BOP, NU Tree and Test to 5000 psi. Freeze protect with Diesel. Rig down and move off Doyon Rig
#141.
20. MI well testing equipmept and surface test tanks. Perform production tests as required. Produced fluids
will be either reinjecteãinto the formation or trucked to Kuparuk or Alpine production facilities.
21. Upon completion of testing¡ plug and abandon or temporarily suspend the well as per AOGCC
regulations.
22. Thoroughly clean location and block off further ice road access to ice location.
IF PILOT HOLE IS NOT TO BE TESTED
1.
PM Pilot Hole as per AOGCC regulations. Go to step 22 and continue as outlined above.
-or-
2.
Plug back Pilot Hole as per AOGCC regulations and open hole sidetrack to secondary bottom hole
location. Go to step 13 and continue as outlined above.
Note:
Open hole sidetrack and completion will be permitted separately as soon as Bottom Hole
Location has been identified.
ORIGINAL
(
Phillips Alaska, Inc.
i".'
~
DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND
DRILLING AREA RISKS
Cirque #3
Drillin Fluid Pro erties:
Cirque #3 Property Grids (Clayseal mud)
Surface
Spud to Base of Permafrost Base of Permafrost to Total Depth
Initial Value Final Value Initial Value Final Value
Density (ppg) 10.0 10.0 10.0 10.0
Funnel Viscosity 70-95 50- 70 45-60 45-60
(seconds)
Yield Point 35-45 27-40 25- 35 20- 30
(cP)
Plastic Viscostiy (lb1100 14-20 15-22 15-25 15-25
sf)
10 second Gel Strength 10-20 10-20 13-25 13-25
Obl100 sf)
10 minute Gel Strength 11-21 14-25 13-22 13-22
Obl100 sf)
pH 8.5-9.5 8.5-9.5 8.5-9.5 8.5-9.5
API Filtrate(cc) <15 6 <6 <6
Solids (%) 5-8 6-9 6-10 6-11
I ntermed ¡ate I Prod uction
Initial Value Final Value
Density (ppg) 10.2 10.5 - 10.7
Funnel Viscosity 40-55 40-55
(seconds)
Yield Point 15-22 18-27
(cP)
Plastic Viscostiy (lb1100 14-20 14-25
sf)
10 second gel 10-19 10-19
10 minute gel 13-22 13- 22
pH 9.0-9.5 9.0-9.5
API filtrate <6 <6
HTHP filtrate NC <12
Solids % 6-11 6-11
Drillin Fluid S stem:
Equipment on file with AOGCC for Doyon 141.
Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033.
ORIGINAL
('
Phillips Alaska, Inc.
(
Maximum Antici ated Surface Pressure and Casin Desi n:
The following information is used for calculation of the maximum anticipated surface pressures for the
planned well:
Casing Casing Fracture Pore Formation MASP Drilling
Size Setting Depth Gradient Pressure Pore
Gradient Pressure
16" 115' MD 1 115'1VD 12.8 ppg 8.9 ppg 53 NA
9-5/8" 2432' MD 1 2318'1VD 12.6 ppg 10.2 ppg 1229 64 psi
7" 6567' MD 1 5991'1VD 13.5 ppg 10.7 ppg 3333 1264 psi
Expected Maximum Mud Weights:
12-1/4" Surface Hole to 24321 MD 1 231811VD:
10.0 ppg
10.7 ppg
8-112" Pilot 1 Production Hole to 6567' MD 1 5991'1VD:
Procedure for Calculating Maximum Anticipated Surface Pressure:
MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat
with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient
to the surface as follows:
1) MASP = [(FG x 0.052) - 0.11] x D
Where:
MASP = Maximum Anticipated Surface Pressure
FG = Fracture Gradient at the casing seat in Ib/gal
0.052 = Conversion factor from Ib/gal to psi/ft
0.11 = Gas Gradient in psijft (above 10,OOO'1VD)
D = True vertical depth to casing seat in ft from RKB
OR
2) MASP = FPP - (0.11 x D)
Where:
FPP = Formation Pore Pressure at the next casing seat
MASP Calculations
1. Drilling below 16" Conductor Casing
MASP = [(FG x 0.052) - 0.11] x D
= [(12.8 x 0.052) - 0.11] x 115'
= 64 psi
OR
MASP = FPP - (0.11 x D)
= 1229 - (0.11 x 2318')
= 974 psi
2. Drilling below 9-5/8" Surface Casing
MASP = [(FG x 0.052) - 0.11] x D
MASP = [(12.6 x 0.052) - 0.11] x 2318'
MASP = 1264 psi
ORIGINAL
(
Phillips Alaska, Inc.
I(
OR
MASP = FPP - (0.11 x D)
= 3333 - (0.11 x 5991')
= 2674 psi
Casing Design Performance Properties
Size Weight Grade Connection Internal Collapse Tensile Strength
Yield Joint Body
16" 63ppf B PEB Conductor Casing
9-5/8" 40 ppf L-80 BTC 5750 psi 3090 979 M 916 M
7" 26 ppf L-80 BTC-M 7240 psi 5410 667 M 604 M
Well Proximi
Risks:
None.
Drillin Area Risks:
Shallow Hazards: See attached explanation
Drilling Risks:
Examination of the offset wells, Tarn #1/#4, Cirque #1/1X/#2, Atlas #l/#lA, Meltwater #1/#2 (See
attached mud weight versus depth graphs for these wells), reveal no subsurface hazards such as abnormal
pressure or lost circulation zones. The Cirque #1 well did experience well control problems, but not because
of abnormal pressures. A Seismic Analysis was performed for the Cirque #3 well and Pore Pressure/Fracture
Gradient Curves derived. Again, no indications of abnormal pressure or weak formations were seen
particularly at shallow depths. The mud weights planned for Cirque #3 are conservatively based on those
used during drilling of the offsets. Prudent and precautionary drilling/tripping techniques will be emphasized
while drilling this well with specific regards to the potential shallow gas hazards which have been encountered
in the Cirque #1 and in the Tarn Wells 4 miles to the North.
Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal
well. Note that cement rinseate will not be in'ected down the dedicated dis osal well but will be rec cled or
held for an 0 en annulus. The Cirque #3 surface/intermediate casing annulus will be filled with diesel after
setting intermediate casing and prior to the drilling rig moving off of the well. If isolation is required per
regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the
production cement job to cover those formations.
PAl may request approval to inject or dispose of fluids in the Cirque #3 9-5/8" x 7" annulus at a later date.
This request would be made after sufficient data is available to meet the requirements of AOGCC's 20 AAC
25.080.
ORIGINAL
~
('
Phillips Alaska, Inc.
f
Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows:
FORMATION DEPTH (ss) UNCERTAINTY POSSIBLE FLUID EST. PORE
TYPE PRESSURE Dsi
Top West Sak Sand 1005' 50' 465
Base Permafrost 1140' 50' 528
Base West Sak Sand 1745' 50' Gas 807
(-80 (K-10) 2290' 50' 1060
(-40 (K-5) 3510' 50' 1825
Ice Berq 4050' 50' Gas 2000
Top Bermuda 5250' 50' Oil 2785
Base Bermuda 5370' 50' 2876
(-35 5375' 50' 2879
Too Albian 5485' 50' Oil 2966
Base Albian 5635' 50' 3135
TD 5810' 50' 3414
Formation Evaluation:
I.
Anticipated logging, coring and testing for this well is as follows:
II.
III.
IV.
Logging
Surface Interval (0 - Surface Casing setting depth)
LWD: GR / Res / PWD
8-1/2" Pilot Hole (Surface Casing setting depth to TD)
LWD: GR / Res / Density - Neutron / PWD
Wireline: Sonic / FMI
Drill Pipe Conveyed: MDT / CMR
Coring
Full Diameter 4" Core in the Bermuda (1 - 2, 90' cores)
Potential Rotary Sidewall Cores (wireline conveyed) in the event full core operations are unsuccessful
Mudlogging
Mudlogging service should be in operation from the base of the surface conductor casing to TD.
Service most likely will include Rap on 5' intervals, lithology, total gas, sample collection, gas analysis
of cuttings, gas chromatography, and HzS detection
Sixty-foot (60') wet and dry samples will be collected from surface to casing point @ +/-2140' TVD SS
Thirty-foot (30') wet and dry samples will be collected from +/- 2140' TVD SS to well TD.
Ten-foot (10') wet and dry samples, or continuous, collected across the Bermuda and Albian.
Flow Testing
Currently, Phillips plans to complete and test the Cirque 3 sidetrack not the Cirque 3 pilot hole.
However, if Phillips decides to complete and test the Cirque 3 pilot hole then the following would
apply:
Flow testing and pressure build-up tests will be used to determine formation properties and estimate
the commerciality of this exploratory well. A reservoir stimulation may be performed in the form of
an acid or frac treatment. The flow period will be determined on-site in response to analysis of initial
ORIGINAL
{ Phillips Alaska, Inc. (
flow period, PBU and fluid properties. The well will be flowed to temporary surface production
facilities consisting of gas separation and fluid storage tanks. Produced fluids will either be trucked to
an existing production facility or reinjected into the formation following completion of the flow testing
operations. Additional prospective intervals may be tested as described above or may be commingled
with the previously tested intervals. If commingling is chosen, production logging will be performed
during the flow test to determine the productivity of the individual zones.
ORIGINAL
f'
Phillips Alaska, Inc.
(
(
Cirque #3 Drilling Hazards S~mmary:
(to be posted in Rig Floor Doghouse Prior to Spud)
8" Casin Interval
Event
Conductor Broach
Risk Level
Low
Gas Hydrates
Moderate
Running Sands and Gravels
Low
Abnormal Pressure in
Surface Formations
Moderate
Lost Circulation
Low
8-1 2" Hole 7" Casin Interval
Event
Sticky clay and tight hole
first 2000' below shoe
Hole cleaning in long, high
an Ie tan ent
Hole swabbing on trips
Risk Level
Moderate
Moderate
Moderate
Thick, low PH mud after
drilling the Camp Sands
Moderate
Elevated Pressure in Iceberg
Formation
High
Abnormal Reservoir Pressure
Moderate
Hydrogen Sulfide gas
Low
Differential Sticking
Low
Lost circulation
Low
Miti ation Strate
Monitor cellar continuously during interval.
Mud gas detection, Increased mud weight,
Decreased mud viscosity, Increased circulating
times, Controlled drilling rates, Low mud
tem eratures Additions of Driltreat Lecithin.
Maintain planned mud parameters, Elevated mud
viscosi from s ud Hi h densi swee s.
Diverter drills, increased mud weight.
Reduced/Cautious trip speeds while drilling surface
hole. Geologist on location to assist in picking
surface casing shoe depth above the C80/K10
marker.
Reduced pump rates, mud rheology, lost circulation
material use of low densi cement slurries
M iti ation Strate
Attention to hole cleaning, PWD tools, wiper trips
Good drilling practices, high RPM, PWD Tools,
circulate 3-4 bottoms u rior to tri s flow checks
Reduced trip speeds (especially thru the C80 / Camp
Sands interval @ +/-2601' MD/2468' TVD), Mud
rheology, Proper hole filling (use of trip sheets),
Pum in out of hole Flow checks.
Raise PH to 10.5-11.0, add thinner prior to trips,
circulate above and below interval on trips in / out
of hole and when runnin casin .
Wellbore intersects the Iceberg @ +/-4582'
MD/4228' TVD, Frequent flow checks while drilling
this interval, PWD tools, Bar on location to weight
u
Well control drills, increased mud weight,
contin encies for to set casin strin .
H2S drills, detection systems, alarms, standard well
control ractices mud scaven ers
Good drilling practices, Mud lubes, Keep string
movin Avoid sto in w BHA across sands.
Reduced pump rates, reduced trip speeds, real time
equivalent circulating density (ECD) monitoring,
mud rheolo lost circulation material
ORIGINAL
(
Phil Ii ps
Alaska,
Plot Reterence is Cirque 3 Vcrsion 16.A.
Creoled by miChoel For: M Chambers:
Dole plotted: 11-0ec-2001
Structure: Cirque 3
Field: Exploration
Coord;no!e, ore in f.et relerence Còrque 3.
True Verticol Depths ore reference Est. (Ooyon
rüe
BAK!A
"-:;
"'n>'~
2550
2400
2250
2100
1950
1800
1650
1500
^
I 1350
,,-...,
-+-
Q)
Q) 1200
......
'--'"'
...c
-+-
\..... 1050
0
Z
900
750
600
450
300
150
0
150
1050
('
~
Inc.
Well; Cirque 3
Location: North Slope, Alaska
TO LOCATION:
1933' FSL, 1378' FEL
SEC. 21, T9N, R7E
Top Albian
C35
Base Bermuda
Target
TARGET LOCATION:
1662' FSL, 1273' FEL
SEC. 21, T9N, R7E
.C80 (K-10)
\~9 5/8 CSG
900
750
600
450
300
150
0
<- West (feet)
ORIGINAL
KOP
338.81 AZIMUTH
2188' (TO TARGET)
***Plane of Proposal***
ESTIMATED SURFACE
LOCATION:
377' FNL, 487' FEL
SEC. 28, T9N, R7E
150
~\
~
,i,.
Q'.'~
!ji&m
TRUE
(
" ~, ~, ~~,
C'ootod b, miehool For: M Chambers
Doto plotlod , , I -Doe-ZOOI
Structure: Cirque 3
PIO' Rof"oneo is Ci'quo 3 Vo"ion H6A
Field: Exploration
Coo'dino'o. 0" in loot 'ofo,one. Ci'qu. 3,
1,uo Vo";eol Dep'h. 0<0 "'o"neo Est. (Do,on "')"
0
350
700
1050
1400
1750
...--..
+- 2100
Q)
Q)
'+-
"--"'
2450
.£:
+-
Q..
Q)
0
0
()
+-
L
Q)
>
Q)
:J
L
f-
I
V
N'¡:¡¡'O;¡
ilAlrnI
'-$
I'll"}
RKB Elevotion: 178'
KOP
2,00
4,00
6,00
8.00
DLS: 2,00 deg per 100 ft
12,00
14,00 Top West Sok
16.00 Bose Permofrost DLS: 2.00 deg per 100 It
18,00
20.00
22.00
24.00
26.00
EOC
Base West Sak
~~
9 5/8 CSG
C80(K-10)
2800
3150
3500
C40 (K-5)
3850
4200
4550
TANGENT ANGLE
27.34 DEG
Iceberg
4900
5250
5600
5950
6300
0
350
2100
700
1050
1750
1400
'(
Alaska,
Inc.
Well: Cirque 3
Location: North Slope, Alaska
338.81 AZIMUTH
2188' (TO TARGET)
...Plane of Proposol."
Target
Bose Bermuda
C35
Top Albian
Base Albian
TO
2450
2800
3150
3500
3850
VertiGo I Section (f eet) - >
Azimuth 338,81 with reference 0.00 N, 0.00 E from Cirque 3
0""""",,-, -~', ,,::I"L
I " , r',1
,,( ø i i I~)¡ i j '~A
4200
4550
4900
5250
Created by michoel For: M Chambers
Dote plotted: 11-Dec-20D1
Structure: Cirque 3
Well: Cirque 3
¡Phillips Alaska, Ince!
Plot Reference is Cirque 3 Version IJ6A
Field: Exploration
Location: North Slope; Alaska:
Coordinates are in feet reference Cirque 3.
Vertical Depths are reference Est. (Doyon
i:I'Ü'E'}
==== If==" OF~ E COMM NT D TA ====
~.
----- Point ----- MO Inc Oir TVO North East V. Sect Oeg/100
KOP 500.00 0.00 338.81 500.00 0.00 0.00 0.00 0.00
C ¡Top West Sak 1189.64 13.79 338.81 1183.00 77.02 -29.86 82.61 2.00
::0
- - ! Base Permafrost 1329.54 16.59 338.81 1318.00 111 .20 -43.12 119.27 2.00
~
- - iEOC 1866.99 27.34 338.81 1815.70 298.36 -115.68 320.00 2.00
§:
¡ Base West Sak 1987.78 27.34 338.81 1923.00 350.08 -135.74 375.48 0.00
r-- :9 5/8 CSG 2432.45 27.34 338.81 2318.00 540.49 -209.57 579.70 0.00
C80 (K-10) 2601.31 27.34 338.81 2468.00 61 2.80 -237.60 657.25 - 0.00
C40 (K-5) 3974.73 27.34 338.81 3688.00 1200.90 -465.63 1288.01 0.00
-.
Iceberg 4582.63 27.34 338.81 4228.00 1461.21 -566.56 1567.20 0.00
Target 5933.51 27.34 338.81 5427.98 2039.67 - 790.85 2187.62 0.00
Base Bermuda 6068.62 27.34 338.81 5548.00 2097.52 -813.28 2249.67 0.00
C35 6074.25 27.34 338.81 5553.00 2099.93 -814.21 2252.25 0.00
Top Albian 6198.08 27.34 338.81 5663.00 2152.96 -834.77 2309.13 0.00
Base Albian 6366.94 27.34 338.81 5813.00 2225.26 -862.81 2386.68 0.00
TO 6566.94 27.34 338.81 5990.66 2310.91 -896.01 2478.53 0.00
(
(
Phillips Alaska, Inc.
Cirque 3
Cirque 3
Cirque 3
Exploration
North Slope, Alaska
PRO P 0 S A L
LIS TIN G
by
Baker Hughes INTEQ
Your ref: Cirque 3 Version #6.A
Our ref: prop4950
License:
Date printed: ll-Dec-200l
Date created: 7-Nov-200l
Last revised: ll-Dec-200l
Field is centred on n70 20 37.l00,w150 51 37.53
Structure is centred on 456236.l03,58909l4.340,999.00000,N
Slot location is n70 6 42.530,w150 21 18.502
Slot Grid coordinates are N 5890540.000, E 455748.000
Slot local coordinates are 377.18 S 485.98 W
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
ORIGINAL
(
(
Phillips Alaska, Inc. PROPOSAL LISTING Page 1
Cirque 3.Cirque 3 Your ref : Cirque 3 Version #6.A
Exploration,North Slope, Alaska Last revised : ll-Dec-2001
Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert
Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect
0.00 0.00 338.81 0.00 0.00 N 0.00 E 0.00 0.00
500.00 0.00 338.81 500.00 0.00 N 0.00 E 0.00 0.00 KOP
600.00 2.00 338.81 599.98 1.63 N 0.63 W 2.00 1. 75
700.00 4.00 338.81 699.84 6.51 N 2.52 W 2.00 6.98
800.00 6.00 338.81 799.45 14.63 N 5.67 W 2.00 15.69
900.00 8.00 338.81 898.70 25.99 N 10.08 W 2.00 27.88
1000.00 10.00 338.81 997.47 40.58 N 15.73 W 2.00 43.52
1100.00 12.00 338.81 1095.62 58.37 N 22.63 W 2.00 62.60
1189.64 13.79 338.81 1183.00 77.02 N 29.86 W 2.00 82.61 Top West Sak
1200.00 14.00 338.81 1193.06 79.34 N 30.76 W 2.00 85.10
1300.00 16.00 338.81 1289.64 103.47 N 40.12 W 2.00 110.98
1329.54 16.59 338.81 1318.00 111.20 N 43.12 W 2.00 119.27 Base Permafrost
1400.00 18.00 338.81 1385.27 130.73 N 50.69 W 2.00 140.21
1500.00 20.00 338.81 1479.82 161. 08 N 62.46 W 2.00 172.77
1600.00 22.00 338.81 1573.17 194.49 N 75.41 W 2.00 208.60
1700.00 24.00 338.81 1665.21 230.92 N 89.54 W 2.00 247.67
1800.00 26.00 338.81 1755.84 270.33 N 104.81 W 2.00 289.93
1866.99 27.34 338.81 1815.70 298.36 N 115.68 W 2.00 320.00 EOC
1987.78 27.34 338.81 1923.00 350.08 N 135.74 W 0.00 375.48 Base West Sak
2000.00 27.34 338.81 1933.85 355.31 N 137.77 W 0.00 381.09
2432.45 27.34 338.81 2318.00 540.49 N 209.57 W 0.00 579.70 9 5/8" CSG
2500.00 27.34 338.81 2378.00 569.42 N 220.78 W 0.00 610.72
2601.31 27.34 338.81 2468.00 612.80 N 237.60 W 0.00 657.25 C80 (K-10)
3000.00 27.34 338.81 2822.15 783.52 N 303.80 W 0.00 840.36
3500.00 27.34 338.81 3266.30 997.62 N 386.81 W 0.00 1069.99
3974.73 27.34 338.81 3688.00 1200.90 N 465.63 W 0.00 1288.01 C40 (K-5)
4000.00 27.34 338.81 3710.45 1211.73 N 469.83 W 0.00 1299.62
4500.00 27.34 338.81 4154.60 1425.83 N 552.84 W 0.00 1529.26
4582.63 27.34 338.81 4228.00 1461.21 N 566.56 W 0.00 1567.20 Iceberg
5000.00 27.34 338.81 4598.75 1639.93 N 635.86 W 0.00 1758.89
5500.00 27.34 338.81 5042.90 1854.04 N 718.87 W 0.00 1988.52
5933.51 27.34 338.81 5427.98 2039.67 N 790.85 W 0.00 2187.62 Target
5933.53 27.34 338.81 5428.00 2039.67 N 790.85 W 0.00 2187.63 Cirque 3 Berm TGT Rvsd 15Nov01
6000.00 27.34 338.81 5487.05 2068.14 N 801. 88 W 0.00 2218.16
6068.62 27.34 338.81 5548.00 2097.52 N 813 .28 W 0.00 2249.67 Base Bermuda
6074.25 27.34 338.81 5553.00 2099.93 N 814.21 W 0.00 2252.25 C35
6198.08 27.34 338.81 5663.00 2152.96 N 834.77 W 0.00 2309.13 Top Albian
6366.94 27.34 338.81 5813 .00 2225.26 N 862.81 W 0.00 2386.68 Base Albian
6500.00 27.34 338.81 5931.20 2282.24 N 884.90 W 0.00 2447.79
6566.94 27.34 338.81 5990.66 2310.91 N 896.01 W 0.00 2478.53 TD
All data is in feet unless otherwise stated.
Coordinates from Cirque 3 and TVD from Est. (Doyon 141) (178.00 Ft above Mean Sea
Bottom hole distance is 2478.53 on azimuth 338.81 degrees from wellhead.
Total Dogleg for wellpath is 27.34 degrees.
Vertical section is from wellhead on azimuth 338.81 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
Level) .
ORIGINAL
(
(
Phillips Alaska. Inc.
Cirque 3,Cirque 3
Exploration,North Slope, Alaska
PROPOSAL LISTING Page 2
Your ref: Cirque 3 version i6.A
Last revised: Il-Dec-2001
Comments in wellpath
--------------------
--------------------
MD
TVD
Rectangular Coords.
Comment
-----------------------------------------------------------------------------------------------------------
500.00 500.00 0.00 N 0.00 E KOP
1189.64 1183.00 77.02 N 29.86 W Top West Sak
1329.54 1318.00 111. 20 N 43.12 W Base Permafrost
1866.99 1815.70 298.36 N 115.68 W EOC
1987.78 1923.00 350.08 N 135.74 W Base West Sak
2432.45 2318.00 540.49 N 209.57 W 9 5/8" CSG
2601.31 2468.00 612.80 N 237.60 W C80 (K-10)
3974.73 3688.00 1200.90 N 465.63 W C40 (K-5)
4582.63 4228.00 1461.21 N 566.56 W Iceberg
5933.51 5427.98 2039.67 N 790.85 W Target
5933.53 5428.00 2039.67 N 790.85 W Cirque 3 Berm TGT Rvsd 15Nov01
6068.62 5548.00 2097.52 N 813 .28 W Base Bermuda
6074.25 5553.00 2099.93 N 814 .21 W C35
6198.08 5663.00 2152.96 N 834.77 W Top Albian
6366.94 5813.00 2225.26 N 862.81 W Base Albian
6566.94 5990.66 2310.91 N 896.01 W TD
Casing positions in string 'A'
------------------------------
------------------------------
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
-----------------------------------------------------------------------------------------------------------
0.00
0.00
O.OON
O.OOE
2432.45
2318.00
540.49N
209.57W
9 5/8" CSG
Targets associated with this wellpath
-------------------------------------
-------------------------------------
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
-----------------------------------------------------------------------------------------------------------
Cirque 3 Berm TGT Rv 454969.000,5892584.000,0.0000
5428.00
2039.67N
790.85W
7-Nov-2001
ORIGINAL
{
(
Phillips Alaska, Inc.
Cirque 3
Cirque 3
Cirque 3
Exploration
North Slope, Alaska
PRO P 0 SA L
LIS TIN G
by
Baker Hughes INTEQ
Your ref: Cirque 3 Version #6.A
Our ref: prop4950
License:
Date printed: ll-Dec-2001
Date created: 7-Nov-2001
Last revised: ll-Dec-2001
Field is centred on n70 20 37.100,w150 51 37.53
Structure is centred on 456236.103,5890914.340,999.00000,N
Slot location is n70 6 42.530,w150 21 18.502
Slot Grid coordinates are N 5890540.000, E 455748.000
Slot local coordinates are 377.18 S 485.98 W
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
ORIGINAL
('
,(
Phillips Alaska. Inc. PROPOSAL LISTING Page 1
Cirque 3.Cirque 3 Your ref : Cirque 3 Version #6.A
Exploration.North Slope, Alaska Last revised : 11-Dec-200l
Measured Inc lin Azimuth True Vert R E C TAN GULAR G RID COO R D S G E 0 G RAP H I C
Depth Degrees Degrees Depth COO R D I N ATE S Easting Northing COO R DIN ATE S
0.00 0.00 338.81 0.00 O.OON O.OOE 455748.00 5890540.00 n70 6 42.53 w150 21 18.50
500.00 0.00 338.81 500.00 O.OON O.OOE 455748.00 5890540.00 n70 6 42.53 w150 21 18.50
600.00 2.00 338.81 599.98 1.63N O. 63W 455747.38 5890541.63 n70 6 42.55 w150 21 18.52
700.00 4.00 338.81 699.84 6.51N 2.52W 455745.52 5890546.52 n70 6 42.59 w150 21 18.57
800.00 6.00 338.81 799.45 14 .63N 5.67W 455742.41 5890554.66 n70 6 42.67 w150 21 18.67
900.00 8.00 338.81 898.70 25.99N 10.08W 455738.07 5890566.05 n70 6 42.79 w150 21 18.79
1000.00 10.00 338.81 997.47 40.58N 15.73W 455732.50 5890580.67 n70 6 42.93 w150 21 18.96
1100.00 12.00 338.81 1095.62 58.37N 22.63W 455725.71 5890598.49 n70 6 43.10 w150 21 19.16
1189.64 13.79 338.81 1183.00 77.02N 29.86W 455718.58 5890617.19 n70 6 43.29 w150 21 19.36
1200.00 14.00 338.81 1193.06 79.34N 30.76W 455717.70 5890619.51 n70 6 43.31 w150 21 19.39
1300.00 16.00 338.81 1289.64 103.47N 40.12W 455708.48 5890643.69 n70 6 43.55 w150 21 19.66
1329.54 16.59 338.81 1318.00 111.20N 43.12W 455705.53 5890651.44 n70 6 43.62 w150 21 19.75
1400.00 18.00 338.81 1385.27 130.73N 50.69W 455698.07 5890671.01 n70 6 43.82 w150 21 19.97
1500.00 20.00 338.81 1479.82 161.08N 62.46W 455686.48 5890701.43 n70 6 44.11 w150 21 20.31
1600.00 22.00 338.81 1573.17 194.49N 75.41W 455673.72 5890734.91 n70 6 44.44 w150 21 20.68
1700.00 24.00 338.81 1665.21 230.92N 89.54W 455659.81 5890771.41 n70 6 44.80 w150 21 21. 09
1800.00 26.00 338.81 1755.84 270.33N 104.81W 455644.76 5890810.90 n70 6 45.19 w150 21 21. 53
1866.99 27.34 338.81 1815.70 298.36N 115. 68W 455634.05 5890838.99 n70 6 45.46 w150 21 21. 84
1987.78 27.34 338.81 1923.00 350.08N 135.74W 455614.30 5890890.83 n70 6 45.97 w150 21 22.42
2000.00 27.34 338.81 1933.85 355.31N 137. 77W 455612.30 5890896.07 n70 6 46.02 w150 21 22.48
2432.45 27.34 338.81 2318.00 540.49N 209.57W 455541.57 5891081.64 n70 6 47.85 w150 21 24.56
2500.00 27.34 338.81 2378.00 569.42N 220.78W 455530.53 5891110.63 n70 6 48.13 w150 21 24.88
2601.31 27.34 338.81 2468.00 612.80N 237.60W 455513 .96 5891154.10 n70 6 48.56 w150 21 25.37
3000.00 27.34 338.81 2822.15 783.52N 303.80W 455448.76 5891325.18 n70 6 50.24 w150 21 27.28
3500.00 27.34 338.81 3266.30 997.62N 386.81W 455366.98 5891539.74 n70 6 52.34 w150 21 29.68
3974.73 27.34 338.81 3688.00 1200.90N 465.63W 455289.35 5891743.45 n70 6 54.34 w150 21 31.96
4000.00 27.34 338.81 3710.45 1211.73N 469.83W 455285.21 5891754.30 n70 6 54.45 w150 21 32.08
4500.00 27.34 338.81 4154.60 1425.83N 552.84W 455203.44 5891968.85 n70 6 56.55 w150 21 34.48
4582.63 27.34 338.81 4228.00 1461.21N 566.56W 455189.93 5892004.31 n70 6 56.90 w150 21 34.87
5000.00 27.34 338.81 4598.75 1639.93N 635.86W 455121.67 5892183.41 n70 6 58.66 w150 21 36.88
5500.00 27.34 338.81 5042.90 1854.04N 718. 87W 455039.90 5892397.97 n70 7 00.76 w150 21 39.28
5933.51 27.34 338.81 5427.98 2039.67N 790.85W 454969.00 5892583.99 n70 7 02.59 w150 21 41.36
5933.53 27.34 338.81 5428.00 2039.67N 790.85W 454969.00 5892584.00 n70 7 02.59 w150 21 41.36
6000.00 27.34 338.81 5487.05 2068.14N 801.88W 454958.13 5892612.52 n70 7 02.87 w150 21 41.68
6068.62 27.34 338.81 5548,00 2097.52N 813.28W 454946.91 5892641.97 n70 7 03.16 w150 21 42.01
6074.25 27.34 338.81 5553.00 2099.93N 814.21W 454945.99 5892644.38 n70 7 03.18 w150 21 42.03
6198.08 27.34 338.81 5663.00 2152.96N 834.77W 454925.73 5892697.52 n70 7 03.70 w150 21 42.63
6366.94 27.34 338.81 5813 .00 2225.26N 862.81W 454898.12 5892769.98 n70 7 04.41 w150 21 43.44
6500.00 27.34 338.81 5931.20 2282.24N 884.90W 454876.36 5892827.08 n70 7 04.97 w150 21 44.08
6566.94 27.34 338.81 5990.66 2310.91N 896.01W 454865.41 5892855.81 n70 7 05.26 w150 21 44.40
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from Cirque 3 and TVD from Est. (Doyon 141) (178.00 Ft above Mean Sea Level).
Bottom hole distance is 2478.53 on azimuth 338.81 degrees from wellhead.
Total Dogleg for wel1path is 27.34 degrees.
Vertical section is from wellhead on azimuth 338.81 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
ORIGINAL
(
f
Phillips Alaska. Inc.
Cirque 3,Cirque 3
E^~loration,North Slope. Alaska
PROPOSAL LISTING Page 2
Your ref: Cirque 3 Version #6.A
Last revised: Il-Dec-2001
Comments in wellpath
--------------------
--------------------
MD
TVD
Rectangular Coords.
Comment
-----------------------------------------------------------------------------------------------------------
500.00 500.00 O.OON O.OOE KOP
1189.64 1183.00 77.02N 29.86W Top West Sak
1329.54 1318.00 111. 20N 43.12W Base Permafrost
1866.99 1815.70 298.36N 115.68W EOC
1987.78 1923.00 350.08N 135.74W Base West Sak
2432.45 2318.00 540.49N 209.57W 9 5/8" CSG
2601.31 2468.00 612.80N 237.60W C80 (K-IO)
3974.73 3688.00 1200.90N 465.63W C40 (K-5)
4582.63 4228.00 1461.21N 566.56W Iceberg
5933.51 5427.98 2039.67N 790.85W Target
5933.53 5428.00 2039.67N 790.85W Cirque 3 Berm TGT Rvsd 15Nov01
6068.62 5548.00 2097.52N 813.28W Base Bermuda
6074.25 5553.00 2099.93N 814.21W C35
6198.08 5663.00 2152.96N 834.77W Top Albian
6366.94 5813 .00 2225.26N 862.81W Base Albian
6566.94 5990.66 2310.91N 896. 01W TD
Casing positions in string 'A'
------------------------------
------------------------------
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
-----------------------------------------------------------------------------------------------------------
0.00
0.00
O.OON
O.OOE
2432.45
2318.00
540.49N
209.57W
9 5/8" CSG
Targets associated with this we11path
-------------------------------------
-------------------------------------
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
---------------------------------------------------------------------------------------------------------.--
Cirque 3 Berm TGT Rv 454969.000,5892584.000,0.0000
5428.00
2039.67N
790.85W
7-Nov-2001
ORIGINAL
Cil'1ue 3
Proposed Plug Back Schematic (Sheet 1 of 2)
Exploration Well - Confidential
Conductor:
16",62.58#
Set @ +1-115' MD
TAM Port Collar:
9-5/8" BTC Box x Pin
Set @ +1- 1000' MD
Surface Casing
9-5/8" 40# L-80 BTC
Float Collar to Surface
Float Collar:
Weatherford - Single Valve
9-5/8" 32-53# BTC Box x Pin
(2) Joints Casing:
9-5/8" 40# L-80 BTC
Float Shoe:
Weatherford - Single Valve
9-5/8" 32-53# BTC Box Up
~
TD 12-1/4" Hole @ 2432' MD, 2318' TVD
(Above the C-80)
TD 8-1/2" Hole @ 6567' MD, 5991' TVD
. Sidetrack Kickoff
. Plug
L
~( PHILLIPS Alaska, Inc.
~ A Subsidiary of PHIlliPS PETROLEUM COMPANY
300' Sidetrack Kickoff Plug positioned wI Top @
2515' MD, 2391' TVD.
Well Bore to be P&A'd as per AOGCC Regulations -
Cement volumes and tops TBD based on Hydrocarbon
Shows
Cirque 3 PB Schematic v1.0
prepared by Mark Chambers
12/12/01
Ci\ "Iue 3
Proposed Completion Schematic (Sheet 1 of 2)
Exploration Well - Confidential
~( PHILLIPS Alaska, Inc.
~ A Subsidiary of PHilLIPS PETROLEUM COMPANY
Conductor:
16",62.58#
Set @ +1- 120' MD
--
L
Tubing Hanger:
FMC Gen V Hanger wI 3-1/2" L-80 EUE 8rd Mod pup joint installed
Tubing: (1) Joint 3-1/2" L-80 EUE 8rd Mod installed below tubing hanger
Spaceout Tubing Pups ( as required): 3-1/2",9.3#, L-80, EUE 8rd
Mod
Tubing ( as required): 3-1/2",9.3#, L-80, EUE 8rd Mod
TAM Port Collar:
9-5/8" BTC Box x Pin
Set @ +1- 1000' MD
Landing Nipple:
3-1/2" Camco 'DS' wI 2.875" No-Go Profile
Tubing ( as required): 3-1/2", 9.3#, L-80, EUE 8rd Mod
Surface Casing
9-5/8" 40# L-80 BTC
Float Collar to Surface
Gas Lift Mandrel: 3-1/2" x 1" Cameo 'KBUG' GLM wI dummy valves
and latches, 6-foot handling pups installed on top and bottom.
Tubing ( as required): 3-1/2", 9.3#, L-80, EUE 8rd Mod
Float Collar:
Weatherford - Single Valve
9-5/8" 32-53# BTC Box x Pin
Gas Lift Mandrel: 3-1/2" x 1" Camco 'KBUG' GLM wI dummy valves
and latches (Max. OD -", ID_"), 6-foot handling pups installed on top
and bottom,
(2) Joints Casing:
9-5/8" 40# L-80 BTC
Tubing ( as required): 3-1/2", 9.3#, L-80, EUE 8rd Mod
Float Shoe:
Weatherford - Single Valve
9-5/8" 32-53# BTC Box Up
Landing Nipple: 3-1/2" Halliburton 'X' Nipple wI 2.813" Selective Profile.
TD 12-1/4" Hole @ 2432' MD, 2318' TVD
(Above the C-80)
Tubing I Pup Joints ( as required): 3-1/2",9.3#, L-80, EUE 8rd Mod
PBR 1 Packer Assembly by Baker Oil Tools:
Packer setting depth TBD.
See Sheet 2 for Lower ComDletion ( Packer Assembly and Below)
Production Casing
7" 26# L-80 BTC
Float Collar to Surface
Float Collar:
Weatherford - Single Valve
7" 20-35# BTC Box x Pin
(2) Joints Casing:
7" 26# L-80 BTC
Float Shoe:
Weatherford - Single Valve
7" 20-35# BTC Box Up
Cirque 3 Schematic v2,O
prepared by Mark Chambers
12/07/01
TD 8-1/2" Hole @ 6567' MD, 5991' TVD
C¡("'tue 3
Planned Completion Schematic (Sheet 2 of 2)
Exploration Well - Confidential
W,..
PHIL.. ~ PHilliPS Alaska, Inc.
W A Subsidiary of PHILLIPS PETROLEUM COMPANY
Production Casing
7" 26# L-80 BTC
Float Collar to Surface
PBR I Packer Assembly, by Baker Oil Tools, consisting ofthe following:
Packer setting depth TBD.
(1) Handling Pup Joint:
3-1/2",9.3#, L-80, EUE 8rd Mod (6 foot length)
(1) Polished Bore Recepticle with Seal Stem:
Baker Model '80-40' PBR, 12 ft Length wI 10ft of Seal Travel, Pinned
to Shear from PBR with 39 KSI overpull
(1) Tubing Anchor:
Baker, Model'KBH-22 'Anchor Seal Assembly
(1) Packer:
Baker Model'SAB-3' Hydraulic Set Permanent Packer, pinned for 1100
psi shear (Fully Set @ 2500 psi)
(1) Crossover Sub:
Baker, 4" LTC Box x 3-1/2" EUE 8rd Pin
(1) Handling Pup Joint:
3-1/2", 9.3#, L-80, EUE 8rd Mod (6 foot length)
Tubing ( 1 Joint): 3-1/2",9.3#, L-80, EUE 8rd Mod
Gas Lift Mandrel: 3-1/2" x 1" Cameo 'KBUG' GLM wI dummy valves and
latches, 6-foot handling pups installed on top and bottom.
Tubing I Pup Joints ( as required): 3-1/2",9.3#, L-80, EUE 8rd Mod
Gas Lift Mandrel: 3-1/2" x 1" Cameo 'KBUG' GLM wI dummy valves and
latches, 6-foot handling pups installed on top and bottom,
Tubing I Pup Joints ( as required): 3-1/2",9.3#, L-80, EUE 8rd Mod
Landing Nipple: 3-1/2" Halliburton 'XN' Nipple wI 2.750" No-Go Profile.
Tubing I Pup Joints ( as required): 3-1/2",9.3#, L-80, EUE 8rd Mod
Shear Out Sub I Wireline Re-Entry Guide: Provided by Baker Oil Tools
wI 3-1/2" EUE 8rd Box Up.
Float Collar:
Weatherford - Single Valve
7" 20-35# BTC Box x Pin
(2) Joints Casing:
7" 26# L-80 BTC
Float Shoe:
Weatherford - Single Valve
7" 20-35# BTC Box Up
PBTD (Top of Float Collar) @ +1- 6457' MD, 5893' TVD
656T;? ~ri:~~~1~I~D 0 RIG I N A L
Cirque 3 Schematic v2.0
prepared by Mark Chambers
12/07/01
Schlumberger
Preliminary Job Design based on limited input data. For estimate purposes only.
Rig: Doyon 141
Location: Exploration
Client: Phillips Alaska, Inc.
Revision Date: 12/12/2001
Prepared by: Chris Avant
Location: Anchorage, AK
Phone: (907) 265-6067
Mobile: (907) 223-8808
email: CAvant@slb.com
Volume Calculations and Cement Systems
Volumes are based on 350% excess in the permafrost and 45% excess below the
permafrost. The top of the tail slurry is designed to be at 1,350' MO.
Lead Slurry Minimum pump time: 200 min. (pump time plus 90 min.)
ARCTICSET Lite @ 10.7 ppg, Class G + 50%0124, 9%(BWOW)044, 0.6%046,
30%053, 1.5%81, 1.5%079, 0.5%065 - 4.44 ft3/sk
0.7632 fe/ft x (115') x 1.00 (no excess) =
0.3132 ft3/ft x (1330" 115') x 4.50 (350% excess) =
0.3132 fe/ft x (1350" 1330') x 1.45 (45% excess) =
87.8 fe + 1712.4 fe+ 9.1 fe =
1809.3 ft3/ 4.44 fe/sk =
Round up to 410 sks
87.8 fe
1712.4 ft3
9.1 fe
1809.3 fe
407.5 sks
< TOC at Surf ace
Previous Csg.
< 16",62.6# casing
at 115' MD
< Base of Permafrost at
1,330' MD (1,318' lVD)
< Top of Tail at
1 ,350' MD
< 9 5/8", 40.0# casing
in 12 1/4" OH
TO at 2,432' MD
(2,318' lVD)
.
Mark of Schlumberger
Have 300 sks of additional Lead on location for Top Out stage, if necessary.
Tail Slurry Minimum pump time: 140 min. (pump time plus 90 min.)
LiteCRETE @ 12.0 ppg - 2.40 ft3/sk
0.3132 fe/ft x (2432" 1350') x 1.45 (45% excess) =
0.4257 fe/ft x 80' (Shoe Joint) =
491.4 fe + 34.1 fe =
525.5 ft3/ 2.4 ft3/sk =
Round up to 220 sks
491.4 fe
34.1 fe
525.5 fe
219 sks
BHST = 56°F, Estimated BHCT = 54°F.
(BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost)
PUMP SCHEDULE
Stage
Pump Rate
(bpm)
Stage
Volume
Cumulative
Stage Time Time
(min)
(bbl) (min)
CW 1 00 6 50 8.3 8.3
Drop Bottom Plug 3.0 11.3
MudPUSH XL 6 50 8.3 19.6
Lead Slurry 6 324 54.0 73.6
Tail Slurry 6 94 15.7 89.3
Drop Top Plug 3.0 92.3
Displacement 6 158 26.3 118.6
Slow Rate 3 20 6.7 125.3
MUD REMOVAL
Recommended Mud Properties: 10.2 ppg, Pv < 15, T y < 15. As thin and light as possible
to aid in mud removal during cementing.
Spacer Properties: 10.5 ppg MudPUSH* XL, Pv ~ 17-21, T y ~ 20-25
Centralizers: Recommend 1 per joint across zones of interest for proper cement
placement.
ORIGINAL
S chi um be rger
Preliminary Job Design based on limited input data. For estimate purposes only.
Rig: Doyon 141
Location: Exploration
Client: Phillips Alaska, Inc.
Revision Date: 12/12/2001
Prepared by: Chris Avant
Location: Anchorage, AK
Phone: (907) 265-6067
Mobile: (907) 223-8808
email: CAvant@slb.com
Volume Calculations and Cement Systems
Volumes are based on 75% excess in the permafrost and 75% excess below the
permafrost. The top of the tail slurry is designed to be at 5,134' MD.
Lead Slurry Minimum pump time: 170 min. (pump time plus 90 min.)
13.0 ppg Class G + 0.04% 0800 + 0.2% 0046 + 0.3% 0065 + 8.0% 0020 + 0.6°10 0167 -
1.99 ft3/sk
0.1585 ft3/ft x (0') x 1.00 (no excess) =
0.1268 ft3/ft x (1330" 2432') x 1.75 (75% excess) =
0.1268 fe/ft x (5134" 1330') x 1.75 (75% excess) =
0 fe + 0 fe + 299.8 fe =
299.8 fe / 1.99 fe/sk =
Round up to 160 sks
0 ft3
Ofe
299.8 fe
299.8 ft3
150.7sks
Previous Csg.
< 9-5/8", 40 #/ft Casing
at 2,432' MD (2318' ìVD)
< Top of Lead at
3783' MD
< Top of Iceberg at
4583' MD (4228' ìV D)
< Top of Tail at
5,134' MD
< Top of Bermuda at
5934' MD (5428' ìV D)
< 7",26.0# casing
in 8 1/2" OH
TO at 6,567' MD
(5,991' ìVD)
.
Mark of Schlumberger
Have 110 sks of additional Lead on location for Top Out stage, if necessary.
Tail Slurry Minimum pump time: 160 min. (pump time plus 90 min.)
15.8 ppg GasBLOK - Class G + 3.0% 0053 + 2.0 gps D600G + 0.1 % 0800 + 0.2% 0047
+ 0.6%0065 - 1.2 ft3/sk
0.1268 fe/ft x (6567" 5134') x 1.75 (75% excess) =
0.2148 fe/ft x 80' (Shoe Joint) =
318 fe + 17.2 fe =
335.2 ft3/ 1.2 fe/sk =
Round up to 280 sks
318fe
17.2 fe
335.2 fe
279.3 sks
BHST = 151°F, Estimated BHCT = 116°F.
(BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost)
PUMP SCHEDULE
Stage
Pump Rate
(bpm)
Stage
Volume
(bbl)
Cumulative
Stage Time Time
(min) (min)
CW 1 00 5 50 10.0 10.0
Drop Bottom Plug 3.0 13.0
MudPUSH XL 5 50 10.0 23.0
Lead Slurry 5 57 11.4 34.4
Tail Slurry 5 60 12.0 46.4
Drop Top Plug 3.0 49.4
Displacement 5 228 45.6 95.0
Slow Rate 3 20 6.7 101.7
MUD REMOVAL
Recommended Mud Properties: 10.7 ppg, Pv < 15, Ty < 15. As thin and light as possible
to aid in mud removal during cementing.
Spacer Properties: 12.0 ppg MudPUSH* XL, Pv ~ 17-21, T y ~ 20-25
Centralizers: Recommend 1 per joint across zones of interest for proper cement
placement.
ORIGINAL
(
(
PHILLIPS PETROLEUM COMPANY
To:
Greg Keith
Laurel Alexander
Mark Chambers
A TO-1458
A TO-1456
A TO-1566
From:
Kathy Heinlein
ATO-1346
Subject:
Pre-Drill Seismic Pore Pressure Prediction for Proposed Well
Location: Cirque #3
Date:
December 2, 2001
NFID
NT!
Summary
Seismic velocity data was used to predict pore pressures likely to be encountered at the
Cirque #3 proposed well location. A local compaction trend and a local velocity to
pressure gradient translation trend model was established using control from the Cirque
#2 offset well. The trends calculated at Cirque #2 were compared to trends observed at
Tarn and Meltwater and found to be similar.
The local compaction trend and translation trend model established from the existing
wells was applied to velocities from 3D seismic data to predict pore pressures. The
predictions show no apparent shallow hazards or large pressure anomalies at the
proposed well location.
Seismic Processin~
The accuracy of seismic geopressure analysis depends critically on the accuracy of the
input velocity field. The velocities used were generated using Phillips' AVEL program,
an automated high-resolution velocity analysis program developed by ARCO
Exploration and Production Technology. This process produces a very accurate velocity
field defined at every sample in time and laterally along each seismic line. The output
RMS velocities were smoothed over 9 COPs to minimize instabilities in the velocity field
that might result from noise, lack of signal or variations in COP fold.
ORIGINAL
(
f
Pressure Prediction Procedure:
The Cirque #2 offset well was used to establish both a local normal compaction trend
line and local velocity vs. pressure translation trend model. This model is similar to the
regional models used previously at Tarn and Meltwater.
Procedure
1.) Normal Compaction Trend Lines (NCTL) were calculated for a series of 3D seismic
lines from the Merged Tarn-Midtarn-Meltwater 3D seismic dataset. The slope of the
individual seismic NCTLs matched the slope calculated at Cirque #2, but the
intercepts varied slightly from the Cirque #2 NCTL. This is not unexpected as the
seismic velocity measures a larger component of horizontal velocity vs the well sonic
log which measures primarily vertical velocity. The NCTL calculated from the Cirque
#2 sonic log has an intercept of 148; the 3D seismic lines have an average intercept
of 160. It was verified that the slope of 160 on the seismic NCTL gave the most
accurate pressure prediction from seismic velocities at the Cirque #2 well. The slope
of the NCTL line (for both sonic log and seismic data) is ' 4.5e-5.
2.) The difference between interval transit times (ITT), recorded by wireline sonic logs
(~T) in the existing wells or by seismic velocities in the proposed wells, and the
interval transit times predicted by a downward extension of the NCTL were
measured. These values are the travel time differences, ~~ T.
3.) A translation trend model was established by comparing transit time differences
(~~ T) to mud weights. This model calculates pressure gradients (PP) using the
equation
PP = C2*~LlT**2 + C1*~~T + CO
Where C2 = -1.34-5, C1 = .0062, CO = .465
4.) Fracture gradients were calculated using the Eaton Method. Inputs are the bulk
density, the calculated pore pressure gradient profile, and a Poisson's Ratio profile
(from a West Cameron model).
ORIGINAL
(
(
Cirque #2:
Figure #1 is the pore pressure gradient calculation for Cirque #2. The left side is the
wireline sonic DT (black curve) with the NCTL (red line). The right side is the pore
pressure gradient calculation (blue curve), actual mud weight (green curve), and the
calculated fracture gradient (red curve). Casing points, areas of hole problems,
formation tops, and lithology changes are as labeled.
A thin zone of over-pressured gas-charged sand was encountered in the Cirque #2 well
at 2171 ft SSTVD (K-10). Similar shallow gas-bearing zones below the permafrost layer
are the suspected cause of the blow-out at the Cirque #1 well. Over-pressured free gas
may have been encountered in approximately this same interval below permafrost, and
additionally gas hydrates may have melted within the permafrost layer as a result of the
gas returns from this interval.
A false pressure increase is noted at approximately 6532 ft SSTVD. This apparent
pressure increase is actually due to a change in lithology which results in slower
velocity.
Seismic Pore Pressure Prediction (No Shallow Hazards Observed),,;,
Pressure gradients were predicted from seismic velocities in a 3D cube surrounding the
proposed Cirque #3 well location.
This report includes displays in time and depth of pressure gradient predictions on 3D
inlines and 3D crosslines at the surlace and bottom hole locations, in addition to time
and depth displays of pressure along the proposed deviated borepath.
Predicted Pore Pressure Gradient Displays in De~
Figure # Seismic Line Well Name
2 IL 4989 Cirque #3 Surlace Location
4 XL 10583 Cirque #3 Surlace Location
6 IL 4966 Cirque #3 TO Location
8 XL 10561 Cirque #3 TO Location
10 3D Traverse Along Cirque #3 Proposed Borepath
Predicted Pore Pressure Gradient Displays in Time with Migrated Time Overlay:
Figure # Seismic Line Well Name
3 IL 4989 Cirque #3 Surlace Location
5 XL 10583 Cirque #3 Surlace Location
7 IL 4966 Cirque #3 TO Location
9 XL 10561 Cirque #3 TO Location
11 3D Traverse Along Cirque #3 Proposed Borepath
ORIGINAL
('
(
Warmer colors indicate higher predicted mud weights (pore pressure gradients).
No Shallow Hazards or areas of high pressure at depth were observed.
Pore Pressure Gradient Prediction at Proposed Well Location:
Figure # Seismic Line Well Name
12 IL 4989, XL 10583 Cirque#3 Surface Location
13 IL 4966, XL 10561 Cirque #3 TO Location
The Potential for the Presence of Gas Hydrates and Seismic Pressure Prediction:
Gas-charged sands within the permafrost zone are thought to have contributed to the
blow-out at the Cirque #1 well. A thin-zone of over-pressured gas-charged sands was
observed at the base of permafrost in the Cirque #2 well. Previous analysis (Heinlein,
2000) shows that there is no apparent indication of the presence of gas hydrates within
the permafrost layer on either the 20 or the 30 seismic data in the area surrounding the
Cirque wells, and that gas-charged sands sitting immediately below the permafrost (in
the K-10 interval) may not appear as a potential pressure anomaly on 30 seismic.
Conclusions:
1.) There are no apparent shallow hazards at the proposed Cirque #3 well location.
2.) The NCTL and Translational Trend Model calculated at the Cirque #2 well are
similar to NCTLs and Translational Trend Models calculated at Tarn and Meltwater.
3.) A thin zone of overpressured gas-charged sands was encountered below permafrost
at the Cirque #2 well. There is the possibility that gas-charged sands exist in this
interval in the vicinity of the proposed Cirque #3 well location, but may not be
apparent on pressure sections predicted from seismic data.
If there are any further questions, please contact me at (907) 263-4761 or via email at
kheinle@ppco.com.
ORIGINAL
(
Kathy Heinlein
(
ORIGINAL
Project Cirque
Well: Cirque 2
NCTL: 148-4.5e-5
12/02/01
K. Heinlein
Cirque 2
DEPTH (D81um ¡clio M$L)
-170
FEET
-170
II
2000
3000
6000
7000
7000
7577
40 60 80 100 120 140
NCn Intercept aI: GL = 14*
Loglilfilhmic Slope = -Ue-8§
... CaaingDepUI * Kick I Flow
+ Repeal: Formation Tellt X Drill Stem Test
A Production Prellllure I!I Leak-off Test
!'21 Lost Circulation Zonell - Formation Top
... Stuck Pipe Location , Sidetraall Location
:z Freeform
--€<--
---*-
--6-
Mud
7677
14 16 16 17 18 19 20
PPG
(Sonic litH: 14*-451':-5 _UDEF, Top Trend Model: PUESTOtEIIE)
WEST _CAMERON)
Figure 1
1n.. 5.$PL.PPC
D
E
p
T
II
fII 4000.0
Cross Section: IL49S9
Method: Trend Curve
NCTL: 1
Model: Pleistocene
12/02/01
K. Heinlein
SURFACE LOCATION
I
w
MIL 0.0
1000.0
2000,0
3000,0
5000,0
0000,0
7000,0
0000,0
COP Interval = no ft
E
pp~
2
T
I
t.I 000,0
E
I"'¡ 900,0
Cross Section: IL4989
Method: Trend Curve
NCTL: 160-4.5-5
Model: Pleistocene
12/02/01
K. Heinlein
SURFACE LOCATION
I
100,0
200,0
300,0
400,0
500,0
000,0
700,0
1000,0
1100,0
1200.0
1300,0
1400,0
1500,0
1000.0
1700,0
1000,0
COP Interval = 110 ft
3
1U-4SE-$ .PPC
D
E
I'
T
II
fII ;000,0
Cross Section: XLi 0583
Method: Trend Curve
NCTL: 160-4.5-5
Model: Pleistocene
12/02/01
K. Heinlein
1000,0
N
CDP ~U~~U
1111111
~~SL 0,0
2000,0
3000,0
5000,0
6000,0
7000,0
8000,0
COP Interval == no ft
m
4
Project:
Cross Section: XL 10583
Method: Trend Curve
NCTL: 160-4.5"5
Model: Pleistocene
12/02/01
K. Heinlein
SURFACE LOCATION
I
N S
CDI' ~U~~~~UUU~U~~U~U~~U~ U~~U~UU~~ UU
11111111112222 3333333 4.4.455555555 9990
0,001234557890123 . 5078901234507 7890
T
I
t.I
E
I"'~ 900,0
COP Interval == no ft
5
16e-4S-SPL_I'PC
D
E
P
T
II
fII 4000,0
Cross Section: IL4966
Method: Trend Curve
NCTL: 160-4.5-5
Model: Pleistocene
12/02./01
K. Heinlein
Seismic
w
CIRQUE 3 8H
[If
1111111111111111111111111111111111
0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
5 5 5 5 5 5 5 6 G G G G 6 G G G G G G G G G G 6 6 6 6 6 6 6 G G 6
089999900000111112222233333444445
0 2 4 6 8 0 2 4 G 8 0 2 4 6 8 0 2 4 6 8 0 2 4 G 8 0 2 4 6 8 0
1000,0
2000,0
3000,0
5000,0
6000,0
7000,0
8000,0
E
pp~
6
T
I
hi 800,0
E
I"'~ 900,0
Project
Cross Section: IL4966
Method: Trend Curve
NCTL: 1
Model: Pleistocene
12/02/01
K. Heinlein
w
CIRQUE 3 8H
1-
E
11111111111111111111111111111111111111111111
0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ° 0 0 0
5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 6 6 0 0 6 6 0 6 6 6 6 6 6 6 6 6 6 0 6 6 0 6 0 6 6 6
"^"'77888889999900000111112222233333444445
68024600240002408024080240802408024000
100,0
200,0
300,0
400,0
500,0
000,0
100,0
1000,0
1100,0
1200,0
1300,0
1400,0
1500,0
1000,0
1100,0
1000,0
COP Interval == no ft
pp~
7
1U-4liE-S.PPG
I)
E
P
T
Ii
fII 4000,0
Cross Section: XL 10561
Method: Trend Curve
NCTL: 160-4.5-5
Model: Pleistocene
12/02/01
K. Heinlein
3_6H
N
44444444444444444
CDP 999999999nnn999999
111111111 '22222
MSLO,0012345078 5
S
4444444444444444444444444444444444444444444444444 444 444 44 444 5
99999999999999999999999999999999999999999999999999 999 99 999 0
4444444455555555550600 OOB 000 777 77 777 778 88888 888899 999 99 999 0
23450789012345078901234567890123450789012345 078901234 50 789 0
1000,0
2000,0
3000,0
5000,0
0000,0
7000,0
0000.0
COP Interval == 110 ft
m
8
12/02/01
K. Heinlein
Method: Trend Curve
Cross Section: Xli 0561 NCTL: 160-4.5-5
Mode!: Pleistocene
CIRQUE 3 OH
~r
N
CD!' U~UH~U~~~~UUU~~~44H
11111111112222222222333
0,0012345010001234507
COP Interval == 110 ft
9
Project:
Cross Section: Traverse
Method: Trend Curve
NCTL: 1
Model: Pleistocene
12/02/01
K. Heinlein
1GHS-SOS.PPC_D
#3
SE
CD!'
COP Interval == 25 ft
10
Cross Section: Traverse
Method: Trend Curve
NCTL: 1
Model: Pleistocene
12/02/01
K. Heinlein
158-4$-$05 PPC T
5.ì."ic:ACClIlGj71
SE
CDI'
100.0
200,0
300,0
400,0
500,0
600,0
700,0
T
~ 800,0
IE
¡"'I 900,0
1000,0
1100,0
1200,0
1300,1)
1400,0
1500,0
1000,0
1700,1)
1800,0
COP Interval == 25 ft
NW
PP§
11
Project Cirque
Well: Cirque 3
NCTL: 160-4.5-5
Pore Pressure and Fracture
12/02/01 K. Heinlein
Cirque 3: Predicted PPG and Fracture Gradient from IL4989 at XL 10583
DEPIHIOaiumsetiDMSL)
¡'¡Sl
---
12 13
PI'G
14
18
11
60 00
NCTL Intercept at GL = 155
Logarilbmic Slope = -45e-85
10
FEEl
M$L
1000
2000
5000
19
6000
20
Figure 12
12/02/01
K. Heinlein
.0 00 80
NCTl ln1ercepl at Gl = 16.
lO ¡arilllmic Slope. -Ue-65
10
11
12
13
2000
3000
4000
0000
20
~
~
o..J
~
0
~
2000
3000.
-
~
w
W
LL
-
J: 4000
~
a.
w
c
5000
6000
7000
8000
1000
0
I . I
- = : = ~ = 116" set @ 98' t = = = =:= = = = =
I I I I
- - - -1- - - - - + - - - - -1- - - - -
I 1 I
- - 1- - - - - ì - - - - -1- - - - -
I I
I I
I
----,--
I
I
- - - - .J - - - - _1_,- - - -
I I
- - - - --1- - - - -I-
I I
----,-----,-
I I
- - - - I - - - - -1- - -
Drill 12-1/4" Hole
I I
- - ì - - - - -1- - - - -
I I
- I - - - - -1- - - - -
I I
------1-----1----
I I
----,-----r---
I I I I
- - - - I - - - - -1- - - - - I - - - - -1- - - - -
- - - - .J - - - - - 1- - - - - ~ - - - - _1- - - - -
I I 1 I
DRilliNG TIME AND MUD WEIGHT CURVE
Tarn #1
I I I I
--------------------------
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----~_____L____~_____L___-
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----~-----~------I-----I-----
I I I I
----,-----r----,-----,----
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--~-----~------I-----I-----
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----~-----r----l-----~----
- -19-5/8" set @ 2398' 1- - - - - ~ - - - -
----,-----r----,-----r----
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----~-----r----l-----~----
---~----_L_---~_____L___-
I I I I
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-----I-----+----~-----~----
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- - - - -1- - - - - + - - - - -1- - - - - ~ - - - -
I I I 1
- - - - -1- - - - - T - - - - -1- - - - - r - - - -
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- - - - -1- - - - - I - - - - -1- - - - - I - - - -
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- - - - -1- - - - - + - - - -
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- - - - -1- - - - - T - - -
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-----1-----1--
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TIME TO DRILL (DAYS)
10
15
Rig Release est @ 1000 hrs 2/11/92
prepared by MAC
11/21/01
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11/21/01
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prepared by MAC
11/21/01
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W
W
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120" set @ 115' I
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1000
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30
prepared by MAC
11/21/01
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prepared by T JB
4/25/01
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DRilliNG TIME AND MUD WEIGHT CURVE
Meltwater North #1
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TIME TO DRILL (DAYS)
10
15
prepared by MAC
11/21/01
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DRilliNG TIME AND MUD WEIGHT CURVE
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Pay
Phillips Alaska, Inc.
P. 0, Box 102776
Anchorage, AK 99510-2776
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STATE: of,ALÄSKA
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0101358
Date
**************100.00*
Vaid after 90 days
AVENUE, SUITE 100
AI( 995013539
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TRANSMIT AL LETTER CHECK LIST
CIRCLE APPROPRIATE LETIERJPARAGRAPHS TO
BEINCLUDEDINTRANSNUTTALLETTER
WELL NAME 0/1 u.-L-- :3
CHECK 1
STANDARD LETTER
DEVELOPMENT
CHECK WHAT APPLIES
ADD-ONS (OPTIONS)
MULTI LATERAL
(If api number last two (2)
digits are between 6.0-69)
DEVELOPMENT
RED RILL
PILOT HOLE (PH)
EXPLORA~
INJECTION WELL
/
ANNULAR DI,BPOSAL
( ANO
V
ANNULAR DISPOSAL
L-> YES
INJECTION WELL
RED RILL
ANNULAR DISPOSAL
THIS WELL
(
"CLUE"
The permit is for a new wellbore segment of existing well
~ Permit No, , API No. . '
Production should continue to be reported as a function of
the original API number stated above.
In accordance with 2.0 AAC 25..o.o5(f), all records, data and
logs acquired for the pilot hole must be clearly
differentiated in both name (name on permit plus PH)
and API number (5.0 -7.0/8.0) from
records, data and logs acquired for well (name on permit).
Annular disposal has not been requested. . .
Annular Disposal of drilling wastes will not be approved.. .
Annular Disposal of drilling wastes will not be approved. . .
DISPOSAL INTO OTHER Please note that an disposal of fluids generated. '. .
ANNULUS
LjYES+
SP ACING EXCEPTION
Enclosed is the approved application for permit to drill the
above referenced well. The permit is approved ,sùbject to
full compliance with 2.0 AAC 25..055. Approval to peñorate
and produce is contingent upon issuan'ce of a conservation
order approving a spacing exception.
(Company Name) will assume the liability of any protest to
the spacing exception that may occur.
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Templates are located m drive\jody\templates
WELL PERMIT CHECKLIST COMPANY PHILLIPS WELL NAME CIRQUE #3 PROGRAM: exp
FIELD & POOL 490165/000000 INIT CLASS EXPLORATION (OIl) GEOL AREA
ADMINISTRATION 1. Permit fee attached. . . . . . . . . . '.' . . . . . . . . . . . Y-.
2. Lease number appropriate*. ~. ~I. -hÞ?t;; /(;.-- .f/b.!. * This is an exploration (delineation) well located -1 mile SE of Cirque #2. The surface location
3. Unique well name and number... . ..' . . . . . . . . . . . . . . 'N of CirQue #3 lies in ADL 375080. and the top productive interval & T.D. lie in ADL 375080.
4. Well located in a defined pool.~. . . . . . . . . . . . . . . ' ** Cirque #3 is governed by CO 430 (Tarn) between the Iceberg & the C35 marker, a depth range
5. Well located proper distance from drilling unit boundary. . . . N from -4582' to 6075' MD. From 6075' to TD at 6567' MD. the well lies outside of any defined pool.
6. Well located proper distance from other wells.. . . . . . . . . Y N
7. Sufficient acreage available in drilling unit.. . . . . . . . . . . - N
8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 'N
9. Operator only affected party.. . . . . . . . . . . . . . . . . . ) N
10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N
11. Permit can be issued without conservation order. . . . . . . . N
12. Permit can be issued without administrative approval.. . . . . N
13. Can permit be approved before 15-day wait.. . . . . . . . . . Y/, N
14. Conductor string provided - . . . . . . . . . - . . . . . . . - . N~- ìlÆs.4Jl(&. / . ~ t( ~ f¡; A'
15. Surface casing protect~ all known USDWs. . . . . . . . . . . N ^}' A tL..:5~ÆJ Y ~.¿ Ki~t -1Í> .L-j¿/SI- '-'"-' . fi ¿ A 4 - L :'1 tu.. Æ~
16. CMT vol adequate to circulate on conductor & surf csg. . . . N ~ 'fIIA.cK- e4-C.e~S C'f..£A.,__. h .
17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . N O/~
18. CMT will cover all known productive horizons. . . . . . . . . . N
19. Casing designs adequate for C, T, B & permafrost. . . . . . . N
20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N \)OU)j) IlL l4-l
21. If a re-drill, has a 10-403 for abandonment been approved. . . Y N ~
22. Adequate wellbore separation proposed.. . . . . . . . . . . . iN
23. If diverter required, does it meet regulations. . . . . . . . . . N
24. Drilling fluid program schematic & equip list adequate. . . . . N
25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 1) - I 'fl . L I' . "
DATE 26. BOPE press rating appropriate; test to 5000 psig. «J) NJ{?ý Cl..i)iJlJCA-t:(~v- . MA~P :: '¿h"f4 ft-<..
i1.i[Qz.. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . Y N =t , I
28. Work will occur without operation shutdown. . . . . . . . . . . Y N .
((tl(O';J 29. IspresenceofH2Sgasprobable..... ....,....... Y @5øz bel'ÏìlV"
GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . . . . .~N *** Offset well Cirque #2 encountered thin. overpressured. gas-charQed sands at :2171/ TVDSS.
31. Data presented on potential overpressure zones***. . . . . . . N which were contr led using 10.5 ppg mud. Planned mut wt across these same sands in Cirque.
32. Seismic analysis of shallow gas zones**** . . . . . . . . . .. ' . Y N #3 is 10 . ' .
A~ D~JE 33. Seabed condition survey (if off-shore). . . . . . . . . . . .. d.:1~****12/18/01: Phone Kathy Heinlein - awaiting final version of shallow hazards report. 11t>7. ~z..:
¡. 7. Dz.- 34. Contact name/phone for weekly progress reports [exploratory onlyJð N velocity analysis of 3D seismic data shows no apparent shallow hazards or pressure anoma ies.
ANNULAR DISPOSAL35. With proper cementing records, this plan 3D data set does not show any shallow gas indicators. CONTACT: Mark Chambers - 265-1319.
APPR DATE ~~~ :::: ~~~~~~t:~~~:~: ~:su~::~:r~e:re~~:;ez~~~i;n~ ~~sie'. '. .' ~ ~ ¡No ~~~c{cw ct'~) M2.0Ç~. (
to surface; f
(C) will not impair mechanical integrity of the well used for disposal; Y N
(D) will not damage producing formation or impair recovery from a Y N
pool; and
E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N
GEOL Y: ENGINEERING: UIC/Annular COMMISSION:
::0 ~~~æm y I ~ ~ ~~S) i h j'), Ex¡/~4 b
WGA~ JMH 'I(~O'~
X dev - redrll serv wellbore seg _ann. disposal para req -
890 UNIT# 011160 ON/OFF SHORE ON
~PJ.~ DATE.
D 12.1 r:?ó (
ENGINEERING
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G:\geology\permits\20 12440- Cirque3- Checklist doc
