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10/6/2005 Well History File Cover Page.doc
Re: Well
.
e
Steve,
We have not drilled this well. I'm not sure if or when we will. I have
been told that we are not drilling in 2007.
Thanks,
Jeff Gasch
Production Engineer
XTO Energy
Office # (432) 620-6742
Cell # (432) 638-7433
Fax # (432) 687-0862
Stephen Mcmains
<steve mcmains@ad
min.state.ak.us>
To
05/03/2007 10:22
AM
Jeff Gasch
<,Jeff Gasch@xtoenergy. com>
cc
Subject
Well
Jeff
Have you started to drill well MGS A21-12 yet? The permit expired May
3, 2007. I noticed this on a report I pulled.
Steve
(See attached file: steve mcmains.vcf
Content-Type: application/octet-stream
Content-Encoding: base64
1 of 1
5/7/20078:47 AM
.
.
FRANK H. MURKOWSKI, GOVERNOR
AI,ASIiA OILAlWD GAS
CONSERVATION COMMISSION
333 W. 7'" AVENUE. SUITE 100
ANCHORAGE. ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907)276-7542
Bobby Smith
Drilling Operations Manager
XTO Energy, Inc.
300 North Garfield, Suite 175
Midland, Texas 79705
Re: Middle Ground Shoal A21-12
XTO Engergy, Inc.
Permit No: 205-071
Surface Location: 1564' FSL, 378' FEL, SEC. 11, T8N, R13W, SM
Bottomhole Location: 761' FNL, 1831' FWL, SEC. 12, T8N, R13W, SM
Dear Mr. Smith:
Enclosed is the approved application for permit to redrill the above development well.
During 2000, XTO submitted a permit to drill application for a sidetrack of the A-24-1LE well.
This sidetrack was approved as Permit to Drill 200-160, API 50-733-20258-02-00 on January 3,
2001. XTO subsequently decided not to drill the sidetrack and requested AOGC cancel the
permit. The API number of 50-733-20258-02-00 is associated with Permit to Drill 200-160 in
AOGCC's databases. Once assigned, an API number cannot be re-used. Accordingly, this
application to sidetrack A-24-01LE is assigned both a new permit to drill number (205-071) and
a new API number (50-733-20258-03-00).
This permit to redrill does not exempt you from obtaining additional permits or approvals
required by law from other governmental agencies, and does not authorize conducting drilling
operations until all other required permits and approvals have been issued. In addition, the
Commission reserves the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the
Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure
to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska
Administrative Code, or a Commission order, or the terms and conditions of this permit may
result in the revocation or suspension of the permit. PI e rovide at least twenty-four (24)
hours notice for a representative of the Commission witn s any required test. Contact the
Commission's petroleum field inspect 659 . 607 (p er).
DATED this3 day of May, 2005
cc: Department ofFish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
;[!~
.
.
RECEIVED
APR 2 9 2005
April 27, 2005
Alaska Oil & Gas Cons. Commís!iion
Anchorage
Mr. John Norman, Chair
Alaska Oil and Gas Conservation Commission
333 West 7th Ave., Suite 100
Anchorage, Alaska 99501
RE: Application for Permit to Drill: A21-12 (Sidetrack of A24-01LE)
Dear Mr. Norman,
XTO Energy, Inc. hereby applies for a Permit to Drill an offshore development well from
Platform A in the Middle Ground Shoal Field of Cook Inlet. The well is planned as a
sidetrack of the existing A24-01LE wellbore in order to penetrate and develop an un-
drained portion of the Hemlock conglomerate in the vicinity of XTO Platform A.
Approval of the associated pre-drilling work plan for the existing wellbore has been
requested via a Sundry Notice submitted under separate cover.
The anticipated spud date of A21-12 is approximately May 31, 2005.
The A21-12 sidetrack will be kicked off in 7" cemented casing in A24-01LE at a depth of
8,200'. A 6" hole will be directionally drilled to a TD of 1O,728'MD at the base of the
Hemlock Formation on the MGS East Flank and a 5" liner set and cemented. The well
will be completed with a 2-7/8" gas lift completion.
Please fmd 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) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a).
2) Fee of $100.00 payable to the State of Alaska per 20 AAC 25.005 (c) (1).
3) A directional plat showing the well's proposed surface and bottomhole
locations per 20 AAC 25.050 (c) (2).
4) Directional plots and proximity calculations in accordance with the
requirements of 20 AAC 25.050.
5) Diagrams and descriptions of the BOP equipment to be used as required by
20 MC 25.035 (a)(I) and (b) and a request for waiver of one of the
provisions of those regulations have been previously submitted and
approved.
6) A complete proposed casing program is attached as per 20 MC 25.030.
7) The drilling fluid program, in addition to the requirements of 20 MC
25.033 is attached.
8) A copy of the proposed drilling program is attached.
9) XTO Energy does not anticipate the presence of H2S in the formation to be
encountered in this well. However, H2S monitoring equipment will be
XTO Energy Inc. . 3000 N. Garfield . Suite 175 . Midland, Texas 79705 . (915) 682-8873 . Fax:: (915) 687-0862
.
Mr. John Norman
Page 2
.
R. ·Er..·.: ~ ii.F'.··
,,;. ...... ....~....~<p ~
APR 2 9 2005
Alaska Oil &
functioning on the rig at all times during sidetracking, 4mJ~aand
completion operations.
10) While this well is considered to be a development well, basic mud logging
will be performed while drilling to aid in tracking the location, thickness and
quality of the intervals penetrated.
11) A Summary of Drilling Hazards is attached.
12) The following are XTO Energy's designated contacts for reporting
responsibilities to the Commission:
1) Completion Report
(20 AAC 25.070)
2) Geologic Data and Logs
(20 AAC 25.071)
Paul Figel, Engineering Manager
(432) 620-6743
Mike Langeler, Senior Geologist
(817) 885-2581
If you have any questions or require additional information, please contact me at (432)
620-6718 or Bill Penrose at (907) 258-3446.
Sincerely,
XTO ENERGY, INC.
¡4L~
Bobby L. Smith
Drilling/Operations Manager
enclosures
cc: Bill Penrose
^ r)nf. t\. "'Inr)!::
1a. Type of Work: Drill D Redrill [] 1 b. Current Well Class: Exploratory D ¡D~vèl~nt~I"" [] Multiple Zone D
Re-entry D Stratigraphic Test D Service it .0._ mP8vfllç:p,~n.tJ3= n. ~nnle Zone []
2. Operator Name: 5. Bond: Blanket [] Sifi'Qi'ê'W'ell'[]. ., ~1~ Well Name and Number:
XTO Energy, Inc. Bond No. 1 03652600 W~G¡;;J! ~¡¡t: A21-12
3. Address: 6. Proposed Depth: ,12. Field/Pool(s):
,-
3000 North Garfield Suite 175. Midland. TX 79705 MD: 10.728' TVD: 9.666' Middle Ground Shoal
4a. Location of Well (Governmental Section): 7. Property Designation: Iß"'?'! ~1>
Surface: 1564'FSL,378'FEL,See.11,T8N,R13VV,SM ADL~ ';"':1. ,.:>r;;
Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date:
761' FNL, 1831' FVVL, See 12, T8N, R13VV, SM N/A 5/31/2005
Total Depth: 9. Acres in Property: '¿b 14. Distance to Nearest
761' FNL, 1831' FVVL, See 12, T8N, R13W, SM ,~o '57 C{(,. $-, '!>...~ Property: 2,580'
4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well
Surface:Y~ 2485781 >f.. 232841 }Þ " Zone- AK-4 (Height above GL): 105 feet ASL Within Pool: 1341' from A14-01
'f.: 3.0>
16. Deviated wells: Kickoff depth: 8,200 feet .- 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 24 degrees ,- Downhole: 5,000 psi Surface: 3,934 psi ,
Îô. Casing Prograrn: Specifications Setiing ûepth Uuantity of Cement
Size Top Bottom c.f.orsacks
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data)
6" 5" 18# P-11 0 STL 3.028' 7,700' 6.738' 10,728' 9.666' 254 cf Class G
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured):
11,994' 9,805' None 11,994' 9,805' None
Casing Length Size Cement Volume MD TVD
Structural
Conductor 370' 24" 370' 370'
Surface 2,010' 13-3/8" 3,575 sx 2,010' 1,830'
Intermediate
Production 10.013' 7" 2,100 sx 10.013' 8,731'
Liner 2,811' 5" 448 sx 11 994 9.805'
Perforation Depth MD (ft): 10,200' -11,784' Perforation Depth TVD (ft): 8,892' - 9,805'
20. Attachments: Filing Fee ~ BOP Sketch ~ Drilling Program ~ Time v. Depth Plot U Shallow Hazard Analysis U
Property Plat D Diverter Sketch D Seabed Report D Drilling Fluid Program [] 20 AAC 25.050 requirements D
21. Verbal Approval: Commission Representative: Date
22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bill Penrose 258-3446
Printed Name Bobby Smith Title DrillinQ/Operations Manager
Signature ~L ..c:r/ Phone 432-620-6718 Date
I Commission Use Only
Permit to Drill 1P1 Number: 58 . 3 Permit Approval f See ~over letter for other
Number: ;:li::f$ ~07 I 50- 733 - :202 .-0 Date: requirements.
Coeditio", of appw,,', ;/;;1;,:
Sam es re ired Yes D No rxr Mud log required Yes D No H
~ L H 0 ollid, mea,"'" y" ~ No 0 DI'oc1loo:f ,"N,y "qol'ed Yes tM No D
Ofh" 50 a ~ T ~ ~~ <>.'> <><>0><.. \. """" $:,., x."""",- ~~ '-"'" \N!:"- ">. 4¡ðf
~ ~ ~ BY ORDER OF
Approved OJ '1 1 ( ;..., ,~ A THE COMMISSION Date:
FO~401 R~d 1~:0~ -.;- T7< 'li\ .
Suþmit..inDuplicate
. STATE OF ALASKA .
ALASKA OIL AND GAS CONSERVATION COMMIS~JHt:I.~r:I\
PERMIT TO DRILL Kt:~J~,,,,,, lED
20 AAC 25 005
~Q~
.
.
XTO Energy, Inc.
RECEIVED
APR 2 9 2005
MGS A21-12
Ala:dc,2 Oil 8,
Commission
Sidetrack Procedure
With the rig over A24-0 1 LE, the BOPE installed and the wellbore plugged back with
cement:
1.
Set whipstock in 7" casing at 8,200'. /
2.
Mill ,xri11r!.nxr i11 7" {,<I~ina ll~in(T F." ~t<lrtpr ",nrl ",,,,tprn-o,,,lrw. ......;11" rI",f'lo~+;~~ ~++
-"-..L.......... ,. ..........L............. .. ......L.... I ............................0 ..................&.ó '"' OJ """..I.. ""'..I. u...J.J.'-J. yy U"""J.J..1.1.\,.IJ.V.l.l .l.l.lJ..l.lCt, \..1\,.1.l.l\,..r\,..r\..111Õ V.l.l
whipstock. POB.
3. M/U 6" bit on directional drilling assembly and RIB.
4. Using water-base mud, directionally drill 6" hole from 8,200' to 10,728' MD, TD. ..
5. Run open-hole logs. ¡i
6. Run and cement 5", 18#, L-80, STL liner at 10,728' MD with TOL at approximately
7,700' (~500' oflap).
7. Run cement bond log over 5" liner.
8. Run 2-7/8",6.5#, L-80, 8rd EUE completion with gas lift design.
9. Pickle inside of tubing with BCI/xylene and circulate inhibited filtered Inlet water
into annulus before setting packer.
10. N/D BOPE, N/U tree. Test tree to 5,000 psi. Release rig.
.
.
XTO Energy, Inc.
.Ala:::ka Oil ((..¡
REC IVED
APR 2 9 2005
CommissiDn
Drilling Fluid Program, Pressure Calculations, and Drilling Area Risks
MGS A21-12
Drilline Fluid Properties:
6" Hole Section
(8,200' - 10,728'MD)
(7,187' - 9,666'TVD)
Density 9.0 - 10.5
YP 12 - 15
API Fluid Loss 8 -10
Chlorides <1,000
pH 9.5
v
Drilline Fluid System:
Two Derrick Shale Shakers Pit Level Indicator (Visual and Audio Alarms)
Desander, Desilter, Mud Cleaner Trip Tank
Centrifuge Fluid Flow Sensor
Degasser Fluid Agitators
Maximum Anticipated Surface Pressure:
6" Hole Section
The maximum anticipated surface pressure (MASP) for the 6" hole section in this
sidetrack will be the lesser of the formation pore pressure (less a full gas column to the
surface) at the 5" liner setting point or the formation fracture pressure at the window in
the 7" casing (less a full gas column to the surface). Based on offset well data, the
highest formation pressure expected in this 6" hole section is 5,000 psi at the section TD ......
of 9,666' TVD (or 0.517 psi/ft). Fracture gradient data for this area indicates that the
fracture gradient at 7,187' TVD (the 7" window depth) is 0.720 psi/ft. Complete
evacuation of the wellbore, except for a 0.11 psi/ft gas gradient, is assumed.
6" hole section
MASP (pore pressure)
MASP (fin breakdown)
(9,666 ft)(0.517 - 0.11) = 3,934 psi
(7,187 ft)(0.720 - 0.11) = 4,384 psi
"
Therefore, MASP in the 6" open hole section is 3,934 psi and the 5,000 psi BOPE system
to be used will be adequate.
.
.
Well Proximity Risk:
The closest wellbore to this one will be approximately 1 ,341ÀI~f01t@ ~1.:t~J¡, ~~11 .-.--
at the kick-off depth of 8,200' MD and diverge away during drilling.
REC IVED
APR 2 9 2005
Drillinl! Area Risks:
The primary drilling risks in the A21-12 area are those of possible stuck pipe in the .'
Tyonek coals above the Hemlock Formation, potential loss of circulation in the Tyonek G ,/
Sands and waterflood-elevated pressure in the Hemlock Formation.
Stuck Pipe
The risk of stuck pipe in the Tyonek coals will be countered in two ways: ,/
1.) Drillers experienced at drilling the formations of the Cook Inlet Basin will be
used.
2.) Bit selection will include those which experience a slower rate of penetration
when entering coal beds, thus giving warning of coals being encountered and
preventing the BHA from entering them until the coals can be reamed open.
Elevated Pore Pressure
The 6" hole section will be in the East Flank of the Middle Ground Shoal structure which
contains waterflood-elevated pore pressures of approximately 5,000 psi. This relatively v'
high pore pressure has been encountered previously and will be controlled with
appropriately regulated mud density.
Lost Circulation
The pore pressure in the Hemlock East Flank of the Middle Ground Shoal is higher than
that in the overlying G Sands, giving rise to the possibility of drilling fluid losses in the G
Sands with the mud weight required to drill the Hemlock. However, the G Sands do not
normally contain sufficient permeability for this to be a problem in the Middle Ground
Shoal area. As a precaution, various types and sizes of LCM will be kept on location to
combat any lost circulation problems that occur.
Disposal of Muds and Cuttinl!s:
MGS Platform C has a dedicated Class II disposal well. All oil-base or sheening waste
wellbore fluids will be injected down the disposal well as will cuttings after they are
ground. Non-sheening water-base fluids and cuttings will be discharged overboard.
,/
A21-12
Casin2: Properties and Desi2:n Verification
Casing Performance Properties
Internal Collapse Tensile Strength
Size Weight Yield Resistance Joint Body TVD MD Design Safety Factor*
(in.) (lb/ft) Grade Cnxn Û2ill Û2ill (1,OOOlbs) (ft RKB) (ft RKB) T B C
5 18 P-110 STL 13,940 13,450 495 580 9,666 10,728 10.81 12.94 3.42
...
"
* Tensile design safety factors are calculated using pipe weight less buoyancy.
Burst design safety factor for the 5" liner is calculated at the depth of the 7" casing window using the expected normal pore pressure
at the 7" window on the outside and waterflood-elevated East Flank reservoir pressure from deeper in the 6" hole section on the
inside.
Collapse design safety factor for the 5" liner is calculated at the 5" shoe using the waterflood-elevated East Flank reservoir pressure_
on the outside and the entire cased hole evacuated except for a gas gradient on the inside. ..
Casing Setting Depth Rationale
5"
10,728'MD/9,666'TVD
Production liner to stabilize producing interval for production operations.
RECEIVED
APR .2 9 2005
Commission
.
.
A21-12 RECEIVED
APR 2 9 Z005
Summary of Drillinq Hazard!¡kaOilSi
POST THIS NOTICE IN THE DOGHOUSE
.-.¡ The 6" hole section will be drilled through the MGS East Flank
which contains elevated pore pressures resulting from
waterflooding. Higher mud weights will be used in this interval to
control the well.
.-.¡ A portion of the 6" hole section will penetrate the Tyonek G Sands.
There is a potential for lost circulation and consequent difficulty in
keeping the hole full. A 5" liner may be set early if lost circulation
problems become severe.
.-.¡ Pipe sticking tendency is possible in the coals above and in the
Hemlock reservoir.
.-.¡ The closest wellbore to this one will be approximately 1,341' from
the A14-01 wellbore at the kick-off depth of 8,200' MD and diverge
away during drilling.
.-.¡ There is no H2S risk anticipated for this well.
CONSULT THE A-21-12 WELL PLAN FOR ADDITIONAL INFORMATION
Created by : Planner
Oate plotted: 30-Mar-2005
Plot re erence is A21-12 Ver 1.
Ref wellpath is A21-12 Ver 1.
Coordinates are in feet reference slot #4-28.
True Vertical Depths are reference Rig Datum.
Measured Depths are reference Rig Datum.
Rig Datum: Planned Datum
Rig Datum to mean sea level: 116.00 ft.
Plot North is aligned to TRUE North.
F:~ XTO Energy, Inc.
.-- -
Location: Cook Inlet, Alaska Slot: slot #4-28
Field: Middle Ground Shoal Well: A24-01
Installation: Platform A Wellbore: A21-12 Ver 1
;[!~
'&1.
....
INTEQ
T
WELL PROFILE DATA
Point MD Inc Azi TVD North East deg/100ft V. Se.
--
KOP 8200.00 24.24 11.04 7186.63 2820.53 2459.88 0.00 3732.42
End of Drop/Turn 8999.39 15.16 263.78 7956.99 2974.25 2385.44 4.00 3810.69
n
."', End of Hold 9371.71 15.16 263.78 8316.34 2963.70 2288.63 0.00 3744. 1
,
,
.~~
",,'"
t A21-12 Tgt Heml 9778.16 5.00 263.77 8716.00 2956.00 2218.00 2.50 3695.60
End of Drop 9978.16 0.00 263.77 8915.75 2955.05 2209.33 2.50 3689.64
.0. & End of Hold 10728.42 0.00 263.77 9666.00 2955.05 2209.33 0.00 3689.64
):>
:C";
,,:>
:::r
£~ n
".,0
(t;:) .~
m _
þ
?;?
~
0> ,.,....
o ~ ,.#f,..
.J>,...
~ï:J J
::::ö Ie'
.... \
~[11
I"V ...
=,
g(=m
:3 U1 j
~ TaLl.
~ rge
ë5
::;:t
¡¡:: 5800
0
0
....
II 6000
E
ü
(].) 6200
ro
ü
(/)
6400
6600
6800
7000
7200
- 7400
...
( ,)
.!
-
7600
7800
ro
CJ
E 8000
( ,)
>
8200
.
V 8400
8600
8800
9000
9200
9400
9600
9800
10000
1
DLS: 4.00 deg/100ft
12.50
11.28
11 .40
12.82
11.95
9.45
2.50 deg/100ft
2.50
XTO Energy, Ine..
Field: Middle Ground Shoal
Installation: Platform A
2050 2100 2150 2200 2250 2300
A21-12 Tgt Hemlock 12/14/03
Tie on - 7186.63 Tvd, 2820.53 N 2459.88 E
& Kick off Point - 24.24 Inc, 8200.00 Md, 7186.63 Tvd, 3732.42 VS
End of
- 15.16Ine, 8999.39 Md, 7956.99 Tvd, 3810.69 VS
End of Hold - 15.16
9371.71 Md, 8316.34 Tvd, 3744.15 VS
A21-12 Tgt Hemlock
End of Drop - 0.00 Inc. 9978.16
8915.75 Tvd, 3689.64 VS
5.000in Casing
3200 3400 3600 3800 4000 4200 4400 4600 4800 5000
Seale 1 em = 100 It Vertical Section«feet) ->
Azimuth 36.88 with reference 0.00 N, 0.00 E from slot #4-28
3050
;: >
5200
1.
is
.
.
XTO Energy, Inc.,slot #4-28
Platform A,
Middle Ground Shoal, Cook Inlet,
Alaska
PROPOSAL LISTING Page 1
Well bore: A21-12 Ver 1
Wellpath: A21-12 Ver 1
Date Printed: 1-Apr-2005
-..
....
INTEQ
Well bore
Name I Created T Last Revised
A21-12 Ver 1 I 30-Mar-2005 T 1-Anr-2005
Well
Name I Government ID I Last Revised
A24-01 I T 19-0ct-2004
Slot
Narne I Grid Northinn I Grid Eastinn I Latitude I LonnitudA I North I East
slot #4-28 I 2485780.6663 I 232840.8677 I N60 47 44.2218 I W151 29 43.9938 I 6844.00N I 378.00W
Installation
Narne I Eastina I Northina I Coord Svstern Name I North Alianment
Platform A I 233063.0833 I 2478929.9820 I AK-4 on NORTH AMERICAN DATUM 1927 datuml True
Field
Name I Eastina I Northina I Coord Svstern Name I North Alianment
Middle Ground Shoal I 234754.5480 I 2500016.5290 I AK-4 on NORTH AMERICAN DATUM 1927 datuml True
Rt:r: j\Il::D.·
[: \'4" . ~f ¡~..
.APR 2 9 2005
..
Comments
All data is in Feet unless otherwise stated
Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 116.0ft above mean sea level)
Vertical Section is from O.OON O.OOE on azimuth 36.88 degrees
Bottom hole distance is 3689.65 Feet on azimuth 36.78 degrees from Wellhead
Calculation method uses Minimum Curvature method
Prepared by Baker Hughes Incorporated
.
.
P~:I~:~~ ~~~~~~~:rft.~ C IVIïf.I:
Wellpath: A21-12 Ver 1 APR :2 9~~Q
Date Printed: 1-Apr-2005 . ...
Alaska Oil ,~ CQmmissÎm¡
Anc.hof£ge
XTO Energy, Inc.,slot #4-28
Platform A,
Middle Ground Shoal,Cook Inlet,
Alaska
WellDath (Grid) Re )ort
MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing
Idea/100ft Sectionlftl
0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 232840.87 2485780.67
10.00 0.00 12.00 10.00 O.OON O.OOE 0.00 0.00 232840.87 2485780.67
400.00 3.00 12.00 399.82 9.98N 2.12E 0.77 9.26 232843.22 2485790.60
430.00 4.00 45.00 429.77 11.49N 3.03E 7.35 11.01 232844.15 2485792.09
466.00 5.25 59.00 465.65 13.23N 5.33E 4.65 13.78 232846.49 2485793.77
497.00 6.25 55.00 496.50 14.93N 7.92E 3.47 16.70 232849.13 2485795.41
528.00 7.75 63.00 527.26 16.84N 11.17E 5.76 20.18 232852.42 2485797.25
559.00 9.00 51.00 557.93 19.32N 14.91E 6.91 24.40 232856.22 2485799.64
595.00 11.25 56.00 593.37 23.06N 20.02E 6.70 30.45 232861.40 2485803.26
710.00 16.00 42.00 705.13 41.12N 39.94E 5.00 56.86 232881.73 2485820.87
806.00 22.00 34.00 795.88 65.89N 58.87E 6.80 88.03 232901.22 2485845.19
874.00 25.75 34.00 858.05 88.70N 74.25E 5.51 115.51 232917.12 2485867.65
968.00 32.00 34.00 940.32 126.32N 99.62E 6.65 I 160.83 232943.34 2485904.68
I
1032.00 33.00 34.00 994.30 154.82N 118.85E 1.56 195.17 232963.21 2485932.74
1122.00 32.00 34.00 1070.20 194.91 N 145.89E 1.11 243.47 232991.16 2485972.20
1245.00 32.00 34.00 1174.51 i 248.95N 182.34E 0.00 308.56 233028.83 2486025.39
1432.00 32.00 33.00 1333.10 ! 331.58N 237.03E 0.28 407.48 233085.39 2486106.75
1651.00 32.50 31.00 1518.32 I 430.68N 298.94E 0.54 523.90 I 233149.54 2486204.41
1722.00 30.50 42.00 1578.90 i 460.45N 320.84E 8.56 560.86 233172.11 2486233.67
1809.00 29.00 45.00 I 1654.44 I 491.77N 350.53E 2.43 603.73 233202.50 2486264.31
2011.00 29.25 43.00 1830.90 I 562.49N 418.81E 0.50 701.28 233272.38 2486333.45
2134.00 29.25 43.00 1938.22 I 606.44N 459.80E 0.00 761.04 233314.36 2486376.46
2344.00 30.75 42.00 2120.08 I 683.87N 530.72E 0.75 865.53 233387.02 2486452.25
2607.00 30.00 42.00 2346.98 782.70N 619.71 E 0.29 997.98 233478.23 2486549.02
2917.00 28.50 45.00 2617.46 892.60N 723.87E 0.68 1148.41 233584.87 2486656.52
3134.00 28.50 42.00 2808.17 967.68N 795.13E 0.66 1251.23 233657.82 2486729.96
3352.00 28.00 39.00 3000.21 I 1046.11 N 862.13E 0.69 1354.18 233726.59 2486806.84
3573.00 26.75 38.00 I 3196.46 1125.62N 925.40E 0.60 1455.75 233791.66 2486884.89
3751.00 27.00 33.00 3355.26 1191.08N 972.08E 1.28 1536.13 233839.81 2486949.27
3785.00 27.00 33.00 3385.55 1204.03N 980.49E 0.00 1551.53 233848.51 2486962.02
3815.00 26.50 34.00 3412.34 1215.29N 987.94E 2.24 1565.01 233856.22 2486973.10
3845.00 26.00 38.00 3439.25 1226.02N 995.73E 6.13 1578.27 233864.25 2486983.66
3875.00 26.00 43.00 3466.22 1236.01 N 1004.26E 7.30 1591.38 233873.01 2486993.45
3895.00 27.50 45.00 3484.08 1242.48N 1010.52E 8.75 1600.31 233879.41 2486999.78
3959.00 28.00 46.00 3540.72 1263.37N 1031.78E 1.07 1629.77 233901.14 2487020.17
4115.00 28.00 47.00 3678.46 1313.78N 1084.90E 0.30 1701.98 233955.39 2487069.36
4333.00 27.75 48.00 3871.16 1382.64N 1160.04E 0.24 1802.16 234032.08 2487136.49
4516.00 30.75 49.00 4030.81 1441.85N 1227.02E 1.66 1889.72 234100.40 2487194.16
4646.00 32.75 49.00 4141.35 1486.73N 1278.65E 1.54 1956.60 234153.03 2487237.85
4868.00 33.25 47.00 4327.54 1567.63N 1368.48E 0.54 2075.23 234244.68 2487316.68
5110.00 33.00 48.00 4530.21 1656.98N 1465.98E 0.25 2205.21 234344.19 2487403.78
5395.00 33.25 48.00 4768.90 1761.19N 1581.72E 0.09 2358.03 234462.27 2487505.33
5645.00 34.50 48.00 4976.45 1854.43N 1685.27E 0.50 2494.76 234567.91 2487596.18
5862.00 35.50 49.00 5154.21 1936.89N 1778.49E 0.53 2616.66 234662.99 2487676.49
6112.00 34.50 49.00 5359.00 2030.96N 1886.71E 0.40 2756.86 234773.32 2487768.07
6225.00 33.50 49.00 5452.68 2072.42N 1934.40E 0.88 2818.64 234821.94 2487808.43
6421.00 31.50 46.00 5617.98 2143.49N 2012.07E 1.31 2922.10 234901.21 2487877.71
6580.00 32.00 47.00 5753.19 2201.07N 2072.76E 0.46 3004.59 234963.20 2487933.90
6875.00 31.00 44.00 6004.73 2309.04N 2182.71 E 0.63 3156.93 235075.57 2488039.33
7028.00 29.00 42.00 6137.23 2364.95N 2234.90E 1.46 3232.98 235129.02 2488094.03
7254.00 27.50 41.00 6336.31 2445.04N 2305.80E 0.70 3339.59 235201.72 2488172.49
All data is in Feet unless otherwise stated
Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 116.0ft above mean sea level)
Vertical Section is from O.OON O.OOE on azimuth 36.88 degrees
Bottom hole distance is 3689.65 Feet on azimuth 36.78 degrees from Wellhead
Calculation method uses Minimum Curvature method
Prepared by Baker Hughes Incorporated
.
.
XTO Energy, Inc.,slot #4-28
Platform A,
Middle Ground Shoal,Cook Inlet,
Alaska
PROPOSAL LISTING Page 3
Well bore: A21-12 Ver 1
Wellpath: A21-12 Ver 1
Date Printed: 1-Apr-2005
.1.
....
INTEQ
WellDath (Grid) Re :>ort
MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing
Idea/100ft Sectionlftl
7445.00 I 25.50 38.00 6507.24 2510.73N 2360.05E 1.26 3424.70 235257.45 2488236.92
7568.00 I 24.75 28.00 6618.65 2554.35N 2388.45E 3.50 3476.63 235286.84 2488279.88
7651.00 25.50 23.00 6693.81 2586.14N 2403.59E 2.71 3511.15 235302.70 2488311.32
7754.00 26.25 19.00 6786.49 2628.09N i 2419.67E 1.84 3554.35 235319.73 2488352.89
7847.00 26.50 14.00 6869.81 2667.67N I 2431.38E 2.40 3593.04 235332.35 2488392.20
7985.00 26.75 12.00 6993.18 2727.93N i 2445.29E 0.67 3649.58 235347.62 2488452.12
8159.00 25.50 6.00 7149.43 2803.49N 2457.35E 1.68 3717.27 235361.40 2488527.39
8200.00 24.24 11.04 7186.63 2820.53N 2459.88E 6.02 3732.42 235364.32 2488544.36
8300.00 20.79 5.72 7279.01 2858.35N 2465.59E 4.00 3766.09 235370.88 2488582.04
8400.00 17.57 358.48 7373.46 2891 .11 N 2466.95E 4.00 3793.11 235373.00 2488614.76
8500.00 14.72 348.33 7469.53 2918.64N 2463.98E 4.00 3813.35 235370.66 2488642.35
8600.00 12.50 334.11 7566.74 2940.82N 2456.69E 4.00 3826.71 235363.87 2488664.69
8700.00 ! 11.28 315.51 7664.63 2957.54N 2445.10E 4.00 3833.13 235352.67 2488681.67
8800.00 11.40 295.07 7762.72 2968.71N 2429.28E 4.00 3832.58 235337.11 2488693.20
8900.00 12.82 277.15 7860.52 2974.29N 2409.31 E 4.00 3825.05 235317.27 2488699.23
8999.39 15.16 263.78 7956.99 2974.25N 2385.44E 4.00 3810.69 235293.40 2488699.74
9000.00 15.16 263.78 7957.57 2974.24N 2385.28E 0.00 3810.58 235293.24 2488699.72
9100.00 15.16 263.78 8054.09 2971.40N 2359.28E 0.00 3792.71 235267.18 2488697.48
9200.00 15.16 263.78 8150.61 2968.57N 2333.28E 0.00 3774.84 235241.12 2488695.24
9300.00 15.16 263.78 8247.13 2965.73N 2307.28E 0.00 3756.97 235215.07 2488693.00
9371.71 15.16 263.78 8316.34 2963.70N 2288.63E 0.00 3744.15 235196.38 2488691.39
9400.00 14.45 263.78 8343.69 2962.92N 2281.45E 2.50 3739.21 235189.18 2488690.77
9500.00 11.95 263.78 8441.04 2960.44N 2258.74E 2.50 3723.60 235166.42 2488688.82
9600.00 I 9.45 263.78 8539.30 2958.43N 2240.28E 2.50 3710.91 235147.92 2488687.23
I I
9700.00 6.95 263.78 8638.26 2956.88N 2226.09E 2.50 3701.16 235133.70 2488686.00
9778.16 5.00 263.78 8716.00 2956.00N ! 2218.00E 2.50 3695.60 235125.59 2488685.30
9878.16 2.50 263.78 8815.78 2955.29N 2211.50E 2.50 3691.13 235119.08 2488684.74
9978.16 0.00 263.78 8915.75 2955.05N 2209.33E 2.50 3689.64 235116.90 2488684.56
10000.00 0.00 263.78 8937.58 2955.05N 2209.33E 0.00 3689.64 235116.90 2488684.56
10100.00 0.00 263.78 9037.58 2955.05N 2209.33E 0.00 3689.64 235116.90 2488684.56
10200.00 0.00 263.78 9137.58 2955.05N 2209.33E 0.00 3689.64 235116.90 2488684.56
10300.00 0.00 263.78 9237.58 2955.05N 2209.33E 0.00 3689.64 235116.90 2488684.56
10400.00 0.00 263.78 9337.58 2955.05N 2209.33E 0.00 3689.64 235116.90 2488684.56
10500.00 0.00 263.78 9437.58 2955.05N 2209.33E 0.00 3689.64 235116.90 2488684.56
10600.00 0.00 263.78 9537.58 2955.05N 2209.33E , 0.00 3689.64 235116.90 2488684.56
10700.00 0.00 263.78 9637.58 2955.05N 2209.33E 0.00 3689.64 235116.90 2488684.56
10728.42 0.00 263.78 9666.00 2955.05N 2209.33E 0.00 3689.64 235116.90 2488684.56
R. r:: ("" E··.··~ n lE- 0-
t,.. "",' ., V .
APR 2 9 2005
Alaska Qí¡ 84 C(lrnm¡~$¡(Jn
A\lchof~~ß
All data is in Feet unless otherwise stated
Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 116.0ft above mean sea level)
Vertical Section is from O.OON O.OOE on azimuth 36.88 degrees
Bottom hole distance is 3689.65 Feet on azimuth 36.78 degrees from Wellhead
Calculation method uses Minimum Curvature method
Prepared by Baker Hughes Incorporated
.
.
XTO Energy, Inc.,slot #4-28
Platform A,
Middle Ground Shoal,Cook Inlet,
Alaska
PROPOSAL LISTING Page 4
Well bore: A21-12 Ver 1
Well path: A21-12 Ver 1
Date Printed: 1-Apr-2005
...
....
INTEQ
Wellbore
A21-12 Ver 1
Name
Wellbore
5.000in Casin
A21-12 Ver 1
Name
A21-12 Tgt
Hemlock 12/14/03
Tar ets
Latitude Lon itude
N60 48 13.32 W151 2859.29
Eastin
235125.59
RECEIVED
APR 2 9 2005
Alaska Oil & Gas Con.'>. Cornmì:;siof!
Anchowge
All data is in Feet unless otherwise stated
Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 116.0ft above mean sea level)
Vertical Section is from O.OON O.OOE on azimuth 36.88 degrees
Bottom hole distance is 3689.65 Feet on azimuth 36.78 degrees from Wellhead
Calculation method uses Minimum Curvature method
Prepared by Baker Hughes Incorporated
.
.
XTO Energy, Inc.
A21-12 Ver 1, A21-12 Ver 1
slot #4-28, Platform A
CLEARANCE LISTING Page 1
Date Printed: 1-Apr-2005
Middle Ground Shoal, Cook Inlet,
Alaska
...
....
INTEQ
Ellipse separations are reported ONLY if BOTH wells have uncertainty data
Only Depth and MaQnetic Reference Field error terms are correlated across tie points
Proximities beyond ft with expansion rate of ft/1 OOOft are not reported
Cutoff is calculated on CENTRE to CENTRE distance
R ,....r·
~-t
. . ...."'...""
Summary data uses Closest Approach clearance calculation for all minima
Hole size/CasinQs are NOT included
Hole size/CasinQs are NOT subtracted from Centre-Centre distance
Ellipses scaled to 2.00standard deviations. Alaska Oil &
ClosinQ Factor Confidence limit of 99.80%
Errors on Ref start at Slot Permanent Datum (0.00)
APR 2 9 2005
Report uses Revised: (D-C)/E Factor Calculation
Well bore
Name I Created I Last Revised
A21-12 Ver 1 I 30-Mar-2005 I 30-Mar-2005
Well
Name I Government ID I Last Revised
A24-01 I I 19-0ct-2004
Name
slot #4-28
Grid Eastin
232840.8677
Slot
Latitude
N60 47 44.2218
North
6844.00N
East
378.00W
Installation
Name I Eastina I Northina I Coord Svstem Name I North Alinnment
Platform A I 233063.0833 I 2478929.9820 I AK-4 on NORTH AMERICAN DATUM 1927 datuml True
Field
Name I Eastina I Northina I Coord Svstem Name I North Alinnment
Middle Ground Shoal I 234754.5480 I 2500016.5290 I AK-4 on NORTH AMERICAN DATUM 1927 datuml True
Clearance Summary
Offset Offset Offset Offset Minimum MD[ft] I Diverging Ellipse Ellipse Clearance Clearance
WellName Well bore Slot Structure Distance From[ft] Separation MD[ft] Factor MD[ft]
[ftl rftl
A24-01 A24-01 LE slot #4-28 Platform A 0.02 8200.00 i 8200.00 -191.84 8200.00 0.00 8200.00
A24-01 A24-01 slot #4-28 Platform A I 0.02 8200.00 8200.00 -191.84 8200.00 0.00 8200.00
A14-01 A14-01 LN slot #4-26 Platform A 1340.87 8200.00 I 8200.00 1151.65 8200.00 7.04 8530.18
A14-01 A14-01 slot #4-26 Platform A 1340.87 8200.00 , 8200.00 1151.65 8200.00 7.04 8530.18
A14-01 A 14-01 LN2 slot #4-26 Platform A I 1341.38 8200.00 I 8200.00 1152.93 8200.00 7.12 8200.00
I
A11-12 A11-12 slot #2-13 Platform A 1526.20 9686.86 I 9686.86 1363.86 9678.48 9.40 9629.27
A12-12 A12-12 slot #4-27 Platform A 1623.83 10344.70 I 10344.70 1485.40 10285.43 11.61 9957.35
Surve Name
Planned
Error Model
Standard
All data is in Feet unless otherwise stated
Coordinates are from Slot and TVD's are from Rig ( Planned Datum 116.0ft above mean sea level)
Reference MD's are from Rig, Offset MD's are from Rig
Calculation method uses Minimum Curvature method
Confidence Limit of 95.45 (1 D)
Prepared by Baker Hughes Incorporated
Middle Ground Shoal
Platform A
XTO Energy., Inc..
Seale 1 em = 25 ft East (feet) _>
1850 1900 1950 2000 2050 2100 2150 2200 2'250 2300
3450
3400
3350
3300
3250
^ 3200
.
3150
.c
1::
~ 3100
3050
3000
2950
2800
¢:
~ 2750
II
E
:: 2700
( )
rn
(,)
(f) 2650
3650
'5200
7800
3600
3550
3500
2900
2850
7700
3050
7600
,# ,#
Ó'd''b 6'.s-'b 6;,.-q,
1850 1900 1950 2000 2050 2100 2150 2200 2250 2300 2350 2400 2450 2500 2550
Seale 1 em = 25 ft East ->
XTO Energy, Inc..
Field:
Installation:
Shoal
Well: A24-01
Wellbore: A21-12
A
Refwellpath isA21-12 Ver 1.
slot #4-28.
Depths are reference Rig Datum.
Measured Depths are reference Rig Datum.
Datum: Planned Datum
to mean 116.00 ft.
is North.
290
TRUE NORTH
280
270
260
250
200
160
190
180
170
Plane Travelling Cylinder - Feet
All depths shown
I
I
I
N
A21..12
Cook Inlet
etrack
Name Signature Date
Originator: Pat Young
Reviewed by: Mark Dick
Customer Approval: Sill Penrose
Version: 1.0 April 12,2005
4/13/2005
.
.
XTO A21.12 ..... '. <
Milling Operation
'.'
Drilling Fluid Syste'O) LSND
Key Products MI Barite, DUO-VIS, Pac Plus UL, Soda Ash, Caustic, Bicarb, Drilzone,
Spersene, Desco CF
"
Solids Control Shakers, Centrifuge, and Magnets
Metal cuttings.
Potential· Problems Torque.
Hole CleaninQ.
MILLING OPERATIONS MUD PROPERTIES
Depth
MD Mud Wt. Yield Point API Fll.!id I,,;oss c.t1t;oride
(ft) (Ib/gal) PV (lb/100ff) (mI130J11fn) 5. (l1'Ig/l) pH <,
".
8,200 9.0 15-25 40+ 5-6 <1000 9.0 -9.5
LSND Mud Formulation:
Soda Ash
Ge'l
Poly Pac
Duo-VIs
Barite
Asphosal Supreme
Resenex
0.2 Ib/bbl
10.0 Ib/bbl
1.5 Ib/bbl
1.75Ib/bbl
For 9.0 ppg.
3.0 Ib/bbl.
3.0 Ib/bbl.
Milling Operations
> The window will be milled with 9.0 Ib/gal LSND drilling fluid that is to be used to drill the Production
section of the well. This will negate the need for a fluid swap and weighting up.
> Maintain good rheology (40 YP) to remove the metal fragments from the wellbore.
> The possibility of problems caused by re-circulation of the metal shavings can be minimized by the
use of the finest shaker screens possible, ensuring the condition of the screens is monitored, and the
presence of sufficient magnets to capture all metal fragments.
> After milling the window circulate at least 1 % bottoms up to ensure that the hole is clean. Consider
using Super Sweep at the conclusion of the milling operations to assist in the removal of any residual
metal.
)õ> Clean the BOPE's, flowline, and all other downstream equipment to remove as much of the metal
debris as possible.
Milling Operations Recommended Solids Control Equipment
Shaker Screens
Centrifu e
Ma nets
110/160'5 or as needed to control mud loss over shakers.
Run as needed to control drill solids %, as well as mud wei ht.
At a ro riate locations
Location Kenai-Cook Inlet Alaska
4/13/2005
Confidential
R· r-f""';;r-
,,'C\,ø>f::IVED
APR 2 9 2005
Afd~ka un & G' " C 3
11;' l,;(¡íI<t 'ommiZSfOf¡
Anchvn:;ge
.
.
XTO A21-12
Production Interval - 6.0"
Drilling Fluid System LSND
Key Products MI Barite, MI Gel, DUO-VIS, Pac Plus UL, Soda Ash, Caustic, Bicarb,
Asphasol Supreme, Resenex , Desco CF
Solids Control Utilize all available equipment
Hole Cleaning
Potential Problems Hole integrity and condition for liner running and cementing
Directional control, Sliding
Lost circulation
INTERVAL MUD PROPERTIES
Depth MD Mud Wt. Yield Point API Fluid Loss Chlorides
(ft) (Ib/gal) (lb/100fe) (mIl30min) (mg/l) pH
8,200-10,728 10.0-10.5 12-15 8-1 0 cc <1000 9.5
Intermediate Hole Interval Operations
> Continue to use the 9.0 Ib/gal LSND mud to drill the Production section.
> Drill ahead using PAC materials to control fluid losses. Use Duo-vIS to maintain rheology. Tannathin,
Desco CF, may also be used to adjust and fine-tune the rheologies.
> Adjust rheology, ROP, pipe rotation speed, pipe running speeds and pump rates as needed to
balance hole cleaning and ECD.
> Mud weight will be weighted as the hole dictates.
Production Hole Interval Weight Up Fluid
Soda Ash
Poly Pac
Duo-VIs
Resinex
Asphasol Supreme
Barite
0.2 Ib/bbl
1.0 Ib/bbl
0.75Ib/bbl
Maintain 3.0 Ib/bbl
Maintain 3.0 Ib/bbl
Maintain 10.0-10.5 ppg
> Ensure that the flow rate is at least 350 gpm to ensure adequate hole cleaning is being achieved.
Reduce pump rates immediately if packing off occurs. Pump high viscosity weighted sweeps and
ream carefully to clean the hole before proceeding with further drilling.
> Upon reaching TD watch the bottoms-up cuttings closely. If the well does not readily cleanup or if
there is any excess of torque, drag, pick-up or slack-off weights pump a second high viscosity sweep
and circulate bottoms up again.
> A G-Seal" and Alpine Co-polymer bead pill consisting of 6#/bbl. of G-seal and 6#/bbl. beads will be
spotted in the open hole prior to running casing.
> If hole conditions allow adjust rheology to reduce swab/surge pressures prior to pulling out of the hole
for the 7.0" liner. (YP @ 20 - 25) Reduce viscosity according to cementing program after liner is on
bottom. Cement the 7.0" liner as per program.
Location Kenai-Cook Inlet Alaska
4/13/2005
Confidential
4
APR2 9 Z005
Alat~ka
.
.
!£j
Proposal No:404150252B
XTO Energy
A21-12
Middle Ground Shoal Field
Alaska
April 13, 2005
Cement Recommendation
Prepared for:
Bill Penrose
Project Drilling Engineer
Fairweather E&P Services Inc.
Prepared by:
J. Jay Garner
Manager, City Sales
Kenai, Alaska
Bus Phone: (907) 349-6518, Anchorage
Email: jgarner@bjservices.com
Mobile: (907) 229-6536
POW E R V I S I 0 N®
POWERPRO . POWERTRAX . POWERLINK
Service Point:
Kenai, AK
Bus Phone:
Fax:
(907) 776-4084
(907) 659-2329
(907) 776-4087
Service Representatives:
J. Jay Garner
Manager, City Sales
Kenai, Alaska
Bus Phone:
Email:
Mobile:
(907) 349-6518, Anchorage
jgarner@bjservices.com
(907) 229-6536
REC
APR 2 9 Z005
Ala::ka Œ¡ &, G
Gr41 05
.
Operator Name:
Well Name:
Job Description:
Date:
XTO Energy
A21-12
5" Liner @ 10,728'
April 13, 2005
.
f£j
Proposal No:404150252B
JOB AT A GLANCE
Depth (TVD)
Depth (MD)
Hole Size
Liner SizelWeight :
Pump Via
Total Mix Water Required
Weighted Spacer
MCS-4D
Density
1st Tail Slurry
Drilling Liner Slurry
Density
Yield
Displacement
Drilling Mud
Density
9,666 ft
10,728ft
6in
5 in, 18 Ibs/ft
Drill Pipe 31/2" 0.0. (2.764" .1.0) 13.3 #
Casing 5" O.D. (4.276" .I.D) 18 #
1,061 gals
40 bbls
11.0 ppg
216 sacks
15.8 ppg
1.15 cf/sack
111 bbls
10.5 ppg
Alat\:a
n ¡r-' 0
'à~. )~!;f'.'
~ v L...
APR 2. 9 2005
Commission
Þ.nd,arage
Report Printed on: April 13, 2005 3:53 PM
Gr4109
.
Operator Name:
Well Name:
Job Description:
Date:
XTO Energy
A21-12
5" Liner @ 10,728'
April 13, 2005
.
Wj
Proposal No:404150252B
WELL DATA
ANNULAR GEOMETRY
ANNULAR I.D.
(in)
6.184 CASING
6.000 HOLE
I
I
I
I
MEASURED
8,200
10,728
DEPTHlft}
I TRUE VERTICAL
I 7,186
I 9,666
SUSPENDED PIPES
DIAMETER lin} WEIGHT I DEPTH(ft)
O.D. I I.D. (Ibs/ft) I MEASURED (" TRUE VERTICAL
5.000 I 4.276 18 I 1 0,728 I 9,666
Drill Pipe 3.5 (in) OD, 2.764 (in)
ID, 13.3 (Ibs/ft) set @
Drill Pipe 5.0 (in) OD, 4.276 (in)
ID, 18 (Ibs/ft) set @
Depth to Top of Liner
Float Collar set @
Mud Density
Mud Type
Est. Static Temp.
Est. Circ. Temp.
VOLUME CALCULATIONS
500 ft x 0.0722 cf/ft
2,528 ft x 0.0600 cf/ft
7,700 ft
10,728 ft
7,700 ft
10,728 ft
10.50 ppg
Oil Based
151 0 F
135 0 F
with 0 % excess =
with 40 % excess =
TOTAL SLURRY VOLUME =
36cf
212 cf
248 cf
44 bbls
=
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APR 2 9 2005
Alaska Oil lJ-'ø,
. ,1 L.uns. C/)mmí~L¡H()n
AnC¡iGr::¡ge
Report Printed on: April 13, 2005 3:53 PM
Gr4117
.
.
Operator Name:
Well Name:
Job Description:
Date:
XTO Energy
A21-12
5" Liner @ 10,728'
April 13, 2005
Wj
Proposal No:404150252B
FLUID SPECIFICATIONS
Weighted Spacer
40.0 bbls MCS-4D + 7 Ibs/bbl MCS-D + 14
Ibs/bbl R-3 + 0.31 Ibs/bbl CD-31 + 29.5 Ibs/bbl
Bentonite + 118 Ibs/bbl Barite - Sacked @ 11
ppg
FLUID
VOLUME VOLUME
CU-FT FACTOR AMOUNT AND TYPE OF CEMENT
1st Tail Slurry
248 1.15 = 216 sacks Class G Cement + 0.1 % bwoc R-3 +
0.8% bwoc FL-63 + 0.3% bwoc CD-32 + 0.05%
bwoc ASA-301 + 1 gals/100 sack FP-6L + 43.6%
Fresh Water
Displacement
CEMENT PROPERTIES
110.9 bbls Drilling Mud @ 10.5 ppg
Slurry Weight (ppg)
Slurry Yield (cf/sack)
Amount of Mix Water (gps)
Amount of Mix Fluid (gps)
SLURRY
NO.1
15.80
1.15
4.91
4.92
1. Final additive loadings to be based on PRTC pilot blend data.
R J\/E[)
APR 2 9 2005
Alazka (}¡!
Report Printed on: April 13, 2005 3:53 PM
Gr4129
.
.
Wj
Operator Name: XTO Energy
Well Name: A21-12
Date: April 13, 2005
Proposal No:404150252B
PRODUCT DESCRIPTIONS
ASA-301
Additive used to reduce or eliminate free water and settling in cement slurries.
Barite - Sacked
A naturally occuring mineral (Barium Sulfate). It is widely used as a weighting material in cement
spacers and occasionally in cement slurries. It can yield a slurry density in excess of 19 Ibs/gal.
Bentonite
Commonly called gel, it is a clay material used as a cement extender and to control excessive free
water.
CD-31
A free flowing high molecular weight dispersant used to lower slurry viscosity and help provide turbulent
flow properties at reduced pump rates. CD-31 also assists in fluid loss control.
CD-32
A patented, free-flowing, water soluble polymer that is an efficient and effective dispersant for primary
and remedial cementing.
Class G Cement
Intended for use as a basic cement from surface to 8000 ft as manufactured, or can be used with
accelerators and retarders to cover a wide range of well depths and temperatures.
FL-63
A non-retarding, non-viscosifying fluid loss additive particularly suited for use with coil tubing and/or close
tolerance liner cementing. FL-63 is effective from low to high temperatures. Concentrations of 0.2% to
1.0% BWOC are typical.
FP-6L
A clear liquid that decreases foaming in slurries during mixing.
MCS-4
A turbulent flow spacer system that prevents water and oil-base mud and cement contamination and
water-wets the casing to increase bonding.
R-3
A low temperature retarder used in a wide range of slurry formulations to extend the slurry thickening
time.
,'VED
APR 2 9 2005
Ala::k;¡ 0:: ~;
r~ . ., ,
",ommlSSlOn
Report Printed on;
April 13, 2005 3:53 PM
Gr4163
13971
FAIRWEATHER EXPLORATION
& PRODUCTION SERVICES INC.
GENERAL ACCOUNT
PO. BOX 103296
ANCHORAGE, AK 99510-3296
PH. (907) 258-3446
FIRST NATIONAL BANK A LAS K A
89-6-1252
DATE
5/2/2005
AMOUNT
$100.00
PAY
One Hundred Dollars And 00 Cents
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TO THE
STATE OF ALASKA
ORDER
333 ~EST 7TH AVE SUITE 100
OF
ANCHORAGE AK 99501
L_______________________~
USA
III 0 * ~ g 7 * III I: * 2 5 2 0 0 0 b 0 I: 0 * * 2 B 2 ~ 0 III
L_____
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TRANSMIT AL LETTER CHECK LIST
CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO
BE INCLUDED IN TRANSMITTAL LETTER
WELL NAME mçS /f'Z-1 - I;>
PTD# ;2OS~~ 671
--I
CHECK WHAT
APPLIES
ADD-ONS
(OPTIONS)
MULTI
LATERAL
(If API number
last two (2) digits
are between 60-69)
"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.
HOLE In accordance with 20 AAC 25.005(t), 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 (50
70/80) from records, data and logs acquired
for well (name on permit).
PILOT
(PH)
SPACING
EXCEPTION
DRY DITCH
SAMPLE
Rev: 04/01105
C\jody\trans m ittal_ checklist
The permit is approved subject to full
compliance with 20 AAC 25.055. Approval to
perforate and produce/inject is contingent
upon issuance of a conservation order
approving a spacing exception.
(Company Name) assumes
the liability of any protest to the spacing
exception that may occur.
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 c ht and
10' sample intervals through targe zo J es.
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During 2000, XTO submitted a permit to drill application for a sidetrack of the A-24-01 LE well. This
sidetrack was approved as Permit to Drill #200-160, API #50-733-20258-02-00 on January 3, 2001. XTO
subsequently decided not to drill the sidetrack and requested AOGCC cancel the permit. The API number
of 50-733-20258-02-00 is associated with Permit to Drill #200-160 in AOGCC's databases. Once
assigned, an API number can not be re-used. Accordingly, this application to sidetrack A-24-01 LE is
assigned both a new permit to drill number (205-071) and a new API number (50-733-20258-03-00). SFD
MGS A21-12
Proposed 1-0il
Hemlock E, F & G
2050710
SFD
5/3/2005
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PTD#: 2050710
Administration
Well bore seg
Annular Disposal
Appr Date
SFD 5/3/2005
Engineering
Appr Date
l1fi1005
Geology
Appr
SFD
Date
5/3/2005
Geologic
Commissioner:
ÞT~
Field & Pool MIDDLE GROUND SHOAL, E,F,G OIL - 524114
D
D
Well Name: MGS A21-12 Program DEV
Company XTO ENERGY INC Initial ClassfType DEV / PEND GeoArea 820 Unit On/Off Shore Off
1 Permittee attache$:! _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . Yes _ . . . . . . . . . .. _.. _ _ _ _ _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _
2 _Lease.number .ap :!ropriate _ _ _ . . . . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No. _ _ . . . . . CQrrected 40Uorm: _OriginatweJI aod. &idetrack.b9thJQc~ted inAQL_0.1765.4. . _ _ _ _ _ _ . . .
3 .U.nique weltn.ame.a[ld oumb.er . . . _ . . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . _ _ _ . . Xes. . . . . . . See. C9mm.e [It at bQttom_oJ{orm.. . . . . . . . . . . . . . . . . . _ . _ . . _ . . . . . . . . . . . . . _ _ _ _ . . . . . . . .
4 WeJUocatedin.a.d.efine$:!pool_ _ _ _ _ _ _. _. _ _........ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _.. . MtD.DLEGRQUNDSHOAL,E,F.GOIL.-5241:14,.govemedþyC044. _ _ _... _ _ _. _ _ _ _ _ _ _...._
5 WeJUocated pr_operdistance from driJling unitb_ound~ry_ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes. . . . _ . . . _ . _ _ . . . _ . _ _ _ _ _ _ _ . _ . _ . . . . _ _ . . _ _
6 We.IUocated proper .dista[lœ_ from Qther wens_ _ _ _ _ _ . _ . . . . . . . . . . _ _ Yes _ _ _ _ _ _ f'> Q inter-welt spacing re&triqionsare &pecifie.dJn CO 44.. . _ . _ . _ _ _ _ _ _ _ _ _ . . _ _ _ _ . _ _ . . _
7 _S.ufficient.acreage_aYailable indrilliog unjt. .. . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ XelL . . . . . _ CO 44 s :!ecifies_nomore thao tw.o_oil com :!letioosJo a quarter se_ction, Jhis sidetraCk conforms t9.that ruJe, _
8 Jf.deviated, js. weJlbore platincJuded _ _ _ . . . _ . . _ . . _ _ _ _ _ _ _ Yes _ _ _ _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
9 _Operator only: affected party _ _ _ _ _ _ _ _ _ . _ . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . . . . . . . _ . . _ . . ... _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _
10 .Operator has.appropriate_Qond inJQrce. . _ . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ _ . . Yes. . . . . . . . . . . . . . . . . . _ . . _ _ . . . . _ . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . _ . _ _ . _ . . . . . . . . _
11 Permit G.é