Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout190-0711. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 6,430 feet N/A feet
true vertical 4,446 feet 4,990 feet
Effective Depth measured 4,990 feet 3,855 feet
true vertical 3,645 feet 2,999 feet
Perforation depth Measured depth 4,204 - 5,819 feet
True Vertical depth 3,192 - 4,110 feet
Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / L-80 4,748 MD 3,506 TVD
3,855 (MD) 465 (MD)
Packers and SSSV (type, measured and true vertical depth)Baker S-3 2,999 (TVD) Camco TRDP-4A-0 465 (TVD)
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13.
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Contact Name:
Authorized Title:
Contact Email:
Contact Phone:
Hilcorp Alaska, LLC
2. Operator Name
Senior Engineer: Senior Res. Engineer:
8,160psi
Daniel E. Marlowe
Operations Manager
Burst Collapse
Mark McKinley
mmckinley@hilcorp.com
Tubing Pressure
1,020psi2,630psi
907 777-8387
6,870psi
488
928
1,442
2,860
4,444
488
929
Conductor
Surface
7,020psi
4,760psi
28"
20"
16" 1,457
3,603
Size
55
Production
Casing
Structural
Liner 3,036
Length
Intermediate
N/A
Junk
5. Permit to Drill Number:
2,289
McArthur River Field / Middle Kenai Gas PoolN/A
measured
1,457
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
0
Gas-Mcf
43
N/A
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
320-181
30
Authorized Signature with date:
Authorized Name:
0
WINJ WAG
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
190-071
50-733-20417-00-00
Plugs
ADL0018730 Trading Bay Unit M-04
measured
3800 Centerpoint Dr, Suite 1400
Anchorage, AK 99503
3. Address:
4. Well Class Before Work:
0
Representative Daily Average Production or Injection Data
300
Casing PressureOil-Bbl
measured
true vertical
Packer
9-5/8"
7"
3,603
1,544
Water-Bbl
MD
488
929
6,430
TVD
PL
G
Form 10-404 Revised 3/2020 Submit Within 30 days of Operations
By Samantha Carlisle at 3:17 pm, May 28, 2020
Daniel Marlowe
I am approving this
document
2020.05.28 13:19:49 -08'00'
Daniel
Marlowe
Perforate
RBDMS HEW 5/29/2020
DSR-5/28/2020gls 6/4/20
_____________________________________________________________________________________
Updated By: JLL 05/27/20
SCHEMATIC
McArthur River Field
Well: M-04
Last Completed: 11/07/1999
PTD: 190-071
API: 50-733-20417-00
PBTD:6,344’ TD:6,430’
28”
RKBto Tbg Head =74’
7”
B-5
3
4
5
6
7
8
16”
9-5/8”
1
2
20”
B-6
C-2
C-3
C-4
B-1
B-3Suspected
WLEG damage
- do not exit
tubing tail
w/eline guns
– 05/04/20
X
X
X
Casing Detail
SIZE WT GRADE CONN ID TOP BTM.
28” Driven Surf 488’
20” 133 X-56 RL4-S 18.730” Surf 929’
16” 75 K-55 Buttress 15.124” Surf 1,457’
9-5/8” 47 L-80 Buttress 8.681” Surf 3,603’
7” 29 L-80 Buttress 6.184” 3,394’ 6,430’
Tubing Detail
4-1/2” 12.6 L-80 Imp. Mod. Butt. 3.958” Surf 4,748’
PERFORATION DATA
Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Date
B-1 4,204’ 4,244’ 3,192’ 3,214’ 2-7/8” 60 Deg, 6spf 05/06/20
B-3 4,382’ 4,444’ 3,294’ 3,330’ 2-7/8” 60 Deg, 6spf 05/04/20
B-3 4,456’ 4,547’ 3,337’ 3,390’ 2-7/8” 60 Deg, 6spf 05/04/20
B-5 4,823’ 4,892’ 3,549’ 3,589’ 2-7/8” 60 Deg, 6spf 10/25/19
B-5 4,905’ 4,930’ 3,596’ 3,611’ 2-7/8” HC, 6spf 10/17/2004
B-6 4,990' 5,015' 3,645' 3,659' 2-7/8” HC, 6spf 1/8/2001
C-2 5,529' 5,537' 3,949' 3,953' 2-7/8” HC, 6spf 11/7/1999
C-3 5,650' 5,696' 4,016' 4,042' 2-7/8” HC, 6spf 11/22/1999
C-4 5,792’ 5,819 4,095’ 4,110’ 2-7/8” HC, 6spf 10/16/2004
Jewelry Detail
NO.Depth
(MD)
Depth
(TVD)OD ID Item
1 74’ 74’ 16.750” 3.958” FMC 16.75” x 4-1/2” Butt. Tubing Hanger, Cameron Type H BPVP
2
459’ 459’ 5.230” 3.833” 4-1/2” Flow Coupling
464’ 464’ 5.250” 3.813” HES “X” Nipple (Screwed to the Camco TRDP-4A-0)
465’ 465’ 8.140” 3.805” 4-1/2” Camco TRDP-4A-0
3 1,678’ 1,649’ 6.600” 3.833”
4-1/2” Daniel’s SMO2 GLM. Upper GLM valve with ¼” port set for
1100 psi and lower GLM has ¼” orifice valve(6.600” Major OD))
4 3,366’ 2,729’ 6.600” 3.958”
4-1/2” Daniel’s SMO2 GLM - Orifice. Upper GLM valve with ¼”
port set for 1100 psi and lower GLM has ¼” orifice valve(6.600”
Major OD))
5 3,855’ 2,999’ 5.875” 3.833” 7” Baker S-3 Permanent Packer
6 3,895’ 3,021’ 5.600” 3.813” Baker X Nipple C/N 801-99-5799
7 4,715’ 3,487’ 5.600” 3.813” Baker X Nipple C/N 801-99-5799
8 4,748’ 3,506’ 5.200” 4.000” Baker Shear Out Ball Seat Sub - WLEG
TAG DATA
Date Depth Disc.
1/2/2000 6,175’ Fill
4/23/2000 6,153’ Fill
5/29/2001 6,096’ Fill
7/24/2002 5,969’ Fill
9/20/2004 5,929' Fill
10/17/2004 4,990' Fish
Fish: 10/17/2004 - Operations report the guns dragging at
each collar. Guns became stuck in tubing then fell to 4,990’
2-7/8” 6 spf HC 25’ gun plus tool string = 31.6’ total
B-1 4,204’4,244’3,192’3,214’2-7/8” 60 Deg, 6spf 05/06/20
B-3 4,382’4,444’3,294’3,330’2-7/8” 60 Deg, 6spf 05/04/20
B-3 4,456’4,547’3,337’3,390’2-7/8” 60 Deg, 6spf 05/04/20
///
,,,,/g,p//
new perfs
Rig Start Date End Date
Slickline/Eline 5/1/20 5/6/20
05/01/2020 - Friday
Attend pre-tour Production meeting. Pre-Job Safety mtg. RU SLU w/ 3.50" LIB toolstring. PT WLV & Lub =
350/1500 - good test. RIH w/ 3.50" LIB to 4990' KB set down. POOH. OOH w/ impression of E-line rope socket on
high side of LIB & perf debris in spangs. Send photo of LIB to Prod. Eng. and call same. Decision made to move
forward w/ 3.70" Blind Box and beat down on fish. Add Knuckle Jar to toolstring. MU 3.70" Blind Box toolstring.
RIH to 100' KB, unable to fall due to well flow. POOH & lay down 3.70" Blind Box. MU 3.50" Blind Box & RIH w/
same to top of fish @ 4990' KB. Beat down for 1 hour, fish does not move. POOH. RIH w/ 2-7/8" x 20' dummy
guns to 4900' KB. Do not tag, tubing clear. POOH. Call out E-Line crew. RD SLU and secure well. Clean area & spot
E-Line unit. Wait on E-line crew to arrive @ Platform on 3:00 PM chopper. Eline crew arrives @ Platform. SL crew
fly back to beach. Pre-Job Safety Meeting with Production Operators and Eline crew. RU ELU. MU GR/CCL and
surface test same. PU lubricator. MU 2-7/8" X 19' perf gun to GR/CCL. Move to well. PT WLV and Lub = 250/1500 -
Good Test. Open swab and RIH w/ GR/CCL/2-7/8" x 19' perf gun tool suite to 4900' ELM. PUH w/ overpull @ 4757'
ELM. Unable to pull into tubing, hanging up w/ 1000 lb. overpull @ WLEG. Work wire, No Change. Call Prod.
Engineer & discuss plan forward. Return to working wire w/ up to 2500 lb. pulls (1250 lb. overpull) @ WLEG. Tool
suite will fall to top of fish w/o resistance to top of fish at 4990' KB. Tool suite will not pass WLEG and re-enter
End of Tubing @ 4748' KB. Notify Prod Operators and Platform Foreman to prep for pull above weak point and
drop tool suite in 7". Decision is to secure well and ELU for night and talk to Offshore Asset Manager and
Engineer in morning before dropping tool suite. Shut down for night. Job in Progress.
Attend Platform Production Operations mtg. Pre-job safety mtg and permit. Fire up ELU. Work wire.
GR/CCL/Perf Gun tool suite is still detained @ End Of Tubing(EOT). Tool and wire will fall freely downhole &
PUH to EOT at normal running weights. Pull up to EOT, 4748' KB WLEG, and work wire overpull up to rope socket
weak point release. Weak Point Release @ 3160 lbs, ~ 2000 lb. overpull. Production Operator shut in well. POOH
slowly. Pull Eline cable into lubricator and above swab valve. Close Swab & bleed off pressures. Break off
lubricator. Cap lubricator, secure & return well to production. LD lubricator, recovered cable to weak point
tattle tale. No cable left in hole. Cut off 180' of cable & re-head. Call for replacement GR tool to be flown to
Platform. Suspend Job, move to ELU to M-09. Job in Progress.
05/02/2020 - Saturday
Daily Operations:
Hilcorp Alaska, LLC
Well Operations Summary
API Number Well Permit NumberWell Name
Trading Bay Unit M-04 50-733-20417-00-00 190-071
hanging up w/ 1000 lb. overpull @ WLEG. Work wire,
Rig Start Date End Date
Slickline/Eline 5/1/20 5/6/20
Daily Operations:
Hilcorp Alaska, LLC
Well Operations Summary
API Number Well Permit NumberWell Name
Trading Bay Unit M-04 50-733-20417-00-00 190-071
05/03/2020 - Sunday
SL crew arrives on Platform. Pre-Job safety & permit w/ Platform operators, EL crew & SL crew. RU SLU. MU SL
toolstring w/ 3.50" LIB and move to well. Production Operator shuts in @ flowline choke and locks open SSSV.
PT WLV & Lub = 250/1500 - Good Test. Open swab and RIH. Tag fish @ 4978' KB for impression. POOH. Close swab
and bleed pressure. Break off well, OOH w/ clear impression of clean rope socket. MU 1-1/4" JDC w/ 3.50" bell
guide fishing toolstring. Move to well. RIH to 4978' latch on fish. 30 oil jar licks, jars fail. Start working spangs,
come up 20' and then free. PUH w/ extra 450 lbs. POOH. Close swab, bleed off pressure. Break off well, OOH
w/ fish on. LD 36' ELine fish (RS/GR & CCL/firing head/2-7/8" x 19' perf gun). RDMO SLU. Return well to
production and bring well back online. Fly SL crew to the beach. MIRU ELU. MU EL tool suite (RS/GR & CCL/firing
head/2-7/8" x 19' perf gun). Surface test GR/CCL and arm perf gun. Move to well. PT WLV & Lub = 250/1500 -
Good Test. RIH w/ GR/CCL/2-7/8" x 19' perf gun tool suite to 4675' CCL depth w/ well flowing @ 1.50 MMSCFD,
T/IA = 30/40. PUH logging to 4000' CCL depth. Send LAS file & pdf copy of log to Town for correlation
verification. RE confirms -7.0' correction. Shift correlation log -7.0' & resend for verification. Corrected Log
Verified by RE. Will use Corrected Log as tie in log for all B-3/B-1 gun runs. RBIH to 4669' CCL depth w/ 2-7/8" x
19' perf gun, 6 spf, 60* phase, 15 gm HMX, GeoRazor carrier. CCL-to- Bottom Shot = 26.10', CCL-to-Top Shot =
7.10'. Log up to 4520.9' CCL depth (4520.9' + 26.10' = 4547' Bottom Shot'). Fire 19' perf gun perforating Zone B-3
from 4528' - 4547'. Log up 200' & POOH. OOH w/ all shots fired. PU Gun#2: 2-7/8" x 24', 6spf, 60* phase, 15 gm
HMX, GeoRazor carrier. CCL-to- Bottom Shot = 31.3', CCL-to-Top Shot = 7.3'. Move to well. Open swab & RIH to
4676' CCL. Log up to 4278', correct -2.0'. RBIH to 4676' CCL. Log up to 4496.7' CCL to place shots on depth (4496.7' +
7.3' = 4504' Top Shot). Fire to perforate Zone B-3 from 4504' - 4528'. Log up 200' & POOH. OOH w/ all shots fired.
PU Gun#3: 2-7/8" x 24', 6spf, 60* phase, 15 gm HMX, GeoRazor carrier. CCL-to- Bottom Shot = 31.3', CCL-to-Top
Shot = 7.3'. Move to well. Open swab & RIH to 4650' CCL. Log up to 4280', correct +1.0'. RBIH to 4650' CCL. Log up
to 4472.7' CCL to place shots on depth (4472.7' + 7.3' = 4480' Top Shot). Fire to perforate Zone B-3 from 4480' -
4504'. Log up 200' & POOH, OOH w/ all shots fired. Secure well and drill deck. Shut down for night. Job in
Progress.
Fire to perforate Zone B-3 from 4480' -
4504'. Log up 200' & POOH, OOH w/ all shots fired.
Fire 19' perf gun perforating Zone B-3
from 4528' - 4547'.
gun #1
Fire to perforate Zone B-3 from 4504' - 4528'.
Rig Start Date End Date
Slickline/Eline 5/1/20 5/6/20
Daily Operations:
Hilcorp Alaska, LLC
Well Operations Summary
API Number Well Permit NumberWell Name
Trading Bay Unit M-04 50-733-20417-00-00 190-071
PJSM & permit w/ Production Operators. Fire up ELU. PU Gun#8: 2-7/8" X 20', 6spf, 60* phase, 15 gm HMX,
GeoRazor carrier. Flow Rate = 2.073 MMSCFD, T/IA = 30/45. RIH CCL/GR/Gun#8(20'). BHA set down @ 2500' & free
spooled several hundred feet of Eline cable off winch drum creating a "bird nest". ELU counter @ 2500'. EL crew
packs off line wiper. Prod Operator shuts in well @ flowline control valve. Clamp cable @ surface & secure
clamp to WLV to prevent BHA from fall in hole. Set winch drum brake. Work ELine cable to remove bird nest.
Stripped bird nested cable off winch drum and coiled same on drill deck. Spool cable from drill deck back on
the winch drum. Remove clamp securing cable to WLV. Start POOH. Winch out 100' of cable and gain full weight
of BHA & 2500' of cable (750 lbs). Continue PUH, BHA picks up cleanly. POOH. OOH w/ Perf Gun#8 BHA. Scale
fines in bottom perf shot scallops. Secure well & turnover to production to bring back online. LD perf gun BHA &
riser. Strip off 3200' of cable and cut to remove all kinked and damaged cable. Re-head Eline cable. Shut down
for night. Job in Progress.
PJSM & permit w/ Production Ops & Eline crew. Fire up ELU. Surface test GR/CCL. PU and arm Perf Gun# 4: 2-
7/8" x 24', 6spf, 60* phase, 15 gm HMX, GeoRazor carrier. Move to well. Standby while Prod. Op. chase M-04
flowline and platform compressor issues. Production found scale in flowline control equipment. Well flowing
@ 1.70 MMSCFD, T/IA = 30/40. RIH Perf Gun# 4 to 4650' CCL. CCL-to-Top Shot = 7.3', CCL-to-Bottom Shot = 31.3',
CCL-to-Top Shot = 7.3'. Log up to 4237' CCL, correct +1.0'. RBIH to 4650' CCL. Log up to 4448.7' to place shots on
depth (4448.7' + 7.3' = 4456' Top Shot). Fire to perforate Zone B-3 from 4456' - 4480'. Log up 200' & POOH. OOH w/
all shots fired. Drain & catch trace of water & Beluga fines (~ 1/4 cup) from Gun# 4 bull plug. LD tools & riser so
crane can make pick for Production. Standby waiting on crane to complete Production pick. Production picked
completed in 15 min. Prod. Operator have scale @ surface in flowline control equipment after Gun# 4 returns to
surface. PU riser & Perf Gun#5: 2-7/8"" x 22', 6spf, 60* phase, 15 gm HMX, GeoRazor carrier. CCL-to- Bottom Shot
= 9.3', CCL-to-Top Shot = 31.3'. Move to well. Open swab & RIH to 4650' CCL. Log up to 4200', correct + 0.25'. RBIH
to 4650' CCL. Log up to 4412.7' CCL to place shots on depth (4412.7' + 7.3' = 4422' Top Shot). Fire to perforate Zone
B-3 from 4422' - 4444'. Log up 200' & POOH. OOH w/ all shots fired. Trace of water ~ 1/4 cup. Prod Ops shut in
well and removes scale from flowline control equipment. Return well to production after cleaning out scale.
Continue to standby while Town monitors flowrate trends of Well# M-04. Receive confirmation to resume
perforating operations. PU Perf Gun#6: 2-7/8" x 20', 6spf, 60* phase, 15 gm HMX, GeoRazor carrier. CCL-to-
Bottom Shot = 26.6', CCL-to-Top Shot = 6.6'. Move to well. Open swab & RIH to 4651' CCL. Log up to 4130', correct
+0.50'. RBIH to 4651' CCL. Log up to 4395.4' CCL to place shots on depth (4395.4' + 6.6' = 4402' Top Shot). Fire to
perforate Zone B-3 from 4402' - 4422'. Log up 200' & POOH. OOH w/ all shots fired & no water in bull plug. PU
Perf Gun#7: 2-7/8" x 20', 6spf, 60* phase, 15 gm HMX, GeoRazor carrier. CCL-to- Bottom Shot = 26.6', CCL-to-Top
Shot = 6.6'. Move to well. Open swab & RIH to 4600' CCL. Log up to 4130', correct +1.50'. RBIH to 4603' CCL
Log up to 4375.4' CCL to place shots on depth (4375.4' + 6.6' = 4382' Top Shot). Fire to perforate Zone B-3 from
4382' - 4402'. Log up 200' & POOH. OOH w/ all shots fired & no water in bull plug. Secure well & drill deck. Shut
down for night. Job in Progress.
05/05/2020 - Tuesday
05/04/2020 - Monday
RIH Perf Gun# 4 to 4650' CCL. CCL-to-Top Shot = 7.3', CCL-to-Bottom Shot = 31.3',
CCL-to-Top Shot = 7.3'. Log up to 4237' CCL, correct +1.0'. RBIH to 4650' CCL. Log up to 4448.7' to place shots on
depth (4448.7' + 7.3' = 4456' Top Shot).
Zone B-3 from 4402' - 4422'.
Fire to perforate Zone B-3 from 4456' - 4480'. F
Fire to perforate Zone B-3 from
4382' - 4402'. Lo
B-3 from 4422' - 4444'. Log u
BHA set down @ 2500' & free
gun #4
B3 zone
Rig Start Date End Date
Slickline/Eline 5/1/20 5/6/20
Daily Operations:
Hilcorp Alaska, LLC
Well Operations Summary
API Number Well Permit NumberWell Name
Trading Bay Unit M-04 50-733-20417-00-00 190-071
05/06/2020 - Wednesday
PJSM w/ Production Operators & permit. Fire up ELU. MU Perf Gun#8 BHA. Surface test GR/CCL. Arm 20' perf
gun: 2-7/8 x 20', 6 spf, 60* phase, 15 gm HMX, GeoRazor carrier. CCL-to-Top Shot = 6.6', CCL-to-Bottom Shot =
26.6'. M-04 = 2.073 MMSCFD. WSM requests & Production Operators reduce flow rate = 0.900 MMSCFD. T/IA =
54/45. Move to well. RIH w/ 2-7/8" X 20' Perf Gun#8 BHA. Tension bobble @ 2510', TIH to 2700' CCL. Make pass
back up to 2400', tension bobble again passing 2500'. RBIH and make a 2nd repeat pass to 2400'. Pull up clean
and RBIH by 2500' clean. Continue TIH to 4650' CCL. Pull correlation log from 4650' to 3830'. Send to Town for
analysis. Geo requests +2' correction. Add correction & resend. Correction verified by RE. RBIH to 4450' CCL. Log
up to 4217.4' to place shots on depth (4127.4' + 6.6' = 4224' Top Shot). Fire Perf Gun#8 to perforate Zone B-1 4224' -
4244'. Log up 200' & POOH. OOH w/ all shots fired. ~ 1/4 cup water in perf gun bull nose plug. No fines in water.
PU Perf Gun#9: 2-7/8" X 20', 6spf, 60* phase, 15 gm HMX. RIH w/ Perf Gun#9 to 4452 CCL. Log up to 4100', make
+4.5' correction. RBIH to 4450' CCL. Log up to 4197.4' CCL to place shots on depth (4197.4' = 6.6' = 420' Top Shot).
Fire Gun#9 to perf Zone B-1 4204' - 4224'. Log up 200' & POOH. OOH w/ all shots fired. No water in gun - DRY. RD
ELU and pack up & stage Eline equipment on platform drill deck. Turn over well to Production and slowly open
up to full rate. Clean drill deck area. Fly crew to beach. Job Complete.
e Zone B-1 4224'-
4244'.
B-1 4204' - 4224'. Log u
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require a spacing exception? Yes No
9. Property Designation (Lease Number): 10. Field/Pool(s):
McArthur River Field / Middle Kenai Gas Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
6,430'~4,990
Casing Collapse
Structural
Conductor
Surface
Intermediate 1,020 psi
Production 4,760 psi
Liner 7,020 psi
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
Commission Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:mmckinley@hilcorp.com
Contact Phone: (907) 777-8387
Date:
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
Authorized Signature:
Operations Manager
Mark McKinley
PRESENT WELL CONDITION SUMMARY
Length Size
2,630 psi
N/A
COMMISSION USE ONLY
Authorized Name:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0018730
190-071
50-733-20417-00-00Anchorage, AK 99503
Hilcorp Alaska, LLC
Trading Bay Unit M-04
CO 228A
12.6 / L-80
TVD Burst
4,748
6,870 psi
8,160 psi
Tubing Size:
MD
488'
928'
1,442'
488'
929'
28"
20"
488'
16"1,457'
929'
3,603'
Perforation Depth MD (ft):
1,457'
4,823 - 5,819
3,603'
3,855 (MD) 2,999 (TVD) & 465 (MD) 465 (TVD)
Tubing Grade: Tubing MD (ft):
3,549 - 4,110
Perforation Depth TVD (ft):
Authorized Title:
17. I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
5/12/2020
4-1/2"
Daniel E. Marlowe
Baker S-3 Packer & Camco TRDP-4A-0 SSSV
4,446' 4,990' 3,645' 1,302 psi
3,036' 7"
2,860'9-5/8"
6,430' 4,444'
Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval.
Daniel Marlowe
I am approving this
document
2020.04.27 15:08:37 -08'00'
Daniel
Marlowe
By Samantha Carlisle at 3:25 pm, Apr 27, 2020
320-181
DLB-04/27/2020 DSR-4/27/2020
X 10-404
gls 4/28/20
Com m
tion Required? Yes
4/28/2020
dts 4/28/2020
JLC 4/28/2020
Well Work Prognosis
Well Name:Trading Bay Unit M-04 API Number: 50-733-20417-00
Current Status:Gas Well Leg:B-2 (NE corner)
Estimated Start Date:5/12/2020 Rig:E-Line
Reg. Approval Req’d?403 Date Reg. Approval Rec’vd:
Regulatory Contact:Juanita Lovett Permit to Drill Number:190-071
First Call Engineer:Mark McKinley Office: 907-777-8387 Cell: 907-953-2685
Second Call Engineer:Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904
Current Bottom Hole Pressure:385 psi @ 3,549’ TVD 0.1 psi/ft Gas Gradient to surface
Maximum Expected BHP:1,694 psi @ 3,911’ TVD 0.433 psi/ft Water Gradient to Surface
Maximum Potential Surface Pressure:1,302 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4)
**Well to be perforated while flowing
Brief Well Summary:
Well M-04 is a gas well completed in the B & C Sands. This project will add additional perforations in the
B-1, B-3, and C-1 Sand.
E-line Procedure:
1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low.
2. RU e-line guns and perforate with well flowing per program.
3. RD E-line.
4. Turn well over to production.
Attachments:
1. Current Wellbore Schematic
2. Proposed Wellbore Schematic
_____________________________________________________________________________________
Updated By: JLL 11/06/19
SCHEMATIC
McArthur River Field
Well: M-04
Last Completed: 11/07/1999
PTD: 190-071
API: 50-733-20417-00
PBTD: 6,344’ TD: 6,430’
28”
RKBto Tbg Head = 74’
7”
B-5
3
4
5
6
7
8
16”
9-5/8”
1
2
20”
B-6
C-2
C-3
C-4
X
X
X
Casing Detail
SIZE WT GRADE CONN ID TOP BTM.
28” Driven Surf 488’
20” 133 X-56 RL4-S 18.730” Surf 929’
16” 75 K-55 Buttress 15.124” Surf 1,457’
9-5/8” 47 L-80 Buttress 8.681” Surf 3,603’
7” 29 L-80 Buttress 6.184” 3,394’ 6,430’
Tubing Detail
4-1/2” 12.6 L-80 Imp. Mod. Butt. 3.958” Surf 4,748’
PERFORATION DATA
Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Date
B-5 4,823’ 4,892’ 3,549’ 3,589’ 2-7/8” 60 Deg, 6spf 10/25/19
B-5 4,905’ 4,930’ 3,596’ 3,611’ 2-7/8” HC, 6spf 10/17/2004
B-6 4,990' 5,015' 3,645' 3,659' 2-7/8” HC, 6spf 1/8/2001
C-2 5,529' 5,537' 3,949' 3,953' 2-7/8” HC, 6spf 11/7/1999
C-3 5,650' 5,696' 4,016' 4,042' 2-7/8” HC, 6spf 11/22/1999
C-4 5,792’ 5,819 4,095’ 4,110’ 2-7/8” HC, 6spf 10/16/2004
Jewelry Detail
NO.Depth
(MD)
Depth
(TVD)OD ID Item
1 74’ 74’ 16.750” 3.958” FMC 16.75” x 4-1/2” Butt. Tubing Hanger, Cameron Type H BPVP
2
459’ 459’ 5.230” 3.833” 4-1/2” Flow Coupling
464’ 464’ 5.250” 3.813” HES “X” Nipple (Screwed to the Camco TRDP-4A-0)
465’ 465’ 8.140” 3.805” 4-1/2” Camco TRDP-4A-0
3 1,678’ 1,649’ 6.600” 3.833”
4-1/2” Daniel’s SMO2 GLM. Upper GLM valve with ¼” port set for
1100 psi and lower GLM has ¼” orifice valve(6.600” Major OD))
4 3,366’ 2,729’ 6.600” 3.958”
4-1/2” Daniel’s SMO2 GLM - Orifice. Upper GLM valve with ¼”
port set for 1100 psi and lower GLM has ¼” orifice valve(6.600”
Major OD))
5 3,855’ 2,999’ 5.875” 3.833” 7” Baker S-3 Permanent Packer
6 3,895’ 3,021’ 5.600” 3.813” Baker X Nipple C/N 801-99-5799
7 4,715’ 3,487’ 5.600” 3.813” Baker X Nipple C/N 801-99-5799
8 4,748’ 3,506’ 5.200” 4.000” Baker Shear Out Ball Seat Sub - WLEG
TAG DATA
Date Depth Disc.
1/2/2000 6,175’ Fill
4/23/2000 6,153’ Fill
5/29/2001 6,096’ Fill
7/24/2002 5,969’ Fill
9/20/2004 5,929' Fill
10/17/2004 4,990' Fish
Fish: 10/17/2004 - Operations report the guns dragging at
each collar. Guns became stuck in tubing then fell to 4,990’
2-7/8” 6 spf HC 25’ gun plus tool string = 31.6’ total
_____________________________________________________________________________________
Updated By: JLL 04/24/20
PROPOSED
McArthur River Field
Well: M-04
Last Completed: 11/07/1999
PTD: 190-071
API: 50-733-20417-00
PBTD: 6,344’ TD: 6,430’
28”
RKBto Tbg Head = 74’
7”
B-5
3
4
5
6
7
8
16”
9-5/8”
1
2
20”
B-6
C-2
C-3
C-4
B-1
B-3
C-1
X
X
X
Casing Detail
SIZE WT GRADE CONN ID TOP BTM.
28” Driven Surf 488’
20” 133 X-56 RL4-S 18.730” Surf 929’
16” 75 K-55 Buttress 15.124” Surf 1,457’
9-5/8” 47 L-80 Buttress 8.681” Surf 3,603’
7” 29 L-80 Buttress 6.184” 3,394’ 6,430’
Tubing Detail
4-1/2” 12.6 L-80 Imp. Mod. Butt. 3.958” Surf 4,748’
PERFORATION DATA
Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Date
B-1 ±4,204’ ±4,270’ ±3,192’ ±3,229’ Future
B-3 ±4,382’ ±4,444’ ±3,294’ ±3,330’ Future
B-3 ±4,456’ ±4,547’ ±3,337’ ±3,390’ Future
B-5 4,823’ 4,892’ 3,549’ 3,589’ 2-7/8” 60 Deg, 6spf 10/25/19
B-5 4,905’ 4,930’ 3,596’ 3,611’ 2-7/8” HC, 6spf 10/17/2004
B-6 4,990' 5,015' 3,645' 3,659' 2-7/8” HC, 6spf 1/8/2001
C-2 5,529' 5,537' 3,949' 3,953' 2-7/8” HC, 6spf 11/7/1999
C-1 ±5,406’ ±5,462’ ±3,880’ ±3,911’ Future
C-3 5,650' 5,696' 4,016' 4,042' 2-7/8” HC, 6spf 11/22/1999
C-4 5,792’ 5,819 4,095’ 4,110’ 2-7/8” HC, 6spf 10/16/2004
Jewelry Detail
NO.Depth
(MD)
Depth
(TVD)OD ID Item
1 74’ 74’ 16.750” 3.958” FMC 16.75” x 4-1/2” Butt. Tubing Hanger, Cameron Type H BPVP
2
459’ 459’ 5.230” 3.833” 4-1/2” Flow Coupling
464’ 464’ 5.250” 3.813” HES “X” Nipple (Screwed to the Camco TRDP-4A-0)
465’ 465’ 8.140” 3.805” 4-1/2” Camco TRDP-4A-0
3 1,678’ 1,649’ 6.600” 3.833”
4-1/2” Daniel’s SMO2 GLM. Upper GLM valve with ¼” port set for
1100 psi and lower GLM has ¼” orifice valve(6.600” Major OD))
4 3,366’ 2,729’ 6.600” 3.958”
4-1/2” Daniel’s SMO2 GLM - Orifice. Upper GLM valve with ¼”
port set for 1100 psi and lower GLM has ¼” orifice valve(6.600”
Major OD))
5 3,855’ 2,999’ 5.875” 3.833” 7” Baker S-3 Permanent Packer
6 3,895’ 3,021’ 5.600” 3.813” Baker X Nipple C/N 801-99-5799
7 4,715’ 3,487’ 5.600” 3.813” Baker X Nipple C/N 801-99-5799
8 4,748’ 3,506’ 5.200” 4.000” Baker Shear Out Ball Seat Sub - WLEG
TAG DATA
Date Depth Disc.
1/2/2000 6,175’ Fill
4/23/2000 6,153’ Fill
5/29/2001 6,096’ Fill
7/24/2002 5,969’ Fill
9/20/2004 5,929' Fill
10/17/2004 4,990' Fish
Fish: 10/17/2004 - Operations report the guns dragging at
each collar. Guns became stuck in tubing then fell to 4,990’
2-7/8” 6 spf HC 25’ gun plus tool string = 31.6’ total
gls
Fish above
proposed perfs
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
,- LIVED
NOV 0 8 2019
A e%^....
1. Operations Abandon L Plug Perforations
Ll Fracture Stimulate LJ Pull Tubing L Opera ions s tdown
Performed: Suspend ❑ Perforate
❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑
Plug for Redrill ❑ Perforate New Pool
❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑
2. Operator
4. Well Class Before Work: 5. Permit to Drill Number:
Name: Hilcorp Alaska, LLC
Development ❑✓ Exploratory ❑ 190-071
3. Address: 3800 Centerpoint Drive, Suite 1400
Stratigraphic ❑ Service ❑ 6. API Number:
Anchorage, AK 99503
50-733-20417-00-00
7. Property Designation (Lease Number):
8. Well Name and Number:
ADL0018730
Trading Bay Unit M-04
9. Logs (List logs and submit electronic and printed data per 2 AAAC25.071):
10. Field/Pool(s):
N/A
McArthur River Field / Middle Kenai Gas Pool
11. Present Well Condition Summary:
Total Depth measured 6,430
feet Plugs measured N/A feet
true vertical 4,446
feet Junk measured —4,990 feet
Effective Depth measured 4,990
feet Packer measured 3,855 feet
true vertical 3,645
feet true vertical 2,999 feet
Casing Length Size
MD TVD Burst Collapse
Structural
Conductor 488' 28"
488' 488'
Surface 929' 20"
929' 928'
Intermediate 1,457' 16"
1,457' 1,442' 2,630 psi 1,020 psi
Production 3,603' 9-5/8"
3,603' 2,860' 6,870 psi 4,760 psi
Liner 3,036' 7"
6,430' 4,444' 8,160 psi 7,020 psi
Perforation depth Measured depth 4,823 - 5,819
feet
True Vertical depth 3,549 - 4,110
feet
Tubing (size, grade, measured and true vertical depth)
4-1/2" 12.6 / L-80 4,748 (MD) 3,506 (TVD)
3,855 (MD) 465 (MD)
Packers and SSSV (type, measured and true vertical depth)
Baker S-3 2,999 (TVD) Camco TRDP-4A-0 465 (TVD)
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
N/A
Treatment descriptions including volumes used and final pressure:
N/A
13.
Representative Daily Average Production or Injection Data
Oil -Bbl
Gas -Md Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation: 0
1196 0 40 30
Subsequ:1 0
1830 0 40 30
14. Attachments (required per20 AAC 25.070, 25.071, 825.283)
15. Well Class after work:
Daily Report of Well Operations ❑✓
Exploratory ❑ Development ✓
p ❑ Service ❑ Stratigraphic ❑
Copies of Logs and Surveys Run El
16. Well Status after work: Oil El ✓ WDSPL ❑
Printed and Electronic Fracture Stimulation Data ❑
GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑
17. 1 hereby Certify that the foregoing is true and Correct t0 the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
319-451
Authorized Name: Stan W. Golis
Contact Name: Dan Marlowe
Authorized Title: Operations Manager
Contact Email: dmMarlowe@hilcorp.com
t>t"
Authorized Signature:
Contact Phone: (907) 283-1329
Date: t tLLOL
4 /
Form 101104 Revised 4/2017 r� //-157/1 A IOell1
Oell` Original Only
K
corn Alaska. LLC
RKBto Tbg Head = 74'
PBTD: 6,344' TD: 6,430'
SCHEMATIC
McArthur River Field
Well: M-04
Last Completed: 11/07/1999
PTD: 190-071
API: 50-733-20417-00
Casing Detail
SIZE
WT
GRADE
CONN
ID
TOP
BTM.
28"
74'
16.750"
Driven
FMC 16.75" x 4-1/2" Butt Tubing Hanger, Cameron Type H BPVP
Surf
488'
20"
133
X-56
RL4-S
18.730"
Surf
929'
16"
75
K-55
Buttress
15.124"
Surf
1,457'
9-5/8"
47
L-80
Buttress
8.681"
Surf
3,603'
7"
29
L-80
Buttress
6.184"
3,394'
6,430'
Tubing Detail
41/2" 12.6 L-80 I Imp. Mod. Butt. 3.958" Surf 4,748'
Jewelry, Detail
NO.
Depth
(MD)
Depth
(TVD)
OD
ID
Item
1
74'
74'
16.750"
3.958"
FMC 16.75" x 4-1/2" Butt Tubing Hanger, Cameron Type H BPVP
2-7/8" 60 Deg, 6spf
459'
459'
5.230"
3.833"
4-1/2" Flow Coupling
2
464'
464'
5.250"
3.813"
HES "X" Nipple (Screwed to the Camco TRDP-4A-0)
3,645'
465'
465'
8.140"
3.805"
4-1/2"Camco TRDP-4A-0
3
1,678'
1,649'
6.600"
3.833"
4-1/2" Daniel's SM02 GLM. Upper GLM valve with '/.'portsetfor
1100 psi and lower GLM hasY' orifice valve(6.600" Major OD))
4
3,366'
2,729'
6.600"
3.958"
4-1/2" Daniel's SM02 GLM -Orifice. Upper GLM valve with V
port set for 1100 psi and lower GLM has''/." orifice valve(6.600"
Major OD))
5
3,855'
2,999'
5.875"
3.833"
7" Baker S-3 Permanent Packer
6
3,895'
3,021'
5.600"
3.813"
Baker X Nipple C/N 801-99-5799
7
4,715'
3,487'
5.600"
3.813"
Baker Nipple C/N 801-99-5799
8
4,748'
3,506'
5.200"
4.000"
Baker Shear Out Ball Seat Sub-WLEG
PERFORATION DATA
Zone
Top (MD)
Btm (MD)
Top (TVD)
Btm (TVD)
SPF
Date
B-5
4,823'
4,892'
3,549'
3,589'
2-7/8" 60 Deg, 6spf
10/25/19
B-5
4,905'
4,930'
3,596'
3,611'
2-7/8" HC, 6spf
10/17/2004
B-6
4,990'
5,015'
3,645'
3,659'
2-7/8" HC, 6spf
1/8/2001
C-2
5,529'
5,537'
3,949'
3,953'
2-7/8" HC, 65pf
11/7/1999
C-3
5,650'
51696'
4,016'
41042'
2-7/8" HC, 6spf
11/22/1999
C-4
5,792' 1
5,819
4,095'
4,110'
2-7/8" HC, 6spf
10/16/2004
TAG DATA
Date
sc.
1/2/2000ill
4/23/2000ill
5/29/2001ill
Vqqnrimh
7/24/2002ill
9/20/2004ll
10/17/2004h
Fish: 10/17/2004 - Operations report the guns dragging at
each collar. Guns became stuck in tubing then fell to 4,990'
2-7/8" 6 spf HC 25' gun plus tool string = 31.6' total
Updated By: JUL 11/06/19
Hilcorp Alaska, LLC
Well Operations Summary
Well Name Rig
API Number Well Permit Number
Start Date End Date
Trading Bay Unit M-04 I Eline
50-733-20417-00-00 190-071
110/25/19110/25/19
Daily Operations:
10/25/19 - Friday
Crews unload boat & spot eq. Rig up a -line. PT Lubricator 250 /1500, good. RIH t/4900. Log up t/- 4740', having issues
pulling past, free down cont. working, until pulling through. Cont. POOH. Look at tools, had sand on tools, cleaned off. PT
lub 250/1500, good. RIH t/ 4900' log up t/ 4750, send log to town for correlation, verification good. Shoot interval 4869'-
4892'w/ 2 7/8" guns 60 deg Phasing, 6-spf, good indication gun fired. POOH, all shots fired. C/o guns. PT lubricator
250/1500, good. RIH log, correlation up t/4750, put guns on depth (/4846'-4869', attempt fire, no joy. POOH test tools,
had loss of communication at bottom of GR. Changed out & tested good. M/U lubricator & test 250/1500, good. RIH
t/4880' log up t/ 4750', correlate, put guns on depth f/4846'-4869', fire guns, good indication of guns firing. POOH. All
shots fired. C/o guns. M/U lubricator & test 250/1500, good. RIH t/4880' log up t/ 4750', correlate, put guns on depth
(/4823'-4846', fire guns, good indication of guns firing. POOH, all shots fired. R/D a -line.
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
Stan W. Golis
Operations Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Re: McArthur River Field, Middle Kenai Gas Pool, TBU M-04
Permit to Drill Number: 190-071
Sundry Number: 319-451
Dear Mr. Golis:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.claska.gov
Enclosed is the approved application for the sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
1 r vM
Je .Price
Chair
DATED this day of October, 2019.
-113DMSLf-Ljpr'T 1 Q 2019
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25 280
('{t^•— (ti ii 20,793
SA
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑
Suspend ❑ Perforate Q • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter CasingEl ❑ Other:
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
Hilcorp Alaska, LLC
Exploratory ❑ Development Q ,
Stratigraphic ❑ Service ❑
190-071 .
3. Address: 3800 Centerpoint Drive, Suite 1400
6. API Number:
Anchorage, AK 99503
50-733-20417-00-00 '
7. If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? CO 228A -
Will planned perforations require a spacing exception? Yes ❑ No ❑Q
Trading Bay Unit - M-04
9. Property Designation (Lease Number): 10. Field/Pool(s):
ADL0018730 I McArthur River Field / Middle Kenai Gas Pool
11, PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft):
Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
6,430 - 4,446
4,990 3,645 151 psi N/A -4,990'
Casing Length
Size MD F D Burst Collapse
Structural
Conductor 488'
28" 488' 488'
Surface 929'
20" 929' 928'
Intermediate 1,457'
16" 1,457' 1,442' 1 2,630 psi 1,020 psi
Production 3,603'
9-5/8" 3,603' 2,860' 6,870 psi 4,760 psi
Liner 3,036'
7" 6,430' 4,444' 8,160 psi 7,020 psi
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
4,905 - 5,819
13,596 -4,110
4-1/2"
12.6# / L-80
4,748
Packers and SSSV Type:
Packers and SSSV MD (ft) and TVD (ft):
Baker S-3 & Carrico TRDP-4A-0
3,855 (MD) 2,999 (TVD) and 465 (MD) 465 (TVD)
12. Attachments: Proposal Summary Q Wellbore schematic Q
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Strati ra hic
g p ❑ Development ❑� Service ❑
14. Estimated Date for
15. Well Status after proposed work:
Commencing Operations10/28/2019 :
❑ WINJ ❑ WDSPL
OIL ❑ Suspended ❑
GAS WAG ❑ GSTOR ❑ SPLUG ❑
16. Verbal Approval: Date:
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Name: Stan W. Golis Contact Name: Dan Marlowe
Authorized Title: Operations Manager Contact Email: drnarlOWe hICOr .COfr1
Contact Phone: (907) 283-1329
J
Authorized Signature: R. Date: �
S7%X4/ COMMISS N SE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
� Y V I — W(✓_
Plug Integrity F-1BOP Test ElMechanical Integrity Test ❑ Location Clearance ❑
Other:
3BDMS�� OCT 10 2019
Post Initial Injection MIT Req'd? Yes ❑ No ❑
/
Spacing Exception Required? Yes E]Nod Subsequent Form Required: / Q —c / 0
APPROVED BY
Approved by: 1 COMMISSIONER THE COMMISSION Date:' 0 I-fbI I 1
�rm46-473t 14i d17 Approved awl( Ri IsMMiJfdr SAL from the date of approval.
llJ P'lS
Submit Form and
Attachments iq Duplicate
1> Jn- I /Li
N
Hikwp Alpeka, LLC
Well Work Prognosis
Well Name:
Trading Bay Unit M-04 .
API Number:
50-733-20417-00
Current Status:
Gas Well
Leg:
B-2 (NE corner)
Estimated Start Date:
10/28/2019
Rig:
E -Line
Reg. Approval Req'd?
403
Date Reg. Approval Rec'vd:
Regulatory Contact:
Juanita Lovett
Permit to Drill Number:
190-071
First Call Engineer:
Dan Marlowe
Office: 907-283-1329
Cell: 907-398-9904
Second Call Engineer:
Stan Golis
Office: 907-777-8356
Current Bottom Hole Pressure: 505 psi @ 3,542' TVD 0.143 psi/ft SIBP '
Maximum Expected BHP: 505 psi @ 3,542' TVD 0.143 psi/ft SIBP
Maximum Potential Surface Pressure: 151 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4)
**Well to be perforated while flowing
Brief Well Summary:
Well M-04 is a gas well completed in the B & C Sands. This project will add additional perforations in the
B-5 Sand.
E -line Procedure:
1. MIRU E -line, PT lubricator to 1,500 psi Hi 250 Low.
2. RU a -line guns and perforate with well flowing per program.
3. RD E -line.
4. Turn well over to production.
Attachments:
1. Current Wellbore Schematic
2. Proposed Wellbore Schematic
11ilcorn Alaska, LLC
RKBto Tbg Head = 74
PBTD: 6,344' TD: 6,434
SCHEMATIC
McArthur River Field
Well: M-04
Last Completed: 11/07/1999
PTD: 190-071
API: 50-733-20417-00
Casing Detail
SIZE
WT
GRADE
CONN
ID
TOP
BTM.
28"
74'
16.750"
Driven
FMC 16.75" x 4-1/2" Butt. Tubing Hanger, Cameron Type H BPVP
Surf
488'
20"
133
X-56
RL4-S
18.730"
Surf
929'
16"
75
K-55
Buttress
15.124"
Surf
1,457'
9-5/8"
47
L-80
Buttress
8.681"
Surf
3,603'
7"
29
L-80
Buttress
6.184"
3,394'
6,434
rubing Detail
4-1/2" I 12.6 I L-80 I Imp. Mod. Butt. I 3.958" 1 Surf I 4,748'
Jewelry Detail
NO.
Depth
(MD)
Depth
(TVD)
O D
ID
Item
1
74'
74'
16.750"
3.958"
FMC 16.75" x 4-1/2" Butt. Tubing Hanger, Cameron Type H BPVP
2-7/8" HC, 6spf
459'
459'
5.230"
3.833"
4-1/2" Flow Coupling
2
464'
464'
5.250"
3.813"
HES "X" Nipple (Screwed to the Camco TRDP-4A-0)
3,949'
465'
465'
8.140"
3.805"
4-1/2" Carrico TRDP-4A-0
3
1,678'
1,649'
6.600"
3.833"
4-1/2" Daniel's SM02 GLM. Upper GLM valve with Y.."portsetfor
1100 psi and lower GLM has Y." orifice valve(6.600" Major OD))
4
3,366'
2,729'
6.600"
3.958"
4-1/2" Daniel's SM02 GLM -Orifice. Upper GLM valve with Y"
port set for 1100 psi and lower GLM has Y<" orifice valve(6.600"
Major OD))
5
3,855'
2,999'
5.875"
3.833"
7" Baker S-3 Permanent Packer
6
3,895'
3,021'
5.600"
3.813"
Baker X Nipple C/N 801-99-5799
7
4,715'
3,487'
5.600"
3.813"
Ba kerX Nipple C/N 801-99-5799
8
4,748'
3,506'
5.200"
4.000"
Baker Shear Out Ball SeatWEG
PERFORATION DATA
Zone
Top (MD)
Btm (MD)
Top (TVD)
Btm (TVD)
SPF
Date
B-5
4,905'
4,930'
3,596'
3,611'
2-7/8" HC, 6spf
10/17/2004
B-6
4,990'
5,015'
3,645'
3,659'
2-7/8" HC, 6spf
1/8/2001
C-2
5,529'
5,537'
3,949'
3,953'
2-7/8" HC, 6spf
11/7/1999
C-3
5,650'
5,696'
4,016'
4,042'
2-7/8" HC, 6spf
11/22/1999
C-4
5,792'
5,819
4,095'
4,110'
2-7/8" HC, 6spf
10/16/2004
TAG DATA
Date
Depth
Disc.
1/2/2000
6,175'
Fill
4/23/2000
6,153'
Fill
5/29/2001
6,096'
Fill
7/24/2002
5,969'
Fill
9/20/2004
5,929'
Fill
10/17/2004 1
4,990'
Fish
Fish: 10/17/2004 - Operations report the guns dragging at
each collar. Guns became stuck in tubing then fell to 4,990'
2-7/8" 6 spf HC 25' gun plus tool string = 31.6' total
Updated By: JLL 10/20/17
ff
corp Alaska, LLC
RKBto Tbg Head = 74'
PBTD: 6,344' TD: 6,430'
PROPOSED
McArthur River Field
Well: M-04
Last Completed: 11/07/1999
PTD: 190-071
API: 50-733-20417-00
Casing Detail
SIZE
WT
GRADE
CONN
ID
TOP
BTM.
28"
74'
16.750"
Driven
FMC 16.75" x 4-1/2" Butt. Tubing Hanger, Cameron Type H BPVP
Surf
488'
20"
133
X-56
RL4-S
18.730"
Surf
.929'
16"
75
K-55
Buttress
15.124"
Surf
1,457'
9-5/8"
47
L-80
Buttress
8.681"
Surf
3,603'
7"
29
L-80
Buttress
6.184"
3,394'
6,430'
Tubing Detail
4-1/2" 12.6 L -8D I Imp. Mod. Butt. 3.958" 1 Surf 1 4,748'
Jewelry Detail
NO.
Depth
(MD)
Depth
(TVD)
O D
ID
Item
1
74'
74'
16.750"
3.958"
FMC 16.75" x 4-1/2" Butt. Tubing Hanger, Cameron Type H BPVP
7/24/2002
459'
459'
5.230"
3.833"
4-1/2" Flow Coupling
2
464'
464'
5.250"
3.813"
HES 'X"Nipple (Screwed to the Camco TRDP-4A-0)
3,645'
465'
465'
8.140"
3.805"
4-1/2"Camco TRDP-4A-0
3.
1,678'
1,649'
6.600"
3.833"
4-1/2" Daniel's SM02 GLM. Upper GLM valve with Y"portsetfor
1100 psi and lower GLM has Y" orifice valve(6.600" Major OD))
4
3,366'
2,729'
6.600"
3.958"
4-V2" Daniel's SM02 GLM -Orifice. Upper GLM valve with Z"
port set for 1100 psi and lower GLM has''/." orifice valve(6.600"
Major OD))
5
3,855'
2,999'
5.875"
3.833"
7" Baker S3 Permanent Packer
6
3,895'
3,021'
5.600"
3.813"
Baker X Nipple C/N 801-99-5799
7
4,715'
3,487'
5.600"
3.813"
Baker X Nipple C/N 801-99-5799
8 1
4,748'
3,506'
5.200"
4.000"
Baker Shear Out Ball Seat Sub-WLEG
PERFORATION DATA
Zone
Top (MD)
Btm (MD)
Top (TVD)
Btm (TVD)
SPF
Date
B-5
±4,823'
±4,892'
±3,549'
±3,589'
7/24/2002
Future
B-5
4,905'
4,930'
3,596'
3,611'
2-7/8" HC, 6spf
10/17/2004
B-6
4,990'
5,015'
3,645'
3,659'
2-7/8" HC, 6spf
1/8/2001
C-2
5,529'
5,537'
3,949'
3,953'
2-7/8" HC, 6spf
11/7/1999
C-3
5,650'
51696'
4,016'
4,042'
2-7/8" HC, 6spf
11/22/1999
C-4
5,792'
5,819
4,095'
4,110'
2-7/8" HC, 6spf
10/16/2004
TAG DATA
Date
Depth
1/2/2000
6,175'
4/23/2000
6,153'
5/29/2001
6,096'
MFish
7/24/2002
5,969'
9/20/2004
5,929'
10/17/2004
4,990'
Fish: 10/17/2004 - Operations report the guns dragging at
each collar. Guns became stuck in tubing then fell to 4,990'
2-7/8" 6 spf HC 25' gun plus tool string = 31.6' total
Updated By: JLL 10/01/2019
Davies, Stephen F (CED)
From:
Davies, Stephen F (CED)
Sent:
Monday, October 14, 2019 9:59 AM
To:
Holly Tipton
Cc:
Roby, David S (CED)
Subject:
RE: Additional ADL's on 10-403's
Holly,
You are correct; the mistake is mine. On my workstation, the TD of this well lies amongst a tangle of wells radiating from
the Graying and Steelhead Platforms, and I mis-identified the well path when I was reviewing this sundry application.
The only affected lease for M-04 is ADL 18730. Please correct my error on Hilcorp's copy of this Sundry, and I will
correct AOGCC's copy.
Apologies and thanks for your help,
Steve Davies
AOGCC
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission
(AOGCC), State of Alaska and is for the sole use of the Intended recipient(s). It may contain confidential and/or privileged Information. The unauthorized review, use
or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding
it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or
From: Roby, David S (CED) <dave.roby@alaska.gov>
Sent: Monday, October 14, 2019 9:39 AM
To: Davies, Stephen F (CED) <steve.davies@alaska.gov>
Cc: Holly Tipton <hotipton@hilcorp.com>
Subject: FW: Additional ADL's on 10-403's
Steve,
It looks like you're the one that made this particular change to Hilcorp's 403, can you answer Holly's question?
Thanks,
Dave Roby
907-793-1232
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.
The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,
please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Dave Roby at 907-
793-1232 or dave. robyPalaska.eov.
From: Holly Tipton <hotipton@hilcorp.com>
Sent: Friday, October 11, 2019 4:57 PM
To: Roby, David S (CED) <dave.robv@alaska.aov>
Subject: Additional ADL's on 10-403's
Good afternoon Dave,
One of our regulatory techs noticed that her 10-403's are coming back with additional ADL's listed in the "Property
Designation' box of the form and we cannot quite figure out where some of these ADL's are coming from. I'm hoping
you may be able to shed some light on this for us, or at least point me in the right direction as to who can!
For example, the regulatory tech visited Lase rfiche to pull the ADL for TBU M-04 (PTD 190-071) and AD L0018730 was
listed as the only ADL. Once she received the approved 10-403 back, ADL0017594 was added to the form Laserfiche had
two ADL's listed — ADL0018730 and ADL0017594. I am curious as to why ADL0018730 was added to the 10-403 since the
SHL, BHL, and wellbore path all fall within ADL0018730. (A screenshot of the well path and lease outlines are attached.)
Was ADL0017594 added because this gas wells' path is within 1,500' of the lease line? These types of things are hard to
explain over email, so please give me a call if you want additional explanation!
Thankyou!
Holly Tipton
Regulatory Tech - CIO Asset Team
Hilcorp Alaska, LLC
0:(907)777-83301 m:(281)543-8964
e: hotipton@hilcorp.com
M
The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this
communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review,
dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and
permanently delete the copy you received.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission,
opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and
the recipient should carry out such virus and other checks as it considers appropriate.
OF Tot • •
IA- ���v7, s9 THE STATE Alaska Oil and Gas
o f LAS <11-1
Conservation Commission
A
333 West Seventh Avenue
z
Alaska 99501-3572
Anchorage,*M, GOVERNOR BILL WALKER g Main: 907.279.1433
OFALAS Fax: 907.276.7542
www.aogcc.alaska.gov
Stan W. Golis
Operations Manager SCANNED NOV 1 3 2012
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Re: McArthur River Field, Middle Kenai Gas Pool, Trading Bay Unit M-04
Permit to Drill Number: 190-071
Sundry Number: 317-506
Dear Mr. Golis:
Enclosed is the approved application for sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
Hollis S. French
Chair
DATED this day of October, 2017.
RED:LS l_ V„Lv C i
• • RECEIVED
OCT 26 ?0U
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION /P, C
APPLICATION FOR SUNDRY APPROVALS �`1
20 MC 25.280
1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑
Suspend ❑ Perforate 0 , Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑
2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number.
Hilcorp Alaska,LLC ` Exploratory ❑ Development 0 . 190-071
3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number.
Anchorage,AK 99503 50-733-20417-00-00
7.If perforating: 8.Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? CO 228A '
i
Will planned perforations require a spacing exception? Yes ❑ No 0 -7 Trading Bay Unit-M-04 •
9.Property Designation(Lease Number): 10.Field/Pool(s):
ADL0018730 , McArthur River Field/Middle Kenai Gas Pool ,
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD):
6,430 - 4,446 _ 4,990, 3,645 . 151 psi N/A —4,990'
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 488' 28" 488' 488'
Surface 929' 20" 929' 928'
Intermediate 1,457' 16" 1,457' 1,442' 2,630 psi 1,020 psi
Production 3,603' 9-5/8" 3,603' 2,860' 6,870 psi 4,760 psi
Liner 3,036' 7" 6,430' 4,444' 8,160 psi 7,020 psi
Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft):
4,905-5,819 . 3,596-4,110 4-1/2" 12.6#/L-80 4,748
Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft):
Baker S-3&Camco TRDP-4A-0 3,855(MD)2,999(TVD)and 465(MD)465(TVD)
12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 , Service ❑
14.Estimated Date for 15.Well Status after proposed work:
Commencing Operations: 11/10/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑
16.Verbal Approval: Date: GAS 0 • WAG ❑ GSTOR ❑ SPLUG ❑
Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Name: Stan W.Golfs Contact Name: Dan Marlowe
Authorized Title: Operations Manager Contact Email: dmarlOWe U@hilCOrp.Com
�QQ Contact Phone: 283-1329
Authorized Signature: T `� Date: 1 O 1.4 f t`�
COMMISSION USE ONLY
Conditions of approval: Notify Commission so at a representative may witness /7 5 `//,
Lundry
Number.n )
Plug Integrity CI BOP Test 1:1 Mechanical Integrity Test ❑ Location Clearance ❑ h/
Other:
2 nnr
Post Initial Injection MIT Req'd? Yes CI No CIj ,/ RBD S Lv l5 ' - 2U$
Spacing Exception Required? Yes ❑ No i Subsequent Form Required: 6 0 tt O`
ICOLCr\--- APPROVED BY I 1
Approved by: COMMISSIONER THE COMMISSION Date:
, 1°/z7/0-- /1/°/ '7 ORIGINAL ' ' 3 -- 7Submit Form and
r\n��\JJJJ�Jm 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate
• •
Well Work Prognosis
Hilcarp Alaska,LLC Date: 10/20/2017
Well Name: Trading Bay Unit M-04 API Number: 50-733-20417-00
Current Status: Gas Well Leg: B-2 (NE corner)
Estimated Start Date: 11/10/2017 Rig: E-Line
Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd:
Regulatory Contact: Juanita Lovett Permit to Drill Number: 190-071
First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904
Second Call Engineer: Stan Golis Office: 907-777-8356
Current Bottom Hole Pressure: 505 psi @ 3,542'TVD 0.143 psi/ft SIBP
Maximum Expected BHP: 505 psi @ 3,542'TVD 0.143 psi/ft SIBP
Maximum Potential Surface Pressure: 151 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4)
**Well to be perforated well flowing
Brief Well Summary:
Well M-04 is a gas well completed in the B &C Sands.This project will add additional perforations in the
B-5.
E-line Procedure:
1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low.
2. RU e-line guns and perforate with well flowing per program.
3. RD E-line.
4. Turn well over to production.
Attachments:
1. Current Wellbore Schematic
2. Proposed Wellbore Schematic
McArthur River Field
• • Well: M-04
SCHEMATIC Last Completed: 11/07/1999
PTD: 190-071
I[il(rorp Alaska,LLC API: 50-733-20417-00
RKBtoTI ,bgHead=74' Casing Detail
SIZE WT GRADE CONN ID TOP BTM.
28" Driven Surf 488'
..-,
. L
28" 2 i X 20" 133 X-56 RL4-S 18.730" Surf 929'
16" 75 K 55 Buttress 15.124" Surf 1,457'
9-5/8" 47 L-80 Buttress 8.681" Surf 3,603'
20
7" 29 L-80 Buttress 6.184" 3,394' 6,430'
Tubing Detail
16"
1
4-1/2" 12.6 L-80 Imp.Mod.Butt. 3.958" Surf 4,748'
Jewelry Detail
il 3 Depth Depth
N0. (MD) (TVD) OD ID Item
1 74' 74' 16.750" 3.958" FMC 16.75"x 4-1/2"Butt.Tubing Hanger,Cameron Type H BPVP
459' 459' 5.230" 3.833" 4-1/2"Flow Coupling
2 464' 464' 5.250" 3.813" HES"X"Nipple(Screwed to the Camco TRDP-4A-0)
465' 465' 8.140" 3.805" 4-1/2"Camco TRDP-4A-0
4
3 1,678' 1,649' 6.600" 3.833" 4-1/2"Daniel's SMO2 GLM.Upper GLM valve with '''A"port set for
g j $ 1100 psi and lower GLM has'A"orifice valve(6.600"Major OD))
4-1/2"Daniel's SMO2 GLM-Orifice.Upper GLM valve with '''A"
4 3,366' 2,729' 6.600" 3.958" port set for 1100 psi and lower GLM has A"orifice valve(6.600"
Major OD))
9-5/8"
5 5 3,855' 2,999' 5.875" 3.833" 7"Baker S-3 Permanent Packer
6 3,895' 3,021' 5.600" 3.813" Baker X Nipple C/N 801-99-5799
fif 6
7 4,715' 3,487' 5.600" 3.813" Baker X Nipple C/N 801-99-5799
8 4,748' 3,506' 5.200" 4.000" Baker Shear Out Ball Seat Sub-WLEG
PERFORATION DATA
iii 7N. 8
Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) SPF Date
B-5 4,905' 4,930' 3,596' 3,611' 2-7/8"HC,6spf 10/17/2004
B-6 4,990' 5,015' 3,645' 3,659' 2-7/8"HC,6spf 1/8/2001
B-5 C-2 5,529' 5,537' 3,949' 3,953' 2-7/8"HC,6spf 11/7/1999
C-3 5,650' 5,696' 4,016' 4,042' 2-7/8"HC,6spf 11/22/1999
A• C-4
C-4 5,792' 5,819 4,095' 4,110' 2-7/8"HC,6spf 10/16/2004
G2 TAG DATA
Date Depth Disc.
1/2/2000 6,175' Fill
C-3
4/23/2000 6,153' Fill
5/29/2001 6,096' Fill
C4
7/24/2002 5,969' Fill
9/20/2004 5,929' Fill
10/17/2004 4,990' Fish
A, .,,'A
PBTD:6,344' TD:6,430' Note:Oct. 2004 Perf. Operations report the guns dragging at
each collar. Guns became stuck in tubing then fell to 4,990'
Updated By:JLL 10/20/17
ti 4111
• McArthur River Field
Well: M-04
PROPOSED Last Completed: 11/07/1999
PTD: 190-071
Hilcorp Alaska,LLC API: 50-733-20417-00
RKBtoTbgHead=74' Casing Detail
J , 1 SIZE WT GRADE CONN ID TOP BTM.
28" Driven Surf 488'
28 2 20" 133 X-56 RL4-S 18.730" Surf 929'
16" 75 K-55 Buttress 15.124" Surf 1,457'
9-5/8" 47 L-80 Buttress 8.681" Surf 3,603'
20"
7" 29 L-80 Buttress 6.184" 3,394' 6,430'
Tubing Detail
4-1/2" 12.6 L-80 Imp.Mod.Butt. 3.958" Surf 4,748'
16"
Jewelry Detail
3 Depth Depth
NO. (MD) (TVD) OD ID Item
1 74' 74' 16.750" 3.958" FMC 16.75"x 4-1/2"Butt.Tubing Hanger,Cameron Type H BPVP
459' 459' 5.230" 3.833" 4-1/2"Flow Coupling
2 464' 464' 5.250" 3.813" HES"X"Nipple(Screwed to the Camco TRDP-4A-0)
465' 465' 8.140" 3.805" 4-1/2"Camco TRDP-4A-0 ,
4 4-1/2"Daniel's SMO2 GLM.Upper GLM valve with '''A"port set for
3 1,678' 1,649' 6.600" 3.833" 1100 psi and lower GLM has'A"orifice valve(6.60(YMajor OD))
® NI 4-1/2"Daniel's SMO2 GLM-Orifice.Upper GLM valve with /<"
,
4 3,366' 2,729' 6.600" 3.958" port set for 1100 psi and lower GLM has'A"orifice valve(6.600"
Major OD))
gs/g 5 3,855' 2,999' 5.875" 3.833" 7"Baker S-3 Permanent Packer ,
5
6 3,895' 3,021' 5.600" 3.813" Baker X Nipple C/N 801-99-5799
X 6
7 4,715' 3,487' 5.600" 3.813" Baker X Nipple C/N 801-99-5799
8 4,748' 3,506' 5.200" 4.000" Baker Shear Out Ball Seat Sub-WLEG
PERFORATION DATA
7 Zone Top(MD) Btm(MD) Top(ND) Btm(ND) SPF Date
a
B-5 ±4,811 ±4,911 ±3,542' ±3,600' 6 Future
B-5 4,905' 4,930' 3,596' 3,611' 2-7/8"HC,6spf 10/17/2004
8-5 B-6 4,990' 5,015' 3,645' 3,659' 2-7/8"HC,6spf 1/8/2001
/�
= C-2 5,529' 5,537' 3,949' 3,953' 2-7/8"HC,6spf 11/7/1999
B-6
(? C-3 5,650' 5,696' 4,016' 4,042' 2-7/8"HC,6spf 11/22/1999
C-4 5,792' 5,819 4,095' 4,110' 2-7/8"HC,6spf 10/16/2004
-C-2 TAG DATA
Date Depth Disc.
=-C-3 1/2/2000 6,175' Fill
4/23/2000 6,153' Fill
=---0-4 5/29/2001 6,096' Fill
7/24/2002 5,969' Fill
9/20/2004 5,929' Fill
7„ g: . ___* 10/17/2004 4,990' Fish
PBTD:6,344' TD:6,430' Note:Oct. 2004 Perf. Operations report the guns dragging at
each collar. Guns became stuck in tubing then fell to 4,990'
Updated By:_ILL 10/20/17
Pages NOT Scanned in this Well History File
XHVZE
This page identifies those items that were not scanned during the initial scanning project.
They are available in the original file and viewable by direct inspection.
/~,/)..,,,¢"~/File N umber of Well Histo ry File
II~I U' II
PAGES TO DELETE
RESCAN
[g"~Color items - Pages:
[]
[]
Grayscale, halftones, pictures, graphs, charts -
Pages:
Poor Quality Original - Pages:
Other- Pages:
DIGITAL DATA
OVERSIZED
Diskettes, No.
Other, No/Type
Logs of various kinds
Other
Complete
COMMENTS:
Scanned by: Bevedy~Vincent
TO RE-SCAN
Notes:
Nathan Lowell
Re-Scanned by: Beverly Bren Vincent~Lowell
Date: ~ ~' Is~
NOTScanned.wpd
)
Unocal Alaska
909 W. 9th Avenue
Anchorage, AK 99501
Tele: (907) 263-7889
Fax: (907) 263-7828
E-mail: oudeand@unocal.com
)
UNO CALf)
61""(,,,
. f1rß.. .-";;"e,i·! i ... .
~".,
Debra Oudean
G & G Technician
Date: March 16,2005
To:
AOGCC
Helen Warman
333 W. 7th Ave. Ste#100
Anchorage, AK 99501
SCANNED JUN 1 t7 2005
~11I,m
;~E~ )O~;; ..tYt~khK P',~:"<."J,;·);!;~;~RQ-ftrÉ:"'.:[,j:>],:..';/ :.i; !¡f~~~ i.6.~~riJ~~~ï:{~~: ~~M c~
I c¿2ilo ¡;I:::~:::: :::----!:~=::-:~::::::-:::~----.'.:-:. -::: ::~::--'--~-~--JI!
\I¡ GAMMA RA YlCCL ' ' ,
>................ ................................. ...·.....·....·..........-·....·................··1.......·......·... ........... ......... ............ ...................... .................................. ..................................... ."............... ............. .................. ...- ..............................."...............................-.... ....................... .......... ....... ........... .. .... ................... ..................... ...... ...... i
~9/ &1Lì Schlumberger TBU M-13 ~~~~¡E~~~7c~~CORD 2.5 HSD POWERJET 6 SPF 5 INCH 10/14/20042350-2880 l' 1 1 !
! lš;;¡,lu;;,í;~-;g;r]Tãû'M-'15-lCoM¡;LËTiõNRËcôRDi56TüBïÑGPûNcH2õ-Es--;¡5iNC¡:¡T1oï1312õõ41âõóõ:¡¡:iõö--'nr--1T-i
} 'r?~; « ~~~~~~~:~l:~~~:~~~~~~i!~~~E~~~~~~:_~~~~~~~:~~-~l:~;~~~=õõ~T:~:~·-:r::::~:;::~1~:-j
/Cfo ,a',I.:. .~~~:~~~::~~:~~~----1~~:~~~~:~~~:;-:.~~~:-:~w~~T-6-s·¡;F--j:-:~~~-n~:~:·r:::~:~:----F---:r-~--::
J ~ 1.... {'!J ~ ...'..'...... ...... ...........,.. ..,.1.................__.. ....__J.._ ...... .. ..,... ........-...... . .....,-.. ... ...... . ...-..- .-..,......- ....n....".. . ~...... .n..' -...- -...."..-.. .. ............-... -...----..-,~_... _._..1 -,...-....,...........- _.. . ., ." .._~.__.............._....I._-,.....
Please aCkn~::; ;::iPt by inin9 an~9 one copy of this transital O;AX to (907) 263-7626.
Rect;;y/!~t/ Jr~t«~ú- Date: ~/iO~~
, STATE OF ALASKA,
ALASkblL AND GAS CONSERVATION COMMkbN
REPORT OF SUNDRY WELL OPERATIONS
Representative Daily Average Production or Injection Data
Gas-Mcf Water-Bbl Casing Pressure
5,890 1 20
7,930 0 20
15. Well Class after proposed work:
Exploratory D Development 0
16. Well Status after proposed work:
OilD Gas 0 WAG D
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
1. Operations Abandon U Repair Well U
Performed: Alter Casing D Pull Tubing D
Change Approved Program D Operat. Shutdown D
2. Operator Union Oil Company of California
Name:
3. Address:
PO Box 196247, Anchorage, AK 99519
7. KB Elevation (ft):
160' KB about MSL
8. Property Designation:
Steelhead Platform
11. Present Well Condition Summary:
Total Depth measured 6,430' feet
true vertical 4,446' feet
Effective Depth measured 6,344' feet
true vertical 4,398' feet
Casing Length Size
Structural 488' 28"
Conductor 929' 20"
Surface 1,457' 16"
Intermediate
Production 3,603' 9-5/8"
Liner 3,036' 7"
Perforation depth:
Measured depth: 4,905 to 5,819'
True Vertical depth: 3,596 to 4,109
Tubing: (size, grade, and measured depth)
Packers and SSSV (type and measured depth)
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13.
Prior to well operation:
Subsequent to operation:
14. Attachments:
Copies of Logs and Surveys Run
Daily Report of Well Operations
Oil-Bbl
0
0
x
Contact Steve Tyler 263-7649
Printed Name Timothy C. Brandenburg a
Signature 7 _--a L- Q. ~/
25 -j) J
Form 10-404 Revised 04/2004 ¿::::/
Plug Perforations U
Perforate New Pool D
Perforate 0
4. Current Well Class:
Development 0
Stratigraphic D
StimulateU Other U
WaiverD Time Extension D
Re-enter Suspended Well D
5. Permit to Drill Number:
ExploratoryD 90-71
Service D 6. API Number:
50-733-20417-00
9. Well Name and Number:
M-04
10. Field/Pool(s):
McArthur River/GGS, Mid, Kenai
Plugs (measured)
Junk (measured) 4,990' fish in hole, tagged 10/04
MD TVD Burst Collapse
488' 487'
929' 928' 3060 psi 1500 psi
1 ,457' 1 ,442' 2630 psi 1 020 psi
3,603' 2,861' 6870 psi 4760 psi
6,403 4,444' 8160 psi 7020 psi
S''''C'A'! NL\QE'P' q ¡: f~ ') rry 2004
"ð !'i!. !,,~, L ~- t, /.., It
4-1/2", L-80 @ 4,748'
REC "lJ=D
DEe 2 2 2004
Alaska Oil & Gas Cons. Commission
RBDMS BFl DEC 2 sA1t1lJl°rage
Baker S-3 Packer @ 3,855'
n/a
Tubing Pressure
367
376
Service D
GINJ D WINJ D WDSPL D
Sundry Number or N/A if C.O. Exempt:
304-376
Title Drilling Manager
Phone 907-276-7600
Date 12/16/2004
ORIG1NAL
Submit Original Only
- ",
UNOCAL8
RKB to TBG Head = 74'
KB to MSL = 160'
1 I
3
L
L
4
I
6
7
8 "LJI
9 "'-
EOT at 4748'
~
~
\
= A-6 Future
= B-2 Future
= B-3 Future
= 8-5
-
B-6
-
~ C-2
= C-3
-
.-. ~ C-4
.,., ~
PBTD = 6344'
TD = 6,430'
)
)
Steelhead
Well M-4
Actual Completion 1/8/01
CASING AND TUBING DETAIL
SIZE WT GRADE CONN ID TOP BTM.
28" Driven Surf 488'
20" 133 X-56 RL4-S 18.730" Surf 929'
16" 75 K-55 Buttress 15.124" Surf 1457'
9-5/8" 47 L-80 Buttress 8.681" Surf 3603'
7" 29 L-80 Buttress 6.184" 3394' 6430'
Tubing:
4-1/2" 12.6 L-80 Imp. Mod. Butt. 3.958" Surf 4748'
JEWELRY DETAIL
NO. Depth OD ID Item
1 74' 16.75" FMC 16.75" x 4-1/2" Butt. Tubing Hanger,
Cameron Type H BPVP
2 74.5' 4.500" 3.958" Double pin sub 4.1/2" Imp. Mod. Buttress
3 458' 5.230 Flow Coupling
3 464' 5.250" 3.813" HES "X" Nipple
3 465' 7.125" 3.844" 4-1/2" Camco TRDP.4A.0
4 4.500" 3.958" 4-1/2" 12.61b/ft L.80 Imp. Mod. Butt. Tubing
5 1678' 6.600" 3.833" 4-1/2" Daniel's SM02 GLM. Upper GLM valve
3365' with v'¡" port set for 1100 psi and lower GLM
has v'¡" orifice valve(6.600" Major OD))
6 3855' 4.875" 3.830? 7" Baker S-3 Permanent Packer
7 3894' 5.600" 3.813" Baker X Nipple
8 4715' 5.600" 3.813" Baker X Nipple
9 4748' 5.200" 3.958" Baker Shear Out Ball Seat Sub
Zone
B-5
B-6
C-2
C-3
C-4
Interval
4905' -4930'
4986' -5011 '
5529'.5537'
5650' -5696'
5792'.5819'
PERFORATION DATA
SPF Date
2.7/8" HC, 6spf 10-17.04
2-7/8" HC, 6 spf 1-8.01
2-7/8" HC, 6spf 11-7-99
2.7/8" HC, 6 spf 11-22-99
2-7/8" HC, 6 spf 10-16-04
TAG DATA
Date Depth
1/2/00 6175'
4/23/00 6153'
5/29/01 6096'
7/24/02 5969'
10/17/04 4990' (top offish)
(FISH - Head, Adaptor, Firing head, 2-7/8" gun - total length = 31.6')
CRW 11/04
10/16/04
)
)
PJSM. RU. Pressure test to 2500 psi, WIH with GR/CCL and 27' gun. Tied in w/ Schlumberger GR/CCL 11/4/99.
TP@430 psi. Perforated 5792-5819 (27) 2 7/8 HC PJ, 6 spf. TP@ 499 1 min, TP@ 580 2 min, TP@ 650 4 min,
TP@ 700 7 min, TP@ 685 9 min. POOH. Laid down lubricator/BOPs. Secure well. Started well test.
10/17/04
Remade head. Laid out equipment. PJSM. RU M-4 and PT to 2500#. RIH with CCL and 25 foot gun. Tied in. TP
@ 485 psi. Perforated 4905-4930 (25) 2 7/8 HC 6 spf. Logged up and started out of hole. Pollard RU on
lubricator. WIH with hydraulic jars, stem, spangs, KJ, stem, KJ, stem, 3" blind box. (180 #). Found top of fish at
4990 KB. (242 feet below tail) Set down 3 times. No movement. Left fish in hole and flow well. Suspended
operations. RD.
M-04 morning report summary, CONFIDENTIAL: last revised 12/16/2004, Page 1
- - -
1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate ~ ~JIISKa ,-, . . .,,"~,~, .....,..",v...'U
Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extensi~ÈPrage Other 0
Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0
2. Operator Name: 4. Current Well C~: VJG~ 5. Permit to Drill Number:
Union Oil Company of California Development Exploratory 0 90-71 /
3. Address: Stratigraphic 0 Service 0 6. API Number/
PO Box 196247, Anchorage, AK 99519 50-733-20417-00
7. KB Elevation (ft): 9. Well Name and Number:
160' KB above MSL M-04 ".r
8. Property Designation: 1 O. Field/Pools(s):
Steelhead Platform McArthur River/GGS, Mid, Kenai
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
6,430' 4,446' 6,344' 4,398'
Casing Length Size MD TVD Burst Collapse
Structural 488' 28" 488' 487'
Conductor 929' 20" 929' 928' 3,060 psi 1,500 psi
Surface 1,457 16" 1 ,457' 1,442' 2,630 psi 1,020 psi
Intermediate
Production 3,603' 9-5/8" 3,603' 2,861 6,870 psi 4,760 psi
Liner 3,036' 7" 6,430 4,444 8,160 psi 7,020 psi
Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft):
4,990 - 5,696' 3,646 - 4,044' 4-1/2" L-80 4,748'
Packers and SSSV Type: Baker S-3 pkr Packers and SSSV MD (ft): 3,855'
12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work:
Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: 10/16/2004 Oil 0 Gas 0'/ Plugged 0 Abandoned 0
16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0
Commission Representative:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh 263-7627
Printed Name Tim C. Brande~rg ~ Title Drilling Manager
Signature 'r¿ - C_^ ........... ~hone 907-276-7600 Date 10/11/2004
// COMMISSION USE ONLY
£,/'
Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3&1 '/.. .3?¿'
Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0
Other:
S"b,,""e"' Fo"" Req";",~ 404. OR I GI NAL
APP""'d~
BY ORDER OF t't>/Í~I)f/
COMMISSIONER THE COMMISSION Date:
- , ,, /
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVAL
20 MC 25 280
V-t~1t () [ Iff ¿V£)1
RECEIVED
OCT 1 2 2004
Form 10-403 Revised 12/2003 /J D J?M INSTRUCTIONS ON REVERSE
rJJV/,lS ~.
Submit in Duplicate
M-4 Work Summary
Perforate and Test C-4 and B-5 Sands
. MIRV Slickline. Tag fill. RIH wi gauges. Obtain flowing pressure survey.
. RIH wi dummy gun. RD Slickline.
. MIRV Eline. RIH wi 2-7 18"guns (HC, 6spf, 60° phasing). ,/
. Perf the following sand (GR log will determine DIL depth for perf):
C-4 sand 5792'md to 5819'md
. POOH. Test for 6-12 hours.
. RIH w 2-7/8" guns (HC, 6spf, 60° phasing).
. Perf the following sand
B-5 sand 4905'md to 4930'md
/
B-5 sand 4814'md to 4897'md
. RD Eline.
. Turn well over to production.
¡..-,.-'-j
('1:~¿//
UNOCAL8
Steel head
Well M-4
Actual Completion 1/8/01
RKB to TBG Head = 74'
KB to MSL = 160'
CASING AND TUBING DETAIL
SIZE WT GRADE CONN ID TOP BTM.
28" Driven Surf 488'
20" 133 X-56 RL4-S 18.730" Surf 929'
16" 75 K-55 Buttress 15.124" Surf 1457'
9-5/8" 47 L-80 Buttress 8.681" Surf 3603'
7" 29 L-80 Buttress 6.184" 3394' 6430'
Tubing:
4-1/2" 12.6 L-80 Imp. Mod. Butt. 3.958" Surf 4748'
2
3
4
JEWELRY DETAIL
NO. Deoth OD ID Item
1 74' 16.75" FMC 16.75" x 4-1/2" Butt. Tubing Hanger,
Cameron Type H BPVP
2 74.5' 4.500" 3.958" Double pin sub 4-1/2" Imp. Mod. Buttress
3 458' 5.230 Flow Coupling
3 464' 5.250" 3.813" HES "X" Nipple
3 465' 7.125" 3.844" 4-1/2" Camco TRDP-4A-0
4 4.500" 3.958" 4-1/2" 12.6 Ib/ft L-80 Imp. Mod. Butt. Tubing
5 1678' 6.600" 3.833" 4-1/2" Daniel's SM02 GLM. Upper GLM valve
3365' with W' port set for 1100 psi and lower GLM
A-6 Future has W' orifice valve(6.600" Major aD))
6 3855' 4.875" 3.830? 7" Baker S-3 Permanent Packer
B-2 Future
7 3894' 5.600" 3.813" Baker X Nipple
8 4715' 5.600" 3.813" Baker X Nipple
9 4748' 5.200" 3.958" Baker Shear Out Ball Seat Sub
6
7
8
9
EOT at 4748'
B-5 Proposed /
C-2 Actual
5529'-5537'
C-3 Actual
5650'-5696'
Zone
B-6
C-2
C-3
Interval
4986' -5011'
5529'-5537'
5650'-5696'
PERFORATION DATA
SPF Dme
2-7/8" HC, 6 spf 1-8-01
2-7/8" HC, 6spf 11-7-99
2-7/8" HC, 6 spf 11-22-99
B-6 Actual
4986-5011'
C-4 Proposed /
TAG DATA
Date Depth
1/2/00 6175'
4/23/00 6153'
5/29/01 6096'
7/24/02 5969'
PBTD = 6344'
TO = 6,430'
JWS 8/16/04
~1T~1TŒ (ill~ ~~~~æ~
AIfASIiA OIL AND GAS
CONSERVATION COMMISSION
/
í
/
I
¡
/
/
FRANK H. MURKOWSK/, GOVERNOR
333 W. 7'" AVENUE, SUITE 100
ANCHORAGE. ALASKA 99501.3539
PHONE (907) 279-1433
FAX (907) 276-7542
Tim C. Brandenburg
Drilling Manager
Union Oil Company of California
P.O. Box 196247
Anchorage, Alaska 99519
Re:
McArthur River M -04
Sundry Number: 304-376
Dear Mr. Brandenburg:
Enclosed is the approved Application for Sundry Approval relating to the above-
referenced well. Please note the conditions of approval set out in the enclosed
fonn.
As provided in AS 31.05.080, within 20 days after written notice of this decision,
or such further time as the Commission grants for good cause shown, a person
affected by it may file with the Commission an application for rehearing. A
request for rehearing is considered timely if it is received by 4:30 PM on the 23rd
day following the date of this letter, or the next working day if the 23rd day falls
on a holiday or weekend. A person may not appeal a Commission decision to
Superior Court unless rehearing has been requested.
BY ORDER OF THE COMMISSION
DATED this¥day of October, 2004
Enc!.
'i90~071-0 T~DiNG' BAY UNiT M~0'4 50L 733-20417-00 UNION OIL CO OF
CALIFORNIA
Roll #1: Start: Stop Roll #2: Start Stop
MD 06430 TVD 04446 Completion Date: 11/7/99 Completed Status: 1-GAS Current:
T Name Interval Sent Received T/C/D
L ADN-TVD FINAL 2900-4400
L AND-MD FINAL 3603-6430
L CDR-MD FINAL 3603-6430
L CDR-TVD FINAL 29004400
L COMP RCD FINAL 1400-5800
L GR/CCL FINAL 3400-6314
L HSD/GR/CCL Correla FINAL 4700-5011
L PERF FINAL 5400-5630
L RST/S FINAL 1400-5800
L TCB-MD FINAL 3603-6430
L TCB-TVD FINAL 2900-4400
L USIT-CCL FINAL BL(C) 1340-6314
R SRVY RPT SCHLUM 1421-6430
OH 2/5
OH 2/5
OH 2/5
OH 2/5
CH 5
CH 5
CH 5
CH 5
CH 5
OH 2/5
OH 2/5
CH 5
OH
11/9/99 11/12/99
11/9/99 11/12/99
11/9/99 11/12/99
11/9/99 11/12/99
5/18/00 5/19/00 CUL
5/18/00 5/19/00 CUL
4/28/01 5/1/01
5/18/00 5/19/00 CUL
5/18/00 5/19/00 091
11/9/99 11/12/99
11/9/99 11/12/99
5/18/00 5/19/00
11/9/99 11/12/99
Tuesday, September 25, 2001
Page 1 of l
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION CL)MMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X
Pull tubing: /[,Iter casing: Repair well: Other:
2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB)
Union Oil of California (Unocal) Development: X 160' KB feet
3. Address Exploratory: 7. Unit or Property name
....
Stratigraphic: Tradin Bay Unit
P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: _
4. Location of well at surface 8. Well number
1032' FNL, 606' FWL, Sec. 33, T9N, R13W, SM M-4
At top of productive interval 9. Permit number/approval number
542' FSL, 1804' FWL, Sec. 28, T9N, R13W, SM 190-71
At effective depth 10. APl number
50-733-20417-00
At total depth 11. Field/Pool
2086' FSL, 2205' FEL, Sec. 28, T9N, R13W, SM McArthur River/GGS, Mid. Kenai
12. Present well condition summary
Total depth: measured 6430 feet Plugs (measured)
true vertical 4446 feet
Effective depth: measured 6344 feet Junk (measured)
true vertical 4398 feet
Casing Length Size Cemented Measured depth True vertical depth
Structural 313' 26" Driven 356' 356'
Conductor 849' 20" 2050 sx 929' 928'
Surface 1379' 16" 1000 sx 1457' 1442'
Intermediate
Production 3529' 9-5/8" 965 sx 3603' 2862'
Liner 3016' 7" 679 sx 3414'-6430' 2757'-4446'
Perforation depth: measured 4990'-5015', 5529'-5537', 5650'-5696'
true vertical 3646'-3660', 3950'-3954', 4018'-4044'
Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 at 4748' ~ CEt V~'
Packers and SSSV (type and measured depth) Baker "S-3" pkr. at 3855' J/IN _l
13. Stimulation or cement squeeze summary Alaska Oil & Gas Cons. COmrnissio~
Intervals treated (measured) Anchorage
Treatment description including volumes used and final pressure
.....
14. Representative Daily Average Production or Injection Data,
OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 0 7000 0 700 640
Subsequent to operation 0 13000 0 700 671
....
15. Attachments: 16. Status of well classification as:
Copies of Logs and Surveys run:
Daily Report of Well Operations: Oil: Gas: X Suspended: Service:
....
17. I hereby certify that the foregoing is true and correct to the best of my knowledge:
Form 10-404 Rev 06/15/88
SUBMIT IN DUPLICATE
Unocal Corporation
P.O. Box 196247
Anchorage, AK 99501
Telephone (907) 263-7660
UNOCALe)
Dan Williamson
Drilling Manager
Monday, January 15, 2001
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
Attn: Mr. Robert Christensen
Subject: Trading Bay Unit
Well M-4
APl No. 50-733-20417-00
10-404 Perforate bench B6
Dear Mr. Christensen'
Please find enclosed in duplicate Form 10-404 for the perforation of the B6 bench in well
M-4.
The following intervals were perforated on 1/8/01'
Bench Top Bottom Feet
B6 4,990 5,015 25
Total: 25
If you have any questions, please contact Ralph Holman at 263-7838.
Dan Williamson
Drilling Manager
RECEIVED
JAN
A)aska Oil 8, Gas Co~s. Commission
Anchorage
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X
Pull tubing: Alter casing: Repair well: Other:
2. Name 'of Operator 5. Type of Well: 6. Datum elevation (DF or KB)
Union Oil of California (Unocal) Development: X 160' KB feet
3. Address Exploratory: 7. Unit or Property name
Stratigraphic: Tradin Bay Unit
P.O. Box 196247 Anchorage, Alaska 99519-6247 Service:
4. Location of well at surface 8. Well number
1032' FNL, 606' FWL, Sec. 33, T9N, R13W, SM M-4
At top of productive interval 9. Permit number/approval number
542' FSL, 1804' FWL, Sec. 28, T9N, R13W, SM 90-71
At effective depth 10. APl number
50-733-20417-00
At total depth 11. Field/Pool
2086' FSL, 2205' FEL, Sec. 28, T9N, R13W, SM McArthur River/GGS, Mid. Kenai
12. Present well condition summary
Total depth: measured 6430 feet Plugs (measured)
true vertical 4446 feet
Effective depth: measured 6344 feet Junk (measured)
true vertical 4398 feet
Casing Length Size Cemented Measured depth True vertical depth
Structural 313' 26" Driven 356' 356'
Conductor 849' 20" 2050 sx 929' 928'
Surface 1379' 16" 1000 sx 1457' 1442'
Intermediate
Production 3529' 9-5/8" 965 sx 3603' 2862'
Liner 3016' 7" 679 sx 3414'-6430' 2757'-4446'
Perforation depth: measured 5529'-5537', 5650'-5696'
true vertical 3950'-3954', 4018'-4044'
Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 at 4748'
Packers and SSSV (type and measured depth) Baker "S-3" pkr. at 3855'
13. Stimulation or cement squeeze summary
Intervals treated (measured) .... ~ i '~' ! .'!'~ t~ i ..... "' ;!' 'U.,,~.,.., "
Treatment description including volumes used and final pressure
,
14. Representative Daily Avera.qe Production or Injection Data
OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 0 5.3 0 0 925
Subsequent to operation 0 6.5 1 790 930
15. Attachments: 16. Status of well classification as:
Copies of Logs and Surveys run:
Daily Report of Well Operations: Oil: Gas: X Suspended: Service:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge:
Signed '{ _ tt'~0/[//~ i , Date:
Form 10-404 Rev 06/15/88
SUBMIT IN DUPLICATE '~,,,~'~ -- '"
Unocal Corporation
P.O. Box 196247
Anchorage, AK 99501
Telephone (907) 263-7660
UNOCAL )
Dan Williamson
Drilling Manager
Thursday, March 23, 2000
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
Attn' Mr. Robert Christensen
Subject: Trading Bay Unit
Well M-4
APl No. 50-733-20417-00
10-404 Perforate bench C3
Dear Mr. Christensen: !61E:) - O~ (
Please find enclosed in duplicate Form 10-404 for the perforation of the C3 bench in well
M-4.
The following intervals were perforated on 11/23/99:
Bench Top Bottom Feet
C3 5,650 5,696 46
Total: 46
If you have any questions, please contact Ralph Holman at 263-7838.
Sincerely,
Dan Williamson
Drilling Manager
STATE OF ALASKA
ALASKA O,-AND GAS CONSERVATION (.,,JMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL: GAS: X SUSPENDED: ABANDONED: SERVICE:
2. Name of Operator 7. Permit Number
Union Oil Company Of Califonia (UNOCAL) 90-71
3. Address 8. APl Number
P.O. Box 196247, Anchorage, AK 99519 50-733-20417-00
4. Location of well at surface Slot No.9 Leg B-2 Steelhead Platform~~ 9. Unit or Lease Name
1032' FNL, 606' FWL,Sec 33, T9N, R13W, SM ~- ';. :':': ~,.~~ Trading Bay Unit
At Producing Interval .~ ....
Top ~ . 10. Well Number
11. Field and Pool
2086' FSL, 2205' FEL, Sec 28, T9N, R13W SM ~.ii.i"... McArthur River, GGS, Middle Kenai Gas Sands
5. Elevation in feet (indicate KB, DF, etc.) I 6: Lease Designation and Serial No.
160' KB above MSL I ADL 18730
6/20/90 original 10/21/99 re-entry 10/31/1999 11/7/99 187' feet MSL One
22. Type Electric or Other Logs Run
USIT, GR/ADN/CDR
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
26" Drive Pipe 42.5 356' Driven 0
20" 133 X-56 80 929' 26" 2050 sx 0
16" 75 K-55 78' 1457' 22" 1000 sx 0
9-5/8" 47 L-80 74' 3603' 12-1/4" 670 sx lead/295 sx tail 0
7" liner 29 L-80 3414' 6430' 8-1/2" 518 sx lead/161 sx tail 0
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MDi' PACKER SET (MD)
4-1/2" 4748' 3855'
C-2 Interval 5529-5537' MD (3949-3954' TVD), 6spf HC, 60 deg
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
,,,
27. PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
11/7/99I Flowing
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO
I
11/7/99 24 TEST PERIOD --> 5.3M Nil
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 925 psi 0 psi 24-HOUR RATE => 5.3M Nil
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. S ~..~. ir~, ~
Anchorage
Form 10-407
Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate
29. 30.
GEOLOGIC MARKERS FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
31. LIST OF ATTACHMENTS
directional survey, completion drawing, summary history
32. I hereby certify that the foregoir~ isatr~ e and correct to the best of my knowledge
Signed itle !~ Date
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 space 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 productin intervals for only 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 (DF, KB, etc.).
Form 10-407
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Steelhead M-4 Operations Summary
Commence operations at 21 October 1999. Remove dry hole tree from M-4 and NU and
test BOP's. PU 14-3/4" BHA and RIH to 1335'. Clean out 16" casing and rat hole to
1480'. Perform LOT to 15.1 PPG EMW. POOH for 12-14" directional BHA. MU BHA
and RIH. (Service Top Drive- 18 hours) Drill 12-1/4" hole from 1480' to 3616'. Perform
short trip and POOH to run 9-5/8" casing. Run and cement 9-5/8" casing at 3602'. Set
wellhead pack-off and P/T BOP's. Make up 8-1/2" directional BHA and RIH. Drill out
shoe track and 9' new hole to 3625'. Perform LOT to 15.6 ppg EMW. Drill 8-1/2' hole
from 3625' to TD at 6430'. POOH to run 7" liner. Pick up and run liner to TD at 6430'.
Circulate and condition mud. Cement liner, set top isolation packer, circulate out excess
cement and POOH. Make up cleanout out assembly and RIH to PBTD at 6344'. Test
liner lap to 2500 psi. Displace well to inhibited FIW and POH. Run 4-1/2" single string
completion to 4748'. Set packer and P/T annulus to 2500 psi. Nipple down BOP's and
install and test tree. Release rig to M-32RD at 24:00 hrs 5 November 1999.
The well was perforated on 7 November from 5529' to 5537' (C-2 Grayling Gas Sand).
Initial well test results are as follows: 5.3MMSCFD, 925 psi FTP
UNOCAL
Steelhead
Well M-4
Actual Completion 11/7/99
RKB to TBG Head = 74'
SIZE
28"
20"
16"
9-5/8"
7"
Tubing:
4-1/2"
WT
CASING AND TUBING DETAIL
GRADE CONN ID
TOP BTM.
133
75
47
29
Driven Surf 488'
X-56 RL4-S 18.730" Surf 929'
K-55 Buttress 15.124" Surf 1457'
L-80 Buttress 8.681" Surf 3603'
L-80 Buttress 6.184" 3394' 6430'
12.6 L-80
Imp. Mod. Butt. 3.958" Surf 4748'
9
EOT at 4748'
A-6 Proposed
3946-4045'
B-2 Proposed
421 O-4270'
B-3 Proposed
4390'- 4620'
B-5 Proposed
= 4875'-4935'
B-6 Proposed
~ 4980-5015'
C-2 Actual
5529'-5537'
~ C-3 Proposed
- 5655"-5705'
C-4 Proposed
5813'-5822'
JEWELRY DETAIL
NO. Depth OD ID Item
1 74' 16.75"
2 74.5' 4.500" 3.958"
3 458' 5.230
3 464' 5.250" 3.813"
3 465' 7.125" 3.844"
4 4.500" 3.958"
5 1678' 6.600" 3.833"
3365'
6 3855' 4.875" 3.830?"
7 3894' 5.600" 3.813"
8 4715' 5.600" 3.813"
9 4748' 5.200" 3.958"
Interval Zone
C-2 5529 '-5537'
FMC 16.75" x 4-1/2" Butt. Tubing Hanger,
Cameron Type H BPVP
Double pin sub 4-1/2" Imp. Mod. Buttress
Flow Coupling
HES "X" Nipple
4-1/2" Camco TRDP-4A-0
4-1/2" 12.6 lb/ft L-80 Imp. Mod. Butt. Tubing
4-1/2" Daniel's SMO2 GLM. Upper GLM valve
with ¼" port set for 1100 psi and lower GLM
has ¼" orifice valve(6.600" Major OD))
7" Baker S-3 Permanent Packer
Baker X Nipple
Baker X Nipple
Baker Shear Out Ball Seat Sub
PERFORATION DATA
SPF Date
2-7/8" HC, 6spf 11-7-99
PBTD = 6344' TD = 6,430'
NM 11/5/99
Client ................... : UNOCAL
Field .................... : McArthur River
Well ..................... : M-4
API number ............... : 50-733-20417-00
Engineer ................. : Nutter
Rig: ..................... : Steelhead
State: ................... : Alaska
ANADRILL
SCHLUMBERGER
Survey report
31-Oct-1999 20:25:44
RECEIVED
Page
1999
aske Oil & Gas Cons. Commission
Spud date ......... ~~g~ 21-0ct-99
~ast survey date ......... : 31-0ct-99
Total accepted surveys...: 88
MD of first survey ....... : 1421.00 ft
MD of last survey ........ : 6430.00 ft
1 of 4
ORIGINAL
Survey calculation methods
Method for positions ..... : Minimum curvature
Method for DLS ........... : Mason & Taylor
..... Depth reference
Permanent datum .......... : Mean Sea Level
Depth reference .......... : Drill Floor
GL above permanent ....... : -350.00 ft
KB above permanent ....... : Top Drive
DF above permanent ....... : 160.25 ft
...... Vertical section origin
Latitude (+N/S-) ......... :
Departure (+E/W-) ........ :
0.00 ft
0.00 ft
Platform reference point
Latitude (+N/S-) ......... : -999.25 ft
Departure (+E/W-) ........ : -999.25 ft
Azimuth from rotary table to target: 39.52 degrees
Geomagnetic data
Magnetic model ........... : BGGM version 1999
Magnetic date ............ : 21-Oct-1999
Magnetic field strength..: 1105.39 HCNT
Magnetic dec (+E/W-) ..... : 21.34 degrees
Magnetic dip ............. : 73.58 degrees
MWD survey Reference Criteria
Reference G .............. : 1002.03 mGal
Reference H .............. : 1105.39 HCNT
Reference Dip ............ : 73.58 degrees
Tolerance of G ........... : (+/-) 2.50 mGal
Tolerance of H ........... : (+/-) 6.00 HCNT
Tolerance of Dip ......... : (+/-) 0.45 degrees
Corrections
Magnetic dec (+E/W-) ..... : 21.31 degrees
Grid convergence (+E/W-).: 0.00 degrees
Total az corr (+E/W-) .... : 21.31 degrees
(Total az corr = magnetic dec - grid cony)
Sag applied (Y/N) ........ : No degree: 0.00
[(c)1999 Anadrill IDEAL ID6_0C_04]
ANADRILL SCHLUMBERGER Survey Report 31-0ct-1999 20:25:44 Page 2 of 4
Seq Measured Incl Azimuth Course
# depth angle angle length
- (ft) (deg) (deg) (ft)
1 1421.00 18.75 18.00 0.00
2 1470.00 18.77 18.00 49.00
3 1533.02 18.84 20.06 63.02
4 1600.17 20.54 22.25 67.15
5 1662.88 23.09 24.30 62.71
TVD Vertical Displ
depth section +N/S-
(ft) (ft) (ft)
Displ
+E/W-
(ft)
Total
displ
(ft)
At
Azim
(deg)
DLS
(deg/
100f)
1407.89 121.40 121.56 43.41 129.08 19.65 0.00
1454.29 136.06 136.55 48.28 144.83 19.47 0.04
1513.94 155.08 155.75 54.90 165.14 19.42 1.06
1577.17 176.56 176.84 63.08 187.75 19.63 2.76
1635.38 198.93 198.23 72.31 211.01 20.04 4.24
6 1728.81 25.71 26.45 65.93 1695.42 225.34 222.82 84.00 238.13 20.66
7 1756.63 26.78 27.72 27.82 1720.37 237.35 233.77 89.61 250.36 20.97
8 1790.91 28.09 29.91 34.28 1750.80 252.87 247.61 97.22 266.01 21.44
9 1822.00 29.35 32.52 31.09 1778.06 267.65 260.38 104.97 280.74 21.96
10 1846.48 30.54 35.58 24.48 1799.27 279.81 270.49 111.81 292.69 22.46
11 1883.43 32.13 39.48 36.95 1830.84 299.01 285.72 123.53 311.28 23.38
12 1916.52 33.06 41.08 33.09 1858.72 316.83 299.31 135.05 328.37 24.29
13 1942.82 33.92 41.84 26.30 1880.65 331.33 310.19 144.66 342.26 25.00
14 1978.40 35.24 42.43 35.58 1909.94 351.51 325.16 158.21 361.61 25.95
15 2011.48 36.57 42.52 33.08 1936.74 370.88 339.47 171.31 380.24 26.78
16 2040.01 37.66 42.22 28.53 1959.49 388.07 352.19 182.91 396.85 27.45
17 2071.65 38.80 41.90 31.64 1984.34 407.63 366.72 196.03 415.83 28.13
18 2104.62 40.05 41.65 32.97 2009.81 428.55 382.34 209.97 436.20 28.77
19 2130.45 41.29 41.50 25.83 2029.40 445.38 394.93 221.14 452.63 29.25
20 2165.45 43.22 41.34 35.00 2055.30 468.90 412.58 236.71 475.66 29.84
4 20
4.34
4 82
5.72
7 91
6 97
3.83
3 64
3.83
4 02
3 87
3.66
3 82
4.82
5 52
21 2197.06 44.73 41.40 31.61 2078.05 490.83 429.05 251.22 497.19 30.35 4.78
22 2224.49 46.29 42.27 27.43 2097.27 510.38 443.63 264.27 516.38 30.78 6.12
23 2259.30 48.73 42.43 34.81 2120.78 536.02 462.60 281.56 541.55 31.33 7.02
24 2291.87 50.97 42.95 32.57 2141.78 560.88 480.89 298.44 565.97 31.82 6.98
25 2319.94 53.08 42.83 28.07 2159.05 582.96 497.10 313.50 587.70 32.24 7.52
26 2358.12 55.79 42.25 38.18 2181.26 613.97 519.99 334.50 618.28 32.75 7.20
27 2387.62 57.32 41.90 29.50 2197.52 638.56 538.26 350.99 642.58 33.11 5.28
28 2409.53 57.59 41.46 21.91 2209.30 657.02 552.05 363.27 660.85 33.35 2.09
29 2448.03 57.43 41.54 38.50 2229.98 689.48 576.37 384.79 693.01 33.73 0.45
30 2479.71 57.77 40.38 31.68 2246.96 716.21 596.57 402.32 719.56 34.00 3.27
Srvy
tool
type
TIP
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
Tool
qual
type
6-axis
6-axis
6-axis
--
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6 -axis
6-axis
6-axis
[(c)1999 Anadrill IDEAL ID6_0C_04]
ANADRILL SCHLUMBERGER Survey Report
Seq Neasured Incl Azimuth
# depth angle angle
- (ft) (deg) (deg)
31 2504.56 58.30 39.61
32 2541.93 58.61 39.21
33 2573.46 58.64 39.46
34 2598.42 58.66 39.58
35 2641.11 58.63 39.35
Course
length
(ft)
24.85
37.37
31.53
24.96
42.69
36 2670.36 58.68 39.07
37 2691.41 58.69 39°75
38 2732.05 58.19 39.19
39 2763.59 56.86 39.31
40 2790.41 56.32 39.56
29.25
21.05
40.64
31.54
26.82
41 2825.47 56.32 39.63
42 2856.92 56.46 39.70
43 2883.67 56.55 39.67
44 2920.04 56.47 39.97
45 2951.53 56.33 39.93
35.06
31.45
26.75
36.37
31.49
46 2978.13 56.28 40.41
47 3013.76 56.33 40.73
48 3046.06 56.39 40.40
49 3070.35 56.34 40.94
50 3165.11 56.02 41.16
26.60
35.63
32.30
24.29
94.76
51 3232.43 56.24 41.52
52 3257.10 56.31 41.61
53 3326.06 56.39 41.79
54 3355.19 56.29 42.05
55 3419.83 55.97 41.89
67.32
24.67
68.96
29.13
64.64
56 3517.63 56.25 42.31
57 3554.29 56.41 42.47
58 3652.98 56.07 41.72
59 3748.95 56.62 42.31
60 3843.39 57.36 41.97
97.80
36.66
98.69
95.97
94.44
31-Oct-1999 20:25:44
TVD Vertical Displ Displ
depth section +N/S- +E/W-
(ft) (ft) (ft) (ft)
2260.11
2279.67
2296.08
2309.07
2331 28
2346.50
2357 44
2378.71
2395.64
2410 41
2429.85
2447 26
2462.02
2482.09
2499 52
2514.28
2534 04
2551.94
2565.39
2618.13
2655.65
2669.35
2707.56
2723.70
2759.73
Total
displ
(ft)
Page
737.30 612.72 415.87 740.53
769.14 637.33 436.09 772.25
796.06 658.15 453.15 799.07
817.38 674.59 466.72 820.31
853.83 702.74 489.89 856.64
At
Azim
(deg)
34.17
34.38
34.55
34.68
34.88
878.81 722.09 505.68 881.55 35.00
896.80 735.99 517.10 899.48 35.09
931.43 762.72 539.11 934.01 35.25
958.03 783.33 555.95 960.56 35.36
980.42 800.62 570.17 982.89 35.46
1009.60 823.10 588.76
1035.79 843.26 605.48
1058.10 860.43 619.72
1088.43 883.72 639.15
1114.66 903.83 655.99
1011.99
1038.12
1060.37
1090.63
1116.80
1136.79 920.74 670.27 1138.87
1166.42 943.26 689.55 1168.42
1193.31 963.69 707.03 1195.24
1213.53 979.03 720.21 1215.40
1292.23 1038.40 771.91 1293.88
1348.10 1080.36
1368.60 1095.72
1425.96 1138.58
1450.19 1156.62
1503.81 1196.52
2814.26 1584.91 1256.76
2834.59 1615.38 1279.29
2889.43 1697.35 1340.17
2942.62 1777.16 1399.52
2994.07 1856.27 1458.25
808.83
822.45
860.63
876.83
912.73
967.15
987.72
1042.72
1096.19
1149.33
1349.59
1370.04
1427.25
1451.41
1504.90
1585.82
1616.23
1698.04
1777.72
1856.73
35.58
35.68
35.76
35.88
35 97
36 05
36.17
36 27
36.34
36 63
36 82
36.89
37 09
37.17
37 34
37 58
37.67
37 88
38.07
38.24
3 of 4
DLS
(deg/
lOOf)
3.39
1.23
0.68
0.42
0.47
0.84
2.76
1 70
4.23
2 16
0 17
0.48
0 35
0.72
0 46
1 51
0.76
0.87
1.86
0.39
0.55
0.42
0.25
0.82
0.54
0.46
0.57
0.72
0.77
0.84
Sr~
tool
t~e
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
Tool
qual
type
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
[(c)1999 Anadrill IDEAL ID6_0C_04]
ANADRILL SCHLUMBERGER Survey Report
Seq Neasured Incl Azimuth Course
# depth angle angle length
- (ft) (deg) (deg) (ft)
61 3940.91 57.49 41.38
62 4035.13 55.65 39.41
63 4128.17 55.98 39.23
64 4215o86 56.32 39°50
65 4315.71 54.42 38.99
66 4402.43 54.07 38.90
67 4504.44 54.50 38.36
68 4598.25 54.93 37.78
69 4693.16 54.74 40.44
70 4782.01 54o61 42.91
71 4875.46 54.89 43.11
72 4970.12 55.37 43.43
73 5064.14 55.45 43.52
74 5158.46 55.42 43.47
75 5252.41 55.70 43.19
76 5346.69 55.89 42.27
77 5447.53 55.99 42.21
78 5539.63 56.18 41.68
79 5634.38 56.09 41.46
80 5727.78 56.31 41.18
81 5820.28 56.16 40.99
82 5915.44 56.21 41.23
83 6009.41 55.91 40.81
84 6102.19 56.06 40.72
85 6196.25 56.97 40.71
86 6288.69 57.51- 41.21
87 6351.69 58.09 41.14
Projected to TD
88 6430.00 58.09 41.14
97.52
94.22
93.04
87.69
99.85
86.72
102.01
93.81
94.91
88.85
93.45
94.66
94.02
94.32
93.95
94.28
100.84
92.10
94.75
93.40
92.50
95.16
93.97
92.78
94.06
92.44
63.00
31-Oct-1999 20:25:44
Page
4 of 4
TVD Vertical Displ Displ Total At DLS Srvy Tool
depth section +N/S- +E/W- displ Azim (deg/ tool qual
(ft) (ft) (ft) (ft) (ft) (deg) 100f) type type
3046.57
3098.48
3150.76
3199.60
3256.34
3307.01
3366.56
3420.75
3475.42
3526.80
3580.73
3634.85
3688.23
3741.74
3794.87
3847.87
3904.35
3955.74
4008.54
4060.49
1938.39 1519.63 1203.97
2017.00 1579.50 1254.93
2093.97 1639.04 1303.70
2166.79 1695.34 1349.89
2248.95 1758.97 1401.87
1938 . 77 38 . 39 0 o 53 MWD
2017 . 34 38 . 47 2 . 62 MWD
2094.30 38.50 0.39 MWD
2167.12 38.53 0.46 MWD
2249.27 38.55 1.95 MWD
2319.32 1813.70 1446.11 2319.64 38.57
2402.13 1878.40 1497.81 2402.46 38.57
2478.68 1938.69 1545.03 2479.04 38.55
2556.26 1998.88 1593.96 2556.61 38.57
2628.69 2053.02 1642.16 2628.99 38.66
2704.86 2108.83 1694.21 2705.09 38.78
2782.36 2165.38 1747.45 2782.52 38.90
2859.58 2221.54 1800.70 2859.68 39.03
2937.06 2277.89 1854.16 2937.12 39.14
3014.37 2334.25 1907.33 3014.40 39.25
3092.22 2391.53 1960.24 3092.23 39.34
3175.67 2453.37 2016.39 3175.67 39.42
3252.03 2510.22 2067.48 3252.03 39.48
3330.65 2569.08 2119.69 3330.65 39.53
3408.23 2627.37 2170.93 3408.23 39.57
3485.10 2685.33 2221.47 3485.10 39.60
3564.13 2744.90 2273.45 3564.14 39.63
3642.06 2803.72 2324.62 3642.07 39.66
3718.95 2861.97 2374.83 3718.96 39.69
3797.38 2921.43 2426.00 3797.40 39.71
4111.90
4164.86
4217.33
4269.23
4321.12
3875.09 2980.13 2476.96
3928.38 3020.26 2512.06
4371.15
4404.72
3875.12 39.73
3928.41 39.75
0.41
0.60
0.68
2.30
2.27
78.31 4446.11 3994.83 3070.32 2555.80
0.35
0.58
0.12
0.05
0.39
0.83
0.11
0.52
0.21
0.34
0.24
0.22
0.49
0.18
0.97
0.74
0.93
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
3994.87 39.77 0.00 MWD
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
[(c)1999 Anadrill IDEAL ID6_0C_04]
Schlumberger
Date: 31 Oct 99
Well Name: M-4
Company: UNOCAL
API Number: 50-733-20417-00
Oil Pool: Middle Kenai
Field: McArthur River
Rig: Steelhead Platform
Anadrill Field Crew:
Andre Nutter
Martin Leafstedt
David VanDehey
Anadrill Field Support: District Manager /
Field Service Manager: Joey LeBlanc
SERVICES PROVIDED
RECEIVED
Alaska Oil & Gas Cons. Commission
Anchorage
Service Service Dates Depth Interval
21 oCt 99 - 31 Oct 99
25 Oct 99 - 31 Oct 99
25 Oct 99 - 31 Oct 99
Directional Survey Service (DSS)
Compensated Dual Resistivity (CDR)
Azmuthal Density Neutron (ADN)
1480' -6430'
3615' -6430'
3615' -6430'
OPERATING STATISTICS
Total MWD Pumping Hours: 111.5
Total MWD Below Rotary Hours: 177.5
Total MWD Footage: 4950
Total MWD Runs: 2
Total LWD Pumping Hours: 64.0
Total LWD Below Rotary Hours: 94.5
Total LWD Footage: 2815
Total LWD Runs: I
,lOB PERFORMANCE
DIRECTIONAL
The final survey point was 6430.00 ft with an inclination of 58.09 degrees and an azimuth of 41.14 degrees.
This survey was projected to TD, giving the final bottom hole location:
Measured Depth:
True Vertical Depth:
Displacement at Azimuth:
6430.00 ft
4446.11 ft
3994.87 ft at 39.77 degrees
Schlumberger
FORMATION EVALUATION
Formation evaluation began on run 2 with the CDR (Compensated Dual Resistivity w/Gamma Ray) and
ADN (Azimuthal Litho-Density Neutron w/Ultra Sonic Caliper) tools. Tool communication problems
prevented real time communication with the CDR, but the ADN real time data was collected. Due to some
high ROP during the beginning portion of run 2, real time and recorded memory data were lower in density
compared to the later portions of the 8 ½ inch hole sections were controlled drilling practices were applied.
At the conclusion of the LWD run the tools were dumped and recorded data generated. The final recorded
data for the 8 ½" hole section had good resolution (wireline quality). Final data was presented in LAS
format and the printed PDS logs and files were generated using standard formats.
TRANSVERSE SHOCK
Transverse shock is monitored in the MWD, CDR, and ADN tools. Shocks for run 1 (12 %" hole section)
and run 2 (8 ½" hole section) were infrequent and low in severity.
LESSONS LEARNED
The importance of surface tool inspection and shallow hole testing. While no visual problems could be
noted on surface inspection during this well, the shallow hole test proved a useful tool for the prevention of
increased lost rig time.
Anadrill appreciates the opportunity to provide ARCO Alaska, Inc. with MWD and LWD services.
Sincerely,
Joey LeBlanc
Field Service Manager
MEMORANDUM
State of Alaska
TO:
Alaska Oil and Gas Conservation Commission
Robert Christenson!~~L~ DATE: October 27, 1999
Chairman
THRU' BlairWondzell, ~ FILE NO:
P. I. Supervisor [o[~('~")
FROM: John Crisp,~/~fo-~ SUBJECT:
Petroleum i~spector
BOP UNOCAL SH. DOC
BOPE Test, Steelhead
Unocal #M-4
McArthur River Field
PTD. #90-71
October 27,1999: I witnessed BOPE test on the Steelhead Platform in the
McArthur River Field after intermediate casing was run on Well #M-4
Arrived on Platform 1700 hrs. 10-26-99. Off Platform 2100 hrs 10-27-99. Several
problems w/casing hanger & test plug delayed test. A triplex test pump has
been assembled to use on Unocal Platforms that will decrease test time if no
problems are encountered. This was in part due to Lou Grimaldi's suggestion to
that effect. One failure was encountered on the accumulator. Air operated
hydraulic pump did not function properly. Two air pumps & one electric pump
operated properly. Parts are on the way to Platform to repair pump. Blair agreed
that operations should continue with existing system untill parts arrived on
Platfom. Accumulator will then be retested.
SUMMARY: ! witnessed BOPE test on Steelhead Platform Well #M-4 in the
McArthur River Field. Test time was 12 hours. One failure observed.
Attachments: BOPE test UNOCAL Steelhead 10-27-99jc
cc;
NON-CONFIDENTIAL
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report
OPERATION: Drlg: x Workover:
Drlg Contractor: POOL ALASKA
Operator: UNOCAL
Well Name: M-4
Casing Size: 9 5/8" Set @
Test: Initial Weekly
RigNo. SH. PIt. PTD#
Rep.:
Rig Rep.:
3603' Location: Sec.
Other x
90-71
DATE: 10/27/99
Rig Ph.# 776-6831
Terry Coleman / Nick Scales
Paul Barr
33 T. 9N R. 13W Meridian Seward
MISC. INSPECTIONS:
Location Gen.: P Well Sign
Housekeeping: P (Gert) Drl. Rig
PTD On Location P Hazard Sec.
Standing Order Posted P -"
N/A
P
p
BOP STACK:
Annular Preventer 1
Pipe Rams 1
Lower Pipe Rams 1
Blind Rams
Choke Ln. Valves 1
HCR Valves
Kill Line Valves
Check Valve
Quan. Test Press. P/F
25O/5, OOO P
250/5, 000
P
250/5,000 P
250/5, 000 P
P
250/5, 000
I 250/5, 000 P
2 P
250/5,000
N/A
MUD SYSTEM: Visual Alarm
Trip Tank P P
Pit Level Indicators P P
Flow Indicator P P
Meth Gas Detector Not tested Not tested
H2S Gas Detector P Calibrated
FLOOR SAFETY VALVES:
Upper Kelly/IBOP
Lower Kelly/IBOP
Ball Type
Inside BOP
Test
Quart. Pressure P/F
I 250/5,000 P
250/5,000 P
250/5, 000 P
25O/5, O0O P
CHOKE MANIFOLD:
No. Valves
No. Flanges
Manual Chokes
Hydraulic Chokes
Test
Pressure P/F
13 250/5,000 P
250/5, 000 P
Functioned P
250/5,000
ACCUMULATOR SYSTEM:
System Pressure
Pressure After Closure
200 psi Attained After Closure
System Pressure Attained 5
Blind Switch Covers: Master:
Nitgn. Btl's: 8 bottles
2500 psi. average
3,000 I P
1,200 I P
minutes 60 sec.
minutes 15 sec.
P Remote: P
Psig.
TEST RESULTS
Number of Failures: I ,Test Time: 12.0 Hours. Number of valves tested 20 Repair or Replacement of Failed
Equipment will be made within 7 days. Notify the Inspector and follow with Written or Faxed verification to
[the AOCCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-'1433
REMARKS:
Hydraulic pump on accumulator failed. This pump will be repaired when parts are available.
Accummlator will be retested after air operated pump is repaired. Operator & Rig represenatives are working on Accum. System
to make sure system will not only meet, but also exceed minimum State requirements.
Distribution:
Grig-Well File
c- Oper./Rig
c- Database
C - Trip Rpt File
c- Inspector
STATE WITNESS REQUIRED?
YES x NO
24 HOUR NOTICE GIVEN
YES x NO
Waived By:
Witnessed By:
John Crisp
FI-021L (Rev.12/94) BOP UNOCAL Steelhead 10-27-99jc.xls
TONY KNOWLE$, GOVERNOR
ALASKA OIL AND GAS
CONSERVATION COMMISSION
3001PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
October 6. 1999
Dan Williamson
Drilling Managcr
Union Oil Company of California (L~'OCAL)
P O Box 196247
Anchorage, AK 99519
Trading Bay Unit M-4
UNOCAL
Permit No: 90-71
Sur. Loc. 1032'FNL. 606'FWL. Sec. 33. T9N. RI3W. SM
Btmhole Loc. 2070'FNL. 2170'FEL. Sec. 28. T9N. RI3W. SM
Dear Mr. Williamson:
Enclosed is the approved application for permit to re-enter and change the bottom-hole location
of the above referenced well.
The permit to re-enter 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.
The blowout prcvcntion equipment (BOPE) must be tested in accordance with 20 AAC 25.035:
and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC
25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test
befbre operation, and of the BOPE test prior to drilling new hole must be given so that a
represcntativc of the Commission may witness the tests. Notice may be given by contacting the
Commission at 279-1433.
Sincerely.
Robert N. Christenson. P. E.
Chairman
BY ORDER OF THE COMMISSION
dlffEnctosurc
CeZ
Dcpartment of Fish & Game. Habitat Section w/o cncl.
D~partmcnt of Environmental Conservation w/o cncl.
Unocal Alaska Resource,.
Unocal Corporation
909 W. 9th Avenue, P.O. Box 196247
Anchorage, Alaska 99519-6247
UNOCAL
September 21, 1999
ORIGINAL
Mr. Robert N. Christenson, Chairman
Alaska Oil and Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501-3192
Trading Bay Unit, Steelhead Platform, Well M-4
REQUEST FOR SPACING EXCEPTION
ADL 18730
Dear Chairman Christenson:
RECEIVED
22 1999
Alaska 0il & Gas Cons. Commission
Anchorage
Enclosed and submitted in triplicate is our application for Permit to Drill Trading Bay
Unit, Steelhead Platform Well M-4 (form 10-401) pursuant to 20 AAC 25.005 and our
check No. 2003574 in the amount of $100.00 as required under 20 AAC 25.005(c)(1).
Verification of Application by the undersigned stating that applicant is acquainted with
the facts, pursuant to 20 AAC 25.055(b), is attached as part of this application.
It is requested that the Commission approve an exception to the statewide spacing
regulation 20 AAC 25.055(a)(4) for the drilling of Well M-4, ADL 18730.
Trading Bay Unit Well M-4: The specific location, interval and depth are as follows:
Surface Location:
1032' FNL, 606' FWL, Sec 33, T9N, R13W, SM
Top of productive Interval: 750' FSL, 1995' FWL, Sec 28, T9N, R13W, SM
Total Depth and Location:
6400' MD, 4460' TVD; 2070' FNL, 2170' FEL, Sec 28,
T9N, R13W, SM
Unocal and Marathon are working interest owners in the Well M-4. Furthermore, Unocal
and Marathon are the owners--and Unocal is the operator of all directly or diagonally
offsetting sections. Therefore notices by registered mail pursuant to 20 AAC 25.055(b)
are not necessary.
If you require additional information, please contact Shannon Martin at 907-263-7882, or
Neil Magee, Drilling Department at 907-263-7671.
Very truly yours,
Shannon W. Martin
Enclosures
Unocal Corporation
909 W. 9th Avenue
Anchorage, AK 99501
907-263-7660
UNOCAL
Dan Williamson
Drilling Manager
31 August 1999
Mr. David Johnston
Commissioner
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Ak 99501-3192
Dear Mr. Johnston: ORIGINAL
Enclosed, please find the application for the Permit to Drill (Form 10-401) for the Steelhead
Platform Well M-4. The intent of this well is to provide additional gas deliverability from the
Grayling Gas Sands. UNOCAL plans to spud this well approximately 4 October 1999.
The 16" surface casing in this well was preset in July of 1990 as part of an effort by Unocal
and Marathon to provide a rapid means of providing a replacement well should an existing
gas well be lost during the peak winter demand months. The intermediate casing for this well
is planned to be set at 3900' MD (3019' TVD) which coincides with a pressure transition from
"normally" pressured reservoirs to depleted gas reservoirs. The production liner will be 7" set
at 6400' MD (4460' TVD). The proposed casing setting depths for M-4 are per the
regulations in particular Conservation Order 228 as amended.
Unocal will employ the existing BOP system presently on board Steelhead. For well control
purposes, a fracture gradient of .8 psi/ft has been used the 16", and .85 psi/ft for the 9-5/8"
shoe. UNOCAL'S drilling experience in the~bk, lnlet has demonstrated true shallow
fracture gradients ranging from 0.75 - 0.94 psi/ft (~ee Leak Off Test Data). For the kick
conditions analyzed, the maximum bottom holepressure anticipated remains well below the
anticipated fracture pressure.
UNOCAL plans to complete M-4 as a 4-1/2" single string gas well in the 7" production liner.
Please contact the undersigned with any questions regarding this application.
Dan Williamson
Drilling Manager
enclosure
.--.. STATE OF ALASKA
ALASKA OIL.. ND GAS CONSERVATION CE .,IMISSlON
PERMIT TO DRILL
20 AAC 25.005
la. Type of work Drill: Redrill: 1 b. Type of well Exploratory: Stratigraphic Test: Development Oil:
Re-Entry: X Deepen: Service: Developement Gas: X Single Zone: Multiple Zone:
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
Union Oil Company of California (UNOCAL) 160' KB above MSL feet McArthur River Field
3. Address 6. Property Designation Middle Kenai
P.O. Box 196247, Anchorage AK 99519 ADL 18730
4. Location of well at surface Slot No.9, Leg B-2 Steelhead 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025)
1032' FNL, 606' FWL, Sec 33, T9N, R13W, S.M. Trading Bay Unit AK Statewide Oil & Gas Bond
At top of productive interval 8. Well number Number U62-9269
750' FSL, 1995' FWL, Sec 28, T9N, R13W, SM M-4
At total depth 9. Approximate spud date Amount $200,000
2070' FNL, 2170' FEL, Sec 28, T9N, R13W, SM 10/4/1999
12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
property line Well Proximity Steelhead M-1
3110' at TD feet 18' at 1421' TVD (KOP) 3840 6400' MD, 4460' TVD feet
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2))
Kickoff depth: 434' feet Maximum hole angle: 55 deg Maximum s. urrace 925 psig At total depth (TVD) 1000 psig
18. Casing program Setting Depth
size Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
Existing 20" 133 X-56 RL-4S 849' 80' 80' 929' 928' 2050 sx (in place)
Existing 16" 75 K-55 Butt. 1379' 78' 78' 1457' 1442' 1000 sx (in place)
12-1/4" 9-5/8" 47 lb N-80 Butt. 3822' 78' 78' 3900' 3019' 1250 sx
8-1/2" 7" 29 lb N-80 Butt. 2800' 3600' 2846' 6400' 4460' 430 sx
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured 1457' feet Plugs (measured)
true vertical 1442' feet
Effective depth: measured 1412' feet Junk(measured)
true vertical 1398' feet
Casing Length Size Cemented Measured depth True vertical depth
Structural 849' 20" 2050 sx 929' 928'
Conductor 1379' 16" 1000 sx 1457' 1442'
ISn~erf;mC;d lateRECEIVED
Production
Liner SEP2 £ 1999
Perforation depth: measured
true verticalOil & ons. C0nmlir i n
20. Attachments: Filing fee: X Property Plat: BOP Sketch: X Diverter Sketcl~r?"~m~~ Drilling program: X
Drilling fluid program: X Time vs. depth plot.: X Refraction analysis: Seabed report: 20 AAC 25.050 requirements:
21. I herby~at thesigned~ foregoing ~ true and correct to the best of mYTitle: k n °wi e d g e~J~f~///~/~'/¢~' ~~~/~,,, Date
Commission Use Only/ vv
Permit Number I APl number ~;~ O I Approval date [ See cover letter
.'~[~ '~"""~f t 50- ,~,.~,~-'-' .2.(~ ~/7-- I~'~ "'c~S for other requirements
Conditions ofapproCal Samples required: [ ] Yes ~]~No Mud log required: [ ] Yes j~ No
Hydrogen sulfide measures [ ] Yes "~'No Directional survey required ,~J:Yes [ ] No
Required working pressure for DOPE [ ]2M; '~,/~3M; [ ]5M; [ ] 10M; [ ] 15M
Other:
Approved by ORIGINAL SIGNED'BY by order of
....... ,,, r~.,.;.,~,-,,,,er,~ Commissioner the Commission Date:
Form 10-401 Rev. 12-1-85 Submit in triplicate
Leak OffTest (LOT) Data
Cook Inlet, Alaska
Revised 1/30/97
Alaska Drilling
FIT/LOT
Baker Platform
Ba 28 10/10/93 24" 802' 0.94 18.1
Ba 30 10/24/93 24" 803' 0.83 15.9
,.
Ba30 10/28/93 18-5/8" 2,0ii 0.94 18.1
Ba 28 11/17/93 18-5/8" 2, I35' 0.75 14.5
Ba 29 12/17/94 18-5/8" 2,054' 0.76 14.61
Ba 29 12/29/93 13-3/8" 5,869' 0.85 16.33
Ba 30 1/27/94 13-3/8" 5,467' 0.93 17.96
Ba 28 3/1/94 13-3/8" 3,509' 0.75 14.4'
Ba 31 3/4/96 18-5/8" 801' 0.82 -1'5.68
Ba 31 3/9/96 13-3/8" 2,076' 0.80 15.4
Ba 31 3/15/96 9-5/8" 5,937' 1.02 19.7 FIT
.
Ba 32 4/21/97 13-3/8" 787' 0.91 t7.49
Ba 32 4/27/97 9-5/8" 2,052' 0.76 14.67
Ba 32 5/5/97 7" 3,975' 0.72 13.94
Dillon Platform
16 4/22/94 18-5/8" 1,131' 1.12 21.72~
16 6/16/94 13-3/8" 3,640' 0.82 15.8
16 7/4/94 9-5/8" 9,469' NA 14.2 FIT
17 4/27/94 18-5/8" 1,142' 1.01 19.47
17 5/1/94 13-3/8" 3,560' 0.83 15.9
17 05- 9-5/8" 9,213' NA 16.5 FIT
18 7/26/94 18-5/8" 1,132' 1.02 19.63
18 8/1/94 13-3/8" 3,988' 0.80 15.3
Grayling Platform
G-40 1/24/90 16" 1,926' 0.96 18.46
G-40 2/3/90 13-3/8" 4,977' 0.86 16.54
G-15RD 7/1/98 9-5/8" 8,385' 0.75 14.98LOT
iG-21RD 5/15/98 9-5/8" 7,001' 0.75 14.43'LOT
G-SRD 6/21/98 9-5/8" 7,142' 0.8t 15.61FIT
King Salmon Platform
K-8RD 1/25/85 9-5/8" 0.74
I 7'740'1 14.2ILOT
Monopod Platform
..,
A- 1 rd 4/4/91 9-5/8" 1,132' 1.07 20.57
A-Srd 7/1/89 9-5/8" 3,760'i 1.02 19.61
,.
A-20rd 3/30/90 t 3-3/8" 755' 0.95 18.2
A-20rd 4/13/90 9-5/8" 1,931' 0.85 16.3
A-28rd 11/20'/89 20" 240' 0.75 14.42
A-28rd 11/27/89 13-3/8" 1,140' 0.97 18.65
Steelhead Platform
IM'I(~ I 10/1/97 I '13-3/8" I 837'l 0.81[ 15.64tLOT
UNOCAL AK LOTdata.xls Page I of 2 8/30/99~9:14 AM
Leak OffTest (LOT) Data
Cook Inlet, Alaska
Revised 1/30/97
UNOI AL
Alaska Drilling
Well # Date I Csg Size ShOe(TVD)Depth (psi/ft.)EMW ' EMW(ppg) FIT/LOT
M-16 10/1/97' I ~-5/8"" ..... 1,438,; ,.' 0.91 17.48 LOT ....
Granite Point Platform
11-13rd 2/14/92 9-5/8" 9,966' 0.96 18.4
51 8/7'/92 13-3/8" 3,803' 1.00 19.2
51 7/28/92 18-5/8" 1,010' 0.87 16.8
, ,
51 8/25/92 9-5/8" 9,592' 1.05 20.2
50 5/27/92 18-5/8" 982' 0.91 17.5
50 6/4/92 13-3/8" 4,208' 0.84 - 16.2
50 6/27/92 9-5/8" 9,877' 0.93 17.9
54 11/25/96 13-3/8" 1,120' 1.14 21.94
· 54 11/30/96 9-5/8" 3,334' 0.94 18.13'
54 12/28/96 7" 9,685' 0.81 ! 5.52 *
53 6/3/97 13-3/8" 1,030' 1.27 24.41
53 6/10/97 9-5/8" 4,088' 1.02 19.64
53 6/26/97 7" 10,480' 0.84 16.6 *
Anna Platform
11 rd 10/23/94 13-3/8" 2,976' 0.89 17.2
1 lrd 11/11/94 9-5/8" 8,750' 0.92 17.7 FIT
3rd 12/10/94 9-5/8" 7,839' 0.75 t4.5
"'50 2/8/95 18-5/8" 1,160' 1.38 26.6
50 2/13/95 13-3/8" 4,251 1.01 19.5
50 3/8/95 9-5/8" 9,844' 0.86 16.5
51 1/29/95 · i 18-5/8" 1,130' 1.36 26.2
51 5/15/95 13-3/8" 3,796' 0.71 13.6
51 6/3/95 9-5/8" 9,842' 0.88 17 FIT
52 2/3/95 18-5/8" 1,153' 1.41 27
52 3/27/95 13-3/8" 3,940' 0.84 16.15
· ,
52 4/15/95 9-5/8" 9,470' 0.91 17.6 FIT
,,
7rd2 8/25/95 9-5/8" 4,439' 0.96 18.5
Swanson River Field (Onshore)
[SRU 223-28 [ 8/10/97 } 7" I 2,058'1 .1.10 { 21.11
Notes:
All fracture gradients reported have been corrected for air an? water gaps.
(FIT)-Formation Integrity Test
UNOCAL AK LOTdata. xls Page 2 of 2 8/30/99/9:14 AM
Steelhead Platform
Well # M~4
Trad/ng Bay Unit
August 18, 1999
Hole Section 1
Depth Interval:
1457' to 3900'
12-1/4" hole size
16" casing to 1457'
Mud weight:
Shoe depth (16"):
Est. fracture gradient of 16" shoe:
Depth of next hole section (12-1/4"):
BHP gradient:
Gas gradient (assume worst case):
9.4 ppg=0.49 psi/ft
1457' MD/1442' TVD
0.80 psi/ft
3900' MD/3Cfl9' TVD
0.48 psi/ft
0.0 psi/ft
Gas kick situation/n wellbore. Assume 3/4 mud and 1/4 gas
MSP=BHP - Hydrostatic Pressure
MSP=BHP - (3/4 mud + 1/4 gas)
MSP=(3019'x.48 psi/ft) - ((.75(3019'x0.49 psi/fi)) + (.25(3019'x0.0 psi/fi))
MSP= 340 psi
Therefore, the hydrostatic pressure at the 13-3/8" shoe (Hpsh) is the greatest when the gas (kick) bubble
reaches the 13-3/8" shoe, ifa constant BHP is applied. A conservative estimate would be the MSP plus the
hydrostatic pressure at the 13-3/8" casing depth (Hpcsg).
Hpsh= MSP + Hpcsg
Hpsh= 340 + (1442'x0.49 psi/ft)
Hpsh= 1046 psi
This (Hpsh = 1046 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to
handle the well kick scenario.
Hpsh = 1046 psi < Fpsh = 0.80 psi/ft x 1442' = 1 I53 psi.
Steelhead Platform
Well # M-4
Pressure Calculations
Hole Section 2
Depth Interval:
3900- 6400'
8-1/2" hole size
9-5/8" casing to 3100'
Mud weight:
Shoe depth (9-5/8"):
Est. fracture gradient of 9-5/8" shoe:
Depth of next hole section (8-1/2"):
BHP gradient:
Gas gradient (assume worst case):
8.8 ppg=0.46 psi/ft
3900' MD/3019' TV'D
0.85 psi/fi
6400' MD/4460' TVD
0.40 psi/ft (worst case)
0.0 psi/ft
Gas kick situation in wellbore. Assume i/2 mud and 1/2 gas.
MSP=BHP - Hydrostatic Pressure
MSP=BHP - (1/2 mud + 1/2 gas)
MSP=(4460'x.40 psi/fO - ((.50(4460'x0.46 psi/fi)) + (.50(4460'x0.0 psi/f-t))
MSP= 759 psi
Therefore, the hydrostatic pressure at the 9-5/8" shoe (Hpsh) is the greatest when the gas (kick) bubble
reaches the 9-5/8" shoe, if a constant BI-IP is applied. A conservative estimate would be the MSP plus the
hydrostatic pressure at the 9-5/8" casing depth (Hpcsg).
Hpsh= MSP + Hpcsg
Hpsh= 759 + (3019'x 0.46 psi/fi)
Hpsh= 2147 psi
This (Hpsh = 2147 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to
handle the well kick scenario.
Hpsh = 2147 psi < Fpsh = 0.85 psi/ft x 3019' = 2566 psi.
I ECEIVED
$EP 2 2 1999
Nas~a Oil & Gas Cons. Commission
Anchorage
CASING DESIGN M-4
WELL: STEELHEAD M-4 FIELD: TRADING BAY UNIT DATE: 18-Aug-99 DESIGN BY: Neil Magee
Section 1. MUD WI'. I 8.8 PPG MSP= 340 psi
Section 2. MUD WT. II 9.4 PPG MSP= 759 psi
TENSION MINIMUM
WEIGHT TOP OF STRENGTH
INTERVAL DESCRIPTION wig BF SECTION TENSION
CAS NG ,SIZE BOTTOM TOP LENGTH WT___~. GRADE THREAD LB.__._~S LB__.~S 1000 LBS
I 9-5/8" 3900 82 3818 47 L-80 BTC 179446 179446 1370
TVD 3019 82
2 7" 6400 3600 2800 29 L-80 BTC
TVD 4465 1000
SF TENSION
7.63
COLLAPSE COLLAPSE
PRESS @ RESIST.
BOTTOM wlo TENSION
PSl.___~' PS._.JI
1328 4900
81200 81200 877 10.80 1965 6370
NOTES: See attached for calculation of M.S.P. including assumplions & estimates.
· Collapse pressure 18 calculaled; Normal Pru~uro Fluid Gradiunl for external t;trus~ (,44 p~i/II) arid lhu ca~lHg uvacualud lot lbo Inlornal slruss (0 psi/Il)
*' Maximum suHace pressure is calculaied; (BHP @ depth next csg assuming a Normal Fluid Gradient (.44 psi/it))
SF COLL.
3.69
3.24
MAX
SURF MINIMUM
PRESSURE YIELD
PSI'* PS._.J
1328 6870
SF BURST
5.17
1965 8160 4.15
Hay 12, 1988 (907) 276-7542
ADMINISTRATIVE APPROVAL NO. 228.1
Re: Auxiliary Casing and Cementing Requirements, McArthur River
Field, Trading Bay Unit.
Robert T. Anderson
District Land Manager
Alaska District
Unocal Corporation
P. O. Box 190247
3mchorage, AK 99519-0247
Dear Mr. Anderson:
We have received your !eta_er of May 12, 1988. On behalf of
Unocal and the Working Interest Owners of the Trading Bay Unit
you have requested an amendment to Conservation Order (C.O.) 228.
2~he Commission has reviewed your request and determined that
sound engineering practices will be maintained and the amendment
will not result in physical waste.
Therefore the Commission hereby amends C.O. 228 by adding Rule 4
co read:
Rule 4 Auxiliary Casing and Cementing Requirements
~,~%erever gas bearing strata are expected to exist above a true
vertical depth of 2000', an a~xiliary casing string must be set
and cemented in accord with 20 AAC 25.030(d)(2) before drillin=~
into the expected gas bearing strata. Before drilling out, this
auxiliary casing string must be equipped with blowout prevention
equipment installed and tested.in conformance with 20 AAC
25.035(a). The auxiliary casing string is in addition to and not
in lieu of the surface casing string required by Rule 2(a) of
C.O. 80.
Siru~mre lv,
Chairman
RECEIVED
BY ORDER OF THE COMMISSION
dlf/3.AA228
UNOCAL )
RKB to TBG Head = 74'
Tree connection:
SIZE
28"
20"
16"
9-5/8"
7"
Tubing:
4-1/2"
D teeln earl
Well M-4
proposed Completion
CASENG AND TUBING DETAIL
GRADE CONN ID
TOP BTM.
133
75
47
29
Driven Surf 488'
X-56 RL4-S 18.730" Surf 929'
K-55 Buttress 15.124" Surf 1457'
L-80 Buttress 8.681" Surf 3900'
L-80 Buttress 6.184" 3600' 6400'
I2.6 L-80
Imp. Mod. Butt. 3.958" Surf 5000'
NO.
:
3
4
5
6
7
Depth
74'
74.5'
5200'
5495'
5500'
OD
JEWELRY DETAIL
ID Item
16.75"
4.875
3.958
3.958
FMC 16.75" x 4-1/2" CS Tubing Hanger,
Cameron Type H BPVP
4-1/2" CS Pin x 4-1/2" Imp. Mod. Buttress Pin
Baker TRBPV
4-1/2" 12.6 lb/ft L-80 Imp. Mod. Butt. Tubing
Baker FHL Retrievable Packer
Baker X Nipple
Baker Shear Out Ball Seat Sub
B-4
B-6
PERFORATION DATA
PBTD = ?' ID = 6,396'
M-4 Froposcd Completion.doc
NM 8/23/99
Preliminary Drilling Program
Steelhead M-4
Operation " Time Cumm. Ti'me Total'
1 Skid fig"to STM leg 24.0 24 1.0
2 Connect service lines, instali catWalk,v-door 20.0 44 i.8
3 Remove Tree 8.0 52 2.2
,,
4 N/U 16-3/4" BOP's and riser 12.0 64 2.7
5 P/T BOP's 4.0 68 2.8
,,,
6 MU BHA to drill out 16" casing 5.0 73 3.0
7 KIH picking up pipe 6.0 79 3.3
8 Drill out 16" shoe 2.0 81 3.4
9 Drill 10' of new hole and perform LOT 2.0 83 3.5
10 POOH and lay down 16" assembly 5.0 88 3.7
11 M/U 12-1/4" directional assy and RIH 5.0 93 3.9
12 Drill 12-1/4" hole with MWD to'~100' "' 32.0 125 5.'2
13 CBU 2.0 127 5.3
,.,
"'14 POOH f°r bit 5.0 132 5.5
15 Make up new bit and R_IH 7.0 139 5.8
16 Ream to bottom 2.0 141 5.9
17 Drill fi-om 3100' to 3900' 15.0 156 6.5
18 Circulate hole clean 2.0 158 6.6
19 IMake short trip to 16" shoe 4.0 162 6.8
20 poOH and lay down 12-1/4" BHA 3.5 166 6.9
21 Pull wear bushing and RU to run 9'-5/8" casing 2.0 168 7.0
22 Run 9-5/8" casing to 3900' 8.0 176 7.3
.,,
23 Cement 9-5/8" casing 3.0 179 7.4
24 Install wellhead packoff and test " 2.0 181 7.5
25 Pressure test BOP's 4.0 185 7.7
26 PU 8-1/2" Bt-LA and RIH 5.0 190 7.9
27 Drill out Shoe track and 10' new hole 3.0 193 8.0
28 Perform LOT 2.0 195 8.1
~9 Drill 8-1/2" hole with MWD to 4700' " 20.0 215 8.9
,
..,
30 CBU 2.0 217 9.0
31 pOoH and PU new bit 5.0 222 9.2
32 " R~ and ream to bottom 6.0 228 9.5
33 Drill 8-1/2" hole with MWD from 4700 to 5600' 24.0 252 10.5
34 cBu 2.0 254 10.6
35 POOH and PU new bit 6.0 260 10.8
36 R2H and ream to bottom 6.0 266 11.1
37 !Drill 8-1/2" hole from 5600 to 6400' 24.0 290 12.1
38 Short trip to 9-5/8" shoe 3.0 293 12.2
39 CBU and POOH 5.0 298' 12.4
40 PoOH for wireline logs 4.0 302"' 12.6
41 Run triple combo logs from 640023900'. 9.0 311 12.9
42 Change rams to 7" and test door ~'eals to 2000 p~i 2.0 313 13.0
43 R/U casing tools and run 7" 8.0 321 13.4
,
44 :Cement 7" casing 9.0 330 13.7
45 Change rams to 4-1/2" and P'~T BOP's 6.0 336 14.0
46 L/D 8-1/2" BI-IA 3.0 339 14.1
. ,
47 POOH and P/U 6" clean out assy. 6.0 345 14.4
48 Rill 9.0 354 14.7
....
49 Clean out 7" casing 2.0 356 14.8
.
50 Circulate well to 6% KCL 8.0 364 15.1
,,
51 POOH 6.0 370 1514
52 R/U Schlumberger. Run CET/CBT/GR and TDT 10.0 380 15.8
53 POOH 4.0 384 16.0
54 PU TCp guns 3.0 387 16.1
55 RIH with TCP guns on 5 x 3-1/2" Dp 6.0 393 16.4
56 RU SWS PU Gamzna Ray/C~L 4.0 397 16.5
57 Place guns on depth 2.0 399 I6.6
,. ,
58 Set packer, fire guns, circulate out 4.0 403 16.8
,,,
59 POOH with TCP guns 6.0 409 17.0
60 Rig up to mn 4-1/2" completion 2.0 411 17.1
,,
61 RIH with 4-1/2" completion and packer 8.0 419 17.4
62 SPace out and land hanger 2.0 421 17.5
63 ~ND BOP's 8.0 429 17.9
64 Install 4-1/16" tree and test 6.0 435 18.1
65 Rig down off well 24.0 459 19.1
66 Well to be brought on with nitrogen via coil robing 0.0 459 19.1
UNOCAL
Sfruc'fur~ : STE£LHE~n P!a~on-n
Well
Field : ~4cArf, hur RNer Field Loc~ffon : TBU, Cook Inl~, Alaska
UNOCAL
Eosf (feel) ->
! 800 ! 200 800 4dO 0 ~30 800 1200 1800
{ I L I I ' ' I I I I I ) I i I { I I I I I ' '
8C0
4.0O
800
1200
O 2000
03 2~-00
-I 28C0
I
V
3600
44300
8.7.5 KOP
21.86
25.95
50.15 OLS: &.50 deg per {CO
54.45
~, 45.10
x 54.75 £0C
/
/
/
/
/
/
/
/
/
ro~ O! Sand (5-Ju1-99) ~
/
/
/
/
/
/
/
/
/
/
/
/
?
/
Tap 01 Sand (6-Jul-99)
i i i i i i i i i i i i i : ! i i ~ , , , ~ , , , ,,, , , 1
4430 0 4420 800 1200 1600 ZOOO 2400 2800 52.00 5600 4000 &44)0 ~
Vertical Section (feet) ->
Azimuth ,:79.52 with reference 0.00N, 0.00 E from slot #82-9
-J200
-2~00
2~.C0
-2¢oo A
1600
0
1200 ~
800 ~.~
4-C0
UNOCAL
STEEL~NEAD P1 atform
slot #B2- 9
HcArthur Ri ver Field
I'BU, Cook ~nlet, Alaska
PRO?OSAL LISTING
by
Baker Hughes ~NTEQ
Your ref : M-4 Version
Our ref : prop3478
License :
Date printed : 25-Aug-1999
Oate created : 7-Ju1-1999
Last revised : 7-Ju1-1999
Field is centred on n60 50 4.803,w151 36 18.018
Structure is centred on n60 50 4.803,w151 36 18.018
Slot location is n60 49 54.642,w151 36 5.788
Slot Grid coordinates are N 2499467.742, E 214221.561
Slot local coordinates are 1031.82 S 606.28 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North'is True North
RIECEIVFI)
22 1999
Anchorage
UNOCAL
STEELHEAD P1 atform,*M-4*
McArthur River Field,TSU, Cook Inlet, Alaska
Measured Inclin. Azimuth True Vert
Oepth Oegrees Degrees Depth
142!.00 18.75 18.00 1407.89
1500.00 21.86 22.98 1481.98
!600.00 25.95 27.60 1573.38
1700.00 30.15 31.03 1661.62
!800.00 34.43 33,68 1746.14
lg00.00 38.75 35.81 i826.41
2000.00 43.10 37.57 1901.96
2100.00 47.47 39.06 1972~30
2200.00 51.86 40.36 2037.01
2265.66 54.75 41.13 2076.24
2500.00 54.75 41.13 2211.49
3000.00 54.75 41.13 2500.06
3500°00 54.75 41.13 2788.63
4000.00 54.75 41.13 307L20
4500.00 54.75 41.13 3365.77
5000.00 54.75 41.13 3654.34
5500.00 54.75 41.13 3942.91
5980.!I 54.75 41.13 4220.00
6000.00 54.75 41.13 4231.48
6395.95 54.75 41.13 4460.00
PROPOSAL LISTING Page 1
Your ref : M-4 Version #3
Last revised : 7- Jul- 1999
R E C T A ,~4 G U L A R Dogleg Vert
C 0 0 R D ~ N A T E S Deg/lOOft Sect
121,56 N 43.41 E 0.00 121.40
147.19 N 53.07 E 4.50 I47.32
183.74 N 70.49 £ 4.50 186.59
224.68 N 93.59 E 4.50 232.87
269.75 N !22.23 E 4.50 285.87
318.68 N !56.23 E 4.50 345.25
371.16 N 195.39 E 4.50 410.66
426.88 N 239.46 E 4.50 481.68
485.48 N 288.18 E 4.50 557.89
525.36 N 322.54 E 4.50 610.52
669.50 N .~.43 E 0.00 801.81
977.04 N 7!7.03 E 0.00 -1209.97
1284.58 N 985.63 E 0.00 1618.13
1592.12 N 1254.23 E 0.00 2026.29
1899.66 N 1522.83 E 0.00 2434.45
2207.20 N I791.43 E 0.00 2842.61
2514.75 N 2060.03 E 0.00 3250.77
2810.05 N 23!7.94 E 0.00 3642.69
2822.29 N 2328.63 E 0.00 3658.94
3065.83 N 254!.33 E 0.00 3982.16
Top D1 Sand (6-Jul-99)
All data is in feet unless otherwise stated.
Coordinates from slot ~82-9andl%/D from wellhead (160.25 Ft above mean sea level).
Bottom hole distance is 3982.17 on azimuth 39.66 degrees from wellhead.
Total Dogleg for wellpath is 38.01 degrees.
Vertical section is from wellhead on azimuth 39,52 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
UNOCAL
STEELHEAD Platform,*M-4*
McArthur River Field,TBU, Cook Inlet, Alaska
PROPOSAL LISTING Page 2
Your ref · M-4 Version #3
Last revised · 7-Jul-I999
Co~ents in wellpath
MD TVD Rectangular Coords. Ccmment
5980.11 4220.00 2810.05 N 2317.94 E Top D1 Sand (6-Jul-99)
Targets associated with this wellpath
Target name Geographic Location T.V.D. Rectangular Coordinates Revised
Top D1 Sand (6-Jul-9 4220.00 2810.05N 2317.94E 6-Ju1-1999
33O
~20
,310
300
UNOCAL
Sfru~tura : STEELHEAD Platform
Fl~ld : ~lcArfhur Rlv,r Field
Well : '~1-~.*
Locafton : TBU, Cook Inl~, Alaska
TRU~
,a NORTH
9
1800 ! 3000
10
2O
3O
UNOCAL
i3500
34~30
3300
3200
4331 O0
000
2900
~o60
27C0
2600
5O
2500
290
7O
280
8O
2 t0 150 1
9O
26O
lO0
250
110
120
1500
500
210
600 1 0
1700 190
Normal Plane Travelling Cylinder- Feel:
180 170
150
140
160
A
1900
1800
a 1 O0 200 OOO 4.08 50(
700
1 $0o
4000
1500
4800
14OO
940O
1300
1200
5400
1100
1000
900
8O0
26O
5000
700
600
500
40O
5OO
9200
1 O0
0
4600
8800
-UL;OCAL
Struc'tur, : STEE!..H~.AO Pkrtform
F~eld : ~4cAr~hur RI¥,r
'//ell :
Locaffon : TBU, Cook Inl~i', Alaska
Eos~' (feet) ->
800 gOO 1000 1 1 O0 12.00
7000 6800
5600
5~00
5400
2600
6OOO
58OO
6800 O0
5800 Z600
54O0
2200
400--
7800
/
/
/
/
%
8600
8000
5800
3800
88OO
/
/
/
,,'%
9000
)0
8000
00
56OO
4200
2OOO
O0
4443O
540O
6000
5800
3600
8200
54-OO
860O
6600
100 200 500 400 500
4600
8800
$00 700 800 gOO 1000 11 O0 1200 1500
East (feet) ->
UNO£AL,
14O0
800
/
/
/
720O
6200
74OO
1500 1602
/ - 1900
/ / / t 1800
1700
-1600
15C0
1400
1JaO
~20o A
I
Z
l lCO
0
ICCO ~
--4'-
gCO ~
8C0
700
8800
6OO
g000
9200
5OO
40O
200
94430 2O0
IOO
14O0 1500 1642O
3200 6000
3100
SOO0
2900
2800
UP-O CAL 17'
~..
Sfrucfure : ~-FE£LH'ZAP, Platform
Well : *~--4'
Field : ),IcA4hur ,~,ver Field Location : TDU, Cook Inl~f, Alaska
'UNOCAL
East (feet) ->
2700
2500
2500
.~_ 2~00
~ 2JO0
0
Z
1200 1JO0 140 1500 1600 1700 1800 1gao 2000 2100 200 2500 2~0 25c0 2500 27~ 2flc,0
JOO0
7500
7800
8000 F 3200
8200
eeco ~'--~./ %00 [ZlOO_ Jooo
8soo / / /
~600 / /
2900
/ L 2700
/
/ ~ 2500
4601 /
/ 4800 /
/ zsoo
/
/ 5000
/ 2~0
/ /[2JO0~
/ ,/400
/ -~00
/
/ ~00 -2tO0
/
/ -
/
/ -2000
/
/ ~ IgOO
/
/
/
/ 1800
/
/ / ~4800
7200/' ~ 1700
/
7~0 1800
7600 ~00
1500
1200 1300 1~0 1500 1600 1700 1800 1900 2000 2100 ~00 2300 2~00 25~ 25~ 27~
Easf (feel) ->
220O
2100
2OOO
t 900
18C0
700
1600
1500
0 44] 80 120
760
720
8200
58O
64,0
600
560
520 ·
48O
2000
4.0o
560
Sfrucfur. : STEELHEAO ?~for,m
Jqeld : McA,'ffhur River FTeld
Well
Looaflon: TBU, Cook Inle-f, Alaska
~ Ecsf (feet) ->
) 24O 280 520 J60 4420
4-4.0 4.80 520
58C0
5600,
2600
4-8OO
7200
5OOO
/
/
/
/
/
/
/
5200
/
/
/
7600
/
/
/ .
/
/
/
/
/
/
800
5400
UNO£AL,
/
/
/
/
56O
60~ 84O
8C0
780
I 720
580
5200
4200
~20
55O
A
Z
520
280
24O
160
/
/
iI
5600 /
600 /
/
2000
2400
9000
9200
2800
5000
5600
5200
320
24O
200
160
120
9400
120
8O
8O
120
160
200
240
280 320 360
East (feet) ->
4-0O
480
560
6OO
8O
640
UNOCAL
STEELHEAJ] P1 atform
slot ,-lB2-9
McArthur Ri ver Fiet d
TBU, Cook ~nlet. Alaska
3-D
MINIMUM DISTANCE CLEARANCE
by
Baker Hughes INTEQ
YouF ref : M-4 Version #3
Our ref : prop3478
License :
Date printed : 25-Aug-1999
Date created : 7-Ju1-1999
Last'revised : 7-Ju1-1999
REPORT
Field is centred on n60 50 4.803,w151 36 18.018
Structure is centred on n60 50 4.803,w151 36 18.018
Slot location is n60 49 54.642,wi51 36 5.788
Slot Grid coordinates are N 2499467.742. E 214221.561
Slot local coordinates are 1031.82 S 606.28 E
Projection type' alaska - Zone 4. Spheroid: Clarke - 1866
Reference North is True North
Report is limited to clearances less than 200 feet
DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4*
Object wel 1 path
PMSS <10845-12508>.,G-15Rd~l.GRAYLZNG Platform
PMSS <12376-15114>.,G-15Rd~2,GRAYLZNG Platform
GMS <O-11160'>,,G-21Rd,GRAYLING Platform
PMSS <7938-10750>,,G-21Rd,GRAYLING Platform
PMSS <7261-10650>,0G-5Rd,GRAYLING Platform
GMS <0-11335'>,,G-22,GRAYLING Platform
PGMS? <0-11317'>,,G-40,GRAYLING Platform
MSS <0-12736'>,,G-31,GRAYLING Platform
MSS <630-11451'>,,G-30,GRAYLtNG Platform
GMS <O-12425'>,,G-28,GRAYLING Platform
GMS <O-12366'>,,G-25,GRAYLING Platform
GMS <0-9600'>,,G-6,GRAYLING Platform
PGMS <lO0-11000'>,,G-6Rd,GRAYLING Platform
GMS <0-13800'>,,G-12Rd2,GRAYLING Platform
MSS <10250-13748'>,~G~12.GRAYLING Platform
MSS <10250-13700'>.,G-12Rd.GRAYLING Platform
PMSS <1395.12743'>,,G-14A Rd. GRAYLING Platform
· . MSS <0-10790'>,,G-33,GRAYLING Platform
GMS <O-10268'>,,G-B4Rd,GI~YLING Platform
MSS <2284-11655'>,,G-34,GRAYLING Platform
PGMS <11100-13380'>,,G-36DPN.GRAYLING Platform
PMSS <11830-12¢53'>.,G-36,GRAYLING Platform
GMS <0.12948'>.,G-27,GRAYLING Platform
GMS <0-10642'>,,G-20,GRAYLING Platform
Closest approach with 3-D Minimum Distance method
Distance M.D. Diverging from M.D.
Last revised
4-Aug-1998 3521.2 1736.4
27-Aug-1998 352!.2 1736.4
lC-May-1998 2769.5 4300.0
t-Jun-1998 2769.5 4300.0
10-Ju1-1998 3508.5 2181.8
30-Ju1-1996 3130.2 2265.7
22-Jun-1998 3385.4 2540.0
30-Dec-1997 2366.5 6395.9
30-Ju1-1996 2798.8 4100.0
30-Ju1-1996 3305.6 2216.4
30-Ju1-1996 3261.3 6395.9
30-Ju1-1996 2224.8 5020.0
30-Ju1-1996 2224.8 5020.0
30-Ju1-1996 1182.5 3140.0
30-Ju1-1996 1182.5 3140.0
30-Ju1-1996 1182.5 3140.0
30-Ju1-1996 1802.0 4120.0
30-Ju1-1996 3280.9 2520.0
30-Ju1-1996 3270.8 2580.0
30-Ju1-1996 3206.6 2800.0
30-Ju1-1996 1901.4 3400.0
30-Ju1-1996 1901.4 3400.0
2172.7
2172.7
4300.0
4300.0
2181.8
2265.7
2540.0
6395.9
4100.0
2216 4
6395 9
5020 0
5020 0
3140 0
3140 0
3140 0
4120 0
2520 0
2580.0
2800,0
3400.0
3400.0
30-Ju1-1996 3357.5 2100.0
30-Ju1-1996 2909.9 4820.0
RECEIVED
2100.
4820.
1999
~ A~aska 0il & Gas Cons. Cornmission
Anchorage
L~,~ <U-IU~UU'>..G-2¢.GRAYLi:NG Platform
GMS <0711544' >.. G- 26. GRAYL[,NF-~] atform
MSS <10070-10975'>..G-iO.GRAY~ Platform
PGMS <0-10700'>..G-2Rd,GRAYLI~ Platform
MSS <9120-11278' >,, G- 3Rd, GRAY[liNG P1 atform
GMS <0-8800' (11050)>, .G-3,GRAYLING Platform
GMS <100-11050 '>.. G- 3Rd2, Gtb~YLING P]atform
GMS <0-13661' >.. G- 16. GRAYLING P1 atform
MSS <0-12291 '>, ,G- 19 ,GRAYLING P1 atform
MSS <0- t2007'>, .G- 13 ,GRAYLING P1 atform
PGMS <0-10100'>. ,G-7.GRAYLING Platform
GMS <0-9000'>, ,G-4,GRAYLING Platform
GMS <1400-10400'>, .G-4Rd,GRAYLING P1 atform
MSS <0-15330' >,, G- 9. GRAYLING P1 atform
GMS <0- 8860 '>,, G- 18Rd, GRAYLING P1 atform
MSS <0-16342'>. ,G- 14.GRAYLING P1 atform
MSS <7709-12175' >,, G- 8, GRAYLING P1 atform
GMS <0-11750 '>,. G- 8Rdo GRAYLING P1 atform
MSS <0-11570' >,, G- 32, GRAYLING P1 atform
GMS <0-10115 '>,. G- 11, GRAYLING P1 atform
PGMS <0-11430 '>, .G- 1Rd,GRAYLiNG P1 atform
MSS <8491-11420' >,, G- 1, GRAYLING P1 atform
GMS <0-11742'>,. G- 23Rd, GRAYLING P1 atform
GMS <0- 12075 '>,, G- 23. GRAYLING P1 atform
GMS <0-11900 '>,. G- 17Rd, GRAYLING P1 atform
MSS <3991-15095'>, ,G- 17,GRAYL;NG Platform
PGMS <9300-14384' >OLD,, K- 24, KING SALMON P1 atfo
Steering Tool,, K- 24, KING SALMON P1 atform
K-SRd #2 <6905-11570>, ,K-SRd,KING SALMON Platf
K-SRd #1 <6905-14264>., K-SRd, KING SALMON PI atf
Surface <375-???>, ,K-8,KING SAI HON Platform
Conductor <GSS O- 375>., K- 8, KING SALMON P1 atfor
PGMS <2600-14548' >OLD,, K- 8Rd, KING SAGMON P1 atf
MSS <2622-13927'>0LD, ,K-8,KING SALMON P1 atform
PGMS <0-2500'> NEW, ,K-SRd,KING SALMON Platform
GSS <492- 855' >,, K- 26, KING SAGWON P1 atform
PMSS <981-10956'>, ,K-26,KING SALMON Platform'
EMS <8955 - 11078'>, .K-26Rd. KING SALMON Platfo
PGMS <0-13771' >,, K- 19, KING SALMON P1 atform
GMS <0-12822 '>,. K- ZORd, KING SALMON P1 atform
GMS <8900-13463 '>,, K- I0, KING SALMON P1 atform
GMS <0-13413 '>,, K- 3Rd, KING SALMON P1 atform
GMS <2600-11767'>. ,K-3,KING SALMON P1 atform
MSS <9725-13224'>,, K- 1, KING SA~ MON P1 atform
MSS <2380-12570 '>,, K- 1Rd. KING SALMON P1 atform
GMS <0-2300'>, ,K-1Rd,KING SALMON P1 atform
MSS <10249-14700 '>,, K- 7. KING SALMON P1 atform
GMS <0-10150'>..K-7,KING SALMON Platform
GMS <Z0125-13990 '>.. K- 7Rd, KING SALMON P1 atform
GMS O- 11288 '>,. K- 2, KING SALMON P1 atform
GMS <2403-12915' >,, K- 2Rd, KING SALMON P1 atform
GMS <0-12173'>, ,K-Z3Rd,KING SALMON Platform
MSS <5142-14016 '>., K- 13. KING SALMON P1 atform
MSS <2450-11094 '>,, K° 11, KING SALMON P1 atform
GMS <0,2800'>, ,K-4,KZNG SALMON Platform
MSS <2910-!1772'>, ,K-4,K!NG SALMON Platform
MSS <10683-11439 '>,. K-4Rd, KING SALMON P1 atform
GMS <0-12200 '>,, K- 15Rd. KING SALMON P1 atform
MSS <10836-12447'>,. K- 15, KING SALMON P1 atform
MSS <5028- 8580' >,, K- 20. KING SALMON P1 atform
GMS <0-14700'>, .K-23.KING SALMON Platform
PGMS <0-12120'>, ,K-Z7,KING SALMON Platform
GMS<O-2100'>, ,K-3ORd,KING SALMON Platform
MSS <2170-12600 '>,, K- 30Rd. KING SALMON P1 atform
MSS <11494-13196 '>., K- 30, KING SALMON P1 atform
MSS <5747-10904' >,, K- 22, KING SALMON P1 atform
PGMS <0-10400 '>,, K- 22Rd, KING SALMON P1 ~tform
PGMS <0-11400 '>,, K- 12Rd, KING SALMON P1 atform
GMS <2500-11240'>, ,K-12,KING SALMON P1 atform
GMS <0-13370 '>,, K- 5, KING SALMON P1 atform
PGMS <0-12130'>.,K-IS,KING SALMON Platform
GMS <0-12900'>, ,K-21,KING SALMON P1 atform
GMS <10600-12540'>. ,K-21Rd. KING SALMON Platfor
GMS <0-12156'>,,K- 9, KING SALMON P1 atform
MSS <2063-10825'>,, K- 16, KING SALMON P1 atform
PO~2 ~0- I~225 '~,, K- 25, KING SALMON P1 atform
PGMS <0-13296'>,. K- 6Rd, KING SALMON P1 atform
MSS <2180-11319'>,,K-6Rd,KING SALMON Platform
GMS <9600-13300 '>.. D- 7. DOLLY VARDEN Platform
GMS <0-12900 '>., D- 7Rd. DOLLY VARDEN P1 atform
30- Jul- 1996
30- Jul- 1996
30- Jul- 1996
30- Jul- 1996
30- Jul- 1996
30-Jul -1996
30- Jul- i996
30-Jul -1996
30- Jul- I996
30-Jul -1996
30- Jul- 1996
30-Jul -1996
30-Jul -1996
30-Jul -1996
30-Jul -1996
30-Jul -1996
30-Jul- 1996
30-Jul -1996
30-Jul -1996
30- Jul- 1996
30-Jul -1996
30- Jul - 1996
30- Jul- 1996
30-Jul -1996
30- Jul- 1996
30-Jul -i996
29-Jul -1996
11- Ma r- 1999
18- Jun- 1998
18- Jun- 1998
16- Jun- 1998
16- Jun- I998
29- Jul- 1996
29-Jul -1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
9-Apr- 1998
29- Jul- 1996
29-Jut -1996
29- Jul- 1996
29- Jul - 1996
29- Jul- 1996
29- Jul- 1996
29-Jul -1996
29- Jul - 1996
29- Jul - 1996
29- Jul - 1996
29-Jul -1996
29-Jul -1996
29- Jul - 1996
29-Jul -1996
29- Jul- 1996
29-Jul - 1996
29- Jul- 1996
29- Jul- 1996
29-Jul -1996
29- Jul- 1996
29- Jul - 1996
29- Jul- 1996
29- Jul- 1996
29-Jul -1996
29- Jul- ~996
29-Jul -1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29-Jul -1996
29- Jul- 1996
29- Jul- 1996
30-Dec-1997
30-Dec- 1997
29-Jul ~ 1996
29-Jul -1996
29- Jul- 1996
29-~ul- 1996
29- Jul- 1996
29-Jul- 1996
29- Jul- 1996
2913.5
2468 1
3381 7
2972 5
2905 6
2905 6
2905 6
1065 7
3361 7
3489 5
3358 0
3205 6
3205 7
782 5
935 5
494 6
1780 8
1780 8
3316 1
3057 1
2326 5
2326 5
2371 7
2371 7
3536 7
3536 7~
4289 7
5213 7
9708 0
9708 0
82!1 0
10615 5
9223 2
8161 1
9583 4
10439 1
10380 8
1038O 8
9695 6
9985 5
9985 5
9090 2
9117 0
9962 4
9962 4
10088 4
7738 7
7738 7
7738 7
7925 0
6799 3
9581 0
9650 7
8907 1
9362 1
6624 1
6624 1
8021 5
8021 5
3199 4
7021.7
6780.6
9549.0
6025.6
6025.6
10226.5
10226.5
10127.6
10074.7
6498.6
9872.6
5101.7
5101.7
5829.3
9844.9
4701.0
9371.8
10177.3
7252.5
7252.5
3180
3000
2200
28~0
2860
2860
2860
6395
2420
1872
2480
3920
3920
6395
6395
5820
3760
3760
2620
2440
5940
5940
3100
3100
1581
I581
6395
6395
6395
6395
6395
6395
6395
6395
6395
6395 9
5395 9
6395 9
6395 9
6395 9
6395 9
6395 9
6395 9
6395 9
6395 9
6395 9
6395 9
6395 9
6395 9
6395 9
6395 9
6395 9
6395 9
6395 9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395,9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395,9
6395.9
6395.9
1936.4
1936.4
.0
.0
.0
.9
.0
.7
.0
.0
.0
.9
.9
.0
.0
.0
.0
.0
.0
.0
.0
.0
.8
8
9
9
9
9
9
.9
g
9
9
3180.0
3000.0
2200..0_-
2840.0
2860.0
2860.0
2860.0
6395.9
2500.0
1945.5
4080.0
3920.0
3920.0
6395.9
6395.9
5820.0
3760.0
3760.0
2620.0
2440.0
5940.0
5940.0
3100.0
3100.0
1781.8
1781.8
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395,9
6395.9
6395.9
6395,9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395,9
6395,9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395,9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
6395.9
1936.4
1936,4
PMSS <12052 - 12438'>..D-TRd~.~LLY VA~DE,~ P]
GMS <0-14600' >,, O- 16, OOLLY VAROF~-~'l atform
PGWS <10000-14645' >,, D- 16Rd, DOLLY DEN P1 atf
GMS <0-13585 '>,, D- 24A, OOLLY VARDE_N P1 atform
MSS <2450-10125 '>., D- 31, DOLLY VARDEN P1 atform
GMS <0-10628 '>,, D- 31Rd, DOLLY VARDEN P1 atform
GMS <0-11356'>,, D- 2ARd, DOLLY VARDEN P1 atform
MSS <6927-12557'>,. D- 2, DOLLY VARDEN P1 atform
MSS <9482-12425' >,, D- 2Rd. DOLLY VARDEN P1 atform
MSS <11209-14850 '>,, D- 22. DOLLY VARDEN P1 atform
MSS <!205-10506 '>,. D- 20, DOLLY VARDEN P1 atform
MSS <7866-12700 '>,, D- 14, DOLLY VARDEN P1 atform
GMS <0-13600 '>,, D- 14Rd, DOLLY VARDEN P1 atform
PGMS <0-13700 '>,, D- 6Rd, DOLLY VARDEN P1 atform
MSS <6662-12195 '>,, D- 6, DOLLY VARDEN P1 atform
MSS <11790-15510 '>,, D- 6St, DOLLY VARDEN P1 atfor
MSS <8722-13932'>, .D-8,DOLLY VARDEN Platform
PGMS <700-12250' >,, D-8Rd, DOLLY VARDEN P1 atform
PGMS <0-13111' >, oD- 29Rd, DOLLY VARDEN P1 atform
GMS <100-13050' >,, D-29, DOLLY VARDEN P1 atform
PGMS <0-11150 '>,. D-43, DOLLY VARDEN P1 atform
GMS <0-11510 '>,, D- 25Rd, DOLLY VARDEN P1 atform
MSS <8330-11350 '>,, D- 25, DOLLY VARDEN P1 atform
GMS <0-11600' >,, D- 41. DOLLY VARDEN P1 atform
GMS <6100-12573'>, ,D-40,DOLLY VARDEN P1 atform
PGMS <0-12520' >,, D-4ORd, DOLLY VARDEN P1 atform
MSS '<2506-11160 '>,, D- 32, DOLLY VARDEN P1 atform
GMS <0-12445'>, .D-28,DOLLY VAR]DEN Platform
GMS <0-11000'>, ,D-27,DOLLY VARDEN PlatfoFm
PGMS <0-10300' >,, D- 45, DOLLY VARDEN P1 atform
MSS <2727-11000'>,, D- 13,DOLLY VARDEN P1 atform
PGMS <6600-10920' >,, D- 3Rd2, DOLLY VAR[DEN P1 atfo
PGMS <8700-11100' >,, D- 3Rd, DOLLY VARDEN P1 atfor
GMS <0-10881' >,, D- 3, DOLLY VARDEN P1 atform
PGMS <2100-10225'>, ,D- 15Rd2,DOLLY VARDEN P1 atf
GMS <0-10935' >,, D- 15Rd, DOLLY VARDEN P1 atform
MSS <2642-10250 '>., D- 5, DOLLY VARDEN P1 atform
GMS <0-10650 '>,, D- 5Rd, DOLLY VARDEN P1 atform
MSS <6059-16650' >,, D- 19St, DOLLY VARDEN P1 atfor
MSS <2944- 7950' >., D- 19, DOLLY VARDEN P1 atform
PGMS <0-12345' >,, D-46, DOLLY VARDEN P1 atform
GMS <5600-10700 '>,. D- 9. DOLLY VARDEN P1 atform
PGMS <0-10900 '>., D- 9Rd, DOLLY VARDEN P1 atform
MSS <2701-11682'>., D- 11. DOLLY VARDEN P1 atform
MSS <10665-11808'>,, D- 17, DOLLY VARDEN P1 atform
GMS <0-10800 '>., D- 17Rd, DOLLY VARDEN P1 atform
MSS <0-12071' >., D- 1, DOLLY VAR[DEN P1 atform
MSS <10156-13600 '>,, D- 30, DOLLY VARDEN P1 atform
GMS <0-i2237'>, ,D-3ORd,DOLLY VARDEN Platform
MSS <2220-8175'>, ,D-18.DOLLY VARDEN Platform
GMS <0-11100 '>,, D- 4, DOLLY VARDEN P1 atform
PGMS <8000-12100' >,, D- 4Rd, DOLLY VAJqDEN P1 atfor
MSS <2730-13462'>, ,D-24,DOLLY VARDEN Platform
GMS <0-11180'>, ,D-34,DOLLY VARDEN Platform
PGMS <0-10450 '>,. D- 42, DOLLY VARDEN P1 atform
MSS <3550-16606' >., D- 23, DOLLY VARDEN P1 atform
MSS <3550-17010'>, ,D-21,DOLLY VARDEN Platform
PGMS <O-12970'>,,D-44.DOLLY VARDEN Platform
MSS <10913-11930 '>,, D- 47, DOLLY VARDEN P1 atform
PMSS <10743-10834>,. D- 26Rdl, DOLLY VARDEN P1 atf
GMS <0-111905 '>,, D- 25, DOLLY VAROEN P1 atform
PMSS <10743 - 11500'>, ,D-26Rd2,[DOLLY VARDEN P1
GMS <0-12050 '>,, D- 12Rd, DOLLY VARDEN P1 atform
MSS <9453-12381' >,, D- 12, DOLLY VARDEN P1 atform
MSS <2742-13908' >,, D- 10, DOLLY VARDEN P1 atform
PGMS <0-10873 '>,. D-48. DOLLY VARDEN P1 atform
GMS <800- 2700' >,. D- 10, DOLLY VARDEN P1 atform
PMSS <10247-10355 '>,, M-31, STEELHEAD P1 atform
PMSS <10741-12018'>, ,M-31St#Z.STEELHEAD Platfo
MSS <1103- 2265' >,, M- 26, STEELHEAD P1 atform
PGMS <0-12930 '>,, M- 28, STEELHEAD P1 atform
PGMS <12486-15276' >,, M- 27, STEELHEAD P1 atform
PGMS <2700-9101'>,,M-14,STEELHEAD Platform
PMSS <1006- 7952 '>., M- 15 St, STEELHEAD P1 atform
PHS§ <1006 - 1449' >., M- lS. STEELHEAD Platform
MSS <0-735'>, .OB #2,STEELHEAD Platform
PGMS <0- 857' >,, B1-8. STEELHEAD P1 atform
PGMS <0- 785 '>,, B1- 6, STEELHEAD P1 atform
PGMS <0- 7434' >,, M- 13. STEELHEAD P1 atform
PGHS <500-928'>, .B1-2.STEELHEAD Platform
29-Jul- 1996
29- Jul- !996
29- Jul- 1996
29-Jul- 1996
29- Jul- 1996
29- Jul- i996
29- Jul- 1996
29-Jul- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29-Jul -]1996
29-Jul -1996
29- Jul- 1996
29- Jul- 1996
29-Jul -1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29-Jul- 1996
29- Jul- 1996
29-Jul -1996
29- Jul- !996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- I996
29- Jul- 1996
29-Jul -1996
29- Jul- 1996
29- Jul- I996
29- Jul- 1996
29- Jul- 1996
29-Jul -1996
29- Jut- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- I996
29- Jul- 1996
29-Jul -1996
29- Jul - 1996
29- Jul - 1996
29-Jul -1996
29- Jul- 1996
29- Jul - 1996
29-Jul -1996
29- Jul- 1996
29-Jul- 1996
29- Jul- 1996
29-Jul - 19.96
1- Sep- 1998
2!-Aug- 1998
1-Sep- 1998
29-Jul - 1996
29- Jul- 1996
29-Jul -1996
29- Jul- 1996
29-Jul -1996
29-Jul - 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29-Jul -1996
29-2ul -1996
29-Jul- 1996
29- Jul- lg96
29-Jul -1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
29- Jul- 1996
801i i
t0591 8
10591 8
8830 5
9549 7
8732 5
9200 9
9196.8
9196.8
10591.2
10054.2
10579.9
10579.9
10325.8
10325.8
10825.8
10595.9
10595.9
7691.6
7691.6
9982.7
10438.0
10438.0
9002.2
9225.5
9081,4'-
8487.0
8416.9
9371.5
10499.8
10559.9
9152.4
9152.4
9152,4
10548.2
10486.6
10573.9
10412.7
7867.0
7951.1
10389.5
10556.9
10556.9
9539.4
10091.4
10091.4
8505 1
7544 6
7544 6
5734 2
9661 1
9661 1
9207 6
9955 8
7699 9
10575 4
10568 6
9390 4
8774 2
8649 6
8649.6
8649.6
10574.5
10574.5
9493.1
9869.0
10132.3
165.1
165,1
123.9
93,8
74.0
242.6
353.7
362.4
858,1
573.7
641.3
349.1
494.0
3600
1421
1421
1518
1518
1790
1627 3
1663 6
1663 6
1421 0
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
1854.5
1854.5
1473.7
1421.0
1421.0
1690.9
1618.2
1745.5
1763.6
1918.2
1790.9
1421.0
1421.0
1518.2
1518.2
1518,2
1421.0
1421.0
1421.0
1473.7
1745.5
1727.3
1421.0
1421.0
!421.0
1563 6
i421 0
1421 0
1881 8
2009 1
2009 1
1772.7
1438.5
1438.6
1600.0
142!. 0
2063,6
1421.0
1421.0
1627,3
1772.7
1827.3
1827.3
1827.3
1421.0
1421.0
1429.8
1681.8
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
142!. 0
.0
3600.0
1690.9
1690.9- -
I518.2
1518.2
1790.9
2249.2
4220.0
1663.6
1421.0
1421.0
1421.0
142!,0
I421.0
1421.0
1421.0
1500.0
1500,0
2920.0
1854.5
1473.7
1421.0
1421.0
1690.9
1672.7
i745.5
1763.6
1918.2
1790.9
142!.0
I421.0
1554.5
1554.5
1554.5
1421.0
142!. 0
1421.0
1473.7
1745,5
1727.3
1421.0
I42!.0
1421.0
1563.6
1421.0
1421.0
1881.8
2009.1
2009.1
1772.7
1438.6
1438.6
1600.0
1421,0
2063.6
1421.0
2216.4
1627.3
1772.7
1827,3
1827.3
2300.0
1421.0
1421.0
1447.3
1681.8
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
1421.0
1421 0
1421 0
1421 0
1421 0
1421 0
142! 0
P~S <0-5600'>..,W-5.STEEUqF~]O Platform 29-Ju1-1996 135.8 1421.0
PMSS <6595-6988'>. ,M-1,STEEL'~-~ Platform 29-Ju1-1996 18.6 1421.
PG~S <0- 7250 '>,. H- ISt#l, STEE~ ,~O P1 atform 29-Jul- 1996 18.6 1421.,
PGhiS <0.7419'>, .M-2,STEEUqEAD Platform 29-Ju1-1996 257.0 !421 O-
PGMS <0-7250'>,,M-3,STEELJqEAD Platform 29-Ju1-1996 155.7 1421 0--'
PGMS <0-5185'>, ,M-Zg,STEELHEAD Platform 29-Ju1-1996 227.4 1421 0
PMSS <1334-3625>,.M-16,STEE)HEAD Platform 29-Sep-1997 193.4 1421 0
GSS <975-2660'>, ,M-29,STEELHEAD Platform 29-Ju1-1996 166.7 142! 0
PGMS <0-10938'>, .M-29.STEELHEAD Platform !O-Feb-I998 169.2 142I 0
PMSS <808-1165'>, ,RLF #2,STEE~EAD Platform 29-Ju1-1996 530.0 1421 0
P~tS <0-2310'>, ,RLF #Z,STEELHEAO Platform 29-Ju1-1996 191.0 I790 9
MSS <1363-1859'>, ,RLF #2,STEEL~HEAD Platform 29-Ju1-1996 I00.8 15i8 2
PG~IS <0-14575'>, ,M-30,STEELJqF~AD Platform 29-,lu1-1996 146.7 142! 0
PMSS <1535-4500'>, ,M-9,STEE~F~AD Platform 26-Aug-1996 82.4 1421 0
PMSS <8988 - 12583'>,,M32St#2.STEELHEAD Pla;fo 29-Ju1-1996 145.6 1421 0
P~tSS <12281 - 12660'>, ,M32St#3,STEELHEAD Platf IO-Feb-1998 145.6 I42! 0
~ P1 145.6 1421 0
PMSS <1386 - 9833'>, ,M-32,ST~:LHEAD atform 29-Ju1-1996
PGMS <0-927'>, Bi-IO,STEELHEA Platform 29-Ju1-I996 500 1 1421.0
PMSS <9365 - 10588'>,,M32ST#Z,STEELHEAD Platfo 29-Ju1-1996 145.6 1421.0
PGMS <3700.11700'>. ,M-25,STEELHEAD Platform 29-Ju1-1996 i39.7 1421.0
PGMS <0.6440'> ,M.7,STE~U~EAD Platform 29-Ju1-1996 119.9 I421 0
GSS <0-1421'>, ,*M-4*,STEELHEAD Platform 29-Ju1-i996 0.0 1421.0
I421,0
i421.Q
1421.~
1421 0
1421 0
i421 0
1421 0
1421 0
1421 0
1421 0
1790 9
1518 2
1421 0
1421 0
1421 0
1421 0
1421 0
I421 O
i421 0
1421 0
2380 0
1421 0
Project Summary
Well M-4
Depth
3900'
6400'
TVD Mud
. .:. S'ystern
........
. .
. :~Est:.'i. - .: N/A
'' !';ii':' ':'" ~ '; ';::i : : - . :-.:-
..... : .
Est..
3029': Gel/Gelex
:
....
......
..........
Est .....
4477'" PHPA
Mud
Weight
9~.0 - 9.5
9:2 - 9.8
Cumulative
Mud Cost
5;13.500
$40,500
./fey Issue/Vo. !
Hole Cleaning
Kev ISsue .No. '2
Lost Circulatio.
· Maintain sufficient viscosity to clean wellbore of gavels.
Sweep hole as needed to avoid cuttings buildup
Maintain an adequate stock of lost circulation products at the
rigsite. Spot a LCM pill on bottom prior to running the 9-
5/8" casing
Key ISsue
Sloughing Coal
Key Issue No. 4
Drill Solids'
· Maintain 2 ppb initial concentration of Soltex in production
interval'fluid. Increase concentration to 3 - 4 ppb if coal
slou~hing becomes a problem.
· Run as fine a mesh shaker screen as possible. Run centfifi~ge
during trips to reduce dr/il solids in mud. Maintain adequate
concentration of Polyplus RD in the production interval mud.
....... ~- .... iiii ii mllllllll i
M-I Drilling Fluid5 L.L.C.
721 West First Avenue
Anchorage, Alaska 99501
(907) 274-5564
(907) 2794729 Fax
I I iiii II III iii I Iiiiiiiii iii iiiii i i ii i ii iii i I
rl~~ DRILLING
FLUIDS
...
Interval Summary ( 21/4"
hole)
Well M-4
iiii Driiliing Fluid; system;:
Gel / Gelex
Gel / Gelex / Soda Ash / Caustic Soda / Mf Bar / Polypac UL
Shale Shakers / Desander / Desilter / Centrifuge
Hole cleaning, lost circulation, coal slouch-ting,
i il i'nte ai:Driili:ng 'Fl:Ui:d'proPeAies: :. :
ii.:: ::!iDePth :i!::;: MUd' :: ' Plastic ::.Yield 'i: APl: ::.' Total
.................. . .
;ii.l/t/eight: ViScosity:· :point :: FlUid L°ss pH Solids
(PPg): i (cp) (tbllooft~)i (mll3Omin): . (%)
1457' 8.6 - 9.0 10 - 12 30 - 40 N/C 9.0 - 9.5 < 5%
2000 - 3000' 9.0 - 9.2 12 - 15 20 - 30 10- 12 9.0 - 9.5 +/- 5%
3900' 9.2 - 9.5 I5 - 18 15 - 20 8 - 10 9.0 - 9.5 5 - 8 %
· Pre-treat makeup water with soda ash, build spud mud with 20 - 25 ppb ~v[[ Gel, gelex as
needed for increased viscosity.
· Initial volume of fluid should be +/- 700 bbls.
· Begin drilling, maintain viscosity for adequate hole cleaning, run all solids equipment to maintain
low mud weight. Build additional volume as needed
· Reduce fluid loss with Polypac UL additions as.needed. Lower fluid loss to 6 - 10 cc's prior to
running surface casing.
· Spot a LCM pill on bottom prior to running 9 5/8" casing (25- 50 bbl pill w/15 ppb Plug & 15
ppb Kwikseal) if formation losses are seen.
· After cementing casing, treat any cement returns (and contaminated mud) ~vith Borax and Bi~
carb prior to disposal.
· Dump and clean surface pits prior to next interval.
721 West First Avenue ~ DEILLING
Anchorage, Alaska 99501
(907) 274-5564 FLUID5
(907) 279-6729 Fax
Interval Summary (8 hole)
Well M-4
!i:' ~-:::~:.':.i:i:..:Key prOdUctS'
..... -:: . ...... -.- .:.: : .....-:::--
: ..........:.: ....
-. : :-::---::-. .... -..::: .... -...-::: : .
:'~:~'~:'~: ::~"'" ': SOli'dsilControt:
. . : ........ . .....
.......
...... .
......
.:.: :.. ..:. ...... .
.....
.-: - Potential: p:roblems~
......... . :...::-
...........
.................. :.:: :.-.: . : : .
..........
Ho-Vis / Barite / Soltex / Caustic Soda / Polypac LTL / Polyplus RD
Shale Shakers / Desilter / DCentrifuge
Coal sloughing, drill solids buildup, lost circulation
; nterval Drilling 'Fldid pr Pertie
Depth!. i~iiMud:::~ Plastic : ! Yield: ! :: AP! ' Total
......
: :i !!nterval!i::.. i .:::::::.iWeight..: Viscosity ~; P0i:.nt: i Fluid Loss 3RPIVl Solids.
i : i: (ft)i!i ',i i:(:PPg:) (cp) ' (iblliO0f¢)i i(ml/30min) Reading: (%) ,
.....
3900 - 5000' 9.0 - 9.2 8 - 15 18 - 22 8 - 10 6 -- 8 +/- 5%
5000 - 6400 9.2 - 9.4 8 - 15 18 - 22 6 - 8 8 - 10 +/- 5%
· Isolate one pit of surface mud for drilling out cement. Pretreat with Bicarb as needed.
· Clean other pits and build production interval mud - estimated initial volume - 700 bbls.
· Build mud system with the following, 5 ppb Gel, 1 ppb Polypac UL, 2 ppb Soltex, 1 ppb Poly-
plus RD. Adjust pH to 9.0- 9.5 w/Caustic Soda. Adjust 3 RPM reading to +/- 8 w/Flo~-is.
· If coal becomes a problem, increase Soltex concentration to 3 - 4 ppb.
· Maintain 3/4 to 1 ppb Polyplus RD to inhibit clay swelling.
· Keep drill solids to a minimum by aggressive use of all solids control equipment and water addi-
tions.
· Reduce fluid loss to +/- 6 cc's AP1 prior to, vrunning 7" casing.
· Sweep hole as need to insure adequate hole cleaning.
· Run and cement liner, clean pits, displace well to 3% KCL completion fluid.
M-I Drilling Fluids L.L.C.
721 West First Avenue
Anchorage, Alaska 99501
(907) 274-5564
(907) 2794729 Fax
IIII I I I I I II I II I IIIIIII I II I I I I I I III I
DRILLING
FLUIB5
! f
UNOCAL
Steelhead M-4
Depth vs. Time Summary
1,000
2,000
3,000
a~4,000
5,000
6,000
7,000
, . AFE
-.....Actual~
'Optimum
, ,,
-I
I
0 5 10 15 20 25
Time (Days)
Drilling AFE Cost Est from M-4 slot.xls 8/23/99/10:07 AM
is 3/4' 5000p~i
TYPE GK ~NNULA~
L
lO,O00psi iL
GATE VALVE [i I GATE VALVE 'HCR V~
P2E R~ [O,O00psi
~ i S~G~CA~
16 3/4' 5000psi RISER
B~LL VALVE
RECEJVEI)
~£P ,aa t~I}5
Anchorage
STEELHEAD PLATFORM
8/9
~/ /~ SUCTION P~ ~ l
A A A A
~ ~ts c~. ~ ~ c~.
- o.~ ~ o.~ ~
, ,
0 0 0 0
........................
A
AGITATOR
: J LiUD GUN
..
STEELI~AD PLATFORM
PIT LAYOUT
' 7
; .
,,
·.,
VERIFICATION OF APPLICATION FOR SPACING EXCEPTION
COOK INLET, ALASKA
ADL # 18730
Well: Trading Bay Unit, Well M-4
I, SHANNON W. MARTIN, Land/Legal Analyst, Union Oil Company of California, do
hereby verify the following:
I am acquainted with the application submitted for the drilling of the
Trading Bay Unit, Well M-4.
I have reviewed the application submitted for the exception to 20 AAC
25.055 (a)(4) (statewide spacing) and all facts therein are true.
I have reviewed the plat attached to said application, and it correctly
portrays pertinent and required data.
DATED at Anchorage, Alaska this 21 st day of September 1~}99.
~on ~r~ff'M-artin
Land/Legal Analyst
STATE OF ALASKA
THIRD JUDICIAL DISTRICT
)
) ss
)
SUBSCRIBED TO AND SWORN before me this 21 st day of September 1999.
THE STATE OF ALASKA
My Commission expires' /Z,. {.)~
UNOCAL~
KING
2O
ADL-17594
Unocal
Forcenergy
Tra d~ g
Bay Uni[
Boundary
ADL-18772
Unocal
21
29
GRAYLING /
STEELHEAD I
28
32
33
T9N - R13W
ADL-18729 TSN-- R13W
ADL-18730
Unocal
Forcenergy
0 1,000 2,000 5,000
~ I I
SCALE IN FEET
ADL-1
Unocal J Unocal
Forcenergy
McArthur River Field
Steelhead Platform
M-4 Well Proposal
D-I Sand Penetrations
KING i
ADL-17594
Unocal
Marathon
Trading
Bay Unit
Boundary
ADL-18772
Unocal
GRAYLING
STEE
ADL-~8?30
Unocal
j Marathon
33
T9N - R13W
34
SCALE IN FEET
M??th°n J
Unocal
103z54a 07-SE1:'-9~ 2003574
D~E ......INVoI,CF--JCRED!T,MEMO NO.. voucHER NOi GROSS ....
03-SEP99 DRI'r,T, PERNITM4 09993000_1_44 100 . O0 100 . O0
!
FORM 4-2B181
(REV.
11-95)
PRINTED
IN U.S.A.
]TOTAL ~- 100 O0 1OO O0
CITIBANK DELAWARE 62-20
A Subsidiary of Citicorp 31i
ONE PENN'S.WAY
NEW CASTLE, DE 19720
Union Oil Company of California
Accounts Payable Field Disbursing
UNOCAL
Pay One Hundred Dollars And O0 ************************************
2003574
bthe
o~erSTATE OF ALASKA
of ALASKA OIL & GAS CONSERVATION
COMMISSION
3001 PORCUPINE DR
ANCHORAGE, AK 99501
Date Check Amount
V 07-SEP-99 *****100.00
Void after six months from above date.
ALASKA OIL AND GAS
· CONSERVATION COMMISSION
WALTER J. HICKEL, GOVERNOR
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
TELECOPY: (907) 276-7542
August 19, 1994
Kevin Tabler, Land Manager
UNOCAL
P O Box 196247
Anchorage, AK 99519-6247
Re:
Suspended Wells
Compliance with regulations
Dear Mr. Tablet:
UNOCAL has 15 suspended wells as shown on the attached list: ALASKA
SUSPENDED WELLS AS OF AUGUST 1994.
The applicable regulation is as follows:
20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator
under 20 AAC 25.105(e), the commission will, in its discretion,
approve the suspension of a well if the well
(1) encounters hydrocarbons of sufficient quality and
quantity to indicate the well is capable of producing in
paying quantities as reasonably demonstrated by well tests
or interpretive formation evaluation data; or
(2) is reasonably demonstrated to have future value as a
service well.
For each well on the attached list of suspended wells, please provide
data showing that the well meets the criteria of (1) or (2) above or
advise as to your plans to abandon the well.
Wells 'that meet the criteria of (a) above that you wish to maintain
as suspended, as required by 20 AAC 25.110(e), must have well site
inspections as appropriate this year prior to snow covering the
locations.
·
Chairman
c: Blair Wondzell
encl
bew/llunsusp
ALASI<.A SUSPElkrDED ~-ELLS
AS OF AUGUST 1994
PERMIT
API NUMBER
OPERATOR
WELL NA/~E
WELL WELL STATUS
CLASS STATUS DATE SECT TWP RNG MER
00-0146-0
61-0045-0
66-0008-0
66-0038-0
67-0007-0
67-0023-0
67-0042-0
72-0007-0
75-0008-0
77-0017-0
78-0096-0
79-0017-0
81-0022-0
90-0041-0
90-0071-0
133-10145-01
133-10144-01
283-10020-01
283-10021-00
283-20003-00
733-20018-00
733-20032-00
133-20237-00
283-20045-00
733-20300-00
733-20119-00
733-20441-01
733-20339-00
733-20302-01
733-20417-00
_
UI~/ON OIL CO
UNION OIL CO
UNION OIL CO
UI~/ON OIL CO
UNION OIL CO
%TNION OIL CO
UI~ION OIL CO
U~ION OIL CO
UI~ION OIL CO
U~ION OIL CO
U~ION OIL CO
LrNION OIL CO
U~ION OIL CO
U~ION OIL CO
UI~ION OIL CO
SWANSON RIV UNIT 14 - 15
SWANSON RIV UNIT 43-15RD
NICOLAI CK ST I -A
NICOLAI CK I31~IT 2
NICOLAI CK U~IT 3
GRANITE PT ST 18742 9
GRANITE PT ST 18742 10
SWANSON RIV UNIT 24-33
IVAN RIVER LrNIT 14-31
MGS ST 17595 16
G~ANITE PT ST 18742 31
GRANITE PT ST 18742 34
G~NITE PT ST 18742 40
TRADING BAY ST A-20R~
T~2%DING BAY LT~IT M-04
DEV SUSP 11/08/91 16 08N 009W S
DEV SUSP 8/20/91 15 08N 009W S
DEV SUSP 8/14/91 29 11N 012W S
DEV SUSP 9/18/91 29 11N 012W S
DEV SUSP 9/02/91 20 11N 012W S
D~V SUSP 9/16/89 12 10N 012W S
SER SUSP 9/29/88 31 11N 011W S
DEV SUSP 4/01/93 04 07N 009W S
D~V SUSP 8/18/75 01 13N 009W S
D~V SUSP 2/05/92 31 09N 012W S
SER SUSP 10/07/88 31 11N 011W S
DEV SUSP 9/20/91 31 11N 011W S
DEV SUSP 4/21/82 31 11N 011W S
D~V SUSP 4/23/90 04 09N 013W S
D~-~V SUSP 7/03/90 33 09N 013W S
Unoc,.l North Amer~
Oil & G~
Unoc.i C~rl~ration
P,O, Bo× 190247
Anchorage, Alaska 99519-0247
Telephone (907) 276-7600
UNOCAL?
November 06, 1992
Mr. David M. Johnston
AOGCC
3001 Porcupine Drive
Anchorage, AK 99501-3192
Dear David:
_We!~l.s M-4. and M-19.
Drilling operations on wells M-4 and M-19 on the Steelhead Platform
were stopped in 1990 after running 16" auxiliary casing in each
well. The casing shoe was not drilled out nor was the casing
perforated. A "dry-hole" Xmas tree is installed on each well.
The statu~ of the wells is checked on a routine basis by Marathon
production personnel.
The purpose of leaving the wells in this condition was to allow
expeditious replacement of an existing gas well should it quit
producing during peak winter demand months. Presetting the 16"
casing eliminates having to rig up and then remove the diverter
system, which would be required to drill a "grass roots" well.
Heavy lifts such as this require shutting in of half of the
platform's gas production for safety reasons. The need for
production shut-in is also mitigated by pre-setting the 16" casing
in these wells and thereby eliminating any concerns about collision
with other wells, collision potential is the highest in the upper
part of the hole which would also require shutting in a significant
amount of production.
Because the existing condition of these wells poses no safety
concern and the platform is already at full production Unocal, as
operator, requests permission for a suspension of these wells and
that the AOGCC waive the requirement of a surface plug per 20 AAC
25.1.110.
Yours very truly,
Regional Drilling Manager
GSa/law
Marathon
OilCompany
September 25, 1992
Alaska ,ion
Domestic Production
RO. Box 190168
Anchorage, AK 99519-0168
Telephone 907/561-5311
/,
/.
Mr. David M. Johnston
AOGCC
3001 Porcupine Drive
Anchorage, Alaska 99501-3192
DR, AFl
RE: Wells M-4 and M-19
Dear David: Ii~~'~'~'
Wells M-4 and M-19 on the Steelhead Platform were suspended in 1990 after
running 16" auxiliary casing in each well. The casing shoe was not drilled out
nor was the casing perforated. A "dry-hole" Xmas tree is installed on each well.
The status of the wells is checked on a routine basis by Marathon production
personnel.
The purpose of leaving the wells in this condition was to allow expeditious
replacement of an existing gas well should it quit producing during peak winter
demand months. Presetting the 16" casing eliminates having to rig up and then
remove the diverter system, which would be required to drill a "grass roots"
well. Heavy lifts such as this require shutting in of half of the platform's gas
production for safety reasons. Also kicking off the wells before setting 16"
eliminates collision concerns with other wells when the final section of the hole
is drilled. Collision potential is the highest in the upper part of the hole which
would also require shutting in a significant amount of production.
Because the existing condition of these wells poses no safety concern and the
platform is already at full production Unocal, as operator, requests permission
to suspend these wells and that the AOGCC waive the requirement of a surface
plug per 20 AAC 25.1.110.
Respectfully,
Gary Bush
GRW/nrw
H:\WP\DD\027
A subsidiary of USX Corporation
Marathon
Oil Company
September 24, 1992
Alaska ,ion
Domestic Production
P.O. Box 190168
Anchorage, AK 99519-0168
Telephone 907/561-5311
Mr. Gary Bush
UNOCAL
P.O. Box 196247
Anchorage, AK 99519-6247
RE: Draft Letter to AOGCC
Dear Gary:
Attached is a draft response to the AOGCC's request for action on wells M-4
and M-19 on the Steelhead Platform. I discussed this matter with Steve
McMains prior to his letter dated September 22, 1992.
Please forward our response to the AOGCC under Unocal's letterhead.
Regards,
G. R. Whitlock
Drilling Superintendent
H:\WP\DD\027
A subsidiary of USX Corporation
ALASKA OIL AND GAS
CONSERVATION COMMISSION
WALTER J. HICKEL, GOVERNOR
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
TELECOPY: (907) 276-7542
September 22, 1992
Gary Bush
Union Oil Company of California
P. O. Box 190247
Anchorage, Alaska 99519
Re:
Permit No. 90-0071
Permit No. 90-0108
Trading Bay Unit M-4
Trading Bay Unit M-19
Dear Mr. Bush:
The Commission received completion reports (form 10-407) for the above
referenced wells on September 10, 1992. Both wells were classified by
UNOCAL as suspended. Our records indicate these wells were permitted in
1990 and no subsequent reports of operations were received until those
mentioned. Since no operations were reported to us prior to the 24-
month expiration dates, the permits were recorded in our files as
expired.
According to the daily reports filed with the 10-407's, the wells were
spudded and work performed during 1990. Before moving the rig off
either well, an Application for Sundry Approvals (10-403) should have
been filed requesting a "shutdown of well operations" pursuant to 20
AAC 25.072. In addition, before a well can be classified as suspended,
the procedures and requirements of 20 AAC 25.110 must be met.
Should UNOCAL wish to suspend these well% the Commission requires
submittal of a 10-403 with information as set forth in 20 AAC 25.11~
including any request for exception to the plugging requirements. The
Commission also requests that UNOCAL provide a plan for future well
operations including a timetable for reentry and completion of these
wells.
As always, the Commission stands ready to discuss these reporting
requirements at a mutually convenient time.
David W~Jo~nst~n ~
Chairman~ ~ ~ ~
Alaska Oil and Conservation Commission
cc:
Guy Whitlock, Marathon Oil Co.
~;) prinled on recycled paper b y C, ID.
WELL PERMIT CHECKLIST
FIELD & POOL ~ ~0 ,,~...~"',~
COMPANY~_-/~~/~)/) WELL NAME ~'/'~-'( ,~--- ~ PROGRAM: exp dev ~ redrll serv wellbore seg ann. disposal para req
INIT CLASS .,/~ GEOL AREA 72_ ~ UNIT# /.2_ c~ ~ o' ON/OFF SHORE c~ %3-~?
ADMINISTRATION
1. Permit fee attached ................ ." ......
2. Lease number appropriate ...................
3. Unique well name and number ..................
4. Well located in a defined pool ..................
5. Well located proper distance from drilling unit boundary ....
6. Well located proper distance from other wells ..........
7. Sufficient acreage available in drilling unit ............
8. If deviated, is wellbore plat included ...............
9. Operator only affected party ...................
10. Operator has appropriate bond in force .............
11. Permit can be issued without conservation order ........
12. Permit can be issued without administrative approval ......
13. Can permit be approved before 15-day wait ...........
ENGINEERING
r_P R DATE
GEOLOGY
(,..R D,~TE )
ANNULAR DISPOSAL
APPR DATE
30.
31.
32.
33.
34.
14. Conductor string provided ................... ~
15. Surface casing protects all known USDWs ...........
16. CMT vol adequate to circulate on conductor & surf csg ..... _ N
17. CMT vol adequate to tie-in long string to surf csg ........ N
18. CMT will cover all known productive horizons ..........
19. Casing designs adequate for C, T, B & permafrost .......
20. Adequate tankage or reserve pit .................
21. If a re-drill, has a 10-403 for abandonment been approved...
22. Adequate wellbore separation proposed .............
23. If diverter required, does it meet regulations ..........
24. Drilling fluid program schematic & equip list adequate .....
25. BOPEs, do they meet regulation ................
26, BOPE press rating appropriate; test to ~C~k.._~ psig.
27. Choke manifold complies w/APl RP-53 (May 84) ........
28. Work will occur without operation shutdown ...........
29. Is presence of H2S gas probable .................
Permit can be issued w/o hydrogen sulfide measures ..... Y.-~NN//~! ,~
Data presented on potential overpressure zones ....... Y
Seismic analysis of shallow gas zones ............. Y ,
Seabed condition survey (if off-shore) ............. /Y' N
Contact name/phone for weekly progress repods [exploratory onljYJY N
35. With proper cementing records, t~bie-p1~n
(A) will contain waste ingle receiving zone; . : ..... Y N
(B) will not contami.~freshwater; or cause d~J~J~waste... Y N
to surface;~..-~ ~
(C) w~'al ~ofthe wel! used for disposal; Y N
(D) wJ~lS'~uc~ormation or impair recovery from a Y N
pool; and
(E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N
COMMISSION:
DWJ ~
RNC -
CO
r
c:\msoffice\wo, dian\diana\checklist
Comments/Instructions:
0
Z
0
-!
ITl
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISS,ON
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon __ Suspend ._~
Alter casing __ Repair well __
Change approved program __
Operation shutdowr':__. Re-enter suspended well __
Plugging __ Time extenmon __ Stimulate __
Pull tubing __ Variance __ Pedorate __ Other __
2. Name of Operator
Unocal (Marathon Oil Co. - Sub. Oper.)
3. Address
5. Type of Well:
P.O. Box 190247 Anchora~e, AK 99.519
4. Locationofwellatsudace
1,032' FNL, 606' FWL, Sec. 33 79N, R13W S.M.
Development
Exploratory
Stratigraphic
At top of productive interval
At effectiv~ depth
6. Datum elevation (DF or KB)
160' KB'
7. Unit or Property name
TradinA Bay Uni~
8. Well number
M-4
.At total depth ~o-J'~ f
~~' FNL, ~' FWL, Sec. 33 T9N~ R 13W S.M.
12. Present well condition summary
Total depth: measured 1473 feet
true vertical 1458 feet
Service __
9. Permitnumber
90-0071
10. APInumber
50--733-20417
11. Field/Pool McArthur
Middle Kenai Gas Pool
Plugs (measured)
Effective depth' measured 1473 feet
true vertical 1458 feet
Junk (measured)
Casing Length
Structural 849 '
Conductor 1,379 '
Surface
Intermediate
Production
Liner
Perforation depth: measured
true vertical
None
Size
20"
16"
Cemented
2050 sx
1000 sx
Measured depth
929'
1,457'
feet
River Field
True vertical depth
928'
1,442'
SUBMIT IN TRIPLICATE
RECEIVED
Tubing (size, grade, and measured depth) None
Packers and SSSV (type and measured depth) None
OCT- 1992
.Alaska 0il & Gas Cons. 00remission
Anchorage
13. Attachments
Description summary of proposal __ Detailed operations program __ BOP sketch __
t4. Estimated date for commencing operation
16. If proposal was verbally approved
Name of approver Date approved Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
FOR COMMISSION USE ONLY 3 -
Conditions of approval: Notify Commission so representative may witness
15. Status of well classification as~,r,'
S'uspended ~__
Date
Plug integrity __ BOP Test __
Location clearance __
J Approval No. ,~. _,~, Y/,7
Mechanical Integrity Test
Approved by order of the Commission
Subsequent form required 10-
Original ~'
,.~gned By
David W. Johnston
Form 10-403 Rev 06/15/88
Commissioner
..... STATE OF ALASKA
ALASKA ~,.~, g AND GAS CONSERVATION CL....MISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well
ABANDONED L_; SERVICE
Classification of Serwce v'Vell
0il Co. Sub-operator)
3. Address
P. O. Box 190247 Anchorage, AK 99519
4. Location of well at surface
7. P~,rrnlt NumUer
90-?/
1,032' FNL, 606' FWL, Sec. 33 T9N, R13W S.M.
At Top Producing Interval
t~~h
FNL, ~' FWL, Sec. 33 T9N, R13W S.M.
5.E!evation in feet (indicate KB, DF, etc.)160,KB aboveMSL !6.LeaseA ~DLDesignation and18:7:30:: Serial No.
i7. Total Depth fMD+TVD)
1,473' & 1,458'
I
13. DateT.D. Reached ., 14. Date Comp., Sus~p. orAb~'nd. 15, Water
6/24/90, 7/3/90
18.Plug Back Depth (MD+-FVD)t--Ig,.__Djr_e, ctional Survey I 20. Depth where
1,473' & 1,458' !YES ~ ..... NO
8. APl Number
I 5o- 733-2041~r
! g. Unit or Lease Name
Trading Bay Unit
t
10. Well Number
I1. Field and Pool
McArthur River Field
Middle Kenai Gas Pool
Depth, if offshore I 16. No. of Completions
187' feet MSL ' 0
SSSV set t 21. Thickness of Permafrost
N/Afeet MD i N/A
22. Type Electric or Other Logs Run
Photon
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD ,
CASING SIZE WT. PER FT. GRADE ITOP I BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
20:: 133 X-56 ! O' t~ 929' 26" 2050 sxs cmt
i6"
75
K-55 ~ O' I 1,457' 22" 1000 sxs cmt I 250,000
I ,
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
;nterval, sizeand number) SIZE DEPTH SET (MD) t PACKER SET (MD)
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
NONE DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
27. PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
I
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. ,[24-HOUR RATE e ,
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
Form 10-407
Rev. 7-1-80
CONTINUED ON REVERSE SIDE
Submit in duplicate
STEELHEAD PLATFORM
Well M-4(Preset)
06/i8/90
ACCEPT RIG from Well M-28 @ 0700 hrs. on 6/17/90. Skid rig over to
Well M-4. NU 30" diverter riser and preparing rig for spud.
06/19/90
Finished N/U diverter system and function tested all equipment.
06/20/90
06/21/90
Fin NU diverter. PU BHA. Displaced hole w/spud mud. Ran single shot
surveys. Drld and surveyed from 441' - 907'.
Drilled & surveyed from 907' - 970'. POOH. RIH w/26" hole opener.
Opened hole from 441'- 970'. POOH.
06/22/90
Ran 20" CSG to 930'. Circ & Cond mud.
CSG with 2050 SXS cmt. WOC.
KB to top of Csg
20" Hanger
1 jt. 20", 133#, BUTT X RL4S; X56, Crossover
18 jts., 20", 133#, RL45, X56
1 jt. 20", 133#, RL45 x BUTT, X56, Crossover
Foot Collar, BUTT
I it. 20", 133#, BUTT, X56
Floot Shoe, BUTT
RIH w/stab in equip. Cemented
FROM T..O
0' 80.25'
80.25' 82.63'
82.63' 110.99'
110.99' 845.87'
845.87' 885.65'
885.65' 887.73'
887.73' 926.83'
926.83' 929.08'
06/23/90
WOC. Tested csg to 500 psi. RIH. Tested diver[er to 500 psi. Drld cmt and
float equip. POOH. RIH. Drld 970'-1310'.
06/24/90
Drld and surveyed 1310'-1470'. Pooh. RIH. UR from 886'-1022'. UR arms
would not close. Worked free. POOH. Well bubbling. RIH to 1470'. CBU.
Drained stack. Gas coming from 20"x 34" annulus. POOH. RU to cmt
annulus.
06/24/90
06/26/90
Attempted to bullhead cmt down the 20"x 34" annulus w/o success.
attempted to stab conduit through 20" hgr for*top job w/o success. Ran
photon log. Unable to identify cmt top. Attempted to establish an injection
rate down the 20" annulus w/o success. Waited on perf guns.
Wait on smaller perf guns. RIH w/collar Iocator and locate collars. RIH
w/perf guns. Change of plans. POOH w/guns. Wait on 20" RITS, 20"
EZSV and runnign tools from North Slope. Received tools. RIH and set 20"
EZSV @ 500'. POOH. making up 20" RITS.
H :~wp\92OE06~cc11 .EVO
Anch0ra[!3
Well History- Well M-4
-2-
06/27/90
06/28/90
06/29/90
06/30/90
Run 20" RITS to 455'. perf 472'-474' w/2.60" gun and 11 gram charges.
No inj w/1000 psi. Three more attempts w/16 gram charges @ 472'-474',
482'-484' and 493'-495'. No inj w/ 1000 psi @ each interval. POOH w/
RITS. RIH w/4" gun and 22 GR charges perf 483'-485'. Attempt inj test
and 20" landing jt parted at runnign tool @ 300 psi. Prep to LD landing jt.
LD 20" landing jts. (Left X over and hgr running tool in hole.) RIH w/
R'i-rs. Pump 10 bbls of mud by surging perfs to 1000 psi (gas slowed after
mud). Broke down perfs. Cmt w/ 400 sxs 13.2 ppg TLW w/ additives.
WOC. POOH w/RITS. Recover X over and run tool. Drill cmt 464'-500'.
CBU.
CBU. POOH. RIH w/pkr and set @ 450'. Est inj rat eof 1/2 bpm @ 900
psi. Pumped 30 bbl mud and gas stopped. POOH. PU std d.p. for
taiipipe. RIH. Set pkr w/tail @ 455'. Mix 50 bbl cmt. Pump 20 bbl and
pressure increase to 1000 psi. Circ out cmt. (24 sx through perfs). WOC.
POOH. WOC. RIH. Drill cmt.
RIH. Drill 20" EZSV. CO to 1473'. POOH.
07/01/90
07/02/90
Test diverter system and floor equip. UR 22" hole from 935'-1473'. Circ
and cond mud. RU to run 16" csg.
KB to top of Csg.
16" FMC Hanger
33 jts 16", 75¢, BTC, K-55
16" Floot Shoe, BTC
1 jt 16", 75¢, BTC, K-55
16" Shoe, BTC
FROM TO.
0 79.04
79.04 82.52
82.52 1,412.44
1,412.44 1,414.52
1,414.52 1.454.84
1,454.84 1,456.84
Run 34 its of 16" 75¢ K-55 Buttress csg w/shbe @ 1457'. Cmt w/1000
sxs TLW w/3% CaCI-2, 0.75% gasban and 1/4¢SK flocele. Followed by
450 sxs Class "G" w/ 2% CaCL-2, 0.5% gasban and 1/4¢/SK flocele.
Flush wellhead. WOC. LD 16" landing jts. ND diverter.
H:~wp~92OE06~cc11.EVO
RE£E[VED
Well History- Well M-4
-3-
07/03/90
Fin ND diverter. Performed top job on 20" annulus. NU unihead and dry
hole tree. Prepared for rig skid. RIG RELEASED to Well M-3 @2200 hrs.
on 07/02/90.
H: ~wp~92OE06\cc11 .EVO
EFISTMFIN ......................................................................................
~JlCHFIISTENSENSURVEY CALCULATION AND FIELDWORKSHEETJob No. 0450-(x)801 Sidetrack No,_ .......... Page_ .__1
Company IMARATHON OIL COMPANY Rig Contractor & No. Pool Field McArthur Riv(~r Field
Well Name & No, STEELHEAD PLATFORM/M-4 Survey Section Name Definitive Survey EC Representative M ROSS
.................... W,:,L ^'rA ....................................
Target TVD (FT) Target Coord, N/S Slot Coord, N/S -1031,82 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ S
Target Description Target Coord, E/W Slot Coord, E/W 606.28 Magn, Declination 23,570 Calculation Method RADIUS OF CURVATL
Target Direction (DD) Build\Walk\DL per: 100ff~ 30m~ lOm~ Vert, Sec, Azim, 19,89 Magn, to Map Corr, 23,570 Map North to: OTHER
I ! IIII I I I II aB I all III I I II I I ! III II II III II I I I I I I
SURVEY DATA
Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate
Date Tool Depth Angle Direction Length TVD Section "N(+) /S(_) E(+) /W(-) DL Build (+) Right (+) Comment
Type (Fr) (Da) (DD) (FT) (FT) (l=r) (FT) (Per 100 Fr) Drop (-) Left (-)
0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT
19-JUN-90 GSS 108,00 0,00 0,00 108.00 108,00 0,00 0,00 0,00 0.00 0.00 0,00 8' M,1 ND W/2 [3EG BS
19-JUN-90 GSS 200,00 0,00 0,00 92,00' 200,00 0,00 0.00 0,00 0.00 0,00 0.00
19-JUN-90 GSS 300,00 0,00 0,00 100,00 300,00 0,00 0,00 0,00 0.00 0,00 0.00
19-jUN-90 GSs 434,00 1,25 155,00 134,00 433,99 -1.04 -1,32 0,62 0.93 0,93 115.67
19-JUN-90 GSS 471,00 0,50 174,00 37,00 470.98 -1,49 -1,87 0,77 2,15 -2.03 51,35
19-JUN-90 GSS 499,00 1,00 54,00 28,00 408,98 -1,52 -1.99 1,04 4.72 1,79 -428.57
19-jUN-90 GSS 533,00 1,50 28,00 34,00 532,97 -0,83 -1,44 1,53 2,19 1,47 -76,47
19-JUN-90 GSS 560,00 1.00 45.00 27.00 559.97 -0.27 -0.96 1.88 2,29 -1.85 62.96 ~ ' ~ ,
19-JUN-90 GSS 592.00 1.75 31.00 32.00 591.96 0.46 -0.36 2.35 2.55 2.34 -43.75 "-~' ::'::~ ~
19-JU,,,-90 GSS 623.00 2.50 21.00 31.00 622.94 1.60 0.67 2.85 2.69 2.42 -32.26
20-JUN-90 GSS 678.00 3.50 7.00 55.00 677.86 4.46 3.46 3.55 2.24 1.82 °25.45 ;>~ ~:; "--
20~UN-90 GSS 740.00 4.50 17.00 62,00 739.71 8.74: 7.68 4,44 1.98 1.61 16.13 c;~ ~ ~:;,~ ,~ , ~-- ,,
20-JUN-90 GSS 804.00 5.25 26.00' 64.00 803.48 14.17 12.74 6.44 1.67 1.17 14.06
20-JUN-90 GSS 861.00 5.50 20.00 57.00 860.23 19.50 17.65 8.52 1.08 0.44 -10.53
20-JUN-90 GSS 906,00 5.75 20,00 45,00 905.01 23,91 21.80 10,03 0.56, 0.56 0,00 8' M-1 ND W/2.~.~?EG BS
23-JUN-90 GSS 984.00 7.00 20.00 i 78.00 i 982.53 32.57 29.931 12.99 1.60 1.60 0.00
23-JUN-90 GSS 1076.00 9.25 18.00 92.00 1073.60 45.57 42.23 17.22 2.46 2.45 -2.17
....
23-JUN-90 GSS 1169.00 12.50 19.00 93.00 1164.91 63.11 58.86 22.79 3.50 3.49 1.08
23-JUN-90 GSS 1263.00 14.50 22.00 94.00 1256.31 85.04 79.41 30.47 2,25 2.13 3.19
23-JUN-90 GSS 1357.00 16.50 18.20 94.00 1346.89 110.16 103.00 39.11 2.39 2.13 -4.04
23-JUN-90 GSS 1421.00 18,75 18.00 64.00 1 407.88 1 29.53 121.42 45.13 3.52 3.52 -0.31
I I II I I I III I I I I I I i i __ II I I I
Telecopy No.
(907) 276-7542
June 5, 1990
Gary S Bush
Regional Drlg Mgr
UNOCAL
P O Box 190247
Anchorage, AK 99519-0247
Re: Trading Bay Unit M-4
UNOCAL
Permit # 90-71
Surf Loc 1032'FNL, 606'FWL, Sec 33, TgN, R13W, SM
Btmhole Loc 538'FNL, 2695'FWL, Sec 28, T9N, R13W, SM
Dear Mr Bush
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.
The Commission will advise you of those BOPE tests that it wishes
to witness.
Ver~y truly %ours~
1"t/
Chairman
Alaska Oil and Gas Conservation Commission
BY ORDER OF THE COiVfMISSION
jo
Enclosure
C:
Dept of Fish & Game, Habitat Section - w/o encl
Dept of Environmental Conservation - w/o encl
STATE OF ALASKA
ALASKA UIL AND GAS CONSERVATION CUMMISSION
PERMIT TO DRILL
20 AAC 25.O05
la. Type of work Drill [] Redrill lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil []
Re-Entry [] Deepen Service [] Developement Gas [] Single Zone [] Multiple Zone []
,
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
Union Oil Company of California 160 feet McArthur River
3. Address 6. Property"Designation Middle Kenai Gas
P. O. Box 190247, Anchorage, At( 99519-0247 APL 18730 Pool
4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.025)
1032' FNL, 606' FWL, Sec 33, TgN, R13W Trading Bay Unit Blanket Bond
At top of productive interval 8. Well nurpber Number
5194234
800' FNL, 2600' FWL, Sec 33, T9N, R13W M-4
At total depth 9.'APproximate spud date Amount $200,000
538' FNL, 2695' FWL, Sec. 28, T9N, R13W July 1, 1990
12. Distance to nearest 13. Oi'stance to nearest well 14. Number of acres in prOperty 15. Propos(~0d3~Pt~v~o,,,d
property line
5200 feet 6.2 feeti 3840 6235' TVDfeet
,
16. To be completed for deviated wells 17. Anticipated presSUre (see2OAAC25.035(e)(2)) @ 6235' TVD
Kickoff depth 475 feet Maximum hole angle 54o Maximum surface 3000 psig At total depth ('fVO) 3717 ps~g
,,
18. Casing program Setting Depth
size Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
:2'6" 20" 133 X-56 RL-4S 880 70 70 950 950 1400 sx
22" 16" 75 K-55 BTC 1397 70 70 1467 1450 1400 sx
1'~-1/2" 13-3/8" 61 l(-55 BTC 2980 70 70 3050 2646 1650 sx
12-1/4" 10-3/4" 55.5 N-80 BTC 430 70 70 500 500 2200 sx
1'2-1/4" 9-5/8" 47.0 N-80 BTC 8703 500 500 9203 6235 '
,
,,
20. Attachments Filing fee ~ Property plat [] BOP sketch I~ Diverter Sketch ~ Drilling program []
Drilling fluid program E~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements
21. I hereby certify%that the f0regoing"is true and_c.or~, ct tO the best of my knowledge' '
Signed ~ S, G~°~. Bus*. TitleREGIONAL DRILL ING [v~NAGER Date ~~b
~ ~ Commission Use Only
Permit_Number k..,) [ APl number .... [ Approval date "1 See cover letter
- 7/ I 50- zoO/. 7 I 06/06/90 ,_J for other requirements ,
Oondition5 Of approval 5arnples required [] Yes/~No Mud log requ~.re.d L-J Yes ~ No
Hydrogen sulfide measures [] Ye¢..--¢[ No_ Di.recfional survey required ~. Yes [] No
Required workin~ure f~r ~15E,~~ ¢~,3M;,/~1-] 5M; I-110M; ~] '15M
· ' by order of
_Approved by _ , Commissioner the commission D. ate ~ .
Form 10-401 Rev. 12-1-85
Subr~i triDli'cate
r' '.LING AND COMPLETION PROGRAM
M,-,.~ATHON OIL COMPANY
ALASKA REGION
WELL: M-4
LEG: B-2
SLOT: 9
FIELD:
AFE No.:
TYPE:
Trading Bay Unit, Steelhead Platform
Grayling Gas Sands Dual producer
REVISION NO.:
DATE: 5/18/90
SURFACE LOCATION:
TARGET LOCATION:
BOTTOMHOLE LOCATION:
1032'FNL, 606'FWL, Sec. 33 T9N, R13W
800'FNL, 2600'FWL Sec. 28 T9N, R13W
538'FNL, 2695'FWL Sec. 28 T9N, R13W
KB ELEVATION: 160 ft.
GL ELEVATION:
FORMATION
ESTIMATED FORMATION TOPS:
DEPTH (MD) DEPTH ('I'VD)
' ,.':-,,~ ~nchoraga
POTENTIAL
CONTENT
AC-1
A-1
B-1
C-1
D-1
D-16bc
TOTAL DEPTH
1509 1490
3196 2735
3969 3185
5041 3810
5573 4120
8860 6035
9203 6235
gas/water
gas/water
gas/water
gas/water
gas/water
gas/water
CASING PROGRAM
TYPE
SIZE
SET
GRADE THREAD FROM
SET
TO
HOLE
SIZE
CONDUCTOR:
AUXILIARY:
20
16
133 X-56 RL-4C Surf 950'
950'TVD
75 K-55 BTC Surf 1467'
1450'TVD
26"
17-1/2"
U/R to
22"
SURFACE:
13.375 61 K-55 BTC Surf
3050'
2646'TVD
12-1/4"
U/R to
17-1/2"
PRODUCTION:
10.75 55.5 N-80 BTC Surf 500'
9.625 47.0 N-80 BTC 500' 9203'
12-1/4"
SIZE WEIGHT GRADE
CASING DESIGN
SETTING FRAC GR FORM PRSS
DEPTH,TV @ SHOE @ SHOE MASP
20" 133# X-56 950' 12 445 483
16" 75.0# K-55 1450' 12.1 716 989
DESIGN FACTORS
TENS COLL BURST
19.5 2.41 6.13
12.6 1.02 4.84
13.375" 61.0# K-55 2646' > 14.0 1266 2122 6.96 1.25 1.85
10.75" 55.5# N-80 500' 3000 4.34 15.1 2.25
9.625" 47.0# N-80 6235' > 14.0 3000 3000 4.74 1.43 2.03
DIVERTER SYSTEM
The diverter system will consist of a 29-1/2" x 500 psi annular preventer,
a 30" x 500 psi riser, and two 16" diverter lines each equipped with a 16"
hydraulically actuated full-opening ball valve. A preselected diverter valve
will open automatically and simultaneously when the annular is closed. The
direction of flow can be changed without opening the annular.
BLOWOUT PREVENTERS
The blowout preventer stack will consist of a 16-3/4" x 5000 psi Hydril type GK
annular preventer, a 16-3/4" x 10000 psi Hydril double gate ram type preventer
outfitted with blind rams in the bottom and pipe rams in the top, a 16-3/4" x
10000 psi drilling spool (mud cross) equipped with a 4-1/16"x 10000 psi outlet
and a 3-1/16" x 10000 psi outlet, and a 16-3/4" x 10000 psi Hydril single gate
ram type preventer outfitted with pipe rams. A 16-3/4" x 5000 psi riser will be
utilized between the blowout preventers and the casing spools.
The choke manifold will be rated 3-1/16" x 5000 psi. It will include a remote
hydraulic actuated choke and a hand adjustable choke. Aisc included is a poor-
boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in
the flowline and the mudpits will contain sensors to measure the volume of fluid
in the surface mud system, both with a readout convenient to the drillers console.
The blowout preventers, choke manifold and associated equipment will be
pressure tested to 250 psi and to 3000 psi with the exception of the annular
which will be tested to 250 psi and to 2500 psi.
MUD PROGRAM
DEPTH WEIGHT VISCOSITY WATER MUD
TO ppg sec/qt LOSS TYPE
950' 8.8-9.0 60-80 <30cc's Spud
1450' 9.0-9.2 60-80 <30cc's Spud
2650' 9.2-9.4 40-50 <20cc's PHPA
6235' 9.4-9.8 40-50 < 10cc's PHPA
Mud discharges will be monitored and reported per EPA requirements
MUD EQUIPMENT
The solids control equipment consists of an Brandt dual tandem shale shaker,
a Brandt 2-cone desander, a Brandt mudcleaner, and a Brandt centrifuge.
WELLHEAD SYSTEM
STARTING FLANGE: 30" series 300
CASING HEAD: 20" S.O.W. x 21-1/4" 2000 psi FMC segmented clamp hub
w/2" L.P. outlets
CASING HEAD CLAMP: 21-1/4" 2000 psi FMC segmented clamp
CASING HEAD: FMC Unihead Type II, 2 step, 16" pack-off bottom w/21-1/4"
2000 psi clamp hub x 16-3/4" 5000 psi flanged top w/2-1/16"
3000 psi outlets
TUBING HEAD: FMC TCo60-ET, SPCL 16-3/4" 5000 psi STD BTM x 16-3/4" 5000 psi
FLNGD top w/2-1/16" 5000 psi outlets and four 1/4" SCSSV control line ports
CEMENTING PROGRAM
CONDUCTOR: 20"@ 950' MD
LEAD SLURRY TYPE: Premium cement w/15 Ib/sk Thix Lite 373
TOP OF CEMENT: SURFACE
WEIGHT: 12.8 ppg.
YIELD: 2.17 cu. ft./sk
WATER REQ.: 11.9 gal/sk
PUMPING TIME: 6:00+ hrs:min
EXCESS (%): 100 %
ESTIMATED VOLUME
1000 sx
TAIL SLURRY TYPE:
TOP OF CEMENT:
WEIGHT:
YIELD:
WATER REQ.:
PUMPING TIME:
EXCESS (%):
ESTIMATED VOLUME
Premium cement w/3% CaCI2
8O0 ft.
15.8 ppg.
1.15 cu. ft./sk
5 gal/sk
6:00+ hrs:min
100 %
400 sx
AUXILIARY:
16"@ 1467' MD
LEAD SLURRY TYPE: Trinity Lightweight cement w/.75% Halad 344 and
1% Calcium Chloride
TOP OF CEMENT: SURFACE
WEIGHT: 13.6 ppg.
YIELD: 1.21 cu. ft./sk
WATER REQ.: 5.85 gal/sk
PUMPING TIME: 4:00+ hrs:min
EXCESS (%): 100 %
ESTIMATED VOLUME
1000 sx
TAIL SLURRY TYPE:
TOP OF CEMENT:
WEIGHT:
YIELD:
WATER REQ.:
PUMPING TIME:
EXCESS (%):
ESTIMATED VOLUME
Premium Class G cement w/3% CaCI2
1265 ft.
15.8 ppg.
1.15 cu. ft./sk
5 gal/sk
6:00+ hrs:min
100 %
400 sx
SURFACE:
CEMENTING PROGRAM
13-3/8" @ 3050' MD
LEAD SLURRY TYPE: Trinity Lightweight w/1% CaCI2 + 1.5% Gas Ban and
.4% Halad 344
TOP OF CEMENT: SURFACE
WEIGHT: 13.6 ppg.
YIELD: 1.21 cu. ft./sk
WATER REQ.: 5.83 gal/sk
PUMPING TIME: 3:50 hrs:min
EXCESS (%): 50 %
ESTIMATED VOLUME
1250 sx
TAIL SLURRY TYPE: Premium cement w/1.5% Gas Ban & 1% CaCI2
TOP OF CEMENT: 2600 ft.
WEIGHT: 15.5 ppg.
YIELD: 1.19 cu. ft./sk
WATER REQ.: 5.3 gal/sk
PUMPING TIME: 3:00+ hrs:min
EXCESS (%): 50 %
ESTI MATED VOLUME
400 sx
PRODUCTION: 9-5/8" and 10-3/4" @ 9203' MD
LEAD SLURRY TYPE: Trinity Lightweight w/1.5% Gas Ban,. 14% LWL
TOP OF CEMENT: 2600 ft.
WEIGHT: 13.6 ppg.
YIELD: 1.22 cu. ft./sk
WATER REQ.: 5.95 gal/sk
PUMPING TIME: 4:00 hrs:min
EXCESS (%): 30 %
ESTIMATED VOLUME 1200 sx
TAIL SLURRY TYPE:
TOP OF CEMENT:
WEIGHT:
YIELD:
WATER REQ.:
PUMPING TIME:
EXCESS (%):
ESTIMATED VOLUME
Premium cement w/.75% Gas Ban, .12% LWL
6300 ft.
15.6 ppg.
1.18 cu. ft./sk
5.2 gal/sk
4:00 hrs:min
30 %
1000 sx
DIRECTIONAL PLAN
DESC MD TVD INCL
NORTH
AZIM COORD
EAST
COORD
SECTION
RKB 0 0 0 0 0 0 0
N19.88E 0 0 0
N19.88E 28 10 30
KICK OFF 475 475 0
BUILD @ 1.5 deg/100ft.
KICK OFF 950 950 7
BUILD @ 2.5 deg/100ft.
END OF BUILD 2840 2526 54
HOLD
TOTAL DEPTH 9203 6235 54
N19.88E 911 329 968
N 19.88E 5774 2089 6140
POTENTIAL INTERFERENCE: WELL DISTANCE
DEPTH
M-IS/'I' WITHIN 100' 0-2500'
Mo2 WITHIN 100' 0-1100'
M-3 WITHIN 100' 0-1300'
M-6 WITHIN 100' 0-1900'
M-5 WITHIN 100' 0-1300'
M-25 100' 0ol 100'
M-26 100' 0ol 300'
M-27 WITHIN 100' 0-1000'
G-14A WITHIN 30' 5400-5460
G-14 WITHIN 60' 5200-5350
G-16 WITHIN 60' 6200°6350
RLF#1 100' 1520'
LOGGING PROGRAM
CONDUCTOR: No logging is planned for this interval.
AUXILIARY:
No logging is planned for this interval.
SURFACE:
No logging is planned for this interval.
PRODUCTION:
GR/SP/Cal/DIL/LSS from 7200' to 2700'. FDC/CNL/Cal/GR
from 7200' to 2700'.
COMPLETION:
A Cement Bond Log (CBL/GR) and a directional gyro-
survey will be run prior to perforating.
DRILLING PROGRAM
CONDUCTOR: Nipple up diverter and function test same. Drill a 26"
hole to 975' RKB. (Nudge wellbore away from platform while drilling.) Run and
cement 20" conductor. WOC. Perform top job if necessary. Back out
and L/D landing joint. Set wear bushing. Test diverter and 20" conductor to 500 psi.
AUXILIARY: Drill a 17-1/2" hole to 1450' RKB. Underream the 17-1/2"
hole to 22" from 950' to 1467'. Pull wear bushing. Run and cement 16" auxiliary
casing. WOC. Back out and L/D landing joint. Install FMC Unihead w/16"
pack-off and test void to 700 psi. Nipple up BOPE. Test BOPE and choke
manifold to 2000 psi. Test 16" auxiliary casing to 1850 psi. Set Unihead
wear bushing.
SURFACE: Drill float equipment and 10' of new formation.
Run leak off test. Do not exceed 14.0 ppg equivalent test pressure.
Drill a 12-1/4" hole from 1467' to 3050' per the directional program. Log
if necessary. Underream the 12-1/4" hole to 17-1/2" from 1467' to 3050'. Pull
wear bushing. Run and cement 13-3/8" casing. WOC. Set pack-off
and test void to 1100 psi. Test BOPE and choke manifold to 3000 psi. Test 13-3/8"
surface casing to 2150 psi. Set Unihead wear bushing.
PRODUCTION: Drill float equipment and 10' of new formation.
Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure.
Drill a 12-1/4" hole from 3050' to 9203' per the directional program. Log. Pull
wear bushing. Run and cement 9-5/8" casing with 1300 sx. WOC. Set pack-off and test
void to 2800 psi. Test BOPE and choke manifold to 3000 psi. Test production
casing to 4200 psi. Set wear bushing.
COMPLETION: Cleanout casing to PBTD. Run gyro and CBL.
Perforate and flowtest the D-16A and D-16BC sand with TCP guns.
Kill well, POOH. Set permanent production packer with plug above
perfs. Perforate and flowtest the D-3B and D-6 sands with TCP guns.
Kill well, POOH. Retrieve packer plug and wear bushing. Run dual
strings of 3-1/2" tubing and dual packer. Land tubing. Nipple down BOPE.
Nipple up and test tree to 5000 psi. Unload tubing with CTU and nitrogen.
CORING PROGRAM
No cores are planned for this well.
TESTING PROGRAM
No open hole tests are planned for this well.
HOR ~ONTAL PROJEOTION
SCALE 1 IN. - 1000 FEET
HARATHON OIL
Lea~ B-2, SIo~:~ 9, n~ell No~
STEELHEAD Ple~f'orm. Cook Inlet, Alee
6000
5000 .
4000 _
= 3000 _
-,- 2000 _
1000 _
0
SURFACE LOCAT I ON ~
1032' FNL. 606' FWL
SEC. 33. TgN. Ri 31,/
1000 _
WEST-EAST
1000 0 1000 2000
, I I I
TARGET
TYD=6035
THD-8860
DEP-5861
NORTH 5512
EAST 1994
3000
I
TD LOCAT[ON~
538' FNL. 2695' FWL
SEC. 28. TgN. RI3W
TARGET LOCATION*
800' FNL. 2600' FWL
SEC. 28. T9N. R13W
N 19 DEG 53 MI N E
5861' (TO TARGET)
HARATHON OIL C,~ ·
STEELHEAD Platf*or'm, Cook
Not H-4 Propoae.<l
Inlet, Alaaka
0 RKB ELEVATION, 160'
1 000
KOP / 30" CONDUCTOR TVD=4Z5 THD=4?5 DEP=O
1 .$ DEG/! OOFT DOGLEG
20" CSG PT TVD=950 TMD=95! DEP=30
2,$ DEG/I OOFT
BUILD
16 CSG PT TVD=1450 TMD=1467 DEP=150
200O
I..4
I"rl
3000
4000
EOB TVD=2528 TMD=2840 DEP=968
13 3/8' CSG PT TVD=2650 TMD=3050 DEP=1139
5000
AVERAGE ANGLE
54 DEG 22 HI N
6000
7000
TARGET TVD=6035 TMD=8860 DEP=586!
TD / 9 5/8' CSG PT TVD=6235 THD=9203 DEP=6140
1 000 2000 3000 4000 5000
VERTICAL SECTION
i I
6000 7000
100
50
0
5O
100
150
200
,3O0
250
200
150
100
50
50
100
6000
1800
2200
1800
6400
2O00
/
I
/
/
/
/
/
1600 /
/
~ 1600
/
/
/
/
I0 14130~ 1 400
4000 /
/
/
? ioo , ,,
l~)no 1200 !
/'/1200
/
~ 10~0
! ~' 1000
.
8OO
1000
/
/
/
1800
/
/
/
/
! 16oo
!
!
/
/
/
/
I
~'2400
"~20
1200
300
250
200
1 50
100
5O
0
5O
100
100 50 0 50 100 150 200
1 O0 0 1 O0 200 300 400 500
1100
llOC
1 000
900
80O
700
600
5OO
40O
300
7700
~500
7800
8000
O0
2000
300
2900
2800
2700
2600
2500
/
/
3160
2600
I
3O0O
/
/
!
2g0~2500
/
/
/
28o~
8500 /
/
/
/
2300
/
;leO
O0
52OO
5000
O0
!
1~800 /
/
890(~S000
7400
7300
/
/
/
/2200
O0
I
5500
I
5400
!
/~'211.00
/
/
I
1 O0
1 000
900
800
700
600
5OO
40O
30O
1 O0 0 1 O0 200 300 400 500
200
~00
400
500
600
700
800
1900
1800
1 700
1600
1 500
1400
1 ;300
1200
1100
i,,
3400
3300
3200
~900
31 O0
3,000
3600
35OO
4100
4000
3900
3800
900
2800
~400
/
/
11~?oo
/
/
/
/
/
/
/ 3700
/
~0
3600
I
/
/
/
/
/
/
/
/
4100
otgoo
4200
3900
'200
62O0
6500
I
6400 I
I
I
6100
6000
5900
1900
1800
1700
1600
1 500
1400
1 300
1200
1100
200 :300 400 500 600 700 800
2700
2600 _
2500 _
24OO _
2300 _
2200 _
2100
2000
1 900
500
I
6OO
I
1 O0
700
4600
4500
4400
4300
4800
700
I
5300
5200
51 O0
5000
9OO
O0
/
/
I
/
/
/
/
/
/
/
I
/
/
/
4400
800 900
! _ , !
I
I
I
/
1000
I
!
!
!
/ 5300
/
/
!
/ 5200
/
/
I
51 O0
5000
4900
4800
4700
1100
I
4600
;200
;300
;400
I
7301
I
7200
I
2700
.2600
.2500
.2400
.2300
.2200
2100
2000
1 900
500 600 700 800 900 1 000 1 1 O0
3500
3400 _
3300.
3200 _
3100_
3000 _
2900 _
2800 _
2700 _
800
I
I
i
I
800
900
O0
O0
5900
5600
900
6000
1000 11 O0
O0
L
/
/
/
/
L4000
/
/
/
/
/
/
/
/
;00 /
1200
I
!
!
!
!
/
I
I
/
/
I
'/4300
/
/
.00
/
4200
/
/
/
/
/
4100
5600
5500
i
1000 11 O0
5800
5700
1300 1400
6400
I
6~00
62O0
6100
60O0
,, ,i
1200
1300
I
1400
350C
3400
3300
3200
3100
3000
2900
280O
2700
4300 _
4200 _
4100_
4000 _
3900 _
3800 _
3700 _
3600 _
3500.
11 O0 1 200 1 300 1 400 1 500
I I I I I
91 O0
/
%' 4800
/
I
....~~oo
I ...--~oo ~ .~oo
!
~,~.~'"-6600 ll
I
/
/
/
I
f 5100
/
/
/
/
/
/
500O
,900
9200
7000
6900
'200
6700
6500
1600
1700
74O0
I
I
7300
I
I
7200
I
7100
7300
9400
95OO
! I I
11 O0 1 200 1 300 1 400 1 500 1 600 1 700
_ 4300
_ 4200
_ 4100
_ 4000
3900
3800
3700
3600
3500
5100
5000
4900
4800
47OO
4600
4500
4400
4300
1 400
1 500
1 600
1 700
/
/
/
I
/
5600
/
I
/
/
/
/
I ssoo
7600
/
/
/
/
/
/
! s4oo
1800
7500
! $~oo
/
I
/
I
/
/
/
! s3oo
8000
7900
7800
7700
81 O0
1900
I
850~
8400
8300
8200
_1
2000
I
L SlO0
.5000
_ 4900
_ 4800
_ 4700
. 4600
_ 4500
.4400
_ 4300
1400 1 500 1600 1700 1800 1900 2000
! 700 1 800 1 900 2000 21 O0 2200 2300
5900
5800
57OO
5600
5500
5400
5300
5200
91 O0
8900
900~ /
/
/
6100
9100
./
/
/
I
/
/
/
/
I
/
/
6000
)0
9400
9200
9000
92O0
d5900
I
I
I
/ 8700
[ d5800 9500
/
/ 8600
_ 5900
58OO
5700
5600
55OO
5400
5300
5200
1 700 1 800 1 900 2000 21 O0 2200 2300
STEELHEAD
PLATFORM
CHOKE MANIFOLD
TO GAS BUSTER
TO DERRICK VENT
I I "SWACO
CHOKE LINE
A..--_I
TO SHALE SHAKERS
SECTION AA
ALL VALVES IN FLOW PATH ~RE 3-1/16" 5000 PSI CAMERON GATE TYPE
Fillup Line
16-3/4'
10,000 psi
Doublegate
Pipe Rams
Check Valve I
Kill Li~e ~v/,~~/~v/m' I
Gate Valve Gate Valve [
,I
Flow Line
Hydril
16-3/4' 5000 psi
Type GK Annular
STEELHEAD pLATFORM
Blind Rams
Preventer Schematic
Pipe Rams
----~ I I
I
L~~ C__~hoke Line
Gate Valve HCR Valve
6-3/4' lO,O00.psi
Singlegate
16-314' 5000 psi Riser
-T- I
~]~ Ball Valve
Wellhead
Plan View
STEELHEAD PLATFORM
DiVERTER SYSTEM
Rig Substructure
,
CeramJte filled ~ ~ i' _ Ceramite filled
16' 'Diverter Line ' 16' Remo!e~ 16L'DnleVerter
Operated Ball Valve
Riser
29-1/2' 500 psi Flange
Section View
Conductor,
A A A /~ A A A
CENTRIFUGE ..- MUD --- ~,-- // MUD
PIT I CLEANER DESANDER // DESANDER -- CLEANER :-- CENTRIFUGEpIT
j PIT PIT A.-.~ PIT PIT
100 Bbis Cap 113 Bbls Cap - ~// 113 Bbls Cap 100 Bbls Cap
0.99 Bbls/in 105 Bbl$ Cap / 1.11 Bbls/in RESERVE PiT~//?~// 1.11 Bbls/in 105 8bls Cap 0.99 Sbls/in
1.03 Bbls/in 1.03 Bbls/in
0 ~ -- 0 .... O~ ,.~,.~,.,,.~ _. 0 '~ O '~ O
3.05 Bbls/in ~
A A. ~ A A
' MIX PIT PILL PIT
82 Bbls Cap 80 Bbls Cap
0.77 Bbls/in 0.75 Bbls/in
0 0 0 0
MUD RETURN DITCH
] EQUALIZE R
AGITATOR
MUD GUN
N ~
STEELHEAD PLATFORM
MUD PIT LAYOUT
CHECK LIST FOR NEW WELL PERMITS
ITEM APPROVE DATE
(2 thru 8j ....
(3) Admin
(9 thru
(14 thru
1. Is the permit fee attached ..........................................
YES
2. Is well to' be located in a defined pool .............................
3. Is well located proper distance from property line ..................
4. Is well located proper distance from other wells ....................
5. Is sufficient undedicated acreage available in this pool ............
6. Is well to be deviated and is we!lbore plat included ................
7. Is operator the only affected party .................................
8. Can permit be approved before fifteen-day wait ......................
Does operator have a bond in force ..................................
Is a conservation order needed ......................................
Is administrative approval needed ...................................
Is the lease number appropriate ..................................... ~--
Does the well have a unique name and number .........................
·
.
10.
11.
12.
13.
(5) BOPE
(23 thru'28Y
14.
15.
16.
17.
18.
19.
20.
21.
22.
23.
24.
25
26.
27.
28.
Lease & Well No.
NO
·
·
Is conductor string provided ........................................ ~ ,
Will surface casing protect all zones reasonably expected to
serve as an underground source of drinking water ..................... _~ .
Is enough cement used to circulate on conductor and surface .........
Will cement tie in surface and intermediate or production strings ... _~
Will cement cover all known productive horizons .....................
Will all casing give adequate safety in collapse, tension and burst..
Is this well to be kicked off from an existing wellbore ............. _~
Is old wellbore abandonment procedure included on 10-403 ............
Is adequate wellbore separation proposed ............................
Is a diverter system required .......................................
Is the drilling fluid program schematic and list of equipment adequate_~_
Are necessary diagrams and descriptions of diverter and BOPE attached.
Does BOPE have sufficient pressure rating - Test to ~~ psig .. _~_
Does the choke manifold comply w/API RP-53 (May 84) ..................
Is the presence of H2S gas probable .................................
(6) OTHER
_ thr~
(6) Add:
Geology_.:.
chlqo
Eng~eer{ng:
LCS ~ BEW ~Nn~
rev: 01/30/89
6.011
For
29.
30.
31.
32.
exploratory and Stratigraphic wells:
Are data presented on potential overpressure zones? .................
Are seismic analysis data presented on shallow gas zones ............
If an offshore loc., are survey results of seabed conditions presented
Additional requirements .............................................
INITIAL GEO. UNIT ON/OFF
POOL CLASS STATUS AREA NO. SHORE
/
Additional Remarks:
/
/
TBU M-4
Section 33-T9N-RI3W, SM
McArthur River Field
Cook Inlet
Kenai Borough, Alaska
Artem Ratchkovski, Geologist
Rich Swanson, Geologist
Epoch Well Services Inc,
WELL RESUME
OPERATOR:
WELL NAME:
LOCATION:
FIELD:
COORDINATES:
ELEVATIONS:
COUNTY:
STATE:
APl INDEX:
LEASE ADL
SPUD DATE:
TOTAL DEPTH:
COMPLETION DATE (T.D.):
CONTRACTOR:
RIG #:-
RIG TYPE:
COMPANY GEOLOGIST:
COMPANY ENGINEERS:
MWD COMPANY:
DIRECTIONAL DRILLER I COMPANY:
COMPANY:
MUD TYPES:
HOLE SIZES:
CASING DATA:
MUDLOGGING SERVICES:
TYPE UNIT:
UNIT #:
LOGGING GEOLOGISTS:
UNOCAL CORPORATION
TBU M-4
SEC. 33, T9N R13W, SM
TRADING BAY
R.K.B. = 160'
KENAI BOROUGH
ALASKA
50-733-20413
18730
OCTOBER 21', 1'999
6430'
OCTOBER 31, 1999
POOL ARCTIC ALASKA
STEELHEAD PLATFORM
PLATFORM I TOP DRIVE
ERIC GRAVEN
TERRY COLEMAN I SHANE HAUCK
ANADRILL
TOM DUNN I BAKEHUGHES INTEQ MUD
M-I DRILLING FLUIDS, INC.
GEL/BAR/PAC TO 3615';
PHPA TO 6430"
12.25" TO 3615'; 8.5" TO 6430'
20" AT 929'; 16" AT 1457';
9 518" AT 3603'; 7" AT 6430'
EPOCH WELL SERVICES, INC.
DML
33
ARTEM RATCHKOVSKI ! RICHSWANSON
TBU M-4 BIT RECORD
STEELHEAD PLATFORM
COOK INLET, ALASKA
BIT SERIAL SIZE 'in 32ndst DEPTH DEPTH FEET BIT AVG AVG AVG PUMP " WHY
NUMBER NUMBEF INCHES MAKE , ,TYPE t 2 3 4 IN POOH DRILLF_D HOURS FT/HR WOB RPM PSi T B O PULL
2 M2-168 t2.25" STO MO2SODCL 15 t5 16 13 1,480 3,6t5 2,135 22.84 1t6 18 NIA NIA cSG
3 JR6916 8.5" $TC S73EHPX tt tt tt 1t 3,6t5 6,430 2,818 26.30 t49 B N/A N/A LINER
,
,
,
_
·
_
,,
_
I
UNOCAL
TBU M~4 DAILY MUD REPORTS
STEELHEAD PLATFORM
COOK INLET, ALASKA
DATE DEPTH MW VIS PV YP GELS FL FILTER SOLIDS SAND' pH CI- OIL
MD ppg CAKE % % , ppm %
1012111999 1457' 9.10 46 10 26 71919 12.0 11 4.0 0.00 9.1 200 0196
I
10/21/1999 1480' 9.10 48 t8 14 8/9/9 11.4 1/ 4.0 TR 9.0 600 0/96
10/22/1999 1480' 9.15 44 10 15 5/12/t'2 10.2 1/ 4.0 TR 10.0 800 0/96
10/22/1999 1480' 9.1 $ 45 10 17 5/12/12 10.0 1/ 4.0 TR t 0.0 800 0/96
10/23/1999 1751' 9.2+ 46 14 16 6/t2/15 9.4 1/ 5.0 0.33 9.1 800 0/95
10/23/1999 2080' 9,30 47 14 16 6/12/14 8.8 1/ 5.0 0.33 8.9 900 0/95
I I
10/24/1999 2857' 9.60 46 13 16 7/20/2'2 7.4 <2/ 7.0 0.50 8.9 900 0/93
10/2411999 3442' 9.90 47 13 17 8123/27 7.0 <21 8.0 1.00 815 900 0193
10125/1999 3615' 9.75 46 14 13 6120/30 7.5 <2/ 8.0 0.50 8.5 800 0192
10/25/1999 3615' 9.75 45 14 12 5118/28 7.6 <2/ 8.0 0.50 8.5 800 0/92
10/26/1999 3615' 9.80 40 12 16 10122134 8.2 <21 8.5 0.70 9.4 800 0/91.5
10/27/1999 3603' 9.80 40 12 16 9/11/29 8.0 <2/ 8.5 0.70 9.1 800 0/91.5
10/28/1999 4205' 9.00 47 12 13 7/10/21 6.3 1/ 4.0 0.40 9.0 800 0/96
10/29/'1999 4674' 9.10 43 12 17 7/10/21 6.2 1/ 5.0 0.40 8.7 800 0/95
10129/1999 4973' 9.20 50 13 19 7/11122 6.0 11 5.5 0.50 9.3 800 0/94.5
10/3011999 5897' 9.30 n/a 17 22 7/12/23 5.6 1/ 6.0 0.70 9.0 800 /94
10130/1999 6183' 9.40 n/a 19 23 7113/26 4.9 11 6.5 0.80 8.9 800 0/93.5
UNOCAL
TBU M-4
STEELHEAD PLATFORM
SURVEY SUMMARY
Data from Schlumberger Anadrill
MEASURED HOLE COURSE I VERTICAL COORDINATES DOGLEG
DEPTH ANGLE AZIMUTH LENGTH TVD SECTION N (+,) or S (-) E (+) or W (-) SEVERITY
1 1421.00 18.75 18~00 ~ . ~0.00 1407.89' 121.40 121.56 ' 43,.4,1 0.00
2 1470.00' 18.77 18.00 49.00 1454.29 136.06 136.55 48.28 0.04
3 1533102 " '18.84 20.b6 63.02 151'3.94 155.08 15~.75 ' 54.§0' 1.06
4 1600.17 20.54 22.25 67.15 1577.17 .176.,.~5, 6.., '1'7.6'.84 ~3'.0~, 2.76
5 1662.88 23.09 24.30 62.71 1635.38 198.93 198.23 72.31 4.24
6 1728.81 25.71 26.45 65.93 1695.42 . 225,.34'... 222.82, 84.00 4120
7 1756.63 26.78 27.72 27.82 1720.37 ,2,37.,35~ 233.77 8916:1 4.34 '
8 1790.91 28.09 29.91 34.28 1750.80 252,87 2~47.61 97.22 4.82 '
90 .1822.00 29.35 32.52 31.09 1778.06 267.~5' 260.38 104.9'7 5.72 '
18:46.48 30.54' 35.58 24.48 1799.27 2~9.1~;I 2~0.49 111'.81 7.91
11 1883.43 ~,2.13 39148 36.95 183'b.84 299.01 285.72 123.53 6:97
121 1916.52 33.06 41.08 33.09 1858.72 316.83 29§.3'1 135.05 3.83
' 1978.40 35.24 42.43 35.58 1909.94 351.51 325.16 158.21 3.83
151 2011.48 36.57 42.52 33.08 1936.74 370,1~8 339.47 171.31 4.02
161 2040.01 37.66 42.22 28.53'1959.49 388.07 352.19 182.91 ' 3.87
1178 2071.65 38.80 41.90 ;~'1.64 1984.34 407.63' 366.72 196.03 3.66
2104.62 40.05 41.65 32.§7 2{~09.81 42'81~5 382,34 209.97 3.82
19 2130.45 41.29 41.50 25.83 2~29.~0 445.38 394.93 221.14 4.82
20 '2185.45 43.22 4t.34 3~.00 20~5.;~0 468.90 412.58 236.71 5.52
21 2;I 97.06 44.73 41.40 31.61 20~8.05 490.83 429.05 251.22 4.78
!22~ 2224.49 46.29 42.27 27.43 2097.27 510.38 443.63 264.27 6.12
23, '2259'.30 48.73 42.43" 34.81 2120.78 536.02 462.60 281.56 7.02
24, '2~;91.87 50.97 ' 4~..{~5 ' ;~2.57 '2141.~8 560.88 480.89 298.44 6.98
25' 2319.94 53.08 42.83 28.07 2159.05 582.96 497.10 313.50 7.52
26~ 2358.12 55.79 42.25 38.18 2181.26 613.97 519.99 334.50 7.20
27' 2387.62 57.32 41.90 29.50 2197.52 638.56 538.26 350.99 5.28
UNOCAL
TBU M-4
STEELHEAD PLATFORM
SURVEY SUMMARY
Data from Sct Anadrill
MEASURED HOLE~ coURSE VERTICAL COORDINATES DOGLEG
DEPTH ANGLE AZIMUTH LENGTH TVD SECTION N (+) or S (-) E (+) or W (-) SEVERITY
28. 2409.5.3 57.59 41.46 21.91 2209130 '657.02 552.05 363.27 2.09 '
29 '~4~48.03 57.43 4~.5~t 38.50 2229.98 689.4~ 576.37 384.79 0.45 '
30 2479.71 5~.7.7 40.38 31.68 2246.96 7~6.21 596.57 4[~)2.:~2 3,27 '
31 2504.56 5~.3..0.. .39.61 24.8,.'.5 226b.~1 737.30 612.72 41'5.87 3.39 ,'
32 ~541.93 58.61 .39.21 37.37 227§.67 769.14 637.33 436.b9 i.23
33 2573.46 58.64 39.4,6. 31.53 2296;08 796.06 658.15 453.!5 0.6'8 '
34 25§8.4~ 58.66 ' 39,58 24.96 2309.07 817.38 674.59 ~,66.72 0.42
i , i [ · i .
35 2641.11 58.63 39.35 42.69 2331.28 853.83 702.74 489.89 0.47
36 2670.36 58.68 39.07 29.25 2346.50 878.81 722.09 505.68 0,84
37 2691.41 58.69 39.75 21.05 2357.44 896.80' '735.{)9 ' 517.10 2.76
38 . ~73.2.05 58.19 39.19 40.64 2378.71 931.43 ~62.72 539.11 1.70
39 2763.59 56.86 39.31 31.54 2395.64 958.03 783.33 555.95 4.23
40 2790.41 56.32 39.56 26.82 2410.41 960.42 800.62 570.17 2.16
41 . 2."8~5.47 56.32 39.63 35.06 2429.85 1009.60 823.10 588.76 0.17
42 2856.92 56.46 39.70 31.45 2447.26 1035.79 843.26 605.48 0.48
43 2883.67 56.55 39.6~ 26.75 2462.02 1058.10 860.43 619.72 0.35
44 2920.04 56.47 39.97 36.37 2482.09 1088.43 883.72 639.15 0.72
45 2951.53 56.33 39,.93 31.49 2499.52 1114.66 903.83 655.99 0.46
46 2978.13 56.28 40.41 26.60 2514.28 1136.79 920.74 670.27 1.51
47 3013.76 56.33 40.73 35.63 2534.04 1166.42 943.26 689.55 0.76
48 3046.06 56.3§ 40.40 32.30 2551.94 1193.31 963.69 707.03 0.87
,
49 3070.35 56.34 40.94 24.29 2565.39 1213.53 979.03 720.21 1.86
50 3165.11 56.02 41.16 94.76 2618.13 1292.23 1038.40 771.91 0.39
51 3232.43 56.24 41.52 67.32 2655.65 1348.10 1080.36 808.83 0.55
52 :~257.10 56.31 '41.61 24.67 2669.35 1368.60 1095.72 822.45 0.42
53 3326.06 56.39 41.79 68.96 2707.56 1425.96 1138.58 860.63 0.25
54 3355.19 56.29 42.05 29.13 2723.70 1450.19 1156.62 876.83 0.82
55 :~419.83 55.97 41.89 64.64 2759.73 1503.81 1196.52 912.73 0.54
UNOCAL
TBU M-4
STEELHEAD PLATFORM
SURVEY SUMMARY
Data from Schlumberger Anadrill
MEASURED HOLE COURSE VERTICAL COORDINATES DOGLEG
DEPTH ANGLE AZIMUTH LENGTH TVD SECTION N (+) or S (-) E (+) or W (-) SEVERITY
~6 3517.63 56.25 4.,2.31 97.80 2814126 15,84.91', 1256. ,76 967.15 0.46
57 "~554.29 56.41 42.47 36.66 283~.59 1615.38 1279,,29 9~,7,.7~, 0.57 '
58 3652.98 56.07 4!~72 98.69 2889.4, ~ 1697.~5 1340,17 1042.72 0.72 '
59 3748.95 56.62 42.31 95.97 ~2942.62 1'Z77.16 1399~52 1096.1'9 0.77 '
60 3843.39 57.36 41.97 94.44 2994.0.7 1856.27 1458.~5 ' 1!49'.33 0.84 '
61 3940.91. 57.49 ~t1'.38 97.52 3046.5~ 7 1938.39 1519163 1203.97. 0.53
62 4035.13 55.65 ~9.41 94.22 .,3.098.48 2017.00 1579.'.50 1254.~$ ' 2.62
-6-3.. 4!28.17 55.98 39.23 93.04 3150.76 2093.971' 1639.04 i303.70 0.39'
64 4215.86 56.32 39.50 87.69 3199.60 2166.79 i. 1695,34 1349.89 0.46
65 4315.71 54.42 38.99 99.85 3256.34 2248.9~ 1758,97 ' 1401.87 1.95
66 4402.43 54.07 38.90 86.72 3307.01 23!9,.~32 1813.70 1446.1i 0.41
67 4504.44 54.50 38.36 102.01 3366.56 2402.13 1878.40 1497.81 ' 0.60
68 4598.25 54.93 37.78 93.81 3420.75 ~478'.68 1938.69 1545.03 0.68
69 4693.16 54.74 40.44 94.91 3475.42 2~$6.26 1998.88 1593.96 2.30
70 4782.01 54.61 42.91 88.85 3526.80 262i~.69 2053.02 1642.16 2.27
7.! . 4875.46 54.89 43.11 93.45 3580.73 2704.86 2108.83 1694.21 0.35
72 4970.12 55.37 43.43 94.66 3634.85 2782.36 2165.38 1747.45 0.58
7.3 5..~)64..'14 55.45 43.52 94.02 3688.23 2859.58 2221.54 1800.70 0.12
'~4 5158.46 55.42 43.47 94.32 3741.74 2937.06 2277.89 1854.16 0.05
75 ~'252.41 55.70 43.19 93.95 3794.87 3014.37 2334.25 1907.33 0.39
76 ~346.69 55.89 42.27 94.28 3847.87 3092.22 2391.53 1960.24 0.83
,
~ 5447.53 55.99 42.21 100.84 3904.35 3175.67 2453.37 2016.39 0.11
78 5539.63 56.18 41.68 92.10 3955.74 3252.03 2510.22 2067.48 0.52
79 5634.38 56.09 41.46 94.75 4008.54 3330.65 2569.08 2119.69 0.21
80 5727.78 56.34 41 .~ ~ 93.40 4060.49 3408.23 2627.37 2170.93 0.34
81 5820.28 56.16 40.99 92.50 4111.90 3485.10 2685.33 2221.47 0.24
82 5915.44 56.21 41.23 95.16 4164.86 3564.13 2744.90 2273.45 0.22
83 6009.41 55.91 40.81 93.97 4217.33 3642.06 2803.72 2324.62 0.49
UNOCAL
TBU M-4
STEELHEAD PLATFORM
SURVEY SUMMARY
Data from' Schlumberger Anadrill
, 'MEASURED HOLE COURSE ~ VERTICAL COORDINATES. DOGLEG .
' '"DEPTH ' ANGLE' AZIMUTH. LENGTH T~D s'EcTI0,N N(+) ors (-) E (+) or W (.) SEVERITY
8~, ..... ,6.10.2.!.9' . , .$6.06,' 40,72 ' 92.78 426c~..23 3718.9,,5. 2861.97 2374.83 0.18
'~'. ..... ,6, i'96.2.5, 56.97, "40.~:1'''' '9~.'06''' ¢~2'1.'i"'2 3797.3,8' ' 2921.43 2426.00 0.97
~,'. '"~:~sS.s~"" ~Y'.~ '4~.2~ ,, ,:2.4~,' ~:~Y~'.~S '~s?s.'o~" 2,so.~24~s.,s o.~4
,~,,,'i'.'i'~'~,'.~'",.:",S~.,O~',"',"~,~.~',4, S'~.iOo. i ,4,4,~,4.,.'?,~"~,=~.'~., ~0=o.=~ =s~=.os 0.,~
88' ' 643,0,.0,0 5B.09' ' 41.14. 78.3t. ,~446,'11 399.4.83 3070.32 2555.80 0,00
DAli Y CHRONOL OG Y
TBU M-4
10-22-99:
10-23-99:
10-24-99:
10-25-99:
10-26-99:
10-27-99:
10-28-99:
10-29-99
10-30-99:
10-31-99:
Run in hole with cleanout assembly. Clean out casing to float shoe. Displace
hole with new mud. Ddll from 1473' to 1480'. Take leak-offtest. Pull out of
hole.
Pull out of hole to pickup new BHA. Work on repair of topdrive.
Run in hole with new BHA. Ddll ahead from 1480' to 2201' at report time.
Ddll ahead to casing point at 3615'. Circulating hole clean at report time.
Pull out of hole. Lay down BHA. Rig up to run 9 5/8" casing. Running 9 5/8"
casing at report time.
Run in hole with 9 5/8" casing. Circulate bottoms up. Rig up cementers. Pump
cement.
Test and work on BOPE. Repair topdrive. Pick up BHA No. 3 with 8.5" bit. Run
in hole.
Complete running in hole. Tag and drill cement. Ddll 20' of new formation and
take a leak-off test. Ddll from 3615 to 4390'. Currently repairing topddve at
report time.
Complete repairing topddve. Drill ahead from 4390' to 4674'. Top drive failed.
Make a short trip to the shoe to work on topddve repairs. Complete repairs and
run back in hole from the shoe. Ddll ahead from 4674' to 5120' at report time.
Drill ahead from 5120' to proposed total depth of 6290'. Decide to drill an
additional 70' to 6360'. Decide to ddit. an. additional 50' to 6410'. Then decide to
ddll an additional 20' to 6430'. Total depth is 6430':
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
1490' Tuffaceous Ciaystone = light gray to white; soft to very soft; dominantly
occurs gritty texture; moderately to poor cohesion and adhesion; white ash laminations
and occasional carbonaceous specks present throughout; slight to moderately calcareous.
1540' Sandstone/Sand = medium light gray to calcite matrix; subangular to
subrounded; moderately well sorted; medium gray to light brownish gray; clasts range in
size from very fine lower to fine upper; irregular to subblocky cuttings; friable to
moderately hard; varied grain support/sorted; composed 60-70% quartz, 20-30% chert,
10-20% igneous/meta/volcanic lithics; estimated fair visual porosity and permeability; no
oil indicators present.
1610' Coal = grayish black to black; generally Iow grade lignite; smooth to slightly
woody texture; moderately firm to firm; brittle to slight sectile tenacity; irregular, subblocky,
to platy cuttings; slight resinous luster; occasionally interbedded with carbonaceous shale.
1650' Sand = very light to light gray; 90% disaggregated grains, translucent;
dominantly pale white to light gray; upper fine to upper medium, occasional lower coarse;
locally moderate to well sorted; common moderately soluble tuffaceous clay matrix,
closely grading to a sandy claystone; mostly rounded; quartz to quartz arenite; no oil
indicators.
1675' Coal = black to brownish black to dusky brown; Iow to very Iow grading to
lignite; some pieces are closely gradational to carbonaceous shale with strong carbonized
wood zones; brittle; irregular fracture habit; subplaty elongated pieces; dull resinous luster;
smooth texture; irregular occasional planar structure.
1740' Tuffaceous Claystone = light gray to grayish brown to near bluish-greenish
gray; soft to rarely firm pieces; redeposited ash with various degree of reworking; common
visible glass shards; clayey to ashy slight glassy texture; dull to slight sparkly luster due to
embedded sand grains and carbonaceous material; occasional scattered tuff in sample.
1775' Sand = light gray with strong greenish gray hues; fine to medium; occasional
very fine silty size; occasional sparsely scattered lower coarse grains; moderate to well
sorted; tuff clayey matrix; subrounded to rounded; quartz and sublithic arenite in sample;
occasional greenish to grayish Iow grade greenstone metalithics; irregularly slightly
calcareous; common to abundant glass volcanic shards; occasional scattered tuff in
sample; no oil indicators.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
1820' Coal = grayish black to dusky brown; soft to slight firm; Iow grade lignite to
carbonized wood; brittle; irregular chunks to subplaty elongated pieces; carbonaceous
shale, firm to very firm; somewhat planar structure, occasionally subfissile; occasional
thin sandstone laminations.
1845' Tuff = equally reworked ash, clayey ash type; occasional fractured bentonitic
type; common carbonaceous laminations.
1900' Tuffaceous Claystone = light gray to medium light gray to white; very soft
to soft; gelatinous to slight chalky texture; common visible glass shards; cuttings are
dominantly amorphous lumps; occasional irregular to subblocky in more composed
samples; commonly embedded with fine to medium sand grains; slight to moderately
calcareous.
1960' Sand = light gray to medium light gray overall; individual grains are clear,
translucent, light gray to medium light gray, black, and occasional reddish orange; clasts
range in-size from fine grain upper to occasional bit broken pebbles; dominantly fine to
medium-grain; angular to subrounded; dominantly subangular to subrounded; moderately
sorted; sand is dominantly unconsolidated in sample; inferred variable grain
support/calcareous cement material; composed of 70-80% quartz, 10-20% grayish-black
chert fragments,. 10% igneous/metamorphic/lithic fragments (dominantly meta-greenstone
and occasional argillite); estimated fair to good visual porosity and permeability; no oil
indicators present.
2030' Sand/Conglomerate = light gray to medium light gray overall; clasts range
from fine grain upper to pebble size; dominantly fine to medium; subangular to
subrounded; moderately sorted; composed 80% quartz, 10% chert, 10%
igneous/metaJvolcanic iithic fragments; estimated fair to good visual porosity and
permeability; no oil indicators present.
2080' Tuffaceous Claystone = light gray to grayish brown to near bluish-greenish
texture; dull to slight sparkly luster; occasional scattered tuff in sample.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
2125' Sand = light to medium gray; fine grain upper to coarse grain; dominantly
fine to medium; subangular to subrounded; moderate sorting; 50% quartz, 30% chert,
20% lithics; no oil indicators.
2150' Tuffaceous Claystone = light gray to medium light gray to white; occasional
greenish-gray hues; very soft to soft; readily matrix for sand; clayey, ashy to slight gritty
texture; slight to moderately calcareous.
2200' Coal = black to brownish black to dusky brown; dominantly Iow grade lignite;
smooth gray; soft to rarely firm pieces; redeposited ash with various degrees of reworking;
common visible glass washes out in sample; dominantly acts as matrix shards; clayey to
ashy to slight glassy to slight woody texture; grading to carbonaceous shale in part; brittle
irregular fracture habit; subplaty to irregular to elongated pieces; dull to slight resinous
luster; irregular to occasional planar structure.
2275' Sand/Conglomerate = light gray to medium light gray to occasional light
brownish gray; clasts range in size from fine grain upper to-bit broken pebbles; dominantly
'~- fine to medium grain; subangular to subrounded; moderate to well sorted in part; sand is
dominantly unconsolidated in sample; dominantly calcareous clay matrix material;
composed of 50-60% quartz, 20-30% chert fragments, 10-30% igneous/meta/volcanic
lithic'fragments; estimated fair visual porosity and permeability; no oil indicators present.
2310' Tuffaceous Claystone = light gray to medium light gray; very soft to soft;
mushy, sticky pasty consistency; readily washes out in sample; soluble in water; clayey to
slight gritty texture; dominantly occurs in sample as amorphous lumps embedded with
sand; common white ash laminations and visible glass shards present throughout; slight to
moderately calcareous.
2410' Sand/Conglomerate = medium light gray to medium gray to light brownish
gray; individual clasts are light medium gray, medium gray, translucent, clear, black, and
reddish orange, clasts range in size from fine grain upper to pebble size; dominantly fine
to coarse; grain size increasing with depth; dominantly calcareous clay matrix; composed
50% quartz, 30-40% chert, 10-20% igneous/met/volcanic lithics including meta-
greenstone, argillite and jasper; estimated fair visual porosity and permeability; no oil
indicators present.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
2440' Coal = black to grayish black to dusky brown; firm to moderately hard; brittle
to slight sectile tenacity; lignite grade; smooth to crenulated texture; subblocky, elongated
wedgelike, and platy cuttings habit; earthy to subresinous luster; irregular to occasional
planar fracture; grading to carbonaceous shale in part.
2475' Sand/Conglomerate -- light gray to medium gray overall; clasts range from
fine to pebble size; subangular to subrounded; moderately sorting; composed 50-60%
quartz, 20-30% chert, 10-30% lithics; estimated fair visual porosity and permeability; no oil
indicators present.
2510' Coal = grayish black to black; firm to moderately hard; lignite grade; brittle;
smooth to slight woody texture; irregular, platy and subblocky cuttings; irregular to planar
fracture.
2570' Tuffaceous Claystone -- light gray to medium light gray with greenish-gray
hues; dominantly acts as matrix material for sand; amorphous to irregular cuttings; clayey,
ashy, gritty texture; poor to moderate cohesion and adhesion; very soluble; glass shards
visible; slight to moderately calcareous.
2590' ' Sand/Conglomerate -- light medium gray to medium gray overall; clasts
range from fine grain upper to bit broken pebbles; dominantly fine to coarse; subangular
to subrounded; moderate sorting; clay matrix support; dominantly unconsolidated in
sample; more composed fragments are easily friable; composed 50-60% quartz, 30-40%
chert; 10-20% igneous/meta/volcanic lithic fragments; estimated fair visual porosity and
permeability; no oil indicators
2640' Coal = black to dusky brown; very Iow to Iow grade of lignite; firm to
moderately hard cuttings; subplaty to subblocky cuttings habit; occasionally thin
sandstone laminations in coal; irregular to occasional planar fractures; dull resinous
luster; brittle; occasionally subfissile.
2700' Tuffaceous Claystone -- light gray to medium light gray with light brownish
and olive hues; soft to occasional slight firm; serves as matrix for embedded sandstone
grains; dominantly structureless; amorphous to occasional irregular cuttings habit; clayey;
ashy; dull earthy occasional slight sparkly luster due to scattered carbonaceous material
and sand grains; common ash laminations throughout sample; poor to moderate cohesion
and adhesion; very slightly to slightly calcareous.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
2770' 'Coal = grayish black to dusky brown; brittle; dense texture; subplaty to
occasional subblocky; dull resinous luster; common woody fragments in sample; Iow
grade of lignite with common carbonaceous laminations; occasional thin laminations of
sandstone on coal; irregular to occasional planar fracture habit; occasional slightly fissile;
smooth to very slight gritty texture.
2830' Sand/Conglomerate = light gray to medium light gray, greenish gray with
sand grains commonly translucent for finer clasts; clasts range from upper very fine to
medium and occasional coarse and lower pebble; occasional broken pebbles in sample;
poor to fair sorting; subangular to subrounded occasional rounded; non to slightly
calcareous; dominantly clayey tuffaceous matrix; no oil indicators.
2875' Tuffaceous Claystone = light brownish gray to brownish olive gray;
occasional strong secondary pale bluish gray hues; soft to occasional very slightly firm;
easily pulverized and hydrated; moderate solubility; dull to earthy luster to occasional
slight sparkly luster due to scattered carbonaceous material and sand grains;
structureless; amorphous to occasional irregular pieces; sand grains are commonly
. embedded in clayey matrix.
2940' Coal = dark grayish black to dusky brown; Iow grade of lignite; abundant
amount of carbonized wood, and carbonaceous material in sample; dull resinous luster;
irregular subplaty elongated and subblocky cuttings; irregular fracture habit; brittle;
occasionally subfissile.
3000' Sand/Conglomeratic Sand -- clear, light gray to medium gray with olive
hues, clear mostly for finer clasts; whitish-bluish and creamy for larger upper medium
to coarse clasts; clasts range from medium fine to coarse to bit-broken pebbles; fine to
coarse to bit-broken pebbles; both clayey ashy matrix and grain support; subrounded to
rounded; fair to good sorting; moderately-high sphericity (for sand); slightly calcareous.
3100' Tuffaceous Claystone = light brownish gray to medium gray with olive
hues; very soft to occasionally slightly firm; dull to earthy luster; scattered carbonaceous
material and ash throughout the sample; smooth to grainy texture; amorphous to
occasional irregular pieces; locally silty; scattered glass shards in sample; common black
mineral pinpoint inclusions; slight calcareous; scattered carbonaceous material in sample.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
3140' Coal = grayish black to dark brownish black; very Iow to Iow grade lignite;
brittle; smooth to slightly gritty text; irregular to occasional planar fracture habit; dull to
subresinous luster; overall firm to hard; some coal pieces have woody laminations and are
softer; occasional slightly fissile to subfissile.
3200' Sand/Conglomeratic Sand = consists of diverse lithic clasts, color from
light gray to medium-dark gray with olive hues, white, creamy, greenish gray and brown
red; entire range of roundness and shape in sand/conglomerate; finer clasts tend to be
rounder and clearer; larger clasts are creamier and more angular; bit impacted pebbles in
sample; both calcite matrix and grain support; consists mainly of quartz, clastic glass
shards and evenly distributed dark mafic minerals in matrix; good estimated visible
porosity and permeability; no oil individual; slightly calcareous to locally calcite; rare to
occasional white micaceous flakes in sample.
3250' Coal = brownish black to dusky brown; firm to occasional slightly soft;
mostly Iow grade of lignite; considerable amount of carbonized wood and woody
fragments (which tend to be softer); brittle; smooth to slightly gritty texture; irregular
subplaty elongated to subblocky pieces.
3300' Sand/Conglomeratic Sand = clear, translucent, light to medium gray,
greenish gray, brown red; dark gray;' upper fine to coarse to pebbles; quartz, feldspar,
volcanic metalithics, jasper, cherty fragments; moderately to well sorted; subangular-
subrounded.
3345' Coal = grayish black to black; irregular subblocky, platy and elongated
cuttings; planar to irregular fracture; Iow grade lignite grading to carbonaceous shale in
part; dull to slight resinous luster; smooth to slight crenulated surface texture.
3400' Sand/Conglomerate = light gray to medium gray to light brownish gray
overall; individual clasts are medium gray; light brownish gray; clear, translucent and
greenish-gray; clasts range from fine grain upper to bit broken pebble; angular to
subrounded; poor to moderate sorting; composed 40-50% quartz, 20-30% chert, 20-40%
igneous/meta/volcanic lithics; varied calcareous matrix and grain support; estimated fair
visible porosity and permeability; no oil indicators present.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
3450' Tuffaceous Claystone = light gray to medium light gray; very soft to soft;
poor to moderate cohesion and adhesion; clayey, ashy, to slight gritty texture; dominantly
occurs as a matrix material for sand; slight to moderately calcareous.
3510' Sand/Conglomerate = light gray to medium light gray to light brownish gray
overall; clasts range from fine upper to bit broken pebbles; dominantly medium to coarse;
subangular to subrounded; moderately sorted; slight to moderately calcareous due to
calcite cement; composed 50% quartz, 20-30% grayish-black chert, 20-30% lithics; no oil
indicators.
3540' Coal = grayish black to black to occasional dusky brown; irregular to
subblocky to subplaty cuttings; brittle to slight crumbly tenacity; Iow grade lignite grading
to carbonaceous shale in part; irregular to slight planar fracture.
3600' Tuffaceous Claystone = light to medium gray with occasional white to
grayish-green hues; very soluble in water; readily washes out in sample; dominantly
occurs in sample as a cement matrix for sand; very soft to soft; occasional slightly firm;
slight to moderately calcareous.'.
3640' Sand/Conglomerate = clear, light gray to translucent white, olive; greenish-
gray; upper fine to lower coarse, occasional pebble size conglomerate broken grains; fair
sorting; subangular to subrounded; clay matrix support; quartz and cherty fragments.
3750' Sand/Conglomerate = clear to light gray to greenish gray with occasional
olive hues; translucent white and creamy for larger clasts; clasts range from upper fine to
lower coarse; upper coarse to pebbles for conglomerate; poorly to moderately sorted; all
range of roundness and shape; finer sands tend to be better rounded; most sand grains
embedded into clayey matrix; consists mostly of quartz and rest is scattered cherty
fragments, feldspar and various metalithics.
3810' Tuffaceous Claystone = light brownish gray to greenish gray with olive
hues; very soft, structureless; amorphous; hydrophilic; poor to moderate cohesion
and adhesion; contains sand grains in its matrix; dull earthy luster to slight sparkly luster
due to scattered sand and glass shards and various carbonaceous material; slight to
locally moderate calcite.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
3840' Coal = dusky brown to brownish black; Iow grade lignite; occasional
carbonized wood in coal; irregular subblocky to elongated pieces; irregular fracture habit;
occasional slightly subfissile; brittle.
3920' Sand/Conglomerate = clear to light gray, medium dark gray, greenish gray
to black; occasional white creamy; clasts range from lower fine to medium to very coarse
subangular to subrounded; poorly to moderately sorted; slight to moderately calcareous
due to calcite cement; clay matrix also present; quartz and cherty fragments in sample.
3970' Tuffaceous Claystone = light to medium brownish gray with olive hues;
amorphous to occasional subblocky pieces; soft to very soft; acts as a matrix to sand; dull
to earthy luster; readily washes out in sample; slightly calcareous.
4000' Sand/Conglomeratic Sand = clear to light gray, greenish gray, light reddish
brown to dark gray, white creamy; clasts range from very fine to upper medium to coarse
to occasional lower pebble; subrounded to subangular to angular; moderately sorted; sand
in unconsolidated form and embedded in clayey matrix; scattered ash in sample;
dominantly quartz, feldspar and-cherty-fragments.
4030' Tuffaceous Claystone = light to medium brownish gray; soft to occasional
slight firm; massive; irregular subblocky pieces to amorphous almost structureless; gritty
to smooth texture; dull to earthy slight sparkling luster; acts as a matrix for embedded
sand grains and abundant carbonaceous material; slight calcareous to calcareous;
occasionally scattered glass shards in sample.
4100' Sand/Conglomerate -- light to medium gray to dark gray; greenish gray to
occasional light brownish red; olive gray; clasts range in color and size; size ranges from
upper very fine to upper medium for sand and up to very coarse in pebble for
conglomerate; poorly to occasional moderately sorted; angular to subrounded; Iow to
moderate sphericity; consists of 70% quartz and feldspar; 20% cherty fragments and 10%
various metalithics.
4140' Coal = dusky brown to dark brownish gray to black; brittle; irregular
fractures; subblocky occasional elongated pieces; smooth to slight gritty texture; thin
sandstone laminations.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
4270' Coal = grayish black to black to dusky brown; irregular to subblocky to
subplaty cuttings; dull to subresinous luster; firm to brittle tenacity; uneven to slight planar
fracture.
4325' Tuffaceous Claystone = light to medium brownish gray; soft to occasional
slight firm; amorphous to subblocky to irregular cuffings; smooth, clayey to slight gritty
texture; dull to earthy to slight sparkly luster due to embedded sand grains; common white
ash laminations and carbonaceous material; commonly occurs as a matrix for sand;
slightly to moderately calcareous; very calcareous in part.
4400' Tuffaceous Claystone = light to medium brownish gray, olive gray, light
greenish gray; soft to slightly firm; appears as amorphous lumps with occasional
subblocky pieces; almost structureless; acts as a matrix for finer sands; dull to earthy
luster; for finer sands; dull to earthy luster; slightly sparkly due to scattered carbonaceous
material and embedded sand grains; slightly calcareous to locally calcareous; common
white ash laminations in claystone.
· o .
4525' Sand/Conglomerate = wide range of colors and roundness in a sample
clasts: clear light gray to cream white fOr very fine to lower medium sand grains; medium
dark graY to black; bluish green, light brownish red,.'olive gray for coarse and pebble-size -.
cherty conglomerate-fragments; sample display also wide range of roundness-from
dominantly rounded to subrounded finer clasts to angular to subangular larger clasts
(coarse to pebble); Iow to moderate sphericity, occasional high sphericity (finer clasts);
poor to occasional moderately fair sorting; composed of quartz, feldspar and various clast
fragments, chert and various volcanic metalithics; scattered carbonaceous
material and occasionally volcanic ash in sample; calcareous; unconsolidated in sample;
insignificant amount of tuffaceous claystone matrix which holds sand grains; matrix and
gray support; calcite cement sand matrix present; considerable amount of sloughing coal
fragments (not fresh) in sample.
4595' Coal = brownish black to dusky brown to brown; firm; brittle; uneven to
occasional planar fractures; subblocky to elongated pieces; Iow grade of lignite; frequent
sandstone laminations on coal; carbonized wood laminations; occasional scat woody
fragments; subresinous to dull luster.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
4660' Conglomerate/Sand = clear to light gray to medium dark gray to blackish
brown, greenish gray to light brownish red, olive gray; clasts size ranges from upper very
fine to coarse and occasional pebbles; poorly to moderately sorted; dominantly Iow
sphericity subangular to subrounded to occasional rounded for finer clasts; calcite and
clay matrix; calcareous to very calcareous.
4685' Coal = dusky brown to grayish black to black; Iow grade lignite to carbonized
woody fragments; frequent sand laminations; brittle; uneven to irregular fracture habit;
subresinous dull luster; smooth to slight gritty texture.
4740' Tuffaceous Claystone = light brownish gray; soft to occasional slight firm;
amorphous; dominantly structureless; smooth to slight gritty texture; acts as sand matrix;
calcite.
4800' Sand/Conglomerate = clear to light gray to medium dark gray, greenish
gray with occasional olive hues; translucent creamy white and also black metalithics;
claSts size ranges from upper very fine to upper medium with occasional lower coarse and
rare 'very coarse and bit-broken pebbles; poorly to occasional, moderately fairly sorted; Iow
to moderate sphericity; composed mainly of quartz & feldspar, cherty conglomeratic
fragments and various volcanic metalithics in sample; common scattered volcanic ash
and tuff in sample; abundant carbonaceous material and washed-out coal fragments.
4850' Coal = brownish black to dusky brown; firm to slightly firm; Iow grade of
lignite; abundant woody fragments; common thin silty sand laminations on coal; irregular
to occasional planar fractures.
487,5' Sand/Conglomerate -- clear to light gray to medium dark gray; greenish-
gray to olive gray, black, light brownish red to green; clasts range from very fine to lower
-coarse; entire range of roundness and shape; dominantly Iow to moderate sphericity; very
calcareous; calcite cement; both grain and clay matrix support.
4930' Tuffaceous claystone = light to medium brownish gray; olive gray to green;
soft to slightly firm; irregular subblocky pieces to amorphous; acts as a matrix for
embedded sand grains and pinpoint black mineral inclusions and glass shards;
moderately calcareous.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
4975' Sand/Conglomerate = wide range of color and shape; light gray to medium
dark gray~ greenish gray, brownish red, green, occasional blackish brown; very fine to
lower coarse embedded in clay matrix; Iow sphericity; poorly sorted; quartz, feldspar,
cherty fragments and various volcanic metalithics in sample; occasional to scattered ash;
calcareous to locally very calcareous.
5020' Tuffaceous Claystone = light brownish gray to medium gray with frequent
olive to bluish hues; appears as amorphous mass with rare subblocky irregular pieces;
acts as clay matrix for embedded sand; abundant sloughing coal and carbonaceous
material in sample; slight to moderately calcite; dull earthy luster.
5050' Coal = black to brownish black, dusky brown to grayish black; firm to
moderately firm; appears as subblocky to subplaty to irregular elongated pieces; irregular
to occasional slight planar fracture habit; fresh resinous luster; frequent sandstone
laminations; occasional woody fragments in coal, which is continued to be a Iow grading of
lignite abundant carbonaceous material in sample.
5135' Sand = clear to light gray; very fine to medium; poor to fair sorting;
subangular to subrounded; some grains are. pitted; Iow to occasional moderately
sphericity; calcareous; embedded in clay matrix; quartz and feldspar, occasional light
brownish red jasper; rare to occasional greenish minerals-epidote, greenstone in sample.
5175' Tuffaceous Claystone = light to medium brownish gray; olive gray to
greenish; soft to slight firm; commonly appears as amorphous lumps that hold sand in it's
matrix; occasional small subblocky pieces; dull earthy luster; dull earthy luster; scattered
carbonaceous material and volcanic ash in sample.
5210' Coal = black to dusky brown; firm to moderately firm; Iow grade of lignite;
common frequent semi-carbonized woody laminations; occasional thin silty laminations of
sand on coal; dull subresinous luster; fresh irregular to uneven fractures; brittle;
occasionally slightly subfissile.
5260' Sand = clear to light gray to white cream, occasional greenish gray and dark
gray; medium very fine to medium, occasional lower coarse usually translucent white to
creamy white angular fragments; finer-grained sand tend to be better rounded; subangular
to subrounded overall; dominantly clay matrix support; overall increase in clay content;
calcareous to locally very calcite; moderate sphericity.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
5325' Tuffaceous Claystone = light to medium gray to brownish-olive gray; soft to
occasional slightly firm; appears as irregular mushy lumps; amorphous, structureless;
dull earthy luster; scattered glass shards; scattered carbonaceous material; locally slightly
calcareous to calcite.
5355' Coal = grayish black to dusky brown; firm to moderately firm; very brittle;
uneven to conchoidal fracture habit; resinous dull luster; Iow grade of lignite; occasional
silty laminations; woody fragments.
5400' Tuff = grayish white; represents the least reworked, least disturbed section
of claystone; airfall deposition with no redistribution with water; very soft; ashy texture; dull
to slight glassy luster.
5435' Coal = grayish black to dusky brown; subblocky to subplaty irregular
cuffings; very brittle; irregular to occasional conchoidal fracture habit; frequent thin silty
laminations; scat ash in sample; occasional scattered woody fragments in overall lignite.
5460' Tuffaceous Claystone = light to medium brownish gray; soft to slightly firm;
irregular cuttings habit to amorphous; acts as matrix for finer sands; common silty
laminations; dull earthy luster; slight calcite to locally calcareous.
5500' 'Sand/Sandstone = light gray to creamy white occasional translucent white;
upper very fine sorting; subrounded to subangular; moderately sphericity; silty in part;
commonly embedded into clay ashy matrix; locally slightly calcareous.
5540' Coal = black to blackish brown to dusky brown; very brittle; very Iow grade of
lignite with frequent woody laminations; common thin silty laminations; irregular to
occasional conchoidai fracture habit.
5575' Tuff = light gray to bluish gray; white; least disturbed end fraction of tuff.
claystone; ashy-clayey texture; very soft to soft; appears as hydrophilic mushy lumps.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
5610' Coal = blackish brown to dusky brown to black; firm; irregular to subblocky
pieces; brittle; irregular to occasional conchoidal fracture habit; closely gradational to
carbonaceous shale; lignite with frequent carbonized woody laminations; dull subresinous
luster; occasional silty sandstone laminations.
5650' Tuffaceous Claystone = light to medium brownish gray, light greenish gray
with olive hues; soft to firm; dull to earthy luster; occasional blocky to subblocky habit
dominantly amorphous lumps; structureless; smooth to slightly gritty texture; occasional
visible glass shards scattered in sample; common scattered carbonaceous specks; acts
as a matrix for embedded sandstone; occasional silty laminations; ash in sample.
5700' Tuff = light creamy gray to creamy white; equally reworked, least disturbed
end fraction of tuffaceous claystone; soft ashy texture; sparkly to particulate glassy luster;
abundant visible glass shards.
5730' Tuffaceous Claystone -- light to medium gray with olive-light brownish
hues; soft to firm; appears as massive irregular shaped subblocky to subplaty; smooth
'to scattered; commonly carbonaceous specks embedded in claystone; slight calcareous
to locally calcareous;, locally silty; abundant sand grains embedded in clay
matrix.
5790' Coal = grayish black to dusky brown; frequent carbonized woody fabric; firm
to conchoidal and planar fracture habit; commonly slight subfissile; dull earthy vitreous to
subresinous luster.
5865' Sand/Sandstone = light gray to occasional clear and creamy white; silt to
fine to occasional lower medium; poorly to moderately sorted; moderate sphericity;
angular to subrounded; mixed clay matrix and grain supported, roughly equal fractions
of each with grain support shows moderate to occasional good porosity.
5900' Sand/Sandstone = light gray to clear to bluish white; fine to upper medium;
moderately sorted; Iow to moderate sphericity; angular to subangular to occasionally
subrounded; mixed clay matrix and grain supported; scattered carbonaceous
specks throughout the sample.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
6005' Coal = grayish black to black, dusky brown; moderately firm to firm subplaty
to subblocky cuffings; Iow grade of lignite with occasional visible woody carbonized
laminations in coal; common silty laminations on coal; brittle to slightly fissile; fracture
habit from irregular to occasionally conchoidal and uneven.
6040' Tuffaceous Claystone = light to medium brownish gray; olive brownish gray
to light greenish gray; soft to slight firm; few irregular subblocky pieces, mostly appears as
amorphous lumps, acts as a matrix for sands; abundant carbonaceous material scattered;
occasional to common ashy clay fragments.
6100' Sand/Conglomerate -- clear to light gray, medium dark gray to olive gray,
light brownish red, bluish green; clasts range from fine to medium for sand, and up to
pebbles and coarse occasional bit impacted conglomerate; moderately to occasional well
sorted; entire range of roundness and shape; Iow to moderately sphericity; rare
to occasional white micaceous flakes scattered.
6150' Tuffaceous Claystone = light brown to light brownish gray to occasional
olive gray; soft to slightly firm; brittle when dry; very few small subblocky cuttings, mainly
appears as amorphous lumps which contain clasts of very fine to lower medium sands;
Smooth to slightly gritty text; dull earthy luster to occasionally slightly sparkling luster due
to continued scattered carbonaceous specks/carbonaceous material in sample.
6200' Sand/Conglomerate = clear to light gray to medium dark gray, olive gray,
black, whitish pink, light brownish red and greenish gray to green; clasts size ranges from
very fine to upper coarse and pebbles, occasional broken by bit cobble fragments; entire
range of roundness and shape; dominantly subangular to subrounded; both grain and clay
matrix support is present; sand grains are embedded in amorphous clay lumps; composed
of mainly quartz, feldspar, chert & cherty fragments, and various metalithics, also
greenstone, epidote and rare jasper.
6305' Coal -- dark blackish gray to black, occasional dusky brown; irregular chunky
subblocky rare subplaty elongated pieces; brittle to very brittle; Iow grade of lignite with
very few pieces having carbonized woody laminations; dull resinous to dominantly shiny
subresinous luster; common irregular fractures to uneven conchoidal fractures on edges.
UNOCAL - TBU M-4
LITHOLOGY SUMMARY
6390' Sand/Sandstone/Conglomeratic Sand = clear to light gray, dark gray-
black, g~een gray, red; very fine-medium, coarse-pebble chert conglomerate; poorly to
moderately sorted; both grain and clay matrix support, also calcite cement, calcareous,
locally very calcite; quartz, feldspar, chert, jasper, occasional greenstone veins.
JNOCAL
TBU M-4
Date: 10122/99
Time: 5:00 AM
MORNING REPORT
DEPTH: 1,480' Yesterday: 1,473'
REMARKS:
MAX GAS OBSERVED WHILE CIRCULATING ABOVE SHOE WAS 330 UNITS.
24 Hour Pm~lress:
BIT INFORMATION:
No. Size Type SIN Jets
Interval
Footage
Hours Condition
High
Rate of Penetration 10 at 1,474'
Surface Torque N/A at N/A
Weight on Bit 6 at 1,478'
Bit RPM NIA at N/A
Pump Pressure N/A at N/A
Low
5 at 1,479'
N/A at NIA
4 at 1,475'
N/A at NIA
N/A at N/A
Average
7
N/A
5
NIA
N/A
~Jhr
amps
RPM
DRILLING MUD REPORT:
MW VIS
9.1 46
GAS SUMMARY: High Low
Total Ditch Gas Out: 40 at 1,479' 31 at 1,475'
Methane (C-1) 3,441 at 1,479' 2,670 at 1,475'
..~'"'Ethane (C-2) 0 at N/A 0 at N/A
~ropane (C-3) 0 at N/A 0 at N/A
Butane (C-4) 0 at N/A 0 at N/A
Pentane (C-5) 0 at N/A 0 at NIA
Background Gas: units Trip Gas: N/A units
Connection Gas: N/A units (ave) 0 units (max) Wiper Gas: N/A units
Average
34 units
2,955 ppm
0 ppm
0ppm
0ppm
0 ppm
HYDROCARBON SHOWS:
NONE
LITHOLOGY:
70% TUFFACEOUS CLAYSTONE, 30% SANDSTONE ~ 1480'.
DAILY ACTIVITY SUMMARY:
RIH W/CLEANOUT ASSEMBLY, CLEAN OUT CASING TO FLOAT SHOE, DISPLACE HOLE TO NEW MUD, DRILL TO 1480', DO
LEAK-OFF TEST, POOH.
Epoch Personnel on site: 2
"Report By: RICH SWANSON
Daily cost: $1395.00
Cumulative cost: $4185.00
UNOCAL
TBU M-4
Date: 10123199
Time: 5:00 AM
DEPTH: 1480'
REMARKS:
Yesterday: 1480'
MORNING REPORT
24 Hour Progress: 0'
BIT INFORMATION:
No. Size Type
2 12.25" STC
SIN Jets
LK4636 2x15,1x16,1x13
Interval
148~
Footage
0'
Hours Condition
0
Rate of Penetration
Surface Torque
Weight on Bit
Bit RPM
Pump Pressure
High
10 at 1,474'
N/A at N/A
6 at 1,478'
N/A at NIA
N/A at N/A
Low
5 at 1,479'
N/A at NIA
4 at 1,475'
NIA at NIA
NIA at NIA
Average
7 ft/hr
NIA amps
5 Klbs
NIA RPM
NIA psi
DRILLING MUD REPORT:
MVV VIS
9.1 46
GAS SUMMARY: High Low
Total Ditch Gas Out: 40 at 1,479' 31 at 1,475'
'Methane .(C-1) 3,441 at 1,479' 2,670 at 1,475'
."~'~hane (C-2) 0 at N/A 0 at NIA
mpane (C-3) 0 at N/A 0 at N/A
Butane (C-4) 0 at NIA 0 at NIA
Pentane (C-b') 0 at NIA 0 at N/A
Background Gas: units
Connection Gas: NIA units (ave) 0 units (max)
Trip Gas:
Wiper Gas:
NIA units(~
NIA units~
Average
34 units
2,955 ppm
0 ppm
0 ppm
0 ppm
0 ppm
HYDROCARBON SHOWS:
NONE
LITHOLOGY:
DALLY ACTIVITY SUMMARY:
POOH TO PICKUP NEW BI-IA. WORK ON TOPDRIVE REPAIRS.
Epoch Personnel on site: 2
~'~Report By: RICH SWANSON
Daily cost: $1395.00
Cumulative cost: $6975.00
.~NOCAL
TBU M-4
Date: 10124/99
Time: 5:00 AM
DEPTH: 2,201'
Yesterday: %480'
REMARKS:
MORNING REPORT
24 Hour Progress: 721'
BIT INFORMATION:
No. Size Type
2 12.25" STC
SIN
LK4636
Jets
2x15,1x16,1x13
Interval Footage Hours
1480'-2201' 721' 10.56
Condition
IN HOLE
Rate of Penetration
Surface Torque
Weight on Bit
Bit RPM
Pump Pressure
599
NIA
32
N/A
N/A
High
at
at
at
at
at
2,178'
NIA
1,512'
N/A
N/A
Low
6 at 1,483'
NIA at N/A
I at 1,515'
N/A at NIA
N/A at N/A
Average
87
N/A
16
N/A
N/A
ftJhr
amps
RPM
ps~
DRILLING MUD REPORT:
MW VIS
9.2+ 46
GAS SUMMARY: High Low
Total Ditch Gas Out: 416 at 1,790'
~..~,Methane (C-1) 46,666 at 1,790'
[thane (C-2) 0 at NIA
Propane (C-3) 0 at NIA
Butane (C-4) 0 at N/A
Pentane (C-5) 0 at N/A
Background Gas: 95-105 units
Connection Gas: NIA units (ave) 0 units (max)
5 at 1,735'
603 at 1,735'
0 at NIA
0 at N/A
0 at NIA
0 at NIA
Trip Gas: NIA
Wiper Gas: NIA
units
units
Average
100 units
14,887 ppm
0pprn
0ppm
0ppm
0 ppm
HYDROCARBON SHOWS:
NONE
UTHOLOGY:
30% TUFFACEOUS CLAYSTONE, 60% SAND, 10% CONGLOMERATE ~ 2200'.
DAILY ACTIVITY SUMMARY:
DRILL FROM 1480' TO 2201', CURRENTLY DRILLING AHEAD.
Epoch Personnel on site: 2
Report By: RICH SWANSON
Daily cost: $1395.00
Cumulative cost: $6975.00
dNOCAL
TBU M-4
Date: 10/25/99
Time: 5:00 AM
DEPTH: 3,615'
Yesterday: 2,201'
REMARKS:
MORNING REPORT
24 Hour Progress: 1,414'
BIT INFORMAT,'ON:
No. Size Type
2 12.25" STC
SIN
LK4636
Jets Interval Footage Hours
2x15,1x16,1x13 1480'-3615, 2,135, 22.84
Condition
IN HOLE
Rate of Penetration
Surface Torque
Weight on Bit
Bit RPM
Pump Pressure
336
N!A
62
NIA
N/A
High
at
at
at
at
at
2,934'
N./A
2,666'
N/A
N/A
Low
13 at 3,138'
N!A at N/A
1 at 3,162'
NIA at N/A
N/A at N/A
Average
131
N!A
22
N/A
NIA
ft/hr
amps
RPM
ps~
DRILLING MUD REPORT:
MW VIS
9.6 46
GAS S UMt-,'-~RY: High Low
Total Ditch Gas Out: 5,014 at 2,736' 10 at 2,736'
/--".Methane (C-1) 10000000 at 2,736' 2,071 at 3,587'
~thane (C-2) 0 at NIA 0 at NiA
Propane (C-3) 0 at N/A 0 at NIA
Butane (C-4) 0 at NIA 0 at N/A
Pentane (C-5) 0 at NIA 0 at NIA
Background Gas: 220-250 units Trip Gas: N/A
Connection Gas: NiA units (ave) 0 units (max) Wiper Gas; NIA
units
units
Averagc
259 units
47,473 ppm
0ppm
0pprn
0ppm
0 ppm
HYDROCARBON SHOWS:
NONE
LITHOLOGY:
90% TUFFACEOUS CLAYSTONE, 10% SAND ~ 3615'
DAILY ACTIVITY SUMMARY:
DRILL TO AND REACH CASING POINT ~ 3615' MD, CURRENTLY CIRCULATING HOLE CLEAN.
Epoch Personnel on site: 2 Daily cost: $1395.00
Report By: RICH SWANSON Cumulative cost: $8370.00
.-
...'
-dNOCAL
TBU M-4
Date: 10126199
Time: 5:00 AM
MORNING REPORT
DEPTH: 3,615'
Yesterday: 3,615'
REMARKS:
MAX GAS OBSERVED WHILE CBU WAS 1224 UNITS
24 Hour Progress: O'
BIT INFORMATION:
No. Size Type
2 12.25" STC
SiN Jets inte~wai
LK4636 2xl 5,1x16,1x13 1480'-3615'
Footage
2,135'
Hours Condition
22.84 OUT
Rate of Penetration
Surface Torque
Weight on Bit
Bit RPM
Pump Pressure
High
0 at N/A
N/A at N!A
0 at N/A
N/A at N/A
N/A at N/A
Low
0 at N/A
NIA at
0 at NIA
NIA at NIA
N/A at N/A
Average
0 fi/hr
N/A amps
0 mbs
N/A RPM
NIA psi
DRILLING rvIUD REPORT:
MW VIS
9.75 46
GAS SUMMARY:
Total Ditch Gas Out:
Methane (C-1) ·
'~'""Ethane (C-2)
Propane (C-3)
Butane (C-4)
Pent,~ane (C-5)
Background Gas:
Connection Gas:
N/A units
N/A units (ave)
High
0 at N/A
0 at NIA
0 at NiA
0 at N/A
0 at N/A
0 at NIA
0 units (max')
Low
0 at NIA
0 at N/A
0 at N/A
0 at NIA
0 at N/A
0 at NIA
Trip Gas:
Wiper Gas;
N/A units
N/A units
Avorag(~
0 units
0 ppm
0 ppm
Oppm
0ppm
0 ppm
HYDROCARBON SHOWS:
NONE
LITHOLOGY:
NO NEW FORMATION DRILLED
DAILY ACTIVITY SUMMARY:
RUNNING 9 5!8" CASING IN HOLE AT REPORTTIME.
Epoch Personnel on site: 2
Report By: RICH SWANSON
Daily cost: $1395.00
Cumulative cost: $9765.00
0NOCAL
TBU M-.4
Date: 10127199
Time: 5:00 AM
DEPTH: 3,615'
Yesterday: 3,615'
REMARKS:
MAX GAS OBSERVED WHILE CBU WAS 624 UNITS
MORNING REPORT
24 Hour Progress: 0'
BIT INFORMATION:
No. Size Type
2 12.25" STC
SIN Jets Interval
LK4636 2x15,1x16,1x13 1480'-3515'
Footage
2,135'
Hours Condition
22.84 OUT
Rate of Penetration
Surface Torque
Weight on Bit
Bit RPM
Pump Pressure
High
0 at N/A
NiA at N/A
0 at N/A
NIA at NIA
N/A at N/A
Low
0 at N/A
NiA at N/A
0 at NIA
N/A at NIA
N/A at N/A
Average
0 fi/hr
NiA amps
0 KJbs
NIA RPM
N/A psi
DRILLING MUD REPORT:
MW VIS
9.75 46
GAS SUMMARY: High Low
Total Ditch Gas Out: 0 at N/A 0 at N/A
-' Methane(C-I) 0 at NIA 0- at N/A
.-~--"~=_thane (C-2) 0 at NIA 0 at N/A
Propane (C-3) 0 at N/A 0 at N/A
Butane (C-4) 0 at N/A 0 at NIA
Pentane (C-5) 0 at NIA 0 at NIA
Background Gas: N/A units
Connection Gas: N/A units (ave) 0 units (max)
Trip Gas:
Wiper Gas:
N/A units
N/A units
Average
0 units
0 ppm
0 ppm
0ppm
0ppm
0pprn
HYDROCARBON SHOWS:
NONE
UTHOLOGY:
NO NEW FORMATION DRILLED
DALLY ACTIVITY SUMMARY:
RIH W/9 518" CASING, CIRCULATE BO'I-rOMS UP, PUMP CEMENT,-
/~,~Epoch Personnel on site: 2
Report By: RICH SWANSON
Daily cost: $1395.00
Cumulative cost: $11160.00
,JNOCAL
TBU M-4
Date: 10128199
Time: 5:00 AM
DEPTH: 3,615'
REMARKS:
Yesterday: 3,615'
MORNING REPORT
24 Hour Progress: 0'
BiT INFORMATiON:
No. Size Type
3 8.5" 'STC
2 12.25" STC
SIN Jets Interval
JR6916 4x11, 4x12 3615'-
LK4636 2x15,1x16,1x13 1480'-3615'
Footage
0'
2,135'
Hours Condition
0 RIH
22.84 OUT
Rate of Penetration
Surface Torque
Weight on Bit
Bit RPM
Pump Pressure
High
0 at N/A
NiA at NiA
0 at NIA
N/A at N/A
N/A et N/A
Low
0 at N/A
NiA at NiA
0 at NIA
N/A at NIA
N/A at N/A
Average
0 ft/hr
NiA amps
0 i~bs
N/A RPM
N/A psi
DRILLING MUD REPORT:
MW VIS
9.8 40
GAS SUMMARY: High Low
Total Ditch Gas Out: 0 at N/A 0 at N/A
Methane (C-1) .0 at N/A 0 at N/A
· "'"";.thane (C-2) 0 at N/A 0 at N/A
Propane (C-3) 0 at N/A 0 at NIA
Butane (C-4) 0 at N/A 0 at N/A
Pentane (C-5) 0 at N/A 0 at NIA
Background Gas: N/A units Trip Gas:
Connection Gas: NIA units (ave) 0 units (max) Wiper Gas:
N/A units
NIA units
Average
0 units
0ppm
0ppm
0ppm
0pprn
0ppm
HYDROCARBON SHOWS:
NONE
UTHOLOGY:
NO NEW FORMATiON DRILLED
DALLY ACTIVITY SUMMARY:
TEST AND WORKON BOPS, WORK ON TOP DRIVE, PICK-UP 8.5" BIT, PICK-UP BHA #3, RIH.
~.,Epoch Personnel on site: 2
Report By: RICH SWANSON
Daily cost: $1395.00
Cumulative cost: $12555.00
,~NOCAL
TBU M-4
Date: 10129199
Time: 5:00 AM
DEPTH: 4,390'
REMARKS:
Yesterday: 3,615'
MORNING REPORT
24 Hour Progress: 775'
BIT INFORMATION:
No. Size Type
3 8.5" STC
2 12.25" STC
SIN
JR6916
LK4636
Jets Interval Footage Hours Condition
4x'11, 4x12 3615'-4390' 775' 5.51 IN HOLE
2x15,1x16,1x13 1480'-3615' 2,135' 22.84 OUT
Rate of Penetration
Surface Torque
Weight on Bit
Bit RPM
Pump Pressure
High Low Average
599 at 3,714' 15 at 3,616' 207 fi/hr
N/A at N/A N/A at N/A N/A amps
27 at 3,616' 3 at 4,299' 6 Klbs
NIA at NIA NIA at NIA NIA RPM
N/A at NIA NIA at NIA NIA psi
DRILLING MUD REPORT:
MW VIS
9.8 40
GAS SUMMARY:
Total Ditch Gas Out:
Methane (C--1).
'"~"~'thane (C-2)
?mpane (C-3)
Butane (C-4)
Pentane (C-5)
High Low Average
710 at 4,137' 0 at 4160'-4390' 66 units
86,355 at 4,137' 0 at 4160'-4390' 6,992 ppm
0 at N/A 0 at N/A 0 ppm
0 at NIA 0 at NIA 0 ppm
0 at N/A 0 at NIA 0 ppm
0 at NIA 0 at NIA 0 ppm
Background Gas: 75-100 units Trip Gas: N/A units
Connection Gas: N/A units (ave) 0 units (max) Wiper Gas: N/A units
HYDROCARBON SHOWS:
NONE
MTHOLOGY:
40% TUFFACEOUS CLAYSTONE, 40% SAND, 20% CONGLOMERATE ~ 4390'
DAILY ACTIVITY SUMMARY:
RIH, TAG AND DRILL CEMENT AND 20' RAT HOLE, DO LEAK OFF TEST, DRILL FROM 3615'-4390', CURRENTLY WORKING ON TOP DRIVE,
~..,,Epoch Personnel on site: 2
Report By: RICH SWANSON
'Daily cos{: $1395.00
Cumulative cost: $13950.00
UNOCAL
TBU M-4
Date: 10130199
Time: 5:00 AM
DEPTH: 5,120'
Yesterday: 4,390'
MORNING REPORT
24 Hour Progress: 730.
BIT INFORMATION:
No. Size Type
3 8.5" STC
2 12.25" STC
SIN
JR6916
LK4636
Jets
4x11, 4x12
2x15,1x16,1x13
Interval Footage Hours
3615'-5120' 1507 11.35
1480'-3615' 2,135' 22.84
Condition
IN HOLE
OUT
Rate of Penetration
Surface Torque
Weight on Bit
Bit RPM
Pump Pressure
456
NIA
58
N/A
N/A
High
at
at
at
at
at
4,694'
NiA
4,391'
NIA
NIA
Low
7 at 4,397'
NiA at NiA
0 at 4,404'
N/A at N/A
N/A at N/A
Average
466
NiA
13
N/A
NIA
f'fJhr
amps
RPM
psi.
DRILLING MUD REPORT:
MW VIS
9.2 50
GAS SUMMARY: High Low Average
Total Ditch Gas Out: 262 at 4,502' 0 at 4,390' 77 units
Methane (C-1): 111,023 at 4,598' 0 at 4,978' 8,188 ppm
~'~-'"Ethane (C-2) 0 at NIA 0 at N/A 0 ppm
Propane (C-3) 0 at N/A 0 at N/A 0 ppm
Butane (C-4) 0 at N/A 0 at N/A 0 ppm
Pentane (C-5) 0 at N/A 0 at N/A 0 ppm
Background Gas: 75-100 units Trip Gas: 805 units ~ 4,674'
Connection Gas: N/A units (ave) 0 units (max) Wiper Gas: N/A units ~
HYDROCARBON SHOWS:
NONE
UTHOLOGY:
40% TUFFACEOUS CLAYSTONE, 40% SAND, 20% CONGLOMERATE ~ 5050.
ABUNDANT SLOUGHING COAL IN SAMPLES
DAILY ACTIVITY SUMMARY:
WORKING ON TOP DRIVE, DRILL FROM 4390' TO 4674', TOP DRIVE FAILED; SHORT TRIP TO SHOE WHILE WORKING ON THE TOP DRIVE;
DRILL FROM 4674 TO 5120' (5 AM DEPTH), CURRENTLY DRILLING
l~Poch Personnel on site: 1
Report By: ARTEM RATCHKOVSKI
Daily cost: $1395.00
Cumulative cost: $15345.00
.,NOCAL
TBU M-4
Date: 10/31199
Time: 5:00 AM
DEPTH: 6,290'
Yesterday: 5,120'
REMARKS:
MORNING REPORT
24 Hour Progress: 1,170'
BIT INFORMATION:
No. Size Type
3 8.5" STC
2 12.25" STC
SIN
JR6916
LK4636
Jets
4x11,4x12
2x15,1x16,1x13
Interval Footage Hours
3615'-6290' 2675 25
1480'-3615' 2,135' 22.84
Condition
IN HOLE
OUT
Rate of Penetration
Surface Torque
Weight on Bit
Bit RPM
Pump Pressure
423
NiA
3O
N/A
N/A
High
at
at
at
at
at
NIA
5,903'
NIA
N/A
Low
11 at 6,267'
NiA at NiA
0 at 6,279'
NIA at NIA
N/A at N/A
Average
121
NiA
6
NIA
N/A
ftJhr
amps
RPM
psi
DRILLING MUD REPORT:
MW VIS
9.4 50
GAS SUMMARY: High Low
Total Ditch Gas Out: 1,729 at 6,010'
Methane (C-1) 222,724 at 6,015'
../-'-~.thane (C-2) 144 at 5,352'
· Jropane (C-3) 0 at N/A
Butane (C-4) 0 at N/A
Pentane (C-5) 0 at N/A
7 at 6,151'
0 at 5,235'
0 at 6,290'
0 at NIA
0 at N/A
0 at NIA
Background Gas: 25-50 units Tdp Gas:
Connection Gas: NIA units (ave), 0 units (max) Wiper Gas:
150
NIA
units
units
6,290'
Average
191 units
20,877 ppm
2ppm
0ppm
0ppm
0 ppm
HYDROCARBON SHOWS:
NONE
UTHOLOGY:
30% TUFFACEOUS CLAYSTONE, 40% SAND & SANDSTONE, 30% CONGLOMERATE ~ 6430'
DAJLY ACTIVITY SUMMARY:
DRILL TO TD ~ 6290' AT 2:10 AM 10/31/99.
.~.,~ Epoch Personnel on site: 1
'Report By: ARTEM RATCHKOVSKI
Daily cost: $i395.00
Cumulative cost: $16740
~NOCAL
TBU M-4
Date: 11/01199
Time: 5:00 AM
MORNING REPORT
DEPTH: 6,430'
REMARKS:
Yesterday: 6,290'
24 Hour Pm~lress:
140'
BIT iNFORMATiON:
No. Size Type
3 8.5" STC
2 12.25" STC
S/N
JR6916
LK4636 .
Jets
4xl 1, 4x12
2x15,1x16,1x13
Interval
3615'-5120'
1480'-3615'
Footage
2815'
2,135'
Hours
25.3
22,84
Condition
OUT
OUT
Rate of Penetration
Surface Torque
Weight on Bit
Bit RPM
Pump Pressure
194
NiA
17
N/A
N/A
High
at
at
at
at
at
6,334'
NIA
6,404'
N/A
NIA
22
NiA
0
NIA
NIA
Low
6,359'
NiA
6,361'
N/A
N/A
Average
95
NiA
1
N/A
N/A
ft/hr
amps
RPM
ps~
DRILLING MUD REPORT:
MW VIS
9.4 50
GAS SUMMARY: High Low
Total Ditch Gas Out: '164 at 6,407' 8
,/~,,,.M. tethane (C,1) 26,603 at 6,407' _ 1,226
bane (C-2) 0 at N/A 0
?mpane (C-3) 0 at NIA 0
Butane (C-4) 0 at NIA 0
Pentane (C-5) 0 at NIA 0
Background Gas: 25-50 units Trip Gas:
Connection Gas: N/A units (ave) 0 units (max) Wiper Gas:
6,409'
6,409'
NIA
N/A
NIA
N/A
150
NIA
units
units
6,290'
Average
33 units
4,649 ppm
ppm
0pprn
0ppm
0 ppm
HYDROCARBON SHOWS:
NONE
UTHOLOGY:
30% TUFFACEOUS CLAYSTONE, 40% SAND & SANDSTONE, 30% CONGLOMERATE ~ 6430'
DAILY ACTIVITY SUMMARY:
DECIDE TO DRILL 70' MORE, DRILL TO 6360', DECIDE TO DRILL 50' MORE, DRILL TO P=41O',
DECIDE TO GO 20' MORE, DRILL TO 6430', REACHED TD AT 6:45PM 10/31/99
Epoch Personnel on site: 2
Report By: ARTEM RATCHKOVSKI
Daily cost: $1395.00
Cumulative cost: $18135
