Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout169-034
Marathon
MpM ®Alaska Production LLC
May 28, 2010
!~=,~> ..
RECEIVED
.JUN 0 2 2i11ti
Daniel T. Seamount, Jr., Commission Chair Alaska 0~ Stu Coats. Commission,
Alaska Oil & Gas Conservation Commission An~her~ge
Attn: Jim Regg
333 W. 7th Avenue, Suite 100 S ~~- ~
Anchorage, AK 99501
~~d t`~
Reference: Report on Disposal Injection Operations
Well S-4, Spark Platform, North Trading Bay Unit
Well S-4 on the Spark platform of the North Trading Bay Unit is governed by
Disposal Injection Order (DIO) No. 13, approved September 12, 1997.
This report covers the final disposal injection operations for S-4 from January 1,
2009 until September 12, 2009, when the well was plugged and abandoned.
S-4 has been shut-in for most of the reporting period. The only injection during
2009 was in July for a total of 1175 barrels, injected at a maximum pressure of 900
psi.
Attached please find an injection monitoring report and chart showing daily injected
volume and maximum injection pressure on the annulus.
Please contact me with any questions at 907-565-3043.
Sincerely,
Tiffany Stebbins
Compliance Representative
Alaska Asset Team
P.O.Box196168
Anchorage, AK 99519-6168
Telephone 907/561-5311
Fax 907/565-3076
F~,rd~- i~ad:,,~8~r-w
cc: M. D. Dammeyer
Well file
Houston file
i •
Marathon Alaska Production LLC
Spark Platform, well # S-4
S-4 Injection Monitorin Sheet
Max Injection Pressure Daily Injection
Date on Annulus (psi) Volume (bbls)
7/7/09 300 200.0
7/14/09 225 115.0
7/15/09 225 150.0
7/19/09 300 45.0
7/20/09 300 21.2
7/21 /09 300 224.5
7/23/09 300 229.0
7/24/09 200 15.3
7/25/09 900 148.0
7/30/09 900 27.0
Total In~ected Volume bbls 1175.0
O
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Page 2 of 2
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ALRSK~I( PfJD GA ~~ OI~~SEl~V~1-IQN C`OMMIS~
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~~~~~ ~~~~~~~~~~-~~ ~~~~~~~~~~~~~~ ~~~~~~~~~ ~~~oo~
1a. Weli Status: Oil~ Gas~ Plugged ~ Abandoned ~ Susperided L=~
zoAac25.~o, ` 2o~n,cze.~~o
GINJ ~ WINJ [] WDSPL~ \NAG ^ Other^ No. of Completions: 1b. ~ 8a Qn$. Q~IC~~Q
Development ^ pnchor~~~ratory~
Service ~ Stratigraphic Test~ ~I
2. Operator Name:
Marathon Oil Company 5. Date Comp., Susp., or
band. 9l12l2009 . 12. Permit to Dri~l Num6er:
169-034-0. e
3. Address:
P.O. Box 196168, Anchorage, AK 99519-G168 6. Date Spudded:
6/3/1969 13. API Number:
50-733-20184-00-00 -
4a. Location of Well (Governmental Section):
Surface: 2615' N& 2492' W fi- SE cr, Sec 26, T10N, R13W; SM • 7. Date TD Reached:
6/27/1969 14. Well Name and Number:
N. Trading Bay Unit S-04 .
Top of Productive Horizon:
3158' FSL & 4202' FEL, Sec 26, T10N, R13W, SM 8. KB (ft above MSL): 115
Ground (ft MSL): 15. Field/Pool(s):
G-NE/Hemlock-NE Oil .
Total Depth:
2065' S& 776' E fr NW cr, Sec 26, T10N, R13W, SM 9. Plug Bacl< Depth(MD+TVD):
57' BML Undefined WDSP ,
4b. Location of Weli (State Base Plane Coordinates, NAD 27):
Surface: x- 227758.341 ' y- 2534480.7 ' Zone- 4 10. Totai Depth.(MD + TVD):
. 10744 MD, 10368 TVD • 16. Property Designation:
ADL035431 •
TPI: x- ~~5 ~ 6 S~~-7 y- Z~~~ ~ Z g, c~ S Zone-
Total Depth: x-_~ y- 2„~,33~4,~-6~8--~ Zon 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit:
18. Directional Survey: Yes ~ No ~
(Submit electronic and printed information per 20 AAC 25.050) /Q•LZ' 19. Water Depth, if Offshore:
60 (ft MSL) 20. Thickness of Permafrost (TVD):
21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071):
22. CASING, LINER AND CEMENTING RECORD
CASING WT. PER
GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT
FT TOp BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD pULLED
13-3/8 61 J55 BTC 0 2132 0 2131 17-1/2 1000 sks "G"/10% gel
400 sks class "G" tail
9-5/8 47 NSO 0 10744 0 10329 12-1/4 1050 sks class "G"
23. Open to production or injection? Yes ~ No Q if Yes, list each 24. TUBING RECORD
interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD)
4-1/2 10341 10087
10341
25. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
~~,~,~~~ 1~ ~J ";~ ~ ia ~~y~ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
518-575; CIBP @ 575 41 bbls 15.9 ppg "G" cmt plug
1881-2282 25 bbls 15.9 ppg "G" cmt plug
4205-5967 squeeze perts w/ 33 bbls 15.9 ppg "G" cmt
9220-9245, CIBP @ 9245 bailed 25' cement above CIBP
26. PRODUCTION TEST
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Date of Test: Hours Tested: Production for
Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio:
Flow Tubing
Press. Casing Press: Calculated
24-Hour Rate ~ Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr):
27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^ Sidewall Cores Acquired? Yes ^ No ^
If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water
(submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071.
V
' Form 1~-407 Revised 2/2007 CONTINUEO ON REVERSE /p(~J~~ (~1~ i~ / U•ZZ •~~
1/ 1 .s::~ /p ~ ~~. ~9'
-
-
28. GEOLOGIC ti1ARKERS (List aii formations and markers encountered) 29. FORMATION TESTS
NAME MD TVD Well tested? ~ Yes ~ No If yes, list intervals and formations tested,
briefly summarizing test resuits. Attach separate sheets to this form, if needed,
Permafrost - Top 0 and submit detailed test information per 20 AAC 25.071.
Permafrost - Base 0
G-zone formation, pert tops
G-1 10126
G-2 10149
G-3 10226
G-4 10261
G-5 10298
Hemlock formation, perf tops
H-1 10354
H-2 10395
H-3 10531
H-4 10651
Formation at total depth:
H-4 10770 10237
30. List of Attachments:
Summary of abandonment, final P&A wellbore diagram
31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tiffany Stebbins
Printed Name: Tiffany Stebbins Title: Regulatory Compliance Representative
Signature: t~~~%~~ -~%~~U'~~ Phone: 907-565-3043 Date: 10/12/2009
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. Submit
a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.
Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for
lnjection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool
completely segregated. Each segregated pool is a completion.
Item 4b: TPI (Top of Producing Interval).
Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other
spaces on this form and in any attachments.
Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28.
Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool.
Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed
description and analytical laboratory information required by 20 AAC 25.071.
Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and
analytical laboratory information required by 20 AAC 25.071.
Form 10-407 Revised 2/2007
Marathon Oil Company • • Page 1 of 2
North Trading Bay Unit no. S-4
API 50-733-20184-00-00, Sundry Number: 309-141
Work Summary
7/7/09 Rig up P&A equipment. Pump 200 bbis water down well @ 1 bpm and 300 psi pump pressure.
7/8/09 Continue rigging up P&A equipment while Pollard W ireline rigs up on well #4 to perform surveys.
Ken Walsh interpreted the Pressure Temperature survey completed 7/8/09 to show that: "this static
temperature-pressure profile was taken the next day after injecting about 200 bbls of 50 deg F fluid at
1 bpm down the Spark S-4 tubing. My analysis indicates that most, if not all, of the injection fluid
exited the wellbore through the top four perforation intervals including 4594-4624', 4654-4684', 5428-
5438', and 5523-5543' MD." Log data was forwarded to Guy Schwartz, who also confirmed that
target zones were reached during disposal and fluids were not exiting elsewhere in the formation.
Approval was granted to use S-4 for disposal.
7/14/09 Injection began into S-4. Below is a copy of the table used to record injection volumes and
pressures.
spa~rk S4 ~]actkin R~ca~d
p~sur~ an
~
C~ t~
~
7/25/09 Had increase in surface injection pressure up to 900psi during disposal. At the time of the pressure
increase, we were circulating fluid from S1 RD 9-5/8" annulus and disposing of the returns. We
stopped injection. We began evaluating remedial actions to heal the well prior to any further injection
activities.
7/28/09 Check SCSSV and grease tree valves until they stop leaking while changing fuel filters on crane. R/U
wireline with 3.75" gauge ring. Open well up with 250 psi and RIH to 6000' with no obstructions.
7/29/09 Waiting on boat loaded with perf equipment to begin perforating S- 4. Boat arrived. Offload perf guns
and backload 2-3/8" tbg and 2-3/8" Weatherford tools. The Expro pert gun information is as follows:
3.375" OD, 6 spf, 60 degree phasing, 0.35" entry hole, 43.30" penetration. R/U perf guns. RIH with
perf guns to 4684' & fire. POOH. Guns did not go off. Re-head e-line. RIH with 14' of Expro perf guns
to 4684' & fire. POOH. Guns did fire. Re- load e-line with another perf gun. RIH with 10' of Expro
perts gun to 4670' & fire. POOH, secure welis and equipment.
7/30/09 R/U and RIH with 6' DP pertorating guns to 4660' and fire guns. POOH. Make up another 14' of perf
guns. RIH to 4624' and fire guns. POOH. Make up another 16' of perf guns. R!H to 4610' and fire
gun. POOH. R/D wireline and R/U fluid pump on tbg. Start pumping on tbg at 250 psi at 1.5 bpm.
Pressure started to climb slowly. Shut down pump at 900 psi, after pumping a total of 27 bbis.
Summarv of re-perforations:
7/30/09 4594-4610' 16' un, 6 s f
7/30/09 4610-4624' 14' un, 6 spf
7/30/09 4654-4660' 6' un, 6 s f
7/29/09 4660-4670' 10' un, 6 spf
7/29109 4670-4684' 14' un, 6 s f
7/29/09 4670-4684' Gun didn't o off
Marathon Oil Company ~ • Page 2 of 2
North Trading Bay Unit no. S-4
API 50-733-20184-00-00, Sundry Number: 309-141
~
8/11/09 Re-perforating the wellbore did not increase disposal capability. Discussions were heid with AOGCC
on 8/11/09 to discuss Spark abandonment plans. Verbal plans were discussed to abandon S-4. A
follow-up abandonment application was submitted. ~~~~ ~Q S- Q~5
8/13/09 Abandonment plans were approved by AOGCG
8/31/09 Pressured up on 13-3/8" casing in well S-4 to 300 psi and charted same for 15 minutes. Good test.
9/2/09 M/P 40 bbls of 8.7 ppg KCL because of tree valve leaking. R/U wireline unit for well bay of S-4 & S-7
RIH with 20' of 3" cement dump bailers and tag CIBP and dump 25' of cement on top of CIBP. Totat
of 2 runs.
9/3/09 R/U pump lines and begin injection test. Inject a total of 136 bbls. 1 bpm @ 1800 psi, 1.5 bpm @
2000 psi, 2 bpm ~ 2500 psi. Shut down injection test and prepare cement equipment. M/P 35 bbls,
173.6 sks of 15.9 ppg, 1.132 yield, 15.9 ppg, class "G" Neat cement down tbg, injecting into the
perforations and displaced TOC #0 4394' RKB which is 200' above the top of the perfs. During the last
16 bbls of displacement, the pressure rose from 800 psi to 1900 psi, which it stayed at after shutting
down the pump.
9/4/09 Test tbg to 1000 psi and chart for 15 minutes. Good test. Test 9-5/8" csg to 1000 psi. Chart recorder
quit working. Replaced recorder and retested. Good test. R/U e-line with 2 ft perf gun @ 4 spf and
RIH & tag TOC at 4205' RKB. Pull up to 2282' RKB and shoot gun with 500 psi on tbg. Tubing
pressure fell to 0 psi. Circulated 3 bbls and shut down pump. POOH with W/L. R/U cement
equipment. M/P 25 bbls, 124 sks of 1.132 yield, 15.9 ppg, class "G" Neat cement down tbg, taking
returns out of 9-5/8" csg, displacing TOC to 1932' RKB, leaving a 350' cmt balance plug from 2282' to
1932' RKB in both the 4-1/2" tbg and the 9-5/8" x 4-1/2" annulus. WOC
9/5/09 Test intermediate balance plug and chart 15.
9/8/09 N/D tree and remove. Tree clamp bolts were froze up. Attempt to back out hanger pins. Pins were
froze solid with rust. Connect up to SCSSV with hyd. pump and attempt to open. Hyd pump broke.
Replaced hyd pump. Valve apparently leaking down hole. Ordered SCSSV stop leak. Secure well.
9/9/09 R/U and pump stop leak down SCSSV line until opened. R/U e-line unit. RIH with 4-1/2" tbe cutter
and tag TOC at 1881' RKB. Pull up to 600' RKB and cut tbg. POOH, R/U landing joint and handling
tools. Screw into hanger and pull tbg up to work deck and set the slips. Remove landing joint &
hanger. POOH with tubing and UD on work deck. Total pipe pulled out of well was 545 ft. R/U and
RIH with gauge ring to 600' RKB. POOH. M/U CIBP for 9-5/8" csg and RIH and set at 575' RKB and
POOH. M/U CIBP for 9-5l8" csg and RIH and set at 575' RKB and POOH. N/U tree. M/U 2 ft
perforating gun @ 4 spf and RIH to tag top of CIBP and pressure up 9-5/8" csg to 500 psi. Shoot gun
and pressure fell to 0 psi. Circulated 3 bbls and shut down pump. POOH and R/D e-line.
9/10/09 M/P cement. Circulate 108 bbls of 3% KCL down the 9-5/8" csg and up the 13-3/8" csg until clean.
Shut down pumping and R/U cement mixing equipment and materials. Mix 41 bbls, 203 sks of 15.9
ppg, 1.132 yield, class "G" Neat cement. Pump a 300' balance plug in both the 9-5/8" and the 13-
3/8"x 9-5/8" casings, from ± 574' RKB to ± 274' RKB. Clean all equipment and work deck.
9/12/09 R/U and RIH with 1-11/16" weight bar to177' WLM (62 BML) and tag TOC with AOGCC present. /
POOH and R/D e-line.
~~~ ~~
~~
RKB - MSL 115'
WATER DEPTH 60'
TM D @ 10744'
ND @ 10329'
PBTD @ 10700'
MASTP 10 psi MIT 5/14/09
API# 50-133-20184
All depths are RKB unless otherwise noted
9/12/2009
AOGCC WITNESSED Tag TOC @~57' BML ```
9/10/2009
~518' Surtace Cement Plug
95/a"and95/s"X133/s"
Mixed & Pumped ~41 bbls 15.9 ppg "G"
9/9/2009
Pertorated 9 5/s° Casin @~575' RKB
Surtace Casing - 2132'
13 3/a" 61 ppf J55 BTC
CMT 1000 "G" Lead
400 "G" Tail
Cement circulated to surface
Production Tubing @ 10093'
41h" 12.6 ppf N80 Buttress
3 1h" 9.2 ppf, N80 Buttress
10093' to 10341'
Tubing - Casing Perforations
4594'-4624'
4654'-4684'
5428'-5438'
5523'-5543'
5937-5967'
Tubing restriction at GLM @ 8231'
Wireline 2.85" GR to BP C~ 9188'
"Pollard" 5/14/2009
Fish: 21' x 1-11/16" w/ 3.789" GR
Otis XO Sliding Sleeve @ 10057'
Baker Retriva-D Packer @ 10087'
I D=3.813"
Production Casing C 10744'
9 5/s" 47 ppf N80
CMT 1050 sks "G"
CTOC @ 7264'
Gauge Hole Calculations
Marathon Oil Company ~
North Trading Bay Unit
Spark Platform Well S-4
"FINAL P&A CONFiGURATION"
All Depths measured RKB to top of equipment
9/9/2009
SET CIBP @ ~575' RKB
9/9/2009
Cut and Pulled 4~/z " Tubin from ~600'
II~401' Intermediate Cement Plug
~Pertorated Tubing ~ -2282' RKB
'Mixed & Pumped ~25 bbls 15.9 ppg "G"
'~Displaced TOC to ~1881' RKB
~TOC ~251' Above Surtace Casing Shoe
I BOC ~150' Below Surface Casing Shoe
Tagged TOC C~ 1881' RKB 9/9/2009
9/4/2009
~1762' Bottom Hole Cement Plug
Mixed and Pumped ~33 bbls 15.9 ppg "G"
Squeezed ~1373' of Perforations
Ta ed TOC @~4205' _~389' Above PerFs
9/2/2009
Bailed 25' Cement above CIBP @~9245'
Cement From ~9245' TOC @ ~9220'
~4684' RKB 14' Re-Pert Active perfs
~4670' RKB 10' Re-Pert Active PerFs
~4660' RKB 6' DP Re-Pert Active Pert's
~4624' RKB 14' DP Re-Perf Active Perfs
~4610' RKB 16' DP Re-Pert Active Perfs
P~rtc~'X' Ninnle C~a 1_03nR'
Perforations 10126'-10337'
Portco'X' Nipple @ 10341'
Baker Retriva-D Packer @ 10341'
Perforations
10356'-10592'
PBTD 10700'
MARATHON SPARK S-4 FINAL P&A CONFIGURATION PAGE 1 9/30/2009
TMD = 10744'
MEMORANDUM
TO: Jim Regg
P. I. Supervisor ~ ~~
FROM: Bob Noble
Petroleum Inspector
Sept 12, 2009:
~J
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Sept.12, 2009
SUBJECT: Well Abandonment
NTBU S-04
Marathon Oil Corp.
PTD 169-034
I traveled to the Spark platform and met with Marathon Oil Rep. Dan Byrd. He
notified me that he had set the top cement plug and the well. They were ready to
do a tag run with eline. I was there to witness Marathon's tag to find the TOC.
Pro-Serv Offshore had set a bridge plug at 575' RKB and pumped 41 barrels of
class G Neat cement. (Not Witnessed).
I witnessed Pro-Serv Offshore rig up and run eline in the well. They tagged hard
cement at 177' wireline or 62' below mudline.
Summary:
Attachments: none
rt: ~- ~. ~~ rl~~~
Aband Marathon NTBU S-04, 9-12-009.doc
~~~ ~ .' ~~ ~ae ~~` ~Q` , a:~
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COI~SER~
Anchorage, AK 99519-6168 ~~
Q~~~
... . _. .._ ., :<: ~. \~. - \
Re: G-NE/Hemlock-NE Oil; Undefined WDSP,
North Trading Bay Unit 5-04, Spark Platform
Sundry Number: 309-141
, ~~~,
Dear Ms. Stebbins: _~~~ `~„ ~ ~>~ - ~~ ~': , °~'~'`~~~'
~
~
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SEAN PARIYELL, GOVERNOR
~
K
S~ Da.a~ ~ Vrv-.7 ~~ 333 W. 7th AVENUE, SUITE 100
~O~ CO~~SjO~ ~ ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
$~ FAX (907) 276-7542
Ms. Tiffany Stebbins
Regulatory Compliance Rep.
Marathon Oil Company
P.O. Box 196168
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.
When providing notice for a representative of the Commission to witness any
required test, contact the Commission's petroleum field inspector at (907)
659-3607 (pager).
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.
Sincerely,
Cathy P. Foerster
Commissioner
DATED this ~J day of August, 2009
Encl.
~~
~,
~~~
~~~~~v~,
~ STATE OF ALASKA • ~P~ ~ ~ 7~(}~
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROV~IIa~ ~~~ ~ ~~~ ~~'~~~• ~~'~"~~`0~"
20 AAC 25.280 AitCh~lt'~!~~
1. Type of Request: Abandon ^~ ' Suspend ^ Operationai shutdown ^ Perforate ^ Waiver ^ Other ^
Alter casing ~ Repair well ~ Piug Perforations ^ Stimulate ^ Time Extension ~
Change approved program ^ Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~
2. Operator Name: 4. Current Well Class: 5. Permit to DriA Number:
Marathon Oil Company Development ~ Exploratory ~ 169-034-0 •
3. Address: Stratigraphic ~ Service ~. 6. API Number:
P.O. Box 190168, Anchorage, AK 99519-6168 50-733-20184-00-00 .
7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number:
property line where ownership or landownership changes: NOI'th Tfadlllg Bay UIIIt S-04
Spacing Exception Required? Yes ^ No ^ Spark platform
9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s):
ADL035431 • RKB-MSL 115' ' G-NE/HEMLOCK-NE OIL; UND.EFINED WDSP
12• PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
10,770' • ~,0;23'1`~ j~~j,:~~~ z~.c 10,700' is1,2~1° j~ SG'~,~
.~:~ 9,245' ~ None ~
~
Casing Length Size MD ND Burst Collapse
Structural
Conductor
Surface 2,132' 13 3/8" 2,132' 2,131'
Intermediate
Production 10,744' 9 5/8" 10,744' 10,329'
Liner
Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft):
4,594-5,967; 10,126-10,592 4,592-5,956; 9,787-10,199' 4 1/2"; 3 1/2" N-80 Buttress 10,364'
Packers and SSSV Type: Otis SCSSV ball valve Packers and SSSV MD (ft): 269'
two Baker Retriva-D packers 10,087', 10,341'
13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work:
Detailed Operations Program ~ BOP Sketch ~ Exploratory ^ Development ^ Service Q,
15. Estimated Date for 16. Well Status after proposed work:
Commencing Operations Oil ~ Gas ~ Plugged ^ Abandoned Q.
17. Verbal Approval: Date: WAG ^ GINJ ~ WINJ ^ WDSPL ~
Commission Representative:
18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tiffany Stebbins
Printed Name Tiffany Stebbins Title Regulatory Compliance Rep.
Signature Phone
e
~
''l O
907-565-3043 oc~/ -~
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3oq -~'~ ~
Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~
Other: ~ ~ r I_Yn ~,~.G C c rs~.a..+~ ~~c / /~
'~'~ ' ~' ~- ~ (~iae-~w-~ iS °~ pProv~1'
~)
a-s' p~-r ~Q/~ C Z•S. l I Z C ~
Subsequent Form Required:
{ O r ~ ~ ~
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date: g~~3 ~~f
Form 10-403 evised 06%200~ F ~ '~~ ~~, ,~4~~' ~ ,~ ~~~~ '~`" q~~2'~ ~{, 21.~~
Submit° n cate
~y~2~~
~ •
MARATHON OIL COMPANY
NORTH TRADING BAY UNIT
SPARK PLATFORM S-4
TEMPORARY ABANDONMENT PROCEDURE
03/31/09
WELL DATAAPI# 50-133-20184
Elevation: 115' RKB - MSL SCSSV: Otis Ball Valve @ 269'
Water Depth: 60'
Total Depth: 10,770' Nipple: 10,308', 10,341'
Surtace Pipe: 13 3/a" 61 ppf J55 C~ 2,132'
12.451" ID, .15215 bbl/ft
Production: 9 5/s" 47 ppf 10,744'
8.681" ID, .0732 bbl/ft
Tubing: 4~/z" 12.6 ppf N80 Buttress 10,364'
3.958" ID, .01522 bbl/ft
Packer: Baker Retriva-D C~ 10,087'
Baker Retriva-D @ 10,341'
Perforations: 4,594' - 5,967'
10,126' - 10,592'
PBTD: 9,245' Tubing Bridge plug
CURRENT STATUS
Well S-4 on the Spark platform was originally completed as a producing well. It was plugged back with a bridge plug
set in the tubing at 9245' isolating the original perforations. Holes were punched in the tubing and production casing
from 4594' - 4684' and 5428' - 5967' and the well was converted to an injection well. The well is now being
scheduled for abandonment.
NOTE: The well History indicates a substance similar to paraffin may be found in the wellbore Tubulars.
This substance was successfully treated with a"XYLENE" based solvent in the past.
ABANDONMENT PROCEDURE
1. Mobilize tree technician to location to ensure the operation of the tree valves, flanges. Repair as needed.
2. Mobilize abandonment crew and equipment to location. PerForm JSA and rig up equipment.
3. Check tubing and casings for pressure. Fill and test casings with weighted fluid and record results using a
continuous pressure chart recorder.
4. PerForm JSA for wireline operations. Rig up wireline lubricator and test to 1500 psi. Pressure up on SCSSV
control line and lock SCSSV in open position. Run gauge ring in 4 1/~" tubing to 9245', pull all tubing plugs as
required.
5. POOH with wireline line and rig down.
6. PerForm JSA for electric line operation and dump bailer operation. RIH with dump bailer and tag top of tubing
bridge plug @ 9245' RKB and record results. Dump cement leaving 25' of cement on top of the tubing bridge
plug @ 9245', to 9220' RKB. (Note: tubing restriction +~- 8231'). POOH.
7. Perform JSA on mixing cement and pressure pumping. Rig up pump and lines. Test pump lines to 1500 psi.
Perform injection test into perforations from 4594'-4684' and 5428' - 5967'. Pump 1.5 times the tubing
volume for test. Report casing and tubing pressures and/or returns prior to mixing cement. Record injection
rate and pressure.
8. Mix and pump determined volume of cement (volume is dependent on injection test) mixed with fresh water.
Squeeze into perforations, displace to a maximum depth of 4394' or until squeeze pressure is achieved
(1000 psi over injection pressure).
Spark S-4 Page 1 4/17/2009
~ •
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9. WOC and test tubing to 1500 psi while monitoring 9 5/s" casing pressu e for possible communications.
Document results using a continuous pressure chart recorder.
10. Perform JSA on electric line operations and explosives handling. RU electric line lubricator and test to 1500
psi. RIH with 2' of 4 SPF guns loaded with tubing punch and tag top of cement for bottom hole plug at 4394'
RKB and record results. Pull up to 2232' and fire guns. POOH.
11. PerForm JSA for mixing cement and pressure pumping. RU pump and lines and test lines to 1500 psi. Break
circulation down 4 1h" tubing taking returns out 9 5/s" casing. Mix and pump 22 bbl cement slurry for a 300'
cement plug in the 4 1/2" tubing and the 4 1/z" X 9 5/s" casing annulus from 2232' RKB - 1932' RKB'.
12. WOC and test to 1000 psi. Record results on a continuous pressure chart recorder.
13. Perform JSA on electric line operation and explosive handling. Rig up electric line lubricator and test to 1500
psi. RIH with a 4 1h" jet cutter and tag TOC for intermediate well bore plug @ 1932' RKB and record results.
Pick up to 600' RKB and cut 4'/z" tubing. POOH.
14. Rig down tree.
15. Perform JSA on proper pipe handing procedures. Pull 4 1h" tubing out of hole and check for N.O.R.M.
16. PerForm JSA for safe electric line operation and explosive handling. RIH with 9 5/e" gauge ring and tag top of
tubing stub at ~ 600' RKB. POOH.
17. RIH with 9 5/s" CIBP and tag tubing stub @ 600' RKB, pick up to 575' RKB and set CIBP. POOH.
18. RIH with perforating gun armed with 2 ft of 4 SPF casing punch, tag CIBP @ 575' RKB and set CIBP. POOH.
19. Perform JSA on cement mixing and pressure pumping. Rig up pump and lines. Test pump lines to 1500 psi.
NOTE: IF POSSIBLE
A) Circulate clean, down the 13 3/s" casing and up the 9 5/s" casing with weighted fluid. Mix and pump 41
bbl cement slurry for a 300' cement plug in the 9 5/s" casing and the 9 5/S" x 13 3/s" casing annulus
from 575' RKB - 275' RK6.
B) If unable to circulate the 9 5/s" X 13 3/e" casing annulus, RIH with work-string to CIBP, Pick up work-
string 10' and displace a 22 bbl slurry for a 300' cement surface plug from 575' RKB - 275' RKB in
the 9 5/s" casing only.
20. Pick up work-string 20' above TOC and circulate clean. POOH.
21. WOC. Perform JSA for wireline operations. RIH with Blind Box and tag TOC @ 275' RKB and record results.
POOH.
22. RD. Well is temporarily abandoned.
Spark S4 Page 2 4/17/2009
~ ~
~ Marathon Oil Company
North Trading Bay Unit
~taRAr~fi~~ Spark Platform Well S-4
"CURRENT"
RKB - MSL 115'
WATER DEPTH 60'
API# 50-133-20184
All Depths measured RKB to top of equipment
All depth are RKB unless otherwise noted
Maximum angle = 29 deg @ 10351'
Production Tubing @ 10093'
4 1h" 12.6 ppf N80 Butt
Surtace Casing - 2132'
13 3/a" 61 ppf J55 BTC
Cemented w/ 1000 sks Class G w/ 10% gel
tailed in with 400 sks neat
Cement circulated to surface
Production Tubing "Extension"
3 1/z" 9.2 ppf N80 Butt Tbg
10093' to 10364'
Production Casing @ 10744'
9 5/s" 47 ppf H80 BTC
Cemented w/ 1050 sks Class G(1197 cuft)
ETOC = 7712' (25% xs)
SCSSV - Otis ball valve @ 269'
4" Camco GLM (all dummied)
2489' 8694'
4715' 8231'
6531' 9798'
7909'
ing - Casing PerForations
4594'-4624'
4654'-4684'
5428'-5438'
5523'-5543'
5937-5967'
Tubing restriction at GLM @ 8231'
Tubing bridge plug @ 9245'
Fish: 21' x 1-11/16" w/ 3.789" gauge ring
Otis XO Sliding Sleeve @ 10057'
Baker Retriva-D Packer @ 10087'
I D=3.813"
Portco'X' Nipple @ 10308'
Perforations 10126'-10337'
Portco'X' Nipple @ 10341'
Baker Retriva-D Packer @ 10341'
Perforations
10356'-10592'
T.D. = 10770'
• !
~ Marathon Oil Company
North Trading Bay Unit
~utTNt~N Spark Platform Well S-4
~
"PROPOSED"
RKB - MSL 115'
Water Depth 60'
API# 50-133-20184
All Depths measured RKB to top of equipmen
All depths are RKB unless otherwise noted
300' Surtace Cement plug
Pertorate 9 5/a" @ 575' RKB
95/a"and95/a"X133/e"=4lbbls
9 5/e" only = 22 bbis
575'RKB-275'RKB
Maximum angle = 29 deg @ 10351'
Surtace Casing - 2132'
13 3/a" 61 ppf J55 BTC
Cemented w/ 1000 sks " G" 10% gel
tailed in with 400 sks neat
Cement circulated to surface
Production Tubing C~ 10093'
4 1/z" 12.6 ppf N80 Butt
3 1h" 9.2 ppf, N80 Butt
10093' to 10341'
@ 575' RKB
300' Intermediate Cement Plug
Pertorate 4 ~/s" @ 2232' RKB
4~2"and4~/z"X9 5/e"=22bbls
2232' RKB - 1932' RKB
(100' Below and 200' Above SCS)
Bottom Hole Cement Plug
"BBLS Determined by Injection"
Pertorations Squeezed
TOC @ 4394' (200' Above PerFs)
Tubing - Casing Perforations
4594'-4624'
4654'-4684'
5428'-5438'
5523'-5543'
5937-5967'
Tubing restriction at GLM @ 8231'
Fish: 21' x 1-11/16" w/ 3.789" gauge ring
Otis XO Sliding Sleeve @ 10057'
Baker Retriva-D Packer @ 10087'
I D=3.813"
ai ement op o n ge ug
Tubing bridge plug C~ 9245'
Leaving TOC C 9220'
Portco'X' Nipple @ 10308'
Pertorations 10126'-10337'
Portco'X' Nipple @ 10341'
Production Casing @ 10744'
9 5/a" 47 ppf H80
Cemented w/ 1050 sks Class G(1197 cuft)
ETOC = 7712' (25% xs)
Baker Retriva-D Packer @ 10341'
Perforations
10356'-10592'
T.D. = 10770'
• . Page 1 of 1
Schwartz, Guy L (DOA)
From; Laughlin, Gary A. [galaughlin@marathonoii.com]
Sent: Tuesday, August 11, 20094:35 PM
To: Schwartz, Guy L(DOA); Stebbins, Tiffany A.
Cc: Aubert, Winton G(DOA); Laughlin, Gary A.
Subject: RE: S-04 P& A ~~ ~ ~~,~ _ ~~ c.~
Guy,
Yes we will be testing both the tubing and the casing to ensure the perfs are completely cemented.
Thanks for catching it, my third check missed this.
Gary
From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov]
Sent: Tuesday, August 11, 2009 4:29 PM
To: Laughlin, Gary A.; Stebbins, Tiffany A.
Cc: Aubert, Winton G (DOA)
Subj+ect: S-04 P & A
Gary,
I was just "triple" reviewing #he P& A procedure for S-04. On Step 9 there is no mention of testing the annulus
after the cement sqz....., just the tubing test to 1500 psi. and watching the annulus for communication. Seems
like a casing test should be done also to verify the perfs are cemented off campletely. Can you verify if this will
be done... if so 1 can hand correct the 403 sundry with this step and send it on.
Regards,
Guy Schwartz
Senior Petroleum Engineer
AOGCC
793-1226
sil2~zao9
~ • Page 1 of 1
~d'j°~ °~
Schwartz, Guy L (DOA)
From: Schwartz, Guy L(DOA) 17~ t~ 9_ O 3y
Sent: Friday, June 26, 2009 2:03 PM ~~~`'
To: 'Laughlin, Gary A.'
Cc: Regg, James B(DOA); Aubert, Winton G(DOA) (winton.aubert@alaska.gov)
Subject: 3S-04 : 3S-05 status for Disposal injection NTBU
Gary,
As per our conversation today use NTBU S-04 for injection disposal of Class 2 wastes in conjunction with the P&
A activities on the Spark plafiForm. Since S-05 will not pass a CMIT the alternative well S-04 will be used per
Disposal Injection Order no. 13 .
Since NTBU S-04 doesn't have serviceable tubing or packer casing integrity cannot be determined. S-04 does
have a recent baseline temperature pass but AOGCC requests a subsequent temperature log after the first P& A
well (or 200 bbls) fluid have been injected. This will determine if the injected fluids are staying in the targeted
zones (Tyonek Formation). Additionally, annulus/tubing pressures and rates must also be monitored and
recorded during any injection sequence as per DIO No.13. - Rule 2. Injection surface pressure is not to exceed
1000 psi and 300 bbls per day as stated in DIO No. 13 Rule 4.
Regards,
Guy Schwartz
Senior Petroleum Engineer
AOGCC
793-1226
7/2/2009
~T~ ~ 6 ~'-o~~t
Marathon Oii We . S-4 Field: Spar 07-08-2009
Pressure (psia)
0 400 800 1200 1600 2000 2400 2800 3200 3600 4000
.--~
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Pressure - Perfs 13 3!8"
95l8" TBG o Mandrel
7-8-09 Pressure Temperature 7-8-09 Temperature
40 50 60 70 80 90 100 110 120 130 '140 150 160 170
Temperature (Deg. F)
nr~ l~ ~-a3y
Marathon Oil We : S-4 Field: Spar 05-14-2009
_ __ - - __ - -- - ~
Pressure (psia)
0 400 800 1200 1600 2000 2400 2800 3200 3600 4000
0
500
1000
1500
2000
2500
3000
3500
4000
.-.
~
~ 4500
~
.~
Q 5000
d
~
5500
6000
6500
7000
7500
800
850
900
950
- Pressure-Temperature Profile
1 Going in hole to 9150' MD
W
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40 50 60 70 80 90 100 110 120 130 140 150 160 170
Temperature (Deg. F)
~ --- - - - -
Pressure - Perfs 13 3/8" 9 5/8" ~~°TBG ~ Mandrel Temperature
~~~ ~,.b~~
/
Laughlin, Gary A.
From: Laughlin, Gary A.
Sent: Monday, May 18, 2009 8:35 AM
To: winton.aubert@alaska.gov
Cc: Laughlin, Gary A.
Subject: FW: Conversation Follow-up
Importance: High
Sensitivity: Confidential
Attachments: Picture (Enhanced Metafile); Picture (Enhanced Metafile)
;~t,~,~: _a~~~~;~, ~~,
, '}~ . ~.~ h9.~..0
From: Laughlin, Gary A.
Sent: Monday, May 18, 2009 8:21 AM
To: (winton_aubert@admin.state.ak.us)
Cc; Lauqhlin, Gary A.
Subied: Conversatlon Follow-up
Importance: High
Senaitivity: Confidential
Winton,
This is a follow up to our conversations May 13th and May 14th, 2009.
~
All Wells
• It is my understanding you will be checking to see if you can strike the phrase "temporarily abandoned" in each well abandanmenfi procedure and replace it
with "'permanently abandoned" for the Spark Platform sundries submitted in April 2009. ~
• Marathon will be added an additional 70' of cement to the top of the cement surface plug, thereby increasing it to 370' to adhere to the regulatory citation
25.112 section (d).
We are currently running a gauge ring and temperature surveys for all wells on the Spark Platform. I expect to see the results Tuesday or Wednesday next week.
After reviewing, I witl send you an email on the order we plan to abandon the wells. We plan to have simultaneous well abandonment operations. The only
certainty at this time is we wiVl abandon S-51ast.
(d) Plugging of the surface of a well must meet the following requirements:
(1) by the displacement method, a cement plug at least 150 feet in length, with the top of the cement no more than five feet below original ground
level onshore, or between 10 and 30 feet below the mudline datum offshore, must be placed within the smallest diameter casing string;
A+I~:rat}iar7 UU L:s~mp€iny
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~A'u'~1:' L1Lp1!5 ~:@~.. ,~ ~ =i ~~r ~ ~ ~ -~ ~' `h'ifiR?. ~..~a t~ :+'~P ._,.i..
!w~:a Ar7gF~: - ~~ , ~ 3978 ~'3329'
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If Part B online line 17(example is from the 5-09 Sundry), is unsuccessful the a"top job" will be performed. This step exists on all Sundries but line number
may vary.
~~ - f'~li~~:icl~ I.~.. .~ .. 1,.r~~;,,~~~' J~~i. ~~~~`J ~.I~~'aJ~ I `,i:~~; 5'i: Si.l ~.r} ii*`.. '~f~~5. ,. ~~I'1PE~1[,i'~ .JC~ t~,l.
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. 1 'I. ,..
",. °~al't :_I.I I. I , , : ~.ll. . .~r: ;,~I;~1; ! . _ .. `ir :~ii:l'Ig r_t .. . ... ~ . _ .. _' . ~ e:)In'I~4` ;a`~"1.1 „~, f,':.'r , •.~
F w:P.. . + ~~ (+'r . _..
li; I°` ~_r<:I.le~ b: .. ,~. i:l„~~; sn~;: ;J ~e +. i,s '~, ~..se~i~; >a~ri.i i,s, F.'- tiv;ir, ,vr,rxs: ~t i;., t;: +;:IFsF, ~`~r,. ~. .~.~ h~.r..:'-~~i~t!.
. ,.
; ;. ~ .:+.- ~.1 :~ ~ ~ ~ k ~ r d: •;Itd . . ,~~, i~ ~'~s ~v~~`~~..I t :.~:.Y'u.... ~,`i,.k! f~.} i :,, -. _. ~-... ~~ ~ ~r~ tht* ~ ;.;, ~ ...
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•
2
S-9
We will be attempting to remove a fish located approximately 4' below the tubing hanger stuck in the early 90's from S-9.
Thanks
Gary
r~
LJ
•
•
•
Spark Platform Abandonment Review
North Trading Bay Unit
Marathon Oil Company
Well NTBU S-O1RD (PTD174-005) - Sundry Application 309-138
Well NTBU S-02RD (PTD174-024) - Sundry Application 309-139
Well NTBU 5-03 (PTD169-O11) - Sundry Application 309-140
Well NTBU 5-04 (PTD169-034) - Sundry AppGcation 309-141
Well NTBU S-OS (PTD169-039) - Sundry Application 309-142
Well NTBU S-07RD (PTD169-096) - Sundry Application 309-143
Well NTBU 5-08 (PTD171-033) - Sundry AppGcation 309-144
Well NTBU 5-09 (PTD174-027) - Sundry Application 309-145
Requested Action:
Marathon Oil Company (Marathon) proposes to pertnanently abandon the above
referenced wells on the Spark Platform in the Cook Inlet.
Recommendation:
I recommend approval of the above referenced Sundry Applications to allow Marathon to
permanently abandon the wells.
Discussion:
Marathon proposes to permanently abandon the above wells on the Spark Platform by
setting the required multiple cement plugs in the wellbore. (At a later date to be
determined the Spark Platform structure will be removed; at this time the casing strings
will be cut and pulled just below mudline to complete the total abandonment of the wells.
) The Spark Platform is one of two, the other being the Spurr Platform in the North
trading Bay Unit (NTBU). Production began from the Spark Platform in January 1969
and peaked at nearly 12,000 bopd in November 1969 before beginning a rapid decline.
By January 1992 production from the platform had fallen to less than 300 bopd and
production was shut in. In November 1996 gas production, but not oil production, from
the platform was reestablished but and peaked at over 5.2 mmcfpd in May 1998. The
platform produced no water during the first year an a half of gas production but then
quickly rose to over 200 bwpd. The initial attempt at gas production ceased in May 2000,
a second attempt was made beginning in July 2003 but as soon as there was any
significant gas production there was also significant water production, up to almost 400
bwpd. By September 2005 significant gas production had ceased on the platform but
intermittent, averaging about 1 mmcfpd but only producing, usually, one day per month,
production continued until July 2007. There have been no further attempts to resume
production from the platform. Cumulative production from the platform is about 17.5
mmbo and 6.8 bcfg, 4.6 bcfg of which was associated gas recovered during oil
production.
• •
There have been a total of twelve wells drilled from the Spark Platform, of which four
have already been P&A'd (NTBU S-O1, 5-02, S-02DPN, and 5-07). Of the eight
"active" wells that are the subject of this review two are waste disposal wells (NTBU S-
04 & S-OS), one is classified as a gas well (NTBU S-02RD) but has not produced since
July 2007, and the remainder are classified as shut in.
Decline curve analysis of the oil production indicates that remaining reserves in the
known oil accumulations accessible from the Spark Platform range from zero for an
economic limit of 300 bopd for the platform to 1,096 mbo for an economic limit of 50
bopd for the platform. The following table shows the remaining reserves at various
economic limits.
Economic Limit (bo d) Remainin Reserves (mbo
50 1,096
100 869
200 410
300 0
Below is a graph of the decline curve analysis showing production extrapolated to a 50
bopd economic limit. Without specific economic information it is impossible to say what
truly the economic limit is for the Spark Platform. However, in a May 23, 1992, letter
from Marathon to the Department of Natural Resources (copy atta.ched) Marathon stated
that the platform had been uneconomic since 1990 and that at that time the break even oil
price was in excess of $20/bbl. Although oil prices are substantially higher than that now
operation costs have also increased dramatically since that time and the platform lik~ly
remains uneconomic today at any oil production rate that could be obtained from the
existing facilities and wellbores.
-"-1
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io
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O : 0.0763624 A.e.
. . . . . . . .
~ ~ : 288.357 bbVd
tl :01f37/7982
~ te 022612014
Fnel F+ate : 49.9199 C61/d
CLm Rod. : 17508.9 N6h1
~ Qim ~te : 0731/1992
. . .
~
~ ReserVes :1086.35Mti61
. . .
: F~serVes Da[¢ ' 02l2&20'14 !
. . . . . . . .... HJfi : '1 BBD52 M%~I
. . . I
Farecast Endod BY : Pate
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12t314
04TE
Several attempts have been made at sustaining substantial gas production from the
platform but none of them have lasted more than a year of regular production, and you
have to use a pretty broad definition of regular to get that as they were only able to
maintain production for an entire month a handful of times in the 11 plus years they
attempted gas production.
Conclusion:
The Spark Platform appears to be well beyond its economic life and permanently
abandoning the wells at this time, to prepare for a future platform and casing removal ,
appears to be the prudent course of action.
~ '
D.S. Roby~`'~'^,,..--°
Sr. Reservoi~ngiiieer
April 23, 2009 - Revised July 2, 2009
• w. w~,
ProducUOn Manaaer
Alaska Region ~
Domesuc Producuon
~ Marathon
MARIITMON Oil Company
P.O. Box 190168
Anchorage, Alaska 99519
Telephone 907/561-5311
March 23, 1992
Mr. Harold Heinze, Commissioner
Department of Natural Resources
400 Willoughby Avenue, 5th Floor
Juneau AK 99801-1796
Dear Commissioner:
SUSPENSION OF PRODUCTION OR OPERATIONS
Enclosed for processing is an application for suspension of production or
operations and a fiiing fee of ~,50.
Pursuant to 11 AAC 82.670 Suspension of Production or Operations, Marathon
Oil Company, P. 0. Box 190168, Anchorage, Alaska 99519, hereby requests
approval of suspension of production or operations for a two-year period
commencing June l, 1992. The leases affected are ADL-17597, ADL-18776, and
ADL-35431. The lands within the North Trading Bay Unit, as shown on
Exhibits 1 and 2, are described as follows:
T10N, R13W, Sec. 26: SW;, SZ NW;; Sec. 27: SE;, Sz NE:; Sec. 34: EZ;
Sec. 35: W2. ~
Two platforms have produced from the Unit to an onshore processing facility
at Granite Point. The Spark Platform, purchased by Marathon in 1984, was
recently shut in because it was uneconomic to operate. The Spurr Platform,
purchased by Marathon and Unocai in 1988, is currently operating at a loss.
Oil production from Spark Platform was approximately 330 BOPD prior to
shut-in, while Spurr Platform is currentiy producing about 250 BOPD.
Spark Platform
Overall, Spark has been uneconomic since 1986 when oil prices dropped
dramatically. Since that time Spark has lost ~Z.O MM on an operating
income basis as shown in Exhibit 3. Not included in this amount is the
$6.7 MM invested during that time. The break-even oil price for 1991 was
over 320 per barrel not including the cost of investment recoupment through
DD&A. 5ince reserves are defined as economically producible, no oil
reserves can be assigned to Spark with an oil price below ~20.
The Unit does have economic gas reserves which could be developed from
Spark. Gas reserves have been proved with a down structure fuei gas well
on the Spurr Platform which has recovered 3.5 BCF. Current plans call for
developing remaining gas reserves by recompleting Spark Platform Wells
A subsidiary or USX Corooration
Mr. Haroid Heinze• •
March 23, 1992
Page 2
S-2RD and S-8 uphoie near the gas reservoir structure top. In addition,
gas separation and dehydration facilities and compression wiil need to be
installed on the platform.
Proven Unit gas reserves are committed to both Unocal and Marathon con-
tracts. Because both companies currently have sufficient deliverability to
,L _meet contract demand, it is not economically justified to invest the
" necessary $7.7 MM gross cost to develop Unit gas at this time. If gas
~~~ production was commenced from Spark Platform, Unit gas sold would displace
'~ • gas sales from other fields which have already been developed. In the
~ mid-1990's, Marathon will begin to need additional deliverability to meet
contract demand. Plans are to develop Unit gas to meet this demand.
Spurr Platform
The Spurr platform has been uneconomic since 1990. It has lost 51.0 MM
since that time as shown in Exhibit 4. Investments totaling 56.9 MM
incurred since 1988 are not included in this caiculation. As with Spark,
the break-even oil price for 1991 was over 520 per barre7, not inciuding
DD&A costs. Therefore, no oil reserves can be attributed to Spurr. Spurr
does have one gas well, TS-3R0, completed in gas sands. It is currently
shut in because of down hole mechanical problems.
:~
'0~~ Losses are expected to increase in 1992 to $0.8 MM as a result of lower
~ J~'~ prnduction and a projected $12.00 per barrel oil price. This does not
' inciude the substantial ~onies required to stay in compliance with oil
~ spill and process hazard management regulations recently enacted. These
losses are not acceptable and as a result Spurr Platform and the attendant
onshore production facility at Granite Point must be shut in.
Until recently, the non-unit area developed by Spurr was thought to contain
significant undeveioped reserves. Evaluation of 3-D seismic and the
performance of Monopod Platform Well A-28RD now indicates no further
economic deveiopment potential exists. With once planned development
potential eliminated, Spurr has no further utility for oil production under
current economic conditions. Future gas production from Spurr is possible
and will be evaluated as part of the overail deveiopment scheme.
Marathon`s Plans Durin4 Two-Year Susoension
The main reason for the requested two-year suspension is to eliminate
unnecessary economic losses until Marathon develops Unit gas. During this
two-year suspension Marathon will continue to evaluate the gas market to
determine the optimum timing of gas development. The gas market is dynamic
and Marathon constantly evaiuates suppiy and demand. Marathon will also
monitor oil prices to determine if resumption of oil production is feasible
and will review alternate production strategies which couid reduce operat-
ing costs. This is applicable to both platforms.
~ ~ ~ Mr. Haroid Hein~ ,
- March 23, 1992
Page 3
A major undertaking during this suspension period wiil be the evaluation of
abandonment options for Spark, Spurr and Granite Point Production Facility.
This evaiuation wiil attempt to optimize method and timing of abandonment.
As no platform has been abandoned in the Cook Inlet to date, much research
needs to be done prior to abandoning the first structure. It is stressed
that this work does not preciude the planned resumption of operations at
Spark or the possible resumption at Spurr.
A revised plan of development reflecting the changes proposed in this
application is being sent under separate cover. If there are questions or
if further information is needed, please contact R. J. Murphy at 564-6425.
Thank you for considering this application.
Sincerely,
. •4
~~ 1 ~.,~~`~+(: y `.
W. Watson
cc: Mr. James Eason
Department of Natural Resources
Division of Oil and Gas
P. 0. Box 107034
Anchorage AK 99510-7034
A:LAND2/MH07/BGP
•
NORTH TRAOING 8AY UNIT 80UNOARY
PRIOR TO AUGUST 2, ~976
+
E~iHIBIT 1
ATTACNED AND MADE A PART OF
UNIT AGAEL~~IENT
FOA THE flEVELOPMENT AND OPEAATiON OF THE
NORTH TRADING 8AY UNIT AREA
+
~
1
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T9N R13W
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\\~~
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NOATH TRADING 8AY UNiT BOUND
AND HEMLOCK 3 'G' FORMATIO;
PARTICIPATING AREA BOUNDAR
I EFFECTIVE AUGUST 2. 1978
~
34 \35
2
ARATHQ
UNION MARATHON
\ ADL1759~~ \ ADL 18776 \\
MAP SOURCE
OIVISIO pS PROTRACTION
SHEET. GAIO NO. 5•13•5
STATE Oll ANO GAS LEASES
AD~•17597, AOl•18776, QOL•~5l31
LEG EN 0
~
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PARTiC1PATING AFiEA
NORTH TAADING 8AY UNIT AAEA
HEI~LOCK & `G' PARTICIPATING AREA
~ ~ COOK INLET, ALASKA
PARTiCIPATiNG AREA
LATEST CONTRACTION DATE: AUGUST 2, 1976
' OWNERSHIP AS OF:SEPT, i, 1988
RAARA~'~O~ ~~L C~4~iPA~Y
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~~~~~~~~~
~ STATE OF ALASKA .
ALASKA OIL AND GAS CONSERVATION COMMISSION '~~'~ ~~~~~~
REPORT OF SUNDRY WELL OPERATIONS ~;~$~~ ~~~ ~ ~~t,~ , { ,a ~~~x3.~+,~~~~;~7j
1. Operations Abandon Repair Well Plug Perforations Stimulate Other `
Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool [] Waiver [] Time Extension ^
Change Approved Program ^ Operat. Shutdown ~ Perforate Q~ Re-enter Suspended Well ^
2. Operator Marathon Alaska Production LLC 4. Well Class Before Work: 5. Permit to Drill Number:
Name: Develo ment
p ^ Exploratory[]
169-034 ~
3. Address: P.O. Box 196168 Stratigraphic^ Service0 6. API Number:
Anchorage, AK 99519-6168 ~ 50-733-20184-00-00 -
7. KB Elevation (ft): 9. Well Name and Number:
RKB-MSL 115' ~ N. Trading Bay Unit S-04 •
8. Property Designation: 10. Field/Pool(s): .
ADL035431 • Trading Bay/ G-NE/Hemlock-NE Oil, Undefined WDSP
11. Present Well Condition Summary:
Total Depth measured 10770 • feet Plugs (measured) tubing bridge plug @ 9245' MD
true vertical 10 , jL ~5'L feet Junk (measured) 21'x1-11/16" w/ 3.789" gauge ring
, ~~~
Effective Depth measured 10700 feet
4
~.?~yL,,~ ~ ~ '``':" ~~~~~
~ 4 a Y
~~
J
~
~
3
,
.
,
.Y:?;~SSs+~4,
'
~t
~
true vertical 10291 feet ~
~
Casing Length Size MD TVD Burst Collapse
Structural
Conductor
Surface 2132' 13-3/8" 2132' 2131'
Intermediate
Production 10744' 9-5/8" 10744' 10329'
Liner
Re-perf through tubing and 9-5/8" casing 4594-4624', 4654-4684' 6 spf
Perforation depth: Measured depth: Perfed through tubing and 9-5/8" casing C~3 4594-4624', 4654-4684', 5428-5438', 5523-5543', 5937-5967' DIL
1 01 26-1 01 38', 1 01 49-1 021 3' 10226-10337', 10356-10476', 10484-10553', 1 0561-1 0592'
True Vertical depth:
Tubing: (size, grade, and measured depth) 4-1/2" 12.6 ppf N80 Buttress tbg @ 10093', 3-1/2" 9.2 ppf N80 Buttress 10093-10364'
Packers and SSSV (type and measured depth) Otis ball valve SCSSV @ 269'; Baker Retriva-D Pkrs @ 10087', 10341'
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13• Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: perfs plugged up - average 260 psi average 260 psi
Subsequent to operation: 27 bbls 7/30/09 . 250 250
14. Attachments 15. W ell Class after work:
Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ •
Daily Report of Well Operations Daily ops, WBD 16. Well Status after work:
Oil ^ Gas ^ WAG ^ GINJ ' ^ WINJ ^ WDSPL ^~ '
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
309-262
contact tastebbins@marathonoil.com
Printed Name Tiffany Stebbins Title Regulatory Compliance Representative
~ . y,
Signature K~ Phone 907-565-3043 Date 8/3/2009
,~
Form 10-404 Revised 04/2006 ~ ~~~" ~~~~ ~~ '~ l~~~
Submit Original Only ~ 8'- ~~~
~
•
Marathon Alaska Production LLC
N. Trading Bay S-04 re-perforation
Form 10-404 Daily Report of Operations
The Expro perf gun information is as follows:
3.375" OD
6 spf
60 degree phasing
0.35" entry hole
43.30" penetration
/
Summarv of re-perforations:
~
7/30/09 4594-4610' 16' un, 6 s f
7/30/09 4610-4624' 14' un, 6 s f
7/30/09 4654-4660' 6' un, 6 s f
7/29/09 4660-4670' 10' un, 6 spf
7/29/09 4670-4684' 14' un, 6 s f
7/29/09 4670-4684' Gun didn't o off
Daily Report
7/28/09
Check SCSSV and grease tree valves until they stop leaking while changing fuel filters
on crane. R/U wireline with 3.75" gauge ring. Open well up with 250 psi and RIH to
6000' with no obstructions.
7/29/09
Waiting on boat loaded with perf equipment to begin perforating S- 4.
Start working on wellheads and SCSSVs for S-8 and S-9 while waiting on boat.
Boat arrived. Offload perf guns and backload 2-3/8" tbg and 2-3/8" Weatherford tools.
R/U perf guns. RIH with perf guns to 4684' & fire. POOH. Guns did not go off.
Re-head e-line. RIH with 14' of Expro perf guns to 4684' & fire. POOH. Guns did fire.
Re- load e-line with another pert gun. RIH with 10' of Expro perfs gun to 4670' & fire.
POOH, secure wells and equipment. Shut down for the day.
7/30/09
R/U and RIH with 6' DP perforating guns to 4660' and fire guns. POOH
Make up another 14' of perf guns. RIH to 4624' and fire guns. POOH
Make up another 16' of perf guns. RIH to 4610' and fire gun. POOH.
R/D wireline and R/U fluid pump on tbg.
Start pumping on tbg at 250 psi at 1.5 bpm. Pressure started to climb slowly.
Shut down pump at 900 psi, after pumping a total of 27 bbls. Report to Marathon's office.
~ ~
~~ Marathon Oil Company
North Trading Bay Unit
~~~~~~t~ Spark Platform Well S-4
"CURRENT"
RKB - MSL 115'
WATER DEPTH 60'
API# 50-133-20184
Maximum angle = 29 deg @ 10351'
Production Tubing @ 10093'
41h" 12.6 ppf N80 Butt
Surtace Casing - 2132'
13 3/s" 61 ppf J55 BTC
Cemented w/ 1000 sks Class G w/ 10% gel
tailed in with 400 sks neat
Cement circulated to surface
Production Tubing"Extension"
3 1/z" 9.2 ppf N80 Butt Tbg
10093' to 10364'
Production Casin~ @ 10744'
9 5/a" 47 ppf H80 BTC
Cemented w/ 1050 sks Class G(1197 cuft)
ETOC = 7712' (25% xs)
REVISED 8/03/2009
All Depths measured RKB to top of equipment
All depth are RKB unless otherwise noted
SCSSV - Otis ball valve @ 269'
4" Camco GLM (all dummied)
2489' 8694'
4715' 8231'
6531' 9798'
7909'
Tubing - Casing Perforations
4594'-4624' ReperfJuly29-30,2009
4654'-4684' RepertJuly29-30,2009
5428'-5438'
5523'-5543'
5937-5967'
Tubing restriction at GLM @ 8231'
Tubing bridge plug @ 9245'
Fish: 21' x 1-11/16" w/ 3.789" gauge ring
Otis XO Sliding Sleeve @ 10057'
Baker Retriva-D Packer @ 10087'
I D=3.813"
Portco'X' Nipple @ 10308'
Perforations 10126'-10337'
Portco'X' Nipple @ 10341'
Baker Retriva-D Packer @ 10341'
Perforations
10356'-10592'
T.D. = 10770'
•
~~ ~ ~ ,
~~~ ~ ~ ~ ~h~~ ~ ~ " ~~~ ~ ~~~` ~ ~~f.
~
~ ~ ~ ~_~~~. ~.~ ~ ~~~~ ~~
~ ~_
~
C01~5~RQA
.
l a:., ~ ~ ~ ` a ~`.~,~ ~ ~~~ ~ ~ ~ g
~~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ SEAN PARNELL, GOVERNOR
~_ ~~x~ ~~~ ~~ ~~ ~ ~
~ ~~~
~SttrB~ OI~ A~D t7r1~~,7 333 W. 7th AVENUE, SUITE 100
ii~~ CD~IISSI~~ ,~~ ANCHORAGE, ALASKA 99501-3539
~ PHONE (907) 279-1433
? FAX (907)276-7542
Ms. Tiffany Stebbins
Regulatory Compliance Rep.
Marathon Oil Company
P.O. Box 190168
Anchorage, AK 99519-6168
' ~~ a
~r~
Re: G-NE/Hemlock-NW Oil; Undefined WDSP, North Trading Bay
Unit S-04, Spark Platform
Sundry Number: 309-262
~~:;. t~~.;y~~~~~ ~~[' ~„ . ~ijZE~;
Dear Ms. Stebbins:
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.
When providing notice for a representative of the Commission to witness any
required test, contact the Commission's petroleum field inspector at (907)
659-3607 (pager).
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.
Sincerely,
~ ~
Cathy . Foerster
Commissioner
r~
DATED this 3 day of August, 2009
Encl.
• •
~ ~ ~ ~ ~ ~~ N •,~.a. ~ . £ ~.~. ~ .~ ~ .~ ~~,,.... F ~ k x..a! ~ @ ~ ~~ ~ ~ ~'~~yy' r ~ `~ b~
~~.. a ~; f Y ~ " 4. q i' ~ ~ ~ ~r
~ ~ ~'~~~ ~ ~ ~~ ~ k, ~ ~g ~ ~ ~ ~ ~ ~ ~~.
~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ P ~ , ~3~ a ~ ~ ~p~ ~ SEAN PARNELL, GOVERNOR
~ ~i` ~ ~ ~.~: ~.~~,~ ; ~ , ~v ~ ~ ~"~~ '~,4 ~~ 0 ~~' ,~~. ~° E~: ~
1
~-78~ DI.a~ ~ ~7r~-7 ~ 333 W. 7th AVENUE, SUITE 100
CO1~T5ERQATIOi~T COAirII551O1~T ~ ANCHORAGE, ALASKA 995013539
PHONE (907) 279-1433
FAX (907) 276-7542
Ms. Tiffany Stebbins
Regulatory Compliance Rep.
Marathon Oil Company 3 (~
P.O. Box 190168 ,;~~,~~a~:,~ r~~,~~+ ~~` ~~}~l;::' / ~
Anchorage, AL 99519-6168 `~ ~
r
Re: G-NE/ Hemlock-NW Oil; Undefined WDSP, North Trading Bay
Unit S-04, Spark Platform
Sundry Number: 309-262
Dear Ms. Stebbins:
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.
When providing notice for a representative of the Commission to witness any
required test, contact the Commission's petroleum field inspector at (907)
659-3607 (pager).
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.
Sincerely,
Daniel T. Seamount, Jr.
/ Chair
/~
DATED this'3 day of August, 2009
Encl.
OMarathon. Alaska Production LLC
August 3, 2009
Cathy Foerster
State of Alaska
Alaska Oil and Gas Conservation Commission
333 W. 7"' Avenue, Suite 100
Anchorage, AK 99501-3539
`_
Alaska Asset Team L�ate,
P.O. Box 196168
Anchorage, AK 99519-6168
Telephone 907/561-5311
Fax 907/565-3076
Re: 20 AAC 25.300 (Request for Information) — Status of Oil and Gas Wells
Dear Ms. Foerster:
In response to your June 22, 2009 letter requesting a plan of action and timing for such activities
associated with the referenced list of inactive wells, please find attached a table with the requested
information.
As indicated in the table, Marathon anticipates a measured program of P&A activities, averaging
three -to -five well abandonments per year. Marathon has already begun such a program with its
offshore wells, beginning with the Spark Platform wells in 2009.
All of the onshore wells on the list are within active oil and gas leases that are regularly visited and
inspected.
Marathon anticipates updating plans for its inactive wells in the appropriate annual Plan of
Development for each property. Any and all forward activities are subject to funding approval.
Please also note that your June 22 letter erroneously referenced "KU 41-08". We believe that your
June 22 letter reference to well "KU 41-08" was a typo and is intended to refer to Well KU 41-18.
This well matches the referenced drilling permit (171-010).
Should you have any questions or wish to review the attached plans with us, please feel free to call
Lyndon Ibele at (907) 565-3042.
Sincerely,
Carri Lockhart
Alaska Asset Team Manager
Attachment: Marathon plan for list of inactive wells
cc: B. Schoffmann
L. Ibele
K. Skiba
T. Stebbins
Well Files
SCANNED
Marathon Oil Company, Alaska Asset Team
Anticipated schedule of well abandonment activities
Confidential
8/3/2009
Timing lWell
I Permit No.
I Pad or location
2009-2011 S-1 RD
174-005
Spark
S-2RD
174-024
Spark
S-3
169-011
Spark
S-4
169-034
Spark
S-5
169-039
Spark
S-7RD
169-096
Spark
S-8
171-033
Spark
S-9
174-027
Spark
TS -1
168-048
Spurr
TS -2
168-050
Spurr
TS -3RD
168-065
Spurr
TS -4
168-066
Spurr
TS -6
168-090
Spurr
TS-7RD
169-026
Spurr
TS -8
169-027
Spurr
TS -9
169-092
Spurr
2012-2015
BC 7
176-006
BCU Pad 7
CLU 3
181-058
CLU Pad 3
CLU 4
187-034
CLU Pad 3
KU 33-30
159-015
KGF pad 33-30
KU 42-30
181-091
KGF pad 33-30
KU 44-30
168-071
KGF pad 33-30
SU 23-15
161-014
Sterling Unit
KU 41-18
171-010
KGF pad 41-18
KU 43-12
169-087
KGF pad 14-6
KU 11-6
165-017
KGF pad 34-31
KU 21-5
169-035
KGF pad 43-32
W F1-21 rd
193-183
West Fork
WF2-21
192-010
West Fork
• ~ ~1
'' STATE OF ALASKA `~
` ALAS~IL AND GAS CONSERVATION COMM~ON
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25280
~~~~~~~~
~u~ ~ s zoo~
~~BS~~ ~f~ c~t tiAS f'.nns f"nmmte~e
1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ~+ Waiver ~~~~r~~~ Other Q
Alter casing ~ Repair well ^ Plug Perforations ~ Stimuiate ^ Time E~ension ~
Change approved program [] Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Marathon Oil Company Development ~ Exploratory ~ 169-034-0 •
3. Address: Stratigraphic ~ Service ~ 6. API Number:
P.O.Box 190168,Anchorage,AK 99519-6168 50-733-20184-00-00 '
7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number:
property line where ownership or landownership changes: NOfth TI'adlllg Bay Ulllt S-04 •
Spacing Exception Required? Yes ^ No ~ Spark platform
9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s):
ADL035431 • RKB-MSL 115' ' G-NE/HEMLOCK-NE OIL; UNDEFINED WDSP •
~ 2• PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft},~~ Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
10,770' , 1¢,22T" ~p ~„~,''~ ~ 10,700' 10,291' BP Q 9,245' tbg restricted 8231' GL
Casing Length Size MD ND Burst Collapse
Structural
Conductor
Surface 2,132' 13 3/8" 2,132' 2,131'
Intermediate
Production 10,744' 9 5/8" 10,744' 10,329'
Liner
Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft):
4,594-5,967; 10,126-10,592 4,592-5,956; 9,787-10,199' 4 1/2"; 3 1/2" N-80 Buttress 10,364'
Packers and SSSV Type: Otis SCSSV ball valve Packers and SSSV MD (ft): 269'
two Baker Retriva-D packers 10,087', 10,341'
13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work:
Detailed Operations Program ~ BOP Sketch ~ Exploratory ^ Development ^ Service Q "
15. Estimated Date for ~ Well Status after proposed work:
Commencing Operations: `~z ~~~9 t/e~^6~ r.~, yi, O' ~ Gas ~ Plugged ^ Abandoned ^
17. Verbal Approval: ~,z 7„ ~j ~ Date: AG ~ GINJ ~ WINJ ^ WDSPL ^~ ~
Comm ission Representative: SG~ W~,~ -f ~-Z
~t
18. I hereby certify that the foregoing is tru nd correct to the best of my knowledge. Contact Tiffany Stebbins
Printed Name Tiffany Stebbins Title Regulatory Compliance Rep.
~
Signature ~ Phone Date 7/27/2009
907-565-3043
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~O y~a~p~
Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^
Other:
Subsequent Form Required: ~~y ou y
~
~ --~-~""~~° ~ APPROVED BY
H. ~~ ~r~ ~~~~~
Approved by: g ~~
~ COMMISSIONER THE COMMISSION Date:
~
.
~
.,~::~~ 7 z-~f 7 cti
Form 10-403 Revised 06/2006 u--~ ~~~~ t~~ z~~ Ea ~~~,C~ ubmit in Duplicate ~
"`~r~,~~ ~, ~ =3 a 4
d~
~
lMIARtltTH~M
~
RKB - MSL 115'
WATER DEPTH 60'
TMD @ 10744'
ND C 10329'
PBTD C~? 10700'
MASTP 10 psi MIT 5/14/09
API# 50-133-20184
Surface Casing - 2132'
133/s"61ppfP110BTC
CMT 1000 sks "G" Lead
400 sks "G" Neat Tail
Cement to surface
Production Tubing @ 10093'
41/z" 12.6 ppf N80 Buttress
• •
Marathon Oil Company
North Trading Bay Unit
Spark Platform Well S-4
"PROPOSED" ~
Wireline 2.85" GR to BP ~ 9188'
"Pollard" 5/14/2009
Production Tubing "Extension"
3 1/z" 9.2 ppf N80 Buttress
10093' to 10364'
REVISED 7/27/09
All Depths measured RKB to top of equipment
All depth are RKB unless otherwise noted
SCSSV - Otis ball valve @ 269'
4" Camco GLM (all dummied)
2489' 8694'
4715' 8231'
6531' 9798'
7909'
Tubing - Casing
PerForations
4594'-4624' ~
4654'-4684' ~
5428'-5438' •
5523'-5543' _
5937-5967' •
REPERF /
REPERF
Tubing restriction at GLM @ 8231'
Tubing bridge plug @ 9245'
Fish: 21' x 1-11/16" w/ 3.789" gauge ring
Otis XO Sliding Sleeve @ 10057'
Baker Retriva-D Packer @ 10087'
I D=3.813"
Portco'X' Nipple @ 10308'
Pertorations 10126'-10337'
Portco'X' Nipple @ 10341'
Production Casin~ @ 10744'
9 5/s" 47 ppf N80 BTC
CMT 1050 sks "G"
CTOC @ 7264'
Gauge Hole Calculations
Baker Retriva-D Packer @ 10341'
Pertorations
10356'-10592'
Marathon Spark S-4 Current Page 1 7/27/2009
TMD = 10744'
~ ~ Page 1 of 1
Schwarti,_Guy L (DOA) . : ~ ~f~ ~~ 7" ~3L/
From: Laughiin, Gary A. [galaughlin@marathonoil.com]
Sent: Monday, July 27, 2009 2:53 PM
To: Schwartz, Guy L (DOA)
Cc: Aubert, Winton G(DOA); Stebbins, Tiffany A.
Subject: RE: Repert S-4
Thanks, will do.
Gary
__ _ _ __
From: Schwartz, Guy L (DOA) [mailto:guy.schwariz@alaska.gov]
Sent: Monday, July 27, 2009 2:46 PM
To; laughlin, Gary A.
Cc: Aubert, Winton G(DOA); Stebbins, Tiffany A.
Subject: RE: Reperf S-4
Gary,
I can give you verbal approval to reperf S-04. Be sure and send a 403 sundry request tomorrow with the specific
intervals you plan on shooting. Based on the temperature survey the upper zones are the best areas.
Also, a 404 will be required for followup after perfing is complete.
Thanks
Guy Schwartz
Senior Petroleum Engineer ~
AOGCC
793-1226
From: Laughtin, Gary A. [mailto:galaughlin@marathonoil.com]
Sent: Monday, July 27, 2009 2:34 PM
To: Schwar~, Guy L (DOA)
Cc: Aubert, Winton G(DOA); Stebbins, Tiffany A.
Subject: Reperf 5-4
Importance: High
Guy,
Marathon would like to get permission to reperf the Spark well S-4 (DIO #13) within the same interval the well is
currently completed into.
148 bbls of fluid from S-7RD were injected into the S-4 and the maximum tubing pressure climbed to 900 psi.
The current interval referenced is between 4595' and 5967' MD.
Thanks
Gary
S/3/2009
Spark 54 Injection record.pdf • • Page 1 of 1
Schwartz, Guy L (DOA)
~-.I~ lG~-Q3y
From: Paxton, Todd D. [tpaxton@marathonoil.com]
Sent: Monday, July 27, 2009 8:05 AM
.. ... _ .,..
To: Schwartz, Guy L (DOA)
Cc: Stebbins, Tiffany A.; Laughtin, Gary A.; Schoffmann, A B(Ben); Keppers, Craig J.; Paxton,
Todd D.; Berga, Pete; Byrd, Dan
Subject: Spark S4 Injection record.pdf
: r n....
Attachments: Spark S4 Injection record.ZlP :~~ ,; ~+~f~y~-~o C;t; ;' ~ lUU;~
«Spark S~4 Injection record.ZlP»
Mr. Schwartz,
FYI......attached is the document we use to record Spark S4 injection pressures and volumes.
On Saturday, you'll note an increase in surface injection pressure up to 900psi. At the time of
the pressure increase, we were circulating fluid from S1 RD 9-5/8" annulus and disposing of the
returns. We stopped injection as a result of the pressure increase and are evaluating remedial
actions to heal the well prior to any further injection activities. Expect to see a sundry soon to
further that effort.
Thanks,
Todd Paxton
Offshore Supervisor
907-394-1322
8/11/2009
• ~
Spark S4lnjectiun Record
~ 3~
~~~6
Date
Totat tnjected bbls) Max pressUre on
Annulus
Recorded by
7 . ~f.~' 22S' ~~sr
~'"` d ~.~...5" ~,S
J~
~ ~ ~ {~
' ~ f, ~ ~ ~ a
~ ,r~ ~. , . ~~
~ ~ dG
~ ~ ~ ~.~ -' ~ ~
~ ~ ~ ~ ~ 'Z~ ~
~ C~ ~ L ~ ~ C
. ~
7~~,a~2oos
~
._ ~,.„
i
~~t. ~*;
,`
~
~
~
k
~
• • Page 1 of 2
Schwartz, Guy L (DOA) ;,~,~y
`1'`~ -
From: Schwartz, Guy L (DOA)
Sent: Thursday, July 09, 2009 11:20 AM
To: 'Stebbins, Tiffany A.'; Regg, James B(DOA); Aubert, Winton G(DOA) I~ ~~ ~~'~ ~ a~~
Cc: galaughlin@marathonoil.com; Randy Ellis
Subject: RE: Spark S-4 Static Pressure-Temperature survey 7-8-09
Tiffany,
The recent temperature logs confirm injection into the target Tyonek Fm sands. I agree with the interpretation as
presented below from Mr. Walsh. Marathon can use S-04 as a disposal well for the upcomina well abandonment
program. Be sure and follow DIO No. 13 stipulations including:
1) Track and record pressure on the tubing and IA during injection into S-04. Pressures cannot vary by
more than 25% ... (send AGOCC a copy of the recorded tbg/IA data after every pumping sequence )
2) Do not pump more than 300 bbis per day and stay below the 1000 psi Max injection surface pressure.
Thanks,
Guy Schwartz
Senior Petroleum Engineer
AOGCC
793-1226
` ' y~~~~~v' .~UL ~- ~; ~~~1,~3
~r r:t
From: Stebbins, Tiffany A. [mailto:tastebbins@marathonoil.com]
Sent: Thursday, July 09, 2009 10:08 AM
To: Schwar~, Guy L(DOA); Regg, James B(DOA); Aubert, Winton G(DOA)
Cc: galaughlin@marathonoil.com; Randy Ellis
Subject: FW: Spark S-4 Static Pressure-Temperature survey 7-8-09
Guy, please find attached the data and plots from a Pressure-Temperature survey completed
7-08-09 for Spark S-4. Below is a data and plot interpretation by Marathon representative Ken
Walsh.
After reviewing the data, please confirm that Marathon will be able to use Spark S-4 as a
disposal well during our Spark well abandonment program.
Thanks,
~1~~'~'~ ~~,~,~
Regulatory Compliance Representative
Marathon Oil Corporation
Phone 907-565-3043
Ce11907-529-0522
Fax 907-565-3076
From: Walsh, Ken
Sent: Thursday, July 09, 2009 9:45 AM
To: Keppers, Craig ].; Stebbins, Tiffany A.
7/10/2009
~ • Page 2 of 2
Cc: Ibele, Lyndon
Subject: RE: Spark S-4 Static 7-8-09
Craig,
It is my understanding that this static temperature-pressure profile was taken the next day after
injecting about 200 bbls of 50 deg F fluid at 1 bpm down the Spark S-4 tubing. My analysis
indicates that most, if not all, of the injection fluid exited the wellbore through
the top four perforation intervals including 4594-4624', 4654-4684', 5428-5438', and 5523-
5543' MD. This is based on the cooling trends on the temperature log. It appears that very
minimal or no injection fluid exited the perForation interval at or below 5937-5967' MD. This
is presumed since no cooling trend was apparent across or below this set of perforations.
The fluid gradient from 200' to 90Q0' MD is calculated at 0.4364 psi/ft. This represents a
relatively fresh water fluid gradient. Although the fluid gradient was calculated from measured
depth; it should be accurate as the MD and TVD are appreciably the same at the depths
evaluated.
~~
Ken D. Walsh
Senior Production Engineer
Marathon Oil Company-Alaska Asset Team
907-283-1311 (office)
907-394-3060 (cell)
7/10/2009
~- ~Marathon Oil ~ 1N'efl: ~S-4 ~ Field:~Spar'rc ~07
Pressure (psia)
0 400 800 1200 1600 2000 2400 2800 3200 3600 4000
.-.
~..
a~
a~
~
....
t
.r
~
a~
~
Pressure - Perts 13 318"
. c c;; TF^__ F,'andrel
-_-_-; _ -_ _ --- - , - __. ,_8-~9lemperature
40 50 60 70 80 90 100 11Q 120 130 '140 '150 160 170
Temperature (Deg. F)
·
Alaska Aeream
~NfJ Marathon
MARATIIOII Oil Company
PO BOX 196168
Anchorage. AK 99519-6168
Te/ephone 907/561-5311
Fax 907/565-3076
Alaska Oil & Gas Cons. Commissioii!
Anchorage
RECEIVED
JUL 0 2 2007
June 28, 2007
Tom Maunder
AOGCC
333 West 7th Ave, Suite 100
Anchorage, AK 99501
s~ JUt 1 '1 2007
Reference: 2006 Annual Report of DislJOSalln/ectlon Operations.
Well 8-4 and 8-5, Spark Platform, North Trading Bay Unit
Dear Mr. Maunder:
This annual report of disposal operations covers the period of January 1, 2006 through December 31,
2006 for wells S-4 and S-5 on the Spark platform of the North Trading Bay Unit. Disposal via well S-4
is govemed by Disposal Injection Order (010) No. 13 for the North Trading Bay Unit (approved
September 17, 1997), and disposal well 8-5 is govemed by 010 No. 15 approved Augus131, 1998.
DUring the report period, there were no prOduction activities on the Spark platform. The only
ProdUCing gas well, S-2rd, was shlIf-in for the entire period due to liquid loading. Therefore, there
were no fluIds Produced or injected dUring the report period. All rates and pressures for the two
Spark injection disposal wells were "zero" as indicated on the attached Plots for calendar year 2006.
The las1 mechanical integrity test for S-5 was conducted on July 13~ 2004 and the nex! such tes1 is
due by July 13~ 2008. Well S-4 is nol equipped with a serviceable tubing or packer, and therefore
mechanical integrity is established by al/emative means as set forth in 010-13.
Sincerely,
éì4.S
,("8. Schoffmann
Operations Superintendent
Marathon Oil Company
Enclosures
J {¡;~-034-
.
.
Disposal Well S-4 Casing Pressure
Spark Platform - North Trading Bay Unit
I. Spark #4 Casing Pressure 1
2000
1800
1600
1400
...
;;
~200
e
'"
..
ë1000
...
...
~ 800
..
Co)
600
400
200
¡;;
i\3 i5
0
0 0
'" 0
'"
Date
Disposal Well S-5 Casing Pressure
Spark Platform - North Trading Bay Unit
\- Spark #5 Casing Pressure I
2000
1800
1600
1400
...
~200
e
'"
..
ë1000
...
...
~ 800
..
Co)
600
400
200
0
I §
i\3
~
Date
.
.
Disposal Well S-4 Injection Volume
Spark Platform - North Trading Bay Unit
\. Spark #4 Injection Volume I
800
700
600
Q
...
3:500
III
ai
E
=400
~
c
0
~300
:š"
200
100
0
~ \o!
i\3 ~
0 i\3 0
0 g 0
'" '"
'"
Date
Disposal Well S-5lnjection Volume
Spark Platform - North Trading Bay Unit
I_ Spark #5 Injection Volume I
800
Q
...
3:500
III
f
'"400
~
i
1300
i5 ~ ~
0 i\3 0
ã! g 0
'"
'"
Date
700
600
.
.
Disposal Well S-4 Injection Pressure
Spark Platform - North Trading Bay Unit
I. Spark #4 Injection Pressure 1
2000
-
i5
o
o
'"
~
¡;¡
o
o
'"
~
¡;¡
o
o
'"
~
¡;¡
o
o
'"
~
¡;¡
o
o
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1800
1600
1400
...
õi
...
!!1200
'"
..
ë1000
...
5
ti 800
..
:s
600
400
200
o
Date
Disposal Well S-5 Injection Pressure
Spark Platform - North Trading Bay Unit
I_ Spark #5 Injection Pressure I
2000
1800
- ~ ~ ~
i5
¡;¡ i\3 ~ 0
0 0 0
ã! 0 '"
'"
Date
1600
1400
...
I
!!1200
~
ë1OO0
...
c
o
ti 800
..
:s
600
e
Alaska A. Team
/ ~ ~-061{
Marathon
Oil Company
P.O. Box 196168
Anchorage, AK 99519-6168
Telephone 907/561-5311
Fax 907/565-3076
June 13, 2006
-E-(~,E
¡,i',! I 'Î.~nc~~
-r "',..i. --, ~ - ...,.
Winton Aubert
AOGCC
333 West 7th Ave
Suite 100
Anchorage, AK 99501
,~.(ë
'-'f'" h 'íNt.:J'\
;)'>;?(f·w·~ ~~µ
"\ I;:: ínq~
,,:s. ~1j .~"""".1'
Reference: Report on Disposal Injection Operations
Well S-4 and S-5, Spark Platform, North Trading Bay Unit
Dear Mr. Aubert:
This annual report of disposal operations covers the period of January 1, 2005 through
December 31, 2005 for wells S-4 and S-5 on the Spark platform of the North Trading Bay
Unit. Disposal via well S-4 is governed by Disposal Injection Order (010) No. 13 for the
North Trading Bay Unit (approved September 17, 1997), and disposal via well S-5 is
governed by 010 No. 15 approved August 31, 1998.
Attached are two plots showing injection volume and injection pressure for wells S-4 and S-
5. Injection into well S-5 began on September 3, 1998. Because well S-4 is designated as a
backup disposal well for S-5, injection into S-4 ceased when injection began in S-5.
The S-2RD gas producer was flowed from mid-November 2004 until it was shut in mid-
September 2005 due to liquid loading problems. Injection of the produced fluid from the S-
2RD well was injected solely into the S-5 well. All injection into S-5 was below the 010
operating limits of 1000 bbls/day and 3000 psi surface disposal pressure. A workover of S-
2RD is currently under evaluation. If this workover is implemented and is successful,
injection operations will recommence in S-5 with S-4 as the backup.
Sincerely,
0f~lr---
A. B. Schoffmann
Operations Manager
L:\Spark\Wells\Regulatory\Spark 4 and 5 Annuallnj Rept - 06-2006.doc
Enclosures
Disposal Wells 5-4 and 5-5 Injection Pressure
Spark Platform - North Trading Bay Unit
['- ÜÎS,,~' I
,_ "'=.s.~_
2,000
1,800
~
1,600 IIiî
) ,~
"
1,400 iI
g)
'w
Co 1,200
~
~
II)
II) 1,000
e
a..
c
0
:¡:; 800
u
Cþ
.....
.5
600
400
200
.~,p'
~ ¡¡¡¡I. '" ,,~ íìII II ~
I#~ , ~ IIiî
iIíi . iilliI.,
" "', ïiiïJ"lIIJ J'iìj '" " ~
, , . 1Iiî.
II!!! , .' ,,¡¡¡¡ 1!Iii\f.î.j ' ;jbJ
11£J ill ~~IIIII IIiìt
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b b b b b ~~ b ~~ ~~ f1~~ ~~ ~ b
~f:j ~f:j ~f:j ~f:j ;t(,f:j -s::f:j ~~
~\'6 ~\'6 'V~'6 ~~~ ~~~ tX·'6 ~t:f").:$ ~t:f'S ~~~ ~~flì ~OC; *,o~ (\.. <¡:)flì
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500
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/£ ~ /£.if
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& /£ &.
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OJ
Disposal Wells S-4 and S-5 Injection Volume
Spark Platform - North Trading Bay Unit
. S-4 /J, 8·5
&
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&
£iì, .íì.
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."""".~"':', ,~",~",,,,_.,:~.., 'f:.....,~,..,~.~--":"~."'~,.....'':.''''''''''-";()~ /"',~~,.."r',,:.v, ...-.·...."..c......·,..
~'\:j~
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~~ ~~ ~~ ~~~ f}:)e~ ~(;) ~'iS rJ
t..:~~ t..:+'I> ~+'l> tl;,ç:f)~ tl;,f:$)~ f)I"f R/(;p (I..*'O (I.. ~q;
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.-- .---- .-- ~, ----,..--.. ----...---
e
e
UIC File Review
Date:
Subject:
PTD #:
Orders:
Reviewers:
Initiating Action:
June 23, 2003
Unocal N. Trading Bay Unit (NTBU)
Spark Platform Well S-4 (Waste Disposal)
169-034
CO 69, 74, 108 (pressure maintenance-11/18/71) and 225
DIO 13
Tom Maunder, P.E.
Intent to perform MIT on Spark S-5
Review Summary--Well File
1. This well was drilled in June 1969.
13-3/8" @ 2132', w/1000 sx Class G w/10% gel followed by 400 sx Class G tail
9-5/8" ~ 10744', 1050 sx Class G.
2. Well was suspended pending completion as a water injector.
3. Well was completed in multiple zones for injection in early May 1972 and placed in service.
Injection ceased in January 1981.
4. The platform was "sold" to Marathon prior to the end of 1991 when Marathon proposed to SI the
well. The well was SI long term effective February 25, 1992.
5. In September 1996, Marathon submitted a sundry application to dispose of up 35000 bbls of
produced water from well S-2 (168-050) via the 13-3/8" x 9-5/8" annulus. Marathon proposed to
dispose of any produced water directly from the separator with surface pressures of up to 1000 psi.
Marathon's plans were to produce S-2 on during times of high demand (October - March).
6. Marathon provided further information in on October 15, where in their letter they attempted to
justify their choice of annular disposal. Their points were limited disposal volume likely and no
other really viable options.
7. Blair wrote an analysis and recommendation to the Commissioners on October 22. In that
document he separated the potential wastes into completion fluid/filtrate (eligible for annular
disposal and produced water (not eligible for annular disposal).
8. Sundry 396-187 was approved October 25, 1996. The sundry specifically states "Approve annular
disposal of completion fluids and filtrate for 90 days after production begins." A report of annular
disposal was required.
9. On February 11, 1997, Marathon requested an extension of 396-187 through the end of March to
accommodate the planned production period. In the application it was indicated that disposal
volumes had been low, on the order of 1 to 2 bpd with a pumping pressure below 200 psi.
10. Sundry 397-026 was approved February 12, 1997. No specific requirements are noted on the
sundry other than a report of disposal.
11. In early November 1997, Marathon proposed to perforate the tubing and 9-5/8" casing in multiple
intervals between 4594' and 5697'. Although it is not stated, fluids would then be pumped down
the 9-5/8" x 4-1/2" annulus rather than the OA.
12. The 404 filed in mid December 1997 indicates that Marathon was disposing of 7 bwpd at 735 psi.
200:t
M:\UIC File Reviews\030623-ntbuS-4-file-review.doc
13. Marathon submitted the first annual report of operations required by DIO 13 on September 23,
1998. Of note in the report is the substantial increase of produced water from S-02. In May 1998,
water production increased from 5 to 200 bwpd.
14. Marathon subsequently submitted an operations report in early October 2001. Spark well S-05 was
approved for disposal injection in September 1998. Following that approval, S~04 has been in back
up status.
Review Summary--DIO 13
1. On June 26, 1997, Marathon submitted an application for a Disposal Injection Order (DIO) to
allow disposal of the produced water from S-02 into the OA of S-04. Marathon erroneously
applied for a Class II authorization.
2. On July 29, 1997, Marathon submitted a revised application that more completely described the
applicability of annular disposal in this case.
3. On July 31, 1997, a hearing notice was published. The notice included a statement that this DIO
would require an exception to the regulation requiring an injection well to be completed with
tubing and a packer.
4. DIO 13 was issued September 12, 1997. The ordered specified in Rule 4 that the average daily
disposal rate could not exceed 5 bbl/day with the maximum disposal rate not exceeding 300
bbl/day. Rule 2 authorized pressure monitoring for demonstrating mechanical integrity.
5. In early May 1998, the water production from S-02 dramatically increased. Marathon applied for
a revision of the average daily disposal rate to 200 bbl/day. This was granted May 15, 1998.
There is no information in the DIO file regarding point 11 reviewed in the well file regarding
perforating the tubing and 9-5/8" casing and changing the disposal path to the 9-5/8" x 4-1/2"
annulus.
Conclusions
1. At this time Marathon has no immediate plans for S-04 other than to likely keep it available to
backup S-05.
2. The DIO allows disposal of water produced with natural gas via disposal in the OA. Such an
approval for production waste is likely unique in Alaska.
3. The well is presently configured with perforations through the 4-1/2" tubing and 9-5/8" casing
that eliminates the need to dispose of fluids via the OA.
4. The disposal perforations in the wellbore are within the approved interval as specified in the DIO.
Recommendations
1. No immediate action is necessary on well S-04 or DIO 13.
2. As time allows, the DIO should probably be "cleaned up" to better reflect the present
configuration of the well and the injection path.
Tom Maunder, PE
Sr. Petroleum Engineer
M:\UIC File Reviews\030623-ntbuS-4-file-review.doc
Marathon
Oil Company
P.O. Box 196168
Anchorage, AK 99519-6168
Telephone 907/561-5311
October 12, 2001
Ms. Wendy Mahan
Alaska Oil & Gas Conservation Commission
3001 Porcupine Dr.
Anchorage, AK 99501-3192
Reference: Report on Disposal Injection Operations
Well S-4 and S-5, Spark Platform, North Trading Bay Unit
Dear
Ms.
Mahan:
This annual report of disposal operations covers the period of June 1,1999 through June 30, 2001
for wells S-4 and S-5 on the Spark platform of the North Trading Bay Unit. Disposal via well S-4 is
governed by Disposal Injection Order (DIO) No. 13 for the North Trading Bay Unit (approved
September 17, 1997), and disposal via well S-5 is governed by DIO No. 15 approved August 31,
1998. Due to an oversight the report due on or about July 1,2000 was not submitted, therefore this
report covers a two year period.
Attached are four plots showing injection volume and injection pressure for wells S-4 and S-5.
Injection into well S-5 began on September 3, 1998. Since well S-4 is designated as a backup
disposal well for S-5, injection into S-4 largely ceased when injection began in S-5.
As. shown from the attached graphs, injection into S-5 from June 1999 through June 2000 was
within the conditions of the disposal injection order. Little injection has taken place since July 2000
due to problems with the sole producing well, S-2RD. A workover of S-2RD is currently under
evaluation. If this workover is implemented and is successful, injection operations will recommence
in S-5 with S-4 as the backup.
Sincerely,
.-..__...~
W. C. Barron
Operations Superintendent
N:\DRLG\SPARK~S-4\Spark 4 and 5 Annual Inj Rept - 10-2001 .doc
Enclosures
RECEIVED
OC ' ,
blO~ Oil ~ o,~,
·
40coots,e
A subsidiary of USX Corporation
Disposal Wells.S-4 and S'5 Injection Volume
Spark Platform- North Trading Bay Unit
900
· * · S-4[
8oo ..... · S.5~1"-"
700 ........................................
600
·
300 .............................................................. ~ ......... .-e .....................................................................................................
200 ...............................
100 .................... e ................
0
Disposal Wells S-4 and S-5 Injection Volume
Spark Platform- North Trading Bay Unit
o.~ ............................................................... - .............................. I' s-si
0.8 ..........................................................................................................................................................................................
0.7 ..........................................................................................................................................................................................
0.6 .........................................................................................................................................................................................
0.5 ..................................................................................................................................... ~ ....................................................
0.4 ...........................................................................................................................................................................................
Oa3 ..........................................................................................................................................................................................
0~2 .........................................................................................................................................................................................
0 ~1 ..........................................................................................................................................................................................
0 I I L II I II I [ I I I II ,111 I I
Disposal Wells S-4 and S-5 Injection Rates
Spark Platform- North Trading Bay Unit
1600
$
e~
lOOO .............................................. ? .............. -~, ........ e--~ .... ~--~ ........... -i.---~---~ .......................................................
800 ............................... ~- ....................... +--. ............................................ ~ ......................................................................
800 .................... ~- .......................................................... -~ .................................................. · ...................................................
400 .......................................................... . ....................................................................................................... t .......................
~00
..........................................................................................................................................................................................
Disposal Wells S-4 and S-5 Injection Rates
Spark Platform- North Trading Bay Unit
120
** ' I* s',l .... j
100 ..........
60 ~ .............................................................. : .........................................................................................................................
. .
III I I I III I
0 III ~ ,
Alaska R{
Domestic r ,v,,uction
Marathon
Oil Company
P.O. Box 196168
Anchorage, AK 99519-6168
Telephone 907/561-5311
September 23, 1998
Ms. Wendy Mahan
Alaska Oil & Gas Conservation Commissio~aska Oil & (~as Cons.
3001 Porcupine Drive Ancho?a~e
Anchorage, Alaska 99513-7599
Reference: Report on Disposal Injection Operations
_.~/..e.[j..~ Spark Platform, North Trading Bay Unit
Dear Ms. Mahan:
COMM - ~,~
RES ENG
_SR ENG
,NRO
,,SR GEOL
GEOL ASST -
STAT TECH -_
STAT TECH
,
FILE,
_
D~o P-;L.~ -
Disposal Injection Order (DIO) No. 13 for the North Trading Bay Unit well S-4 requires
that Marathon submit an annual report of disposal operations on or about July 1. This
report covers the period from the start of continuous injection in well S-4 in September
1997 to September 1, 1998. Next year's report will be prepared for the period of
September 1, 1998 to July 1, 1999, and will be submitted in July 1999.
Approval to inject produced fluids from well S-2rd into the annulus of well S-4 was
granted on September 12, 1997, and continuous production from well S-2rd began on
September 27, 1997.
Initially, injection in well S-4 was into the annulus of the 95/8" and 133/8'' casing strings.
Injectivity via this annulus was poor however, and in November 1997 Marathon
obtained sundry approval (#397-196) to inject into the annulus of the 4%" tubing and
9¥8" casing. Perforations were added (see wellbore schematic) to facilitate injection
into the high-quality disposal zones. This operation was successful in improving
injection into well S-4.
In May 1998, water production from well S-2rd increased greatly. Marathon asked to
increase the daily average injection allowable from 5 BWPD to 200 BWPD on May 8.
This request was granted by the AOGCC on May 15 for a six-month period. The
attached graph shows injection volumes and pressure into well S-4 since May 1998. In
general, water injection into well S-4 has been sufficient to produce well S-2rd at a
minimum rate. The graph shows that injection pressure tends to gradually climb in well
A subsidiary of USX Corporation Environmentally aware for the long run.
Report on Disposal Injection Operations
Well S-4, North Trading Bay Unit
September 21, 1998
Page 2
S-4, which is due to the buildup of trapped gas in the annulus. Note the drastic
reduction in injection pressure on July 1 after bleeding off trapped gas pressure from
the annulus.
The annular pressure measurements prior to August 1998 shown in the attached graph
are occasionally high due to incorrect placement of the annular pressure transducer
upstream of a choke. When the separator dumped fluid, the pressure transducer
briefly sensed separator pressure instead of true injection wellhead pressure. The
pressure transducer was moved directly onto the wellhead in August 1998, which
eliminated the pressure "spikes" seen in previous months. Ignoring these spikes, the
graphical trend clearly indicates that the AOGCC wellhead injection pressure limitation
of 1,000 psig was never exceeded.
A misunderstanding by Marathon operating personnel led to the AOGCC injection
volume limitation being exceeded for four days in August 1998. The Marathon person
on duty thought that the maximum allowable daily injection volume was 400 BVVPD
when in fact only 300 BVVPD was allowed. Actual injected water volumes exceeded the
allowable by less than 100 BVVPD for these four days. Marathon supervisory
personnel took corrective measures as soon as they became aware of the problem,
and since then the maximum daily injection volume has not been exceeded. Marathon
personnel monitor injection volumes into well S-4 continuously, and shut-in when the
300 BWPD limit is reached.
Sincerely,
·
ng~neer
JGFJnrs
M:\WP~OPNS98~JGE923.
Enclosures
1,400
1,200
1,000
800
600
4OO
Disposal Well $-4
Spark 'Platform, NTBU
---a--Injection Pressure
--e- Water Volume
500
t450
400
350
300 ~
250 ~
200 ~
150
2OO
100
5O
North Trading Bay Unit
Spark Platform, Well S-4
Marathon Oil Co., Alaska Region
Water Disposal Via
4-1/2" x 9-5/8" Annulus
11/28/97
SCSSV - Otis ball Valve @ 269'
· 13-3/8", 61#, J-55, BTC Casing @ 2132'
Tubing: 4-1/2", 12.6#, N-80, Butt.
4" Camco KBM Gas Lift Mandrels (all dummied)
2489'
4715'
6531'
7909'
8694'
8231'
9798'
Fish: 21' x 1-11/16" w/3.789" gauge ting
(11/23/97)
3-1/2", 9.2#, N-80, Butt. Tubing
10093'- 10341'
Plugged Perforations
G-1 10126'- 10138' (4 spt)
G-2 10149'- 10213' (4 spt)
G-3/4/5 10226'- 10337' (4 spt)
Plugged Perforations
H-1/2U 10356'- 10476' (4 spt)
H-2L/3 10484'- 10553' (4 spt)
H-3 10561'- 10592' (4 spt)
TD= 10770'
Tubing - Casing Perfs
4594' - 4624' DIL
4654' - 4684' DIL
5428'-5438' DIL
5523'-5543' DIL
5937'-5967'DIL
Tubing Restriction Aroung GLM @ 9231'
Tubing Bridge Plug ~ 9245'
Otis "XO" Sliding Sleeve @ 10057'
ID = 3.813"
Baker Retrieva-D Packer @ 10341'
Crossover (4-1/2" x 3-1/2") ~ 10093'
Portco "X" Nipple @ 10308'
ID = 2.750"
Portco "X" Nipple @ 10341'
ID = 2.750"
Baker Retrieva-D Packer ~ 10341'
Otis "Q" Nipple ~ 10364'
ID = 2.635"
9-5/8", 47#, N-80, BTC Casing ~ 10744'
Last Rev.: JGE, 12/29/97
1. Operations performed:
" STATE OF ALASKA
ALASKA oIL AND GAS CONSERVATION COJv,,v. SSlON
REPORT OF S'UNDRY WELL OPERATIONS
g:~cmn~drlg~spark~s.4\S4_404.XLS
Operation Shutdown Stimulate Plugging
Pull Tubing __ Alter Casing Repair Well
Perforate X
2. Name of Operator
MARATHON OIL COMPANY
3. Address
P. O. Box 196168, Anchorage, AK 99519-6168
4. Location of Well at Surface
2615' FNL, 2492' FEL, Sec 26-10N-13W, S.M.
At top of Productive Interval
3158' FSL, 4202' FEL, Sec 26-10N-13W, S.M.
At Effective Depth
At Total Depth
3220' FSL, 4504' FEL, Sec 26-10N-13W, S.M.
12. Present Well Condition Summary
Total Depth: measured
true vertical
5. Type of Well:
Development
Exploratory
Stratigraphic
Service X
10770' feet Plugs (measured)
10237' feet
Other
6. Datum Elevation (DF or KB)
115' KB above MSL feet
7. Unit or Property Name
North Trading Bay Unit
8. Well Number
S-4
9. Permit Number
69-34
10. APl Number
50-- 133-20184
11. Field/Pool
Hemlock & G-Zone
Tubing bridge plug {~ 9245' MD
Effective Depth: measured
true vertical
10700' feet Junk (measured)
10291' feet
Casing Length Size Cemented
Structural
Conductor
Surface 2132' 13-3/8" 1000sx
Intermediate
Production 10744' 9-5/8" 1050sx
Liner
Perforation Depth:
ORIGINAL
Measured Depth True Vertical Depth
2132' 2131'
10744' 10329'
measured
10126-10138', 10149-10213', 10226-10337', 10356-10476', 10464-10553', 10561-10592'
4594'-4624', 4554'-4684', 5428'-5438', 5523'-5543', 5937'-5967'
true vertical
9787-9797', 9807-9864', 9875-9973', 9990-10095', 10102-10145', 10169-10199'
4592'-4622', 4652'-4582', 5422'-5432', 5517'-5537', 5926'-5956'
Tubing (size, grade, and measured depth)
4-1/2", 12.6~, N-80, Butt tbg 0-10093'; 3-1/2", 9.28, N-80, Butt tbg @ 10093-10364'
Packers and SSSV (type and measured depth)
10087' Baker D Pkr; 10341' Baker D Pkr
RECEIVED
DEC 16 lgg?
Naska Oil & Ga Cons. Commission
Anchorage
13. Stimulation or Cement Squeeze Summary
Intervals Treated (measured) Perforated through tubing and 9-5/8" casing {~ 4594'-4624', 4554'-4684', 5428'-5438', 5523'-5543', and
5937'-5967' DIE Currently disposing via 41/z" x 9s~'' annulus.
Treatment Description Including Volumes Used and Final Pressure
14.
Representative Daily Avera,qe Production or Iniection Data
OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure
Tubing Pressure
Prior to Well Operation 0 0 7 950
Subsequent to Operation 0 0 7
15. Attachments 116. Status of Well Classification as:
Copies of Logs and Surveys run
I
Daily Report of Well Operations -~- Oil Gas Suspended
,
17. I hereby certify tl~t the foregoing is true a1~d correct to the best of my knowledge.
Signed '~ ~ '~~ Title Production Engineer
Form 10-404 Rev. 06/1~~
735
735
Service Annular disposal well
Date 15-Dec-97
Submit in Duplicate
MARATHON OIL COMPANY ,:~ DALLY WELL OPERATIONS REPC''''''-~ PAGE I OF I
DATE: 11/24/97
FILL DEPTH/DATE:
DATE LAST WL WORK:
WORK DONE:
PRESENT OPERATION:
PROBLEMS:
FIELD: N. Trading Bay Unit WELL #:
TUBING: 4-1/2" CASING: 9-5/8"
TREE CONDITION:
BENCHES OPEN:
Add perfs to increase injectivity
Spark S-4
Day #2, AFE 8001097
SUMMARY
0600
i0830
OF OPERATIONS
RU Schlumberger.
RIH w/3¥8" dummy. Tag solid on top of fish @ 9193' ELM. No difficulty picking up. Beat down on
fish several times, and fish dropped down hole. Chase fish down 100', then PU back through gas lift
mandrel. Getting a lot of drag in vicinity of GLM, but pull through. POOH.
030
330
RIH w/GRJCCL. Log tie-in strip from 4500' - 6100' ELM. POOH.
MU tool stdng to run Baker tubing bridge plug (model Delta-lAA, 6000 psi diff., 3-11/16" OD). RIH wi
BP to GLM @ 9231' MD. Attempt to work past spot where fish had hung up, but get stuck. Bridge
plug is at 9245' MD (14' below the top of the GLM). Unable to pull free. Set bridge plug @ 9245' MD,
and tool string pulled free. POOH.
,1630
LD setting tool. PU 33/8", 6 spf, 60 ° phase spiral HSD guns w/22.0 gm charges. SITP = 0 psig, 9%"
csg = 0 psig, 133/8'' csg = 220 psig. Tie previous GR/CCL strip into SP/DIL log. Perforate as follows:
Interval Comments
5,937' - 5,967' DIL
5,523' - 5,543' DIL
5,428' - 5,438' DIL
5,408'- 5,428' DIL
4,654' - 4,684' DIL
4,594' - 4,624' DIL
No change in csg or tbg pressure.
No change in csg or tbg pressure.
No change in csg or tbg pressure.
Guns misfired, DID NOT PERFORATE
133/8'' csg went from 220 psig to 210 psig.
No change in csg or tbg pressure.
During perforating operations the fluid level did not change in the tubing (850! to 900'), and no
pressure developed on the tubing or production casing. Decided not to go back and perforate
misfired interval from 5,408'- 5,428' MD.
0200
RDMO Schlumberger. Left wells S-4 and S-2rd shut-in pending installation of a line to dispose of
~fluids down the 9%" csg instead of 13%" csg.
Vendor Equipment Daily Cost Cumulative Cost
Schlumberger Electric line $47,200 $47,200
ERA Helicopters $2,300 $3,600
APC Roustabouts $1,600 $2,000
Baker Oil Tool Bridge plug, etc. $1,000 $1,000
Misc. Boats & trucking, etc. $4,700 $5,200
DAILY COST: $ 56,800 CUM: $ 59,000 REPORTED BY: J.G. Eller
MARATHON OIL COMPANY
DALLY WELL OPERATIONS REP~~''''~
PAGE 1 OF I
DATE: 11/23/97
FI LL DEPTH/DATE:
DATE LAST WL WORK:
WORK DONE:
PRESENT OPERATION:
PROBLEMS:
FIELD: N. Trading Bay Unit WELL #:
TUBING: 4-1/2" CASING: 9-5/8"
TREE CONDITION:
BENCHES OPEN:
Add perfs to increase injectivity
Spark S-4
Day #1, AFE 8001097
SUMMARY OF OPERATIONS
'0900
1030
1430
1630
1800
~1900
RU Schlumberger on well S-4.
Attempt to MU lubricator to Schlumberger union-half. Incompatible threads. Wait on 4W' EUE 8rd
box by 41/2'' buttress pin crossover. (Note: For future reference, Schlumberger in Kenai has an Acme
union-half w/internal 41/2'' buttress thds that will make up to the S-4 tree top.)
Crossover arrives on platform. Finish RU.
RIH wi 3.789" gauge ring. SITP = 0 ps/g, 9%" csg = 0 ps/g, 13%" csg = 250 psig. Gauge ring is
tagging up in vicinity of sliding sleeve @ 10,057' MD. Unable to work deeper, and getting significant
drag pulling up out of it. POOH.
Unable to pull up past gas lift mandrel @ 9,231' MD. Can move tool downhole easily, but after
~multiple attempts cannot get above GLM. Pull w/reline out of E/L head wi 2,600 lbs of pull, and finish
POOH. Fish consists of 1-11/16" head, CCL, weight bar, misc. fittings, and gauge ring. (Note:
Diagram of fish to follow.)
Secure well and SDFN.
Vendor Equipment Daily Cost Cumulative Cost
M/sc $500 $500
Helicopters $1,300 $1,300
APC Roustabouts $400 $400
DALLY COST: $ 2,200 CUM: $ 2,200 REPORTED BY: J.G. Eller
o~'.~'~l Dl-[VlilFiti, ll0ll ~11 ~ompany
'11- 4-~/ 'IU'IUAitl ' ancn0rage~
o :~XCELtSUNCX~n~gx;cc~S4AS~.XI.~
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
l. Type of Request: Abandon Su~par~l~ Ol~ati~ Shutdown~ Re-enter 8uspelxled Well_._
Alter Casing ~ Repair Wel__ Plugging ~ Time EIdenglon -..- $flrr~late
Change Approved Program Pul Tubing Variance Perkm~ X Other
Z. Nair.~ of Ope/u~r s. TyI~ of Well: e, Oa~m liilevatlm (DF or KB)
MARATHON OIL C...(~., PANY Development i 115' KB above MSL feet
3. Address Exptomtery ~ ?. Unit or Property Name
P. O. Bex tg6168, Anohora~le, AK 99~19-6168 Stratlgraphl~ N~h Trad~[~ Bay Un~
'-~. LOcation of Well at Surface ....... Sewtce ~ B. Well Number ' '
2015' FNL, 2492' FEL, Sa: 26-10N.t 3W, $.M. ' .......
^1: top of Productive Interval 9, Penllit 'Number
:3156' FSL, 420Z FEL, 8e~ 26-10N-13W, S,M, 69-34
At Effective Depth 10. APl Number ....
5O- 133-20184
At Total Depth 11. FleldlPed .....
3220' FSL, 4504 FEL, .$..,.ec. 2§-10N-13W, 3,M. Ht~lllook & G-Zon~
,~, ~ ,,,,,, ,,,
12. Pr~e,~t Well Condition 8urnmary
Total Depth: measured 10770' feet Plugs (rnessured)
true vadical 10237' feel
Effective Depth: measured 10700' feet Junk (measured)
true verll~at 10291' feet
Casing Length Size Cemented Meaeured Del~.h True Vertlcel Del~h
Structural
Conductor
Surface 2132' 13-3/8" 1000sx 21SZ 2131'
Intermediate
Production 107'44' 2-,.~8' 1050sx 10744' 1032g' ..... ~,:
Per~omtton Oepth: measured
10126-t0138', 10149-10213'. 10226-10337', 10356-10478', 10484-10~-~', 1056t.105~2'
true vetlcal
~.~, ·
ORIGIN ': .......
Pa~er~ ~ $~V (~e end measured
,.
13. Atta~hrnent~ 'D~-iptton Summary of Pr~osal_~X .... Detailed Operatt~n~ Pro~ __ BOP elicit'"
14, Ei,[{i~ateda Date for (~-rnir~n,alng Operation i l5."~tua of Well Classification as: ......
1 t117/97
18, If Proposal was Verbally Ap~areved OI1__ G~ISuspended.
Name ~ Approver Date Approved Ser~e Annular disfm~,..t ,well ....
,, ,,,, ,, ,,,, i,, -.
17, ! hereby Gs~fy ~ha~,~he fore§olng Is true alld ~on;ect'l° the best of my knowledge. "'
\ "'7',, \ ........... ~oncoMM~s~us~o~.y
Cc,,qe,~n~ of Appi ~ N~fy Comm-"~i0n so mpmsenlat?~n~ay wi{ness .....
Meollanloal
Original Signed By
F~w 10403 R~. 01~/15/IN~ ............
· C,O~3~j Sub. ~ in
,- ~m~'r B¥:~aratn0n 0il Company 907 276 7542;# 8/ 9
:11- 4-97 :iO:llA~I ; Anch0rago~
SPARK PLATFORM, WELl, S-4
TRADING BAY FIELD
ADD PERFORATIONS IN DISPOSAL ZONE
Add perforations to increase injectivity in water disposal zone.
1. Shut off injection into annulus of well S4 prior to arrival of d~trie line. Allow annular
pressure to bl~t off as much as possible.
2. MIRU electric line. Test lubricator to 4,000 psig.
3. RIH w/GR/CCL/durmny gun to 3 ~, (ID=2.992") crossover at 10,087' MD. Tie in and run
strip log. POOH.
4. MU and RIH wt through-tubing bridge plug for 4½", 12.6 ppfmbing (min. ID 3.813"
10,057' MD). Set bridge plug at 10,072' MD. POOH.
5. RIH w/3%", 6 spf, 60° phase spiral, HSD guns loaded w/:2:2.7 gm UltraJet charges and
perforate as ~bllows:
4594'- 4624' Dm (30')
4654'- 4684' DIL 00')
5408'- 5438' DIL (30')
5522'.~ 5544' DIL (229
5937'- 5967'Dm (30')
6. RDMO electric line. Resume annular injection.
JOE
November 4, 1997
- ~N'i' t~¥:~lara~hon Oil Company '11- 4-97 'iO'llA[~I '
.~.X_~~, ~.~.._~_?,,~_~, ~x ~ ....... ~
Anchorage~. 907 276 7§42;# 9/ 9
· ; , ~ -~,-lS'
, ~l PI .t~laFatfloll Ull ~ompany uut :-'.tD [~'~Z;g ~/ u
Alaska Region
Domestic Production
Marathon
Oil Company
P.O. Box 196168
Anchorage, AK 99519-6168
Telephone 907/561-5311
November 4, 1997
·
Mr. Blair Wondzell
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99513-7599
Reference: North Trading Bay Unit, Spark Platform, Well S-4
Dear Mr. Wondzell:
Please find attached a procedure for adding perforations in well S-4 in the
North Trading Bay Unit. Well S-4 is an annular disposal well, and the
perforations are being added to increase injectivity. There will be no change
in disposal status of this well. This work is expected to commence sometime
in November 1997. Please contact me if further information is needed.
Sincerely,
· Production Engineer
A subsidiary of USX Corporation Environmentally aware for the long run.
; Z-II-U/ ; Z;~UF~ Ancnorage~
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
,r, Type ,of Reque~C Al~ndon
AIl~r Casing
Change Approved Pro, mm
Name of Opera~*
MARATHON OIL COMPANY
Address
P. O. O~x 1~0168. Anohom~. AK ~1~168
L~n ~ W~I ~
~1~ FS~ 2~ FEC S~, ~-10N-13W.SM
At e~ of P~ Intel
31~ FSL, ~ FE~ ~, ~l~-13W-~M
AtEff~i~ ~
At Total Depfh
3220' FSL, ~ FEL, Sec, 26-10N-f3W-$M
Present Well C. mditlo~ Summary '"
Total Depth: measured
true vertical
Suspend ~ Operation Shutdown Re-enter Suspended Well
Repair Wellw Plugging .--- ~Time Extension stimulate ---
Pull Tubing...._ Vadartoe Perforate Other X
to~/'-- I' 7, Unit ot pr~e~-Name
phlo: ! North ?racllnl~l Say Unit
· X ~ a. Well Number "
'L.. S-4 ·
Iio/APl Nlanber .....
L_ so- ~33-2ole4
! 11. Fidd/Pool ' "
~G-Zona
1O770 feet
10237 fe~
Plugs (measured)
EffectNe De,h: measured
tree vertloal
10700 fee{ Junk (me~urad) 105gs'- 1070o' ~l
10~1 feet ·
Ca~lng
Structural
Conductor
Surface
Intermadista
PreduGlk~n
Uner
Perforation Depth:
Length Size Cemented Measured Depth True Vertical Depth
2132' 13 3/8" 1000 ~ 2132' 2131'
10744' gr:~8' 1050 ~X 10744' 10329'
messy'ed
10126-10138', 10149-10213', 10226'.1033T, 10356.10476', 1B484.1~, 10561.1059Z
true ve,lcal
9787-8797, gs07-g884', ~875-~73', 9990-1 (X)95', 10102-10145', 10169-10199'
Tul~g (s~, grade, and measured depth)
4-1/2", 12.t~ N~80 Butt tbg ~ 0-10093': 3-1/2", g.2~ N-80 Butt lbg ~ 10093-10354'
Packem and 855V (lype and measured d.pth)
10087' BeRet D Pkr; 10341' Baker D Pkr
ORIGINAL
~3,. A~chment~ Description aUmllla~ of P ~ro-";~___! Ovtaled Opi'ations Progm~
~4. Estimated Date for Commencing Operation ~ifleaUen a~:.
15. If Prowl wes Verbally Approval '
Name of Al~mVer L Date Al:~oved J S~ca Armuler Oisj:x:~d Well
17, I hereby certify th~ thatching is tree a~nd coffect to the best of my knowledge.
~ TiUe Produ~on Engineer
BOP Skel~h
Su~ended__
Date 2/11~97
.... FOR COMMISSION USE ONLY ~
I Rug Integrity BOP Test Local/on Clearance -
~o~ =f~ c~~ Original signed By
~m I~ Rw, ~1~ ' . · C ' '
Approved Copy
Returned
Alaska Region
Domestic Production
P.O. Box 198168
Anchorage, Alaska 99519
Telephone (907) 561-5311
FAX # 564-8489
DATE: 2/11/97
TIME: 2:43 PM
PLEASE DELIVER THE FOLLOWING PAGES TO:
NAME:
COMPANY/FIRM:
Blair Wondzell
AOGCC
FAX NUMBER: 276.7542
FROM:
NAME: Michael R. Olson
EXTENSION:
lAM TRANSMITTING 4
664.6315
PAGES INCLUDING THIS COVER PAGE.
IF TRANSMISSION IS NOT COMPLETE, PLEASE CALL: (907) 561-5311.
NOTE:
S-4: Sundry applicalion
Alaska,..,.~on
Domestic Production
Marathon
Oil Company
P.O. Box 196168
Anchorage, AK 995 ! 9-6168
Telephone 907/561-5311
February 11, 1997
David Johnston
Alaska Oil & Gas Conservation Commissio~
3001 Porcupine Drive
A~chorage, AK 99501-3192
Dear Mr. Johnston:
Please find attached Sundry Form 10-403, Application for Sundry
Approvals, requesting an extension to the existing Spark Platform
Well S-4 annular injection permit through March 31, 1997. A
permit was previously approved (approval #96-187) for a 90 day
period following initial production from S-2rd. The permit is set
to expire February 17, 1997.
s-2rd began production On'November 20, 1996 following
installation of gas processing equipment on the remotely operated
Spark Platform. Due largely to software and telemetry problems,
coupled with minor mechanical problems, the gas system was not
fully commissioned until January of 1997. Total up-time was only
29%. The following table summarizes S-2rd production data:
, , ,
Prod. Time Gas Prod . Water
_. , , (hours) (mscf) Prod/Inj** (bw)
,
,,
·
November, 1996 6 2,500 1
,,
, ,
December, 1996 124 23 016 8
, i . ,,~ , ,
January., 1997 457 106,949 34
,
February, 1997, 0 0 0 "
,
,
Total 587 132,465 43 " '
*through February 11, 1997
**approximate water volume injected into S-4 annulus
DUe to the lim/ted injection data, it has been difficult to
evaluate S-4's annular injection program. The data recently
gathered, however, indicates this well will be an ideal
A subsidiary of USX COrl~oration
Environmentally aware for the long run.
candidate. Injection pressures are currently at 170-200 psig @
1-2 bpd injection rate.
Well S-2rd is currently produced only when there is a demand for
the gas. Marathon,s plans call for S-2rd to be available for
production through the end of March, 1997. The well will then be
SI until next winter season. I am requesting an extension of the
annular disposal sundry through March 31, 1997. I am currently
working on an application for Underground Injection (20 AAC
25.252) for S-4 and anticipate having it for your review by
February 28, 1997.
If you have any q~/estions, please contact me at 564-6315.
Sincerely,
Production Engineer
Attachments
cc:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request:
Abandon Suspend Operation Shutdown
Alter Casing ~ Repair Well Plugging__
Change ApProved Program Pull Tubing ~ Variance
Re-enter Suspended Well
Time Extension Stimulate
Perforate Other X
2. Name of OperatOr
MARATHON OIL COMPANY
3. Address
P. O. Box 196168, Anchorage, AK 99519-6168
4. Location of Well at Surface
2615' FSL, 2492' FEL, Sec. 26-10N-13W-SM
At top of Productive Interval
3158' FSL, 4202' FEL, Sec. 26-10N-13W-SM
At Effective Depth
At Total Depth
3220' FSU 4504' FEL, Sec. 26-10N-13W-SM
5. Type of Well:
Development .....
Exploratory ~
Stratigraphic __
Service X
6. Datum Elevation (DF or KB)
115' KB above MSL
feet
7. Unit or Property Name
North Trading Bay Unit
8. Well Number
S-4
9. Permit Number
69-34
10. APl Number
50-- 133-20184
11. Field/Pool
Hemlock & G-Zone
12. Present Well Condition Summary
Total Depth: measured
true vertical
10770 feet Plugs (measured)
10237 feet
Effective Depth: measured
true vertical
10700 feet Junk (measured) 10595' - 10700' fill
10291 feet
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation Depth:
Length Size Cemented Measured Depth
2132' 13 3/8" 1000 sx 2132'
10744' 9 5/8" 1050 sx 10744'
measured
10126-10138',10149-10213',10226'-10337',10356-10476',10484-10553',10561-10592'
true veflical
9787-9797',9807-986~,9875-9973',9990-10095',10102-10145',10169-10199'
Tubing (size, grade, and measured depth)
4-1/2", 12.6# N-80 BUtt tbg @ 0-10093'; 3-1/2", 9.2# N-80 Butt tbg @ 10093-10364'
Packers and SSSV (type and measured depth)
10087' Baker D Pkr; 10341' Baker D Pkr
ORIGINAL
True Vertical Depth
2131'
10329'
13. Attachments Description Summary of Proposal__ Detailed Operations Program. BOP Sketch
Request for disposai
14. Estimated Date for Commencing Operation 115. Status of Well Classification as:
10/31/96
If Proposal was Verbally Approved Oil __ Gas
Name of Approver Date Approved
16. Suspended__
Service Annular Disposal Well
17. I hereby certify that the foregoing is true an/~rrect to the best of my knowledge.
Signed-.....~'"~.... -,,. ~.~ ~,//,//~ Title Production Engineer Date .
FOR COMMISSION USE ONLY
Conditions of Approval: N. otify Commission so representative may witnes.s IApproval No. ....,
Approved by Order of the Commission nfl-i-al ginned BY c~'w;~a~.o, er. _ Date/O"i;~ ~:~
,-,-,u ....... " ~-'" '-',',:,u ~,Opy Subr~it in T'riplicate
Fo,m,O.40,,ev. 06,,5,,8 0avid W. Johnston eturne_d
MARATHON OIL COMPANY
SPARK PLATFORM WELL S-4
Request for Disposal
Applicant:
Marathon Oil Company Date: September 19, 1996
P.O. Box 196168
Anchorage, AK 99519
Telephone: (907) 564-6315
Facsimile: (907) 564-6489
Attention: Michael Olson
Required information per 20 AAC 25.080
(1) Application for Sundry approval - Form 10-403 attached.
(2) Designated well: Marathon requests approval to annularly
inject produced fluids into Well S-4. S-4 is located on the
Spark Platform, Lat. N60~' 55' 42", Long. W 151° 31' 50",
offshore Cook Inlet, Alaska (see attached map).
(3) Depth to the base of fresh water aquifers: There are no
drinking water aquifers above the disposal zone. The AOGCC
has already exempted aquifers in similar geologic settings
beneath the surface at Granite Point, McArthur River, Middle
Ground Shoal and Trading Bay fields. Ail of these fields
lie in Cook Inlet as does the well proposed in connection
with this notice.
(4) Depth and Thickness of the receiving zone and the confining
zone: Depth of injection will be between 2132' md (13-3/8"
casing shoe and 7045' md (Top of Cement for the 9-5/8"
casing string - calculated). The receiving zones total 355'
of thickness. The shallowest interval to likely receive
fluid is 4590' md; the deepest interval is 7040' md. There
are no open hole logs above 2100' md for S-4. Based on S-1
open hole logs (with in 1/4 mile radius of S-4), the
confining layer is between 1500' and 2100' md and is
believed to consist of 10-20' coal layers separated by tight
siltstone (See attached S-1 open hole log).
(5) List of all publicly recorded wells within 1/4 mile and all
publicly recorded water wells within one mile of the well to
receive drilling waste:
Public recorded wells:
@ 2000': S-l, S-ltd, S-2, S-2rd, S-2D2, S-3, S-5, S-7, S-
7rd, S-8, S-9;
@ 4600': S-l, S-3, S-8
@ 6000': S-3
Public recorded water wells:
None
(6)
(7)
(8)
(9)
Estimate of maximum volume and density of waste slurry to be
disposed: The produced fluids to be disposed of should
consist of a density of 8.46 #/gal. The initial production
test for Well S-2rd UG-5 sand indicated 0 BWPD produced;
however, water production may increase as additional sands
are perforated. We are requesting the maximum of 35,000
bbls of produced fluid for disposal in Well S-4 annulus.
Maximum anticipated injection pressures at the outer casing
shoe: Produced water will be injected directly from the
separator to the annulus. A high pressure shutdown switch
is installed on the production separator liquid discharge
line to prevent the injection pressures from exceeding 1000
psig. The pressure at the casing shoe at 2132' md is:
0.44 psi/ft (hydrostatic gradient) * 2132' (tvd of 13-3/8"
casing shoe) + 1000 psig (surface injection pressure) = 2000
psig.
Details that show the shoe of the outer casing is set below
the base of any freshwater aquifer and cemented with
sufficient cement to provide zone isolation: The 13-3/8"
shoe is located 2132' md. The 13-3/8" casing was cemented w/
1400 sacks of class G cement. Records indicate good cement
returns were received at surface. No cement bond logs were
run. Based on S-1 open hole log, there are no fresh water
zones below 600' md.
Details that show the inner and outer casing strings have
sufficient strength in collapse and burst to withstand the
anticipated pressure of disposal operations: The 13-3/8"
casing is rated to 3090 psig burst - assuming no back side
pressure. The maximum pressure anticipated at 2132' is 2000
psig. The 7" casing is rated to 4750 psig collapse -
assuming no internal hydrostatic pressure. The maximum
pressure anticipated at 7045' md is 4100 psig.
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I ~ i
I NORTH TRADING BAY UNIT I
I I Cook Inlet, AIosko ,
I I STRUCTURE MAP
I
I I TOP HEMLOCK PROOIJ~Ie JNTERVAL I
I NORTH TR~OIN6 B~Y LINI? .~
,m mm mmmm em mm mmmmm mm mm m m m m mm m mm em mm mm mm mm
_1
MEMORANDUM
Oil and Gas Conservation Commission
State of Alaska
To'
David Johnston
Tuckerman Babcock
Date' October 22, 1996
File' S4wdisp.doc
From: Blair Wondzell
Sub'
Annular disposal of work-over
and produced fluids, Spark
Platform, Trading Bay Field
Situation: Marathon Oil Company plans to produce gas from well S-2rd on
the Spark Platform, Trading Bay Field, North Trading Bay Unit (NTBU). On a
drill stem test, the well produced gas without any water production.
However, at this time the tubing probably contains completion fluid; with
continued production of gas, minor water production will probably occur
(eventually up to 5 bbl. per day is expected). Disposal of this water is the
problem.
Analysis and Recommendations: The completion fluid and early produced
fluids (probably mud filtrate) are clearly drilling/workover fluids and come
under the annular disposal regulations 20 AAC 25.080. Long term produced
fluid would be formation water and would therefore come under the normal
disposal well regulation 20 AAC 25.252. I propose that we approve
Marathon's 10-403 proposal to pump completion fluids and mud filtrate into
the 9-5/8" by 13-3/8" annulus of NTBU well S-4 until 90 days after
productions starts; after that time, fluid disposal would be under the normal
disposal well regulation 20 AAC 25.252.
Options: Several options for disposing of the completion fluids and produced
fluids from NTBU well S-2rd have been considered, they are: 1) disposal to
Cook Inlet from the platform is not economic due to the equipment and man
power required to treat the small volumes of water expected; 2) there is no
enhanced recovery on this platform so it can not be used for that purpose; 3)
it can not be pumped down the tubing in an existing well because they have
been killed with mud to secure them in a safe condition; 3) It would be
uneconomic to store the water on the platform and barge it ashore or to an
approved facility; 4) it can not be shipped ashore in a separate line because
there is only one line to shore; 5) it can not be sent ashore with the gas for
onshore separation and disposal because this would cause the gas line to
"water load"; and (6) annular disposal is a viable option.
The best option appears to dispose of it down the annulus of Spark well S-4.
The problem with this option is that an annulus does not fit the criteria of a
normal disposal well nor does the fluid type match that which can normally
be pumped down an annulus. However, the fluid in the tubing to be
unloaded prior to production could be considered a drilling (completion) waste
and could properly be pumped down the annulus of well S-4; the water
production which is expected in the future is not a drilling waste.
Marathon's proposal: Marathon submitted a 10-403 request to dispose of
the wellbore-load fluids and future produced water from NTBU well S-2rd
down the annulus of well S-4. The data required by 20 AAC 25.080 for
annular disposal has been furnished except data on the confining and
receiving zones; data required by 20 AAC 25.252(c) for a disposal well has
been submitted as follows: (1) a plat; (2) a list of affected operators; (3) an
affidavit is not necessary; (4) (5) Logs of the disposal well previously
submitted; (6) construction of the disposal well; (7) (8) estimated average
and maximums injection pressure; (9) (10) and (11) data on the aquifer
exemption.
Produced water will be injected directly from the separator to the annulus. A
high pressure shutdown switch is installed on the separator liquid discharge
line to prevent the injection pressures from exceeding 1000 psig. Mike
Olden with Marathon told me that some years back they checked to see if
the annulus was open, at that time it would take fluid (at Iow rates) without
pumping.
Well construction: N. Trading Bay Unit well S-4 was drilled and completed in
June, 1969 by cementing 13-3/8" 61 # J-55 surface casing at 2,132' with
1400 sx of "G" cement (had good cement returns to surface) and by
cementing 9-5/8" 47# N-80 casing at 10,744' with 1050 sx of "G" cement.
The well was completed as a water injection well - our records show that
cumulative injection has been 13,322,174 bbls of water. The last injection
was in January of 1981; the well was secured in February, 1992.
Aquifers: Prior to our taking over primacy of the Alaska Class II UIC
program, EPA exempted the aquifers at Trading Bay Field; the citation
147.102 is as follows:
(b) The following aquifers are exempted in accordance with the provisions of
144.7(b) and 146.4 of this chapter for Class II injection activities only:
(2)The portion of aquifers beneath Cook Inlet described by a 1/4 mile area
beyond and lying-directly below the following oil and gas producing fields:
(iv) Trading Bay Field.
Alaska Region
Domestic Production
Marathon
Oil Company
P.O. Box 196168
Anchorage, AK 99519-6168
Telephone 907/561-5311
October 15, 1996
David Johnston
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501-3192
Dear Mr. Johnston:
A sundry for Well S-4 annular injection was submitted to the
AOGCC on September 19, 1996 for the disposal of produced fluids
from Well S-2rd. Marathon is completing the construction work to
tie S-2rd into the CIGGS system and would like to begin
production at the end of October, 1996. Approval of the S-4
sundry, however, is required prior to commencing production.
Disposal of produced fluids down an existing platform well bore
is the most efficient and environmentally safe way of handling
these fluids. Other options were evaluated however none were as
viable as disposing of the produced water down the S-4 annulus.
Existing wells have all been killed with mud and injection down
the tubing is queStionable. Storage of produced fluids on the
platform would result in a higher potential for spills as well as
additional operational costs required for transporting fluids by
barge. Not separating the produced fluids from the gas on the
platform would decrease efficiencies of the pipeline (from water
loading) and could result in pipeline freezing problems when the
well is shut-in for extended periods.
Due to the limited volumes we expect to dispose of, S-4 annular
injection is a sound and efficient solution. Based on Well S-
2rd's DST, water production is estimated initially at 0 bwpd,
however water production will likely increase over time. Other
dry gas wells Marathon operates at Beaver Creek, Kenai Gas Field,
and Sterling initially started out at 0 bwpd and gradually
increased to 5 bwpd (condensation). During the initial unloading
of this well, we may also produce a small volume of well bore
fluid remaining from the workover. A conservative estimate of
produced water is less than 100 bbls (including wellbore cleanup)
this winter season.
RECEIVED
OCT 1 6 1996
A subsidiary of USX Corporation
Naska_011 & Gas (tops C0mmlssi0n
~-nwron~l;l~a~l~ware for the long run.
Please let me know if there is anything we can provide you to
help expedite approval of the S-4 annular injection sundry.
Sincerely,
Michael R. Olson
Production Engineer
cef
RECEIVED
OCT 1 ~; lg95
Alaeka OH & Gas Conj. Commlallon
Anohorage
Alaska Rb~,on
Domestic Production
Marathon
Oil Company
P.O. Box 196168
Anchorage, AK 99519-6168
Telephone 907/561-5311
september 19, 1996
Blair W0ndzell
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501-3192
Dear Blair:
Enclosed is the AOGCC application for sundry approval to dispose
produced fluids from Well S-2rd into the 13-3/8" by 9-5/8"
annulus of Well S-4. Also enclosed is information requested by
20 AAC 25.080.
Well S-2rd was completed in UG-5 sand in August, 1994. Plans are
currently underway to install production facilities on the
platform and begin gas production by October 30, 1996.
Well S-2rd will be produced only during peak demand periods
between October through March, and shut-in for the remaining year
unless gas demands require additional production.
Although S-2rd was tested with no water production, we anticipate
some water production over the long term. This is why we are
requesting approval to inject produced fluid down the annulus of
Well S-4.
If you have any questions, please contact me at 564~?~1¢.!,~,.., i.-_~ ,,-~ ~;~:'~'~~ "? ~'~'
Sincerely,
Michael R. Olson
Production Engineer
ORIGINAL
Attachments
cc: CEF
A subsidiary of USX Corporation Environmentally aware for the long run.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request:
Abandon Suspend Operation Shutdown
Alter Casing Repair Well Plugging
Change Approved Program m Pull Tubing Variance
Re-enter Suspended Well
Time Extension Stimulate
Perforate Other X
2. Name of Operator
MARATHON OIL COMPANY
3. Address
P. O. Box 196168, Anchorage, AK 99519-6168
4. Location of Well at Surface
2615' FSL, 2492' FEL, Sec. 26-10N-13W-SM
At top of Productive Interval
3158' FSL, 4202' FEL, Sec. 26-10N-13W-SM
At Effective Depth
At Total Depth
3220' FSL. 4504' FEL, Sec. 26-10N-13W-SM
5. Type of Well:
Development
Exploratory
Stratigraphic
Service X
6. Datum Elevation (DF or KB) ~
115' KB above MSL feet
7. Unit or Property Name
North Trading Bay Unit
8. Well Number
S-4
9. Permit Number
69-34
10. APl Number
50-- 133-20184
11. Field/Pool
Hemlock & G-Zone
12. Present Well Condition Summary
Total Depth: measured
true vertical
Effective Depth: measured
true vertical
10770 feet Plugs (measured)
10237 feet
10700 feet Junk (measured) 10595' - 10700' fill
10291 feet
DUPLICATE
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation Depth:
Length Size Cemented Measured Depth True Vertical Depth
2132' 13 3/8" 1000 sx 2132' 2131'
10744' 9 5/8" 1050 sx 10744' 10329'
Tubing (size, grade, and measured depth)
4-1/2", 12.6~ N-80 Butt tbg @ 0-10093'; 3-1/2", 9.L~ N-80 Butt tbg @ 10093-10364'
Packers and SSSV (type and measured depth)
10087' Baker D Pkr; 10341' Baker D Pkr
measured
true vertical
9787-9797', 9807-9864', 9875-9973', 9990-10095', 10102-10145', 10169-10199'
13. Attachments Description Summary of Proposal__ Detailed Operations Program BOP Sketch
Request for disposal
14. Estimated Date for Commencing Operation 115. Status of Well Classification as:
I
10/31/96
Oil ~ Gas ~
Service
16. If Proposal was Verbally Approved
Name of Approver
Date Approved
Annular Disposal Well
Suspended
17. I hereby certify that the foregoing is true and/c~rrect to the best of my knowledge.
Title Production Engineer Date ~~~'.
FOR COMMISSION USE ONLY
IApproval No. ~ ~ .~ ~
Conditions of Approval: Notify Commission so representative may witness I ~ ~ ~ --/~ V
Plug Integrity BOP Test Location Clearance ~ .
-- Mechanical ,n~ity Test. , Subsequent Form Required 10-~~. ,' ~~~ ~~D~X
Approved by Order of the Commission Original Signeo u5 Commissioner Date IO~5-~
~o~ ~o.~o~,~v. ~,,s,~ David W. Johnston Approvea Copy Submit in Triplicate
Retu?od
MARATHON OIL COMPANY
SPARK PLATFORM WELL S-4
Request for Disposal
Applicant:
Marathon Oil Company Date: September 19, 1996
P.O. Box 196168
Anchorage, AK 99519
Telephone: (907) 564-6315
Facsimile: (907) 564-6489
Attention: Michael Olson
Required information per 20 AAC 25.080
(1) Application for Sundry approval - Form 10-403 attached.
(2) Designated well: Marathon requests approval to annularly
inject produced fluids into Well S-4. S-4 is located on the
Spark Platform, Lat. N60~' 55' 42", Long. W 151'~' 31' 50",
offshore Cook Inlet, Alaska (see attached map).
(3) Depth to the base of fresh water aquifers: There are no
drinking water aquifers above the disposal zone. The AOGCC
has already exempted aquifers in similar geologic settings
beneath the surface at Granite Point, McArthur River, Middle
Ground Shoal and Trading Bay fields. All of these fields
lie in Cook Inlet as does the well proposed in connection
with this notice.
(4) Depth and Thickness of the receiving zone and the confining
zone: Depth of injection will be between 2132' md (13-3/8"
casing shoe and 7045' md (Top of Cement for the 9-5/8"
casing string - calculated). The receiving zones total 355'
of thickness. The shallowest interval to likely receive
fluid is 4590' md; the deepest interval is 7040' md. There
are no open hole logs above 2100' md for S-4. Based on S-1
open hole logs (with in 1/4 mile radius of S-4), the
confining layer is between 1500' and 2100' md and is
believed to consist of 10-20' coal layers separated by tight
siltstone (See attached S-1 open hole log).
(5) List of all publicly recorded wells within 1/4 mile and all
publicly recorded water wells within one mile of the well to
receive drilling waste:
Public recorded wells:
@ 2000': S-l, S-lrd, S-2, S-2rd, S-2D2, S-3, S-5, S-7, S-
7rd, S-8, S-9;
@ 4600': S-l, S-3, S-8
@ 6000': S-3
Public recorded water wells:
None
(6)
(7)
(8)
(9)
Estimate of maximum volume and density of waste slurry to be
disposed: The produced fluids to be disposed of should
consist of a density of 8.46 #/gal. The initial production
test for Well S-2rd UG-5 sand indicated 0 BWPD produced;
however, water production may increase as additional sands
are perforated. We are requesting the maximum of 35,000
bbls of produced fluid for disposal in Well S-4 annulus.
Maximum anticipated injection pressures at the outer casing
shoe: Produced water will be injected directly from the
separator to the annulus. A high pressure shutdown switch
is installed on the production separator liquid discharge
line to prevent the injection pressures from exceeding 1000
psig. The pressure at the casing shoe at 2132' md is:
0.44 psi/ft (hydrostatic gradient) * 2132' (tvd of 13-3/8"
casing shoe) + 1000 psig (surface injection pressure) = 2000
psig.
Details that show the shoe of the outer casing is set below
the base of any freshwater aquifer and cemented with
sufficient cement to provide zone isolation: The 13-3/8"
shoe is located 2132' md. The 13-3/8" casing was cemented w/
1400 sacks of class G cement. Records indicate good cement
returns were received at surface. No cement bond logs were
run. Based on S-1 open hole log, there are no fresh water
zones below 600' md.
Details that show the inner and outer casing strings have
sufficient strength in collapse and burst to withstand the
anticipated pressure of disposal operations: The 13-3/8"
casing is rated to 3090 psig burst - assuming no back side
pressure. The maximum pressure anticipated at 2132' is 2000
psig. The 7" casing is rated to 4750 psig collapse -
assuming no internal hydrostatic pressure. The maximum
pressure anticipated at 7045' md is 4100 psig.
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AtlanticRichfieiaCom~any .
NORTH TRADING BAY UNIT
Cook inlet, Alaska
STRUCTURE MAP
TOP HEMLOCK PRO(X~NG INTERV~
I NORTH TR~IDIN~ E~IY UN/T
STATE OF ALASKA ' ' 0
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF'SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown m Stimulate__ Plugging
Pull tubing Alter casing __ Repair well __
Perforate __
Other ~ .~
2. Name of Operator
Marathon 0il Company
3. Address
P.O. Box 102380 Anchorage, AK
4. Location of well at surface
2,615' FSL, 2,492' FEL,
At top of productive interval
3,158' FSL, 4,202' FEL,
At effective depth
9951(]
5. Type of Well:
Development
Exploratory
Stratigraphic m
Service _Z..
Sec. 26-10N-13W-SM
Sec. 26-10N-13W-SM
At total depth
3,220' FSL, 4,504' FEL, Sec. 26-10N-t3N-SN
12. Present well condition summary
Total depth: measured
true vertical
10,770' feet
10,237' feet
Effective depth: measured 10,700'
true vertical 10,291 '
Casing Length
Structural
Conductor
Surface
2,132'
Intermediate 10,744'
Production
Liner
Perforation depth: measured
Size
feet
feet
Plugs (measured)
Junk (measured)
Cemented
6. Datum elevation (DF or KB)
Z Unit or Property name
North Trading] Bay
8. Well number
feet
Unit
9. Permit number/approval number
10. APl
3 J--20184
Field/Pool
Hem]ock& G-Zone
10,595' - 10,700' (fill)
Measured depth
True vertical depth
13 3/8" 1,000 sx 2,132' 2,131'
9 5/8" 1,050 sx 10,744' 10,329'
true vertical
See Attachment #1
Tubing (size, grade, and measured depth)
4-1/2", 12.6# N-80 Butt tbg @0 - 10,093';
Packers and SSSV (type and measured depth)
10..087' Baker "D" Pkr.' 10.341' Baker "D"
13. StimUlation or cement squeeze summary
Intervals treated (measured)
Treatment description including volumes used and final pressure
10,093'
Pkr.
- 10,364', 3-1/2", 9.2# N-80 Butt
APR 1 T 1992'
Alaska Oil & Gas Cons. Com~.[sst
Anchorage
14.
Prior to well operation
Subsequent to operation
Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Md Water-Bbl Casing Pressure
Tubing Pressure
0
0
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations _~.
16. Status of well classification as:
Oil ~ Gas ~ Suspended
Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed Title
Form 10-40~ Rev 06/15/88
Engineering Supv
Date .~/~,/~ ~.
/
SUBMIT IN DUPLICATE
Attactmeet-II
SPARK NELL S-4
G-ZONE
MD
10,126' - 10,138'
10,14g' - 10,213'
10,226' - 10,337'
TVD
9,787' - g,797'
g,807' - g,864'
9,875' - g,g73'
HEMLOCK
10,356' - 10,476'
10,484' - 10,553'
10,561' - 10,592'
9,ggo, - 10,095'
10,102' - 10,145'
10,169' - 10,199'
All Perfs are 4 SPF from 4" Csg guns
\Spark\S4.doc
RECEIVED
APR 1 ? 1992
Alaska Oil & 6as Cons. com~'~ss~ot~
Rn~tu~'age
Attachment #2
SPARK WELL S-4
Daily Well Operations Report
2/25/92
Installed pressure gauges on tubing and 9-5/8" casing.
Tbg : 0 psi. Csg. = 0 psi.
Well shut in with all valves on tree closed.
\Spark\S4.doc
RECEIVED
APR 1 ? lgg~-
Alaska Oil & Gas Cons. Commissio~
Anchorage
A'~tachment ~-'3
RL CEIVED
APR 1 7 1992
Alaska .Oil & Gas Cons. Commission
~chorage
· m
" ' STATE OF ALASKA .
ALASKA OIL AND GAS CONSERVATION COMMISSION 0
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __
Alter casing __ Repair well __ Plugging ~ Time extension __ Stimulate ~
Change approved program ~ Pull tubing __ Variance __ Perforate ~ Other _X.
2. Name of Op.erator
Marathon Oil Company
3. Addr~s.~)o BOX 102380 Anchorage, AK 99511
4. Location of well at surface
2,615' FSL, 2,492' FEL, Sec.
At top of productive interval
3,158' FSL, 4,202' FEL, Sec.
At effective depth
Atto~,~,~l FSL, 4,504'
5. Type of Well:
Development X
Exploratory __
Stratigraphic __
Service ~
26-10N-13W-SM
26-10N-13W-SM
FEL, Sec. 26-10N-13W-SM
6. Datum elevation (DF or KB)
115' KB above MSL
i~)U n,i[ cf,.Property na~e
run mraa~ng ~ay Unit
8, Well number
5-4
9. Permit number
69-34
10. APl number
'l:.~p- 20184
1~ Field/Pr)ol
i~a'loc[ & 6-Zone
feet
12. Present well condition summary
Total depth: measured
true vertical
Effective depth' measured
true vertical
10,770' feet
10,237' feet
10,700' feet
10,291 ' feet
Plugs (measured)
Junk (measured)
10,595' - 10,700' (fill)
Casing Length
Structural
Conductor
Surface 2,132'
Intermediate 10,744'
Production
Liner
Perforation depth: measured
Size
true vertical
Tubing (size, grade, and measured depth)
4-1/2", 12.6# N-80 Butt tbg
P~c~?~ql S~SaVk(teYCe ~p,~ mP. asure, d d~.nth~
D Pier., 1~,'341'
Cemented
Measured depth
True vertical depth
13 3/8" 1,000 sx 2,132' 2,131'
9 5/8" 1,050 sx 10,744' 10,329'
RECEIVED
See
- 10,093'; 10,093'
Baker "D" Pkr.
Attachment #1 DEC 1 ? 199t
Alaska 0il & Gas Cons.
Anchorage
- 10,364', 3-1/2", 9,2# N-80 Butt tb,
13. Attachments 1, 2, Description summary of proposal ._Z
&3
Detailed operations program
BOP sketch
14. Estimated date for commencing operation 15. Status of well classification as:
January 2, 1992
16. If proposal was verbally approved Oil __ Gas __ Suspended __
Name of approver Date approved '-Service Zn,jector - $;l:
17. I hereby certify that the foregoing~is true and correct to the best of my knowledge.
Signed ~~ ~ Title Operations Enqineerin,q Superv. Date
FOR COMMISSION USE oNLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity __ BOP, Test __ Location clearance __
Mechanical Integrity Test ,~ _ Subsequent form required 10-
Approved by order of the Commission
Form 10-403 Rev 06/15/88
OBIOiNa) SIGNED BY
~ n~r~lr-. N RMITH
~t.,-,(.~ - -- -.~ '
jApproval No.
uy~¢,¢ OO~¥
---"~0mmissioner Date
SUBMIT IN TRIPLICATE
G-ZONE
MD
10,126' - 10,138'
10,149' - 10,213'
10,226' - 10,337'
Attachment #1
SPARK WELL S-4
HEMLOCK
TVD
9,787' - 9,797'
9,807' - 9,864'
9,875' - 9,973'
10,356' - 10,476'
10,484' - 10,553'
10,561' - 10,592'
9,990, - 10,095'
10,102' - 10,145'
10,169' - 10,199'
All Perfs are 4 SPF from 4" Csg guns
\Spark\S4.doc
RECEIVED
DEO 1 7' 1991
Alaska Oil & Gas Cons. Commission
Anchorage
Attachment #2 ~'~
SPARK WELL S-4
Well Securing Procedure
le
Ensure pressure gauges on tubing and casing are calibrated.
Ensure SCSSV control line pressure is bled to zero.
Leave well SI - no other work required.
\Spark\S4.doc
RECEIVED
DEO 1 1 1991
Alaska Oil & Gas Cons. Commission
Anchorage
"t
.I
A'~tachment "'""~
t
RECEIVED
DEC 17 t991
Alaska Oil & 6as Cons, CommiSsion
Anchorage
I
"/"1 $'~
Atlantic~RichfieldCompany North AmeriCan Producing Division
"~ South Al~'SkT'~'~strict
Post Office box 360
Anchorage, Alaska 99501
Telephone 907 277 5637
B. C. Anderson
District Engineer
April 20, 1972
State of Alaska
Department of Natural Resources
Oil & Gas Division
3001 Porcupine Drive
Anchorage, Alaska 99504
Attention Mr. Homer L. Burrell
Gent lemen:
Re: North Trading Bay Unit S-4
Permit No. 69-34
We are enclosing State of Alaska Form P-3, Subsequent
Notice of Commencement of Water Injection, for NTBU well
S-4o
Very truly yours,
B. C. Anderson
BCA/RI:sr
Enclosure
APR 2 1972
DIVISION OF OIL AND (SAS
Form P--3
. tLEV. 9-30-6 9
Submit "Intentions" in Triplicate
~ & "Subsequent Reports" in Duplicate
STATE O'F ALASKA
OIL AND GAS CONSERVATION COMMITTEE
SUNDRY NOTICES AND REPORTS ON WELLS
(Do not use this form for proposals to drill or to deepen
Use "APPLICATION 'FOR P'EH.~iT-L' 'for such'p~o~osal~J . .
1.
O~L ~-~ G^S [] OT.ER Water Injection
WELL WELL
2. NA~IE OF OPERATOR
Atlantic Richfield Company
3. ADDRESS OF OPERATOR
P. 0. Box 360~ Anchorage~ Alaska 99510
4. LOCATION OF WELL
At surface
2615' N & 2492' W from SE Corner, Sec. 26, TiON, Rl~g,
SoMe
13. ELEVATIONS (Show whether DF, RT, GR, etc.
115 '
Check Appropriate Box To Indicate Niat'ure of NOtice, Re
NOTICE OF INTENTION TO:
TEST WATER 8HUT-OFF
FRACTUaE TREAT
SHOOT OR ACIDIZE
REPAIR %VELL
PULL OR ALTER CASINO
MULTIPL~ COMPLETE
AaANDON'
CHANOE PLANE
~Other)
5. AP1 ND-MERIC~ CODE
50-133-20184
6. LEASE DESIGNATION AND SERIAL NO.
ADL 35431
7. IF IN'DIA.N. ,~T.T.O'A'FI~E OR TRIBE NAME
s. VmT, F~M OR ~r~SE NA~E
North Trading Bay Unit
9. WELL NO.
S-4 (22-26)
10. FIELD A~D POOL, OR WILDCAT
NE. 0il Pool--Hemlock & "G" Zones
11, SEC., T., R., M., (BOTTOM HOLE OBJECTIVE)
Sec. 26, T10N, R13W, S.M.
12. PE-I~2~IIT NO.
69-34
~o., or Other Data
SUBSEQUENT RBPORT OF:
WATER SHUT'OFF J I REPAIRINO WELL
FRACTURE TREATMENT ALTERINO CASING
SHOOTING OR AClDIZINO ! ] AaANDONMENT'
(Other)Commencem~ of Water Injectio~--~
(NOTE: Report results of multiple completion on Well
Completion or Recompletion Report and Log form.)
15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any
proposed work.
Water injection commenced in well S-4 on 4/19/72 at 3:15 p.m.
Pertinent initial injection data for the first 16 hours of injection are as follows:
Surface Injection Pressure - _l_8_00_p. aiK
Final Injection Rate C-~6~0 ~WPD~
APR 2 1197
DIVISION OF OiL AND CAS
,~,N~H~ ~. ~,-,
16. I hereby ~f, ~~correct
SIGNED
~. c. Anderson
TITLE District Engineer DATE
4/20/72
(This space for State office use)
APPROVED BY
CONDITIONS OF APPROVAL, IF ANY:
TITLE DATE
See Instructions On Reverse Side
SUBJECT
ATLANTIC RICHFIELD COMPANY
PAGE NO.
North Alaska District
Drilling Group BY DATE
12-12-71
I ~ ; .i ~ :f ,. ; uamco si d& pocket mandrel
,, ~ ,
.
/ , ,- { ~, ,
~ 10,090 ~/~'~ ~4/'x~ . . 16 Seal assembly
' '~ ~ ~ d ~ = . ' '. . 3-1/2 9 2~ N-80 butt tbg
'~' ' ~ ~ · ~--~
~ , · 1 t 3-1/2, tub~n
~ t . :, ~ q ~ · 7 ', ' ,, ~,, , ·
, ., ~ ~ ~ ~ ~ ' '. . .. 3-1/2 ported, X: n~pple
, , ~ , ~ -~"I0;337' ....... ~ ..................' ~ : ....
:10;350 ;~ : ~ " J 16' seal assembly
, . ' ~" ~ '10 356'. 3-1/2","~", nipple
, . , ;, , . , . 4~ t~ er shear sub
I ~ ' ~ ~ t " ' ' ' ~ ' '
~t · ~ ' : I ' ' " ' '
Atlant[cRichfieldCo~Pa~y
North A~i,~an Producing Division
North Ala District
Post Offic,~-Box 360
Anchorage, Alaska 99501
Telephone 907 277 5637
January 24~ 1972
State of Alaska
Department of Natural ResOurces
0il & Gas Division
3001 Porcupine Drive
Anchorage, Alaska 99504
ATTENTION: Mr. Homer Burrell'
North Trading Bay Unit
Well' S-4 (22'26)
Permit 69-34'
Gentlemen:
Attached is a P-3 'Subsequent Report of selective zone
completion as a water injector for the above mentioned
well' '
Very truly yours,
N. Bell''
Sr. Dist. Dr.lg, Supervisor
B/WTJ/mm
Enclosure:
Form 1~--3
REV. 9-30-6 9
"Intentions" in Triplicate
& "Subsequent Reports" in Duplicate
STATE O'F ALASKA
OIL AND GAS CONSERVATIO,N COMMITTEE
SUNDRY NOTICES AND REPORTS ON WELLS
(Do not use this form for proposals to drill or to deepen
use "APPLICATION 'FOR ~'EP,~iT-L'' 'for such 'p~o~osalsJ .. ,
O,LWZLL ~--] GASW~LL [] OTHE, Water Insection
2. NAME OF OPERATOR
Atlantic Richfield Co~pan¥
3. ADDRESS OF OPERATOR
P. 0. Box $60~ Anchorage ~ Alaska ~10
4. LOCATION OF WELL
At surface
2615' N & 2492' W fr SE cr Sec 26, T10N, R13W, SM
13. ELEVATIONS (Show whether DF, RT, OR, etc.
~. APl N~CAL CODE
50-~-20184
6. LEASE DESIGNATION A.ND SERIAL NO.
ADL 3}431
7. IF I1N-DIA/~, AJ.,LO'I-r~M~ OR TRIBE NAME
8. UNIT, FArM OR LEASE NAME
North ~rading Bay
9. WELL NO,
, $-4 ('22-26)
10. FLELD AND POOL, OR WILDCAT
NE 0il Pool-Hemlock & "G" Zones
11, SEC., T., R., M., (BOTTOM HOL~
OBJECTIVE)
Sec 26~ T10N, R1}E~ SM
12. PIiIR1VIIT 1VO.
11~' KB
J 69-' 4
Check Appropriate Box To I,ndicate Nmture of NOtice, Report, or Other Data
NOTICE OF INTENTION TO:
TEST WATER SHUT'OFF PULL OR ALTER CASINO
FRACTUSE TREAT i ' ' MULTIPL][~ COMPI,ETE
SHOOT OR ACIDIZE ABANDON$
REPAIR WELL CHANGE PLANS
iOther)
SUBSEQUENT RmPOBT OF:
WATIR SHUT-OfF [ REPAIRINO WmLL
FRACTURE TREATMENT --- ALTERING CASING X~
SHOOTING OR ACIDIZINO , ABANDONMENTs
(Other) Complete as Water In.~eetor_
(Now~: Report results of multiple ~ompletion on Well
Completion or Reeompletion Report and Log form,)
!5. D~:SCR,~£ I'ROP0SZD OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any
proposed work.
Beg~.n operations 1-5-72.
Displaced mud w/sea water ~ 6000'. Tested pipe rams & Hydril to 1500 psi OK. Drilled out
cement and float collar 10650-10700'. Ran G-R & CBL 10700-9750'. Shot four 1/2" holes/ft
10354-10100'. Tested casing 15 mAn OK. Ran GR from 1.0684-9750'. Shot four 1/2" holes/ft
10592-10561', 10553-10484', 10476-10371' & 10332-10226'. Cleaned out hole to 10625'.
Ran & set 9-5/8" retrievable packer ~ 10341' (top) w/bottom ~ 10349'. Ran & set 9-5/8"
retrievable packer ~ 10087' (top) w/bottom ~ 10095'. Ran. 7 jts 3-1/2" 9.2# N-80 buttress
tubing on 320 its 4-1/2" 12.6# buttress tubing. Ball valve ~ 269'. Gas lift valves ~
2490', 4715', 6531', 7909', 8694', 9231' & 9798'. Bottom of shoe ~ 10364'. Tested
control line & ball valve w/5000 psi OK. Installed tree & tested w/3000 psi OK.
Released rig ~ 4:00 PM 1-13-72.
Selective zone injection well.
16. I hereby certify that ~lf~foregoi~A~_ true and correct
(This space ~r ~ate office use)
TITLE Sr. Dist. Dr] g. 2uperv~sor DATE
APPROVED Bt
CONDITIONS OF APPROVAL, IF AN~:
TITLE DATE
See }nstrucfions On Reverse Side
'~Atlant~CRichfieldCompany
North American Producing Division
North Ala~istrict
Post Office ~,'ox 360
Anchorage, Alaska 99501
Telephone 907 277 5637
January 3,' 1972
State of Alaska
Department of Natural Resources
Oil & Gas Division
3001 Porcupine Drive
Anchorage, Alaska 99504
ATTENTION: Mr. O. K. Gilbreth
Gent lemen:
Attached please find the completion assembly for
Well S-4 on the "Spark" Platform.
Very trul~ yours, "
.... ~"~?
B. T. Loudermilk
Dist. Drlg. Supervisor
BTL/WTJ/m~
Enclosure:
AtlarRicRichfieldComPany North American Producing Division
Alaska Distr--,
,~60
~ Post Office ~..
Anchorage, Alaska 99501
Telephone 907 279 1411
August 5, 1969
Mr. Homer L. Burrell, Di rector
Department of Natural Resources
Division of Oil and Gas
State of Alaska
3001 Porcupine Drive
Anchorage, Alaska 99504
OKG
KLV
HWK
REL
FILE
Dear Mr. Burrell'
Re'
Trading Bay Field- NE Oil Pool
Well 'No. S-4 (22-26)
The followi.ng enclosures are being filed as a part of the
Completi on Report:
1. Form P-7 (filed in duplicate)
2. Daily Well History (filed in duplicate)
3. Directional Survey (filed in duplicate)
This well's status is "Temporarily Suspended" as approved
by Sundry Notice dated July 11, 1969.
Very~uly yours,
R. W. McCleskey, Jr. ~
Seni or Dri 11 ing Engineer
RWM: ve
Enclosures
Form P--7
/:.. SUBMIT IN DUPLIC/.
~iATE OF ALASKA (See o{~er in-
structions on
reverse side)
OIL AND GAS CONSERVATION COMMITTEE
i
WELL cOMPLETION OR RECbiVIPL~TION REPORT AND
WELL W ELL DRY 0 ther
b. TYPE OF COMPLETION: Temporarily
BACK P~ESVR. Other
EN
~VELL
NAME OF OPERATOR
At]antic Ri chfi el d Comp ,a.n,¥~ ~'
ADDRESS OF OPERATOR :~
~0C ~ O, "'F WELL (R'e~ort l~cation clearlff ~nd~in a6c~?]~e with any ~tate t~q~it~$)*
At su~ace
261-5' N & 249~,' ~o,~r.~ cr, Sec 26 T10N, R13W SM
At top prod. interVa ep ~ 9
ot perforated '
t tota~ ~
2065'S & 776'E fr NW ct, Sec 26, T10N, R13~, SM
ORIGINAL
§. AP1 N~IER/CAL CODE
APT GO-1 33.~F)l R4
6. LEASE DESIGNATION A/~D SERL4~ NO.
, ADL 35431
7. IF INDIAN, ALI.~TTEE OR TRIBE NAME
,:
UNIT,FAPAVI OR LEASE NAME
Trading Bay Field
9. 'WELL NO.
S-4 #22-26
~0~.~L~ ~ POOL; OJ~.WZ~CA~, . ,
!j, ra. al ~no. u~ay .ri e) a--Heml aCK
R.E. Ull POOl
SeC 26, 110~, R13~,
12; P ~EB/VIIT
69-34
6-3-6'9 /, I 6-27-69 '- J 6-29-69 ' J 115 KB I 40'
18. TOTAL DEI:~H,"MD & TVD[lO. PLUG; BA. CK MD .& T~'D~2O. IF.1V~JLTI~LE CO~L., J 21. INTERVALS DRILLED BY
0 .... - 'J - ~ m- ~W~Y* J ROTARY TOOLS CABLE TOOLS
] ,/7OMo (T0,~352 V~) 10~666: ~O do_26~n)'~ No I All -
m. traDucING ~VAL(S). OF ~S ~T~0~, Bd~OM. N~E (~ A~ ~)' ' ~. W~ DIRE~ON~
perforated SURV~ ~DE
Not
,m
24. TYPE ELECT-RIC AND_OTHER LOGS RUN
DIL, FDC
."~ ~-~. ' CASING RECO1LD (Report all strings set in w~ll)
CASING SIZE %VEIGHT. HOLE SIZE CEAIY_a. NTII~G RECOI~)
A_NiOUN'T PULLED
26. LINF~R R~CO~D
-, SIZE '& TOP (AID) BOTTOM (MD)
None _
~8. PEI~'OI:I. ATIONS OPF_~ TO
SACKS CEMEATT* '
None
(interval. size and number)
30. -: PRODUCTION
DATE FIRST PI~ODUCT~ON I P~ODUCTION METI{OD (Flow,s.g, gas lift, pumping--size and type of pump)
None ~to be completed later as water injector
DATE OF TEST, II-iOU~S T~STED 'JCttO-T<E SIZE PROD'N FOR OIL---B]DL. GAS---1V~CF.
TEST PE~JIOD
31. ~mPOS~T~ON OF aXS (Sold, used ~or fuel, vented, etc.)
- ' s~. hST o~' ATTACH~ENTS
27.. TUBIATG R]~OOB,D
SCREEN (MD) SIZE DEPTH SET (1V~D) J PACKER SET (~)
None ;' ' ' j
I
29. ACID, SH0r, F~'URE, C~T SQU~ZS, ~C.
~-~ ~v~ (~n)'J ~o~'r ~ m~~~-- u~ ~
l
Nnn~
W~6~ ~ (~o~o~ o~
~x~ut-in)
temp. suspended
i
jWA~B~. ]OIL ORAVITY-~I (C~.)
TEST WITNESSED BY
33. I hereby certlfy/t~at t~le fol~e~oing a~l attached information is complete and correct as determined from allravailable records
. !%. ~, I'llJb I UU r~uy~ ~O ['. _ ' " ....
*(See Instructions and Spaces For Additional Data on Reverse Side)
INSI~RUCTIONS
General: This form is de, signed for ;submitting a.c0'mplete and correct well .completion report and tog on.
.
all;types of' lands and leases in AlaSka. .~ ·
Item: 16: Indicat:e ~ghich elevation is Used. as refe;rehce (~here not Otherwise shown) for depth measure-
ments given'in c;ther spaces on'4his,form and in any ~ttachments.
Items20, ~nd~22:: If'this'well~'is completed.for sepa?'~¥b;'"pr0ductioh ~rom more than one interval zone
(multiPle completion'), so state in item 20, and in item 22 show the prcd'ucing interval, or intervals,
top(s), bottom(s) and name (s) (if'.ahy) for o:~ly the inferV~'l: reported :in item 30. Submit a separate report
.(Page) on this form, adequately identified, for e~ch additional i,.nte~val to.~ seperately p~oduc~ show- ing the a~.itional data pertinent to' such interval. "' ' ?.:, '"
I~m2~: "Sacks Cement"¥:~: Attached Supplemental ..;recO.r:ds for',thiS .well should .show the de~ils of .any mu!:
tiple Stage cementing and the location of the cementing ~ol.
I'~m 28: SUbmit a separa.te completion re~rt on.,this,~fo~,m {or~e~ch inter~l to
(~ ,instruction for i,fems.r20.~d 22 above)
T .,
" 34. SUMMAI~Y OF PO~'V~ATION TESTs INC~UDIN(; INT~VAL T~TED
,
~ ~. CO~ DATA, A~ACH BRIEP,~ D~CRIP~ONS~k. OF LITHOLOGy,
, AN~ D~FEc~D '~.OWS OF OIL,
_
. , ,
ATLANTIC RICHFIELD COMPANY
PLATFORM
SPARK
NTBS S-4
No. 22-26
Leg 3 Slot 1
Casing History
13 3/8" at 2132'
9 5/8" at 10,744'
Spud
673/69
Complete
6/29/69
RNAT~O
A TLA"<T I C RICHFIELD
NTBS S-4 ~'~0. 22-26
PLATFOR~ SOARK LEG 3 SLOT 1
ELEVATION 115 K.B,
RECORD OF SURVEY
ALL CALCULATIONS PERFORMED BY I B ~ ELECTRONIC CO!qPUTER
TRUE
'JEAS. DRIFT VERTICAL
DEPTH ANGLE DEPTH
D ~
SUB DRIFT
SEA DIREC
DEG,
TOTAL CO!)i~:D i NATES
C L 0 5 0 ~ E 5
D I STANCE AN~Lt
D M S
DOG
DEG/IOOFT DISTA:~CE
SLOT 1 FROM CENTER LEG 3 NORTH'4,~2 AND EAST 0,09
63 0 0 63.00 -51,99 N 0 E 4.42 N 0.09 E
88 0 9 87,99 -27.00 S 41W 4,36 N 0.04 E
113 0 4 112,99 -2,00 S 87 W 4,36 N 0.00 E
138 0 9 137,99 22,99 S 88 W 4,36 N 0,06 W
163 0 15 162.99 47.99 S 83 E ~,34 N 0.04 E
188 0 9 187,99 72,99 N 81 E ~,35 N 0,11 E
213 0 9 212,99 97.99 N 33 E 4,41N 0.15 E
238 0 19 237,99 122.99 N 42 E ~,52 N 0,24 E
263 0 15 26~,9g 147,99 N 45 E ~.60 N 0.32 E
288 0 19 287.99 172,99 N 41 E 4,70 N 0.41E
313 0 15 312e99 197e99 N 18 E 4,80 N 0,45 E
338 0 9 337e99 222,99 N 4 W 4,87 N 0.44 E
363 0 15 362,99 247,99 N 51W 4,93 N 0,35 E
38~ 0 24 387,99 272,99 N 72 W 4,98 N 0.18 E
413 0 45 412e99 297,99 N 85 W 5,01N 0.14 W
~23 0 49 422.99 307,99 N 87 W 5,02 N .0.28 W
ABOVE INFORMATION FROM. SPERRY SUN GYRO SURVEY NO, SU-3-16350
502 4 0 501,80 386,80 N 20 E
593 3 30 592.63 477,63 N 31 E
834 2 30 833.40 718.40 N 39 E
1203 1 30 1202.27 1087.27 N 46 E
'1557 1 15 1556,19 1~41,19 N 15 E
~150 1 0 2149,10 2034,10 S ~7 W
.~232 1 15 3230,84 311'5,84 N 65 W
3761 1 30 3759.66 3644.66 N 67 W
10.20 N 1.59 E
14,96 N 4.45 E
23.13 N 11,07 E
29,84 N 18.02 E
37,30 N 20,02 E
36.75 N 9.68 E
45,73 N 11,70 W
52.1~ N 24.45 W
4,42 N 1 9 59 E
4,36 N 0 34 ~'7 E
4.36 N 0 7 21E
4,36 N 0 47 36 W
4,35 N 0 37 ~8 E
~.36 N 1 32 3 E
4.~2 N 2 0 22E
4.52 N 3 8 29 E
4,72 N 5 3 50 E
~,S3 N 5 2~ 13 E
4.89 ~; 5 13 15 E
4.98 N 2 7 5 E
5.01N 1 37 2 ~
5.02 N 3 15 43 W'
10,32 N 8 54 24 E
15.61 N 15 35 b2 E
25,64 N 25 35 5 E
34.86 N 31 7 51 E
42.33 N 28 13 33 E
3~.0~ N 14 4~ ~9 E
48.17 N 14 3 38 w
5'?.59 N 25 7 21 w
O,uO0 1,2~
U,640 1.27
0.~77 1.30
0.320 '1.37
1,535 1,26
0.423 1,20
0,521 1.18
0,55b 1,t2
0.28~ 1,07
0,291
0,531 .1
0,~72
0,647 1.32
1.485
5,463 1,54
0.960
0,449 -3.59
~,278 -8.20
0.048
4230 2 15 4228.30 4113,30 N 59 W
4451 3 15 4448,94 4339.94 N 65 W
4512 3 70 4509,83 4394,83 N 60 W
4935 4 30 4931,52 4816.52 N 59 W
5658 5 45 5650.89 5535,89 N 55 W
6105 9 45 6091,47 5976,43 N 51W
6206 9 15 6191.12 6076.12 N 70 W
626g 10 0 6257,16 6138.16 N 74 W
6330 11 30 6312,93 6197,93 N 74 W
6B60 12 15 6342,25 6227,25 N 72 W
6599 17 15 6570,50 6455.50 N 69 W
6780 20 15 6740,31 6625,31 N 66 W
7142 21 45 7076,54 6961,54 N 65 W
7241 21 15 7168,81 7053,81 N 74 W
7302 21 BO 7225,57 7110,57 N 74 W
7481 22 45 7390.64 7275,64 N 75 W
7771 23 0 7657,59 7542.59 N 76 W
7965 23 30 7835,50 7720,50 N 78 W
8183 27 30 8035,42 7920.42 N 76 W
8470 24 30 8296,57 8181,57 N 77 W
8706 24 45 8510.90 8395,90 N 80 W
8918 24 BO 8703,81 8588,81 N 79 W
9146 24 45 8910,86 8795,86 N 79 W
9427 26 0 9163.43 9048.43 N 80 W
9614 26 15 9331,14 9216,14 N 81 W
9828 26 45 9522,24 9407,24 N 81W
10021 27 15 9693,82 9578.82 N 82 W
10175 27 45 9830.11 9715,11 N 81 W
10331 28 0 9967,85 9852,85 N 82 W
10770 29 0 10351,80 10236.80 N 77 W
61.62 N 40.23 W
66.92 N 51.58 W
68,78 N 54,8.i W
85.87 N 83.26 W
127.42 N 142.59 w
175.06 N 201,42 W
180,61N 216.68 W
183,63 N 227.20 W
186.98 N 238.89 W
188.99 N 2~4,9~ W
214,35 N 311.11W
239,83 N 368.3~ W
296,52 N 489.91 W
306.41 N 52~.40 W'
312,57 N 545,89 W
330.49 N 612.75 W
B57,90 N 722.70 W
373.98 N 798.37 W
~95.01N ~82.71W
~21,79 N 998.68 W
438,94 N 1095.98 W
495.72 N 1182.28 W
473.93 N 1275.98 W
495.32 N 139'7.29 W
508.26 N 1478.98 W
523.33 N 157~.12 W
535.63 N 1~61,63 W
546.84 N 1732.45 W
557,0~ N 1804.97 W
73.59 N ~3 8 19 W
84.50 N 37 37 39 W
87,95 N 38 33 3 W
119,61 N 44 6 49 w
191.23 N 48 12 57 W
266.87 N 49 0 19 ~
282.09 N 50 11 12 W
292e13 N 51 3 11 W
303,36 N 51 P~ 55 W
309,35 N 52 21 10 w
377.80 N 55 26 O W
~3~.53 N 56 b5 52 W
572e66 N 5~ 48 55 W
607.36 N 59 42 7 W
~29,05 ~ 60 12 17 W
696.20 N 61 39 35 W
~06.47 N 6~ 39 1~ W
881.62 N 64 53 59 W
957,07 N 05 53 29 W
1084~10 N 67 6 12 W
1180.61N 68 10 25 W
1267.07 N 68 55 13 W
1361,1~ N 69 37 25 W
148~e49 N 70 28 92 W
156~,88 N 71 2 3 W
1658,83 N 71 36 3~ W
1745.83 N 72 7 59 W
1816,71 ~ 72 2~ b~ W
1888,98 ~'~ 12 50 56 w
~'~ 2101,30
604,91N 2012.35
ABOVE INFORMATION FROM SPERRY SUN SINGLE SHOT SURVEYS
0.169
0,~33
0.237
0.180
3,i29
1.594
2.459
2,851
2.11b
1.740
3.367
0.~10
0.729
0.159
0,482
0.360
0.376
0,540
0,229
0.110
0,470
0,271
0,234
0.350
0.442
0.3~0
0.589
~9.34
?2,97
105.25
2~4.78
261.00
271,94
290.4~
~1.20
4~3e45
~92,32
79~.9Z
873.92
1079,33
1117.28
i~bg.4b
1563.38
1745,79
1888.9~
21~1.11
MOTTO~ HOLE CLOSURE 2101,30 FEET AT N 73 16 8 W
'~EASURED DEPTH AND OTHER DATA FOR
EVERY EVEN
100 FEET
OF
SUB SE A
DEPTM,
TRUE
N, EASURED VERTICAL SUB
DEPTH DEPTH SEA
~D-TVD
DIFFERENCk
VERTICAL
CORRECTION
TOTAL
COORDIhATES
215 215. 100·
315 315, 200.
415 415, 300,
515 515, 400,
615 615, 500.
715 715, 600,
816 815, 700,
916 915, 800,
1016 1015, 900,
1116 1115, 1000,
1216 1215, 1100,
1316 1315, 1200,
1416 1415, 1300,
1516 1515, 1400,
1616 1615, 1500,
1716 1715. 1600,
1816 1815, 1700,
1916 1915, 1800,
2016 2015, 1900,
2116 2115, 2000,
2216 2215, 2100,
2316 2315, 2200,
2416 2415, 2300,
2516 2515. 2400,
2616 2615, 2500,
2716 2715, 2600.
2816 2815, 2700.
2916 2915, 2800.
3016 3015, 2900.
3116 3115, 3000,
3216 3219, 3100,
3316 3315, 3200,
3416 3415, 3300,
3516 3515, 3400,
3616 3615, 3500,
3716 3715, 3600,
3816 3815, 3700,
3916 3915, 3800.
4017 4015, 3900,
0
0
0
0
0
0
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
2
0
O
0
0
0
0
1
O
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
4.42
5,01
10,89
15,72
19,11
22.50
24,61
26.43
2B,25
30,10
32,21
34,32
36.43
37.24
37,15
37,06
36.97
36,88
36.79
37,36
38.28
39,21
40,13
41,05
41,97
42,89
43,82
45,66
47,59
48.61
49,64
50,66
51,68
53.26
55.28
57,31
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
0.17
2,01
5,0'7
7,82
10.56
12,61
14,49
16.37
18.09
19,22
19.78
18.99
17,25
15,51
13,76
12.02
10,28
8,38
6,40
4,42
2.45
0,47
1.50
3,48
5,45
7,43
9,41
11.~9
1~,73
16,1~
18.55
20,96
23.37
26,31
29.68
33,05
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
W
W
w
W
W
W
W
w
W
w
W
W
W
4117
4217
4317
4417
4517
4617
4718
4818
4918
5019
5119
5220
5320
5421
5521
5622
5723
5825
5926
6027
6129
6230
6332
6436
6541
6646
6753
6860
6968
7076
7183
7291
7399
7507
7616
7725
7834
7943
8052
8161
827O
8380
849O
8600
8711
8820
8930
9040
4115,
4215,
4315.
4415,
4515.
4615,
4715,
4815,
4915,
5015,
5115,
5215,
5315,
5415,
5515,
5615,
5715,
5815,
5915,
6015,
6115,
6215,
6315,
6415,
6515,
6615e
6715,
6815,
6915e
7015,
7115,
7215.
7315,
7415,
7515,
7615,
7715,
7815.
7915,
8015,
8115.
8215e
8315,
8415,
8515,
8615,
8715,
8815,
4000,
4100,
4200.
4300.
4400,
4500,
4600,
4700.
4800.
4900,.
5000,
5100,
5200,
5300.
5400,
5500,
5600.
5700,
5800.
5900.
6000,
6100,
6200,
6300,
6400,
6500,
6600e
6700,
6800,
6900,
7000,
7100,
7200,
7300.
7400.
7500.
7600.
7700,
7800.
7900.
8000,
8100,
8200,
8300,
8400,
8500.
8600.
8700,
2
2
2
2
2
2
3
3
3
4
5
5
6
6
7
8
10
11
12
14
15
17
21
26
31
53
61
68
76
84
92
101
110
119
128
137
155
165
175
185
196
205
215
225
0
0
0
0
0
0
1
0
0
1
0
1
0
1
0
1
1
2
1
1
2
1
2
5
5
7
7
8
7
8
8
8
9
9
9
9
9
9
9
10
10
10
11
9
10
10
59.33 N
61,35 N
53,70 N
56,10 N
68,99 N
73.04 N
77,10 N
~1.15 N
85.20 N
90.69 N
96.47 N
102,25 N
108.02 N
113.80 N
119,57 N
125,35 N
13~.35 N
145,17 N
155,98 N
166,80 N
176,37 N
181.77 N
187,12 N
197,04 N
208,17 N
221,02 N
236.03 N
252.42 N
269,28 N
286.14 N
300,64 N
311,42 N
322,28 N
332,99 N
343,26 N
353.53 N
363,09 N
372,13 N
382,35 N
392,86 N
403,17 N
413,42 N
423,26 N
431,27 N
439e30 N
447.99 N
456,70 N
36,41
39,78
49,84
55,16
61,90
68.65
75,W0
82.14
90,14
98,39
106.64
114,99
123,14
131,38
139,63~
1~1,15
177.86
191,22
205,03
220.73
239,31
266,03
295,02
326,10
359,80
395,34
431,50
~67,66
504,28
541,89
582,11
622.79
663,97
705,16
747e12
789,65
~31,91
874,10
918,09
962,~5
1007.04
1052,44
1097,82
11~2,~5
1187,34
1232,60
W
W
w
w
w
w
w
W
W
W
W
W
W
w
W
w
W
W
w
W
W
W
W
W
w
W
W
w
W
W
W
W
W
W
W
W
W
W
w
W
9151 89~, 8800,
9262 90 * 8900.
93?3 9115, 9000.
9~8~ 9215, 9100,
9596 9315. 9200.
9708 9~15'e 9300,
9820 9515e 9~OOe
9932 9615, 9500.
100~5 9715, 9600.
10158 9815. 9700,
10271 9915. 9800.
236
2~+7
258
269
~281
293
3).?
11 ~7~.28 N 1277,97 w
11 ~B2,75 N 1~26,00 W
11 ~91,22 N 137~,03 W
11 ~99.30 N 1~22,~1W
12 507,01N 1471,12 W
12 51e,87 N 1~20,73 W ~
12 522,76 N 1570,51 .W
12 529,98 N 1621,~3 W
13 b37,37 N 1672,63 W
13 545,60 N 172~,60 W
13 553,13 N 1777o15 W
INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH,
TRUE
MEASURED VERTICAL SUB
. DEPTH DEPTH SEA
TOTAL COORDINATES
1000 999, 88~,
2000 1999, 1'88~,
3000 2998, 2883,
4000 3998, 3883,
5000 ~996, ~881,
6000 - 5987, 5872,
7000 69~. 6829,
8000 7867, 7752,
9000 8778, 8663,
10000 9675* 9560-
26,15 N
36.89 N,
56,11 N
89,61 N
169*29 N
27~,28 N
377,36 N
'~62.27 N
53~. 29 N
/0770 ·
i
Form P--3
REV. 9-30-67
STATE OF ALASKA
Submit "IntentionsP in Triplicate
& "Subsequent Reports" in Duplicate
OIL AND GAS CONSERVATION; COMMITTEE
SUNDRY NOTICES AND REPORTS ON WELLS
(Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir.
Use "APPLICATION FOR PER1ViIT--" for such proposals.)
OILwELL F--! GASwELL []] OTHER Temporarily Suspended
API 50-133-20184
ADL 35431 REL
7. IF INDIA/~, ALLO',t"I'~i~ OR TRIBE-N~t~LE
2. NAME OF OPERATOR
Atl ~nti.¢ Ri chfield 'Comnany
ADDRESS OF OPERATOR
P.0. Box 360, Anchorage. Alaska
4.LOCATION O,F WELL
At surface
UNIT FAK1VI OR LEASE NAME
Tra~ing Bay Field
99501
9. WIlL NO.
S-4 #22-26
It ¢~f~ h~n~y~' pfeWl"dD~H e m 1 oc k
2615'N & 2492'W fr SE cr, Sec 26, T10N, R13W, SM
li:'~EC.,'T~, ~i.,'~Z, '(Bo'r'~DM HOLE
OBJECTIVE)
Sec 26, T10N, R13W, SM
i3. ELEVATIONS (Show whether DF, RT, GR, etc. 12. P~IiM. IT NO.
115' KB 69-34
i4. Check Appropriate Box To m~ndicase Nlat'ure of N~oti'c'e, I~e ~ort, or Other .Data
NOTICE OF INTENTION TO:
TEST WATER SHUT-OFF II PULL OR ALTER CASING
FRACTURE TREAT MULTIPLE COMPLETE
SH00T OR ACIDIZE IZ ABANDON'
REPAIR WELL CHANGE PLANE
( Other )
EUBSEQUENT REPORT OF:
FRACTURE TREATMENT ALTERING CASINO
SHOOTING OR ACIDIZING ABANDONMEN'T'
(Other)
NOTE: Report results of multiple completion on Well
ompletion or Recompletion Report and Log form.)
15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertineut details, and give pertinent dates, including estimated date of starting an}'
proposed work.
1 Drilling has been completed and 9-5/8" casing run and cen~nted @ 10,744'. An oil
completion is not feasible.-
e
Plans are to complete this well as a water injection well after installing water
injection equipment on the Spark Platform. Timing is presently for the 4th quarter
1969,
3. Request is made to Change the status of S-4 from "0il Well" to "Temporarily Sus-
pended'' until plans in No. 2 above can be carried out,
~6. I hereb~ ce~ fo~~et
SIGNED, R., I], ,f'a13ns~nnP
F)i stri ct [lri 1 1 i n9 ~qupervi SOLUTE
,luly 2:1969
(This space for State
APPROVED BY
CONDitiONS OF ~p~ov~L,
TITLE
TITLE
See 1,nstrucfions On Reverse Side
Approved Cop)'
Returned
Form No. P-.-4
I%E¥. 9-30-6'7
STATE OF ALASKA
OiL AND GAS coNSERvATION CO/~ITTEE
IMONTHLY REPORT O'F:~DRILLING
AND WORKOVER OPERATIONS
SUBMIT I~ DEPLICATE
O£L ~ GAS ~-~ OTHER
WELL -- WELL
Temporarily Suspended
2. NANIE OF OP]GRATOR
At] antic Richfield Company
~. AD~J~RESS OF' OPEi~ATOR
P.O. Box 360, Anchorage, Alaska
99501
4, LO~ATION O'F WELL
2615'N &.2492'W fr SE cr, Sec 26, TION, R13W, SM
APl NUMERICAL CODE
API 50-133-20184
0.' LEASE DESIGNATION AXD SERIAL NO.
ADL 3543]
!7. IF INDIAN, ALXDTI~E OR TRIBE NAME
8, UNIT FA/~M OR LEASE NA_ME
TracJi ng Bay Fi el d
9. WELL NO.
S-4 #22-26
10~ Fit;L/) A-ND POOL, OR WILDCAT
Tradi ~ng,B~a~ Hemlock
NF n.~
li.' ~EC~., ~T.", 1~., ~ ~ BO~OM HO~
O~~)
Sec 26, 1!0~, R13~, $~
13. REPORT TOTAL DEP//-I AT END OF MONTH, CHANGES IN HOLE SIZE, CASING A_ND CEMENTING JOBS INCLUDING DEPTH
SET ANI) VOLUMES USED, PERFOI:{ATIONS, TESTS A_ND RESULTS, FISHING JOB~, JUNK IN HOLE AI~D SIDE-TRACKED HOLE
AND A~IY OTI-IER SIGNIFICANT CHA~F~ IN HOL~ CONDITIONS.
Trading Bay S-4 (2,2-26) June, 1969
Spudded @ 1'00 a.m. 6-3-69. Drld 17-1/2" hole to 2150'. Ran and cmtd 13-3/8" 61# J-55
csg @ 2132'G,!Collar @ 2047') w/lO00 sxs Class "G" cmt pre-mixed w/lO% gel followed w/400
sxs Class" Neat cmt. CIP @ 5:15 a.m., 6-05-69. Tstd 5" DP rams & csg rams w/2500
psi OK & Hydril w/1600 psi OK. Directionally drld 12-1/4" hole 2150-10,175'. Ran
Schlumberger DIL 10,12'0-2232' & Sonic 10,120-7500'. Ran Schlumberger HDT 10,120-7500'.
Directionally drld 12-1/4" hole 10,175-10,770'. Ran Schlumberger DIL 10,756-10,120' &
Density log 10,760-7500. Ran and Cmtd 9-5/8" 47# csg @ 10,744' (collar @ 10,665') w/lO50
sxs Class "G" cmt w/l% CFR-2. CIP 6:20 p.m. 6-29-69. Installed packoff & tstd to 5000 psi
OK. Removed BOPE. Temporarily suspended. Will be completed as water injector at later
date. RELEASED RIG @ 12M 6-29-69.
14. I hereby certify tl~t the f~orego~ is ~ and correct ·
with the Division ine$ & Minerals by th~ 15th of the succeeding montk unless otherwise directed.
Distribution:
Orig.: Drilling Section - Dallas
cc:- District Office
Engineering Division - (720)
Co-Owner(s) - As Appropriate
Regional Office, Well Record File
The Above is Correct:
...//~'. ', ./s' ) ~,., .... .? .... ,., ,~
S I GNATI)RE
7-02-69
DATE
TI TI.E
..
PA(;I'~ NO, )' (NIIMIW. R AI.I. DAII.Y Wi'.'I.I. III.~TORY I:OttM.~ CON.~I".(:III'IVI:.I.Y AS 1'111<¥ Alii': I'IH'~I'MW.D I"Oit EM:Il WEI.I., )
INSTRUCTIONS: This form is used during drilling or workover operations. If testing, coring., or perforating, show formation
name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work per-
formed by Producing Section will be reported on "INTERIM" sheets until final completion. Report official or representative
test on "FINAL" form, (1) Submit "INTERIM" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday
of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion.
DAILY WELL HISTORY - INTERIM
District Alaska County or Parish Kenai Borough
North Trading Bay Field- Hemlock
Field Northeast Oil Pool Lease or Unit NTBS S-4
State
Alaska
, ,, We I 1 No. 22__._:2~
Date & Depth
at 8:00 A.M.
6-16-69
6-17-69
6-18-69
6-19-69
6-20-69
6-23=69
6-2~-69
6-25-69
6-26-69
6-27-69
Complete Record for each Day While Drilling or Workover in Progress
8085' (604') MW 72~, Vis 38, WL 10 cc's, Diesel Oil 2~ Drlg
Directionally drld 12-1/4" hole 7481-8085'. Both turbines down 5-3/4 hfs
~1 went down due to PL overspeed & ~2 due to surging. Replaced voltage
converter on ~1 from turbine ~2. Ran Sperry Sun Gyro Survey ~ 100' intervals
423-2130'.
Survey: 7965', 23030', VD 7834.63, N78W, N374.22, W808.26.
8359' (274') -MW 72~, Vis 38, WL 10 cc's, Oil 2°~ Drlg
Directionally drld 12-1/4" hole 8085-8359'. Tstd CSO & pipe rams w/3000 psi
OK & Hydril w/2000 psi OK. Survey: 8183', 23030', VD 8034.56, N76W,
N395.25, W892.60.
8706' (347') MW 72~, Vis 40, WL 7.9 cc's, Oil 7% Drlg
Directionally drld 12-1/4" hole 8359-8706'.
Survey: 8470', 24-1/2°, VD 8295.67, N77W, N421.73, W998.52.
8928' (222') MW 72~, Vis 38, WL 7.8 cc's, 0il 6% Drlg
Dire ct ionally drld 12-1/4" hole 870~-8928'.
Survey: 8918', 24030', VD 8792.90, N79W, N455.67, Wl182.13.
.
9328' (400') MW 71~, Vis 37, WL 7.9 cc's, Oil 5% Drlg
Directionally drld 12-1/4" hole 8928-9328'
Survey: 9146'~ 24-3/4°, VD 8909.95, N79W, ~473.89, W1275.83.
10,135' (807') MW 69. 5~, ..Vis 38, WL 7.0 cc's, Oil 5% Drlg
Directionally drld 12-1/4 hole' 9328-10135'.
Survey: 10,021', 27-1/4°, VD 9692.91, N82W, N535.58, W1661.76'.
10,175' (40') MW 69~, Vis 42,' WL 6.8 cc's, Oil 5% Logging
Drld 12-1/4" hole 10~135-10,175'. Cond mud for logs. Measured out of
hole 50' long, did not correct. Ran Schl DIL 10,120-22.3.2 .&..Sonic 10,120-7500'.
Tstd BOPE~ OK. Survey: 10,175',-~7°45', VD 9829.20, N81W~ N546.80,
W1732.58.
10,331' (156') MW 70~, Vis 42, WL 6.6cc's Meas'g out of hole
RIH to 7000' w/Bit ~31. Rec'd change of orders. POH & ran Schl HRD dipmeter
10,120-7500i. Cont drlg w/Bit ~32 to present depth.
10,500' (218') MW 69~, Vis.'38, WL 6.4cc's, Oil 5% Drlg.
Directionally drld 10,331-10,500' Meas'd out on Bit ~32 @ 10~331'
· Y
corrected depth to 10,282'. Survey:' 10,331', 28°, VD 9966.94, N82W.
10,724' (224') MW 71~, Vis 38, WL 5.9cc's Oil 5% Drlg
Directionally drld 12-1/4" hole 10,500-10,724'.
PAGE NO.. 2
The Above is Correct:
Il
Di:::trict Dt'.41].irtkL.~?_t.~22frv:i~
TITI.E
,(NUMHI;:II AI,i. I)AII,Y WEI,i. lllSTORY FOIIMS IX')NSECUTIVEI,Y AS TllEY AllE PllEI'AIH']I IqHI EACII WEI.I.. )
7-02-6,9
DATE
INSTBUCTIONS: Prepare and submit the INITIAl. BEPOBT on the first Wednesday after s well is spudded or workover operations are
started. Daily work prior to spudding should be summarized on the form giving inclusive dates only.
DALLY WELL HISTORY-INITIAL REPORT
District Alaska County or Parish Kenai Borou?;h
North Trading Bay Field - Hemlock
Field Northeast Oil Pool Lease or Unit NTBS S-4-
State Alaska
Well No~,~,-2 '
Auth. or W.O. No.._1~'7377
Title Drill North Trading Bay State ..S-4 ~/-~2-2~
Atlantic Richfield Company
Operator
Spudded or
W.O. Begun Spudded Date 6-03-69
TARCO'S W.I.
Prior. Status
ttourl:OOAMi£ a W. O.
lOO¢
Date & Depth
as of 8:00 A.M.
6-03-69
6-04-69
6-05-69
6-o6-69
6-o9-69
6-10-69
6-11-69
6-12-69
6-13-69
Complete Record for each Day Reported
k80' (136') NY 7~, Vis 37, WL 11 ce's, oil 5~ Drlz.
Spudded @ 1 AM, 6-03-69. RIH w/12-1/4" bit & 18" HO. Top of cmt @ 344'.
Drld hard cmt 344-421', formation 421-450', POH. Scribed in w/12-1/4" bit,
N30°E,' jetted & drld 450-480'.
1557' (1077') MW 75~, Vis 61", WL 16.5 cc's, 0il 3~ Drlg.
Drld 12-1/4" hole from 450-604' OH to 17-1/4" & drld 17-1/2" hole 604-1557'
Survey: 1557', 1-1/4°, .VD 1556.~31, N15E, N39.92, E20.02.
2150' (593') NY 7~, Vis 66, IlL 17.2 cc's, Oil 2~ WOC
Drld 17-1/2" hole from 1557-2150'. 13-3/8" csg cmtd @ 2132'. Ran & cmtd
2085' (50 jts) 13-3/8" 61~ J-55 Buttress csg ~ 2132' w/Baker guide shoe &
.Flexi-i-flow collar @ 2047', cmtd w/lO00 Class "G" Cmt p. re-mixed w/lO~
" " at
gel followed w/400 sx Class G Ne cmt. Mixing time 35 rains, displ
w/1770 CF Wtr in 30 mins. Had good cmt returns after 1200 CF displ. Bumped
plugs w/2000 psi. Float held OK. CIP @ 5:15 AM, 6-05-69. 10 centralizers
used @ 200' spacing.
Survey: 2150' 1°, VI)2149.11, S87W, N36.78, E9.68.
2960' (810') MW 75~, Vis 71, WL 15.8 ee's Oil 2~ Drlg
Removed 20" riser & Hydril & installed 13-3/8" OCT ~ack-off. Tstd w/3000
psi, OK. Ran 12-1/4" bit. DO cmt 2047-2132' & drld 12-1/4" hole 2150-2960'.
5658' (2698') NY 71~, Vis 42, ~ 15.3 ce's, Oil 3~ Drlg.
Tstd 5" DP rams & csg rams w/2500 psi OK & Hydril w/1600 psi OK. Drld
12-1/4" hole from 2960-5658'.
Survey: 5658'~ 5-3/4°, VD 5650.91, N55W, N127.45, W142.60.
6164' (506') NY 72~, Vis 40, WL 14 ee's oil 2~ Drlg
Directionally drld 12-1/4" hole from 5558-6164'
Survey: 6105', 9-1/2°, VD 6091.47~ NS1W, N175. $8, W201.42.
/
6757' (593') NY 72#, Vis 38, WL 11.8 ce's.
" m
Directionally drld 12-1/4 hole fro 6164-6757'.
Survey' 6599', 17-1/4°, VD 6569.63, N69W, N214 32, W311.00.
7100' (443') lV~ 72~, Vis 37, WL 10.8 ce's, Oil 2~ Drlg.
Directionally drld 12-1/4" hole from 6757-7100'.
Survey: 6780', 20-1/4°, VD 6739.44, N66W, N239 80, W368.23.
7266' (166') NY 73#, Vis 42, WE 9 cc's, Oil 2~ Drlg
Directionally drld 12-1/4" hole from 7100-7266'
Survey: 7241', 21015', VD 7167.94, N74W, N30~.~8, W534.30.
Distribution: The Above is Correct.:
Orig.: l)ril, ling Section- Dallas
cc;-l)istrict, O£fice _---~~/.~.'/'.: .......... ,,.z~ .... ,' ~-(')Pr~ ..............
Engineering l)ivision - (720) s~(;~:aTtmE /' /' DATE
Co-Owner(s) - As Appropriat. e (,/
lh, l,~ional Office, Well lh,cov,l l"i
T 1 TI.
I'M;I'i Nil ............... (NItMI~I(II AI.I. IiAiI.Y ~1;i,!, lilt, FOllY I-'i~IIMS (:()NSI..IllrI'IVI.;I.Y A5 TIII(Y Alii" I'IiI.I'AIII. Ii Iq)Il I';ACII ~1(I,1,. ) 31~.,1','~-1
9iV!SIOg'~ ~]~F U:IL A~i[~' GAS
Re~ Tradim~ ~ay S.-4 (22-26
A t 1 an t i c R i c h fi ~? l duo~,,pa,~y ~ ~
Operator
.~ir. i'~. D. Johnstone
))istrict Drilli)~g Supervisor
Atla~tic Iiichfield Co~':~pany
P. O. Box 260
Anchorage, Alaska 99,50t
~ear Sir:
E~closed is the approved applicatio~ for
to drill the referenced well. t:~ell samples a~td core
chips are ~ot required.
Please ~ote that Item lb of 'the application has bee;'~
corrected to show a multiple zone com?letion and 'that
Item 15 is not filled in.
Sectio)~ 2060 of the Oil a~d Gas Conservatio~
Regulations was not co~plied with. Please do so i(~
the future.
Very truly yours
HL,~
L~ 1 re. C to)"
MEMORANDUM
TO:F- ~le Walltngton
Deputy
State of Alaska
DEP~i~RTM£NT OF NATURAL ~,ESOURCES
~/2 GAS
DIVISION OF OIL
DATE : April 23, 1969
FROM: ~Jl)l~)or L. Burrell
Di rector
SUBJECT: Tradi.g Bay $-4 (22-26)
Atlantic Richfield C~pany,
Operator
Enclosed are- the approved application for pemit to drill, a location
plat, an~ a check in the amount of $50 for filling fee.
[~L~ :n~
Enclosu~$
MEMORANDUM
TO: F Don H. Shepard
Industrial Safety Inspector
Department of Labor
FROM: flomer L. ~urrell
Director
State of Alaska
DEPARll,IENT OF ~iAT~RAL RESOURCES
"'
DIVISIO~t OF OIL,,-~'~,~ GA~
DATE : April 23, 1969
SUBJECT.' Trading 8ay S-4 (22-26)
Atlantic Richfield C~mpany,
Operator
Enclosed is a copy of tJ~e approved application for peD~dt to drill
for the above .c~pttoned ~el 1.
HLB~my
Enclosur~
Form P--1
R~-~V. 9~30-67
SUBMIT IN TRI~ ATE
. (O%her instructions on
reverse side)
STATE O'F ALASKA
OIL AND GAS CONSERVA'I'ION ,CO,MMITTEE'
APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK
llL TYPE OF WORK
DRILL []
b. TYPE OF WELL .,
OIL[] OAS ~--]
WELL WELL OTHER
DEEPEN []
2. NAME OF OPERATOR
Atlantic Richfield Company
PLUG BACK []
3. ADDRESS C~ OPERA?OR
P. O. Box 360, Anchorage, Alaska 99501
4. LOCATION O'F WELL
A~surface 2615N & 2492W from SE Cr,Sec. 26, T10N, R13W,SM
At pro.posed prod. zone
2450'S & 1620'E fr NW Cr' seC' 26 ;T10N,R13W,SM
13. DISTANCE IN MILES AND DIRECTION F2OM NEAREST TOWN OR'POST OFFICE*
28 miles NW fr. Kenai, Alaska
14. BOND INFORMATION:
Statewide Federal InsUrance Co. ~011-38-40
TYPE Surety and/or No.
: : ; '. : ' . '116 NO. OF ACRES IN LEASE
PROPOSETM
15,
DISTANCELocATioNFROMTo NEAREST : Il
PROPERTY OR LEASE LLNEi FT. : ': ' ' ' :: ! :
(Also to nearest drig, unit, if any)' .. . .~ i -
18. DISTANCE FROM PROPOSED LOCATION* '~ ' ~ ' ~ ~ 19. PRoPosED
TO NEAREST WELL DRILLING,. COMPLETED, ~ ~,., ~ [ '
OR APPLIED FOR FT. i
1100 ' ~ '::~ ' '[ 10'600'~
21. ELEVATIONS (Show whether DF, RT, C-R, etc.)
115 ' KB
~PI 50-133-20184
§.
6. LEA~E DESIGNATION AND SERIAL NO.
ADL 35431
7. IF INDIAN, A3.J~O~ OR TRIBE NAME
8. UNIT~FARM OR LEASE NAME
Trading Bay Field
9. Vv~LL NO.
8-4 ~22- 26
10. FIELD AND POOL, OR WILDCAT
*Tra~in~ Bay Hemlock
N 0~1 P~ol
11. SEC., T., R., M., (BOTTOM
HOLE OBJECTIVE)
Icc. 26, T10N,
12.
A~o--, $100, 000
17. NO. ACRES ASSIGNED
TO THiS WELL
8O
20. ROTARY OR CABLE TOOLS
Rotary
23. PI~OPOSED
R13W,SM
.~ASING AND CE1V[ENTING PROGRAM
APPROX, DATE WORK WILL START*
April 24, 1969
- ,
SIZE OF HOLE SIZE OF CAsING~i':'WEIGHT PER FO~ ' GRAD;~ SETTING DEPTH QUANTIT, OF CEMEN= _
18" 13-3/8" 'I 61~ J-55 2,000' 2,000 ex.
12~" 9-5/8" ~ ~. 47~ :N-80 10:600' 700 ex.
: .
Logging ~ TD~ ~.
20" Hydril on 20" Casing .....
13-3/8" double gate w/CsO and 5" rams on 13-3/8" tested to 3000 PSI,
and Hydril ,
*TO be co-mingled in Well'~bre With :!~ Trading Bay "G" NE 'OiI Pool Zone.
IN ABOVE SP~CE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and
proposed new productive zo~e. If Proposal is to drill or deepen direct ~onally, give pertinen% data on subsurface locations and rneasu~(~ and
true vertical depths. Give blowout preventer program.
24. I hereby certify that the Foregoing is True an¢~ Correct
(This space for State office/dse~'
L/
Diet. Drill.
CONDITIONS OF APPROVAL, IF ANY:
I SAMPLES AND COl~ CHIPS REQUIRED
[] YES ~ NO,
DIRECTIONAL SURVEY REQUTRED
~ YES ~ NO
OTHER REQU~TS:
A.P.I. ~CA,L CODE
50-133-20184
Super-
visor
PERMIT NO_
APPROVED BY_
§9-3 . ~Rov~ DA~
TI~. DIRECTOR
"--- *See In~ructi°ns On Reverse Side
April 23, 1969
D~TE Apri 1 23: lg6q
O~
22
27
..// /
// I
/// I
/ / /
/ /
/ / /
/
/ 34
/ !
/
!
!
!
!
!
/
!
TTI0 N - R 13, W
23
/
/
35
, &,
24
25
TTION-RI2W
I
I
I
I
I
I
I
I
+
!
I
I
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+
I
!
19
3O
ATL ANTICRICH FIE LDCOMPANY
ALASKA DISTRICT
WELL LOCATION MAP
NORTH TRADING BAY
Store S-4 (22-26)
11-6~
SCALE I" = ?000' O_ · lO00 ,., 2000
AtlantiCRichfieldCompany North Americ..~. Producing Division
Alaska District
Post Office Box 360
Anchorage, Alaska 99501
Telephone 907 277-5637
April 21, 1969
State of AlaSka,
Department of Natural Resources
Oil & Gas Division
3001 Porcupine Drive
Anchorage, Alaska
Gentlemen:
oKG
KLV
HWK
REt.
The enclosed Form P-l, Application for Permit
to Drill, is re-submitted for our Trading Bay
Field well No. S-4 (22-26)o showing the cor-
rected lease and field names.
Very truly yours,
RWM: tll
enc
APR
DIVISION OF OIL AND
Robert T. Anderson
District Land Manager
Union Oil Company.~California
2805 Denali Street, ,-,nchorage, Alaska 99503
Telephone (907) 277-1481
union
April 18, 1969
Division of Oil and Gas
3001 Porcupine Drive
Anchorage, Alaska 99503
Attention: Mr. Thomas R. Marshall, Ir.
Re'
APPLICATION FOR PERMIT TO DRILL
NORTH TRADING BAY STATE
S-4 (22-26)
Gentlemen:
Union Oil Company of California, as an affected operator pursuant to
Section 2060 of the State Oil-and Gas Conservation Regulations, has no
objection to the subject well being drilled as set forth in the referenced
Application dated April 10, 1969.
Yours very truly,
Robert T. Anderson
WSM/nr
CC'
Atlantic Richfield Company
P. O. Box 360
Anchorage, Alaska
2 1 gP .g
DIVISION OF OIL AND GAS
ANcHorAgE
Form 401 ANC-A (New 7/67)
PETROLEUM PRODUCTS
April 15, 1969
TEXACO INC.
P. O. BOX 664
ANCHORAGE, ALASKA 99501
State of Alaska
Division of Oil and Gas
3001 Porcupine Drive
Anchorage, Alaska·
Attention t ~. Homer Burrell
ATLANTIC RICHFIELD COMPANY
WELL $-4, NO. 22-6
SPARK PLATFORM
_TRADING BAY ........ -
OKG
KLV
H\:v'?.
Rr:L _
_
FILE
Gentlemen
Reference is made to Atlantic Richfield's application
to drill the subject well.
In accordance with Section 2060 of the Conservation
Re~lation, please be advised that Texaco has no objection to
the well location.
Very truly yours,
TEXACO Inc.
Claude H. Brown
District Landman
CC: Atlantic Richfield Company
Attn: Mr. R. D. Johnstone
;
RECEIVED
APR 1,19
DIVISION OF OIL AND OAS
ANCHORAGE
Atla~icRichfieldCompany North Ameri~,..,,, Producing Division
Alaska District
Post Office Box 360
Anchorage, Alaska 99501
Telephone 907 277-5637
April 14, 1969
TRM
FILE
State of Alaska
Department of Natural Resources
Oil and Gas DiVision
3001 Porcupine Drive
Anchorage, Alaska
Attention: Mr. T. R. Marshall, Jr.
Gentlemen:
Please find enclosed check for $50 that should
have been included with the Application to
Drill NTBS S-4 922-26. Sorry for this oversight.
Very truly yours,
R.. D. Jg~stone
Distr ict~Drilling Supervisor
RDJ: tll
ck enc
AtlanticRic~fieldCb~pany North Amerig'~Producing Division
Alaska Distric~,
Post Office Box 360
Anchorage, Alaska 99~
Telephone 907 279~4~'~
April 10, 1969
State of Alaska
Department of Natural Resources
.Oil and Gas Division
3001 Porcupine Drive
Anchorage, Alaska
Attention: Mr. T. R. Marshall, Jr.
Gentlemen:
Re: North Trading Bay State S-4 ~22-26
Section 26, T1ON, R13W, SM
Enclosed please find the Application for Permit
to Drill, in triplicate, together with a plat
of the location, and a check in the amount of
$50 to cover the filing fee.
Very truly yours,
R. D. J~stone
Distrid4f Drilling Supervisor
RDJ:tll
encs (3)
APR 14 1969
DIVISION OF OIL AND OAS
ANCH4~,AGE
Form P~I
REV. 9.-30-67
SUBMIT IN TRI~ .{TE
(Other instructions on
reverse side)
STATE OF ALASKA
OIL AND, GAS CONSERVATION CO,MMITTEE
APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK
~a. ~.o~o.~ DRILL k--I DEEPEN [] PLUG BACK
2. NAME OF OPERATOR
Atlantic Richfield Company
3. ADDRESS O~ OPERATOR
P. OD Box 360, Anchorage,Alaska 99501
4. LOCATION OIF WELL
Atsurface 2615N & 2492W from SE Cr, Sec. 26,
R13W, SM
At proposed prod. zone
2450'S & 1620 E frOm NW Cr, Sec~26;~Tl:0N~"~1r3W,SM
T10N,
13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR.POST OFFICE*
28 miles NW fr Kenai, 'Ala:~ka'
14. BOND INFOI~NIATION:
Statewide Federal Insurance Co. ~8011-38-40
TYPE Surety and/or No.
PROPOSED~, '; _ - -[: ': '~- · [16; !NO. OF; ~aiCRES IN LEASE
15.
DISTANCE~%~FROM~OR ~[%TLNE / F~-~ ....
(Also to nearest drig, unit, if any) -' "]fg.' pRoPOSED DEP~PI ·
18. DISTANCE FROM PROPOSE]~ IJOC'AT~Z~N* ' "~ ' '
TO NEAREST WELL DRILLING, .COMPLETEI),
/
OR APPLIED FOR, FT. ll00 ...... '/ l~01,'6001 ' '
21. ELEVATIONS (Show whether DF, RT, CR, etc.)
115 ' KB
5.
6. ~.P.~SE D~tGNATION AND SERIAL NO.
ADL 35431
7. IF INDIAN, ALLO~I'EE OR TRIBE NAM~
8. UNIT, FARM OR LEA~SE NAME
North Trading Bay State
9. WELL NO.
8-4 ~22-26
10. FIELD AND POOL, OR WILDCAT
North Trading Bay State
11. SEC., T., R., M., (BOTTOM
HOLEOBJECTIVE)
;ec. 26, T10N, R13W, SM
12.
~o~t $100,000
17. NO. ACRES ASSIGNED
TO THiS WELL
80
20. ROTARY OR CABLE TOOLS
Rotary
22. APPROX. DATE WORK WILL START*
.~pril 24, 1969
23. · - F'I{OPOSED CASING AND CEMEiN'I'~NG PROGI~kl~
SIZE OF HOLE SIZE OF CASING1 - WEIGHT P~ F~' GRAD~ i ' : sET,iNG, DEP~" ~. · QuANTiT~ OF C~M~N~ _
18" ~3- 3/8" 61~ J'55 2,000' 2,000 sx.
12~" 9-5/8" : 47~ . . .N?80 . 10,600' ... 700 sx. ..
. , ,
,
Logging ~ TD.
Completion zones` will:ben, Upper Ken&i & Hemlock
20" Hydril on 20" Casing
13-3/8" double gate w/CS0 and 5" rams on 13-3/8" tested to 3000 PSI,
and 'Hydr ii RECEIVED
APR 14 1969
ertinen~ dam on suosurtace ~oca~
proposed new productive zof~e. If Proposal is to drill or deepen dire~t2onally, give p ~ and
true vertical depths. Give blowout preventer program.
24. I hereby certify that the Fore~g~ing i~;True aha- Correct
APPROVAL,
OF
IF
ANY:
(This space.~or State of£ice~ ___ CONDITIONS
S LES AND CORE RmU
Dist. Drill.
=TL~ Sup_~rvi-_~r
[ OTHER RE~U~S:
[] YES ~ NO
DIRECTIONAL SURVEY R.EQUTRED A.P.I. ~CAL CODE
i3YES [] No .g'O -- -
APPROVED BY
*See InstructiOns On Revere Side
DATE
F-
i
O~
] TION-RI3W
22
27
' .~iE.T E.,~A C 0-
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S-3 ~.' , /
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ARCO
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35
'T TTION-RI2W
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.~6"SPARK PLATFORM 25 I 30
i
I
ATL ANTICRICHFIE LDCOMPANY
ALASKA DISTRICT
36
¢~,, ~,'~ck~° WELL LOCATION MAP
L¢~.~ State S-4 (22-26)
SCALE 1"=2000' 0 ' i~O 2000
CHECii=L!ST FOR NEW WELL PERi,ilTS
4. Is wall located proper distance from prope.~:ty line ......... .,,,,~ ...... /~
&
Is suf):::.c..~,.c.,;:)~, uuacctL:'~ated acre.age, avoi
9o Can perm:lt: be ~.,pprox;eo before ten-:<m5 .... , ............................ '~'
].0 ~
12.
16.
17.
18.
19.
Does opera[:or have a bond i.n force .......... o, ~ ........ o .............
..,o. eqt ..... te ~o~v in collapse and tension
. s ' roductive horizons ..................
WiI1 ecment cover all po,,.,sible p
Will ~ '
m-')~ac, caszng cover ail fresh water zones
Does Y, OPE have suffic:i..ent pressure rating ............................
Can this permit be approved inmmdiately .............................
'Ap p rove 1 Re co.ow, ended:
Thomas It',. Ma=shalI, .Jr. ~~~~. Karl. L VonderAhe
W. Kugler ~_~~ Robert E. Larson
Harry
