Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout161-043 W
STATE OF ALASKA
ALAS IL AND GAS CONSERVATION COMMIS
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned Q Suspended❑ 1b. Well Class:
20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑
GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑
2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number:
Union Oil Company of California Abend.: 10/27/2010 I 161 -043
3. Address: 6. Date Spudded: 13. API Number:
PO Box 196247, Anchorage, Alaska, 99519 11/7/1961 50- 133 - 10119 -00- -- 00)
4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: t
Surface: 1190 FSL 1350 FEL Sec 8, T7N, R9W, S.M. 12/27/1961 Soldotna CK Unit (SCU) 34 -08
Top of Productive Horizon: 8. KB (ft above MSL): 15. Field /Pool(s):
N/A GL Ground (ft MSL): Swanson River Field
Total Depth: 9. Plug Back Depth(MD +TVD):
1190 FSL 1350 FEL Sec 8, T7N, R9W, S.M. Surface Hemlock Oil Pool
4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation:
Surface: x- 340,963 y- 2,451,941 Zone- 4 11,175'MD (11,175'TVD) FEDA028996 [Soldotna Creek Unit]
TPI: x- N/A y- N/A Zone- 11. SSSV Depth (MD + TVD): 17. Land Use Permit:
Total Depth: x- 340,963 y- 2,451,941 Zone- 4 N/A N/A
18. Directional Survey: Yes LJ No 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD:
(Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A
21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re- drill /Lateral Top Window MD/TVD:
N/A N/A
23. CASING, LINER AND CEMENTING RECORD
WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT
CASING FT TOP BOTTOM TOP BOTTOM PULLED
22" Surface 28' Surface 28'
11 -3/4" 47 J -55 Surface 2,009' Surface 2,009' 16" 1400sxs 116lb/ft
N -80, 170' 10 -5/8" x Stage one 700sxs 116lb/ft
7" 23, 26, 29 p -110 Surface 11,170' Surface 11, 9 -7/8" Sta a two 1100sxs 116lb /ft3
24. Open to production or injection? Yes❑ NoQ If Yes, list each 25. TUBING RECORD
interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
N/A N/A N/A
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
��,, t� t� DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
i4f N V 2 Z 01U 10,294'- 10,771' 35 bbl 15.6 ppg cement
1,939'- 2,109' 30 bbl 15.6 ppg cement
P7. PRODUCTION TEST
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Abandoned Well N/A
Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio:
N/A 24 Test Period
Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr):
Press. 24 -Hour Rate •••►
28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No ❑✓
If Yes to either question, list formations and intervals cored (MD +TVD 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.
NOV
RBDMIS NOV 18 010 _'14 &"n n COS.'
A
��U
Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only
29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS
NAME MD TVD Well tested? Yes F± No If yes, list intervals and formations tested,
briefly summarizing test results. Attach separate sheets to this form, if
Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071.
Permafrost - Base
Formation at total depth:
31. List of Attachments:
Current Schematic, Operations Summary, Directional Survey, Abandonment Pictures
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola 263 -7640
Printed Name: Timothy C. Brandenburg Title: Drillig Manager
Signature: Gl Phone: 276 -7600 Date: 11/17/2010
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 1b: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for
Injection, 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 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other
(explain).
Item 28: 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 30: 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 12/2009
Chevron
Chevron - Alaska
W Daily Operations Summary
Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft)
SCU 34 -08 SOLDOTNA CK UNIT 34 -08 FEDA028996 5013310119 QA5263 164.00
Primary Job Type Job 8 gory Objective Actual Start Date Actual End Date
Abandon Well - Permanent Abandon 8/6/2010 8/16/2010
Primary Wellbore Affected Wellbore UWI Well Permit Number
SCU 34 -08 501331011900 1610430
8 /3i2o10 00.00 .o/a12o1CO 00:00 ;
Operations Summary
R/U E -line. R/U lubricator and test to 250low / 3500high psi - test OK. M/U 2.25" tubing cutter. RIH and cut tubing at 10,300' WLM. Tubing and casing
pressure = 0 psi. R/D E -line.
014/2010 00:00 - 8/5/2010 00:00 ,
Operations Summary
R/U pumping equipment. Pump down 7" x 11 -3/4" annulus to establish injectivity. Pumped a total of 65 bbl of lease water injecting at 380 psi and 1.4
bpm. R/D pumping equipment.
$18/2010 00:00 +'OF/{ 0 :Ot>~ ai
Operations Summary
Move rig from SRU 31 -33WD. Set BPV. N/D Tree. N/U BOPE. Notified Bob Noble w/ AOGCC 24 hour notice of planned BOPE Test. Waived witness.
Notified Tom Zelenka w/ BLM.
tltsa o/8r2tr�a co r
Operations Summary
Test BOPE to 250low / 3000 psi high - test OK. Pull BPV. Pull hanger free. Pulled 2 -7/8" tubing above tubing cut at 10,300' WLM. Pump lease water
down tubing and annulus. Monitor well, 0 psi. POOH with 2 -7/8" tubing.
018/2010 00:00., 81912010 00:00
Operations Summary
P/U 7" casing scraper BHA. RIH on 3 -1/2" workstring and tag top of tubing cut at 10,313' RKB (10,317' Orig RKB). Pump lease water down tubing and
annulus. Monitor well, 0 psi. POOH w/ 7" casing scraper.
81912010 00 :00.8/10/2010.00.00,
Operations Summary
L/D 7" casing scraper. P/U cement retainer. RIH and set 7" cement retainer at 10,290' RKB (10,294' Orig RKB). P/U above retainer and circ hole clean w/
8.5 ppg lease water. Sting into retainer w/ 1 O down weight. Perform injectivity test to 4 bpm, 2,250 psi. R/U cementers. Mix and pump 10 bbl chem wash
and 35 bbl cement. Displace with lease water. Squeeze 30 bbl 15.6ppg class G cement below retainer. P/U out of retainer and lay 5 bbl 15.6ppg class G
cement on top of retainer. R/D cementers. POOH to 10,008' RKB. Reverse circulate lease water. Monitor well. Displace lease water over to 13.8 ppg
mud. POOH. Notified Jim Regg w/ AOGCC 24 hour notice of planned plug tag. Waived witness to all remaining plug tags, will witness surface plug.
Notified Bill Diel w/ BLM.
811012010 00:00 - 8111111201-0
Operations Summary
POOH. P/U bridge plug. RIH and set 7" bridge plug at 8,238' RKB (8,242' Orig RKB). P/U above bridge plug and tag w/ 15K down weight. Circ and cond
mud. R/U cementers. Mix and pump 20 bbl 14.7 ppg mudpush and 20 bbl 15.6 class G cement. Displace with 13.8 ppg mud. R/D cementers. POOH to
7,498' RKB. Reverse circulate mud. POOH.
8111/2010 00:00 `- 8/12/2010 00;00
r
Operations Summary
POOH. P/U 7" bridge plug. RIH and set bridge plug at 2,105' RKB (2,109' Orig RKB). Circ and cond 13.8 ppg mud. R/U E -line. RIH w/ 15' of 4 -5/8" 21 spf
perf guns. Perforate from 2,024'- 2,039' WLM (2,028'- 2,043' Orig RKB). Saw 300 psi increase on 7 "x11 -3/4" annulus. POOH. Make 2nd run w/ 15'of
4 -5/8" 21 spf pert guns. Tag bridge plug at 2,109' WLM. Perforate from 2,024'- 2,039' WLM (2,028'- 2,043' Orig RKB). R/D E -line. Notified Jim Regg w/
AOGCC and Bill Diel w/ BLM 24 hour in advance of witnessing surface cement plug at 8:30 a.m.
8/12/2010 00:00 - 8/13/2010 00 :00 : N
Operations Summary
Bleed 7 "x11 -3/4" to 50 psi. Circulate 13.8 ppg mud down 7" and up 7 "x11 -3/4 ". Partial returns at 13.3+ ppg mud. P/U 7" cement retainer. RIH and set
retainer at 1,935' RKB (1,939' Orig RKB). POOH. R/U E -line. RIH w/ 6' 1- 11/16" casing punch. Tag retainer at 1,933' WLM. Punch casing from
1,910' - 1,916' WLM (1,914'- 1,920' Orig RKB). POOH. P/U cement stinger. RIH and sting into cement retainer. Establish circulation below retainer and up
7 "x11 -3/4" annulus thru punch holes and up 7" casing. Shut in and monitor well. Bleed pressures to 0 psi, well static. R/U cementers. Mix and pump 10
bbl chem wash ahead of 30 bbl 15.6 ppg cement. Lost returns with 5 bbl cement pumped. Continue w/ cement job. Unsting from retainer. Open
7 "x11 -3/4" annulus and bleed back 8 bbl mud. POOH to 1,497' RKB. Circ and cond mud. Shut in and monitor well. Tubing and 7" casing at 0 psi. 7" x
11 -3/4" at 80 psi. Bleed back 5 bbl mud and pressure went to 0 psi. Wait on cement.
8113/2010 00:00 - 811412010 '
Operations Summary
Test 7" and 7 "x11 -3/4" to 750 psi - did not test. Circulation established. RIH to 1,909' RKB. Circ and cond mud. R/U cementers. Mix and pump 15 bbl
cement. Squeeze thru 7" casing punch holes down 7 "x11 -3/4" annulus. Bleed back 5 bbl into 7 ". Monitor well. Workstring = 0 psi, 7" = 0 psi, 7 "x11 -3/4" _
25 psi. POOH to 1,503' RKB. Circulate 20 bbl down workstring, saw 180 psi on 7" and 7 "x11 -3/4" psi. Lost 7 bbl. POOH to 1,152' RKB. Circulate down
workstring, saw 120 psi on 7" and 7 "x11 -3/4" psi. Lost 2 bbl. Monitor well - static. POOH to 714' RKB. Circ and cond mud. RIH and tag cement at 1,870'
RKB w/ 4k down weight. P/U to 1,840' RKB. Circ and cond mud. Test 7" casing to 1,000 psi for 30 min - test OK. Test 7 "x11 -3/4" to 1,000 psi - did not
test. Communication w/ 7" casing. Establish injection down 7 "x11 -3/4" at 2 bpm at 560 psi. Inject 8 bbl. Monitor well - static. POOH.
Chevron
Chevron - Alaska
Daily Operations Summary
Well Name Legal Well Name Lease Surface UW1 ChevNo Original RKB (ft) :Water Depth (ft)
SCU 34-08 SOLDOTNA CK UNIT 34-08 FEDA028996 5013310119 QA5263 164.00
WIT
H
7,
0114110,10:00-00, - 01,141201,4 AQ
Operations Summary
R/U E-line. P/U 6' 1-11/16" casing punch. RIH and tag cement at 1,856'WLM (1,860'Orig RKB). Punch 7" casing from 1,844'- 1,850'WLM (1,848'-
1,854' Orig RKB). POOR Attempt circulation down 7" - no joy. Establish circ down 7 "x11 -3/4 ". P/U 6' 1- 1 1/16' casing punch. RIH and punch 7" casing
from 1,804' - 1,810' WLM (1,808' - 1,814' Orig RKB). Establish circ down 7" and up 7'x111-3/4" annulus - good returns, no losses. R/D E-line. RIH w/
3-1/2" workstring to 1,804' RKB. Establish circ down 7" and up 7 "x11 -3/4" annulus - good returns, no losses. R/U cementers. Mix and pump 5 bbl water
and 15.7 bbl 15.6 ppg cement. Balance plug between workstring and casing strings. Bleed pressures to 0 psi - no flow. POOH to 1,183' RKB. Pump 8.5
bbl 13.8 ppg mud down 7" casing and hold squeeze pressure of 600 psi on 3-1/2", 7", and 7 "x11 -3/4" annulus. Shut-in well and wait on cement.
:00'1 L
Operations Summary
Wait on cement. Bleed well to 0 psi. Test 7"x11 -3/4" to 750 psi for 30 min - test OK. POOH. R/U slickline. RIH wl 7" bridge plug and set at 466' SLM (470'
Orig RKB). POOR R/D slickline. R/U E-line. P/U 6'1-11/16" casing punch. RIH and tag bridge plug at466'WLM. Punch 7" casing from 454'-460' WLM
(458'- 464'Orig RKB). R/D E-line. R/U to circ down 7" casing. Displace 13.8 ppg mud to 8.5 ppg lease water. R/U cementers. Mix and pump 20 bbl
chem wash and 64 bbl 15.8 ppg cement. Cement returns to surface at 55 bbl cement pumped. R/D cementers. N/D BOPE. N/L1 dry hole tree. R/D and
prep for rig move to SCU 13-34.
fi 01 WE,
Operations Summary
Dug out cellar & surface concrete around cellar before wellhead removal and abandonment. Waiting on equipment to break up cement in bottom of
cellar.
W
1,4f2jWW"" I-� MIA 40,
Operations Summary
Finish excavating cellar for well abandonment.
Operations Summary
Begin cutting wellhead off. AOGCC Lou Grimaldi on location to witness cut.
7
101a
-IZV2010 00*00
Operations Summary
Continue cutting wellhead off with Wach's saw no success, rocks or gravel destroying blades, currently cut into & exposed all casing strings.
1012 90-90,-0012,41,24114-00--00 p7
Operations Summary
Cut wellhead off and dress out pipe for final abandonment 4.7' below original ground level. Cement to surface in 7 "x11 -3/4" and inside 7" casing.
7 7"
FM
K
Q
.,60 -
Operations Summary
AOGCC Jeff Jones witnessed cement to surface in all annuli and the installation of abandonment plate on well.
evro .
SCU 34 -08
A A Schematic
ctual P&
RB:164 M / GL' 148.75' ANBL
_ KB-THF:16.2 KB Casing and Tubing Detail
Size Type Wt/ Grade Top Btm CONN / ID Cement / Other
2Z' 29 22" Conductor Surface 28' - Cemented
1 1 11 -3/4" Surface 47 #, J -55 Surface 2,009' 8RD / 11.000" 1400 sx / Cmt to Surface
1aapPynM,d 29 #, N -80 Surface 121' Butt / 6.184"
TOC: 1,860' 23 #, N -80 121' 1 4,943' Butt / 6.366"
700 sx / Cmt to 4,265'
26 #, N -80 4,943' 6,881' Butt /
7" Production 29 #, N -80 6,881' 7,797' Butt / 6.184"
2 7,797' 7,799' DV Collar
29 #, N -80 7,799' 8,679' Butt / 6.184" 1100 sx / Cmt to 10,275'
11-314'@2009 ; 29 #, P -110 8,679' 11,170' 1 8RD /6.184"
3 Tubing '7" Marker Jt at 10,275.50'
2 -7/8" Production 6.5 #, N -80 10,317' 10,712' 8RD / 2.441" Colla sed at 10,318' SLM
CBL Tqx 4,263
laappgr�x,d
Production String Je elry Detail
# Depth RKB Length ID OD Item
1oG 7,703 1 470' 1.00' 7" Bridge Plug TOC = Surface
DVCollar , 2 1,939' 1.12' 7" Cement Retainer TOC = 1,860')
7 , 79 T - 3 2,109' 1.14' 7" Bridge Plu
4 4 8,242' 1.14' 7" Bridge Plug (TOC = 7,706'
TOC: 10,163 5 10,294' 1.12' 7" Cement Retainer (TOC = 10,163')
C6L Top: 1Q.M "' 5 6 10,317' 2.442" 2.875" Cut joint, 2 -7/8" tubin
Collapsed apse d Tubing 7 10,572' - - Cameo MM GLM
l SLM ( 6 8 10,616' 2.313" 3.668" XA Sliding Sleeve [Opens U
06r10 9 10,630' - 2.4375" 3.6875" Brown CC Safety Joint
10 10,641' 5.72' 2.416" 5.983" Baker FH packer Set 6/29/86
11 10,679' 2.205" 1668" XN Nipple Min ID = 2.205"
7 12 10,713' Baker Shear Sub
13 10,778' 15.67' Fish: Slickline Tools, 15.67' Lost 7/21/83
14 10,809' 89' Fish: Tubing Tail cut -off, 89' Cut 6/4/70
8
Perforation Data
ZONE TOP BTM SPF Condition
9 SQZ 458' 464' 4 1- 11/16" Tubing Punch 4 spf (1 run ) 8115/10
LM SQZ 1,808' 1,814' 4 1- 11/16" Tubing Punch 4 spf (1 run) 8114/10
SQZ 1,848' 1,854' 4 1- 11/16" Tubing Punch 4 spf (1 run) 8/14/10
10 SQZ 1,914' 1,920' 4 1- 11/16" Tubing Punch 4 spf 1 run) 8/12/10
SQZ 2,028' 2,043' 42 4 -5/8" Bi shot 21 spf (2 runs ) 8/11/10
WSO 10,679' 10,680' 5 W.S.O. (Water Shut-off), Squeezed 1/20/62
H1 10,682' 10,696' 4 Squeezed 1/20/62
H2 10,721' 10,758' 8 Re erf 6 /5 /70,' /� "EH
11 H3 10,766' 10,786' 8 Re- erf 6/5/70, '' /2 ' EH
v &O. H4 10,792' 10,810' 8 Re- erf 6/5/70,'/2' EH
F+1
Top of Fill & 12
Collapsed Casing
10,753 SLM
2rM3
i. F+2
Collapsed Casing
10771' RKB
6123/86 7" Cement Bond Log
�
13 ux 4,265' - 4,525' - Good
H4 4,525' - 4,845' - Fair
14 4,845' - 5,090' - Good
r 5,090' - 5,430' - Fair
7 " @ 11,170 ' Directional Data: 5,430' - 7,797' - Good
TD- 11,175' PBTD= 11,121' max hole angle = 2.5° at 4659' MD 10,275' - 11,170' - Good
SCU 34 -08 Actual P&A Schematic 8- 15- 10.doc Updated by STP 8 -15 -10
COMPLETION REPORT
SOLDOTNA CREEK UNIT 34 -8
SECTION 8, T. 7 N., R. 9 W., SEWA.RD B & M Page 15.
STANDARD OIL COMPANY OF CALIFORNIA, W.O.I. - OPERATOR
DEVIATION DATA
Depth Degrees
16o, 0 45'
1,107' 0 30'
2,030 0 30
3,527' 1 00'
4; 1 00
4,36o, 1 0 30 1
4,659' 29 3
4,940' 2 00
5,187' 10 30'
5,495' 10 45'
5,670' 1 1 5'
5,8701 cP 45
6,025 CP 30
6,145' C' 45
6,2611 1 00'
6,507` W 451
6,650' CP 45'
5' 1 0 15 1
7112
71232 r 1 0 1 1
7,318' 1 00'
7,570' 1 00
7,745' 1 o8'
7,945' 1 0 15 1
8, 021 1 1 45
8,180 1 3 0'
8,268 1 00'
8,344t 1 0 00
8,485t :' 00'
8,571' 1 4 5'
8,655' 1 30'
8,783' 1 30'
8,9041 2 00
9,026' cP 45'
9,110 d' 45
9,238 � 45
9,385 r
9,456, 1 45
9.,512' �' 00
9o770' 10 00
9,954 1 451
10,0541 CP 45'
1o,1o4' 1 15'
10,127' 1 081
10, 200 1 301
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STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Surface Abandonment / Location Clearance / Suspended Well
( Title 20 AAC 25.170 )
FILE INFORMATION:
Operator: Union Oil Co. Well Name: SCU 34-08 -
Address: PO Box 196247 Anch. Ak 99519 PTD No.: 161 -043 -
API No. 50- 133 - 10119 -00
Surface Location (GPS): Unit or Lease Name: Soldotna Creek Unit •
North 60 deg 42.472' / West 150 deg 53.40 Field and Pool: Swanson River / Hemlock
Section: 8 ' Township: 7N ' Range: 9W Meridian: S.M. •- Downhole P&A Date:
20 AAC 25.120 - ABANDONMENT MARKER:
Insp. Date: 1 Surface Monument 1 Approval Date:
Post OD: (4" min) Length: ft. Set on (Wellhead, Csg , In Cmt)
Height above final grade (4' min.): _ ft. Casing stub ft. below final grade
Top of Marker Post Closed ? All openings closed ?
Inspector:
Insp. Date: 10/27/10 1 Subsurface Monument 1 Approval Date:
Marker Plate Diameter: 111" - Distance below final grade Level: 4'
Thickness: 0.25 " Side Outlets removed or closed: Yes
Marker Plate Attached To Conductor N (Y /N) - Cement to surface (all strings)? Yes
Inspector: Jeff Jones -
Exact Information Beadwelded Directly to Marker Post or Blind Marker Plate:
Insp. Date 10 /27/10 1 1 Approval Date:
SCU 34-08 Union Oil Co. of Califomia
1190' FSL 1350' p1FE�L Section p 8 T7N R9W S.M. -
i -043
Inspector: J eff Jones
Insp. Date 1 20 AAC 25.170 - LOCATION CLEANUP: Approval Date:
Pit's filled in? Liners Removed or Buried? Debris Removed:
Notes:
General condition of pad /location: ( Rough, Smooth, Contoured, Flat, )
Notes:
Type of area surrounding location: ( Wooded, Tundra ,Grass,Brush,Dirt,Gravel,Sand)
Debris on surrounding area:
Notes:
Access road present? Type road: ( Dirt, Gravel, Ice, Other) Condition:
Condition of road:
Notes:
Cellar filled in? Type of fill: Height above grade:
Notes:
Type work needed at this location:
Inspector:
RECOMMENDED FOR APPROVAL OF ABANDONMEN' Yes No ✓ (If "No" See Reason )
Distribution: Reason: L o%l c leapaf,ce y 6 1 110
orig - Well file
c - Operator Final Inspection performed? Yes No ✓
c - Database
c - Inspector Final Approval By: DATE:
Title:
Sheet by L.G. 8/5/00 P -A Surface SCU 34 -08 10 -27 -10 JJ.xls 11/16/2010
• •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg � ' �'��'�� DATE: October 27, 2010
P.I. Supervisor
SUBJECT: Plug & Abandonment
FROM: Jeff Jones SCU 34 -08
Petroleum Inspector Union Oil Co.
PTD 161 -043
SRF /SCU
Section: 8 Township: 7N Range: 9W Meridian: SM
Drilling Rig: Key Energy #3 Rig Elevation: Total Depth: 11,175' MD Lease No.: FED A028996
Operator Rep.: Clint Chanley
Casino/Tubing Data: Casing Removal:
Conductor: 22" O.D. Shoe@ 28' MD Casing Cut@ 28'- removed Feet
Surface: 11.75" O.D. Shoe@ 2009' MD Casing Cut@ 10' Feet
Intermediate: O.D. Shoe@ Casing Cut@ Feet
Production: 7" O.D. Shoe@ 11,170' MD - Casing Cut@ 10' Feet
Liner: O.D. Shoe@ Casing Cut@ Feet
Tubing:3'�
11 4," O.D. Tail@ 10,712' MD ' Casing Cut@ +/- 10,300 Feet
Plugging Data:
Type PIuq Bottom of T.O.C. Mud Weight Pressure
(bottom upl Founded on Cement T.O.C. Depth Verified? above plug Test
I Perforation Bottom 10,753' 10,140' No 13.8 # No
Annulus Bridge plug 8230' 7690' No 13.8 # No
Annulus Bridge plug 2100' 1910' No 13.8 # No
Annulus Bridge plug 500' Surface Yes " N/A No
Type PIuq Founded on: Verified?
Open Hole Bottom Drillpipe tag
Perforation Bridge plug Wireline tag
Annulus Balanced C.T. Tag
Casing Stub Retainer No
Surface
October 27, 2010: I traveled to Union Oil Co.'s SCU 34 -08 well location to witness the surface plug and abandonment (P&A)
procedures.
Well SCU 34 -08 has downhole plugs in place. On my arrival I noted that the 22" conductor and 3.5" tubing had been removed
from the well. The 11.75" and 7" casing strings were cut off 4 ft. below original ground level and were filled with cement to
surface. A marker plate with the required information was then bead welded to the outer casing in accordance with AOGCC
regulations.
Summary: I witnessed the successful surface P&A of Union Oil Co.'s well 34 -08 in the Swanson River Field, SCU.
cc: Attachments: Site Pictures (3) .--
Distribution:
-Well File (original)
-Read File
- DNR/DOG
Rev.:01/26/09 by L.R.G. P -A UOC SCU 34 -08 10 -27 -10 JJ.xls 11/16/2010
r -
• •
SCU 34 -08 (Union) Surface Abandonment
PTD 1610430
Photos by AOGCC Inspector J. Jones
10/27/2010
3 , . Casing stub; cement to
surface; SCU 34 -08
... II
`U
,x•140 'V.
',.,0"..., Marker plate; SCU 34 -08
a `
Excavation to 4 feet;
t ` r SCU 34 -08; conductor
a �. ;^ 1 / , was removed
• • Regg, James B (DOA) Page 1 of 2
�61 - 04-3
From: Grimaldi, Louis R (DOA)
Sent: Thursday, October 21, 2010 10:27 PM
To: Aubert, Winton G (DOA); DOA AOGCC Prudhoe Bay
Subject: RE: SCU 34 -08 P &A Sundry 310 -230 Marker Plate Installation on 22" Conductor
Attachments: SCU 34 -08 Cutoff saw 10 -21 -10 LG.JPG; SCU 34 -08 Cutoff saw 10 -21 -10 LGb.JPG
Winton,
Update on this well. I went out to Swanson River and watched them saw on this casing for about 4 hours. -
They went through 4 blades while I was there and they had already killed off 4 before I got there. You
could hear the gravel grinding around inside the annular space as the saw worked back and forth.
In the first picture, look at the casing just above the absorb and there is a slight bell, that is the bottom of
the casing (conductor) and there is some cement evident there. Clint Chanley told me that a small amount
of dark hydrocarbon weeped out of there and so everyone is spooked to cut the casing with a torch. I saw
no evidence off hydrocarbons on the reciprocating saw.
The second picture shows just how short the Conductor is (12'), it is also very thin (maybe 3/8 "). 1 would
not be surprised if they find another casing string inside as this conductor would not serve as good
anchorage for a diverter.
left as they they were using the last blade and were not halfway through the casing. Clint will call me in
the morning to let me know how they eended up and the plan forward.
I still feel that the "conductor should be removed and the abandonment marker welded directly the the
more substantial Surface pipe. I advised Clint to get in touch with the BLM to see what they thought. After
I speak with Clint I will let you know more.
Lou
From: Grimaldi, Louis R (DOA) NOV
Sent: Thu 10/21/2010 3:38 PM
To: Aubert, Winton G (DOA); DOA AOGCC Prudhoe Bay
Subject: RE: SCU 34 -08 P&A Sundry 310 -230 Marker Plate Installation on 22" Conductor
I spoke with Clint Chanley about this well this morning after they got excavated. He told me that the 18"
conductor shoe was visible in the hole and that there was not any cement between the conductor and
surface casing that he could tell.
Clint wanted to know if he should cement the short section (approximately 2') of the conductor to the
Surface pipe. Clint conveyed that there was some contamination of the material between CondxSurf
pipes and he would have to clean that out.
I felt that welding the plate to that short of a piece of conductor pipe would serve no purpose and getting a
plate secured to the Surface casing would be better. I also told Clint that he should have Porhola call
Winton and get a conversation started about the possibility of making this change.
I am heading out to location and will see what it looks like. If the conductor is not anchored to the surface
paper I think the plate should be welded to the Surface pipe.
We should also talk to BLM about this.
Lou
Cell 252 -3409
From: Aubert, Winton G (DOA)
Sent: Thu 10/21/2010 1:32 PM
To: DOA AOGCC Prudhoe Bay
10/22/2010
• Page 2 of 2
Subject: FW: SCU 34 -08 P&A Sundry A-230 Marker Plate Installation on 22 11 Conductor
Does anyone have an opinion on the below?
Thanks,
WGA
From: PORHOLA, STAN T [ mailto :stan.porhola @chevron.com]
Sent: Thursday, October 21, 2010 1:20 PM
To: Aubert, Winton G (DOA)
Cc: Chanley, Clint M [APRS]; Maunder, Thomas E (DOA); Regg, James B (DOA)
Subject: SCU 34 -08 P&A Sundry 310 -230 Marker Plate Installation on 22" Conductor
Winton,
We are currently finalizing the abandonment of Swanson River well SCU 34 -08 under Sundry 310 -230.
The original ground level was found to be 6' below top of pad. We excavated out the cellar down to 11' below top of pad in
order to make room for cutting the casing strings.
We plan to cut the casing strings at 9' -10' below top of pad in order to achieve a cut at 3'-4' below original ground level.
The 22' conductor was set at 28' RKB. This puts the shoe at 12' below pad level, very near our current excavation depth.
No cement was found down to this 12' depth between the conductor and surface casing annulus, even though cement to
surface was documented during the cementing of the 11 -3/4" surface casing back in 1961.
After cutting the casing strings this will leave only 2' -3' of conductor string length.
Our field personnel have been in contact with your inspector, Lou Grimaldi, and he said he was concerned about the short
length of conductor left once we install the marker plate. He was wondering if it would be better to install the marker plate
on the 11 -3/4" casing.
Our proposal is to continue as planned, topping of cement in the conductor x surface annulus and the surface x production
annulus. Cut the casing at 9' -10' below top of pad and weld on the 22" plate.
If you have any questions or concerns, please feel free to contact me.
Stan Porholaeo
Drilling Engineer
MidContinent/Alaska Business Unit
Chevron North America Exploration and Production
3800 Centerpoint Dr. Suite 100
Anchorage, AK 99503
Tel 907 263 7640
Fax 907 263 7884
Cell 907 229 1769
stan.porhola @chevron.com
Mail Confidential Footer
Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message
(or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any
part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by
replying to the message or contacting me at (907) 263 -7640.
10/22/2010
SCU 34 -08 Surface P &A
PTD 161 -043; Sundry 310 -230
Photos by L. Grimaldi
10/21/2010
Attachment to email dated 10/21/2010 (L. Grimaldi) re: status of SCU 34 -08 surface abandonment
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Chevron Fral Castro Chevron North Arnet Exploration and Production
Technical Assistant 3800 Centerpoint Dr. Suite 100
Anchorage, AK 99503
907 263 78
Fax:
Fax: 907 263 7828 28
E -mail: fcastro @chevron.com
DATE October 21, 2010
To: AOGCC
fin, Christine R
333 W. 7 Ave. Ste# 100
Anchorage, AK 99501
IT 1
1� �� cg i ✓ �' ? 4§ �� � -'`a•. �'� � � ``Z. ",�q�. � F��;- , 4::fi'".� { t �� � �a.+.�.� lf�i���`" �. , 7� � �#, � �^„.� §$ r
SRU 32A -33 PERFORATION RECORD 9/17/2010 10698 -10849 X X
SCU 34 -08 2,25" TUBING CUTTER 8/3/2010 10000 -10310 X X
NOV T 5 2010
�OC3)
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX cz. 7 263 7828.
, i
Received By: Date:
J's3e�y
FW: Scanned Document from 003KE~85
Regg, James B (DOA)
From: Noble, Robert C (DOA)
Sent: Sunday, August 15, 2010 6:43 PM
To: Regg, James B (DOA)
Subject: FW: Scanned Document from 003KEN185
Attachments: Document.pdf
Jim
Here is the chart from the SRU 34-08 casing test.
Bob
• Page 1 of 1
Pry ~ ~ i - c~ ~-.~
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From: Hegwer, Chad [FGC Safety & logistics] [mailto:HEGW@chevron.com]
Sent: Sun 8/15/2010 8:38 AM
To: Noble, Robert C (DOA)
Cc: Menapace, Michael Sam
Subject: FW: Scanned Document from 003KEN185
Mr. Noble,
Please find attached the scanned copy of the BOP test chart for Swanson River Unit 34-08. If I can be of more
assistance please let me know.
Chad Hegwer
CHEVRON -FGC Safety & Logistics
Drilling Expediter
Swanson River
Office (907) 283-7315
hegw@chevron.com
Out of the night that covers me,
Black as the pit from pole to pole,
I thank whatever gods may be
For my unconquerable soul.
In the fell clutch of circumstance
I have not winced nor cried aloud.
Under the bludgeonings of chance
My head is bloody, but unbowed.
Beyond this place of wrath and tears
Looms but the Horror of the shade,
And yet the menace of the years
Finds and shall find me unafraid
It matters not how strait the gate,
How charged with punishments the scroll,
I am the master of my fate:
I am the captain of my soul.
r '~' .. ~,,,,
-----Original Message-----
From: 003KEN185@chevron.com [mailto:003KEN185(a,chevron.com]
Sent: Sunday, August 15, 2010 8:34 AM
To: Hegwer, Chad [FGC Safety & logistics]
Subject: Scanned Document from 003KEN185
Please open the attached document. 'This document was digitally sent to you using an HP Digital Sending device.
8/16/2010
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Timothy C. Brandenburg
Drilling Manager
Union Oil Company of California ~~ ~ ~ ~'
P.O. Box 196247
Anchorage, AK 99519
Re: Swanson River Field, Hemlock Oil Pool, SCU 34-08
Sundry Number: 310-230 ~ ~~~~~
Dear Mr. Brandenbur ,~ta~~'~°~~~ ~~ ~ ~ A
g
Enclosed is the approved Application for Sundry Approval relating to the above
referenced well. Please note the conditions of approval set out in the enclosed
form.
As provided in AS 31.05.080, within 20 days after written notice of this
decision, or such further time as the Commission grants for good cause shown,
a person affected by it may file with the Commission an application for
reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the
next working day if the 23rd day falls on a holiday or weekend.
Sincerely,
Daniel T. Seamount, Jr.
r Chair
DATED this 3 day of August, 2010.
Encl.
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STATEOFALASKA ~~ ~ ~~ ~0~~~o$IDZ,Zo1o
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS~~sk~ & Ges CI~,Gission
20 AAC 25.280
1. Type of Request: Abandon ^~ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^
Suspend ^ Plug Perforations ^~ Perforate ^ Pull Tubing ^~ Time Extension ^
Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ^ Alter Casing ^ ^
2. Operator Name: 4. Current Well Class: emtit to Drill Number.
Union Oil Company of California Development^ Exploratory ^ 61-043
3. Address: Stratigraphic ^ Service ^ 6. API Number:
PO Box 196247, Anchorage, AK 99519 50-133-10119-00 -
7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number:
property line where ownership or landownership changes:
Spacing Exception Required? Yes ^ No ~ Soldotna CK Unit (SCU)'34-08~
9. Property Designation (Lease Number): 10. Field/Pool(s):
FEDA028996 [Soldotna Creek Unit] ~ Swanson River Field /Hemlock Oil Pool -
11 • PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured):
11,175 11,175 10,753 10,753 N/A 10,753' (fill)
Casing Length Size MD ND Burst Collapse
Structural
Conductor 28' 22^ 2g' 28'
Surtace 2,009' 11-3/4" 2,009' 2,009' 3,070 psi 1,510 psi
Intermediate
Production 11,170' 7" 11,170' 11,170' 6,340 psi 3,830 psi
Liner
Pertoration Depth MD (ft): / Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft):
10,679'-10,680', 10,682'- 10,679'-10,680', 10,682'-
10,696', 10,721'-10,758', 10,696', 10,721'-10,758',
'
' 2-7/8" ~ 6.5# N-80 10,712'
10,766'-10,786', 10,792'- 10,766'-10,786
, 10,792
-
10,810' 10,810'
Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft):
~
'
'
Baker FH Packer / N/A ND) / N/A
MD (10,641
10,641
12. Attachments: Description Summary of Proposal ^~ 13. Well Class after proposed work:
Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development ^~ - Service ^
14. Estimated Date for /2010 15. Well Status after proposed work:
Commencing Operations: $ ~~ Oil ^ Gas ^ WDSPL ^ Plugged ~ ^~
16. Verbal Approval: Date: N/A WINJ ^ GINJ ^ WAG ^ Abandoned ~ ^~
Commission Representative: GSTOR ^ SPLUG ^
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola 263-7640
Printed Name Timothy C. Brandenburg Title Drilling Manager
Signature ~~ ~~ Phone 276-7600 Date 7/28/2010
`- ~ COMMISSION USE ONLY
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witness Sundry Number: ~l ~ ~~~~
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Subsequent Form Required: ~ ~ ,. -r
APPROVED BY
THE COMMISSION Date: ~ 3 /
Approved by: COMMISSIONER
Form 10-403 Revised 12/2009 , ~ ~ AUG d ~ Lo Submit in Duplicate
Chevron •
Swanson River Unit
Well #SCU 34-08
7/27/10
OBJECTIVE:
• Plug, isolate zones, & abandon onshore well, Soldotna Creek Unit: SCU 34-08. This well has no production potential or
future wellbore utility.
PROCEDURE SUMMARY:
1 RU Eline. Pressure test lubricator 250psi low/3500psi high.
2 RIH and cut tubing at +/- 10,300' RKB.
3 Circulate well with lease water.
4 Contingency: (If unable to establish circulation, punch tubing above cut).
5 MIRU Key Energy Rig #3.
6 NU BOP., test same to 250psi low/3,000psi high. i'
7 Pull 3-1/2" production tubing at +/-10,300' above collapsed tubing at 10,321'.
8 Scrape 7" casing and tag tubing cut depth of +/-10,300'.
9 Run 7" cement retainer to +/-10,275' and tag with 10K. ~
10 Sting into retainer and squeeze +/-30 bbl +/-15.8 ppg cement across Hemlock zones.
11 Pull out of retainer and spot +/-5 bbl +/-15.8 ppg cement above cement retainer.
12 Displace well over to +/- 13.8 ppg mud. (Abnormally pressured zone @ 10,278'. Killed with 12.8 ppg ~
mud during drilling.)
13 Run 7" bridge plug to +/-8,200' and tag with 10K. /
14 Spot +/-20 bbl 15.8 ppg cement on top of bridge plug. (Abnormally pressured zone @ 8,130'. Killed with
12.0 ppg mud during dri112~.)g. ~GI~ ~~,~ ~
15 Run 7" bridge plug to +/2;96646 ' (+/~ below 11-3/4" shoe) and tag with 10K.
16 RU Eline. Perforate +/-15' section above bridge plug. Make 2"d run to re-perforate +/- 15' section to
increase shot density. Attempt to circulate up 7" x 11-3/4" annulus.
17 Run 7" cement retainer to +/-1,934' and tag with 10K.
18 RU Eline. Casing punch +/-6' section above cement retainer at +/- 1,910'. Establish circulation up 7" x
11-3/4" annulus.
19 Contingency: (If unable to establish circulation, punch casing above previous cut).
20 Sting into retainer and squeeze +/-30 bbl +/-15.8 ppg cement below retainer up thru casing punch.
21 RU Slickline. Run 7" bridge plug to +/- 500' RKB.
22 RU Eline. Casing punch +/-6' section at +/- 490' RKB. Establish circulation up 7" x 11-3/4" annulus.
23 Circulate +/-75 bbl %-15.8 ppg cement to surface.
24 RD. Release Key Energy Rig #3.
25 Excavate cellar, cut off casing 3' below natural GL, set marker plate, collect GPS coordinates specifying
coordinate system in daily report, backfill cellar. Close out location.
Current BHP: 3,567 psi @ 10,721' TVD
Max Downhole Pressure: 3,567 psi @ 10,721' TVD (Based on fluid level at 2,650' and a produced water gradient)
MASP: 2,496 psi (Based on a pressure gradient of 0.1 psi per foot of true vertical depth)
SCU 34-08 REVISED BY: STP 7-27-10
9
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FF1
Top of Rll 8 ~~~
~ 11
CdlaFsed Caarg
•,
18753 SLM
2/24193
FF2
Cdlapsed Casing `:
-
1x771, RFB '"
6/23/86
12 ~'# .' ~
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Casing and Tubing Detail
Size Type Wt/ Grade Top Btm CONN / ID Cement /Other
22" Conductor - Surface 28' - Cemented
11-3/4" Surface 47#, J-55 Surface 2,009' SRD / 11.000" 1400 sx / Cmt to Surface
29#, N-80 Surface 121' Butt / 6.184"
23#, N-80 121' 4,943' Butt / 6.366" 700
4
265'
/ C
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26#, N-80 4,943' 6,881' Butt / 6.276" sx
,
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7" Production 29#, N-80 6,881' 7,797' Butt / 6.184"
7,797' 7,799' DV Collar
29#, N-80 7,799' 8,679' Butt / 6.184" 1100 sx / Cmt to 10,275'
29#, P-110 8,679' 11,170' 8RD / 6.184"
Tubing '7" Marker Jt at 10, 275.50' (14.26
2-718" Production 6.5#, N-80 Surface 10,712' 8RD / 2.441" Colla sed at 10,318' SLM
Produc tion Strin Jewel Detail
# De th RKB Len th ID OD Item
1 16.20' - - - Tubin Han er, 2-7/8" 2-7/8" 8RD lift threads ?
2 912' - 2.313" 3.668" X Ni le Min ID = 2.313"
3 5,500' - - - Camco MM GLM
4 7,497' - - - Camco MM GLM
5 8,986' - - - Camco MM GLM
6 10,572' - - - Camco MM GLM
7 10,616' - 2.313" 3.668" XA Slidin Sleeve O ens U
8 10,630' - 2.4375" 3.6875" Brown CC Safet Joint
9 10,641' 5.72' 2.416" 5.983" Baker FH acker Set 6/29/86
10 10,679' - 2.205" 3.668" XN Ni le Min ID = 2.205"
11 10,713' - - - Baker Shear Sub
12 10,778' 15.67' - - Fish: Slickline Tools, 15.67' Lost 7/21/83
13 10,809' 89' - - Fish: Tubin Tail cut-off, 89' Cut 6/4/70
Perforation Data
ZONE TOP BTM SPF Condition
WSO 10,679' 10,680' S W.S.O. aterShut-o , S ueezed 1/20/62
H1 10,682' 10,696' 4 S ueezed 1/20/62
H2 10,721' 10,758' 8 Re- erf6/5/70,'/z'EH
H3 10,766' 10,786' 8 Re- erf 6/5/70, Yz' EH
H4 10,792' 10,810' 8 Re- erf6/5/70,'/2'EH
• Packer fluid consists of 9.8 ppg NaCI Brine
• Found collapsed 7" casing at 10,771' on 6/23/86
• 7" casing tested to 2,800 psi above 10,645' on 6/27/86
• Tagged collapsed tubing at 10,318' SLM w/ 1.25" LIB and 2.3" LIB on 3/11/95
• Tubing x casing communication confirmed 7/26/95
.~;
Directional Data:
7D=11,175' P67D=11,124' max hole angle = 2.5° at 4659' MD
7" Cement Bond Lo;;
4,265' - 4,525' - Good
4,525' - 4,845' - Fair
4,845' - 5,090' - Good
5,090' - 5,430' - Fair
5,430' - 7,797' - Good
10,275' - 11,170' - Good
SCU 34-08 Actual Well Schematic 5-06-10.doc Updated by STP 7-01-10
~>ICVrv~ - Swanson River Unit
SCU 34-08 Well SCU 34-08
~' Proposed 7/27/10
- PROPOSED SCHEMATIC
.~~
(ill: 164 F~ / (~ 148.75' AN6L
F~THF: 16.Z Ill
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1
13.8 ppg
Mud
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CBL Top: 4,265 ''
1 13.8 ppg
Mud
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7,79T ;5:
4
Cli Tap: 10,275'
Collapsed Tubirg
10,321' SLM
5/06110
Top of RII 8 ,
Collapsed Casing
10,753' SLM
2/24193
Collapsed Casing'1
10,7TI' RIB y
6/231186
13
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Casing and Tubing Detail
Size Type Wt/ Grade Top Btm CONN / ID Cement /Other
22" Conductor - Surface 28' - Cemented
11-3/4" Surface 47#, J-55 Surface 2,009' 8RD / 11.000" 1400 sx / Cmt to Surface
29#, N-80 Surface 121' Butt / 6.184"
23#, N-80 121' 4,943' Butt / 6.366" 700
4
265'
/ C
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26#, N-80 4,943' 6,881' Butt / 6.276" m
,
sx
o
7" Production 29#, N-80 6,881' 7,797' Butt / 6.184"
7,797' 7,799' DV Collar
29#, N-80 7,799' 8,679' Butt / 6.184" 1100 sx / Cmt to 10,275'
29#, P-110 8,679' 11,170' 8RD / 6.184"
Tubing `7" Marker Jt at 10, 275.50' (14.26')
2-7/8" Production 6.5#, N-80 10,300' 10,712' 8RD / 2.441" Colla sed at 10,318' SLM
Produc tion Strin Jewel Detail
# De th RKB Len th ID OD Item
1 500' 2.0' - - 7" Brid a Plu TOC =Surface)
2 1,934' 2.0' - - 7" Cement Retainer (TOC = 1,910')
3 ;Z,A84'' /0 2.0' - - 7" Bridge Plu
4 ' 8,23 ' lr.! ~' 2,0' - - 7" Brid a Plug (TOC = 7,690')
5 10,275' 2.0' - - 7" Cement Retainer (TOC = 10,140')
6 10,300' - 2.442" 2.875" Cut joint, 2-7/8" tubing
7 10,572' - - - Camco MM GLM
8 10,616' - 2.313" 3.668" XA Slidin Sleeve O ens U
9 10,630' - 2.4375" 3.6875" Brown CC Safet Joint
10 10,641' 5.72' 2.416" 5.983" Baker FH acker Set 6/29/86
11 10,679' - 2.205" 3.668" XN Ni le Min ID = 2.205"
12 10,713' - - - Baker Shear Sub
13 10,778' 15.67' - - Fish: Slickline Tools, 15.67' Lost 7/21/83
14 10,809' 89' - - Fish: Tubin Tail cut-off, 89' Cut 6/4/70
Perforation Data
ZONE TOP BTM SPF Condition
WSO 10,679' 10,680' 5 W.S.O. ater Shut-o , S ueezed 1/20/62
H1 10,682' 10,696' 4 S ueezed 1/20/62
H2 10,721' 10,758' 8 Re- erf 6/5/70, '/z' EH
H3 10,766' 10,786' 8 Re- erf6/5/70,'/z'EH
H4 10,792' 10,810' 8 Re- erf6/5/70,'/2'EH
• Cut tubing at 10,300' above collapsed tubing using Jet Cutter
• Squeeze 30 bbl cement below squeeze packer at 10,275', spot 5 bbl above to 10,140'
• Circulate 13.8 ppg mud and leave between plugs
• Spot 20 bbl cement above bridge plug at 8,230' to 7,690'
• Squeeze 35 bbl cement below squeeze packer at 1,934', squeeze thru punch holes at 1,910'
• Circulate 75 bbl cement (35% excess) above bridge plug at 500' to surface
/ ~,s 3 : I ~ hl~l
io21ti
r, r.. f= ~y~\
Directional Data:
7D=11,175' P67D=11,124' max hole angle = 2.5° at 4659' MD
7" Cement Bond Loy
4,265' - 4,525' - Good
4,525' - 4,845' - Fair
4,845' - 5,090' - Good
5,090' - 5,430' - Fair
5,430' - 7,797' - Good
10,275' -11,170' - Good
SCU 34-08 Proposed Well Schematic 7-27-10 doc Updated by STP 7-27-10
Chevron . •
Summary of Key Energy Rig #3 Specifics
SCU 34-08 Plug & Abandonment
The SCU 34-08 plug & abandonment will involve setting 4 downhole plugs. The rig specifics are for the
planned rig up on this well and are likely to change from well to well.
Proposed Configuration
Rig Model
The rig model is a Hopper Hydra-hoist, Back-model GXXTA.
Drawworks
The drawworks are GXXTA-MD 10x42; w/ Sand Drum 15,000 ft - 9/16" sand line.
Derrick
The derrick is a telescoping double, with 260,000 Ib capacity, 30" crown sheaves and McKissick 30"
150 ton 73A traveling block..
Pipe Handling
The pipe handling system is a HydraWalk-hydraulic catwalk, 38' long, 5' wide, 5' high. The base
beam is internally guided and load bearing. The beam is load rated with 102' derrick and 10,000 of 2-
7/8" tubing to 58 mph winds.
BOP Specifications ~
Annular, 5M 7-1/16" Hydril
Single gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram (2-3/8", 2-7/8", or 3-1/2" rams)
Double gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram (2-3/8", 2-7/8", or 3-1/2" rams) and blind ram
Mud Cross, 5M, 7-1/16"
BOP Diagram
See attached.
Accumulator
120 gallon KOOMEY Accumulator System. Includes 5 functions with manual bypass and remote
panel. Eight 15 gallon accumulator bottles. 200 gallon hydraulic tank with air operated hydraulic
pump.
Pits %
The pit consists of a 200 bbl tank partitioned into three isolatable compartments. An optional shale
shaker is also available that is a 3'x4' Jr. Standard-hydraulic driven.
Pump
The pump is a National JWS-400 7"x4.5" Triplex rated to 5,000 psi on an independent skid. The
pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent
stand pipe line.
Kill Line
The Kill Line/Circulating Line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors.
Key Energy Rig #3 Specs (SCU 3408) rev0.doc 7/06110
Chevron ~ •
Kill Line Valves
The kill line valves consist of 2 ea. manually operated, 2-1/16", 5M valves attached to the mud cross..,
with co-flex hose with a Unibolt/Hub-flanged connectors.
Choke Line
The choke line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors.
Choke Line Valves
The choke line valves consist of 1 ea. manually operated, 2-1/16" 5M valve and 1 ea. automatically
operated HCR valve that is attached to the mud cross with co-flex hose with a Unibolt/Hub-flanged
connectors.
Choke Manifold
See attached.
Choke Return Line/Diffuser Line
The diffuser line will consist of 2", 5,000 psi hose with Unibolt connections. The line will run from the
choke manifold to the diffuser tank.
Diffuser Tank
A diffuser tank will be placed adjacent to the mud pits with the capability of fluid transfer to the
circulating system.
Gas Detection
There is a single gas LEL monitor and a single H2S monitor be placed at the work platform; and a
single gas LEL monitor and a single H2S monitor at the shale shaker if used.
PVT
There is no PVT system for the circulation system on this workover rig, as is standard practice in this
type of well service work.
Key Energy Rig #3 Specs (SCU 3408) rev0.doc 7/06/10
Chevron ~ BOPS Diagram
SCU 34-08 Plug & Abandonment
7/06/2010
L Annular preventer, Hydril,
7 1/16 5M Flanged
3.08'
I haffer Chasovoy 7 1/16 5 Pipe Ram ~ 9.00'
O i 4' stdd X 7 1~M stdd
1.04'
haffer Chasovoy 7 1/16 5 Pipe Ram ~
stdd X 7 1 5M stdd
2.27'
Blind Ram
• Mud Cross, 7 1/16 5M FE X
7 1/16 5M FE w/ 2 1/16 5M
X 2 1/16 5M EFO
Kill line 2 1/16 5M Choke line 2 1/16 5M
1.6T i o' I o o
00 00 00
Unibolt HCR Unibolt
ChEVron ~ Swanson River 2010
Choke Manifold
07/01/2010
Blooey Line To Gas Buster
Unibolt Connection
00
0 0
~`
August 3, 2009
Dale A. Haines
Manager, Oil & Gas
Operations
Cathy Foerster
Commissioner
Alaska Oil & Gas Conservation Commission
333 W. 7th Avenue
Anchorage, Alaska 99501
Dear Commissioner Foerster,
\ o `-C-S 0
Union Oil Company of California
3800 Centerpoint Drive, Suite 100
Anchorage, AK 99503
Tel 907 263 7951
Fax 907 263 7607
Mobile 907 227 0761
Email daleah@chevron.com
AUG 0 tb 2009
AlPRkR nii & Gas Cons, Nrinmigsirart
Ariv,,hoil.nn,
Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas
Wells
This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking
the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive
for more than five years you provided us. Attached is an updated list with our comments.
Please note that nearly a third of the list you provided is comprised of wells on the Baker and
Dillon platforms. We are currently conducting operations to prepare both of those platforms for
abandonment. We expect the actual well abandonment work to commence in 2010. Our long
range well abandonment plans for our other fields are currently being developed. The current
strategy is to group/sequence well abandonments by platform over the next several years.
Please also note the following corrections to your list: (1) added G-30 to the Commission's list of
wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for
less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown
status).
Thank you for the opportunity to respond with the revisions to the list. If you would like to
discuss our long range abandonment plans please let us know and we can set up a time to
discuss them with the Commission.
If you have any further questions regarding this response please contact Larry Greenstein at
907-263-7661
Sincerely,
�),4 I�
Ctkl-
Dale Haines
Alaska Area Operations Manager
SCOW OCT 022014
DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe
WELL PTD # SHUT-IN
Br 5-87
1680240
Apr -88 No known damage
Gas - No Production
Phase 1 Abandon
abandon at end of platform life
An -3RD
1941490
Sep -97 No known damage.
Low oil production.
Phase I Abandon
abandon at end of platform life
Br 14-42
1790330
Dec -00 No known damage
Produced water
Phase I Abandon
abandon at end of platforrn life
Br 16-42
1670770
Feb -87 Abandoned
Phase I Abandon
abandon at end of platform life
Br 18-42
1680120
Apr -89 Collapsed Casing
100% water production
Phase I Abandon
abandon at end of platform life
GP 31-14RD#2
1002660
Jul -98 No known damage
High Water Cut
Phase I Abandon
abandon at end of platform life
D-6RD
1820200
Dec -00 Tubing -to -casing communication
Failed MIT
Possible restore injection
abandon at end of platform life
D-18
1690040
Dec -03 No known damage
Made too much sand and water
Phase I Abandon
abandon at end of platform life
D-30RD2
1880980
Nov -91 Perforations covered
Will not flow
Currently used as volume bottle for gas
abandon at end of platform life
D-40RD
1820830
Sep -01 Shallow hole in tubing near #2 GLM
Stopped producing
Phase I Abandon
abandon at end of platform life
G-8RD
1780450
Sep -02 E -Line wire in LS.
Low oil production from LS.
Phase I Abandon
abandon at end of platform life
G-24
1760320
Mar -03 No known damage
High Water Cut
Phase I Abandon
abandon at end of platform life
G-30
1690470
Jun -02 Slickline fish in SS.
Low oil production from LS.
Phase I Abandon
abandon at end of platform life
G-34RD
1790130
Sep -02 No known damage
Low oil production from LS.
Phase I Abandon
abandon at end of platform life
K-6RD
1880280
Sep -98 Tubing and casing full of sand
No Flow
Phase I Abandon
abandon at end of platform life
K-9
1680380
Oct -96 Full of sand, Holes in casing.
No Flow
Phase I Abandon
abandon at end of platform life
K-20
1690660
Jun -02 Tubing sanded up
No Flow
Phase I Abandon
abandon at end of platform life
K-21RD
1790160
Jun -79 Tubing integrity in question
High water cut
Phase I Abandon
abandon at end of platform life
K-23
1780040
Sep -97 Tubing full of sand
High water cut
Phase I Abandon
abandon at end of platform life
Ba -5
1650380
Jun -03 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Ba -6
1660030
Jun -03 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Ba -11
1670170
Jun -03 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Ba -13
1670490
Jun -03 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Ba -18
1760750
Oct -94 No known damage
Gas well that watered out
Phase I Abandon
abandon at end of platform life
Ba -20
1851350
Jun -03 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Ba-25RD
1830720
Jun -03 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Ba -28
1931190
Jun -03 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Ba -29
1931180
Jun -03 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Ba -30
1931200
Jun -03 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Ba -31
1951990
Dec -97 No known damage
Produced water
Phase I Abandon
abandon at end of platform life
Di-2RD
1750070
Dec -02 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
DO
1670280
Dec -02 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Di4
1670580
Jul -98 H draulic pump failure
No production
Phase I Abandon
abandon at end of platform life
Di -13
1750440
Dec -02 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Di -14
1750660
Dec -02 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Di -15
1760450
Dec -02 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Di -16
1940570
Dec -02 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Di -17
1940560
Dec -02 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
Di -18
1940980
Dec -02 No known damage
Platform shut-in -- uneconomic
Phase I Abandon
abandon at end of platform life
SCU 12A-10
1750570
Jan -97 milled through csg during plug removal
rocks to 7000'
Possible P&A
2010-2013
SCU 13-4
1750150
Jul -03 no known damage
no flow
Possible WO for T onek
2011-2014
SCU 13-9
1810980
Nov -01 no known damage
no flow
Possible G -Zone RTP
2011-2014
DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe
WELL PTD # SHUT-IN
SCU 21-8
1620190
Aug -9
parted tbg
high water (Hem) no flow (G Zone)
Possible P&A
2010-2013
SCU 21A-4
1801050
Dec -0
no known damage
no flow
Possible shallow gas
Remove due to SI date
SCU 2113-16
1852550
Se -0
no known damage
no flow
Possible shallow gas
2011-2014
SCU 2313-3
1840100
Apr -9
punched hole in tbg
high water
Possible shallow gas
2011-2014
SCU 24A-9
1750220
Se -0
no known damage
no flow
Possible WO for T onek
2012-2015
SCU 31-8
1810990
Nov -0
no known damage
no flow
Possible Sidetrack to G-Zone/I-Iemlock
2012-2015
SCU 312-9
1600280
Nov -0
no known damage
cemented drill pipe in well
Attempted recom letion to G -Zone - Ops Shutdown
Remove due to Ops SD
SCU 314-3
1610230
Mar -9
no known damage
no flow
Possible WO for T onek gas
2011-2014
SCU 3213-9
1002670
Nov -0
no known damage
no flow
Possible T onek oil
2011-2014
SCU 34-8
1610430
Jan -9
no known damage
no flow
Possible P&A
2010-2013
SCU 41B-9
1002690
Nov -9
no known damage
no flow
Possible WO for T onek gas
2011-2014
SCU 43-9
1620310
May -9
punched hole in tbg
high water
Possible P&A
2010-2013
SCU 444
1740660
Oct -0
no known damage
no flow
Possible T onek oil
2012-2015
SRU 212-10
1600180
Oct -9
no known damage
high water
Possible Beluga gas
2010-2013
SRU 212-27
1610330
Dec -0
no known damage
tight sand - no flow
Possible other shallow gas
2011-2014
SRU 234-15
1600410
Dec -0
no known damage
no flow
Possible shallow gas or gas storage
2011-2014
Monopod A-10
1670760
Apr -81
Collapsed casing
Producing Coal
Phase I Abandon
abandon at end of platform life
Monopod A-23 1
1720200
Jun -81
Collapsed casing
Producing Coal
Phase I Abandon
abandon at end of platform life
Monopod A-30 1
1730140
Oct -91
No known damage
Water production due to WF breakthrough
Phase 1 Abandon
abandon at end of platform life
SARAH PALIN, GOVERNOR
tlrti l
��r �� taT
SKA 011LA11 D GAS 333 W. 7th AVENUE, SUITE 100
CONSERVATION COMMc`''IrON ANCHORAGE, ALASKA 99501-3539
�L41 $1 l:L 1i lii• ►T►7 lD•E PHONE (907) 279-1433
FAX (907) 276-7542
June 22, 2009
Dale Haines
UNOCAL
3800 Centerpoint Dr. Ste 100 SCANNED OCT 4 2014
Anchorage AK 99503
Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells
Dear Mr. Haines:
The records of the Alaska Oil and Gas Conservation Commission (Commission)
indicate that the oil and gas wells on the attached list that are operated by UNOCAL
have been inactive for five years or longer.
If, for any listed well, UNOCAL believes the Commission's information is not correct,
by August 3, 2009, please indicate the status of the well—i.e., in production, plugged
and abandoned, suspended, converted to a water well, or converted to an injection
well—and provide all documentation relevant to the well's correct status.
If, for any listed well, UNOCAL agrees that the Commission's information is correct, by
August 3, 2009, please identify the plans, including the schedule, to plug and abandon
the well, suspend the well, return the well to production, or convert the well to a water
well or injection well.
This request is made pursuant to 20 AAC 25.300. Responding does not relieve
UNOCAL of the obligation to comply with any legal requirements or mean that the
Commission will not take any additional action, such as an enforcement action under 20
AAC 25.535.
If you have questions regarding this request for information, please contact Mr. Winton
Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertCa�alaska.gov.
Sincerely,
4401Z'_"
Cathy . Foerster
Commissioner
Enclosure
Operator Company
Permit No.
Well Name
UNOCAL Union Oil Company of California
168-024
Granite Pt St 17587 5
_ Union Oil Company of California
194-149
Granite Pt St 18742 03RD
Union Oil Company of California
179-033
Granite Pt St 18742 14
Union Oil Company of California
167-077
Granite Pt St 18742 16
_
Union Oil Company of California
168-012
Granite Pt St 18742 18
Union Oil Company of California
100-266
Granite Pt St 31-14RD2
Union Oil Company of California
182-020
Trading Bay Unit D-06RD
Union Oil Company of California
169-004
_
Trading Bay Unit D-18
Union Oil Company of California
188-098
_
Trading Bay Unit D-30RD2
_
Union Oil Company of California
182-083
_
Trading Bay Unit D-40RD
Union Oil Company of California
178-045
_
Trading Bay Unit G-08RD
_ Union Oil Company of California
176-032
_
Trading Bay Unit G-24
Union Oil Company of California
179-013
Trading Bay Unit D-06RD
Union Oil Company of California
188-028
_
Trading Bay Unit G-34RD
Union Oil Company of California
168-038
Trading Bay Unit K-06RD
Union Oil Company of California
169-066
Trading Bay Unit K-09
_
Union Oil Company of California
179-016
_
Trading Bay Unit K-21 RD
_
Union Oil Company of California
178-004
Trading Bay Unit K-23
Union Oil Company of California
165-038
MGS St 17595 05
Union Oil Company of California
166-003
MGS St 17595 06
Union Oil Company of California
167-017
MGS St 17595 11
Union Oil Company of California
167-049
MGS St 17595 13
Union Oil Company of California
176-075
MGS St 17595 18
Union Oil Company of California
185-135
MGS St 17595 20
Union Oil Company of California
183-072
MGS St 17595 25RD
Union Oil Company of California
193-119
MGS St 17595 28
Union Oil Company of California
193-118
MGS St 17595 29
Union Oil Company of California
193-120
MGS St 17595 30
Union Oil Company of California
195-199
MGS St 17595 31
Union Oil Company of California
175-007
S MGS Unit 02RD
Union Oil Company of California
167-028
S MGS Unit 03
Union Oil Company of California
167-058
S MGS Unit 04
Union Oil Company of California
175-044
_
S MGS Unit 13
Union Oil Company of California
175-066
S MGS Unit 14
Union Oil Company of California
176-045
_
S MGS Unit 15
Union Oil Company of California
194-057
S MGS Unit 16
Union Oil Company of California
194-056
S MGS Unit 17
Union Oil Company of California
194-098
S MGS Unit 18
Union Oil Company of California
175-057
_
Soldotna Ck Unit 12A-10
Union Oil Company of California
175-015
Soldotna Ck Unit 13-04
Union Oil Company of California
181-098
Soldotna Ck Unit 13-09
_
Union Oil Company of California
162-019
Soldotna Ck Unit 21-08
Union Oil Company of California
180-105
Soldotna Ck Unit 21A-04
Union Oil Company of California
185-255
Soldotna Ck Unit 21 B-16
Union Oil Company of California
184-010
Soldotna Ck Unit 23B-03
Union Oil Company of California
175-022
Soldotna Ck Unit 24A-09
Union Oil Company of California
181-099
Soldotna Ck Unit 31-08
Union Oil Company of California
160-028
Soldotna Ck Unit 312-09
Union Oil Company of California
161-023
Soldotna Ck Unit 314-03
Union Oil Company of California
100-267
Soldotna Ck Unit 32B-09
Union Oil Company of California
161-043
Soldotna Ck Unit 34-08 _
_
Union Oil Company of California
100-269
Soldotna Ck Unit 41 B-09 _
Union Oil Company of California
162-031
Soldotna Ck Unit 43-09 _
Union Oil Company of California
174-066
Soldotna Ck Unit 44-04 _
_
Union Oil Company of California
160-018
Swanson Riv Unit 212-10
Union Oil Company of California
161-033
Swanson Riv Unit 212-27 _
Union Oil Company of California
160-041
Swanson Riv Unit 234-15
Union Oil Company of California
167-076
Trading Bay St A-10
Union Oil Company of California
Union Oil Company of California
172-020
173-014
Trading Bay St A-23DPN
Trading Bay St A-30
Form ~160-5
(JUNE 1990)
UNITED STATES
DEPARTMENT OF THE INTERIOR
BUREAU OF LAND MANAGEMENT
SUNDRY NOTICES AND REPORTS ON WELLS
Do not use this form for proposals to drill or to deepen or reentry to a different reservoir.
Use 'APPUCATION FOR PERMIT-' for such proposals
SUBMIT IN TRIPLICATE
1. Type of Well
Oil Gas
~: Well I~ Well r-] other
2. Name of Operator
Union Oil Company of California (dba Unocal)
3. Address and Telephone
P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600
4. Location of Well (Footage, Sec., T., R., M., or Survey Description)
Swanson River Unit -- 14 Wells
Soldotna Creek Unit -- 7 Wells
FORM APPROVED
Budget Bureau No. 1004-0135
Expires: March 31, 1993
5. Lease Designation and Serial No.
6. If Indian, Nlottee or Tribe Name
7. If Unit or CA, Agreement Designation
Swanson River/
Soldotna Creek Units
8. Well Name and No.
9. APl Well No.
10. Field end Pool, or Exploratory Area
Swanson River Field
11. County or Parish, State
Kenai, Alaska
12.CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA
TYPE OF SUBMISSION TYPE OF ACTION
I-'1 Change of Plans
Notice of Intent
Subsequent Report
I-'-I Final Abandonment'
[-] Abandonment
I'-] Recompletion ~ New Construction
I--I Plugging Back J-'J Non-Routine Fracturing
I'-'l Casing Repair r-] Water Shut-Off
r'-] Altering Casing r-] Conversion to Injection
~: Other Temporarily Abandon I-'} Dispose Water
(Note: Report rasults of multiple conmpletion on Well
Completion or Fle<x)mple6on Repmt and Log fo~m.)
13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of stmlJng any txoposed work.
If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zone pertinent to Wis work.)*
As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status
for the twelve month period, April 1,1996 to March 31,1997:
Soidotna Creek Unit
(.e2' J Cj SCU 21-8 ,MISCU 34-9 ~-) ~SRU 212-10
(O I" ~J~ SCU 34-8 ~'--~SCU 41B-9 (.eO -~.~_ RU 12-15
(~- I SCU 243-81 ~U 14-3400-I ~SRU 14-15
41
SRU 43A- 15
SRU
~'0: I 0.'7 '/ J ~ I ( SRU 23-22
* High GOR well that may be produced intermittently
Swanson River Unit
SRU 23-27
s.u 33 -27 00-,-,0
SRU 34-28 ~,~- 7_
SRU 43-28 (p I"~_
SRU 21-33WD ~ ~.-~, /~PR 0 1 1996
SRU 24-33 ~ ~.- '7
14. I hereby certify th~ bge foregoing is true and con'ect.
Dennis L. Groboske
Petroleum Engineer pat, 3/29/96
Conditions of approval, if any:
Date
ThJe 18 U.S.C. Section 1001, makes it a c~ime for any person knowingly and willfully to make to any department or agency of ttm United Slates any false, rmUUous or
fraudulert statements or repf__ _,,~-~_ '_fions as to any' m~__f__m,, within its jurisdiction.
*See Instruction on Reverse Side
o.
Attachment No. 1
Swanson River Field
Proposed Temporarily Abandoned Wells: Total 21 Wells
Twelve Month Period: April 1, 1996 to March 31, 1997
Shut-in Wells under Evaluation for
Shut-in Wells during Field BlowdoWn
Rate Potential
P&A
Shallow Gas Potential
and 'Hemlock Only' P&A
Hemlock
Producers
Future Shallow Gas P~'oducer
with the Hemlock Abandoned
$CU 34-8
SCU 243-8
SCU 13-9
SCU 41B-9
SRU 21-33WD
SRU 34-28
SRU 43-28
SRU 212-10
SRU 212-27
SRU 12-15
SRU 41A-15
SRU 23-27
SRU 331-27
SCU 14-34
7 Wells 2 Wells 5 Wells
*~.,h GOR well that may be produced intermittently
SCU 21-8
SCU 34-9*
SRU 14-15
SRU 43A-15
SRU 14-22
SRU 23-22
SRU 24-33
2 Wells
5 Wells
ATTACHMENT 2
SWANSON RIVER FIELD
Wells with Temporarily Abandoned Status Change
Removed from 1996 Temporarily Abandoned Status
· SCU 34-4 Recompleted in Tyonek G1 and G2 zones
· SCU 43A-4
Recompleted in Tyonek G1 and G2 zones
· SCU 13-4
Workover to remove tubing fish. Currently
producing from Hemlock
· SCU 23B-3
Returned to full time production
· SCU 314-3
Returned to full time production
· SCU 43-9
Returned to full time production
· SCU 23-15
Returned to full time production
Additions to 1996 Temporarily Abandoned Status
· SCU 13-9
Recompleted in Tyonek G2 zone Iow rate
oil producer.
tkE.. t::lvE. D
Z~PR 0 ~ 1996
ARCO ALASKA INC.
Cook Inlet/New Ventures Engineering
TRANSMI'I~AL
#355
TO: John Boyle . FROM: Tom Wellman
COMPANY: AOGCC COMPANY: ARCO Alaska, Inc
DATE: Sept. 18, 1989 WELL NAME: SRIJ 34-8
Transmitted herewith are the following ~'
Blue Sepia Sepia
Line Folded Rolled Mylar Tape
PERF. DEPTH RECORD, GR CCL 1 1
,
,
Receipt Acknowledgement:
Remm reciept to ARCO ALASKA, Inc.
ATrN: Judy Boegler ATO 1390A
Post Office Box 100360
Anchorage, AK 99510-0360'
Alaska Oil & Gas Cons. Commissio~
Anchorage
ARCO Alaska, inc. f-'%
Post Office b,.,x 100360
Anchorage, Alaska 99510-0360
Telephone 907 263 4724
T. Stewart McCorkle
Engineering Manager
Cook Inlet/New Ventures
September 13, 1989
Mr. C. V. Chatterton, Chairman
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
RE: Results of Re-perforation
SCU 34-8
Swanson River Field
Dear Mr. Chatterton:
This is to submit the results of the re-perforation of SCU 34-8
that was Performed on August 23, 1989.
If you have any questions concerning this matter, please
contact Staey Striekland at 263-4914.
Sincerely,
T. S. McCorkle
TSM:SLS:eh:0008
Attachment
RECEIVED
sEP 151989
~Je, s~a 0i~ & G~s Cons. Commissiot~
Anchorage
ARCO Alaska, /nc. is a Subsidiary of AtlanticRichfieldCompany
AR3B~6279
STATE OF ALASKA
AL, .A OIL AND GAS CONSERVATION COMMk )N
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown __ Stimulate __ Plugging .__ Perforate ~
Pull tubing ~ Alter casing ~ Repair well m Pull tubing m Other
2. Name of Operator 5. Type of Well:
ARCO Alaska, Inc. Development...~.X
Exploratory __
3. Address Stratigraphic_
P. 0. Box 100360 Anchorage, AK 99510 Service__
4. Location of well at surface
1190' N and 1350' W of SE corner of Sec. 8, T7N, R9W, SB&M
At top of productive interval
Straight Hole.
At effective depth
At total depth
6. Datum elevation (DF or KB)
164' KB
feet
7. Unit or Property name
Sol dotna Creek Unit
8. Well number
SCU 34-8
9. Permit number/approval number
B
10. APl nur~ber
50--133-10119-00
11. Field/Pool
Swanson River/Hemlock
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
11,175 feet Plugs (measured)
11,175 feet
1 O, 773 feet Junk (measured)
1 O, 773 feet
10,773-11,175'
Casing Length
Conductor ' 28 '
Surface 2009 '
Production 11,170'
L rXX
Perforation depth:
Size Cemented
Measured depth
11-3/4" 1440 sx
True vertical depth
7" 1800 sx
0-28' 0-28'
0-2009' 0-2009'
0-11,170' 0-11,170'
measumd/True Vertical
10,721-10,760' MD (H2); 10,766-10,786' MD (H3);
t~(uve~vYe~l Re'perforated Interval
10,721-10,758' MD (H2)
Tubing (size, grade, and measured depth)
2-7/8", N-80, 6.5//, 10,713' MD
Packers and SSSV (type and measured depth)
Baker 7" Model 'FH' packer e 10,641' MD
13. Stimulation or cement squeeze summary'
Intervals treated (measured)
10,792-10,810' MD (H4)
RECEIVED
s [ P 151989
0ii & 6,' s Cons. 6ommissio. i,.
Anchorage
Treatment description including volumes used and final pressure
14.
Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
Tubing Pressure
Prior to well operation
Subsequent to operation
15, Attachments
Copies of Logs and Surveys run N/A
Daily Report of Well Operations ~
95 9037 127 650
102 8850 122 680
Status of well classification as:
Oil _~X Gas __ Suspended
Service
1330
1330
17. I hereby certify that the foregoing is true and'correCt to the best of my knowledge.
Signed ~'~.~.~ Title Cook Inlet Engineering Manager
Form 10-404 Rev 06/15/88
Date
SUBMIT IN DUPLICATE
--- AUG-24-'89 0?:06 ID?U~ANSON RIUER
TEL N0:~6517~,
~550 P02
ARCO Alaska, inc.
WELL SERVICE REPORT
·/7/I -.
- 20:~o
_'~ 0 ;0o- . ....
ECEi" :D
.RFp I r~ IQi~Q
O c. EoK r.~s .Locx,. su~^m COm,.uEo o..^cx
ARCO Alaska, Inc/ '
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 263 4724
T. Stewart McCorkle
Engineering Manager
Cook Inlet/New Ventures
August 9, 1989
Mr. C. V. Chatterton, Chairman
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear Mr. Chatterton:
Attached is an Application for Sundry Approval to Re-
perforate the H2 and potentially the H3 intervals in Well SCU
34-8.
We propose to re-perforate at least 37' of the H2 sand
( 10, 721-10,758' MD) using a 1-11/16" strip perforating gun
at 4 SPF. In addition, we may re-perforate the remaining 2'
of H2 sand (10,758-10,760' MD) and up to 5' of the H3 sand
(10,766-10,771' MD) if bailing efforts are successful in
removing fill.
With your approval, we would like to begin this work as soon
as possible. If you have any questions, please contact Stacy
Strickland at 263-4914.
Sincerely,
T. S. McC0rkle
TSM:SLS:ch:0003
Attachment
cc: S.W. Ohnimus
A. R. Kukla
UNOCAL Corporation
Marathon Oil Company
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279
- /-'-,, STATE OF ALASKA ,.4
AL XA OIL AND GAS CONSERVATION Co~lt~ .ON
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 ~ PulI tubing ~ Variance __ Pedorate ~ Other
2. Nature of Operator
ARCO Alaska, Inc.
3. Address
P. O. Box 100360 Anchorage, AK 99510
5. Type of Well:
Development
Exploratory
Stratigraphic
Service
4. Location of well at surface
1190' N and 1350' W
~top~produ~iveinterval
Straight Hole
~effectivedepth
of SE corner of Sec. 8, T7N, R9W, SB&M
At total depth
6. Datum elevation (DF or KB)
164' KB
7. Unit or Property name
So I dotna Creek Un i-t-
8. Well number
SCU 34-8
9. Permit number
10. APl number
50-- 133-10119-00
11. Field/Pool
Swanson River/Hemlock
feet
12. Present welt condition summary
Total depth: measured
true vertical
11 175' feet PlugS(measured)
11~ 175' feet
None
Effective depth: measured 10,773 ' feet Junk (measured)
true vertical 10,773 ' feet
10,773-11,175'
Casing Length Size Cemented
Conductor 28 ' 22" --
Surface 2009' 11-3/4" 1440 sx
Production 11,170' 7" 1800 sx
Perforation depth: measured/Tr ue vert i Ca I
10,721-10,760'MD (H2); 10,766-10,786'MD (H3);
proposed ~ re-perfs
10,721-10,760'MD (H2); 10,766-10,771 'MD (H3)
Tubing (size. grade, and measured depth)
2-7/8", N-80, 6.5# @ 10,713' MD
Packers and SSSV (type and measured depth)
Baker 7" Model 'FH' packer @ 10,641' MD
MeasureddeCh
0-28'
0-2009'
0-11,170'
10,792-10,810'MD
~ueverticaldepth
0-28'
0-2009'
0-11,170'
13. AttaChments
DesCription summary of proposal __ Detailed operations program ~ BOP Sketch ._~."-
14. Estimated date for commencing operation
August, 1989
16. If proposal was verbally approved
Date approved ! 15.
Status of well classification as:
Oil .~X Gas__ Suspended __
Name of approver Service
,
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed
Title Cook INlet Engineer ing Manager 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- ~'1 ~/~1
Original Signed By
Approved by order of the Commissioner David W. jOhnslon
FOrm 10-403 Rev 06/15/88
SUBMIT IN TRIPLICATE
SCU 34-8 Re-perforating Procedure
SR 66
Ob_iective: Re-perforate the H2 Sand and potentially the 1-13 Sand to increase oil production.
Have fire extinguishers on location.
NOTE: Verify that Sundry approval has been obtained before performing this work.
1, Attempt to bail fill down to collapsed casing at 10773' MD. Last tag was made on 7/25/89 at
10760' MD with a 1.75" gauge ring. Sample of coarse sand and gravel was recovered. If
progress is not readily made, proceed with re-perforation of 1-12 Sand only.
2. RU E-line lubricator and pressure test lubricator.
3. RIH with 1-11/16" Silver Jets (Western Atlas) or equivalent strip perforating guns, weight
bars, gamma ray, and CCL. Tie in to Neutron Collar Log (1/3/62).
4. If no bailing progress was made, perforate the interval from 10,721' to 10,758' MD with 4 -
JSPF. If bailing was successful, perforate all open intervals, i.e. H2 Sand- 10721' to
10760' MD and part of the H3 Sand above collapsed casing - 10766' to 10771' MD.
5. RD E-line. Initiate well production as soon as feasible after perforating. Watch robing
pressure closely to detect possible perforating debris in the choke.
Pertinent Data
Tubing:
Tubing Tail:
Packer Type:
Casing Size:
2 7/8" X 6.5 #/ft Capacity 0.00579 BPF
10,713' MD Min ID 2.205" XN Nipple at 10,679' MD
Baker FH at 10,641' MD.
7" X 29g/ft P- 110 at Packer
EECE V ED
..
~E~faska 0il & t~as (;c~ns, Comn~issi0a
Anchorage
ARCO Alasi~ Inc. it a subsidiary of Atlantic Rlchflel¢l Company
AR38-6001-A
E-Line BOPE's
Grease Head/
Hydraulic Packoff
Lubricator Extension
Manual Rams
Swab Valve
Double Master
Valves
Wellhead
/'% STATE OF ALASKA '-%
ALAS~....OIL AND GAS CONSERVATION COMIC. SION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing []
Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing (~ Amend order [] Perforate ~ Other
2. Name of Operator 5. Datum elevation (DF or KB)
Chevron U.S.A. Inc. G.L. = 147' K.B. = 164 feet
3. Address 6. Unit or Property name
P.O. Box 107839, Anchorage, AK 99510 Soldotna Creek Unit
4. Location of well at surface
1190' N & 1350' W of SE Corner Section 8, T7N' R9W,
SB&M
7. Well number
SCU 34-8
At top of productive interval
Same as above
Ateffective depth
Same as above
Attotaldepth
Same as above
8. Permit number
61-0043
9. APl number
50-- 133-10119
10. Pool
Swanson River - Hemlock
11. Present well condition summary
TOtal depth: measured
true vertical
'11,175 feet
11,175 feet
Plugs (measured) 11,170 '
- 11,124'
Effective depth:
measured 10,809 feet
true vertical 10,809 feet
Casing Length Size
Structural
Conductor 24 ' 22"
Surface 1,990 ' 11-3/4"
Intermediate
Production ' 11,153' 7"
Liner
Perforation depth: measured 10,720' - 10,760'
squeezed 10,696'
true vertical
Junk (measured) 89.00' = Venturi Shoe,
Jt 2-7/8" Tbg, "D" Nipple, Jt 2-7/8"
Tb Cut J 2-7/ "T
Cemente~;' ~easure~dep't~g' True Vertical depth
45' 45'
2,009' 2,009'
11,170' 11,170'
; 10,766' - 10,786'; 10,792' - 10,810'
- 10,682' & 10,679
Tubing (size, grade and measured depth) 2-7/8" 6.5# N-80 8RD EUE at 10,715'
Packers and SSSV (type and measured depth)
12.At t ac h ments
Description summary of proposal [] Detailed operations program I~ BOP sketch
13. Estimated date for commencing operation
May 15, 1986
14. If proposal was verbally approved
Name of ,~pprover ! Date approved
15. I hereby~;~rtify/[~hat the oregoing is true and correct to the best of my knowledge
Area Operations
Signed ~ Titleg,,ne,.~ n t'e.H~n ~
Commission Use Only
Conditi~/of approval Notify commission so representative may witness I Approval No.
[] Plug integrity [] BOP Test [] Location clearance
I
Date
Approved by C- J_ '~/'~z~./3,~~
.
Form 10-403 Rev 12-1-85
Commissioner
by order of
the commission Date
Submit in triplicate
PRO 316-1
PROPOSAL FOR WELL OPERATIONS
Well:
Field:
Location:
Elevation:
Present Status:
SCU 3z~-8
Swanson River
At surface:llg0' N & 1350' W of SE Corner Section g, T7N,
Rgw, SB&M
At Top Prod. Interval: Vertical Well
At TD: Vertical Well
G.L. 1#7' K.B. = 16¥
TD (MD): 11,175'
PBTD (MD): 11,12z$'
Casing:
22" Cemented @ 28'
1 l-3/q" Cemented @ 2009'
7" Cemented @ 11,170'
Perforations:
Squeezed:
10,721'- 10,760'
10,766'-10,786'
10,792'-10,810'
10,696'-10,682' & 10,679'
BHT:
172° F at I0,700'
Tubing:
See the attached detail..
3unk:
See the attached detail.
NOTE:
On 3anuary 25, 1986 it was attempted to
bleed off casing pressure of 3800 PSI
unsuccessfully. Also, there is a tubing
leak at the GLM at 7831'.
BLO~/OUT CONSIDERATIONS:
I.
0
.
.
.
Ga~ This well has produced over 5,000 MCFD. Care must be taken at all
times not to swab the well and to keep the hole full on trips.
Lost Circulation: None anticipated, but lost circulation material (salt pills)
should be readily available at all times.
Precautions: Any kicks should be handled by normal procedures. Rig crews
should be made aware of these methods, and care must be exercised at all
times.
Maximum Anticipated Formation Pressure: 47~;0 PSI from static gradient
survey 3-11-8z~. Programmed weight of 9.2 PPG will provide 370 PSI of
overbalance.
Maximum Anticipated Surface Pressure: 3800 PSI from SICP 1-25-86.
Blowout Prevention Equipment: Minimum of Class III - 5000 PSI.
,L
SCU 30-8
' WORKOVER PROGRAM
I.
.
.
11.
12.
13.
Prior to moving in the workover rig, make sure that there are dummy valves
in all gas lift mandrels. Open the CAMCO sleeve valve at 10,668'. Install the
back pressure valve.
Move in and rig up the workover rig.
Remove the back pressure valve, and kill the well using workover fluid (See
the attached program).
Install the back pressure valve, and nipPle down the tree.
Nipple up the Class III 5000 PSI BOP stack; and test the rams, manifold, and
valves to 5000 PSI. Test the annular to 3500 PSI. The AOGCC and BLM may
witness the test and must have 20 hours prior notice.
Remove and back pressure valve. Circulate the well dead.
Rotate the tubing string 5+ times releasing the Brown "CC" safety joint at
10,692'. Pull out of the hole with the 2-7/8" tubing (see the attached detail).
NOTE: Have a "CC" retrieving tool on the location when releasing the
tubing.
Pick up and trip in the hole with a "CC" retrieving tool, bumper sub, jars,
q-3/0" drill collars, and 3-1/2" drill pipe. Circulate the well clean. Latch
onto the fish at 10,692'. Release the Brown HS-16-1 packer with right hand
rotation. Circulate the well dead. Pull out of the hole, and lay down the
fish.
Pick up and trip in the hole with a 6-1/8" bit, 7" casing scraper, 0-3/0" drill
collars, and sufficient 3-1/2" drill pipe to clean out to the top of the fish at
10,809'. Circulate the well clean. POH.
Pick up and trip in the hole with a mill control guide, extension, overshot
dressed with grapples, extension, bumper sub, jars, drill collars, and drill pipe.
Wash to the top of the fish, and work over fish. Pull out of the hole, and lay
down the fish.
Trip in the hole with a 6-1/8" bit, and clean out fill from 10,898' - 11,120'.
Circulate the well clean. Pull out of the hole.
Rig up, and run a CCL/GR/Neutron log, and CET log from PBTD to depth as
directed by Anchorage Engineering.
Trip in the hole with a 7" retrievable packer on drill pipe set at 10,650'. Test
the 7" casing above the retrievable packer to 2750 PSI for 30 minutes.
LOCate leaks if there are any. A squeeze procedure will follow if there are
any leaks.
I! there are squeezes, after all squeezes and clean out runs are made, make a
7" casing scraper run to PBTD.
NOTE: IF IT IS DECIDED NOT TO PERFORATE, GO TO STEP NO. 20
15.
16.
17.
18.
19.
20.
21.
22.
23.
25.
Run the Tubing Conveyed Perforating Guns and 3-1/2" drill string dry per the
attached detail,
Space out using a GR, and land the drill string with a full joint on the top.
Set the packer; nipple up the test head and surface lines; and test to 5000
PSI.
Load the drill string with 1000 PSI underbalanced nitrogen cushion. Drop the
firing bar, and flow the well on an 8/6t4" choke until the rate and pressure
have stabilized. Flow as directed by Anchorage Engineering.
Shut the well in, and open the bypass on the packer. Reverse circulate the
well dead. Release the packer, and circulate the well.
Pull out of the hole, and lay down the TCP guns.
Trip in the hole with a 6-1/8" bit and casing' scraper to PBTD. Circulate the
well clean. Pull out of the hole~ and lay down the drill string.
Pick up and trip in the hole with the production equipment and 2-7/8" tubing
per the attached proposed tubing detail. Test the production string in the
hole internally below the table to 5000 PSI.
Space out with a full joint of tubing on the top. Install the back pressure
valve. Nipple down the BOPE. Nipple up, and test the tree to 5000 PSI.
Remove the BPV.
Reverse circulate the annulus with lease crude until clean returns are
obtained at the surface.
Hydraulically set the packer. Pressure up and shear out the ball. Test the
annulus/packer to 1500 PSI for 30 minutes.
Install the back pressure valve; rig down the rig; remove the back pressure
valve; and return the well to production per the Area Foreman.
WORKOVER FLUIDS PROGRAM
SCU 34-8
SWANSON RIVER FIELD
FLUIDS SYSTEM:
PROPERTIES
KILL CIRCULATING
Type
Weight(PPG)
Viscosity (SEC/QT)
Fluid Loss (CC/30 Min)
Plastic Vis. (CPS)
Yield Pt. (Lbs/100 Ft2)
Gels (Lbs/100 F t2)
pH
Solids (96 by Volume)
Litesal/Liteplug Litesal/Liteplug
10.2 9.5
65 - 70 35 - 50
5- 7 NC
8- 10 8- 10
20 - 30 8 - 12
8/12 3/3
9 g
17 7
Use primarily a brine water system with the above pills for either kill plug setting
or viscous sweeps.
If cement squeezes are required, pretreat for cement contamination prior to
drilling cement.
-- RE TRi~VASL £ PACK£R
,o
--- 5/../D/NG
--- ,S PA C ~[( R,5
--- ~" 7'CP GUN, S & - ~" ,j',zt,~/=' (D£PTH A $ D/NEC TED )
L
'FOLLOW'IXI5 DEPTI..I,.~ :
"-- Z ,.Z'7',s. ~a# (~.$~ Al-80 ~ffO EU~ TI. It~I^IC~
-- OTI§ "XA " $1EE'VE
-- 7" x Z ~a" BAKER "F/-t" PACKER
--- I0' PIJM
'F'~ 7'0 = 11~ IZ~t '
T'D =/¥/7Y'
P,~OF~SE~ 7'U~I~G DETAIl_
SWAA/,50M CREEK L/All T
C/-IEVROI~I U,~A I~C.
[ ] [[ [ i
OIL AND GAS CONSERVATION COMMI~EE
5UN~ NOTICES AND EEPOET$ ~ W~ k-028966 ...... ~-'5 ~G ~'
(~O Rot ~se this ~o~ ~oT p~oposa[s ~ drH~ oT to de~pe~
use "AP~LICATION'FO~ ~'E~'~~'' ~or sUch'p~o~osal~)
.... ~. IF I~I~. ,,.LO'~"r~ OR TRIBE ~-I' ~:OI
2. NAME OF OPE~TOR 8. UNIT, F~ OR T.E~SE NAME ~k~'J J
Standard 0il Company ,of California Soldotna Creek Un:.= J REV
~. O. Box 7-839 ~chora~e, Alask- .... 99510 34-8 _.~:~ SEC
~t~u~¢~ 1190~ North and 1350~ Nest from Southeast Swanson River
Corner of Sectio~ 8. u. SEC.,o~E~Z~E)T., a., ~., (~Om ~O~
5ec[~on 8~ T. 7 N.~ R. 9 W.
SB&M
12. P~T NO.
13. ELEVATIONS (Show whether DF, RT, GR,
164' K.B.
Check Appropriate Box To I,nd}cate NJature of N~tice, Re
NOTICE OF INTENTION TO:
TEST WATER SHUT-OFF
FRACTURE TREAT
SHOOT OR ACIDIZE
REPAIR 'WELL
PULL OR ALTER CASINO
MULTIPLE COMPI,ETE
ABANDON*
CHANGE PLANS
~Other)
~rt, or Other Data '
SUBSEQUENT REPORT OF:
FRACTURE TREATMENT ~ ALTERING CASING
SHOOTINg OR ACIDIZINO ABANDONMENT*
(Other) '
(NOTE: Report results of multiple completion on Well
Completion or Recompletion Report and Log form.)
15. DESCRIBE PROPOSED OR CO.MPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent datee, including estimated date of starting an)'
proposed work.
1. Pump 70 bbls. Swanson River Well solvent down tubing.
2. Acidize well in 3 equal stages as follows (each stage):
a. 270 gallons 15% HCL and additives.
b. 810 gallons 5% HCL and additives·
c. 2700 gallons 12-10% HCL-HF and additives.
d. 1080 gallons 5% HCL and additives.
3. Return well to production by gas lift.
SIGNED (~ TITLE District Superintendent
.,~,=f...~.,~ v · ~.~& J. ~. A.~ ,,~,. v,~l
DATE
Oct. 13, 1972
(Thi. space for State.~fi~e l~se) _/}
CONDITIONS 0~ kPPROVAL, IF A~ :-
TITLE
See Instructions On Reverse Side
DATE
/? -. ?z/
~roved COpy
Returned
Furm P. 7
~UBMIT IN DUF~TE*
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMITTEE
i i. i i i i i
WE[k ~OMPLETIO~ OR RKOMPLETIO ~ REPORT A~D LOG *
i .. iiii
TYPE OF WELL: oil, ~ GA~' ~ - '~ -
WELI, WELL DRY OthPr
TYP~ OF COMPLE~ON:
BACK
2. NAME OF OPERATOR
3. ADDRESS Or OPERATOa ' '
4. T. OC~r[ON Or WELL (Report location clearly and in accordance with any State requiremeflts)*
At surface
At top prod. Interval reported below
At total depth
1J. DATE SPUDDED ]14. DATE T.D. REACHED
15. ',DATE COMP 'SUSP OR.ABAND:
] 8, TOTAL DEFrk/, MD & TVD I9, PLUG, BACK MD & 'rVDF. I~/V~LTI~LE COM~L., I21.
PRODUCING INT~VAL(S), OF ~IS COM~TION--TOp, BOSOM, N~E (~ AND ~)*
24. TY/~E ELECTRIC AND OTHER LOGS.RUN
5. API NI. FM,EKICAL CODE
6. LEASE DESIGNATqON A.ND SERIAL NO.
7. IF INDIA.N, ALLOTTEE OR TRIBE NANLE
UNIT,FA.Ih'Vi OR LEASE NAME
9. WELL NO.
i0' FIELD A2qD POOL, OR WILDCiT
il. SEC., T., R., M., (BOTTOM HOLE
DIRECTIVE)
12. PEH,MIT NO,
i16.' ]
ELEVATIONS (DF, RKB, RT, GR, ~PC)* 17. ELEV. CASINGHEAD
INTERVALS DRILLED BY
'!' CABI,E TOOLS
23, WAS DIRECTIONAL
SURVEY MADE
1
CASI.NG SIZE 1 WEIGHT, LB,;FT,
11,'7,5' ,
LINER iR~EC O~13
_ _~ [[ TOP (MD) I BOTTOM (MD)[tSACKS CEMENT* i
2s. PE~FOR.ATXONS OP~ w6 P~bbu, '~o~" ~Xntcrval, size and number)
i i
CASING RECORD (Report al~ strings set in well)
[ :h~,,l . I(, I
Al"°. iq'W[
iii
PRODUCTION
l,~qe
I 27. I'-
SCREEN (MD) SIZE
_
. J zT/t . j
i i
29. -ACID, SHOT, Fi~ACq. JRE, CE~,IENT SQU'.U. EZ~, ETC,
D~Ili iNT~V.~ (MD) J AsmuNr /~D I'21ND OF M~IEPAAL US~
1o~ - ~e~ ....... ~' ·: q~ ~.
I
ii ii i ] i i i
CEAiLNTING RECOI~D i A~OUNT PULLI~.D
TUBING HECOFLD
DEPTH SE/' (MD) ~ PACKER SET (MD)
DATE FIRST PIIODUCTION [ Pl%ODUCT1ON MElt{OD (Ftowh~g, gas lift, pumping--size and type of pump)
F~OW, TUBINC~ IC^S~G P~ESSUa~ icX~cm-Xrm., Om--~L. ~s--~r¢~.
31. DISPOSITION Or GAS (8otd; u~ed .for .fuel, vented, etc.)
32. LIST 0~' ATTACHMENTS
I V~ELL STATUS (Producing or
unut-ln)
GAS--NkCF. WA'fER~BBL. J GAS-OIL ILATIO
i
W~B~L, OIL GRAVITY-~I (CORR.)
I
ITEST WITNESSED BY
" 33. I hereby, certify that the foregoing and attached information is complete and correct as determined from all-available iecords
SIGNED TITLE DATE
*(See Instructions and Spaces for Additional Data on Reverse Side)
INSTRUCTIONS
General: This form is designed for submitting a complete and correcl well completion report and log on
all types of lanJs and leases in Alaska.
Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure-
ments given in cther spaces on this form and in any attach:~-~ents.
Items 20, and 22:: If this well is completed for separate ~rcduction from more than one interval zone
(mulliple completion), so state in item 20, and in item 22 show the p~cJuci~.g interval, or intervals,
top(s), bottom(s) and name (s) (if any) for only the intervof reported in item 30. Submit a separate report
(page) on this form, adequately identified, for each additional interval to be seperately produced, show-
ing the additional data pertinent to such interval.
Ite~m26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul-
tiple stage cementing and the location of the cementing tool.
Item 28: Submit a separate completion report on this form for each inlerval to be separately produced.
(See instruction for items 20 and 22 above).
AI{.Y OF FORMATION TF..STS IN('LUDIN(; INTERV^L TESTED, I:~RE.S~$URI~- DATA AND ~OVERI~S OF OIL GAS,
35. G~G IC MARK~
WAT~ AND MUD
"DATA. Aq'I'ACI[ BRIEF D.~CRI'RI~ONS :O'F 51TIIOLOGY, poROSITY. F[{Ac~R~. APP~NT .DIPS
AND I)~['EC~'EI} S}I(}WS OF OIL. GAS OR
COMPLETION REPORT - REPERFORATING
STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERTAIONS,
INC.
- OPERATOR
AREA:
PROPERTY:
Kenai Peninsula, Cook Inlet
Area, Alaska
Soldotna Creek Unit
LAND OFFICE: Anchorage
Lease No.: A-028966
WELL NO.: SCU 34-8 SECTION 8, T-7-N, R-9-W, SEWARD B&M
LOCATION: Surface: 1190' North and 1350' West from Southeast Corner of
Section 8.
ELEVATION: 164' K.B. K.B. is 15.25'
DATE:. November 18, 1970 BY:
ab o ve.~o~ n d~,-~./~. ,.. ~.~
C. V. CHATTERTON
District Superintendent
REPERFORATED BY:
DATE COMMENCED:
DATE COMPLETED:
Go-International
June 4, 1970
June 5, 1970
SUMMARY
TOTAL DEPTH: 11,175' PLUGS: 11,124'-11,170'
EFFECTIVE DEPTHS: Fill,
JUNK: Tubing cut off, top at 10,809'. 10,898'; Tubing
Fish, 10,809'
CASING: 22" cemented at 28'.
11-3/4" cemented at 2009' with 1440 sacks cement.
7" cemented at. 11,170' with 1800 sacks in two stages.
First Stage around shoe with 700 sacks, Second Stage
through DV at 7797' with 1100 sacks cement.
ORIGINAL PERFORATIONS:
5½" holes at 10,679' (Squeezed).
4%" holes/foot 10,682'-10,696' (Squeezed) .
10,721'-10,760'; 10,766'-10,786'; 10,792'-10,810'
REPERFORATIONS:
2 - 1/8" ceramic jet holes per foot: 10,810'-10,792';
10,786'-10,766'; and 10,760'-10,721'.
COMPLETION REPORT - REPERFORATING
S~LDOTNA CREEK !/AlIT 34-~
STANDARD OIL ~-.Q_~- CAL. . , W.O.I. - OPERATOR
Page 2
March 27, 1970
A wireline feeler run by C. A. White stopped at 10,939'.
June 4, 1970
Go-International ran a 1-3/4''~ collar tocator to 10,898' then cut tubing
6' below Brown packer (tubing cut at 10,715'). Tubing tail dropped in
hole. Theoretical top at 10,809' . '
June 5, 1970
Go-International, reperfo, rated through tubing 10,810'-10,792,; 10,786'-
10,766'; and 10,760'-10,721' with 2 - 1/8" ceramic JHPF.
NOTE: Reperforated entire zone - sands. 2, 3, and 5.
I ~ a
Cr~" ..... NOTE: ALL ..... TUBING IS/~..~ 6-5 "'80 EUE 8R RG 2
49 JOINTS
45 JOINTS
40 JOINTS
;3:3 'JOINTS --
29 JOINTS '
26 JOINTS
23' JOINTS --
90 JOINTS
-- I LANDING MANDRE... TO KB
.:=...--LANDING MANDREL 8~ NIPPLE
1578.
1521. CAMCO 2~'s' MM MANDREL
301 I.
3024. _~CAMCO 2~" MM MANDREL
4285.
4298. ..._~CAMCO 2~/~' MM MANDREL
5337. ._~CAMCO 2~" MM MANDREL
'53 50.
6263.6276. --L__i...~_cAMco 2~~ MM MANDREL
7092. _,~CAMCO 2~" MM MANDREL
7] 05.
7844.7831.& ._~-.C
AMCO 2~" MM MANDREL
16.20'
2.46'
13.
1420.
.13,
1261,
13,
1039.
13,.
9'1 3.
13.
819.
13.
723.
1:5.
2824.
670.60
-- 10,703.36-
CO SLEEVE VALVE
I JOINT 2~" EUE
ROWN CC SAFETY JOINT
PUP JOINT 2~" EUE TUBING
BROWN 2'~"x 7" HS-~I6-1 PACKER
TBG0.6 BELOW PACKER (~ 10,715'
2.60'
21.26'
I. 40'
I0. I0'
6.00'
10,800
B9' CUT OFF FISH CONSISTS OF
I CUT OFF JOINT 2~i"' TBG. 25,00'
I JOINT 2~' TUBING 31.00'
CAMCO 'D" NIPPLE .95'
I JOINT 2~a* TUBING
VENTURI m SHOE 2~s" . 67'
89. 00'
TOP OF FILL ~ 10,898'
MV lOC
TUBING DETAILS
S. C. U, 34-8
1190'N. 5 1350' W. Fr..SE COR. SEC. 8,T. 7N.,R.9W
STANDARD OIL COMPANY OF CALIFORNIA
W{$T[RN OPERAI'ION.~, tnt.,OP['RATOR
10-22-70
SUNDRY NO
,, . :..~ , , . -_,. . ,
~CE OF INT~iON TO RE-DRILL O~
. - . , .... . .. _: .
~TI~ OF INTENTION ~ ~T OR ACID~t~:~'~.~_:.-.]::-,( .~BSE~ ~ OF ABAN~N~T.---~..'
.: . ..
,, ,, . , , .- , ,,..
'L (INDICATE A~VE IY:CH~'M~K NACRE
-~: '"
Well ~;':~._~.0. ~ ]~tcd' l*'.:'-(k:' from ~ine. o.._ :h .. ~ and ..~0_ ft. from ~~:~.::'~']
(State or Territory) ,. '
........ (Fk~l) (OeOnty or Sui)division)
The elevation of the derr."i~ floor above'sea level is 3~1~! ..... ft.
DETAILS OF WORK
(State frames of and expected d~pths to ol;jl~tivm sandst~ show size.s, weights, and lenlths of p~oposed cllhllll|'lndlglt! in~ points~.and all other Important proposed work)
r~
~nt, on gas
I und~t~tand that this plan of work ~it r~c~lv~ a4~proval in wrltlnI by tho ~g~l~ltEurvey I~fore operations may i~I
STANDARD OTL COMPANY OF CALIFORNIA
WESTERN OPERATIONS, INC.
Anchorage, ~Alaska
Aprt.1 60
Mr, M. H. S~ter, Region~$~~visor
United~te/Geolo~~ Survey
~'~. D. D. Bruce, Chief - Petroleum Branch
State Department of Natural Resources
P. o. Box Z~8
Anchorage, Alaska
Gentlemen:
We enclose here~&th the followtnE information and well
data for your files and information:
APR 11 1962
Petroleum Branch
Dlvls}an of Mhes and Minerals
Alaska Dept. of Natural fce~ou~ces
Yours very truly,
STANDARD OIL COMPANY OF CALIF. ORNIA
Western Operations, Inc.
C. V ~TTERTON
- 'RECEIVE '
APR 11 1962
Petroleum Branch
Division of Mines and Minerals
Alaska Dept. of Natural Resource~
COMPLETION REPORT - NEW WELL
STANDARD OIL COMPANY OF CALIFORNIA - WESTERN OPERATIONS INC. - OPERATOR
AREA: Kenai Peninsula~ Cook Inlet Area, Alaska
PROPERfT: Soldotna Creek Unit
LAND OFFICE: Anchorage
Lease No.: A-028966
WF~ NO. SCU 3k-8 SECTION 8, T. ? N., R. 9 W., SEWARD B & M
LOCATION: Surface: 1190' North and 1350' West from Southeast Corner
Section 8.
ELEVATION: 164' K.B.
DATE: March 16, 1962
BY:
K. B. is 15.25' above ground.
,. ,/:>,?.- .. . .
: X_ ~ ~ :/.,' ... ' ~
C. V. CHATTERTON, District Superintendent
DRILLED BY: Reading & Bates Drilling Company, Rig ~6.
DATE C0~2~ENCED DRILLING: November 7, 1961.
DATE COMPLETED DRILLING: January 28, 1962.
DATE OF INITIAL PRODUCTION: February 1, 1962.
PRODUCTION: Daily Average 3~0 B/.D
Oil 317 B/,D
Water 3 B/D
Gas 59 MCF/D
Flowing
Gravity '37.4°
TP 500 psi
Bean 1R/64"
SUMMARY
TOTAL DEPTH: 11,175 '
PLUGS: 11, 124 - 11', 170'
JUNK: None
CASING:
22" cemented at 28'.
11 3/ cemented at 2009' with 1440 sacks cement
7" cemented at ll, 170' with 1800 sacks in two sta~es.
First Stage around shoe with 700 sacks, Second Ste~ge
through DV at 7797' with 1100 sacks cement.
Page 2.
PERFORATIONS:
I t!
5 ~., holes at 10,679' (Squeezed.)
4~ holes/foot 10,682 - 10,696' (Squeezed.)
10,721 - 10,760'
10,766 - 10,786'
10,792 - lO,810'
WELL SURVEYS:
1. Schlumberger Induction-Electrical Log 150 - 11,168'.
2. Schlumberger Sonic Log 150 - 1980'.
3. Schlumberger Continuous Dipmeter 2009 - 10,988'.
4. Schlumberger Micro-log Caliper 10,140 - ll, 140 '.
5. Schlumberger Neutron-Collar Log 9800 - ll, ll9',
7600 - 8,000'.
6. Schlumberger Cement Bond Log 2000 - ll, 120'.
DRILL STEM TESTS:
HCT ~1 on 5 holes at 10,679', W.S.O. (Squeezed.)
HCT ~2 on perfs, at 10,805 - 10,810'.
HCT ~3 on perfs, at 10,696 - 10,682' & 10,679' (Squeezed.)
HCT ~4 on perfs, at 10,696 - 10,682' & 10,679', W.N.S.O. (Squeezed)
HCT ~5 on perfs, at 10,696 - 10,682' & 10,679', W.S.O.
COMPLETION REPORT
SOLDOTNA CREEK UNIT 34-8
SECTION .8.., T. 7 N.., R.. 9 W:..~. SEWARD B & M
STANDARD OIL 00MPAEY OF CALIFORNIA, W.O.I. - OPERATOR
Page 3-
November 7,_ 1~6!
Spudded 'at 4:00 A.M., November 7, 1961
Drilled 16" hole
0 - 856'
November 8, 1961
Drilled 16" hole
856 - 2, 0~0'
November 9, 1961
Drilled 16" hole
856' drilled
174' drilled
85 pcf mud
80 - 84 p cf mud
199o. 4o '
Landing head to G.L. 3- 25 '
G.L. to K.B. 15 -25 '
Cemented at 2008.90 '
2,030 - 2,035' 5' drilled
Circulated. Ran Schlumberger Induction-Electrical Log interval 150 - 1992'
and Sonic Log interval 150 - 1980'.
Reamed 16" hole
0 - 1,762' 1,762' reamed 85 pcf mud
November.. 10, !96!
Reamed 16" hole
1,762 - 2,035' 273' reamed 82 pcf mud
Circulated. Ran 48 joints 11 3/4" casing. Cemented 11 3/4" casing at 2009'
in a single stage with 1440 sacks of cement using Halliburton power equipment.
Used one top rubber plug.
Pumped 40 bbls. of water ahead, mixed 1440 sacks of cement in 58 mins. using
Halliburton truck~ displaced in 15 mins. using rig pumps. Average slurry
weight ll6~. Bumped plug with ll50 psi. Full circulation.
Hookload weight of casing before cementing 88,000~ and after cementing before
landing casing 50,000~.
CASING DETAIL: 48 Joints or 2027.40' ll 3/4", 47~, 8 Rd., J-55, equipped
Landing Joint 37-_--~ with shoe and float collar
COMPLETION REPORT
SOLDOTNA CREEK UNIT 34-8
SECTION.8, T- T N..~. R. 9.W., SEWARD B & M
STANDARD OIL COMPANY OF CALIFORNIA, W.O.I. - OPERATOR
Page 4.
November. ll~ 1,96...1.
Installed BOPE. Tested BOPE with 1800 psi - OK. Ban 10 5/8" bit. Located
top of cement at 1959'. Drilled out cement and shoe.
Drilled l0 5/8" hole
2,035 - 2~239' 204' drilled
Twisted off. Left 237.42' of fish in hole. Ran in with overshot and engaged
fish. Pulled.
November 12, 1961
Recovered fish.
Drilled l0 5/8" hole
2,239 - 3, 527' 1,288' drilled
Drilled 9 7/8" hole
3,527 - 3,725' 198' drilled
November 13 - 29, 1961
Drilled 9 7/8" hole
3,725 - 8,151' 4, 42'6' drilled 64 - 95 pcf mud
Gas and water entry at 8130 - 8146'. Approximately 160 bbls. water entered.
November 30 - December .2, 1.96..1.
Drilled 9 7/8" hole
8,151 - 8,485' 334' drilled
December 3~. 1961
Circulated. Ran Schlumberger Induction-Electrical Log interval 2009 - 8485'.
Drilled 9 7/8" hole
8,485 - 8,571'
December 4 - 18, 1961
Drilled 9 7/8" hole
8,571 - 10,200'
65 - 67.5 pcf mud
86' drilled
1,629' drilled
98 - 100 p cf mud
94 - 101 pcf mud
90 - 100 pcf mud
C0~PLETION REPO~
SOLDOTNA CREEK UNIT 34-8
S. EC I.ON .8,. iT.. U., SEUA
STANDARD OIL COMPANY OF CAI~FORNIA, W.O.I.. - OPERATOR
Page 5.
December 19~ 19.61
Drilled 9 7/8" hole
10,200 - 10~318'
Gas and water entry at 10,278' ·
December 20, 1961
Circulated and conditioned mud.
Drilled 9 7/8" hole
10,318 - 10,~08'
· December 21 - 2~, 1961
Drilled 9 7/8" hole
10~408 - 11,000'
December 25, 1961
118' drilled 99 - 94.5 pcf mud
Mud weight cut from 98.5~ to 94.5~
96 - lO1 pcf mud
97.5 - lO1 pcf mud
Attempted
Circulated and conditioned mud. Ran Schlumberger Induction Electrical Log
interval 8485 - 10,994' and Continuous Dipmeter interval 2009 - 10,988'.
December 26,. 1961
Finished logging.
Drilled 9 7/8" hole
ll, 000 - ll, ll3' ll3' drilled
December 27, 196.1.
Drilled 9 7/8" hole
ll, ll3 - ll, 175' 62' drilled
Circulated and conditioned mud to log.
December 28.~.. 19.61.
Ran Schlumberger Induction Electrical Log interval 10,993 - ll, 168'.
to run So~ic Log. Tool stopped at 2022'. Conditioned hole.
90' drilled
102 - 103 pcf mud
592' drilled
lO1 - 102 pcf mud
COMPLETION REPORT
SOLDOTNA CREEK UNIT 34-8
SECTION 8, T. 7 N., ~. 9. W.~. SEWARD B & M
STANDARD OIL COMPANY OF CALIFORNIA, W.O.I. - OPERATOR
Page 6.
.D.e. cember 29, 1961
Ran Schlumberger Micro Log interval lO, 140 - ll, 140'. Circulated.
Ran 7" casing.
.D~ecember 30,_ 1961
Cemented 7" casing at ll, 170' in two stages with 1800 sacks of cement treated
with O. 3% HR-4 using Halliburton power equipment. Used one top rubber plug.
First Stage around shoe with 700 sacks of cement. Pumped 50 bbls. of water
ahead, mixed 700 sacks of cement in 21 mins. using Halliburton truck, displaced
in 39 mins. using rig pumps. Average slurry weight ll6~. Bumped plug with
2000 psi. Full circulation.
Second Stage through DV at 7797'- Dropped DV bomb, opened DV ports in 40 mins.
Pumped 50 bbls. of water ahead, mixed llO0 sacks of cement in 37 mins. using
Halliburton truck, displaced in 26 mins. using rig pumps. Average slurry
weight ll6~. Closed DV ports with 2000 psi. Full circulation. Cement in
place at 6:26 P.M.
CASING DETAIL:
ll3
Below K. B.
Top 3 joints 7" 29~ BT N80; 130.31
Cut & Recovered 26.3.~8
7", 29~ BT N 80 in hole
Joints 7" 23~ BT N 80
C ro s sover
~7 Joints 7" 26~ BT N 80
22 joints 7" 29~ BT N 80
DV collar
21 joints 7" 29~ BT N 80
39 joints 7" 29~ P llO 8 Rd.
Marker joint P llO
19 joints 7" 29~ P llO 8 Rd.
i joint 7" 29~ P llO 8 Rd. w/Baffle
Plate
Float Collar
Shoe
1 joint 7" 29~ P 110
K. B. Depth
17.25 17.25 '
lO 3.93' 121.18~
4,822.23' 4,943.41'
6.75' 4,950.16°
1,931.32' 6,881.~8,
915-39' 7,796-87
2.50' 7,799.37'
879-29' 8,678.66'
1,596.84' lO,275.5o'
1~.26' 10,289.76'
791.83' 11,081.59'
~2.27' 11,123.86'
1.28' 11, 125.
1.45. 11,126.591
43.52, 11,170.11
Casing Landed at
11, 170.11'
Hookload weight of casing before cementing 200,00C~ and after cementing before
landing casing 190,000~.
December 3!, 1961
Changed to 2 7/8" pipe rams.
2 7/8" drill pipe.
Tested packoff with 3000~ psi - OK.
Picked up
COMPLETION REPORT
SOLDOTNA CREEK UNIT 34-8
SECTION .8,...T. 7 N.~ R' 9 w.~ .SEWARD B & M
S~A~OA~O OIL COMPA~ OF CA~Om~A, W.0.m. - O?~ATOH
Page 7.
Janua .ry 1,. 1962
Ran 6" bit. Drilled out DV collar at 7798'- Tested with 2000 psi - OK. Lo-
cated top of plug at 11,083'.
100 p cf mud
January ~., 1962 ~
Drilled out plug and Baffle plate. Drilled cement to top of fill up collar
at 11,124'. Circulated and conditioned mud. Cut mud weight from 100~ to 85~.
Ja~ua.ry. 3~ 1962
Ran Cement Bond Log il, 120 - 2000' and Neutron Collar Log 11, 119 - 9800' and
8000 - 7600'. Shot 5 ~ holes at 10,679' for HCT ~1. (WSO - Test) Ran
casing scraper to 11,125'.
i !!
HCT ~1; on 5 ~ holes at 10,679'
Tool Assembly: 2 outside BT recorders, 3' of perf'd, tail pipe, 7" Type "C"
hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders,
hydrospring tester, and dual closed in pressure valves.
Ran on 10,601' of 2 7/8" drill pipe' Used 2640' of water cushion. Set packer
at 10,630', with 16' of tail to 10,646'. Opened tester at 10:08 P.M. for
3 mins. pressure release.
Shut in tester at lO:ll P.M. for 30 mins. ISI pressure period. Opened tool
to surface at lO:41 P.M. for 60 min. flow test. Shut in tool at ll:41 P.M.
for 30 min. FSI pressure. Pulled packer loose at IR:ll A.M.~ 1-4-62. Re-
covered 30' net rise, all drilling fluid. Faint blow of air for 15 min. then
dead for 30 mins. Very weak blow started after 35 mins., continued until FSI.
Final Pressure Data:
Depth Gauge IH
Top inside 10,616' 6223
Bottom inside 10,620' 6146
Top outside 10,640' 6217
Bottom outside 10,644' 6217
ISI IF FF FSI FH
1241/
~69 2778 6223
1194/ 1194~-' 2861 6146
3165 .,-~1212 / ~35
3194 1~9 l~~3 2881 62=
Conclusion: W.S.O.
COMPLETION REPOR~
SOLDOTNA c~EEH UNXT 34-8
SECTION 8.,. T. 7 N:,,.~ R. 9 W_._~, SEWARD B & M
STANDARD 0IL CON~PANY OF CALIFORNIA, W.0.I. - 0FERATOR
Page 8.
January .4, 1962
Finished HCT ~1. Pulled test tools. Jet perforated 4 ½" holes/foot 10,805 -
lO, 810' using alternate crack jets and no plug jets for HCT ~2.
' ~" holes/foot).
HCT ~2 on perf'd, interval 10,805 - 10,810 (4 ~
Tool assembly: 2 outside BT recorders, 3' of 2 7/8" perf'd, tail pipe, 7"
Type "C" Hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders,
hydrospring tester, and dual closed in valve.
Ran on 10,718' of 2 7/8" drill pipe. Used 2820' of water cushion. Set packer
at 10,750', with 16' of tail to 10,766'. Opened tester at l:lO P.M. for 2 min.
pressure release.
Shut in tester at 1:15 P.M. for 31 min. ISI pressure period. Opened tool to
surface at 1:43 P.M. for 7 hr. 7 min. flow test. Immediate strong blow,
cushion to surface at 2:23 P.M. (40 min.). Mud to surface at 2:52 P.M. (69
min). Oil to surface at 2:58 P.M. (75 min.) Shut in at 3:04 P.M. to move
lines and install trap. Surface pressure 400 - 450~. 3/8" surface bean.
Representative cut: Total 1.O~, (0.7~ water, 0.3 Emulsion. and S & M. ).
Gravity 36.5°API. Shut in tool at 9:00 P.M. for 74 min. FSI pressure and
backscuttled. Pulled packer loose at lO:14 P.M.
Pressure Data:
Depth Gauge IH ISI IF FF FSI
Top inside 10,736 6312 5156 1419/ 1781_~-'° 5083
~/1872 ~- 4409
Bottom Inside 10,740 6230 5077 * ~ * ~" 5009
Top Outside 10,761 6283 5144 167~/ 189~5~./ 5060
~ 1962 -~ .... 4385
Bottom Outside 10,765 6298 5150 1497j..~ 1881~.~ 5069
-'"' 1957 -"~ 4394
January 5, 1962
6301
6224
6283
6295
~" holes/foot the following intervals using
Pulled test tools.. Perforated 4 ~
alternate no-plug and crack jets: 10,805 - 10,792', 10,786 - 10,766', 10,760
10,721', and 10,696 - 10,682'. Circulated and conditioned mud.
85 pcf mud
January 6, !962
Laid down 2 7/8" drill pipe. Started running 2 7/8" tubing.
COMPLETION REPORT
SOLDOTNA CREEK UNIT 34-8
SECTION 8~. T~...7...N:..., R-L .9. W., SEWARD B & M
smAm~mo oil CO~mA~ OF CA,FOX,A, W.O.Z. - oP~A~OR
Page
January 7, 1962
Ran 2 7/8" tubing equipped with Venturi shoe, Camco D nipple, Brown CC safety
joint, Camco sleave valve and 7 Camco MM mandrels at 7821', 7086', 6253',
5328', 4277', 3004' and 1572'. Tubing hung at 10,790'. Removed BOPE.
Installed X-Mas tree. Tested with 5300 psi. OK. Displaced mud with oil.
Started flowing well.
January .8 .- 9, 1962
Flow tested well.
January 10, !962
Flow tested well. Representative rate 920 B/D oil.
18~water. Corr. gravity 36.4°API. Shut in well.
and conditioned mud to kill well.
32/64" bean. Total cut
Opened Camco sleave valve
January 11, 1962
Displaced oil with mud (85~ pcf). Removed X-Mas tree, re-installed BOPE.
January 12, 1962
Tested BOPE with 1500 psi. OK. Pulled tubing. Picked up 2 7/8" drill pipe.
Janua.ry 13, 1962
Finished pulling 2 7/8" tubing.
10,706' for HCT ~3.
Ran in and set Baker Model "K" bridge plug at
HCT ~3 of the interval 10,682 - 10,696' and holes 10,679'. Tool assembly: 2
outside BT recorders, 3' of perf'd, tail pipe, Type "C" Hookwall packer, VR
safety joint, hydraulic jars, 2 inside BT recorders, hydrospring tester, and
dual closed in valve.
R~n on 10,610' of 2 7/8" drill pipe. Used 2821' of water cushion. Set packer
at 10,638', with 16' of tail to 10,654'. Opened tester at 4:18 A.M. for 3 min.
pressure release.
Shut in tester at 4:21 A.M. for 30 min. ISI pressure period. Opened tool to
surface at 4:52 A.M. for 12 hrs. 31 min. flow test. Shut in tool at 5:23 P.M.
for 56 min. FSI pressure. Pulled packer loose at 6:19 P.M.
Well flowed clean water at a rate of 130 B/D. Cushion to surface at 7:20 P.M.
Started with clear water, becoming oily to a maximum of 15% oil. Then decreas-
ing to 100~ water.
COMPLETION REPORT
SOLDOTNA CREEK UNIT 34-8
SECTION 8, T. 7 N.,. R. 9 W.., SEWARD B & M
STANDARD OIL COMPANY OF CALIFORNIA, W.O.I. - 0PERATOR
January 14, 1962 Continue_d
Salinities:
at l0: 30 A.M. (Off Chart
12:00 A.M. 240 G/G
1:00 P.M. 390 G/_G
2:00 P.M. 350 a/a
at 3:0O P.M. 220 a/ G
3:30 P.M. 260 G/~G
4:00 P.M. 300 G/,G
5:00 P.M. 330 G/G
Final Pressure Data:
Depth Gauge IH ISI IF FF FSI FH
Top Inside 10,624" 6069 5224 13.~1~1488 1459/~4666 4958 6069
Bottom Inside 10,628' 6046 5208 1~~1464 1462/'
-"'~634 49~ 6046
Top Outside 10~650' 6054 5211 ./~516 / 4642
Bottom ~tside lO~ 654 ~ 6056 5201 833~' 1452/' 4941 6056
/~1500 /~646
Charts indicate tool functioned OK - Test conclusive.
Backscuttled. Pulled packer loose· Pulled and circulated.
January 15, 1962
Made up squeeze tools· Set packer at 10,548'. Broke down formation with
2900 psi. Took fluid at a rate of 3 bbls./min. Mixed and pumped in 175 sacks
cement preceeded with 20 bbls. water. Displaced with 2 bbls. water and 48 bbls.
drilling fluid. Final pressure 3500 psi. 75 lin. feet left in 7" casing.
Cement in place at 12:08 P.M. Pulled. Ran 7" casing scraper to retainer plug
at 10,548'. Circulated.
J~nuary 16,.. 1962
Stood cemented till 1:30 A.M. Drilled out retainer. Drilled cement from
10,593 - 10,700'. Pressure tested casing with 2500 psi. OK. Circulated
hole clean·
Januar 17, ,196, ,
Made up test tools and ran in hole with 2821' water cushion. Did not locate
bridge plug at 10,706' · Ran to ll, 123' · Pulled. Ran Junk basket to 10,721' ·
Ran in with Model "K" bridge plug. Hung up at lO~ 596'. Attempted to pull
bridge plug. Hung up at 7178'. Set plug.
January ,18 ~ ,,1962
Ran 6" bit. Drilled out bridge plug at 7178'.
Ran junk basket to 10,730' ·
Cleaned out to ll, l~2'
· Pulled.
COMPLETION REPORT
SOLDOTNA CREEK UNIT 34-8
SECTION 8, T. 7 N., R. 9 W., SEWARD B & M
STANDARD 0IL COMPANY OF CALIFORNIA, W.0.I. - OPERATOR
Page 11.
January .19., 1962
Ran Bridge Plug on wireline. Set bridge plug at 10,706'.
HCT ~, of perf's. 10,682 - 10,696' and 10,679', all perf's, squeezed with
cement. Tool assembly: 2 outside BT recorders, 3' of 2 7/8" perf'd, tail
pipe, 7" Type "C" Hookwall packer, VR safety joint, hydraulic jars, 2 inside
BT recorders, hydrospring tester, and dual closed-in pressure valve.
Ran on 10,612' of 2 7/8" drill pipe. Used 2821' of water cushion. Set packer
at 10,6~0', with 16' of tail to 10,656'. Opened tester at 7:30 A.M. for 3 min.
pressure release. Immediate faint blow. Shut in tester at 7:33 A.M. for 33
min. ISI pressure period. Opened tool to surface at 8:06 A.M. for 8 hrs. 6 min.
flow test. Shut in tool at 4:12 P.M. for 66 min. FSI pressure. Pulled packer
loose at 5:18 P.M. Medium blow 8: 06 A.M. to l0: 50 A.M.
10:50A. M.: Water cushion to surface.
2:15.~P.M,: Drilling fluid to surface.
3:15 P,M.: Flowing muddy water.
3:30 P.M': Flowing water, 1.34 ohms at 50°~ F..350 G/.G. No oil.
3:45 P.M.: (Flowing water, l.22 ohms at 46u F. 400 G/G. No oil.
at about 100 B/D rate)
4:12 P.M.: Shut in
4:16 P.M.: Started backscuttling
4:45 P.M.: Sample: 120 ohms at 55° F. 360 G/G. No oil.
5:00 P.M.: Flow stopped. Fluid equalized.
Final Pressure Data:
Depth Gauge IH ISI IF FF FSI FH
Top Inside 10,626' 5945 5235 1274 4650 5042 5936
Bottom Inside 10,630' 5937 5231 1273 4639 5030 5937
Top Outside 10,650' 5959 5247 1379 9 5041 5959
1098/ 1~~6~
Bottom Outside 10~654' 5957 5244 ,/1374 4 5041 5957
Conclusion: W.N.S .0.
Pulled. Made up squeeze tools.
January 20, 1962
Set packer at 10,531'. Broke down formation with 3600 psi, took fluid at a
rate of 15 cu. ft./min. Mixed and pumped in 200 sacks of cement treated with
· 3~ HR4 preceded with 36 cu. ft. water and followed with lO cu. ft. water and
256 cu. ft. drilling fluid. Final pressure 4000 psi. In place 3:30 A.M. 75
lin. feet left in 7" casing. Pressure tested annulus with 1000 psi. Waited 5
mins. built pressure up to 5000 psi. Stood cemented.
79 pcf mud
COMPLETION REPORT
SOLDOTNA CRF~ UNIT 34-8
SECTION 8, T. 7 N.,~ R. 9. ~..~ SEWARD B & M
STANDARD OIL COMPANY OF CALIFORNIA, W.0.I. - OPERATOR
Page 12.
January 21, 1962
Drilled out cement retainer. Drilled cement from 10,546 - 10,698'. Circula-
ted. Pulled. Ran testing tools for HCT ~5-
79 - 81 pcf mud
January 22,,,, 1962
HCT ~5 of perf' s. 10,682 10,696' and 10,679' all perf'
- , s. squeezed with cement.
Tool assembly: 2 outside BT recorders, 3' of 2 7/8" perf'd, tail pipe, 7" Type
"C" Hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders,
hydrospring tester, and dual closed-in pressure valve.
Ran on 10,612' of 2 7/8" drill pipe. Used 2821' of water cushion. Set packer
at 10,640', with 16' of tail to 10,656'. Opened tester at 19:07 A.M. for
5 min. pressure release. Very faint puff blow, then dead.
Shut in tester at 12:]2 A.M. for 30 min. ISI pressure period. Opened tool to
surface at 12:42 A.M. for i hr. 15 min. flow test. Shut in tool at 1:57 A.M.
for 30 min. FSI pressure. Pulled packer loose at 2:27 A.M.
12:42 A.M. Opened tester, no blow.
1:43 A.M. Opened bypass valve to clear possible plugged perfs.
1:47 A.M. Closed bypass valve and reopened tester. No blow.
1:57 A.M. Shut-in tool.
Pulled and recovered 30' of normal drilling fluid.
Pressure Data
Depth Gauge IH ISI IF FF FSI FH
Top Inside 10,626~ 5928 1636 195~~1252 125~~12i2 1525 5897
Bottom Inside 10,630~ 5919 1621 l~ 1~2~' 1~1124 1527 5889
5 5
At_~~ 1967~f' 1549 5827
Top Outside 10~650~ 5921 1632 1 7 /1272
1265j~-19~~127o 154o 5896
Bottom Outside 10,654 ~ 5934 1626 ~'~1265
Conclusion: W.S.O.
Located bridge plug at 10,704'. Drilled out bridge plug. Ran to ll, lRO'.
Ran casing scraper, cleaned out from 10~540 - 10,715'. Ran to bottom. Circu-
lated and conditionedmud.
79 - 80 pcf mud
COMPLETION REPORT
SOLDOTNA CREEK UNIT 34-8
SECTION 8,..T.' 7...N., R. 9 W., .SEWARD B & M
STANDARD OIL COMPANY OF CALIFORNIA, W.O.I'. - OPERATOR
Page 13.
January 23, 1962
Laid down 2 7/8" drill pipe.
bridges at 7799' 8332' 8339'
January.. 24, 1962
Schlumberger ran junk basket on wireline. Kit
, 8345' and 8347'
80 p cf mud
Pulled junk basket.
bridges at 8386'.
January
Picked up 2 7/8" drill pipe.
Circulated. Ran to ll, ll7 ' ·
Ran in and cleaned out
Circulated.
81 pcf mud
Pulled and laid down 2 7/8" drill pipe. Ran 2 7/8" tubing as follows:
K.B. to landing head
Landing flange & Nipple
27 6.5~ N-80 EUE 8 R
49 joints /8"
Camco MM G/LMandrel
27 6.5~ N-80 EUE 8 R
45 joints /8"
Camco MM G/LMandrel
40 JointsG/f/8"
2 6.5~ N-80 EUE 8 R
Camco MM · Mandrel
33 joints 8"
Camco MMG/LMandrel
29 joints /8"
Camco MMG/LMandrel
26 joints 2 7/8" 6.5~ N-80 EUE 8 R
Camco MM G/L Mandrel
23 joints 2 7/8" 6.5~ N-80 EUE 8 R
Camco ~4 G/L Mandrel
90 joints 2 7/8" 6.5~ N-80 EUE 8 R
Camco Sleeve Valve
K.B. Depth
16.20'
2.46'
1,559.34'
13- O0 ' l, 591'
1, 420. '
13. ' 3,024 '
1,261. '
13. ' 4,298'
1, 039- '
13. ' 5,350'
913. '
13. ' 6,276'
819. '
13. ' 7,108 '
723. '
13. ' 7,844'
2,824. ' 10,668'
2.60 ' 10,670.60 '
Brown CC safety joint
Pup Joint
Brown HS-16-1 packer
2 joints 2 7/8" 6.5~ N-80 EUE 8 R
Camco "D" Nipple
1 joint 2 7/8" 6.5~ N-80 EUE 8 R
Venturi Shoe
22.30 ' 10,692.90 '
10.10 ' 10,703 '
6. ' 10,709 '
62.05 ' 10,771.05 '
· 95 ' 10,772 '
31.33' 10,803.33'
· 67' lO, 804 '
Landed tubing at 10,804'. Set packer at 10,703' ·
COMPLETION REPORT
SOLDOTNA cREEK UNIT 34-8
s~,cTi,,0~ .8,.. T. ,7 ~.. ,.. R. ~ ,..W.~ SEWARD ~ ~ ~
STANDARD OIL COMPANY OF CALIFORNIA~ W.O.I. - OPERAT6'R
Page 14.
,Ja. nuary ..2...6, 1962
Removed BOPE. Installed Xmas tree and tested with 5100~ psi for 15 mins. Held
OK, Commenced displacing mud with oil at 1R:O0 NOON 1-26-62. Pumped 50 bbls.
of water ahead~ followed by 570 bbls. of crude oil. Stopped circulating at
8:00 P.M. Formation oil to surface at 4:00 A.M. 1-27-62. Flowed oil to sump
until 9:00 P.M. 1-26-62. Started flowing to trap at 9:00 A.M. 1-27-62. Repre-
sentative flow rate and cuts as follows:
Flow Rates
Flow Period ~iI Gas Bean Size Tbg. Press .Csg,. Press. Trap ,Press.
Hrs. 480 B/D 82 MCF/D 20/64
Total Cut ~ W~ter ..~ Emulsion ~ Sand & Mud Corr. Gravity
1. 1.O 0.5 0.5 0.0 36.4
2. 0.8 0.0 0.8 0.0 36.5
Shut well in at 7:00 A4M. 1-28-62. Shut in pressures; Tbg. press, lP80~psi,
Csg. press. 1080~psi. Produced estimated 800 bbls. formation oil. Flowed
800 bbls. to tank and estimated 250 bbls. to sump. Installed Cosasco plug.
~g released 4:15 P.M. 1-28-62.
S. R. NANSEN
COMPLETION REPORT
SOLDOTNA CRE~ UNIT 34-8
SECTION 8, T. 7 N., R. 9
~~B&M
STANDARD 0IL COMPANY OF CALIFORNIA, W. 0. I.
- OPERATOR
Page
i5.
Depth
160'
1, 107 '
2,030'
3, 527'
4,013'
4, 360 '
4,659'
4,940 '
5,187'
5,495 '
5,670'
5,870'
6,025 '
6,145'
6,261'
6, 5o7'
6,650'
7,125'
7,232'
7,318'
7,570'
7,745'
7,945'
8,021'
8,180'
8,268'
8,344 '
8,485'
8,571'
8,655'
8,783'
8,904 '
9,026 '
9, 110 '
9,238'
9,385'
9,456'
9,512'
9,770'
9,954'
10,054'
1% 104'
10,127'
10,200 '
DEVIATION
DATA
Degree~
3o'
3o'
oo'
00'
30'
30'
00'
3o'
15'
45'
30'
45'
00'
45'
45'
15'
15'
00'
00'
o8'
15'
30'
00'
00'
00'
45'
30'
30'
00'
45'
45'
~5'
45'
45'
00'
00'
45'
15'
08'
3o'
UNITED STATES
DEPARTMENT OF THE` INTERIOR
GEOLOGICAL SURVEY
Petroleum Bra~ch
~,~,on o,~,o~~~~~ ' MO~r~¥ ~~O~r oF o~gA'no~s
Dept.
· ,
Budi~et Bure~t ~N'o. 4~-1h31~I$.$.
ApD~oy~t. e~pir~s 1~-31-'~.
Tk~e followin~ is a eorrec~ repo'r~ of operations a~d prod~ctio?~ (i.~el'~,~iu~ drilli'n~ a~d
wells)for the mort, th of ........~..a~¢.~ ................ ,3~__~.~_, Soldotna Creek Unit ..........................
.~ ~ ~~ .... ~. _o.._~...~ ................................. -L'-~'~ ....... -~'t-~~ o~~-or~~o~
................................. ,~ o ~ ~ , ,. .. _n,~ , ............................. .~ ~ ~ ~ ~ ~ ........ ~ :~ _ ~~~~- -
' C. rD Chatterton
~o~ .................... ~d~__~~ ......................................~'~ ~~-st; '~-e~n ~n~ ent ................
S~c. ~>{u ~r. R~Noa (~ thou~u~)
. 8. ~I 3~ t
' SE ~! " ' ~
SW ~I I D~ille~ out D1 V~ ~d :ested wi%~ 2000 ps~. O.K. Drilled ou% ce~ut
, 1~,~83~- ~,!24'~ Cut mud weighi from 1~~ to 85~. ~n C3L 2000
{ ~,~ and NCL ~- SO00' ~ 98~ - ~,llg'~ '~er~o~ted
hples it 10,679'4 Ran} HCT ~1 on holes ~ ~O,6~9'; WSO_Q, Kt
~.~co~%t~" hte~<z% ~O~O~ - ~O,~0' ~ ~ - ~" ho~'
~Z. ~%~ed o~ ! Tota~ cut ~O~ (O~7~ W,{ O~3~ E,~Co~. g~v~t
H~T ~2$ 31 ~no ~I, ~ hours, 1] ~ute~. Flow te~, 74 minutes.
ess es: IH 6~OO nsl, ISI 511() psi, ~ 1~20 psi, ~ 4365 psm,
r~rfor$ted 4 ~" Holes ~er fo:~ 1~,805' -i0,7~2',110,786' - 10e766'
1~.760) - 10,722~, 10,~96 - 10,6~2,. R~ 2 ?/8 t$bing eq~oped
"~ 1~,790 · ~move~ BO~d. installed x-~ tree. ,Plowed well.
~- Total cut 18%
~pres,~ntative r~te: 9~0 B/D oil~ 32/~" ~ean.
' ~th ~ld ~d ~l~ed we~l. Reinstalled ~.
~ed t~n~. ~et bridge plug ~t 10,7~'. ~ ~CT ~3 of the
' . ihte~tl 10,682 ~ 10,6~6' ~d ~()holes ~ 10,679!. Used 2821'
o~ wat)r cushionq Se%~ uacker at{10,638'.~' 30 ~ne. ISI pressure,
1~ ~$, 31 ~ns. i~ best- We~ n~ed ~lean wa?er at 130
rhte,' ~eeo~z o~ly ars a m~~]of 15% ~1, t~n~decreasing t0
-- . .~[~.- Beg lcemen~ regainer Ia% lO,~O'o Squte,ed holes at
': 1,.-'-::~~~O,696' i~d a~ 10,779' ~th 175 sacks ce,ont. Drilled
~ . ~ "~~t. tested oer~'s, with ~5~ psi. O.K.
'")~ , ~ H~ u~ at 7178'~ Set; ~1~. Dr lled out plug ut~7178. Ran
'-~-- ', t ~x~ .~ ~o,7~6,~ ' ' i
,~ , I I ~t~,. . , · ,
'.:~"I - -~ I '
N'o?E.--There were ....................................... runs or sales of oil; ............................................... M DU. ft. of ga~ sold;
· runs or sal~ of gasoline during the month. (Write "no" where app{icable.)
No~m.--Rep'0rt on this form is required for each calendar month, regardle~ of the 8gains of operations, ~nd must be filed in
duplicate with the supervisor by the 6th of the succeeding mouth, uuless, ot. honvkso dirc~ed bv tho supervisor.
(Jsnumr¥ 1960)
Page 2. ?"~'~ 3~-8
Ran HCT #4 on squeezed perf's, at 10,679'. and 10,682 - 10,696'. Set
packer et 10,640'. Used 2821' of water cushion. ~ater not shut off.
Set cement retainer at 10,531'. Broke down fomms~tion with 3~-~ osi a~
14 cu. ft./min, rate° Squeezed with 200 sacks of cement. Final
pressure 4000 osi. Left 75 lin. ft. inside 7" casing. Ran 7" casing
scraper. Ran NCT %/5 on squeezed perf's. ~,~ater shut off. Ran 6" bit
and 7" casing scraoer to 11,120'. Circulated. ~.~ade rerun with bit
to clean out bridges. Ran 2 7/8" tubing. Landed tubing at 10,804'. '
Set packer 10,703 ' ·
Removed BOPE, installed x-mas tree. Tested x-mas tree with ~100 osi
- 0.~. Displaced mud with oil. Flow tested well. ~eoresentstive flow rates
Flow oeriod: 6 hrs., 480 B/D oil,' 82 ~ICF~D ~as, 20/$4" bean, T.P.
200~ Psi~ C. P. 25# psi, traR pressure 65# psi. Total cut 0.8% (.8%
emulsion) Corr. gravity 36.5~. Set Brown MS-16-1 p~c~er at 10,703'.
~8 ..released January 28, 19_62.
UNITED STATES
DEPARTMENT OF THE INTERIOR
GEOLOGICAL SURVEY
LESSEE'S MONTHLY REPORT OF OPERATIONS
Sta:~e ............ A!a~k_a_ .......... Cou-~tyK~aai_P__en_ias_u_!_a ...... Field ._ Swanson R~v~r
Th, e /btlowin~ is a correct report of operations a;~d productiot~ ('i~eh/./,lin. o~ drilli'~6~ and prod~cin~
wells)for tI~e mo~th of ................ ~q~.O~ ........ [9 ~, So!darns Creek llni~
phone .............................. B~~~..7~201 .... ~ .................... ~en.t's title .... Bi~Srict_.~np~rin~4:
8E}' '::, Srh~n.ed~ 7/8" ho~.e 8,268 - 8,h8~ o ~n ~-m log 2,0o9 '-
SW~.' h' Dr[lled~9 7/8" hole 8,485 - ll,~O'o Ran~I-ES 10,994- 8,485' and
CDh 10,994- 2,OO~'. Drilled 9 7}'8" hole 11,0OO - 11,175' ToDo
F~s% s%age ~~d sh~! w/700 saolts and s~eond s%age %hrouKh D.Vo
at 7,~' with 1[?0 ,,~8 oe~nto Prep. d r~ll ou5
I
t
1
U,S.G
A Lask
F~chf:
F~les
So H. . $o'j/'st®r (2) J ___
eld - Co! Wo _, ~rz~v~, R. R4 Ritt~r
,
NoTv..~Thero were ........................... 2_ ......... runs or sales of oil; ................................................ M cu. ft. of gas sold;
............................................... runs or sales of gasoline during the month. (Write "no" where applicable.)
Now~.~Rcport on this form is required for each calendar month, regardless of the status of operations, and must be filed in
duplicate with the supervisor by the' 6th of the succeeding month, unless otherwise directed by the supervisor.
Forn~ 9-329
UNITED STATES
DEPARTMENT OF THE INTERIOR
GEOLOG~AL SURVEY umT ............ Soldo~na..C=eek
LESSEE'S MONTHLY REPORT OF OPERATIONS
State .... ~_g~.~_sk_.~ .................... Celerity ~._~.!__ _P~__B~_~u.!.~ ....... Fiegd ....... Sw~eon ~!Y.~:~
The followin~ ~s a correct report of oper~io/;.~ and productior~ (i~cludi/~,j drillinff and prod~cin~
welts) for the mo~,t.h of .... No~_e~er .................... 19~! ............. ~p}~p}oa Creek Uni~
Jffent~saddress ........... P..O...Box 7~8~9 ~ Standard Oil ~ of California
..................................... ~'om/,an2~~nO . ...........
}.}_ . .'. Anchorage, ~aska '~
8EC.~ opAND~J WP ~ANGE 'No. P~o.oc~ I . ~ (In,he'ands)
I
~a~ I-~ a So~o L~s~
~ ,0o9,~ w/~,~0 s&cks ~
ou~ eemegg ~ shO~
GALLONS OF I BARRELq 0¥
GASOLINE ] WATER (1!
~RGOVERED I none, so s*ate)
t
. Dri~ed 16" hold O- 2,~35'.
~ a~ cemented 1~ 3/4" casing
ememt. I~ta~ed BOPE ~d tested
.d top of c~nt ~ ~,959~. Drilled
~ed out tb 2,035'; Drilleh 10 5/8"
..
oS..sol- s H. stor~,,, (2)
~laska o~ & c.c~ - D. D.
~ile~, 'rodqeingI
DEC 14 1961
Petroleum Branch
Dhtislon of Mines and Minerals
Dept. of Natural Resourcea
NoT~.--There were ....................................... runs or sales of oil; .............................................. M cu. ft. of gas sold;
........................................... runs or sales of gasoline during ~he month. (Write "no" where applicable.)
NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be flied in
duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by [.he supervisor.
laorm 9-8~9
(January 19~0) to--257ee-s u. s ~ov~a..~.~ ,.mr..e omc~
(SUBMIT IN TRIPLICATE)
UNITED STATES
DEPARTMENT OF THE INTERIOR
GEOLO~iCAL SURVEY
SUNDRY NOTICES AND REPORTS ON WELLS
NOTE[ ~ I{IC)N 10 DRiU_
NOTICE CNc IN~ITNTION TO CHANGe[ ~NS ....... ·
NOTICE O~ INTENTION TO TEST WATER SHUT-OFF
NOTICE OF INTENTION TO RE-D~ILL OR REPAIR WELL
NOTICE OF INTENTION TO ,~)OT OR ACIDIZE __.
NOTICE OF INTENTION TO PULL OR ALTER CASING
NOTICE O~ INTr~TIO~ TO ~NOON WEU.
...........................
SUB~[OUENT R'EPO~T OF WATER $t. tl.n'-O~F
SUBSEQUENT. REPORT OF SHOOTING OR ACIDIZIN~ ........ I ....
SUBSEQUENT REPORT OF /d.T[.RIN6 CASlN~ ......... { .....
SUB~EOU[NT REPORT OF RE-DRILLING OR REPAIR
SUBSEOUENT REPORT OF ABANDONMENT ........ ~ ....
SUPPLEMENTARY WELL HISTORY .... ' ....
_
(INDICATE AIOVE: IY CHECK MARK NATURE OIIr REPO¥~T. NOTICE. OR
..... A~An~s ~_ 28, ................. 1961
Well No. SOU 34-8 is located !200
(~ ~. ~ 8~0. No.)
((k)un~y ur 8ub(ll~ talon?
The elevation of the-? -;--- -=:-above sea level is 160
ft.s mp.oroxi~ately.
DETAILS OF WORK
($tmte r~m~e o/ .nd exl~cteel d~ths to ob~tive ~sl ~ow ~, weilhts~and ~t~
InI ~nts, ~ ail ot~ imprint ~
1. Drill to 2OOO' and cement 11 3/4" casing.
20 Install and Test Class iii Blowout Prevention Equipm~nt.
3. Drill to 8500' ar~ run Electric Log, for correlation°
4. Drill to a~pr~xlmate!y llOO0' (total denth) and run Electric Logs.
5. Cement 7" casing at total deoth in two stages.
6. MAke water Shut-Off tests as required°
7- S.lectivel, Jet perforate Hemlock Zone sands. Test
8. Run 2 7/8" tubing and complete, -.
Address ..... ?,__ O.__l~ox 7-837 ................
.................. ~hor_~ge_,__llaska ................
·
/*'-,,,~ ..... ,--,· - :..=,,~-..:i,, · ........... , ......... "X.
TO D.ILL, :- : '
DEEPEN OR PLUG BACK
:.- --- _. . :-- .- APPLICATION _TO DRILL [~. DEEPIiIN IT[._~- PLUG BACK
'OPi~iR/~~'P'- ----v-- c- ..... .-- : ...... : _ - .-
NAME
OF
O~
_.'., : b:- ' · ' - -·--~:;-' ~. ~ ..... :" ,:,.~SCRI!PTION OF ~WEt]L:' AND ~EASE
Name of lease'"'; %' '-.~ :-, L/-,. 4>: .... i ak:'..~,_-: ~.,--- ~a'~ ..... ': '~ ...... J~~ '' ' -' J E at~n ( ou ). ..
Well location (give footage from section lines) Seetion~township--range or block & survey
Distance, in miles, and direction from nearest townior post office
Distance from proposed location to nearest drilling,
completed or applied--for well on the same lease:
feet
Nearest distance from proposed location
to property or lease line:
Approx. date work Will starl
Proposed depth:
Number of wells on lease, including this well.
completed in or drilling to this r~servoir:
Number of acres in lease:
feet
If lease, purchased with one or more
wells drilled, from who!n purchased:
IRotary or cable tools
Name Address
Status of bond
Remarks: (If this is an application to deepen or plug,:back, briefly describe work to be done, giving present
producing ·zone and expected new producing zone) ~-~--
· 8~ 0il COo, of Cai&fo
CERTIFICATE: I, the undersigned, state that I am the ~- ~__ ~f the ~ _0~~~ ~[J[~,
t
(company), and that I am authorized by said company to make this report; and that this report was pre-
pared under my supervision and direction and that the facts stated therein are true, correct and complete to
the best of my knowledge.
Permit Number:
Approval Date:
Notice: Before send~g
See ~struction on Reverse Side of Form
Signature
Alaska Oil and Gas Conservation Commission
Application to Drill, Deepen or Plug Back
Form No. P-1
Authorized by Order No. 1
Effective October 1, 1958
