Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout194-156Originated: Delivered to:26-Aug-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1L-09 50-029-22025-00 910180917 Kuparuk River Plug Setting Record Field- Final 15-Jul-25 0 12 1R-33 50-029-22529-00 910219407 Kuparuk River Leak Detect Log Field- Final 19-Aug-25 0 13 1R-33 50-029-22529-00 910218799 Kuparuk River Multi Finger Caliper Field & Processed 5-Aug-25 0 14 1Y-06A 50-029-20958-01 910277376 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 23-Aug-25 0 15 1Y-06A 50-029-20958-01 910180481 Kuparuk River Leak Detect Log Field- Final 22-Jul-25 0 16 1Y-06A 50-029-20958-01 910180481 Kuparuk River Plug Setting Record Field- Final 22-Jul-25 0 17 2B-02 50-029-21154-00 910151022 Kuparuk River Packer Setting Record Field- Final 3-Jul-25 0 18 2G-17 50-029-23134-00 910157884 Kuparuk River Leak Detect Log Field- Final 14-Aug-25 0 19 2K-23 50-103-20125-00 910180916 Kuparuk River Plug Setting Record Field- Final 12-Jul-25 0 110 2X-12A 50-029-21189-01 910262801 Kuparuk River Plug Setting Record Field- Final 24-Aug-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:190-034194-156197-134184-122202-243190-014195-176T40827T40828T40828T40829T40829T40829T40830T40831T40832T408338/27/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.08.27 12:51:45 -08'00'21R-3350-029-22529-00 910219407Kuparuk RiverLeakDetect LogField- Final19-Aug-250131R-3350-029-22529-00 910218799Kuparuk RiverMulti Finger CaliperField & Processed5-Aug-2501190 034194-15619 134
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg i7�
DATE: Monday, May 20, 2019
P.1. Supervisor YY�� 41 I27-/lq
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA, INC.
IR -33
FROM: Adam Earl
KUPARUK RIV UNIT IR -33
Petroleum Inspector
Sre: Inspector
Reviewed By:
P.I. Supry JG}
NON -CONFIDENTIAL
Comm
Well Name KUPARUK RIV UNIT 1R-33 API Well Number 50-029-22529-00-00 Inspector Name: Adam Earl
Permit Number: 194-156-0 Inspection Date: 5/8/2019 —
Insp Num: mitAGE190510092622
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well IR -33 Type Inj ! w TVD 6596 Tubing '42T270
421 1400 - 2400 -
PTD 1941560 Type t SPT Test psi 1649 IA 610901 - 1890 1871 �-
BBL Pumped: 4.9 " IBBL Returned: 3.3 OA too 70
220
—
Interval
4YRTS�F P V
Notes: MIT IA -- - -
Monday, May 20, 2019 Page I of I
STATE OF ALASKA RECEIVED
ED
ALTA OIL AND GAS CONSERVATION COM ION
REPORT OF SUNDRY WELL OPERATIONS OCT 1 1 2017
1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ a hutdown ❑
Performed: Suspend ❑ Perforate ❑ Other Stimulate DAlter Casing ❑ Vng p o d Program ❑
Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: DAD Acid Stim ❑.,
2.Operator 4.Well Class Before Work: 5.Permit to Drill Number:
Name: ConocoPhillips Alaska, Inc.
Development ❑ Exploratory ❑ 194-156
3.Address: P. O. Box 100360, Anchorage, Alaska Stratigraphic ❑ Service Q 6.API Number:
99510 50-029-22529-00
7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1R-33
ADL 25628
9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):
N/A Kuparuk River Field/ Kuparuk River Oil Pool
11.Present Well Condition Summary:
Total Depth measured 15,530 feet Plugs measured N/A feet
true vertical 6,945 feet Junk measured 15302' feet
Effective Depth measured 0 feet Packer measured 15,036 feet
true vertical 0 feet true vertical 6,608 feet
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 80 feet 16" 121' MD 121'TVD
SURFACE 7,628 feet 9-5/8" 7,669' MD 4081'TVD
PRODUCTION 15,484 feet 7" 15,520' MD 6938'TVD
Tubing(size,grade,measured and true vertical depth) 3.5" L-80 15,114' MD 6,661'TVD
Packers and SSSV(type,measured and true vertical depth) PACKER- BAKER FB-1 PACKER 15,036' MD 6,608'TVD
SSSV-NONE
12.Stimulation or cement squeeze summary: -p
Intervals treated(measured): N/A SCANNED DEC 1 4 2017.
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: 0 0 360 50 2431
Subsequent to operation: 0 0 205 10 2248
14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work:
Daily Report of Well Operations 2 Exploratory ❑ Development p ❑ Service ❑� Stratigraphic ❑
Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑
Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG E GINJ ❑ SUSP❑ SPLUG ❑
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt:
317-260
Contact Name: Jason Burke
Authorized Name: Jason Burke
Contact Email: Jason.Burke@cop.com
Authorized Title:Staff Wells En ineer
/45..,) Contact Phone: (907)265-6097
Authorized Signatur : Date:f� D
viz- Jo // HI, 7-"
told
•
RBBNJ 3 t.,�, OCT 1 1 2017
Form 10-404 Revised 4/2017 Submit Original Only
• •
1 R-33
DTTMST JOBTYP SUMMARYOPS
9/20/17 ACID RIH WITH JSN, PUMP 100BBLS 10% DAD ACID ACROSS PERFS AT 15,220' RKB
TO 15,115' RKB, TURN WELL OVER TO DSO, JOB COMPLETE
KUP I 1R-33
ConocoPhillips " Well Attribut Max Angle- llit TD
Alakc.II1.:. Wellbore API/UWI Field Name Wellbore Status incl(^) MD(ftKB) Act Btm(ftKB)
CorecePhillips 500292252900 KUPARUK RIVER UNIT INJ 73.85 4,570.871 15,530.0
... Comment H25(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date
1R-33,1 011 0/201 7 1 2:35:59 PM SSSV:NIPPLE Last WO: 12/30/1994
Vertical schematic(actual)
Annotation Depth(ftKB) End Date Annotation Last Mod By End Date
Last Tag:SLM 13,124.0 3/22/2013 Rev Reason:SET ISO SLEEVE,TAG lehallf 2/5/2014
Casing Strings
Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread
,1- CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H-40 WELDED
HANGER;38.5 :l Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD(... Wt/Len(I...Grade Top Thread
SURFACE 9 5/8 8.835 40.8 7,669.0 4,081.1 40.00 L-80 BTC
•
f 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WELen(I...Grade Top Thread
PRODUCTION 7'5,5" 7 6.276 35.8 15,520.0 6,938.2 26.00 L-80 BTC-MOD
I Tubing Strings
i
Tubing Description String Ma...ID(in) TopftKB Set Depth(ft..Set Depth(TVD)9 P (ftKB) p ( )(...Wt(Ibttt) Grade Top Connection
TUBING 31/2 2.992 38.5 15,113.9 6,660.9 9.30 L-80 EUE8RABM
Completion Details
•
Nominal ID
Top(ftKB) Top(TVD)(ftKB) Top not I°) Item Des Corn (in)
'" 38.5 38.5 0.00 HANGER FMC GEN IV TUBING HANGER 3.500
CONDUCTOR;41.0-121DII. 481.4 481.2 3.73 NIPPLE CAMCO DS LANDING NIPPLE NO GO 2.812
14,971.9 6,564.9 47.93 SLEEVE BAKER CMU SLIDING SLEEVE w/CAMCO D PROFILE 2.750
•
15,018.2 6,596.0 47.60 SEAL ASSY BAKER GBH LOCATOR SEAL ASSEMBLY 3.000
NIPPLE,481.4IN 15,036.1 6,608.1 47.48 PACKER BAKER FB-1 PACKER 3.000
15,039.4 6,610.3 47.46 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000
15,053.8 6,620.1 47.36 BLAST RING BLAST RING(1) 2.992
t
15,111.9 6,659.5 47.09 WLEG SXAR SCHLUMBERGER SUB w/WIRELINE RE-ENTRY 2.980
GUIDE
Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)
1111 Top(TVD) Top Incl
Top(ftKB) (ftKB) (°) Des Com Run Date ID(in)
GAS LIFT,2,071.0 14,972.0 6,565.0 47.93 SLEEVE-C SET BAKER 2.75"ISO SLEEVE OAL 52" 1/22/2014 2.310
15,302.0 6,789.4 46.86 FISH 128'Spent Tbg Peri Guns in Rathole Perf on 3/28/95 4/9/1995
(SWS 33/8" HSD)
Perforations&Slots
Shot
Dene
Top(TVD) Btm(TVD) (shots/
Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com
15,132.0 15,165.0 6,673.3 6,695.7 A-3,1R-33 3/28/1995 4.0 (PERF 33/8" HSD TBG CONY;
180 deg.ph;Orient165
deg.CCW F/High Side
SURFACE.40.8-7,669.0-4
15,186.0 15,212.0 6,710.1 6,727.8 A-2,1R-33 3/28/1995 4.0 IPERF 3 3/8"HSD TBG CONV;
-
180 deg.ph;Orient165
deg.CCW F/High Side
Notes:General&Safety
a -e
o • End Date Annotation
SLEESLEVEEVE;14,4,71
972.90, 10/20/2010 NOTE:View Schematic w/Alaska Schematic9.0
-C;1
I -
o.
PACKER',15,035.1 1 "
SBE;15.039.4 •�•
M
1 RIa
WLEG;15,111.9
I
IPERF;15.132.0-15,165.0
(PERF;15,186.0-15,212.0
FISH;15.302.0
PRODUCTION 7"x5',35.8-
15,520.0
OF Tit,
• •
I�7 g THE STATE Alaska Oil and Gas
O f T e c KA Conservation Commission
333 West Seventh Avenue
r Anchorage, Alaska 99501-3572
GOVERNOR BILL WALKER g
Main: 907.279.1433
0%.11,'A'4%‘14.
AALA'A^SgF' Fax: 907.276.7542
www.aogcc.alaska.gov
Jason Burke
Staff Wells Engineer %WED .J I-;L 0 6 201?
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1R-33
Permit to Drill Number: 194-156
Sundry Number: 317-260
Dear Mr. Burke:
Enclosed is the approved application for sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
Cathy P oerster
Chair
DATED this 2y of June, 2017.
RBDMS liL JUN 1 6 2017
RECEIVED
STATE OF ALASKA JUN 15 2017
ALASKA OIL AND GAS CONSERVATION COMMISSION /V7`'S 6( ( 7
APPLICATION FOR SUNDRY APPROVALS AOGCC
20 AAC 25.280
1.Type of Request: Abandon 0 Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑
Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tubing ❑ Change Approved Program❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: Acid Stimulate I]
2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number:
ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 194-156 '
3.Address: Stratigraphic ❑ Service 6.API Number:
P. O. Box 100360,Anchorage,Alaska 99510 50-029-22529-00 '
7.If perforating: 8.Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? N/A
KRU 1R-33 '
Will planned perforations require a spacing exception? Yes ❑ No E 1
9.Property Designation(Lease Number): 10.Field/Pool(s):
ADL 25628 . Kuparuk River Field/Kuparuk River Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD):
15,530' — 6,945' • 15294 6784 2861psi NONE 15302
Casing Length Size MD TVD Burst Collapse
Conductor 80' 16" 121' 121'
Surface 7,628' 9 5/8 7,669' 4,081'
Production 15,484' 7" 15,520' 6,938'
Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft):
15132-15165,15186-15212 , 6673-6696,6710-6728 3.500" L-80 15,114'
Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft):
PACKER-BAKER FB-1 PACKER • MD=15036 TVD=6608
SSSV: NONE N/A
12.Attachments: Proposal Summary 0 Wellbore schematic I] 13.Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0
14.Estimated Date for 7/1/2017 15.Well Status after proposed work:
Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑
Suspended ❑
16.Verbal Approval: Date: GAS ❑ WAG LI GSTOR ❑ SPLUG ❑
Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Name: Jason Burke Contact Name: Jason Burke
Authorized Title: Staff Wells Engineer Contact Email: Jason.Burke@cop.com
Contact Phone: (907)265-6097
Authorized Signat �f:.V � Date: ��17-
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
317- 2cpo
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑
Other:
Post Initial Injection MIT Req'd? Yes ❑ No (9 t ,
Spacing Exception Required? Yes ❑ No Subsequent Form Required: J 0 -4 L- RBDMS ;,-.( JU`� 2/672017
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date: ' -
p ,...,,,,/,....._
VT1_6/lc1 J17_-
7K& 6//y /7-
(a Rel J4/iov fJ ' JprJajcn is valid for 12 months from the date of approval. Attachments in Duplicate
• •
ConocoPhillips Alaska,Inc. Nr
Drilling&Wells ConocoPhillips
Well Intervention Alaska
1R-33 Acid Treatment (TBD)
Engineer: Jason Burke
Wells Engineer
907-231-4568
DAD, dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with
dispersing agent F103. The purpose of the dispersion is to simultaneously dissolve acid-soluble
minerals and remove oil paraffinic deposits. Target areas can be tubulars,perforations or the
critical matrix.
Objectives: Spot Dynamic Acid Dispersion (DAD) treatment with CT into perforations
to increase injectivity
• Coiled Tubing: Spot 100 bbl of DAD into formation
1. MIRU 1.5" CT,MU 5 port wash nozzle BHA
2. Begin RIH down to 15220' MD.
3. When CT has reached depth begin pumping DAD treatment. When treatment is exiting
the CT (depending on CT volume) shut in the choke and begin POOH to 15115'.
Continue injecting DAD into formation and it out of the CT with produced water or
diesel.
a. Do not exceed 4500 psi surface pressure
4. After an additional 5 bbl of fluid has been injected behind the treatment POOH
5. RDMO CT. Return well to injection.
Function SLB Code Concentration Quantity
Acid corrosion inhibitor A264 4 gpt 15 gal
HC1 H036 221.4 gpt 934 gal
Emulsifier F103 15 gpt 63 gal
Iron Control L058 20 ppt 76 lbs
Non-emulsifier W054 2 gpt 19 gal
Xylene _ A026 100 gpt 420 gal
June 7, 2017 1R-33 Well Work Procedure Page 1 of 1
b KUP 1R-33
t ,,
-ConoccPhillips / ' Well Attribu6 Max Angle a D TD
AlHska.1711: , Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB)
CanocoeFlitips 500292252900 KUPARUK RIVER UNIT INJ 73.85 4,570.87 15,530.0
°°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date
1R-33,6/13/20178:16:00 AM SSSV:NIPPLE Last WO: 12/30/1994
Vertical schemaOc(actual)
Annotation Depth(ftKB) End Date Annotation Last Mod By End Date
Last Tag:SLM 13,124.0 3/22/2013 Rev Reason:SET ISO SLEEVE,TAG lehallf 2/5/2014
Casing Strings
Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread
CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H-40 WELDED
HANGER;38.5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len p...Grade Top Thread
SURFACE 9 5/8 8.835 40.8 7,669.0 4,081.1 40.00 L-80 BTC
I i i I il. Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(ND)...Wt/Len It...Grade Top Thread
PRODUCTION 7"x5" 7 6.276 35.8 15,520.0 6,938.2 26.00 L-80 BTC-MOD
Tubing Strings
Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection
TUBING 31/2 2.992 38.5 15,113.9 6,660.9 9.30 L-80 EUE8RABM
Completion Details
Nominal ID
Top(ftKB) Top(TVD)(ORB) Top Incl(°) Item Des Com (in)
li
38.5 38.5 0.00 HANGER FMC GEN IV TUBING HANGER 3.500
CONDUCTOR;41.0-121.0 le 481.4 481.2 3.73 NIPPLE CAMCO DS LANDING NIPPLE NO GO 2.812
14,971.9 6,564.9 47.93 SLEEVE BAKER CMU SLIDING SLEEVE w/CAMCO D PROFILE 2.750
15,018.2 6,596.0 47.60 SEAL ASSY BAKER GBH LOCATOR SEAL ASSEMBLY 3.000
NIPPLE,401.4 a 15,036.1 6,608.1 47.48 PACKER BAKER FB-1 PACKER 3.000
15,039.4' 6,610.3 47.46 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000
15,053.8 6,620.1 47.36 BLAST RING BLAST RING(1) 2.992
15,111.9 6,659.5 47.09 WLEG SXAR SCHLUMBERGER SUB w/WIRELINE RE-ENTRY 2.980
GUIDE
Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)
Top(ND) Top Incl
Top(ftKB) (ftKB) (°) Des Com Run Date ID(in)
GAS LIFT;2,071.0 14,972.0 6,565.0 47.93 SLEEVE-C SET BAKER 2.75"ISO SLEEVE OAL 52" 1/22/2014 2.310
15,302.0 6,789.4 46.86 FISH 128'Spent Tbg Perf Guns in Rathole Perf on 3/28/95 4/9/1995
11 (SWS 3 3/8"HSD)
• Perforations&Slots
Shot
Den
Top(ND) Btm(ND) (shots/
Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com
• 15,132.0 15,165.0 6,673.3 6,695.7 A-3,1R-33 3/28/1995 4.0 IPERF 3 3/8"HSD TBG CONV;
180 deg.ph;Orient165
deg.CCW F/High Side
SURFACE;400-7,069.0-.
15,186.0 15,212.0 6,710.1 6,727.8 A-2,1R-33 3/28/1995 4.0 IPERF 33/8"HSD TBG CONV;
•
180 deg.ph;Orient165
deg.CCW F/High Side
Notes:General&Safety
End Date Annotation
SLEEVE;14,971.9., 1j 10/20/2010 NOTE.View Schematic w/Alaska Schematic9.0
SLEEVE-C;14,972.0
(I
I
ii
B
PACKER;15,038.1
a
SBE;15,039.4 C
IF
I
WLEG;15,111.91
r
(PERF:15,1320-15,1650
IPERF;15,186.0-15,212.0
FISH;15,302.0
PRODUCTION 7°x5';35.8- -
15,520.0
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
I DATE: Wednesday,May 20,2015
TO: Jim Regg
P.I.Supervisor ( ?qW S SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1R-33
FROM: Bob Noble KUPARUK RIV UNIT 1R-33
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 1R-33 API Well Number 50-029-22529-00-00 Inspector Name: Bob Noble
Permit Number: 194-156-0 Inspection Date: 5/14/2015
Insp Num: mitRCNI50516102753
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 1R-33 Type Inj W TVD 6596 - Tubing 2180 2200 • 2200 • 2200 -
PTD I 1941560 Type Test{SPT Test psi 1649 IA 520 3000 - 2960 2960
Interval I4YRTST PIF P r/ OA i to •I 20 20 _ 20 —
Notes:
J 4 l
Ku
Wednesday,May 20,2015 Page 1 of 1
Pages NOT Scanned in this Well History File
XHVZE
This page identifies those items that were not scanned during the initial scanning project.
They are available in the Original file and viewable by direct inspection.
I'~ ~-/~ File Number of Well History File
PAGES TO DELETE Complete
RESCAN
Color items - Pages:
Grayscale, halftones, pictures, graphs, charts-
Pages:
Poor Quality Original - Pages:
[] Other- Pages:
DIGITAL DATA
[] Diskettes, No.
[] Other, No/Type
OVERSIZED
Logs of various kinds
[] Other
COMMENTS:
Scanned by:
Beve~ Vincent
Nathan Lowell
Date:
[] TO RE-SCAN
Notes:
Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si
110 kek. 02-33
Pbt s
Regg, James B (DOA)
From: NSK Problem Well Supv [n1617 @conocophillips.com] Iv 7
"� /
Sent: Wednesday, June 06, 2012 7:27 PM 1
To: Regg, James B (DOA); Schwartz, Guy L (DOA)
Cc: NSK Problem Well Supv
Subject: 1 R -33 (PTD 194 -156) Report of failed MITIA
Attachments: 1R -33 schematic.pdf
Jim / Guy
Kuparuk injector 1R-33 (PTD 194 -156) failed a diagnostic MITIA. The well had been SI since 04/13/10 due to a derated
injection line. The MITIA was performed as a pre- injection MIT prior to the well returning to injection since the injection
line has been repaired. Diagnostics will be performed utilizing Slickline, E -line and DHD as needed. The well has been
added to the monthly report.`Foflowing diagnostics, the appropriate paperwork will be submitted for repair or continued
injection.
Attached are a 90 day TIO plot and schematic.
Please let me know if you have any questions.
Brent Rogers / Kelly Lyons
Problem Wells Supervisor
ConocoPhillips Alaska, Inc.
Desk Phone (907) 659 -7224
Pager (907) 659 -7000 pgr. 909
5itr WC, JUL 1 3 201
1
,
KRU_1R-33
PTD 1941560
6/6/2012
TIO Pressures Plot
TRNANNL
ANNULUS PRESSURE TRENDS
3000.
3000 WELL NAME Wdatiiik-Si'
200.
3000.
2700
3000 _
3000.
•
3000. 2400
, .
3000.
2100 /7- \ __,________7 .------------____
t
1800
-...
1500
1200
900 ki
•
-
--"---
Aik _ la ..A-Are-A-AA-A-AVA-**-A. A •
. .
4 A
600
---
. ,
• ,,,,,t., ? _. ..._
300
z• 1, •,%:41, ,
...-V ' -',.•' o . ..... -----,
*.
•
PLOT START TIME MINOR TIME
PLOT DURATION PLOT END TIME
08 -MAR -12 18:17 MAJOR TIMEWEEK RRS
PICK TIMEIIIIIIIIIIIIIIIIII rffrrrnizrffrff witcritt! rg,
Sc TAG MANE DESCRIPTION P -VALDE LATEST
1111 WL1R -33 -CHOKE FLOW TUBING CHOKE 777777? DRILLSITE WELL
III SCRATCH 96 FLOW TUBING PRESSURE 777777? lr 33
ill SCRATCH_96 FLOW TUBING TEMP ??????? NEXT WELL
IIII ???????
MI ??????? ENTRY TYPE OPERATOR
III 7777777 NMI OPERATOR VERIFIED
III SCRATCH_96 INNER ANNULUS PRES ??????? INN SYSTEM AUTO ENTRY
III SCRATCH_96 OUTER ANNULUS PRES 777777? NW BOTH
A e
w a KUP 1 R 33
Conoco fill ips T
Alaska, �' elrs�ltrataa� �I : r� t � v : 7 .�, 7, .
I W Ilb a API/UM Feld Name Well Status Inc! r) MD (ftKB) Act Btm (ftKB)
_ , 8ps 500292252900 KUPARUK RIVER UNIT INJ 73.85 4,570.87 15,530.0
Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date
Wen Confl •l0 331v1Acto SSSV: NIPPLE Last WO: 12/30/1994
Schemata. ol Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date
Last Tag: CTMD 15,300.0 9/29/2006 Rev Reason: FORMAT UPDATE ninam 11/10/2011
Z
Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String .. String Top Thrd
CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H WELDED
14 ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd
HANGER.37 9 � SURFACE 95/8 8.835 40.8 7,669.0 4,081.1 40.00 L - 80 BTC
Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd
PRODUCTION 7x5 7 6.6 L B MOD
ubmg Str 1=
I , Tub ng Description String 0... String ID Top (ftKB) Set Dpth (1... Set Deh (TVD) ...',String Wt... lstring . St Top Thrd
TUBING 31/2 2.992 276 36.9 36.7 1165,502906..00 ' 9.30 26.00 L -80 80 EUEB RABM
C Details
Top Depth
(ND) Top lncl
Top (1808) (ftKB) in Item Description Comment ID (i^)
36.9 36.9 -1.06 HANGER FMC GEN IV TUBING HANGER 3.500
479.9 479.6 3.53 NIPPLE CAMCO DS LANDING NIPPLE NO GO 2.812
CONDUCTOR,
41 - 121 14,971.9 6,564.6 47.33 SLEEVE BAKER CU SLIDING SLEEVE w/ CAMCO D PROFILE 2.750
15,018.2 6,595.9 47.25 PACKER BAKER FB -1 PACKER 3.000
15,021.5 6,598.2 47.25 SBE BAKER 80 -40 SEAL BORE EXTENSION 4.000
15,094.1 6,647.4 s ++ 47.12 SOS SXAR SCHLUMBERGER 2.980
NIPPLE,480 i -rarl H +i = ♦111re1�"
Top Depth - - - - , > . . a a.. c
(ND) Top loci
Top (11(8) (ftKB) ( °) Description Comment Run Date ID (in)
15,302 6,789.4 46.96 FISH 128' Spent Tbg Perf Guns in Rathole Perf on 3/28/95 (SWS 4/9/1995
33/8" HSD)
44; ,1 ry T1 .;mss >- � ( r,+ ° s
9-. fl8" $r,— n VI, !:. " tii .. -EL i1 xi , .. -.- :'
Shot
GAS LIFT, It': Top (ND) Btm (TVD) Dens
2,069 Top (f0(8) Btm (61(13) (ftKB) (ftKB) Zone Date ( Type Comnrnnt
15,132 15,165 6,673.3 6,695.8 A-3, 1R-33 3/28/1995 4.0 IPERF 3 3/8" HSD TBG CONV; 180 deg. ph;
Orient165 deg. CCW F/ High Side
15,186 15,212 6,710.1 6,727.9 A-2, 1R -33 3/28/1995 4.0 IPERF 3 3/8" HSD TBG CONV; 180 deg. ph;
Orient165 deg. CCW F/ High Side
II a :. 4 y f .t
Ns — tes: Genera! �i a�`e I I °"' `�y �- , ��'�� hglifjtA
End Date Annotation
10/20/2010 NOTE: View Schematic w/ Alaska Schematic9.0
L SURFACE. g
„„:.
SLEEVE,
4,972
PA
15,018
imingr
SBE, 15,022 _
t 1
SOS, 15,094
IPERF.
15.132- 15.165 _ -
Mandrel 0, ails - i Yy (" „ ��7^ r
IPERF, - port
15,18615212 _ Top Depth Top
(
(ND) Incl OD Valve Latch Size IRO Run
Stn Top (*KB) (8103) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com...
1 2,069.3 1,989.5 32.29 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/29/1995
FISH, 15.302 v d
PRODUCTION
74, 37- 15.520 . ,
TD, 16530
Conoco`Phiilips
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360--- --- --
February 1, 2010
Mr. Dan Seamount
Alaska Oil &-Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Mr. Dan Seamount:
~E~EIVED
~1A-~ ~ 5 2010
,~lasica Oil & bas Cuts. Conrrdssian
Anrherage
___ . __
- .~ ~ 1~
~~~ ~
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRIS. Each of
these wells was found to have a void in the conductor. These voids were filled with cement if
needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As
per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that
the treatments took place and meets the requirements of form 10-404, Report of Sundry
Operations.
The cement was pumped December 5th, 2009. The corrosion inhibitor/sealant was pumped
December 22°d, 25th, 26th & 28th, 2009. The attached spreadsheet presents the well name, top of
cement depth prior to filling, and volumes used on each conductor.
Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions
Sincerely,
y Klel~i
ConocoPhillips Well Integrity Projects Supervisor
.~
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
Date 3/1/2010 1 G.1 L & 1 R Pad
Well Name
API #
PTD #
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft al
1G-17 50029229450000 1990620 SF n/a 17" n/a 7.65 12/26/2009
1L-01 50029211960000 1841730 52' 7.7 31" 12/5/2009 10.15 12/22/2009
1 L-02 50029211930000 1841700 45' 5.7 35" 12/5/2009 10.15 12/22/2009
1 L-04 50029211790000 1841540 40` 3.9 24" 12/5/2009 5.8 12/22/2009
1 L-06 50029211640000 1841330 2'5" n/a 2'5" - n/a 7.22 12/26/2009
1 L-08 50029211750000 1841500 34' 3.7 40" 12/5/2009 10.2 12/26/2009
1L-09 50029220250000 1900340 11" n/a 11" n/a 1.27 12/26/2009
1L-11 50029220340000 1900450 16" n/a 17" n/a 2.25 12/25/2009
1 L-12 50029220330000 1900440 7" n/a 15" n/a 3.4 12/25/2009
1 L-13 50029221500000 1910420 13' 2.2 27" 12/5/2009 5.52 12/26/2009
1 L-17 50029221510000 1910430 26' 4.0 18" 12/5/2009 9.35 12/26/2009
1 L-19 50029220490000 1900610 9' 2.5 19" 12/5/2009 4.25 12/25/2009
1 L-23 50029221670000 1910620 SF n/a 17" n/a 2.12 12/26/2009
1 L-26A 50029221730100 2000150 SF n/a 17" n/a 2.97 12/25/2009
1 R-14 50029213860000 1851510 SF n/a 29" n/a 5.95 12/28/2009
1 R-31 50029225380000 1941680 6" n/a 24" n/a 7.22 12/28/2009
1 R-32 50029225230000 1941460 SF n/a 24" n/a 5.95 12/28/2009
1 R-33 50029225290000 1941560 SF n/a 24" n/a 4.67 12/28/2009
MEMORANDUM
TO:
Jim Regg -----.1~;7 ,
et;"
P.I. Supervisor ('(
FROM:
Bob Noble
Petroleum Inspector
.
/ I'~/C' 7
ç I
Well Name: KUPARUK RN UNIT IR-33
Insp Num: mitRCN070510214037
ReI Insp Num:
Well i
P.T.Di
lR-33 ¡Type Inj. i W
1941560 ¡TypeTest i SPT
Interval 4YRTST
P/F
Notes:
Friday, May II, 2007
Packer
TVD
.
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Friday, May I ], 2007
SUBJECT: ylechanical [ntegnty Tests
CO'\OCOPH1LLIPS ,"'L~SKA l"\iC
tR-l3
KUPARUK RIV U"\ilT 1 R-33
Src: Inspector
NON-CONFIDENTIAL
API Well Number: 50-029-22529-00-00
Permit Number: 194-[56-0
~ ~ \ 510
\~
Reviewed By:
P.I. Suprv.J13¡2--
Comm
Inspector Name: Bob Noble
Inspection Date: 5/9/2007
6596
i 2800
~~- ---------
2780
15 Min. 30 Min. 45 Min.
I
,
---_.._-~--
I
Depth
Initial
I
Test psi' 1649
-:/
_~_______--,!ubing I
Pretest
-,--
I IA
'OA
o '225 225,
-----J-----------+--------L
1900 1900 1900
680
SCANNED JUN 062007
~. ....,_<4....t.-.!-.:,~,:____¡&!..,~!~,.,,~...
60 Min.
--
2780
225
-- ---
¡ - __---¡_m____
J~_L____
1900
Page I of I
)
)
Mike Mooney
Wells Group Team Leader
Drilling & Wells
ConocriP'hillips
P. O. Box 100360
Anchorage, AK 99510-0360
Phone: 907-263-4574
November 22, 2004
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Subject: Report of Sundry Well Operations for 1 R-33 (APD # 194-156)
Dear Commissioner:
ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations
for the recent stimulation operation on the Kuparuk well 1 R-33.
If you have any questions regarding this matter, please contact me at 263-4574.
Sincerely,
PI > J4~
M. Mooney
Wells Group Team Leader
CPAI Drilling and Wells
MM/skad
SCANNED NOV 2 4 2004
OR\G\ AL
)
)
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
RepairWell D
Pull Tubing D
Operat. ShutdownD
Abandon D
Alter Casing D
Change Approved Program D
2. Operator Name:
ConocoPhillips Alaska, Inc.
3. Address:
P. O. Box 100360, Anchorage, Alaska
7. KB Elevation (ft):
RKB 86'
1. Operations Performed:
Stimulate [2]
Waiver 0
0
Time Extension 0
Re-enter Suspended Well 0
5. Permit to Drill Number:
194-1561
6. API Number:
50-029-22529-00
Plug Perforations 0
Perforate New Pool 0
Perforate 0
4. Current Well Status:
Development 0
Stratigraphic D
Other
Exploratory 0
Service [2]
9. Well Name and Number:
1 R-33
8. Property Designation:
ADL 25628, ALK 2561
11. Present Well Condition Summary:
Total Depth
Effective Depth
Casing
Structural
CONDUCTOR
SUR. CASING
PROD. CASING
LINER
Perforation depth:
10. Field/Pool(s):
Kuparuk River Field 1 Kuparuk Oil Pool
measured 15530' feet
true vertical 6945' feet
measured 15294' feet
true vertical 6784' feet
Length Size MD
121' 16" 121'
7583' 9-5/8" 7669'
14976' 7" 15062'
458' 5" 15520'
Plugs (measured)
Junk (measured)
15302'
TVD
Burst
Collapse
121'
4081'
6626'
6938'
Measured depth: 15132'-15165', 15186'-15212'
true vertical depth: 6673'-6696',6710'-6728'
Tubing (size, grade, and measured depth) 3-1/2" , L-80, 15096' MD.
Packers & SSSV (type & measured depth) pkr= BAKER 'FB-1' pkr= 15018'
Camco 'OS' Landing nipple 480'
12. Stimulation or cement squeeze summary:
Intervals treated (measured)
15132'-15165',15186'.152121
735 bbls of slick seawater
13.
Treatment descriptions including volumes used and final pressure:
Representative Daily Average Production or Injection Data
Gas-Met Water-Bbl
n/a 380
519
15. Well Class after proposed work:
Exploratory 0 Development 0 Service [2]
16. Well Status after proposed work:
OilO GasO WAG [2] GINJO WINJ 0
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
Oil-Bbl
n/a
Casinq Pressure
TubinQ Pressure
2157
2151
Prior to well operation
Subsequent to operation
14. Attachments
Copies of Logs and Surveys run -
Daily Report of Well Operations_X
Contact
Printed Name
Signature
WDSPLO
Mike Mooney @ 263-4574
Mike Mooney
)¡( 7 )fr~tt/v"
---~
Kuparuk Wells Team Leader,
Date ¡ll-'''' }o~
I . ~(
t. Preoared by Sharon AlIsu -Drake 263-4612
"".. RBDMS 8FL NOV 2 2 1004
Submit Original Only
Title
Phone
¡
~
Form 10-404 Revised 04/2004
)
1 R-33 Well Events Summary
)
Date Summary
11/02/04 POOR BOY HPBD COMPLETED PUMPED 735 BBLS OF 60 DEGREE SLICK
SEAWATER. MAX WHTP 4025 PSI AND MAX RATE WAS 6.7 BPM. RETURNED WELL
TO PW INJECTION POST BREAKDOWN. [HPBD]
)
)
ConocoPhillips Alaska, Inc.
1 R-33
NIP (48CÞ481,
00:3.500)
TUBING
(0-15096,
00:3.500,
10:2.992)
Gas Lift
mdrel/Oummy
Valve 1
(2069-2070,
00:6.018)
SLEEVE-C
(14972-14973,
00:3.500)
PKR
(15018-15019,
00:6.156)
sos
(15094- 15095,
00:3.500)
ill
(15096-15097,
00:3.500)
d .:U
I
, I
.i Ir~
'...-..,..
..)
j~:: .;'%
\,,~. "" , :n'"
-
-:z:.-
Perf +--
(15132-15165)
t-
.:.......-
..io--
+--
-'--
Perf ---
(15186-15212) +--
~
..>--
KRU
1R-33
API: 500292252900
SSSV Type: Nipple
Well Type: INJ
Orig 12/30/1994
Completion:
Last W/O:
Ref Log Date:
TO: 15520 ftKB
Max Hole Angle: 74 deg @ 4571
Angle@TS: 48 deg @ 14912
Angle @ TO: 47 deg @ 15530
Rev Reason: Tag Fill
Last Update: 3/11/2003
Annular Fluid:
Reference Log:
Last Tag: 15294
Last Tag Date: 2/24/2003
Casing String - ALL STRINGS
Description Size
CONDUCTOR 16.000
SUR. CASING 9.625
PROD. CASING 7.000
LINER 5.000
Tubing String - TUBING
Size I Top
3.500 0
Perlorations Summary
Interval TVD
15132-15165 6673-6696
Bottom
15096
Top Bottom TVD Wt Grade Thread
0 121 121 62.50 H-40
0 7669 4081 40.00 L-80
0 15062 6626 26.00 L-80
15062 15520 15520 18.00 L-80
TVD Wt I Grade I Thread
6649 9.30 L-80 EUE 8R ABM
Status Ft SPF Date Type
33 4 3/28/1995 ¡PERF
Comment
33/8" HSD TBG CONV;
180 deg. ph; Orient165 deg.
CCW F/ High Side
33/8" HSO TBG CONY;
180 deg. ph; Orient165 deg
CCW F/ High Side
Zone
A-3
15186-15212 6710-6728
A-2
26 4 3/28/1995 ¡PERF
Gas Lift MandrelsNalves
St MD TVD Man Man
Mfr Type
1 2069 1989 Camco MMM
Other ll)lugs, equip., etc.: - JEWELRY
Depth TVD Type
480 480 NIP
14972 6565 SLEEVE-C
15018 6596 PKR
15094 6647 SOS
15096 6649 TTL
Fish - FISH
Depth Description
15302 128' Spent Tbg Perf Guns in
Rathole
V Mfr V Type V 00 Latch Port TRO Date
Run
RK 0.000 0 3/29/1995
Vlv
Cmnt
DMY
1.5
Description
Camco 'OS' Landing Nipple NO GO
Baker 'CMU' Sliding wI Camco '0' Profile
Baker 'FB-1'
XSAR SChlumberger
3.5" Tubing
ID
2.812
2.750
3.000
2.992
2.992
Comment
Perf on 3/28/95 (SWS 3 3/8" HSD)
MEMORANDUM
TO:
THRU:
State of Alaska
Alaska Oil and Gas Conservation Commission
Commissioner
SUBJECT:
Mechanical
Integrity
Tests
ConocoPhillips Alaska Inc.
P.I. Supervisor~ ~ 1R Pad
Lt
1R-04, 1 R-13, 1 R-32, 1 R-33
Jeff Jones KRU
Petroleum Inspector Kuparuk River Field
NON- CONFIDENTIAL
FROM:
Packer Depth Pretest Initial 15 Min. 30 Min.
WeilI 1R-04 I Type,nj.I G I T.V.D. 16384I Tu~,.~l3~o I 3550 13550I3~0 I,nterva,I 4
P.T.D.I 1851780ITypetestl P I Testpsil 1596 I Casingl 1150I 2500I 2420I 2410I P/F IF, I
Notes: Test fluid: 2.2 bbls diesel.
Packer Depth Pretest Initial 15 Min. 30 Min.
I~-~I Ty, , i.Is I ~.v.~. 1~420 I Tubingl 2350 I 2350 12350 12350 I,ntervall 4
P.T.D.I 18515O0 Imypetestl P ITestpsil 1605 ICasi.gI 1125I 3000I 2970I 2940I P/F I
Notes: Test fluid: 2.5 bbls diesel. Held press, test extra 15 min. Tubing =2350 psi / Casing =2920 psi final.
Packer Depth Pretest Initial 15 Min'i 30 Min.
w ,,I,.-~ I Typelnj. I sI I Tubingl2360I I I I,nterva,I 4,I
P.T.D:I 1941460 Type testl P I Testpsil 1563 I Casingl 1350 I 3O4O I 3020 I 3020 I P/F I'_P i'''''/
Notes: Test fluid: 3.3 bbls diesel.
Packer Depth Pretest Initial 15 Min. 30 Min.
We,,I 1R-33 I Type,nj.I S I T.V.D.I 6596 I Tubingl2350 12350 12350 12350 I,nterva,l' 4
P.T.D.I 1941560 I TypetestI P I Test psiI 164,9 I Casing I 225 I 3150 I 3125 I 3125 I P/F I --P
Notes: Test fluid: 8 bbls diesel.
Type INJ. Fluid Codes
F = FRESH WATER INJ.
G = GAS I NJ.
S = SALT WATER INJ.
N = NOT INJECTING
Type Test
M= Annulus Monitoring
P= Standard Pressure Test
R= Internal Radioactive Tracer Survey
A= Temperature Anomaly Survey
Interval
I= Initial Test
4= Four Year Cycle
V= Required by Variance
W= Test during Workover
D= Differential Temperature Test O= Other (describe in notes)
Test's Details
May 31, :z003: I traveled to ConocoPhillips Alaska's ~c.'s (CPA.I) Kuparuk River Field injection wells 1R-04, 1R-13, 1R-
32 and 1R-33, to witness 4 year MIT's.
Nina Woods was the CPAI representative for the tests today. The pretest pressures on each well were monitored and found
to be stable and the standard annulus pressure tests were then performed with all four wells meeting the criteria for
successful MIT's. The pressure test on well 1R-13 was extended an extra 15 minutes to further demonstrate a non-linear
trend toward stabilization. I inspected four well houses and one exception was noted; the swab valve on well 1R-04 was
leaking bom the balance chamber and was repaired while I was on the pad.
Summary: I witnessed successful MIT's on CPAI's injection wells 1R-04, 1R-13, 1R-32 and 1R-33 in the Kuparuk giver
Field. Four well house inspections, one exception.
M.I.T.'s performed' _4 Number of Failures: _0 Total Time during tests: _s
Attachments: Wellbore schematics (4) ce:
MIT report form
5/12/00 L.G.
CA~NF.[~;? JUL ~) :~ 2003
2 003-053 I_M IT_KRU_ 1 R-33 ii.xls
6/19/2003
PHILLIPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANT
SSSV ~
(1802-1803,
0D:3.500)
KRU 1R-04
1 R-04
APl:
SSSV Type:
Annular Fluid:
Reference Log:
Last Tag:
Last Tag Date:
500292140700
Locked out
8229
3/1/2000
Well Type:
Orig
Completion:
Last W/O:
Ref Log Date:
TD:
Max Hole Angle:
INJ
9/18/1985
8440 ftKB
149 deg(~5200
Angle @ TS:141 de~ (~ 7823
Angle @ TD:I38 deg @ 8440
I
Rev Reason:lSleeve update by
limO
Last Update:16/9/2002
Description Size I Top I So.om I TVD I Wt I Grad.I Thread
CONDUCTOR 16.000 I 0 I 115 I 115 165.001 H40 I
SURF CASING 9.625 I 0 I 4297 I 3927 136.001 J-55 I
PROD CASING 7.000 I 0 I 8427 I 6853 I 26.00 I J-55 I
':~TUBI'NG:i?:
Thread
EUE 8RD
EUE 8RD
Comment
5" Expendable HJ II; 120
PBR
(7801-7802,
0D:3.500)
PKR
(7815-7816,
0D:6.156)
PATCH
0D:2.750)
SLEEVE-C
(7985-7986,
0D:2.750)
PKR
(8024-8025,
0D:6.156)
NIP
0D:2.875)
stI MD I TVD I Man I Man I V Mfr IvTypeI v OD I Latch I .o. I TRO I Date I
Mfr Type Run
2137291 35161 Meda I TMPD I I DMY11.o I aK IO.OOOI0 17/14/i9901
3151591 45201 Meda I TMPD I I BUY I 1.0 I BE 10.0001 0 17/14/19901
415784[ 49381 MedaI TMPD I I DMY 11.0 I BK 10.0001 0 17/1411990l
5162861 52~91 MedaITMPD I I DM?11.o IaKio.oooI0 18/26/19901
6167841 56321 Meda I TMPD I I DM? 11.0 I BK 10.0001 0 18/26/19901
717254159731 aeda I TMPD I I BUY I 1.0 I BK 10.0001 0 18/26/19901
8 177531 633SI Meda I TPDX I / DM? /1.5 IRa I0.0001 0 |4/1/2000|
9178541 64141 MedaI TMPD I ])MY/PATCI~ 1.0 I BE 10.0001 0 ~10/23/199~
Depth I TVD I Type
1802 118021 sssv
7801 I 6374 I PBR
7815 16384 I PKR
7840 16403 I PATCH
7985 16512 I NIP
8o24 16542 I PER
8039 16553 I NIP
8o47 165591 sos
..8o48 1656o I TTL
Vlv
Cmnt
Description ID
2.812
Baker 'FVL' (Locked Out 6/8/95)
Baker
Baker 'FHL'
HES RCP patch, lenth 27.45', isolating station #9 GLM - set 5/7/2000
Set 2.75" BPI SLV 4/1/00,
Baker'FB-l'
Camco 'D' Nipple NO GO.
Camco
3.000
3,000
1.370
2.750
4.000
2.250
2.441
2.441
- SLEEVE
Description I ID
SLEEVE-C BPI ISO sleeve set 4/1/2000 2.310
Comment
Note
Left Pieces in Hole
leaks (~ 7858' WLM & 7842' WLM; Ref: WSR 3/1/2000
w/23,5" X 2.79 dummy patch to 7910' WLM.
Drifted tubing w/27' x 2.473" dummy patch to 7900'
Ped
(8116-8134)
PHILLIPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
SSSV~
(1824-1825,
OD:2.875)
NIP
(7822-7823,
0D:2.875)
SBR
(7861-7862,
0D:2.875)
PKR
(788O-7881,
OD:6.156)
PERF
(8O3O-8O40,
0D:2.875)
PKR
(8O96-8O97,
0D:6.156)
NI~
(8116-8117,
0D:2.875)
TUBING
(0-8124,
OD:2.875,
ID:2.441)
Ped
(821O-8266)
Perf
(8290-8300)
Perf
(8330-8340)
KRU 1R-13
1R-13.
· .
APl: 1500292138500
Well Type: [INj
! Angle @ TS: 145~eg @ 7969
SSSV Type: I TRDP IOdg C°mpleti°n: 17/29/85 '1 Angle@ TD: 144 deg @ 8570
Annular Fluid:I Last W/O:111/10/88 Rev Reason: Ta~.fill
Reference Locj:I Ref Log Date:I Last Update: 3/7/01
Last Tag: 8303 TD: 8570 ffKB
Last Tag Date: 3/6/01 Max Ho e An§ e: 51 deg @ 6700
ICa~ing string~:ALL STRINGS :.. ::: ;:~: .',: ';: :::ii~':i :i~:.::~i~ :' :;'i .:.'::~ i::::..; :;:'.'~':i. : ":
Description {Size I Top I Bottom I T VD I Wt I Gradel Thread
SURFACE 19.6251 0 I 3~5 I 3835[36.001K-~51
PRODUCT,ON 7.000 , o , 8561 690426.00. J-~5,
. CONDUCTOR 16.000 ' 0 115 115 ~ 62.50 , H-40
.Tu_bi_gng _Strin_g_..TU Bi NG ......................
Size Top Bottom ' 'I'VD Wt Grade: -'-'i'~;ead
2.875 i 0 [ 8124 I 6591 6.50 J-55 EUE 8RD AB MOD
Perforations summ~ry . · :.'
Interval TVD
8030-8050 6525-6539
8210-8266 6652-6692
8290-8300 6709- 6716
8330-8340 6737-6744
Zone I Status I Ft !SPF Date Type Comment
C-1,UNIT B 20 12 10/17/85 IPERF 5" HJ II Csg Gun; 120 deg.
I I I I Phasing -
A-4,A-3 56 4 10/17/85 IPERF 4" HJ II Csg Gun; 90 deg.
I I I Iphasing
A-2 I I 10 ] 4 I 10/17/85 I IPERF 14" HJ II Csg Gun; 90 deg.
phasing
I I I I phas ng
Vlv
Cmnt
Other (plugs, equip., etc,
Depth I TVDI Type
8030 6525I PERF
8037 6530 I PERF
Other (plugs, equip;, etc
Depth I TVDI Type
1824 I 1824I SSSV
7822 16379I NIP
.... 7861 164071 SBR
7880 I 64201 PER
8096 165721 PER
8116 165861 NIP
8123 6591I SOS
8124 6591 TTL
- BLAST JOINTS PERFORATED.' '
Description
'Blast Joints Perforated ~ 4 SPF on 7119/87
Blast Joints Perforated (~ 2 SPF on 2/1/87
- JEWELRY · · '
Description
Camco q'RDP-1A-SSA'
Otis 'X' 2.313
Camco 'OEJ' 2.297
Camco 'HRP-I-SP' 2.340
Baker 'DB' 3.250
Camco 'D' Nipple NO GO
Camco
2.441
2.441
. .. ..
2.312
2.250
2.441
2.441
Gas Lift Mandrels/Valves . .. .
Istl MD FTVDI 'Man i Man I VMfr I Vmype IVOOlLatchl Port ITROI Date
/
Mfr Type Run
1 7806/ 6368 Merle TGPD DMY 1.5 TG 0.000 0 11/11/88
2 79151 6445 Meda I TMPD I ] DMY 1.0 I BE 0.000I 0 11/10/88
3 7982 6492 Merla TMPD I DMY 1.0 I BK 0.000 I 0 I 1'1/10/88
4 8073 6556 Mede TMPD DMY 1.0 I BK 0.000 I 0 i11110/88
ii Conoc0PhilliPs AlaSka, Inc. KRU 1 R-32
I 1R'32 .' ! · ~ ~ ~" :. .;:":'- .
APl: 500292252300 Well Type: INJ Angle @ TS: 42 deg @ 10969
SSSV Type: NIPPLE Orig 12/17/1994 Angle @ TD: 41 deg @ 11470
Completion:
NIP (532-533,"r ~ --"~1.~ Annular Fluid: Last W/O: Rev Reason: TAG FILL
0D:3.906) I:'~iii!'~ Reference Log: Ref Log Date: Last Update: 5/2312003
TUBING!~!'~! Last Tag: 11330 TD 11470 ftKB
(0-10547, Last Tag Date: 5/16/2003 Max Hole Angle: 61 deg (~ 8818
0D:3.500, Casin9 Strin9 -ALL STRINGS
ID.2.992) Description Size Top Bottom TVD Wt Grade Thread
CONDUCTOR 16.000 0 121 121 62.58 H-40
SUR. CASING 9.625 0 6423 4073 40.00 L-80
PROD. CASING 7.000 0 10709 6391 26.00 L-80
LINER 5.000 10510 11470 11470 18.00 L-80
;T~bi~:Strin;l.:!~ TUBING ':.;;:;: ;'i' i;ii;il;il :.::!ii!i;i:, ::T:; ii :.:.il i::~ i;: i ~:i!!i:? :!: :,.:i:i::i 'i:?:!i ;~,!:i?:~; !:: i;::i .~ ::: :i: :'~ ;.~ :i!...!i.:.
Gas Lift 3.500 0 10547 6274 9.30 L-80 ABM-EUE
'drel/Dummy Jf~l 'erf°rati°ns Summary ...
Valve 1 Interval TVD Zone Status Ft SPF Date Type Comment
(10436-10437, 11197 - 11237 6749 -6777 A-3 40 4 5/1/1995 IPERF 2 1/8" Enerjet; 180 deg.
OD:6.018) phasing; Oriented (+/-) 90
· ' deg.
11259- 11288 6792-6812 A-2 29 4 4/30/1995 IPEP, F 2 1/8" Enerjet; 180 deg.
phasing; Oriented (+/-) 90
deg.
Gas Lift Mandrels/Valves
Mfr Type I Run I Cmnt
NIP : 1 1104361 6196 Camco IVMVl DMY 1.5 RK 0.000 0 16129/19961
(10482-10483, ~!iill Other )lugs, equip, etc.', - JEWELRY . . ...
OD:3.500)
Depth TVD Type Description ID
iii~::l 532 531 NIP Camco 'DS' Landing Nipple 2.812
PROD.
CASING 10482 6228 NIP Otis'XN' Landing Nipple 2.750
{0-10709, 10516 6252 LOCATOR Baker 3.000
OD:7.000, 10546 6273 MULESHOE Baker(half-muleshoe) 4.000
W~26.00)
LOCATOR
0D:3.500) .
LINER
OD:5.000,
Wt18.00)
MULESHOE
(10546-10547,
Perf
(11197-11237)
(11259-11288)
NiP (480-481,
0D:3.500)
TUBING
(0-15O96,
0~3.500,
ID:2.992)
mdrel/Dummy
Valve 1
(2O69-2O7O,
0D:6.018)
SLEEVE-C
(14972-14973,
0D:3.5O0)
'conocophillips Alaska, Inc.
KRU
I R-33
-- 1R-33 · .:.
APl: 1500292252900
SSSV Type:I Nipple
Annular Fluid:I
Reference Log:J
Last Tag:115294
Last Tag Date:J2/24/2003
' Well Type:J INJ
Orig [ 12/30/1994
Completion:I
Last W/O:I
Ref Log Date:I
TD:~ 15520 ftKB
Max Hole Angle:174 deg (~ 4571
Angle @ TS: 148 deg (~ 14912
Angle @ TD:I47 deg @ 15530
I
Rev Reason:lTag Fill
Last Update:13/11/2003
Description Size Top Bottom I TVa I Wt I Orade I Thread
CONDUCTOR 16.000 0 121 I 121 I62.50 I H-40 I
SUR. CASING 9.625 0 7669 I 4081 14o.ool L-SO I
PROD. CASING 7.000 0 15062 I 662( 126.001 L-SO I
LINER 5.000 15062 15520 I 1552) I 18.00 I L-80 J
3.500 0 15096 6649 I 9.30 I L-80 I EUE8RABM
i'n'terval ...... TVD .... I Zone 1Status I Ft ISPFI Date I Tyl:)e I Comment
15132-15165 6673-6696I A-3 I I 33 I 4 13/28/199511PERF 133/8" HSDTBGCONV;
I I I I I I 1180deg. ph; Orientl65deg.
I I I I I I ICCWF/High Side
15186-15212 6710-6728I A-2 I 1261 4 13/28/199511PERFI33/8"HSDTBGCONV;
I I I I I I 1180deg, ph; Orient165 deg.
I .. I I I I I Iccw F/High Side
VIv
Cmnt
PKR
(15O18-15O19.
0D:6,156)
lOth, er (plugs~ equip.p etc.I
Depth/TVD I Type I
I48014801NIP
I 14972 16565 I SLEEVE-C
1 1501816596 1 PER
I 1509416647 I SOS
I 150961 6649 I TTL
IFish - FISH ·"
Depth I Description
15302 1128' SpentTbg PerfGuns in
I
Rathole
- JEWELRY . .
Description ID
2.812
Camco 'DS' Landing Nipple NO GO
Baker ~CMU' Sliding w/Camco 'D' Profile
Baker 'FB-I'
XSAR Schlumberger
3.5" Tubing
2.750
3.000
2.992
2.992
Comment
Perf on 3/28/95 (SWS 3 3/8" HSD)
SOS
(15094-15095,
0D:3.500)
Tn.
(15096-15097,
0D:3.5O0}
Perf
(15132-15165)
Perf
(15186-15212)
PERMIT
9 b,. ,..- i 56 C D R / F :r, N A L
~ ? 00-.~ 'i 5500
Ai-".e dr'y d~'tch sarnpies r'equ~'r"ed? yes
. 'v'
Was 'the wei'i cot"ed? yes ~___~,na'iys'¥s & descr"i:pt'ion r"ec:::i'v:::<l
C C' i~'i i~"i E N T S
R e c e '¥ v e d ? y ~c.-m n o
No. 10230
COMPANY ·
LOCATION ·
ATTENTION ·
SCHLUMBERGER GEOQUEST
INTERPRETATION AND COMPUTING SERVICES
500 W. INTERNATIONAL AIRPORT ROAD
ANCHORAGE, ALASKA 99518
AK OIL & GAS CONN COMM DATE :
3001 PORCUPINE DR.
BLAIR WANZELL
1R-33 WELL NAME :
I BL OF CBL-SLT-J,GR SERVICES :
i NO. OF BOXES:
'-' JOB NO. :
--- ADD'L TAPES :
JUNE 6, 1996
WELLNAME ·
SERVICES ·
NO. OF BOXES:
JOB NO. ·
ADD'L TAPES ·
WELL NAME ·
SERVICES ·
WELL NAME ·
SERVICES ·
NO. OF BOXES:
JOB NO. ·
ADD'L TAPES ·
NO. OF BOXES:
JOB NO. ·
ADD'L TAPES ·
WELL NAME
SERVICES
NO. OF BOXES:
JOB NO. ·
ADD'L TAPES ·
SCHLUMBERGER COURIER:
DATE DELIVERED:
WELL NAME ·
SERVICES ·
NO. OF BOXES:
JOB NO. ·
ADD'L TAPES
EL, E! V EIJ
JUN O 7 1996
Alaska 011 & Gas Cons. Commission
.RCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
June 5, 1995
Mr. David J. Johnston
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject: 1R-33(Permit No. 94-156) Well Completion Report
Dear Mr. Commissioner:
Enclosed is the well completion report for the recent operations on KRU 1R-
33.
Sincerely,
M. Zanghi ~)
Kuparuk Drillsite Development Supervisor
MZ/skad
RECEIVED
dUN -'t' 1995
0il & Gas Cons. Commission
Anchors.,
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION CO~',
WELL COMPLETION OR RECOMPLETION REPORi'(,~ND/tDG
ztus of Well Classification of serVlde
OIL [~] GAS ~ SUSPENDED r'--] ABANDONED [] SERVICE r~ Classification changed to: WAG injector
2 Name of Operator 7 Permit Number
ARCO Alaska, Inc 94-156
3 Address 8 APl Number
P.O. Box 100360, Anchorage, AK 99510-0360 ~~ 50-029-22529
9 Uniter Lease Name
4 Location of well at surface i '"~..;.~.(: - . ,.-:
' ~- ~"~:?-~; ~ KuparukRiver Unit
653'FSL, 214'FEL, Sec. 18, T12N, R10E, UM I "'""::..-.: i ~-~-'~'J/~ g lO WellNumber
At Top Producing Interval i~/~__i
AtTotal Depthi, ~ %'"~'~./ "~ 11 Field and Pool
2429' FSL, 1281' FWL, Sec. 6, T12N, R10E, UM ....... '~' ~"'--'~'~'?'~"">'~'~ KUPARUK RIVER
5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No.
RKB 86' 45' pad ADL 25628 ALK 2561
12 Date Spudded18-Dec-94 13 Date T.D. Reached28_Dec_94 14 Date Comp. , Susp. or Aband.3/29/1995 (Comp) I15 water Depth' If OffshOreNA feet MSL[16 No. of Completions1
17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set'1 21 Thickness of permafrost
15530' M D & 6946' TVD 15425' MD & 6874' TVD YES X~J NO L.JI NA feet MD[ 1570' APPROX
22 Type Electric or Other Logs Run
GR/CDR/DWOB(MEL), CCL/SLT-J(cbl)
23 CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT GRADE TOP B-rM HOLE SIZE CEMENT RECORD
16. 62.5" H-40 Surf 121 24 265 sx AS I
9.625 40" L-80 Surf 7669 12.25 1520 sx AS III lead, 950 sx Class G tail
7 x 5 26"/18" L-80 Surf 15520 8.5 360 sx Class G Tail
24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
3-1/2", 9.3#, L-SO 15096' in casin~, seal bore
extension @ 15021'
4 spf 15186'- 15212' MD 6710'- 6728'-I-VD 26 ACID, FRACTURE, CEMENT SQUEEZE, FTC
4 spf 15132' - 15165' MD 6674' - 6696' -I-VD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
NONE
27 PRODUCTION TEST
Date First Production IMethod of Operation (Flowing, gas lift, etc.)
I
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO
TEST PERIOD I~
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr)
Press. 24-HOUR RATE
28 CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
RECEIVED
JU~ -7 1995
Al~sk~ 0il & Gas Cons. C0mmissior,
Anchor?
Form 10-407 Submil in duplicate
Rev. 7-1-80 ~INUED ON REVERSE SIDE
30.
GEOLOGIC MARKERS FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Kuparuk C 1491 2 6525
Base Kuparuk C 14976 6568
Top Kuparuk A 15106 6656
Base Kuparuk A 1 5293 6784
RECEIVED
J~JN -7 1995
A!~sk~ 0il & Gas Cons. Commission
Anch0~ ~
~1. LIST OF A'FI'ACHMENT$
32. I hereby cedify that the foregoing is true ~nd corcect to the best of my knowlege.
INSTRUCTIONS
General' This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23' Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
_CO ALASKA INC.
DAILY OPERATIONS
PAGE 1
WELL:
BOROUGH:
UNIT:
FIELD:
LEASE:
API:
PERMIT:
APPROVAL:
1R-33
NORTH SLOPE BOROUGH
KUPARUK RIVER
KUPARUK RIVER
ADL 25628 ALK 2561
50-029-22529
94-156
ACCEPT:
SPUD:
RELEASE:
OPERATION:
DRLG RIG:
WO/C RIG:
12-17-94
12-18-94
12-30-94
10:00
17:30
12:00
PARKER 245
12-18-94 (1)
PARKER 245
TD: 1567 (1446)
12-19-94 (2)
PARKER
TD: 5670 (4103)
12-20-94 (3)
PARKER
TD: 6840 (1170)
12-21-94 (4)
PARKER
TD: 7692' (852')
12-22-94 (5)
PARKER
TD: 7692'(0)
DRILLING SURFACE HOLE
16"@80'GL MW: 9.5 VIS:44 CUM:$92,333
ACCEPT RIG AT 1000 HRS. 12/18/94. ROUND THE CORNER MOVE FROM 1R32 TO 1R33
IN 9 HRS. NU DIVERTER SYSTEM, MIX MUD AND PREPARE TO SPUD. FUNCTION TEST
DIVERTER SYSTEM AND FILL HOLE WITH MUD. PU BHA AND ORIENT TOOLS. DRILL
OUT CEMENT AND DRILL 12-1/4" HOLE F/121' T/737'. DRILL 12-1/4" HOLE F/737'
T/1567'
DRLG SURFACE HOLE
16" @80'GL MW:10.0 VIS: 52 CUM:$171,031
DRILL 12-1/4" HOLE F/1567' T/2792'. RIG SERVICE. DRILL 12-1/4" HOLE F/2792'
T/4900'. DRILL 12-1/4" HOLE F/4900' T/5670'.
DRLG SURFACE HOLE
16"@80'GL MW:10 VIS:45 CUM:$260,624
DRILL 12-1/4" HOLE F/5670' T/5989'. CBU. POOH TO CO BIT. TIGHT SPOT AT 2200'
TO 1800' - SWABBING, WORK THROUGH TIGHT SPOT. SERVICE RIG. RIH W/BIT #2.
DRILL 12-1/4" HOLE F/5989' T/6337'. DRILL 12-1/4" HOLE F/6337' T/6840'.
R/U TO RUN CASING
16"@ 80' GL MW:10.2 VIS 42 CUM:$342,544
DRILL 12.25" HOLE FROM 6840' TO 7440', ADT--4.31, 139.2FPH. SERVICE RIG. DRILL
12.25" HOLE FROM 7440' TO 7692'TD, ADT=I.61, 156.5 FPH. CIRC BOTTOMS UP.
SHORT TRIP FROM 7692' TO 4500'. NO TIGHT SPOTS, NO PROBLEMS. CIRC. AND COND.
FOR CASING. HAD 300 BBLS GAS AND OIL CUT MUD, WT. CUT TO 9.1 PPG. INCREASED
WT. FROM 10 PPG TO 10.2 PPG. WEST SAK ANN. VOL. +/- 213 BBLS. DROP SURVEY,
PUMP PILL. POOH, TIGHT HOLE FROM 2607' TO 1670', WORK PIPE AND PULL SLOW
TO PREVENT SWABBING. RETRIEVE SURVEY AT HWDP. LAY DOWN MOTOR AND MWD.
SLIP AND CUT DRILL LINE 91'. RIG UP TO RUN 9.625' CASING.
RUNNING CASING
16"@80'GL MW: 10.2 VIS:44 CUM:$574,221
PRE-JOB SAFETY MEETING. RAN 7 JTS. CASING, SLIPS JUMPED OPEN AND DROPPED
CASING. RIG DOWN CASING EQUIPMENT. INSPECT SLIPS, WEAR IN SET-RELEASE
MECHANISM, POSS. AIR VALVE MALFUNCTION. WAIT ON FISHING TOOLS. MAKE UP
SPEAR AND FISHING ASSEMBLY, RIH. TAGGED TOP FISH AND PUSHED 30' TO 1511',
BOTFOM AT 1809'. PICKED UP AND HAD FISH. POOH AND LAY DOWN FISHING TOOL[
LAY DOWN 7 JTS. CASING, PULLED WET, FLOAT COLLAR PLUGGED W1TH CIJ'YFINGS.
gnchor~- .
WELL: 1R-33
API: 50-029-22529
PERMIT: 94-156
CONTINUED FROM DAY 5
12-23-94 (6)
PARKER
TD: 7692'(0)
12-24-94 (7)
PARKER
TD: 10635'(2933')
12-25-94 (8)
PARKER
TD: 12640' ( 2005')
12-26-94 (9)
PARKER
TD: 13254' (614')
gnchorz"
12-27-94 (10)
PARKER
TD: 14,745' (1490')
PAGE 2
RIG UP TO RUN CASING. HELD PRE-JOB SAFETY MEETING. RUN 9.625" CASING TO
2364'. CIRC. HOLE CLEAN AT 2364'. RUN 9.625" CASING TO 4961'. CIRC. HOLE CLEAb
AT 4961'. RUNNING CASING, 10 JTS OFF BOTI"OM, NO PROBLEMS.
DRILLING CEMENT
9.625" @7669' MW: 8.5 VIS:31 CUM:$746,880
RUN 9.625" CASING TO 7669'. SEE CASING DETAIL FOR ADDITIONAL INFO. RIG UP
CEMENT HEAD. CIRC. AND CONDITION MUD. CEMENT CASING, CIP AT 1306 HRS.
12/22/94. SEE CEMENT DETAIL FOR ADDITIONAL INFO. NIPPLE DOWN DIVERTER.
PERFORM TOP JOB WITH 250 SX. AS 3 CEMENT, 12.1 PPG RETURNS TO SURFACE, CIP
AT 1613 HRS. MAKE UP SPEED HEAD AND NIPPLE UP 13 5/8" BOPE. TEST BOPE TO
300/3000 PSI, SEE AOGCC TEST REPORT. BOB FOSTER (AOGCC) WAIVED WITNESS OF
TEST. SET WEAR BUSHING. PICK UP, BREAKDOWN AND LAY DOWN FISHING TOOLS.
MAKE UP BHA 3 AND RUN IN HOLE TO FLOAT COLLAR AT 7589'. CIRC. TEST CASING
TO 2000 PSI FOR 30 MINUTES. DRILL OUT FLOAT COLLAR.
DRILLING
9.625" @7,669' MW: 8.9 VIS:34 CUM:$824491
DRILL CMT. AND SHOE AT 7669'. DRILL 10' NEW HOLE TO 7702'. CIRCULATE HOLE
CLEAN. PERFORM FIT TO 12.5 PPG EMW. DIRECTIONAL DRILL 8.5" HOLE FROM 7702'
TO 8318'. SERVICE TOP DRIVE. DIRECTIONAL DRILL 8.5" HOLE FROM 8318' TO 9818'.
DIRECTIONAL DRILL 8.5" HOLE FROM 9818' TO 10635'.
DRILLING
9.625" @7669' MW: 9.1 VIS:38 CUM:$906,398
DIRECTIONAL DRILL 8.5" HOLE FROM 10635' TO 10849'. CIRC. BO'ITOMS UP. SHORT
TRIP TO SHOE AT 7669'. NO TIGHT SPOTS. SERVICE TOP DRIVE. RUN IN HOLE.
DIRECTIONAL DRILL 8.5" HOLE FROM 10849' TO 11,440'. REPAIR 2 MUD PUMPS, ONE
SWAB AND ONE VALVE. DIRECTIONAL DRILL 8.5" HOLE FROM 11,440' TO 12,102'.
DIRECTIONAL DRILL 8.5" HOLE FROM 12,102' TO 12,640'.
RIH AND CHECK SHOT MWD.
9.625" @7669' MW: 9.0 VIS: 48 CUM:$1006,946
DIRECTIONAL DRILL 8.5" HOLE FROM 12,640' TO 13166'. CLUSTER SHOT MWD TO
CHECK REPEATABILITY. DIRECTIONAL DRILL 8.5" HOLE FROM 13166' TO 13255'.
CIRCULATE BOTTOMS UP. POOH. CHECK SHOT SURVEYS AT 12085' AND 11,875',
INDICATE PROBABLE LOOSE WIRE IN MWD RESULTING IN INTERMITTENT
REPEATABILITY. POOH. HOLE IN GOOD SHAPE. LAY DOWN MWD, DOWN LOAD LWD
AND CHANGE BIT. PICK UP FRESH MWD, ORIENT, P/U STAB, TEST MWD AND RIZI TO
SHOE AT 7669'. FILL @ 4000'. SLIP AND CUT DRILL LINE, SERVICE TOP DRIVE AND
SET CROWN-O-MATIC. TIH, CHECK SURVEY @7940', 12337', 12520', 12705', 12892'.
CASED HOLE LOGS COMPLETE ON 1R-32, TREE NIPPLED UP.
DRILLING
9.625" @7669' MW:10.5 VIS: 45 CUM:$1006,946
CHECK SHOTS WITH MWD. DIRECTIONAL DRILL 8.5" HOLE FROM 13,255' TO 14,745'.
WELL: 1R-33
API: 50-029-22529
PERMIT: 94-156
PAGE 3
12-28-94 (11)
PARKER
TD: 15530' (785')
12-29-94 (12)
PARKER
TD: 15530'(0)
12-30-94 (13)
PARKER
TD: 15530' (0) 1
12-31-94 (14)
PARKER
TD: 15520' (0)
CIRCULATING
9.625"@7669' MW:10.9 VIS: 48 CUM: $1210,745
DRLD F/14745 T/14995. DRLD F/14995 T/15035. MONITOR WELL AFl'ER DRILLING
BREAK. WELL FLOWING. SHUT IN WELL. SICP=50, SIDPP=0. CIRC. THROUGH CHOKE
(NO BACK PRESSURE). RAISE MUD WT TO 10.7. WELL OK. DRLD F/15035 T/15511.
DRLD F/15511 T/15530. RAISE MUD WT TO 10.9. CBU. SHORT TRIP T/13150'. CIRC &
COND. MUD.
RUNNING 7" CASING
9.625" @7669' MW:ll.0 VIS: 55 CUM:$1,284,12'
DROP SS SURVEY. PUMP DOWN 25 MIN. POOH. PUMP OUT 1ST 10 STDS. PUMP PILL.
CONT. POOH. LD S-135 DP. RIH W/1ST 10 STDS. CONT. POOH. LD S~135 DP. RACK G IN
DERRICK. LD BHA. SSS=71 DEG. RU TO RUN 5" CSG. HELD SAFETY MEETING. RUN 10 J'I
5", 18#, L-80, LTC, R-3 CASING. RU TO RUN 7" CSG. RUN 7", 26#,L-80, BTC-MOD, R-3
CASING. BREAK CIRC @ 3200'. CONT. RUNNING 7" CSG. CBU @ 9 5/8" CASING SHOE.
CONT. RUNN1NG 7" CSG. BREAK CIRC. @ 10000'.
PREPARING TO MOVE TO 1R-34 7X5"@15,520' MW: 10.8 VIS: 48 CUM:$1544,836
CONT. TO RUN 7", 26#, L-80, BTC-MOD, R-3 CASING. BREAK CIRC. @ 12037'. CONT. T(
RUN 7", 26#,L-80, BTC-MOD, R-3 CASING. BREAKING CIRC @ 14100'. RU CMT HEAD
AND C&C MUD. AT 1 BPM, HOLE TAKING FLUID AT RATE OF 1 BBL/2.5 MIN. CIRC
AND CLEAN UP HOLE. INCREASE RATE TO 3 BPM. TOTAL FLUID LOSS = APPROX 300
BBLS. CIRC 6000 STROKES TO CLEAR 1 CASING VOLUME. RU D/S AND CEMENT CASIN(
WITH 20 BBLS PREFLUSH, 50 BBLS SPACER @ 13#, AND 73 BBLS OF CLASS G LATEX
CEMENT WITH ADDITIVES. DISPLACED WELL WITH 505 BBLS FSW & 77 BBLS DIESEL
CIP @2100 HRS. DID NOT BUMP PLUG. WHILE CEMENTING WELL TOOK 400 BBLS.
MONITORED MUD FLOW BACK THROUGH BOPE. WELL FLOWED BACK APPROX. 200+
BBLS. ND CMT EQUIP. ND STACK. SET SLIPS. CUT OFF CASING. INSTALL PACK-OFF
AND TEST TO 3000PSI F/15 MIN. INJECT 300 BBLS OF WATER @ 10 BPM @ 1650 PSI
DOWN ANNULUS. PREPARING TO DISPLACE ANNULUS WITH DIESEL. LDS ON TBG
ADAPTER TO RKB = 36.5'.
MOVED TO 1R-34.
7X5"@15,520' MW: VIS: CUM: $1603,477
INJECT 70 BBLS OF DIESEL @ 2.5 BPM @ 1000 PSI DOWN ANNULUS. BLOW DOWN LINI
LDDP FROM DERRICK. LEFT 70 STDS IN DERRICK WHILE MOVING. RDMO.
_~: 05/30/95
ge: 1
ARCO Alaska Inc.
DAILY DRILLING REPORT
REMEDIAL AND COMPLETION OPERATIONS
WELL: 1R-33
WELLID: AK8055
AREA/CNTY:
FIELD:
SPUD:
RIG:NORDIC WI: 0% SECURITY:0
AFE: AK8055' TYPE:DEV AFE EST:$ 2042M/ 2750M
STATE: API NUlVZBER:
START COMP: FINAL:
03/20/95 ( 1)
TD:15530'
PB:15425'
SUPV:CO-F
PU 3-1/2" DP MW:
Accept rig 0830 3/19/95. Test BOPE. RIH with bit and
3-1/2" DP.
DAILY: $40,810 CUM: $15,425 ETD:SO
EFC: $2,120,319
03/21/95 (2)
TD:15530'
PB:15425'
SUPV:CJF
03/22/95 (3)
TD:15530'
PB:15425'
SUPV:Cd-F
03/23/95 (4)
TD:15530'
PB:15425'
SUPV:Cd-F
03/24/95 (5)
TD:15530'
PB:15416'
SUPV:CJF
03/25/95 (6)
TD:15530'
PB:15416'
SUPV:CJF
03/26/95 (7)
TD:15530'
PB:15416'
SUPV:CJF
03/27/95 (8)
TD:15530'
PB:15416'
SUPV:CJF
POH W/6-1/8" BIT MW: 8.6 SEAWATER
RIH w/bit & BHA on 3-1/2" DP. Drill cement f/14921' to
7"x4" crossover @ 15021'. POH w/3-1/2" DP.
DAILY:S37,709 CUM:$78,519 ETD:SO EFC:$2,120,319
DRILLING CEMENT @ 15205' MW: 8.6 SEAWATER
RIH w/3.9" round bottom mill on D350HF motor on 3-1/8" DC.
RIH w/3.9" mill on 3-1/2" DP.
DAILY:S34,293 CUM:$112,812 ETD:SO EFC:$2,154,612
WASHING & REAMING THRU 5" CASING MW: 8.6 SEAWATER
Drill cement f/15205-15415. Pressure test 7"x5" csg.
Set down on 7"x5" X-O @ 15026'..
DAILY:S33,426 CUM:$15,425 ETD:SO EFC:$2,154,612
POH WITH 3.9 MILL & MOTOR MW: 8.6 SEAWATER
Continue RIH w/3-1/2" DP.
DAILY:S33,921 CUM:$180,159 ETD:SO EFC:$2,221,959
REVERSE CIRC IN 5" CSG @ 15100' MW: 8.6 SEAWATER
Test BOPE. RIH w/2-7/8" tbg. Reverse circ seawater @ 15000'
DAILY:S30,700 CUM:$210,859 ETD:SO
EFC: $2,221,959
LAYING DOWN 2-7/8" TBG MW: 8.6 SEAWATER
Stage into 5" csg f/15100'-15405'. RU SWS to log. POH
w/3-1/2" DP & 2-7/8" tbg.
DAILY:S64,262 CUM:$275,121 ETD:SO
EFC: $2,316,921
POH LAYING DOWN 3-1/2" DP MW:
RIH w/Baker Pkr. POH laying down 3-1/2" DP.
,IUill - '{ 1995
Oil & Gas Cons. Commission
A,~chor~.,
.8/95 (9)
.15530'
~:15416'
SUPV:CJF
DAILY: $30,700 CUM: $305,821 ETD:SO EFC: $2,386,316
RACK, STRAP, & TALLY 3-1/2" TBG MW: 8.6 SEAWATER
RIH w/ perf ass'y below Baker locator seal ass'y on 3-1/2"
tbg.
DAILY:S38,695 CUM:$344,516 ETD:SO
EFC: $2,386,316
03/29/95 (10)
TD:15530'
PB:15416'
SUPV:DB
RIG RELEASED MW: 0.0 DIESEL
Continue running 3-1/2" completion assembly.RU lubricator &
set BPV. Rig released 0500 hrs 3/29/95
DAILY:S227,987 CUM:$572,503 ETD:SO
EFC: $2,614,303
End of WellSummary for Well:AK8055
ECE!VED
A!aska Oil & Gas Cons. Csmmission
Anchor:
*~***~** SLRVEY PROGRAM
~MP~Y ARCO A~SB~4
~L~ NAME 1R-33
LOCATION i I(UPARUI(
kOCA?tON 2 ~AS~
M~N~tC D~C~INATION 28,80
GRID CO~NC~ ~L~ 0,00
WE~ NUMB~ 0
WELL HEAD LOCATION: LAT(R/-S) 0o00
AZI~.~H FROM ROTA~:Y TABLE TO TARGET IS
TIE IH POINT(TIP) :
MEASLRED DEPTH 121,00
TRUE VERT DB'TH 121,00
INCLINATION 0.00
AZIMUTH 0~00
LATITUDE(N/-S) O,C<~
DEF~RTL~E(E/-W) 0~00
DEP(E/-W) 0,00
345,24
MEASURED INTHR~ VERTICAL
DEPTH DEPTit
ft ft ft
!.-21,00 0,0 121
167,00 46,0 1,.47-: (~O
2~ o~. !17.9 284,?2
379,88 95.0 ~vo
· . -~.:/,
470,05 90,2 46%86
T~R'GET =,~TIuN AZIMUTH LATITUDE
S ~ T~
E~T~UN iNCLN, N/-S
ft deg deg ft
0,00 0,00 0,00 0,00
0,00 0, er,..:, ' 0,00 0,00
O,'P~ 0,96 344,95 0,95
3,89 2,56 ~sn ~
8,62 3,58 0,~"~ 8,61
DEPARTURE DISPLACEMEb~ at AZII~JTH
E/-W
ft ft deg
0.00 0,00 0,00
0,00 0,00 0,00
-0,26 0.97 344,95
-0,81 3,90 348,01
-1.12 8,69 352.56
DLS
deg/
lOOft
0,00
0,00
0~1
1,69
!,27
557,3!
o~1,78
741.6!
89.3 ~8,88
92,5 650,93
89.8 ~ ~
91,0 830,12
'~,6 919,27
!4,90 4,76 359,49 15~I! -1,i4 15,15 355,69 1,32
23,44 6,19 n,30 23,93 51,15 ~ '^
~ ~3,Y. 357~26 1,55
o4,oo 357,38 1,54
33,86 7,46 ~' ~= ~ '~
46,82 9,19 355,06 47,71 -2,68 47~79 356,79 1,9I
62,84 11,43 ~,.~=~ ~' 6~.8s_ .. -4,33 A3,9~. .. 356,122,49
!012,60
1!03,48
1197,17
i387,57
89,4 I006,69
90,9 1~5,17
93,7 1186,03
94,7 1~77,34
7~,/ 1368,87
8!,48 12,78 348,84 82,35
102,21 13,66 349,76 102,77..
~..,~ 14,~o 350,96 125,29
149,86 16,10 351,22 150,02
177.80 !7,99 ~=~ ^'
o~,vo 177,71
-7,25 ~,~,o7 354,77 !,85
-1!,1! 103,37 ~.~,°~ 83 1,00
-14,93 126.17 353,21 1,0!
-18,80 151,17 352,86 1,63
-23.38 179,24 35~,51
!48!,20
!576,14
1670,90
1764,85
207,03 18,57 350,79 Z~6.65
238,96 20.90 350.10 238,27
.. o - 348, 272
273,AA 2~,1/ 11 ,41
310,07 23,48 347,02 307.99
349,52 26,83 347.64 346,5!
-28,26 208,58 352,21
-33,59 240~62 351.77
-40,17 275,36 351,Sl
-48,04 311,72 351.13
-56,67 35!,12 350,71
0,67
2,47
1,54
1,47
3,61
175!,17
2044,68
2140,!2
~ ,~-1
~,5.~ 1888,27
o~,~,5 !968,71
~,4 2048.90
94.9 2126,18
?3,4 21~7,51
393..M ~" '~
~Y.;, 346.96 389.58
441.~ 31,71 346.82 435~96
492.97 33.95 ~,~"'. ~. ~8A.45. .
547 "~
,y; 36,~;"'= 346,~ 5~12
A~ ~ '~ ~ ' 9
~46.',4. 5Yo,45
..u5+83
%6,40 375,20 350,~°.:., 2,,.
-77,21 442,77 349,96 2,29
-88,59 494,45 349,68
-I00,67 549,43 349,44 3,21
-!14,07 607,26 349~17 2,89
2421,44
25!6,82
~'~ 72
2705.08
93,0 2269,60
95,4 2338,09
93,9 2402.&
94,4 2463,01
'~,i 2521,37
666,93 42,53 346,62 655~88
4~,o6 345,90 720,34
733,28 ~ '
802,~) 48,43 344,46 7&6,76
874,02 51,13 343,73 856,04
949,02 53,14 342,33 ~ ~27,83
-128,32 668,32 348,93 3,i2
-!44,07 734o61 348,69 3,32
-161,67 803,2! 348,39 3,15
-181,44 875,06 348.03
-203,36 949,86 347,64 2,41
~ &,',~ 7~
2987,71
3078,41
3174,7!
93,6 ,.5/..:-, ~ P.,
73,9 2626,03
90,7 2669,81
7
76,3 Z i2.8,,
91,1 ~'' 37
1025,i6 55,80 345,10 1000,75
1104,4~. ~z,~U~" =~346,2~ 1077,81
!183,71 62,78 344,6? ti54,68
1270,06 64,i6 344,05 1237~65
t352,62 65,82 342,93 1316,84
-224,69 1025,86 347,35
-244,33 1105,15 347,23
-264,29 1184,54 347,11
-287,51 1270.61 346,72
-311,00 1353+06 346,71
3,7I
4,07
3.?1
1,55
2,14
~58,73
0,-,'..-,/-..3
3637,'~-'6
3823,25
4105,14
92.9 2787.07
92.0 28!8,99
187.2 2877.50
185,3 ~o~ 49
~1,9 3~12o50
,4~8.:Y 68,rs 343,53 1398+92
1524,54 70+44 '344,22 i481,80
1702,35 73,14 344,10 1652+89
1879+54 72.99 343,50 1823,10
2149,46 73,61 344 ~ ~ =
,,o 208~.~8
-335,73 1438,64 346,50
...: 4,8~ ,,4. ,3,5
-359,68 ~.~. o
-408,22 1702,55 346,13
-4~,o/ 1879,67
~°~ ~ 2149,~ ,66
-_,~,-,.., _,,- 345
3,43
1,76
1,44
0,32
0,39
~*******~.**** ANAl}RILL **..~***~*~.**
SUF, gEY
C~,.~ ~ !ONo
***.**~****** CIRCLn. AR ARC METHOD*~*~.
MEASURED INTER~AL '.,~.R'.
DEPTH DE?TH
ft ft ft
.':'u .... _:. 185.5 _ ._
4570,88 .'8,;,= o14/
4851,16 280,3 3227,38
"'.'1" -"-' 282,4 -~-~n
s.~23,21 189,A ~o6~, 10
~ STATt~ AZI~]TH ~TtTL~
SEC?I~ INC~. N/-S
ft deg deg ft
~o..,~o 72,57 344,47 2~o,~/
2594.7! 73,85 35!,47 2515,78
2862.43 73,05 348.40 2780.27
3i32,09 ,a,~. 346,55 3043,71
33!2,77 72,CE~ 345,74 3219~16
DEPARTUR~ DISPL~EMENT at
~/-W
ft ft
-579,82 2326.96
-..~,.~ 2594,84
-.oc,2/ 2862,83
-741,10 3132,"
-784,38 33i3,34
AZ!NUTH
deo
.
3~ ~
,~7
345,82
348,2!
346,32
34~,31
DLS
de0/
10Oft
0,56
2,44
1',09
0,64
0,54
5601,09
6!57~12
~527,90
277,9 3457.97
Z97,1 3545.87
'~" 3628,27
,./8,9
185...5 3484,87
~ ~J ~,"f. -1 : ·
lS.o.~_ ..v 4~,~7
3~/J,61 70,26 347,87 3475,03
3838,20 72,75 347,S~ 3731,58
4104,61 /z,8~ 343,82 ~89,~8
4281,2i 71,59 343,12 '~ ''~
~"=? ~ 72,50 ~"~ ~
.~/,oo o.o,.~ 4327,77
~=~ oa 346,,34
-844,87 o¢/o,~.
-901,82 3839,01 346,41
-968,25 4105,39 346,36
-1018,5! 4281,87 346,24
-1069,10 4457,86 34.5,!2
0,91
0,91
1,19
0,79
0,53
67i5,87
6908,i7
7901,39
7277,64
7~3,38
168~0
186,3 ~ye.5,24
185,~
463.6,58 72,60 343,84 4499,86
... /.,o. 345,06 ~,76,61
5172,64 71,70 345,84 5018,19
5349,77 73,34 346,28 5190~13
-1119,49 4,537,02 346,03
-1168,67 4820,42 345,97
-1212,70 4995,48 345,95
-i256,!9 5173,03 345,95
-t298,86 5350,18 345,95
0,17
0.60
0,51
0,77
0,91
7603,41
7847,9!
8034,78
82!9,05
8407,38
140,0 4062,29
244,5 4i32,82
'nA ~
~o.,. 4186,77
184.3 4239,29
188,3
5483,84 73,24 347,19 5320,66
57t7,89 73,22 345,64 5548,21
5896.8! 73.22 345,50 ~21,48
6073,42 73,67 343,77 5891.79
6253,89 73,i8 344.,79 &%5,54
-1329,63 5484,28 345.97
-1384,62 ~18,38 345,99
~ = 97
-1429,22 5897,29 ~42+.
-1476,02 6073,86 345,94
~s~ ol A254.29 345~89
0,61
0.07
0,93
0,54
8500,79
8688,31
8875,88
9063,26
92_50,88
.930,4 43!9,62
187,5 4373,59
187,6 4429,~B
187,4 4484,98
187,6 4539,96
6343,42 73,73 343,90 6151,76
6522,98 72,81 345,41 ~24,92
670!,98 72,'46 346.62 6498.63
A "7 A' ~
.880, y. 73,15 345,21 6./2,z5
7060,34 72,77 346,25 6846,10
-1549,08 6343,80 345,87
-!596,61 6523,33 345,83
-t639,88 6702,35 345,84
-16&3,45 6881.35 345.84
-1727,66 7060,73 345,84
1,09
0,9!
0,64
0,80
0,56
9441,36
9630,00
9819,86
10~X)6,94
10282,79
190,5 4594,83
188,6 4.44,8,19
t89,9 4703,65
4700,<.,
187.~i
275,8 484..,,."3
7242,71 73.74 ~4,.,70 7023,44
7423,62 ?~ ~n
,~,~ 345,17 7198. y.;'=
.,~,~ 72.63 345,14 7374,47
77~3,51 72,14 ~..,~ 7546,69
8045,81 71,98 342,32 - .'77/98,40
-1770,31 7243,12 345,85
-1814,27 7424,05 345,85
-1860.79 7605,62 345,84
-1906,99 7783,90 345,82
-1981,18 8046.,12 345,,"5_
0,56
0,80
0,41
0,30
0,87
!0473,t5
10659,62
10847,01
11O31,32
190,4 4904.69
186,5 4962,09
94,¥ ~0~8,40
184,~ 5074,~0
8226,52 71.62 343,89 7971,43
8403,87 72,51 343,55 8141,73
8492,14 72,/'7 343,47 8~6,40
8582,54 72,01 345,73 8313,56
8,~,08 72,62 347,37 8484,34
-2033,73 8226,77 345,69
-2083.47 8404,08 345,65
-2108,54 8492,33 345,62
-2132,~ 8582,72 345,61
-2173,38 8758,29 345,63
0,80
0,51
0,29
2,41
0,91
11221,47
11409,24
11593,98
1!78!,19
11966.03
!90,2 513t,01
t87,8 5187,36
184,7 5244,23
187,2 5302,79
184,8 =~s,', =~
,0/ /z./; 345,49 8660,80
9118,67 72,32 344,06 8833.63
9294,34 71.82 342,53 9001,97
9472,01 71,72 343,61 9172,07
,~./,u= 72,40 344,30 9341,o7
-2215,% 8939,79 ,_4.o,.65
-2262,99 9118,89 345,63
-2313,51 9294,51 345,59
-2365,28 9472, !4 345,54
-2413,88 9647,~'"'" 345,51
0,9'5
0,76
0,83
0,55
0,5!
******~****** ANADRILT.
SURVEY CALCU~T!ONS
MEASURED
D~'TH
ft
1,.:-~o/,81
12705.7?
12892,33
IN%RVAL b~:T!CAL TARGET STATION AZIMUTH ~TtTUDE
DEF?H S~CTtON t~LN, N/-S
f~ f~ f~ deg deg f~
!89,4 54t7,73 9828,00 7!,93 343,09 9514,08
182,4 5474.97 10001.i1 71,49 343,4! 9679.94
I~2,0_ . s=~2.~o-,..s'~ _~..~n~7~,46~7!,64 340,71 7844,24
i86.0 ~92.48 10349.29 70.74 343,48 10011,89
186.5 5653.24 10525,60 7!.24 3~,04 10181,22
DE'ARTURE DISF'LACEMENT at AZIMUTH DLS
E/-W deq/
fr fr deg 10Ors
-2464,46 ?828,09 345,48
-2514,41 10001,!7 345,44 0,29
-~J./,Z8 10173,49 345,38 1
-2621,13 10349,31 345,33 1,39
-2670,44 10¢Z~,.1 345,30 0,39
13068.~4
13160.56
13533.55
i76,3 ="*~
J/u~,76 !0~92,52 71,37 342,40 10341,13
'. ~ o& 10779,62 71 ='"
o~,y,. ..~,.. ,~ 344,87 10424,73
189,7 ~..,.~ ~r ~ A~
. . ~/zo,~¢ t075~,70 /~,~ 341,84 10577,38.
183,3 ~ ~ 7! '~ '
!!4,4 ""'~ , ....
5~z~, ~.a11241,33 7i,0~ 341-~v ~0864,86
-2718,,.47 10692,52 345,27
-~/~.~,~2 ~077Y,,.~ ~,~,.,
o45,Z~
-27?4,83 10757,70
-~850,32 11133,29 345~17
-'Pq~.~.. '~P.~ 11241.35
2,:,'-7
!,54
0,68
13743,41
~o, ,/8
14027,~
95,4 ~,,~' o~ ~o~,v.'~°* ~ 69,80 342,04 1~50.~ou
94,4 ~=~ ~" ~" ~* 73 342 ..
14zY.~O 68,
~,~ 1 11034,3?
95,2 ~,,~,~°°~ 85 11507,42 67,46 342,54 11118,64
95,0 603!,i0 11594,69 66,~ 342,80 11202,04
94,? A070,84._11680,78 64.13 342,~'~ 11284,34
-2912,84 ~' ~= ~n
~" .... ~ "~= 08
-~YoY,.~o .141Y,=¢ 345,
-29~4,07 11507,.47 345,06
-2772,07 115~4,75 345,05
-3017,65 11680,86 345,03
1,3~
1,27
1,33
1,20
2,34
14218,38
14503,~
!4577,~0
95,5 6!14~09 11765,91 62,04 343,36 !!365,8i
94,4 6160,05 11848,34 59,69 345,26 !1445,i8
~,~ 8210,62 11728,83
_0,03 345,~}
· - -
~,3 6265,03 120~7,04 54,33 o~ o~ =-, ·
94,~ 4322.(:.) 12082.A~ 5~ ~
.... ,'~ 343,u4 11670,66
-3042.53 11766,00 345,01
-3064,85 11848,44 345,01
-3085,50 11928,93 345,01
-3106,90 !2007,14 345.00
-3128,86 12082,81 344,99
2,28
3,04
3,86
14692,86
I~707
15265.?3
95,0 A~87,02._ _ ,~,,o,~z 24 49,85 344,91 ...~741,37
'"~ ' 6a43.A~
~.l .... 12228,68 49,41 344,75 11811,28
!27,1
OJ£! , _
169,3 6641.10 i2449,7i 47,14 343,&3 12024,35
181,6 6764,95 12582,43 46,83 344,33 12151,95
-3149,17 12156,36 344.99
-3168,'",~ t~28,80 344,?8
.~4,~ 344,98
-3226,98 12449,84 344,78
2,_.'I
0,48
0,84
0,92
0,33
1543i,7i
165,8 6878,24 1Z703,42 46,96 343,29 122~,!8
PRO~C~E~, TO TD
98,3,.7~,¢=A~= ~ ~=//~,=~'~'= ~' 46,96 343,29 1~36,98
-E~97.36 12703,58 344,',:'.6
-3318,02 12/7_,,,..,8
0,47
0,03
ARCO Alaska, Inc.
Date: March 29, 1995
RETURN TO:
ARCO Alaska, Inc.
Attn: Brian Hebert
Kuparuk Operations File Clerk
ATO-1119B
P.O. Box 100360
Anchorage, AK 99510-0360
Transmittal #' 9219
Transmitted here with are the following items. Please acknowledge receipt
and return one signed copy of this transmittal.
LIS Tape and Listing
LWD Open Hole Edit
LIS Tape and Listing
'LWD Open Hole Edit
LIS Tape and Listing
LWD Open Hole Edit
3/13/95 95009
3/13/95 95060
3/09/95 95061
Receipt Acknowledged: Date: R E C I:!V E D
MAR & 0 1995
DISTRIBUTION:
Larry Grant
AOGCC
3001 Porcupine Drive
Anchorage, AK 99501
Alaska Oil & Gas Cons. Commission
Anchorage
ARCO Alaska, Inc.
Date: March 24, 1995
Transmittal #: 9216
RETURN TO'
ARCO Alaska, Inc.
Attn: Brian Hebert
Kuparuk Operations File Clerk
ATO-1119 B
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted below are the following open hole items. Please acknowledge
receipt and return one signed copy of this transmittal.
c~ ~-. l~(~1 R-33
c/.q...~ ~o~.., 1R-34
'~5" I_E, 2T-21
/~ 2T-21
¢~1 R-32
~2Z-23
~ / ~ 2Z-23
.... 2Z-22 . CDR Depth Shifted
CDR Final Print
CDR Final Print
CDR Depth Corrected
CDN Depth Corrected
Slim GR MWD Depth Corrected
CDR Depth Shifted
CDN Depth Shifted .
12/28/94
1/13/95
Feb16-21/95
Feb16,21/95
Dec11 - 14/94
Feb7-10/95
Feb7-10/95
Feb1-4/95
Feb1-4/95
Date'
Ref#95009
Ref#95060
Ref#95077
Ref#95077
Ref#95024
Ref#50-029-22544
Ref#50-029-22544
Ref#50-029-22524
Ref#50-029-22524
DISTRIBUTION'
Mr. Vernon E Pringle, Jr.
(Geology)
DeGIoyer and MacNaughton
One Energy Square
Dallas, TX 75206
Sharon AIIsup-Drake
DS Development
ATO-1205
RECEIVED
tV/AR ;~ 0 1995
Clifton Posey
Ge~le~ 0JJ & Gas Cons. Comrnls,10r~
ATO 1251 Anchorage
Erickson/Zuspan
NSK Central Files
NSK 69
q, arrY Grant (+Sepia)
AOGCC
3001 Porcupine Drive
Anchorage, AK 99501
Sandy Lemke
ATO 1336
TONY KNOWLES, GOVERNOR
ALASKA OIL AND GAS
CONSERVATION COMMISSION
December 12, 1994
3oo, vo.c6v~, r,~tw.
~MNCIIORAGE, ALASKA 99501-3192
PHONE: (907)279-1433
TELECOPY: (907)276-7542
Michael Zanghi
Drill Site Development Supv.
ARCO Alaska, Inc.
P O Box 100360
Anchorage, AK 99510-0360
Re:
Kuparuk River Unit 1R-33
ARCO Alaska, Inc.
Permit No: 94-156
Sur. Loc. 653'FSL, 214'FEL, Sec. 18, T12N, R10E, UM
Btmhole Loc. 2550'FSL, 1267'FWL, Sec. 6, T12N, R10E, UM
Dear Mr. Zanghi:
Enclosed is the approved application for permit to drill the above
referenced well.
The permit to drill does not eXempt you from obtaining additional
permits required by~ law from other governmental agencies, and does not
authorize conducting drilling operations until all other required
permitting determinations are made.
Blowout prevention equipment (BOPE) must be tested in accordance with
20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE
test performed before drilling below the surface casing shoe must be
given so that a representative of the Commission may witness the test.
Notice may be given by contacting the Commission petroleum field
inspector on the North Slope pager at 659-3607.
~~a~r2~~ OF~~T / iSSION
dlf/Enclosures
CC:
Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSluN
PERMIT TO DRILL
20 AAC 25.005
la. Type of Work Drill X Redrill [] 1 b Type of Well Exploratory [] Stratigraphic Test [] Development Oil X
Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone X Multiple Zone []
2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool
ARCO Alaska, Inc. RKB 41' Pad 45' feet Kuparuk River Field
:~. Address 6. Property Designation Kuparuk River Oil Pool
P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25628, ALK 2561
4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025)
653' FSL, 214' FEL, Sec. 18, T12N, R10E, UM Kuparuk River Unit Statewide
At top of productive interval (@ TARGET ) 8. Well number Number
2350' FSL, 1320' FWL, Sec. 6, T12N, R10E, UM 1R-33 #U-630610
At total depth 9. Approximate spud date Amount
2550' FSL, 1267' FWL, Sec. 6, T12N, R10E, UM 1 2/1 5/94 $200,000
12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
property line 1R-1 7 15401' MD
1267'@ TD feet 14.5' ~ 300' MD feet 2560 6987' TVD feet
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2))
Kickoff depth 300' feet Maximum hole angle 70.64° Maximumsurface 241 9 psig At total depth (TVD) 3700 psig
18. Casing program Setting Depth
size Specifications Top Bottom Quantity of cement
Hole Casing Wet,iht Grade Coupling Length MD TVD MD TVD Iinclude stac~e dataI
24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF
12.25" 9.625" 40.0# L-80 BTC 8569' 41' 41' 8610' 4086' 1600 Sx Arcticset III &
HF-ERW 900 Sx Class (3
8.5" 7" 26.0# L-80 BTCMO£ 14909 41' 41' 14950' 6642'
HF-ERW
8.5" 5" 18.0# L-80 LTC 451' 14950' 6642' 15401' 6987' 400 Sx Class (3
HF-ERW Top 500' above Kuparuk
i 9. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented Measured depth True Vertical depth
s L%:'r R E C E IV E D
Surface
Intermediate
Production )EC - 6 1994
Liner
Perforation depth: measured Atic, ska u~l & Gas Cons. Commission
true vertical Anch0ra,qe
20. Attachments Filing fee X Property plat [] BOPSketch X Diverter Sketch X Drilling program X
Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X
21. , hereby certify lhat the foregoing Js true and correct to the best of my knowledgej~l~.. .~/(~. . ~
Signed --. -. Title Drill Site Develop. Supv. Dat
Commission Use Only c..,-' - -
PermLt..Number L_,.I,,~PI number ..--, I Approva~l date ~ I See cover letter for
:z'--r I /~-?~-'K¢~'.~i other requirements
Conditions of approval Samples requJred l'-'l Yes 1~ No Mud Icg required I~1 Yes [~] No
Hydrogen sulfide measures [] Yes ~] No Directional survey required J~ Yes r'l No
Required working pressure for BOPE [] 2M [~ 3M [] 5M [] 10M [] 15M
Other: jt' g]FIS.) Signed By
Oavia W. Johnston by order of
Approved by Commissioner the commission Date_/f.~--/'~ "" ,~'6,,,-
Form 10-401 Rev. 7-24-89 Submit in
,
.
.
10
11
12
13
14
15
16.
17.
18.
GENERAL DRILLING PROCEDURE
KUPARUK RIVER FIELD
1 R-33
Move in and rig up Parker #245.
Install diverter system.
Drill 12-1/4" hole to 9-5/8" surface casing point (8,610')according to directional
plan.
Run and cement 9-5/8" casing.
Install and test BOPE. Test casing to 2000 psi.
Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW.
Drill 8-1/2" hole to total depth (15,401') according to directional plan.
Run open hole evaluation logs or LWD tools as needed.
Run and cement 7" x 5" casing. (If significant hydrocarbon zones are present above
the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule
20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200'
TVD of the surface casing shoe, cement will be down squeezed in the annular space
between the surface and production casing after the primary cement job is
completed.)
ND BOPE. NU tubinghead & full opening valve for cased hole logging.
Secure well and release rig.
Run cased hole cement evaluation. ND full opening valve and NU master valve and cap.
Move in and rig up Nordic #1.
Install and test BOPE. Pressure test 7" x 5" casing to 3500 psi.
Perforate and run completion assembly. This is a "packerless" completion that
utilizes a 4" seal bore extension (SBE) run in the 7" x 5" casing string. The seal
assembly is run on the end of the completion string, stung into the SBE, and tested to
ensure tubing x casing annular integrity.
ND BOPE and install production tree.
Shut in and secure well.
Clean location and release rig.
RECEIVED
DEC -- 6 1994
kl~,ska Oil & Gas Cons. Commission
Anchora¢¢.
DRILLING FLUID PROGRAM
Well 1 R-33
Density
PV
YP
Viscosity
Initial Gel
10 Minute Gel
APl Filtrate
pH
% Solids
Spud to 9-5/8"
surface casing
9.0-10.0
15-25
15-35
50-80'
5-15
15-40
10-12
9.5-10
+_10%
Drill out to
weight up
8.4-9.6
5-15
5-8
30-40
2-4
4-8
8-10
9.5-10
4-7%
Weight up
to TD
11.0
10-18
8-12
35-50
2-4
4-8
4-5 through Kuparuk
9.5-10
<12%
Drilling Fluid System:
Tandem Brandt Shale Shakers
Triple Derrick Shale Shakers
Solids Processing System to minimize drilling waste
Mud Cleaner, Centrifuges, Degasser
Pit Level Indicator (Visual and Audio Alarm)
Trip Tank
Fluid Flow Sensor
Fluid Agitators
Notes:
Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033.
Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW
and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface
pressure of 2,419 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to
3000 psi.
The nearest well to 1 R-33 is 1 R-17. As designed, the minimum distance between the two wells would
be 14.5'@ 300' MD.
Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well
or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will
be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The
annulus will be sealed with 225 sx of cement followed by Arctic pack upon completion of fluid pumping.
Risks in the 1 R-33 drilling area include lost circulation and high pressures in the Kuparuk. Lost "/
circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced
circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if
lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to
reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset
wells show that a mud ,,w, eight of 11.0 ppg will provide sufficient overpressure to safely drill, trip pipe,
and cement. The 9-5/8' casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon /
drilling out of the surface casing.
*Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds.
RECEIVED
DEC -'6 1994
Aiaska- 0il & Gas Cons. Commission
Anchora?
ARCO ALASKA,
][hO.
Structure : Pad 1R Well : 5.3
i Field : Kuparuk River Unit Location : North Slope, Alaska
TD LOCATION: I
2550' FSI. 1267' FWLI
~ , I sec. 6. ~,2,, mo~ I
iP~o~ ~re.eno~ i~ ~ W~io~ ~7. ~
~True Ve~icol Dep[hs ore reference RKB. {
TMD= 15080
N 14.70 DEG W
o 6~_
" _ J ~o~ ~=~ ~=~oo ~:o
12~- 2 . _ , r · , '
~ _ ~ AtSSk~ 0~t & Gas C0ns; Commission
A - ~ EOC WD=2' 18 TM0=2671 OEP=,278
~ - B/ ~~MB=8~7 DEP=6312 ~ I SEC~32N, RIOE
TARGET ANGLE
40 DEG
AVERAGE ANGLE
70.64 DEC
<-- West .......
5600 $000 2400 1800 1200 600 0 600
II II II II II I I I I I 15200
__
__12600
I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I l
600 0 600 1200 1800 2400 3000 .3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 1.3200
Scale1 : ,300.00
Vertical Section on 345.24 azimuth withreference 0.00N, 0.00 E from slot#35
O/W CONTACT 'PFD~078B TMD=15141 0EP-12715
B/ KUP SNOS ~VD=6834 TMD=15201 0EP=12753
TD - 7" CSG PT T'V'D=Og§7 TMD=I5401DEP=I2882
K-5 W0=6106 TMD=I,~210 DEP=12084
END ANGLE DROP - T/ ZONE D 'P,/D=6464 TMD~P=12443 ',~2.oo
T/ ZONE C 'P/D=6578 TMD=14867 DEP=12559 '%,
T/ ZONE A 1'VD=6725 TMD=15059 DEP=12662
A3 SNDS TVD=6741 TMD--15080 DEP=I2675
TARGET
9600
900O
8400
7800
7200 I
6600 I
6000 Z
0
5400 "~
4800
3600
3OO0
_
_ 2400
1200
600
..
0
600 0
10200
ARCO ALASKA,
[1 O.
Structure : Pad 1R
Field : Kuparuk River Unit Location : North Slope, Alaska
Wesf Scole 1 : 20.00
560 520 4~0 440 4{X3 560 320 280 2~0 200 160 1ZO 8{3 40 0 40 BO 120 160 200 240
12001
11601
1120~
920
I
I -
840_
760
g
720
60O
~Bo Z
520 ~
~o~
400
36O
320
.132o
~1160
~1120
~IOBO
1040
1000
1600
920
I
I
Z
0
~"1600
4700
RECEIVED
LTM
52O
1994- f
DEC -6
350
i~as',~. Oii& Gas Cons Commission
' 320
Anchnm.,~ g
I I I I I I I I I I I I i I I I I I I I I I I I i I I i I i I I i I I I '1 I 1
560 520 480 440 4.00 360 320 280 240 200 160 120 80 40 0 40 80 120 160 200 240
< - - We s t ~co,~ ,: ~o.oo
ARCO ALASKA,
]ILO.
Structure : Pad 1R
Field : Kuparuk River Unit Location : North Slope, Alaska
< - - W e s f soo,e ~: 2o.oo
2640 2600 2560 2520 2480 244-0 2400 2360 2320 2280 224~0 2200 2160 2120 2080 2040 2000 1960 1920 1880 1840
8120 IIIIlllllllllltlllllll IIIIIIIIIIIIIIIII
8080
8040
8000
7960
7920,
7880.
·
7600.
.
7760.
.
7720.
76801
I
0
Z
74801
74401
74001
73601
73201
72801
7160_
7120_
..
~ 7080_
8120
_8080
8O40
GOO
_
_7960
_
_7920
.7880
_7840
_7800
_7760
7720
RECEIVED
DEC - 6 1994
Oil & Gas Cons. Commission
Anchora, ~;
2640 2600 2560 2520 2480 2440 2400 2360 2320 2280
7680
_
_7640 J
- I
_76O0
- g
_75600
- -~
_7520'"--I--
_
_7480
7440
7.~60
7,~20
7280
72OO
_71Z0
..
_
_7080 ~
2240 2200 2160 2120 2080 2040 2000 1960 192D 1880 1840
W e S t sco,e ~: 20.00
Casing Design/Cement Calculations
2-Dec-94
Well Number:
Surface Csg MD:
Surface Csg TVD:
Production Csg MD:
Production Csg TVD:
Top of West Sak, TMD:
Top of Kuparuk, TMD:
Top of Target, A3 Sands, TVD:
Estimated Pressure:
Surface Casing Choice:
Production Csg Choice:
Production Casing Frac. Pressure
1 R-33
8,610 ft
4,086 ft
15,401 ft
6,987 ft
6,347 ft
14,718 ft
6,741 ft
3700 psi
** See Page 4
For Casing Choices
3,500 psi
Maximum anticipated surface pressure
Estimated BH pressure at top of target zone
TVD surface shoe
{(13,5'0.052)-0.11}*TVDshoe
Estimated Pressure=
Top of Target, TVD =
Overbalance, psi=
Anticipated Mud Weight =[
4,086 ft
2,419 psiI
3,700.0 ~:j
6,741 ft
150 psi
11.0 PPgl
Surface lead: Top West Sak, TMD = 6,347 ft
Design lead bottom 500 ft above the Top of West Sak = 5,847 ft
Annular area = 0.3132 cf/If
Lead length * Annulus area = 1,881 cf
Excess factor = 65%
Cement volume required = 3,104 cf
Yield for Permafrost Cmt = 1.94
Cement volume required =1 1,600 sxJ
Surface tail:
TMD shoe = 8,610 ft
(surface TD - 500' above West Sak) * (Annulus area) = 865 cf
Length of cmt inside csg = 80 ft
Internal csg volume = 0.4257 cf/If
Cmt required in casing = 34 cf
Total cmt = 899 cf
Excess factor = 15%
Cement volume required = 1,034 cf
Yield for Class G cmt = 1.15
Cement volume required =1 900 sxI
RECEIVED
DEC - 6 1994,
uti & Gas Cons. Commission
Anchor~ ·
Casing Design/Cement Calculations
2-Dec-94
Production tail'
TMD = 15,401 ft
Top of Target, TMD = 14,718 ft
Want TOC 500' above top of target = 14,218 ft
5" casing tail top (100' above A sand) =1 14,950 ft
5" Annulus area (9" Hole) = 0.3054
7" Annulus area (9" Hole) = 0.1745
(5" Casing Top-TOC)*7" Annulus area + (5" to TD)* 5" Annulus area = 265 cf
Length of cmt wanted in csg = 80 ft
Internal csg volume = 0.0997
Cmt required in casing = 8 cf
Total cmt = 273 cf
Excess factor = 75%
Cement volume required = 479 cf
Yield for Class G cmt = 1.19
Cement volume required =[ 400 sxJ
TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=l.8
Surface (Pipe Body): Casing Rated For:
Tension (Pipe Body) = Dead Wt in Air - Buoyant Force
Dead Wt in Air = Length * (WEft)
Buoyancy = Weight of displaced mud
Length
Casing Wt (Ib/ft)
Dead Wt in Air
Buoyancy =
Tension (Pipe Body)
Design Factor
916O00 lb
8,610 ft
40.00 Ib/ft
344400.0 lb
56263.1 lb
288136.9 lb
3.2!
Surface (Joint Strength):
Tension (Pipe Body) = Dead Wt in Air - Buoyant Force
Dead Wt in Air = Length * (WEft)
Buoyancy = Weight of displaced mud
Casing Rated For:
Length =
Casing Wt (Ib/ft) =
Dead Wt in Air =
Buoyancy =
Tension (Joint Strength) =
Design Factor =b
979000 lb
8,610 ft
40.00 Ib/ft
344400.0 lb
56263.1 lb
288136.9 lb
3.41
Production (Pipe Body):
Tension (Pipe Body) = Dead Wt in Air - Buoyant Force
Dead Wt in Air = Length * (Wt/ft)
Buoyancy = Weight of displaced mud
Casing Rated For:
Length =
Casing Wt (Ib/ft) =
Dead Wt in Air =
Buoyancy =
Tension (Pipe Body)=
Design Factor =[
604000 lb
15,401 ft
26.00 Ib/ft
400426.0 lb
66331.0 lb
334095.0 lb
1,81
Production (Joint Strength): Casing Rated For:
Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Length =
Dead Wt in Air = Length * (WEft) Casing Wt (Ib/ft) =
Buoyancy = Weight of displaced mud Dead Wt in Air =
Buoyancy =
~C~l~ ~[)Tension (Joint Strength) =
Design Factor =l
DEC - 6
~.\~.s~ bt[ & Gas Cons. Oommlssio~
667000 lb
15,401 ft
26.00 Ib/ft
400426.0 lb
66331.0 lb
334095.0 lb
2.01
Casing Design / Cement Calculations
BUR,~T - Minimum Design Factor = 1.1
Surface Casing:
Burst = Maximum surface pressure
Casing Rated For:
Max Shut-in Pres =
Design' Factor =[
Production Csg:
1. Design Case - Tubing leak while well is SI
Inside pres=Csg Frac pres (3500 psi)+Mud Wt*.052*TVD
Outside Pres=Backup Gradient (8.9ppg *0.052*TVD)
Net Pressure = Pressure inside-Pressure outside
Design Factor = Rating / Net Pressure
Casing Rated For:
Inside p.ressure
Outside Pressure
Net Pressure
Design Factor
COLLAPSE- Minimum Desion Factor = 1.0
_
Surface Casing
1. Design Case - Lost circulation and Fluid level drops
to 2000' TVD with 9.0 # Mud
2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud)
Casing Rated For:
Mud Gradient =
Ext. Pres. @ Bottom =
Design Factor =[
Production Csg
1. Worst Case - Full evacuation of casing
2. Mud weight on outside = Mud Wt * 0.052 * TVD
Casing Rated For:
Mud Gradient =
Ext. Pres. @ Bottom =
Design Factor =[
2-Dec-94
5750 psi
2418.9 psi
2.4J
7240 psi
7490 psi
3234 psi
4257 psi
1.7J
3090 psi
0.571 Ib/ft
1398 psi
2.2J
5410 psi
0.571 Ib/ft
3990 psi
1.4J
RECEIVED
DEC - 6 1994
A~,ska 0ii & Gas Cons. Cor~iBjs$[o~
Anchor~,.
Casing Design / Cement Calculations
2-Dec-94
Surface Casing Choices
OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength
I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb
2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb
3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb
4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb
Collapse Burst
4750 psi 6870 psi
3090 psi 5750 psi
2020 psi 3520 psi
2090 psi 3580 psi
Production Casing Choices
OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength
I 7.000 6.276 26 L-80 7.5491 sq, in. 667000 lb 604000 lb
I 5.000 4.276 18 L-80 5.2746 sq, in. 376000 lb 422000 lb
2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb
Collapse Burst
5410 psi 7240 psi
10490 psi 10140 psi
4320 psi 4980 psi
RECEIVED
DEC - 6 ]994
~!~.ska 0i! & Gas Cons. Commission
Anchor~
,.JPARUK
RIVER UNI'I
20" DIVERTER SCHEMATIC
I 5
3
DO NOT SHUT IN DIVERTER
AND VALVE AT SAME TIME
UNDER ANY CIRCUMSTANCES.
.
MAINTENAN(~E & OPERATION
UPON INITIAL INSTALLATION:
· CLOSE VALVE AND FILL PREVENTER WITH WATER TO
ENSURE NO LEAKS.
· CLOSE PREVENTER TO VERIFY OPERATION AND
THAT THE VALVE OPENS IMMEDIATELY.
CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN
INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED.
OPEN VALVE TO ACHIEVE DIVERSION.
ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS
DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b)
1. 16"CONDUCTOR.
2. SLIP-ON WELD STARTING HEAD.
3. DIVERTER ASSEMBLYWlTH ONE 2-1/16"- 2000 PSI BALL VALVE.
4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET.
5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON
CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN
PREVAILING WIND CONDITIONS.
6. 20" - 2000 PSI ANNULAR PREVENTER.
RECEIVED DKP , 1/9/94
[)E(.; - 6 1994..
Gas Cons. Commission
Anchor~.
7
6
5
4
I
13 5/8" 5000 PSI BOP STACK
ACCUMULATOR CAPACITY TEST
1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL
WITH HYDRAULIC FLUID.
2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH
1500 PSI DOWNSTREAM OF THE REGULATOR.
3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND
RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS
ARE CLOSED WITH CHARGING PUMP OFF.
4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT
IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING
PRESSURE.
BOP STACK TEST
1. FILL BOP STACK AND MANIFOLD WITH WATER.
2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED.
PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT
IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD.
3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES
ON THE MANIFOLD. ALL OTHERS OPEN.
4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES.
INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES.
BLEED TO ZERO PSI.
5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE
VALVES.
6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES.
7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4.
CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI
LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST
ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE.
8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BO'I-I'OM
RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES.
9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE.
CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO
ZERO PSI.
10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD
AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE
DRILLING POSITION.
11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES.
12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP.
13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM.
SIGN AND SEND TO DRILLING SUPERVISOR.
14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY
OPERATE BOPE DAILY.
1. 16" - 2000 PSI STARTING HEAD
2. 11" - 3000 PSI CASING HEAD
3. 11" - 3000 PSI X 13-5/8" - 5000 PSI
SPACER SPOOL
4. 13-5/8" - 5000 PSI PIPE RAMS
5. 13-5/8" - 5000 PSI DRLG SPOOL W/
CHOKE AND KILL LINES
6. 13-5/8" - 5000 PSI DOUBLE RAM W/
PIPE RAMS ON TOP, BLIND RAMS ON BTM
7. 13-5/8" - 5000 PSI ANNULAR
RECEIVED
Oil & Gas Cons. Commission
Anchor~
WELL PERMIT CHECKLIST
COMPANY ~C~
WELL NAME
GEOL AREA
UNIT#
PROGRAM: exp [] der ~ redrll ri serv []
o o /o F O
ADMINISTRATION
1. Permit fee attached ...................
2. Lease number appropriate ................
3. Unique well name and number ...............
4. Well located in a defined pool .............
5. Well located proper distance from drlg unit boundary..
6. Well located proper distance from other wells ......
'7. Sufficient acreage available in drilling unit ......
8. If deviated, is wellbore plat included .........
9. Operator only affected party ..............
10. Operator has appropriate bond in force .........
Il. Permit can be issued without conservation order .....
12. Permit can be issued without administrative approval..
13. Can permit be approved before 15-day wait ........
ENGINEERING
14. Conductor strin9 provided ............... ~ N
15. Surface casing protects all known USDWs ........ ~ N
16. CMT vol adequate to circulate on conductor & surf csg.. N
17. CMT vol adequate to tie-in long string to surf csg . . . Y ~
18. CMT will cover all known productive horizons; ..... ~ N
19. Casing designs adequate for C, T, B & permafrost .... ~ N
20. Adequate tankage or reserve pit ............. ~ N
21. If a re-drill, has a 10-403 for abndnmnt been approved. ~
22. Adequate wellbore separation proposed .......... ~ N
23. If diverter required, is it adequate .......... ~ N
24. Drilling fluid program schematic & equip list adequate .~ N
25. BOPEs adequate .................... /~ N
26. BOPE press rating adequate; test to ~OO psig.~ N
27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N
28. Work will occur without operation shutdown ....... Y~ N
29. Is presence of H2S gas probable ............. Y ~
GEOLOGY
/
30. Permit can be issued w/o hydrogen sulfide measures .... Y
31. Data presented on potential overpressure zones .....
32. Seismic analysis of shallow gas zones .......... y N
33. Seabed condition survey (if off-shore) ........ /Y N
34. Contact name/phone for weekly progress reports . . . ~. Y N
[exploratory only]
GEOLOGY: ENGINEERING: COMMISSION:
Comments/Instructions:
HOW/Jo - A:~FORMS~cheklist rev 03/94
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
MAR ~ 0 ~995
Alaska 0il & 9,as Cons. Commission
AnchoratJe
Tape Vert f_.i. cati on
chl.]}mberqer AlasKa Co:~pL!ti. no Center
13-.",'AR-1995 0t4: 4.4
**** TAPM ,'~ g A I)KF,
SFRVICP: IP.iAi.!F... .' l~L)TT
DATF ; c~5t0~t~3
OP IC-IM : F'I., I C
T~[;~ NA~E : OSnL',~
CONTIK~URTI[)N ~ : ~
PREVIOUS TAPE :
CmMMENT : a[~CO ~I,AS?:.I 1T?!C., KUPARtJK PIVER Ua!'[', 1. R-33, APE 50-029-22529
Tap~,
Kuparu~, River l. Jpit
M~D/MAD bOGS
OPEPATOP:
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1 P, - 33
5002922529
Arco AlasKa Inc.
18
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I 3-~.,~AR- 1995 0~:44
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VFRSION : 001C01
DAT~ : 95/03/13
~AX R~C SIZ~ : !.024
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PAGE:
5.419
5.895
1.475
2.219
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0.551
2.348
0.7t~2
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0.578
3.506
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**** F I I.,F Tt<A I [.,ER ****
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V~RSION : 00!CO!
D ~'I'~ : 05103113
,~X Rb~C STZR : 1024
FIL~ TYPE :
LAST FILg; :
**** FlbE HE~[)ER ****
F!LF N~g' : EOIT .002
SERVICE : b'LIC
VERSION : 001C01
DAT~: : q5!03/13
~X RF:C SIZE : ~.024
FILE TYPE : [.,U
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Curves and loq
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D~:pTH INCREMENT:
FILE SUMMARY
VENDOR TOO!., (]ODE
LOG H~ADER [)ATA
DATE LOGGED:
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START DEPTH
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28-DgC-94
i$ Taoe Yertfication Listin.,q
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R a,. r,~ W D 6.9 ~ 9 P, p. :'4 w 9
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5.419
5.~95
1.475
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0,551
2.348
0.'7~2
2.289
0,578
3.506
0.311
3.440
0.703
3.30~
0.501
3.174
0.286
3.726
0,366
3.287
0.436
3.368
0.236
3.303
IS Tar)e Verification !,istino
chlumberqer AlasKa Computino Center
13-~.~AR- ! 995
PAGE:
DOWNHOL, E $OF'fWA9 t',
DATA TYPE (MEMORY or
TD DPlLI,.,F~ (r'l.'):
TOP LOG TN~ERVAL
~IT ROTATinG SoE~D
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TOOL STRING (TOP
VENDOR TOOb Chi)El TO(il ~YPE
.....................
CDR C[],'4P ] . RESISTIVITY
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aU[) VISCOSITY (Si
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FI',,UIO bOSS (C3):
RESISTIVITY (OH ~i~q.) ~UD AT ~IE.ASOR~]D TE~PFRAT!IRE
~UD ~T MAX CIRCULATlfIG 'I'~:MPEPA, TURE
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FAST 2.5
15530.0
76b0.0
15474.0
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70.7
73.7
RGS 0
8.500
766q.0
lO,gO
36.0
3.21.0
2.910
0.000
2.65
8 · 500
1,000
****************** RGS RUN ~1. ******************
Distance: 81t to GR: 66.68 ft.
Dj. stance: 8it to ROP: 59,43 ft,
Olsta~ce: ~it to ~es: 56,2~ it.
Drilled Interval 7692 - 1.3252 ft,
$
7 4.0
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PAGE:
FORMAT SP~CIFICATIO!q '~,!~CI..IR[) ~
3 73
5 66
7 65
!,1 66 36
13 66
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** S~]q" TYPE - CHAN' **
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ROp~ )I.j W' ! ~'/HR 6k9179 O0 000 0() 0 2 1 1 4 58 0000000000
ATR LW!, t.)h a ~ 619179 00 00t) 00 0 2 1 I 4 68 0000000000
PSR Lw~ OH ~l~,~ 619i. 79 00 0O0 00 0 2 ! 1 4 60 0000000000
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~TP,LWl 2.~1 PSR. ,(,,W 1 3,036 DER.bWl 2,720
DFPT. 12500.000 CR.bWl 94.103
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0.782
0.578
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~'I'P o I,W 1 4. 108
DFPT. 7~?..6. 000
ATP. !,,~ 1 -999. 250
** END OF DATA
**** FIbE TRAILE~ ****
FTLE NAME : E~)IT .002
SERVICE : FblC
VERgIO~ : O,)ICO1
I.)~T~ : q5103/13
~X REC SIZE
F'"ILF TYPE : I~r,j
L~ST FiLE
**** FILE [~.gA D ~;.R ****
F!LF fig~aE : EDI',t? ,003
VERSIOa : OO~C01
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F'I.',L[;~ TYPE : LO
L~,ST WILE :
Center
13-?fAR-1905 08:44
!05.630 ROPE.Dwi
3. 633 OE9. l.,w 1
] 05.q77 Rt)PE. L~' i
3.4~4 [) E.~'
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83.114 POPF:.LW1
3.41.0 DER. bW 1
b6.519 ROPE.bWl
B.350 DER.LWl
90.344
3.421 [)ER.aW1
93.91.1 POPE.bWl
3.920 F, ER, bWl
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3.~u5 DER.aWl
63.030 ROPE.bWI
-999.75n DF.R.hwl
157.876
3.524
~39.053
3..lb0
252.986
3,726
135.343
3.363
263.686
3.395
334.756
3.387
228.2~2
3.878
297.124
3,g95
-99Q.250
-999.250
TAB.I,~I
TAB.L~I
TAF.LWl
TAa. L~I
T19.!~l
T~B.L~!
TAB.bW1
TAB.LW!
T~B.L~I
PAGE:
0.703
0.286
0,360
0,43b
0.236
0.313
0.249
-999,250
mane Verification !,isti, n~
chlumber%ler Al. asKa Compk~tinq Center
13-~,,~AP-~ 995 0R:44
PAGE:
R A w ~.'i w D
Curves aha loq ~:,_'~der dat. 8 for each bit. run In seoacate
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SURFACE SOF'T,u~RE VERSION:
~ATA TYPE
TD DRILLER
TOP LUG TN"['ERVA.b (F'T}:
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r4AXIM[J~q RECORDED TE~PERATI,,tRE
RESISTIVITY
MI.!D A'T .MEA,:,eURED T.EMPERA. TiIRE (~T):
~I'JD FII,'I'RATE A.T
MUD CAKE
~,~ E'.,I T R 0 ~ T 0 0 ~aTR.IX:
HA, TRiX DENSITY:
~{OLE CORRECT IO~.,~
? 8 -i3F.. '" r
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FAST 2.5
1553o. n
7660.n
15474.0
46.~
71.6
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.~ $ 035
500
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10.90
48,0
3.21,0
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2.65
8.500
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74.0
61,0
0.0
IS mat)e VerJ.'f~catlon [.,ist!,nq
chlumheroer alaska Comput~nq Center
1 ]-,V'AR-1995 (i)8:44,
bistance: ~it to eR: 66.6g ft.
~,)ist~nce: ~it to ROm: 59,43
O~stance: B?t to Des: 56,26 ft.
Drilled Interval 7602 - 13252
[)istenCe: Sit to GR: 66.65 ft,
Distance: 5i5 to P~lD: 59,43
o~stance: 5it r.o Res: 56,~6 it.
Orilled Interval: 1.]252 - 11530 ~t,
S
I~TS F[)RMA17 I')ATA
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** S~,;T TYPE
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.............. ; ...... r;[ ............ ;; ........ ~ ........... ' ........... [' .... ' ..... ' ..... '
jJ[:'pT F 619 . ()0 <) ('.~ 0 0 1 1 4 8 0000000()00
GR LW2 (;~Pl 6i9179 O0 OOO O0 0 3 ! 1 4 68 OOOO000000
R~PF ]:.,~2 F/HR 6:~qi79 O0 ()00 O0 0 3 1 1 4 68 00()0000000
7:A6 LW2 HP 619179 O0 000 O0 0 3 I 1 4 68 0000000000
ATR l,,w2 [) u NI ~.~ 6:[~179 O0 00() O0 0 :] 1 i 4 08 0000000000
PSR 1., ~ 2 /:'j N a; ~,'~ 6191~9 O0 00() O0 0 3 1 1. 4 68 0000000000
IS TaDe YerIf.icat!on I,ist!.nq
chltln, berger i~lasKa Com~[ltinG Cen%er
995 (.)~: 44
PAGE:
1.1
** D,% T ~.. $*
I)FpT. 15530.0C~0 GR. bl,]2 -~99.2b0 ROPE]. b;,~2 98.897
~TP. L~'~2 -999.2K0 PgR.bk~2 -Qgq.250 DE~.bW2 -999.250
DF'pT. 1550[). 0Ok; GR.L¥~2 -Ogq.250 ROPE.Lw2 97.365
ATR.L~,2 -999.250 PSR.L~42 -99q.2~0 DER. bt~2 -999.250
DFPT. 15~O0.000 Ct{. L%42 7~.&2~ ROP~..bW2 52.326
5'1'~. LW2 6.(}fl9 PSR.LW2 5.695 DE~. i5~',~ 2 5.817
DFPT. !4hOd.f}00 CR.LW~ 122.4&1 ROPE.LW2 66. 177
~ T R. L ~' 2 2..[ 41 P S R. L'~ 2 2.4 ~ 9 D E ~. L ~, 2 2.3 ] ~]
D~]PT. 14000.000 GN. b~,~2 ~25.765 R[,)P f{. bW 2 20~ .462
a'r~. I~w2 2.197 ~SR.LW2 2.340 DSR. b'~2 2.282
D~PT. 13500. 000 GR. bW2 1 US. 3~7 ROP~,~. bw2 81.815
aT~. l.,w2 2.325 PSR,Lw2 2,4~3 DER.LW2 2.408
D ?. P T 1. 3 i S l. 0 t, 0 G R. L ~ 2 1 0 8.. 6 9 5 R 0 P ~'.. b ~'~ 2 - 9 9 9 2 5 0
~TR:LW2 -999.250 PSR,LW~ -999.250 [')~R. t,,,~ 2 -999:250
-999.250
-999.250
5.4~9
1.475
0.710
0.551
-999.250
SERVICE : FLIC
VERSION : 00!COl
D~'rE : 951O3113
:~4AX RKC SIZE : !024
FIL,~ TYPE : [,
**** TaPE TK 6