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HomeMy WebLinkAbout205-0081
Winston, Hugh E (CED)
From:Carlisle, Samantha J (CED)
Sent:Monday, October 5, 2020 8:22 AM
To:Winston, Hugh E (CED)
Subject:FW: KRU 1E-105L2(PTD 205-008, Sundry 319-516) MBE treatment - CANCEL SUNDRY
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Thursday, October 1, 2020 1:56 PM
To: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov>
Subject: KRU 1E‐105L2(PTD 205‐008, Sundry 319‐516) MBE treatment ‐ CANCEL SUNDRY
From: Peirce, John W <John.W.Peirce@conocophillips.com>
Sent: Wednesday, September 30, 2020 2:48 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Subject: Re: 10‐403 Sundry Questions and Wellwork Updates
Hi Victoria,
I have a few updates along with a few sundry questions outlined below regarding well work jobs as follows:
1E‐105L2: RPPG MBE treatment (Sundry Approval #319‐516 of 11/13/19) should now be canceled. We did an injection
test to 1E‐105L2 lateral only in mid August at ~1500 BWPD inj while flowing offset 1E‐126 producer to verify that the
target heel MBE for RPPG treatment was still open. However, initial inj test showed no sign of an open MBE and 1E‐126
was producing crude at 65% WC. Thus, we left 1E‐105L2 on injection fulltime during the last 4 weeks at 1000 – 1500
BWPD to continue to evaluate for an MBE, but WHIP has gradually increased from 0 to 150 psi to date, with 1E‐126 on
fulltime at ~400 BOPD, 60 – 65% WC.
We are not yet sure if we misdiagnosed 1E‐105L2 as having an open MBE, or if we an open MBE has healed itself, but we
are pleased with how the wells are now performing and are moving next to normal up other laterals in 1E‐105 to take
injection. I request that 10‐403 Approval #319‐516 of 11/13/19 be canceled.
1A‐07: a C Sd Tubing Patch was installed 9/12/20 in this injector (per 10‐403 apprvl # 320‐160 of 4/10/20), but the patch
performance didn’t look good so we ran an LDL 9/27/20 that found a new C Sd leak (previously undetected) which is just
a few feet below the bottom of the ~96’ OAL patch we just set. 10‐404 for the patch is due 10/12/20, but we would like
to pull the entire patch to redress it and extend the length of it by ~20’ to also be able to re‐install the patch and isolate
the new leak as well. Can we pull the Patch, extent the patch by ~20’ OAL, then reset it to isolate the additional leak
under current 10‐403 apprvl # 320‐160 of 4/10/20, or do we need to cancel this approval and submit a new 10‐403 for
a new patch design?
1E‐119: the Re‐Sqz Casing Leak job is scheduled to be pumped down coil tubing tomorrow.
1J‐105L1 and 1C‐190: these RPPG treatments are scheduled for mid‐October execution. I have received 10‐403
approvals for both jobs.
Thanks,
2
John Peirce
Wells Engineer
CPAI Drilling & Wells
(907)‐265‐6471 office
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Thursday, September 3, 2020 2:16 PM
To: Peirce, John W <John.W.Peirce@conocophillips.com>
Subject: [EXTERNAL]RE: Re 1E‐119 Cement Sqz Casing Leak and 1E‐105L2 RPPG MBE Job
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you
recognize the sender and know the content is safe.
John,
Approval is granted to re‐squeeze 1E‐119 as outlined. All work performed should be included in the 10‐404 submission.
Verbal approval is granted to re‐perforated and proceed with another RPPG treatment as outlined below for well 1E‐
105L2.
Include these approvals with your copies of the approved sundries.
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria.Loepp@alaska.gov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged
information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to
you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov
From: Peirce, John W <John.W.Peirce@conocophillips.com>
Sent: Monday, August 31, 2020 5:26 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Subject: Re 1E‐119 Cement Sqz Casing Leak and 1E‐105L2 RPPG MBE Job
Hi Victoria,
I’m providing a brief summary update regarding progress on well work projects at 1E‐119 and 1E‐105L2. We still need
to perform more work on these wells which I would like to ask some questions about.
1E‐119: Cement Squeeze Casing Leak Job (Sundry Approval #320‐028 of 1/28/20)
3
7/10/20 – CT pumped 20 bbls of 15.8# Cl G Cement as per program. Lost returns after ~2 bbls of cement exiting
nozzle. Put 12 bbls of cement behind pipe, and left 8 bbls in tubing. PUH to safety. Started contaminating cement
down CT. Lost all returns.
7/17/20 – CT tagged top of cement at 6277’ RKB, and performed MIT‐T to 1500 psi that passed.
8/27/20 ‐ Underreamed cement to 6300’ RKB, then MIT‐T to 1500 psi; failed with 0.3 bpm LLR @ 1475 psi. Continued to
underream to 6’ below casing leak at 6338’ RKB in preparation for re‐squeeze. POOH & RD CTU.
Current plan forward ‐ prepare re‐squeeze procedure to pump another 15 bbls of cement to squeeze the casing leak at
6338’ RKB. Original LLR of 0.5 bpm/900 psi has now 0.3 bpm/ 1475 psi.
Question: Can I proceed to pump a re‐squeeze, or would AOGCC want a 10‐404 to report work completed to date along
with a new 10‐403 to approve a re‐squeeze?
‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐
1E‐105L2: Fullbore RPPG MBE job (Sundry Approval #319‐516 of 11/13/19).
11/27/19: CT set IBP at 7319’ RKB
12/02/19: Shot 5' Perf interval 7293‐7298' RKB.
12/06/19: Fullbore pumped 30 bbls 2% KCL Brine Pre‐Flush at rates of 1.0 to 2.5 bpm, and WHP increased from a Vac to
100 WHP, so swapped to Diesel due to early pressure increase, and pumped 75 bbls Diesel at 1.0 to 3.5 bpm while WHP
increased to 650 psi, so decided to SD the job due to poor injectivity. I made a decision to RD and suspend operations
for a new plan forward based upon observing early high treating pressure. The well did not appear ready to take RPPG
slurry, and I suspected the MBE must be further down hole (below the ECP & IBP). The well was not acting like we were
in communication with an open MBE.
4/20/20: CT deflated the IBP at 7319’ in D‐Lat and then pushed it down liner to abandon IBP at 13320' CTMD.
8/30/20: Pumped injectivity test with 250 bbls Seawater followed by 47 bbls Diesel at 1 bpm 200 bbls S/W, 1.5 bpm 25
S/W, 2 to 3 bpm 25 S/W, then 47 Diesel FP. 1E‐105L2 was on a Vac during most of inj test.
Current plan forward – because offset 1E‐126 producer was flowed during 1E‐105L2 injection test with no sign of
excessive water production, we plan to flow test 1E‐126 in the near future while 1E‐105L2 is on injection to determine if
high watercut can suddenly become evident at 1E‐126 indicating that the open MBE from 1E‐105L2 still exists before we
proceed with another MBE treatment attempt at 1E‐105L2. In the meantime, we need to plan for a contingent RPPG
treatment at 1E‐105L2 that is targeted for pumping in mid‐October 2020 if the flow test shows that an open MBE still
exists. From what we learned on the first attempt to pump the RPPG on 12/06/19, we likely need to shoot perfs below
the ECP (below 7324’ RKB per D Lat Hook Hanger Detail) in order to get communication with the MBE, so our plan
forward would be to shoot a new perforation interval at 7372 – 7377’ RKB in D Lat liner, followed by pump an RPPG
treatment as described in the proposed RPPG job approved per Sundry Approval #319‐516 of 11/13/19.
A 10/3/19 Caliper log shows that 1E‐105L2 already has at least 2 holes penetrating through the liner between the base
of the ECP (at ~7325 RKB) and the first Constrictor (at 7426’ RKB) behind the D Lat Liner, but if the MBE is within this
compartmentalized segment of wellbore we should first shoot a 5’ interval of big hole perfs here to enable getting RPPG
slurry into it. The next compartmentalized segment of wellbore exists between Constrictors exists at 7426 and 8006’
RKB, but if an MBE exists is in this segment of the wellbore we are likely to already have good communication to pump
RPPG slurry to it since the Caliper shows this blank liner section has a multitude of holes through it that are likely to be
sufficient to allow RPPG slurry through the liner to the MBE.
4
Question: may I have verbal approval to perforate another 5’ OAL perf interval at 7372 – 7377’ RKB in the D Lat liner if
we need to proceed with another RPPG treatment attempt, or should I send in another 10‐403 seeking approval to add a
this new perf interval?
Regards,
John Peirce
Staff Wells Engineer
CPAI Drilling & Wells
(907)‐265‐6471 office
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
John Peirce
Sr. Wells Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E -105L2
Permit to Drill Number: 205-008
Sundry Number: 319-516
Dear Mr. Peirce:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Enclosed is the approved application for the sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
Je rice
Chair
DATED this` day of November, 2019.
RBDMSNov 14 2019
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 2s ?Rn
l wEIVED
NOV 12 2019
AOGVC
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown[]
Suspend ❑ Perforate D Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE TRTM C "
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number: 5. ArP
ConocoPhilli s Alaska Inc.
Exploratory ❑ Development ❑
Stratigraphic ❑ Service D •
205-008 '
3. Address:
6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510
N 0 t -r— 1 E- 01--l.%1 IF - I Z6,1-
50-029-23243-61-00
7. If perforating: �µ3t�
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? N/A
Will planned perforations require a spacing exception? Yes ❑ No O
KRU 1E -105L2 '
9. Property Designation (Lease Number):
10. Fieid/Pool(s):
ADL 25651, ADL 25660
Kuparuk River Field/ West Salk 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):
13,530' 3,396' 13530 3396 1500psi NONE NONE
Casing Length Size MD TVD Burst Collapse
Conductor 139' 20" 170' 170'
Surface 3,875' 133/8 3,905' 2,586'
Intermediate 7,233' 9518 7,258' 3,528'
Liner 5,900' S i/2 13,530' 3,396'
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
8024-13492
3533-3396
4.500"
L-80
7,229'
Packers and SSSV Type:
Packers and SSSV MD (ft) and TVD (ft):
PACKER = BAKER PAYZONE PACKER
7307 MD and 3538 TVD
12. Attachments: Proposal Summary D Wellbore schematic D
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stratigraphic ❑ Development ❑ Service D '
14. Estimated Date for 12/1/2019
15. Well Status after proposed work:
Commencing Operations:
OIL ❑ WINJ D ' WDSPL ❑ Suspended ❑
GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
16. Verbal Approval: Date:
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Name: John Peirce John Peirce
Contact Name:
Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com
A � : Contact Phone: (907) 265.6471
Authorized Signature: ,� Gtl ' ,. — 9 el i
Date: :4 / / f
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑
Other:
Post Initial Injection MIT Req'd? Yes ❑ No ❑ 9BDMS tLr^j NOV 14 2019
Spacing Exception Required? Yes ❑ No �/ Subsequent Form Required: u �J
APPROVED BY
i
1I
Approved by: COMMISSIONER THE COMMISSION Date:
It l�.o ' mar Submit Porm�d l2
F m 10403 Revised 4/2017 OP Approved application i°si �rl a of approval. Attachments in Duplicate
KUP INJ WELLNAME 1E-105 WELLBORE 1E-105
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10,731.0
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1
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1
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holes, 4 Uri
12,348.0
12,603.0
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511812005
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of slos for all
ISLOTS
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12,902.0
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3,624.]
3,6243
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R
KUP INJ WELLNAME 1E-106 WELLBORE 1E-105
Conoco✓Phillips Aw
Alaska, Ina.
%* F --
1E 10.11 / 1911 ID:51 AM
Mandrel Inserts
vxud znmuac(ecm1)
st
aN
............................... 1--.. ........... .................... .................. --.
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Com
2 6,7129
3,3&1.2 CAMCO
KBO -2- 1
GASLIFT
DMY
BK113
0.000
0.0
78/2010
Ncfes: `Gone
Fat&Safety
End D.R
Ann°bti°n
6/182006
NOTE: TRI LATERAL WELL: A -SAND (1E-105),BSAND (1E-ID5L1), D -BAND (1E-10512)
6VRFACE 7!.03,2.'13
611812006
NOTE:B-SAND LEM CONTAINB CAMCO'OB'NIPPLE w/6.92"ID ]5]8'
ws uvi: 4,2170
1129/2009
NOTE: View Schematic W/ Alaska Bchemafic9.0
CA. LIFT; 62129
SLEEVE; 7,109
91112D10
NOTE'MBE repair w/9 bbs Of lG1-2289E, 105 ae9ree me ipointwax@8]50'
742011
NOTE: OR OFllE MO DIFICAT 10N -PUMPED Ml LBS (4MM) CRYSTAL SEAL IN B LATERAL MBE@8]50
.G;
SEALASSY, 72113
I606LEEYE;],N0.0
O SAND LINER LEM: 7.19]&
7.4326
GUENTERI 76MO
&SAND LINER LEM', 7.48IS
7,W1..
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1S IX0 9
PLUG; TEST 0
INTERMEDIATE; 26.1L.,M0
SLOTS;5.31206,7740�
SLOTS: B 030.09493,0
SLOT.:.471.Nl.A7S0-
SLOTS , m,7310.11,114L-L,
.LOT$ 11 NN
6mTG 12516012, 1.0
3LOT6: 12RQ20.13, QG 0�I
M6ANDLMER;7,6191-�
13,5130
W, KUP INJ WELLNAME 1E-105 WELLBORE 1E -105L2
AM
611 AttributesCOIIOCQPFI1I��pS Alaska,1m.Itiand Nor-
WFATRAK nemorea 1.1 III We.IWreSfaNa IIfaI PI JAao..1KEg
1E-1osq 1mrolan ms+u4
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VemcalcM1.an.... ap
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.......................... ....
Last Tag: 13,0180 621/2006 1E-105,2 Imosbor
Last Rev Reason
rvgNGEB; Re
Annotation FnEDase We11Mre lnaI MOE By
Rev Reason: an iso sleeve, 0-santl tliverteq DBP plug 9/20,2 ppmven
(MISSED)8 SEETT TTYPYPE II DIVERTER 2017 tE-105
Casing Strings
CONDUCTOR; 31DI
NIPPLE; Rod z
Casing Desanp0on OD(in) IDlin) -,IS al Set Depth l%KB) set Depm(ND)_. WULen p... Grade Top mreaa
D -SAND LINER HH 512 4.95 ],260.4 ],416.3 3,558.2 1550 L80 BTCM
Liner Details
Top MKe) Top HVDl@KB) Topmall°I tlem Dea Co. xominauD
lint
],260.4 3,5285 ]8.19 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 3.688
SOREACE; so.oa,spas
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GASurP,67126
],28].8 i J,SMBJ 78.03 JXO BUSHING CROSS OVER BUSHING 1 3.940
7,30fi9 3,538.4 ]8.69 PgCKER BAKER PAY 20NEEXTE CASINGPACKER 5.500
)L
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D -SAND LINER 5112 4.B5 ],W0.9 13,536) 15.50 L-80
Liner Details
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BAKER'HRLINER SETTING SLEEVE
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8,024.0
8,399.0
3,533.0
3,51ll
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10512
&16/2005
40.0
SLOTS
l6%eO Liner, a1tema9ng
joints of lit nkraotletl liner
ISO S EEVEI 7,RM1.0
Tor all DSanB slots 25
x.125 boles, 4 rm &ft
D- SAND LINER LEM; 7,71ao.6
,{925
INIERME01gTE: 25.1$ID]D
8,612.0
9,120.0
3,505.5
34898
WS ,1E-
10512
fil1&2005
400
SLOTS
9,331.0
9,]94.0
3,485.8
3,488.4
D, 1E-
&162005
40.11
SLOTS
10512
10,181.0
10,602.0
3,4]5.6
3,488.9
D,1 -
&1612005
40.0
LOTS
105,2
10,587.0
11,070.0
3,468.9
3,481 d
WS D,1 -
Eli&2005
40.0
SLOTS
105U
1
11,415.0
11,45] 0
3,468 8
3,471.2
WS D,1 -
&16/2005
40.0
SLOTS
105,2
L VAND LrvER HI :7,M+
7,4163—
11,885.0
12,38].0
3,460.6
3,430.6
WS D, E-
&1fi2005
40.0
SLOTS
105L2
12,fi88.0
12,]]3.0
3419.9
3415.8
Wi
fill&2005
400
SLOTS
10512
12,860.0
12,945.0
3,412.3
3.410.0
WTD. 1E-
&162005
40.0
SLOTS
SLOTS:6ov.oe,sa9.o—
10512
H
12,9880
13,074.0
3,408.9
3,40]6
D, 1E-
105,2
&162005
40.0
SLOTS
SLOTS', 661269.1A0—
.13,201034064
3,403.6
W D -
105,2440
6l1&2005
40
SLOTS
E
13,329.03,402.]
3,400.2
SD,1 -
&162005
40.0
SLOTS
SLOTS;%331.697840��
10660
13,492.0
3,399.0
3,396.5
WS D,1 -
6/1612005
40.0
SLOTS
105,2
BLOM, 10,16, 610.9320
Notes: General
& Safety
Eno Dale
Annotation
sI M. 10 EI TEM
61182005 NOTE: TRI -LATERAL WELL'. A -SAND UE -105),B -SAND UE -105L1),0- SAND (1 E-105,2)
611&2005 NOTE: 8.5.OPEN HOLE BEHIND SLOTTED LINER
&1812006 NOTE: 8SAND LEM CONTAINS CAMCO DB' NIPPLE w13.92" ID @ 7578'
1129/2009 NOTE: View Schem9gC wl Alaska Sch.rina 9.0
911112010 NOTE: MBE repair wl9 bbl5 of 1G1 -2289E, 105 degree melbOint wax@8]50'
SLOT$114M0-11,a67.O—
9/42011 NOTE: PROFILE MODIFICATION - PUPPED 2310 LES(4MM) CRYSTALSEAL IN B LATERAL MBE@8750
SLOTS ',11.a6a.612W70—I
BLOM: 1ZM.° 12,MO3
6LOT6;1ja91.D-12,19i
6LOi6; 12669.6130]40 —�
J
2p10�
leg(�
Llg.��13�0�
aB20�370.&,5367
Proposed 1E -105L2 to 1E -126L2 RPPG D MBE Treatment
1 E-105 Tri-Lat injector has 4.5" tubing and horizontal laterals in West Sak A, B, and D sands. The
1E -105L1 B lateral has had 3 separate MBE's, but all these MBE's have now been sealed with
Crystal Seal and RPPG jobs. After the last B Lat RPPG job of 12/10/18, evaluation of 1 E-105 B Lat
only injection and 1E-126 production indicated all B Lat MBE's appeared to be sealed. However,
an open 1E -105L2 `D' Lat MBE still remains open. 1E -105L2 'D' Lat has 5.5", L-80 slotted liner
between 7258 - 13536' RKB. On 9/18/17, a D [PROF saw all injection exiting D Lat at 7260' RKB
(near D LEM), with all injection then flowing down backside of `D' Liner to the first liner slots 764'
below D LEM. The [PROF showed no down flow inside the 764' blank liner section of D Lat. The
exact location of the D MBE is unknown, but IPROF data suggests the 'D' MBE is most likely
somewhere behind the upper 764' blank liner section above all the liner slots in 1 E-1051-2.
On 2/2/18, a Plug was set at 7578' RKB to isolate the A Lat, and it remains set. On 10/2/19, a 'D'
Iso-Slv was pulled and a 'B' Diverter was pulled, from 7258' RKB & 7524' RKB respectively. On
10/3/19, a `B' Iso-Slv was set and a 'D' Diverter was set, and CT drifted a 2.75" OD Dummy Drift
into D Lat to 10378' RKB. IE -105 is now configured to perform a 'D' MBE RPPG treatment.
It is proposed that RPPG slurry be fullbore pumped to the D lateral with intent to halt all flow exiting
D Lat near the D LEM to restore normal matrix injection to D Lat liner, and to seal the D MBE that
likely exists above 8024' RKB behind the —764' blank liner section.
Procedure:
Coil Tubing:
1) RIH with inflatable Bridge Plug & set it inside 4.5" OD blank liner section at 7360' RKB in D Lat.
2) RIH with pert gun & shoot 5' OAL large hole perfs in 4.5" OD blank liner at 7310' RKB in D Lat.
Pumping:
3) At —12 hours before planned RPPG job, put 1 E-1051-2 on PWI 1000 BPD to displace Diesel FP
and gas head from the tubing to the open D MBE to 1E-1261-2. RU pumping equipment at 1E-105
the next morning.
SI 1 E-126 and 1 E-1051-2, and then immediately start fullbore pumping into 1 E-1051-2 with 112 bbls
(-1 ting volume) of 2% KCL Brine at steady rate between 1.5 - 4.0 bpm (pump rate needed
de ends on what rate is needed to let the pump keep up with the vacuum rate of the well), followed
XX bbls of RPPG slurry mixed with 2% KCL Brine while adding 0.5 - 0.75 lbs/gal RPPG on -the -
f y. Continue pumping 0.5 - 0.75 ppg slurry at a steady rate until the WHIP reaches 500 to 800 psi,
t swap to pumping 64 bbls of 2% KCL Brine displacement, followed by 47 bbls Diesel FP to
2000' TVD (3103' RKB), followed by SD to leave RPPG treatment —1 bbl underdisplaced to MBE._
Wait 48 hrs for RPPG to cure in MBE to crosslinked non -flowing RPPG before returning 1 E-1051-2
to injection or 1 E-126 to production.
Return 1 E-1051-2 to PWI to evaluate results of the RPPG D MBE treatment.
After sufficient evaluation time to verify that D MBE is sealed, 1E-105 will be reconfigured to
restore PWI to all three laterals.
JWP 11/11/2019
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
John Peirce
Sr. Wells Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E -105L2
Permit to Drill Number: 205-008
Sundry Number: 319-516
Dear Mr. Peirce:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Enclosed is the approved application for the sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
Je rice
Chair
DATED this` day of November, 2019.
RBDMSNov 14 2019
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 2s ?Rn
l wEIVED
NOV 12 2019
AOGVC
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown[]
Suspend ❑ Perforate D Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE TRTM C "
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number: 5. ArP
ConocoPhilli s Alaska Inc.
Exploratory ❑ Development ❑
Stratigraphic ❑ Service D •
205-008 '
3. Address:
6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510
N 0 t -r— 1 E- 01--l.%1 IF - I Z6,1-
50-029-23243-61-00
7. If perforating: �µ3t�
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? N/A
Will planned perforations require a spacing exception? Yes ❑ No O
KRU 1E -105L2 '
9. Property Designation (Lease Number):
10. Fieid/Pool(s):
ADL 25651, ADL 25660
Kuparuk River Field/ West Salk 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):
13,530' 3,396' 13530 3396 1500psi NONE NONE
Casing Length Size MD TVD Burst Collapse
Conductor 139' 20" 170' 170'
Surface 3,875' 133/8 3,905' 2,586'
Intermediate 7,233' 9518 7,258' 3,528'
Liner 5,900' S i/2 13,530' 3,396'
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
8024-13492
3533-3396
4.500"
L-80
7,229'
Packers and SSSV Type:
Packers and SSSV MD (ft) and TVD (ft):
PACKER = BAKER PAYZONE PACKER
7307 MD and 3538 TVD
12. Attachments: Proposal Summary D Wellbore schematic D
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stratigraphic ❑ Development ❑ Service D '
14. Estimated Date for 12/1/2019
15. Well Status after proposed work:
Commencing Operations:
OIL ❑ WINJ D ' WDSPL ❑ Suspended ❑
GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
16. Verbal Approval: Date:
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Name: John Peirce John Peirce
Contact Name:
Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com
A � : Contact Phone: (907) 265.6471
Authorized Signature: ,� Gtl ' ,. — 9 el i
Date: :4 / / f
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑
Other:
Post Initial Injection MIT Req'd? Yes ❑ No ❑ 9BDMS tLr^j NOV 14 2019
Spacing Exception Required? Yes ❑ No �/ Subsequent Form Required: u �J
APPROVED BY
i
1I
Approved by: COMMISSIONER THE COMMISSION Date:
It l�.o ' mar Submit Porm�d l2
F m 10403 Revised 4/2017 OP Approved application i°si �rl a of approval. Attachments in Duplicate
KUP INJ WELLNAME 1E-105 WELLBORE 1E-105
�nocoP im
Well Attributes�an M1ll4F't 11��1p5 MAiTDwee BPVOVYIWe11Exe ¢lalua,!'MD(II)Anl Me llaPJaBKa. n1C.lWE3T°zAKnne I�nSao, .,M I,.,, ,f�-- I__.__. i )
ons u,
Gns LIFT.
SLEEVE;
OS4rv0 uRER
PLUG;
SLOTS;
SLOTS, 10131011.1140
SLGTS; it581.012.W0.OT
SLOTS; 12.W2.P1a. 05 O_T
DIVERTOR in
Men Des
& Slots
Run Date
SI
snot
Top WO)
elm liVD)
Oona
(ahotsX[
TOP(MB)
eGngll(B)
(r.)
MB)
Otan Zona
Des
on R Top di
TopITVID
lnKBl
Gem
8,312.0
8)]4.0
3,718.9
3,726.6
m.", E-105
511820050,I)
TOO Run
(One
SLOTS
TS
SlolledLtofted
4,21].0
2,399.1
CAMCO
KB --
1
GAS LIFT
DMY
BK
liner for all of
for all
00
81812010
R
Sandslos 2.liner
ASantl slots 2.5x.125
M1Oles, 4 rows/ti
9,030.0
9,498.0
3,]02.2
3,fi94.9
WS A2, 1E-105
Pl WO05
4D.D
SLOTS
Slotletl Liner, alternating fee
Of blanpslotted liner for all
ASantl slots 25x. 125
hales, 4 rowsMl
9)10.0
10,4730
3,7036
3,665.1
WS A2,1E-105
511&2005
40.0
SLOTS
Slotted Liner, alternating its
of blankreoned liner for all
ASand eloB P5 x.125
holes, 4 rowsNi
10,731.0
11,114.0
3,669.7
3,658.2
WS A2, 1E-105
5flidi
40.0
SLOTS
Sorted Liner, aternatingj6
Ofblandsloned liner for all
1
A -Sand slots 2.5x.125
holes, 4 rose In
11,584.0
12,090.0
3,6852
3,859.9
WS A3, 1ET 05
SIMM5
400
SLOTS
lonetl inegalternating¢s
Gf blandslotied liner for all
1
A -Sand slots 2.5 x.125
holes, 4 Uri
12,348.0
12,603.0
3,6484
3,631.0
WS A3, 1E-105
511812005
40.0
Slone Gneeal[ernafingils
of slos for all
ISLOTS
Sand 2.liner
A -Sand note 25x.125
holes, 4 rowsln
12,902.0
13,455.0
3,624.]
3,6243
WS A3.WS A2,
51182005
40.0
SLOTS
Stoned Liner,aemoting jts
1E-105
of blandslon¢tl liner for all
A -Sand Stals 2.5 x.125
Holes, 4 rowan
SI
OR
on R Top di
TopITVID
lnKBl
Make
Mctlel
IOD(in)
Bery
Valve
Typu
Lakh
Type
Pon.
llnl
TOO Run
(One
Run Deb
Com
4,21].0
2,399.1
CAMCO
KB --
1
GAS LIFT
DMY
BK
0.000
00
81812010
R
KUP INJ WELLNAME 1E-106 WELLBORE 1E-105
Conoco✓Phillips Aw
Alaska, Ina.
%* F --
1E 10.11 / 1911 ID:51 AM
Mandrel Inserts
vxud znmuac(ecm1)
st
aN
............................... 1--.. ........... .................... .................. --.
...ER:.G
CONDUCTOR:IMO
NIPLE SEE
N TOP (IIRBI
T°p(�1
911(BI Mak¢
Mo.l OO llnl
6¢ry
Vely°
}ype
Latcn
ryp
Part Size
)In)
TRO Run
(psi)
Run Dale
Com
2 6,7129
3,3&1.2 CAMCO
KBO -2- 1
GASLIFT
DMY
BK113
0.000
0.0
78/2010
Ncfes: `Gone
Fat&Safety
End D.R
Ann°bti°n
6/182006
NOTE: TRI LATERAL WELL: A -SAND (1E-105),BSAND (1E-ID5L1), D -BAND (1E-10512)
6VRFACE 7!.03,2.'13
611812006
NOTE:B-SAND LEM CONTAINB CAMCO'OB'NIPPLE w/6.92"ID ]5]8'
ws uvi: 4,2170
1129/2009
NOTE: View Schematic W/ Alaska Bchemafic9.0
CA. LIFT; 62129
SLEEVE; 7,109
91112D10
NOTE'MBE repair w/9 bbs Of lG1-2289E, 105 ae9ree me ipointwax@8]50'
742011
NOTE: OR OFllE MO DIFICAT 10N -PUMPED Ml LBS (4MM) CRYSTAL SEAL IN B LATERAL MBE@8]50
.G;
SEALASSY, 72113
I606LEEYE;],N0.0
O SAND LINER LEM: 7.19]&
7.4326
GUENTERI 76MO
&SAND LINER LEM', 7.48IS
7,W1..
& ULINER: ],5 N
1S IX0 9
PLUG; TEST 0
INTERMEDIATE; 26.1L.,M0
SLOTS;5.31206,7740�
SLOTS: B 030.09493,0
SLOT.:.471.Nl.A7S0-
SLOTS , m,7310.11,114L-L,
.LOT$ 11 NN
6mTG 12516012, 1.0
3LOT6: 12RQ20.13, QG 0�I
M6ANDLMER;7,6191-�
13,5130
W, KUP INJ WELLNAME 1E-105 WELLBORE 1E -105L2
AM
611 AttributesCOIIOCQPFI1I��pS Alaska,1m.Itiand Nor-
WFATRAK nemorea 1.1 III We.IWreSfaNa IIfaI PI JAao..1KEg
1E-1osq 1mrolan ms+u4
Lest Tag on"INUJ
VemcalcM1.an.... ap
Anudean Depan ll i Entl Date WeIIMre ,tat Mao ay
.......................... ....
Last Tag: 13,0180 621/2006 1E-105,2 Imosbor
Last Rev Reason
rvgNGEB; Re
Annotation FnEDase We11Mre lnaI MOE By
Rev Reason: an iso sleeve, 0-santl tliverteq DBP plug 9/20,2 ppmven
(MISSED)8 SEETT TTYPYPE II DIVERTER 2017 tE-105
Casing Strings
CONDUCTOR; 31DI
NIPPLE; Rod z
Casing Desanp0on OD(in) IDlin) -,IS al Set Depth l%KB) set Depm(ND)_. WULen p... Grade Top mreaa
D -SAND LINER HH 512 4.95 ],260.4 ],416.3 3,558.2 1550 L80 BTCM
Liner Details
Top MKe) Top HVDl@KB) Topmall°I tlem Dea Co. xominauD
lint
],260.4 3,5285 ]8.19 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 3.688
SOREACE; so.oa,spas
OFT; 4,217
GASurP,67126
],28].8 i J,SMBJ 78.03 JXO BUSHING CROSS OVER BUSHING 1 3.940
7,30fi9 3,538.4 ]8.69 PgCKER BAKER PAY 20NEEXTE CASINGPACKER 5.500
)L
Casing Desnlpxon DD (int mllpl rop l%Ka) setDpl61%Kel se Depth DVDI... WULen p... Gmae rap rnreae
D -SAND LINER 5112 4.B5 ],W0.9 13,536) 15.50 L-80
Liner Details
SLEEoK7,16T9
Tort Be Top "Th TKB)
Tapinal l°) Ron Des
Co.
xammal ID
(ln)
m
],3]0.9 3,550.5
]9.61 SLEEVE
BAKER'HRLINER SETTING SLEEVE
S.D00
LOCATOR', 7.211.1
Perforations & Slots
snm
SEAL-kagn 7.z11.9
rap(%KB 1
Btml%KB )
roPITVD)
IflN6)
atm1TV01
InKBI
LinkeO Enna
Dab
Dena
ghobM
1
type
Com
8,024.0
8,399.0
3,533.0
3,51ll
WS D, -
10512
&16/2005
40.0
SLOTS
l6%eO Liner, a1tema9ng
joints of lit nkraotletl liner
ISO S EEVEI 7,RM1.0
Tor all DSanB slots 25
x.125 boles, 4 rm &ft
D- SAND LINER LEM; 7,71ao.6
,{925
INIERME01gTE: 25.1$ID]D
8,612.0
9,120.0
3,505.5
34898
WS ,1E-
10512
fil1&2005
400
SLOTS
9,331.0
9,]94.0
3,485.8
3,488.4
D, 1E-
&162005
40.11
SLOTS
10512
10,181.0
10,602.0
3,4]5.6
3,488.9
D,1 -
&1612005
40.0
LOTS
105,2
10,587.0
11,070.0
3,468.9
3,481 d
WS D,1 -
Eli&2005
40.0
SLOTS
105U
1
11,415.0
11,45] 0
3,468 8
3,471.2
WS D,1 -
&16/2005
40.0
SLOTS
105,2
L VAND LrvER HI :7,M+
7,4163—
11,885.0
12,38].0
3,460.6
3,430.6
WS D, E-
&1fi2005
40.0
SLOTS
105L2
12,fi88.0
12,]]3.0
3419.9
3415.8
Wi
fill&2005
400
SLOTS
10512
12,860.0
12,945.0
3,412.3
3.410.0
WTD. 1E-
&162005
40.0
SLOTS
SLOTS:6ov.oe,sa9.o—
10512
H
12,9880
13,074.0
3,408.9
3,40]6
D, 1E-
105,2
&162005
40.0
SLOTS
SLOTS', 661269.1A0—
.13,201034064
3,403.6
W D -
105,2440
6l1&2005
40
SLOTS
E
13,329.03,402.]
3,400.2
SD,1 -
&162005
40.0
SLOTS
SLOTS;%331.697840��
10660
13,492.0
3,399.0
3,396.5
WS D,1 -
6/1612005
40.0
SLOTS
105,2
BLOM, 10,16, 610.9320
Notes: General
& Safety
Eno Dale
Annotation
sI M. 10 EI TEM
61182005 NOTE: TRI -LATERAL WELL'. A -SAND UE -105),B -SAND UE -105L1),0- SAND (1 E-105,2)
611&2005 NOTE: 8.5.OPEN HOLE BEHIND SLOTTED LINER
&1812006 NOTE: 8SAND LEM CONTAINS CAMCO DB' NIPPLE w13.92" ID @ 7578'
1129/2009 NOTE: View Schem9gC wl Alaska Sch.rina 9.0
911112010 NOTE: MBE repair wl9 bbl5 of 1G1 -2289E, 105 degree melbOint wax@8]50'
SLOT$114M0-11,a67.O—
9/42011 NOTE: PROFILE MODIFICATION - PUPPED 2310 LES(4MM) CRYSTALSEAL IN B LATERAL MBE@8750
SLOTS ',11.a6a.612W70—I
BLOM: 1ZM.° 12,MO3
6LOT6;1ja91.D-12,19i
6LOi6; 12669.6130]40 —�
J
2p10�
leg(�
Llg.��13�0�
aB20�370.&,5367
Proposed 1E -105L2 to 1E -126L2 RPPG D MBE Treatment
1 E-105 Tri-Lat injector has 4.5" tubing and horizontal laterals in West Sak A, B, and D sands. The
1E -105L1 B lateral has had 3 separate MBE's, but all these MBE's have now been sealed with
Crystal Seal and RPPG jobs. After the last B Lat RPPG job of 12/10/18, evaluation of 1 E-105 B Lat
only injection and 1E-126 production indicated all B Lat MBE's appeared to be sealed. However,
an open 1E -105L2 `D' Lat MBE still remains open. 1E -105L2 'D' Lat has 5.5", L-80 slotted liner
between 7258 - 13536' RKB. On 9/18/17, a D [PROF saw all injection exiting D Lat at 7260' RKB
(near D LEM), with all injection then flowing down backside of `D' Liner to the first liner slots 764'
below D LEM. The [PROF showed no down flow inside the 764' blank liner section of D Lat. The
exact location of the D MBE is unknown, but IPROF data suggests the 'D' MBE is most likely
somewhere behind the upper 764' blank liner section above all the liner slots in 1 E-1051-2.
On 2/2/18, a Plug was set at 7578' RKB to isolate the A Lat, and it remains set. On 10/2/19, a 'D'
Iso-Slv was pulled and a 'B' Diverter was pulled, from 7258' RKB & 7524' RKB respectively. On
10/3/19, a `B' Iso-Slv was set and a 'D' Diverter was set, and CT drifted a 2.75" OD Dummy Drift
into D Lat to 10378' RKB. IE -105 is now configured to perform a 'D' MBE RPPG treatment.
It is proposed that RPPG slurry be fullbore pumped to the D lateral with intent to halt all flow exiting
D Lat near the D LEM to restore normal matrix injection to D Lat liner, and to seal the D MBE that
likely exists above 8024' RKB behind the —764' blank liner section.
Procedure:
Coil Tubing:
1) RIH with inflatable Bridge Plug & set it inside 4.5" OD blank liner section at 7360' RKB in D Lat.
2) RIH with pert gun & shoot 5' OAL large hole perfs in 4.5" OD blank liner at 7310' RKB in D Lat.
Pumping:
3) At —12 hours before planned RPPG job, put 1 E-1051-2 on PWI 1000 BPD to displace Diesel FP
and gas head from the tubing to the open D MBE to 1E-1261-2. RU pumping equipment at 1E-105
the next morning.
SI 1 E-126 and 1 E-1051-2, and then immediately start fullbore pumping into 1 E-1051-2 with 112 bbls
(-1 ting volume) of 2% KCL Brine at steady rate between 1.5 - 4.0 bpm (pump rate needed
de ends on what rate is needed to let the pump keep up with the vacuum rate of the well), followed
XX bbls of RPPG slurry mixed with 2% KCL Brine while adding 0.5 - 0.75 lbs/gal RPPG on -the -
f y. Continue pumping 0.5 - 0.75 ppg slurry at a steady rate until the WHIP reaches 500 to 800 psi,
t swap to pumping 64 bbls of 2% KCL Brine displacement, followed by 47 bbls Diesel FP to
2000' TVD (3103' RKB), followed by SD to leave RPPG treatment —1 bbl underdisplaced to MBE._
Wait 48 hrs for RPPG to cure in MBE to crosslinked non -flowing RPPG before returning 1 E-1051-2
to injection or 1 E-126 to production.
Return 1 E-1051-2 to PWI to evaluate results of the RPPG D MBE treatment.
After sufficient evaluation time to verify that D MBE is sealed, 1E-105 will be reconfigured to
restore PWI to all three laterals.
JWP 11/11/2019
c7ii3s-11.
ProActive Diagnostic Services, Inc.
WELL 1. OG
TRANSM17`SAL
To: AOGCC
Natural Resources Technician
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
205008
31413
R,JD
NOV 0 3 2019
AOGCC
RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT)
The technical data listed below is being submitted herewith. Please acknowledge receipt by
returning a signed copy of this transmittal letter to the attention of :
1) Caliper Report
2)
Signed:
Print Name:
ProActive Diagnostic Services, Inc.
Attn: Diane Williams
130 West International Airport Road
Suite C
Anchorage, AK 99518
Pdsanchorage(cDmemorylog.com
03 -Oct -19 1 E-105 L2 1 Report/ CD 50-029-23243-61
Date �o5l //or/
PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (907)245-8951 FAX: (907)245-8952
E-MAIL: PDSANCHORAGE(CaMEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM
httpsflreadcwedhole-myshwepointoom/personal/diane wilhams readcmedhole com/Documents/D
Drive/Achives/MasterTemplateFiles/Templates/Distribution/TransmittalSheets/ConocoPhillips_Transmit. docx
CASED
HOLE
Company: ConocoPhillips Alaska, Inc.
Log Date:
October 3, 2019
Log No.:
14404
Run No.:
1
Pipe Description:
5.5 inch 15.5 Ib. L-80 BTCM
Pipe Use:
Slotted Liner
31413
Memory Multi -Finger Caliper
Log Results Summary
Well:
Field:
State:
API No.
Top Log Interval:
Bottom Log Interval:
Inspection Type : Corrosive & Mechanical Damage Inspection
COMMENTS:
1 E-105 L2
West Sak
Alaska
50-029-23243-61
7,425 Ft. (MD)
10,348 Ft. (MD)
This caliper data is tied into the 7 inch by 5.5 inch cross-over at 7,424.64 feet per the attached liner
tally dated June 15, 2001.
During logging operations, 12 caliper fingers were torn from the caliper as it was pulled past the
diverter. The missing caliper fingers did not affect the recordings throughout the 5.5 inch slotted
liner.
This log was run to assess the condition of the slotted liner with respect to internal corrosive and mechanical
damage to help determine the cause of flow path of fluid from the blank section of liner to the top of the
slotted liner. The caliper recordings indicate multiple holes in the blank section of the liner throughout the
interval logged. Based on the caliper recordings there are multiple areas where the fluid could have exited
above the slotted liner interval. A 3-D log plot of the caliper recordings across the liner logged is included in
this report.
The caliper recordings indicate the 5.5 inch slotted liner logged appears to be in poor condition, with multiple
holes recorded throughout the liner logged. Holes were recorded in 18 of the 34 blank liner joints logged.
The recorded damage appears as a line of deep pitting throughout the interval logged. Cross-sectional wall
loss between 15% and 22% metal volume is recorded in 6 of the 34 blank liner joints logged. Heavy
deposits are recorded throughout the liner interval logged, restricting the I.D. to 2.97 inches at 9,553 feet.
The presence of heavy deposits will mask any additional significant damage that may be hiding behind the
deposits. A graph illustrating the minimum recorded diameters on a joint -by -joint basis across the liner
logged is included in this report.
MAXIMUM RECORDED WALL PENETRATIONS:
Multiple Holes
100
14
8,010 Ft. (MD)
Multiple Holes
100
12
7,905 Ft. (MD)
Multiple Holes
100
42
9,187 Ft. (MD)
Multiple Holes
100
11
7,868 Ft. (MD)
Multiple Holes
100
3
7,519 Ft. (MD)
MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS:
Multiple Holes
22
13
7,966 Ft. (MD)
Multiple Holes
22
42
9,203 Ft. (MD)
Multiple Holes
21
14
8,015 Ft. (MD)
Multiple Holes
20
12
7,929 Ft. (MD)
Hole
16
43
9,206 Ft. (MD)
READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497
Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA -North America Cd)readcased hole. corn
Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314
MAXIMUM RECORDED ID RESTRICTIONS:
Heavy Deposits
2.97 inches
51
9,553 Ft. (MD)
Heavy Deposits
3.02 inches
54
9,680 Ft. (MD)
Heavy Deposits
3.04 inches
50
9,507 Ft. (MD)
Heavy Deposits
3.04 inches
52
9,595 Ft. (MD)
Heavy Deposits
3.06 inches
53
9,634 Ft. (MD)
C. Goerdt C. Waldrop J. McAnelly
READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497
Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica(careadcasedhole.com
Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314
LEM
-AD Sand Window
���i��� ■■■■■■■■ism-_ i� Vii.. _
■■■■■■ Ilk.
eT -
■■ IN on Casing Packer
73r I son
E 9�E
�'�■��
- ALNO
_
- C
iNIMMONS
Cross -Over
I
A
wt
mow
4
MEW
-moi■ - -
idiom Slotted Liner
d son
-
iiic'�F=��.7 - - -
IZ ■■
Dle Holes in
c Casing
Slotted Liner
Slotted- Liner
i
Slotted Liner
Slotted Luer
Slotted Liher
Slatted Liner
Slotted Liner
Slotted Liner
ST61ted Liner-_
Ie Holes in
Casing
j
Slotted Liner
Slotted Liner
Slotted Liner
Slotted Liner
Slotted Liner'
Slotted Liner
Slotted Liner
4
Slotted Liner
Slotted Liner
..��e9 Slotted Liner
Correlation of Recorded Damage to Borehole Profile
Pipe 1 5.5 in (7,424.7'- 10,3477) Well: 1 E-105 L2
Field: West Sak
Company: ConocoPhillips Alaska, Inc.
Country: USA
Survey Date: October 3, 2019
■ Approx. Tool Deviation . Approx. Borehole Profile
1
5
10
15
20
25
30
E
Z 35
c
'o
40
45
50
55
60
65
69
0
50
Damage Profile (% wall) / Tool Deviation (degrees)
7,426
7,593
7,808
8,023
8,234
8,442
8,654
?
U-
C
8,866
t
n.
9,077
9,289
9,500
9,712
9,924
10,138
10,307
100
Bottom of Survey = 69 Perforations
CASED
HOLE Minimum Diameter Profile
Well: 1 E-105 L2 Survey Date: October 3, 2019
Field: West Sak Tool Type: UW MFC 40 No. 10011976
Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches
Country: USA Tubing I.D.: 4.95 inches
Minimum Measured Diameters (in.)
2.75 3 3.5 4 4.5
0.1
5
10
15
20
25
L 30
v
E
0
Z 35
c
'o
40
45
50
55
60
65
7,425
7,593
7,808
8,023
8,234
8,442
8,654
c
D
8,866
s
a
v
9,077
9,289
9,500
9,712
9,924
10,138
�' CASED
HOLE Body g Y Region Analysis
Well: 1 E-105 L2 Survey Date: October 3, 2019
Field: West Sak Tool Type: UW MFC 40 No. 1001 1976
Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches
Country: USA No. of Fingers: 40
Pipe -- 5.5 in. 15.5ppf L-80 BTCM Analyst— - - - Waldrop- - -
Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth
5.5 in. 15.5 ppf L-80 BTCM 4.95 in. 7,425 ft. 10,348 ft.
Penetration (% wall) Damage Profile (% wall)
20 - - -- Penetration body Metal loss body
0 50 100
15
5
J
0 to 20 to 40 to over
20% 40% 85% 85%
Num- ber of ioints analvzed (total 69)__
0 1 14 18
Damage Configuration (body)
20 r T�
15
10
5
25
50
Perforations
0
-
Isolated
General Line Other
Hole /
Pitting
Corrosion Corrosion Damage
Pos. Hole
-
of join s—ddamaged (total= 33)--
Number
2
_0 13 0
18
Bottom of Survey = 69
Perforations
CASED
HOLE
Joint Tabulation Sheet
Well: 1 E-105 L2 Survey Date: October 3, 2019
Field: West Sak Analyst: Waldrop
Company: ConocoPhillips Alaska, Inc.
Pipe Description Nom. ID Body Wall Top Depth Bottom Depth
5.5 in. 15.5 ppf LSO BTCM Liner 4.95 in. 0.275 in. 7,425 ft. 10,348 ft.
Joint
No.
Jt. Depth
(Ft.)
Pen.
Upset
(in.)
Pen.
Body
(in.)
Pen.
%
Metal
Loss
%
Min.
I.D.
(in.)
Comments
Damage Profile
(% wall)
0 50 100
0.1
7425
0
0
0
0
3.91
7" x 5.5" Cross -Over
1
7426
0.08
0.34
100
8
3.94
Hole! Heavy Deposits.
2
7468
0.07
0.36
100
11
3.94
Multiple Holes! Heavy De osits.
3
7510
0
0.61
100
7
3.30
Multi le Holes! Heavy De osits.
4
7551
0.07
0.20
73
2
3.08
Isolated Pittin Heavy Deposits.
5
7593
0.14
0.29
100
4
3.32
Hole! Heavy Deposits.
6
7635
0.06
0.18
65
4
3.55
Isolated Pittin Heavy Deposits.
7
7678
0.13
0.20
72
5
3.73
Line Corrosion. Heavy Deposits.
8
7722
0.08
0.23
83
9
4.01
Line Corrosion. Heavy Deposits.
9
7765
0.12 1
0.55
100
6
4.08
Hole! Heavy Deposits.
10
7808
0.17
0.35
100
9
4.17
MUlti le Holes! Heavy De osits.
11
7850
0.25
0.62
100
13
4.19
Possible Hole in Upset! Multiple Holes! Heay.
12
13
7894
7936
0.25
0.20
0.82
0.57
100
100
20
1 22
4.56
4.63
Possible Hole in Upset! Multiple Holes! Deposits
Multiple Holes! Dei2osits.
14
7979
0.16
0.93
100
21
4.44
Multiple Holes! Heavy Deposits.
15
8023
0.21
0.35
100
12
4.53
Slotted Liner Deposits.
16
8065
0.14
0.38
100
15
4.22
1 Slotted Liner Heavy Deposits.
17
8107
0.11
0.48
100
13
3.99
Slott d Liner Heavy De sits.
18
8149
0.22
0.34
100
18
3.73
Slotted Liner Heavy De osits.
19
8191
0.14
0.70
100
14
4.34
Slotted Liner Heavy Deposits.
20
8234
0.05
0.90
100
1 15
3.98
Slotted Liner Heavy Deposits.
21
8276
0.05
0.50
100
14
3.81
Slotted Liner Heavy De osits.
22
8318
0.09
0.56
100
13
3.61
Slotted Liner Heavy Deposits.
23
8360
0.10
0.75
100
7
3.45
Slotted Liner Heavy Deposits.
24
8399
0.10
0.36
100
1
3.39
Multi le Holes! Heavy Deposits.
25
8442
0.09
0.23
84
15
3.24
Line Corrosion. Heavy Deposits.
26
8486
0.09
0.38
100
7
3.28
Multi le Holes! Heavy De osits.
27
8528
0.08
0.34
100
1 2
3.48
Hole! Heavy De osits.
28
8570
0
0.32
100
7
4.03
Multi le Holes! Heavy Deposits.
29
8612
0
0.66
100
13
3.43
Slotted Liner Heavy De osits.
30
8654
0.09
0.71
100
5
3.54
Slotted Liner Heavy De osits.
31
8696
0.67
0.86
100
10
3.43
Slotted Liner Heavy Deposits.
32
8739
0.13
0.47
100
2
3.52
Slotted Liner Heavy Deposits.
33
8781
0.14
0.53
100
10
3.61
Slotted Liner Heavy Deposits.
34
8824
0.45
0.47
100
9
3.59
Slotted Liner Heavy De osits.
35
8866
0.23
0.48
100
5
3.38
Slotted Liner Heavy De osits.
36
8908
0.19
0.65
100
1
3.24
Slotted Liner HeavyDeposits.
37
8950
0.05
0.46
100
5
3.38
Slotted Liner HeavyDe osits.
38
r399
8991
0.06
0.67
100
5
3.63
Slotted Liner HeavyDe osits.
9034
0.07
0.40
100
15
3.67
Slotted Liner Heavy Deposits.
40
9077
0.49
0.49
100
23
3.66
Slotted Liner Heavy De osits.
41
9121
0.19
0.36
100
8
3.66
Multiple Holes! Heavy De osits.
42
9162
0.49
0.70
100
21
4.05
Hole in Upset! Multiple Holes! Heavy De osits.
43
9204
0.10
0.34
100
16
4.03
Hole! Heavy De osits.
44
9246
0.04
0.19
70
7
3.78
Line Corrosion. Heavy Deposits.
45
9289
0
0.18
65
3
3.86
Line of Pits. Heavy De osits.
46
9332
0
0.27
99
0
3.44
Slotted Liner Heavy Deposits.
47
9374
0.05
0.20
73
3
3.49
1 Slotted Liner Heavy Deposits.
48
9416
0.42
0.59
100
7
3.71
Slotted Liner Heavy De osits.
49
9458
0.06 1
0.31
100
6
3.17
Slotted Liner Heavy Deposits.
Penetration Perforations Penetration Body
Metal Loss Perforations ' Metal Loss Body
Page 1
CASED
HOLE
Well: 1 E-105 L2
Field: West Sak
Company: ConocoPhillips Alaska, Inc.
Joint Tabulation Sheet
Survey Date: October 3, 2019
Analyst: Waldrop
Pipe Description
5.5 in. 15.5 ppf L-80 BTCM Liner
Nom. ID
4.95 in.
Body Wall
0.275 in.
Top Depth Bottom Depth
7,425 ft. 10,348 ft.
Joint
No.
Jt. Depth
(Ft.)
Pen.
Upset
(in.)
Pen.
Body
(in.)
Pen.
%
Metal
Loss
%
Min.
1. D.
(in.)
Comments
Damage Profile
(% wall)
0 50 100
50
9500
0.23
0.84
' 100
1
3.04
Slotted Liner Heavy
Deposits.
51
9543
0.17
0.70
1 100
3
2.97
Slotted Liner Heavy
Deposits.
52
9585
0.20
0.50
100
3
3.04
Slotted Liner Heavy
Deposits.
53
9628
0.09
0.56
100
3
3.06
Slotted Liner Heavy
Deposits.
54
9671
0
0.58
100
10
3.02
Slotted Liner Heaw
Deposits.
55
9712
0.19
0.26
95
5
3.14
Slotted Liner Heavy
Deposits.
56
9753
0.14
0.45
100
11
3.32
Slotted Liner Heavy
Deposits.
57
9796
0.10
0.16
56
1
3.23
Line Corrosion. Heavy Deposits.
58
9839
0.14
0.13
47
1
3.44
Line of Pits. Heavy
Deposits.
59
9881
0.06
0.15
54
1
3.33
Line Corrosion. Heavy Deposits.
60
1 9924
0.06 1
0.08
28
0
3.34
Line of Pits. Heaw
Deposits.
61
62
9966
10008
0.08
0.05
0.13
0.13
48
48
1
0
3.35
3.37
Line of Pits. Heavy
Line of Pits. Heaw
Deno its.
Deposits.
63
10051
0
0.14
52
0
3.44
Line of Pits. Heaw
Deposits.
64
10096
0
0.14
49
3
3.56
Line of Pits. Heaw
Deposits.
65
10138
0.14
0.57
100
7
3.57
Multiple Holes! Heavy Deposits.
66
10182
0.09
0.43
100
5
3.20
Slotted Liner Heavy
Deposits.
67
10223
0.06
0.61
100
8
3.18
Slotted Liner Heavy
Deposits.
68
10265
0.13
0.46
100
13
3.07
Slotted Liner Heavy
Deposits.
69
10307
0.14
0.74
100
21
3.11
Slotted Liner Heavy Deposits.
Penetration Perforations Penetration Body
Metal Loss Perforations ' Metal Loss Body
Page 2
CASED
HOLE ` HOLE
Well: 1 E-105 L2
Field: West Sak
Company: ConocoPhillips Alaska, Inc.
Country: USA
__Tubing: __ 5.5 in. 15.5 ppf L-80 BTCM
Cross-sectional Illustration
Survey Date: October 3, 2019
Tool Type: UW MFC 40 No. 10011976
Tool Size: 2.75 inches
No. of Fingers: 40
Analyst: _ Waldrop
Cross Section for Joint 14 at depth 8,010.380 ft.
Tool speed = 53
Nominal ID = 4.95
Nominal OD = 5.5__ ---
Remaining wall area = 92%
Tool deviation = 77°
Finger = 29 Penetration = 0.925 in.
Multiple Holes 0.93 in. = 100% Wall Penetration HIGH SIDE = UP
CASED i
HOLE Cross-sectional Illustration
Well: 1 E-105 L2 Survey Date: October 3, 2019
Field: West Sak Tool Type: UW MFC 40 No. 10011976
Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches
Country: USA No. of Fingers: 40
Tubing: 5.5 in. 15.5 ppf L-80 BTCM Anal _ Waldrop
Cross Section for Joint 12 at depth 7,904.800 ft.
Tool speed = 50
Nominal ID = 4.95
Nominal OD = 5.5
Remaining wall area = 84%
Tool deviation = 77°
r e
/ 1
j
i
I
Z
I
Finger = 30 Penetration = 0.822 in.
Multiple Holes 0.82 in. = 100% Wall Penetration HIGH SIDE = UP
Cross-sectional Illustration
Survey Date:
CASED
Tool Type:
UW MFC 40 No. 10011976
HOLE HOLE
Well:
1 E-105 L2
Field:
West Sak
Company:
ConocoPhillips Alaska, Inc.
Country:
USA
Tubing:
5.5 in. 15.5 ppf L-80 BTCM
Cross-sectional Illustration
Survey Date:
October 3, 2019
Tool Type:
UW MFC 40 No. 10011976
Tool Size:
2.75 inches
No. of Fingers:
40
Analyst:
Waldrop
Cross Section for Joint 13 at depth 7,965.650 ft.
Tool speed = 49
Nominal ID = 4.95
Nominal OD = 5.5
Remaining wall area = 78%
Tool deviation = 78°
Finger = 23 Penetration = 0.252 in.
Multiple Holes 22% Cross -Sectional Wall Loss
HIGH SIDE = UP
Cross Section for Joint 42 at depth 9,202.680 ft.
Tool speed = 50
Nominal ID = 4.95 _
Nominal OD = 5.5
Remaining wall area = 79%
Tool deviation = 77°
a
` I
Finger = 1 Penetration = 0.335 in.
Multiple Holes 22% Cross -Sectional Wall Loss HIGH SIDE = UP
CASED
==
HOLE
Cross-sectional Illustration
Well:
1 E-105 L2
Survey Date: October 3, 2019
Field:
West Sak
Tool Type: UW MFC 40 No. 10011976
Company:
ConocoPhillips Alaska, Inc.
Tool Size: 2.75 inches .
Country:
USA
No. of Fingers: 40
L__ Tubing___
5.5 in. 15.5 ppf L-80 BTCM
__Analyst: Waldrop
Cross Section for Joint 42 at depth 9,202.680 ft.
Tool speed = 50
Nominal ID = 4.95 _
Nominal OD = 5.5
Remaining wall area = 79%
Tool deviation = 77°
a
` I
Finger = 1 Penetration = 0.335 in.
Multiple Holes 22% Cross -Sectional Wall Loss HIGH SIDE = UP
CASED
HOLE HOLE
Well: 1 E-105 L2
Field: West Sak
Company: ConocoPhillips Alaska, Inc.
Country: USA
Tubing: 5.5 in. 15.5 ppf L-80 BTCM
Cross-sectional Illustration
Survey Date:
October 3, 2019
Tool Type:
UW MFC 40 No. 10011976
Tool Size:
2.75 inches
No. of Fingers:
40
Analyst:
Waldrop
Cross Section for Joint 51 at depth 9,553.400 ft.
Tool speed = 50
Nominal ID = 4.95
Nominal OD = 5.5 '
Remaining wall area = 99%
Tool deviation = 76°
Minimum I.D. = 2.967 in.
Heavy Deposits Minimum I.D. = 2.97 in. HIGH SIDE = UP
I
Minimum I.D. = 2.967 in.
Heavy Deposits Minimum I.D. = 2.97 in. HIGH SIDE = UP
` CASED
HOLE
Well: 1 E-105 L2
Field: West Sak
Company: ConocoPhillips Alaska, Inc.
Country: USA
Tubing___ 5.5 in. 15.5 ppf L-80 BTCM
Cross-sectional Illustration
Survey Date:
October 3, 2019
Tool Type:
UW MFC 40 No. 10011976
Tool Size:
2.75 inches
No. of Fingers:
40
Analyst:
Waldrop
Cross Section for Joint 54 at depth 9,680.010 ft.
Tool speed = 51
Nominal ID = 4.95
Nominal OD = 5.5
Remaining wall area= 1000
/o \
Tool deviation = 78°
Minimum I.D. = 3.020 in.
Heavy Deposits
Minimum I.D. = 3.02 in. HIGH SIDE = UP
ConocoPhillips
AIaSKa.lnc.
KUP INJ
SSSV: NIPPLE
ast WO,
1 E-1 05L2
3(1541 r,2nonn-,
fE-1051-3. 4T120161D'A5:5D wsr
Last Tae
Vereesl schemaae aw,ai
Annotation
Last Tag:
Depth (ftKB) Er1d Date Last Mod By
13,018.0 6212006 Irnosbor
- -
HANGER: 22.0
Last Rev Reason
Annotation
End Data
Last Mod By
Rev Reason: PULL D -sand iso Sleeve, B -sand diverter, DBP plug (MISSED) & SET TYPE 11
DNERTER
92012017
pproven
Casing Strings
Casing Descriptio n Cb (In)
ID (int Top (ftKB) Set Depth (hKB)Set De pM (TVD)... wVlen (I... Grade Top Thread
cor4D UGTDR: 31 a/rDD
D -SAND LINER HH 5 12
4.950 7,260.4 7,416.3 3,558.2 15.50 L-80 BTCM
Liner Details
NIPPLE; 503.2
N-iri.l 10
Top (ftKB) Top (TVD) (ftKB)
Top Incl (% Item Des Cam lin)
7,260.4 3,628.6
7619 HANGER B ER MODEL -1 00 HANGER FOR LEM 3.688
3,34.6
3 XCIBUSHING 1CROSSOVER H N 3.94
7,306.9 3,538.4
78.69 PACKER BAKER PAYZONE EXTERNAL CASING PACKER 5.500
SURFACE; 30.0.3.DD5.3
CaaMg DesOrip[fon (In)
D (In) Top (hKB) Set DepM (ftKB) Set Depth (TVD)... WI/Len 11... Grade Top Thread
GAS LIFT: 4,21ZD
D -SAND LINER 51/21,
4.950 7,370.9 13.536.7 15.50 1--80
Liner Details
GAS LIFT; 5.712 9
Top (hKB)
Top (TVD) (ftKB)
Top Ind (°)
Item Des
Com
Nominal ID
(In)
SLEEVE: 7.103.9
7,370.9
3.550-5
79.61
SLEEVE
BAKER'HR' LINER SETTING SLEEVE
5.000
Perforations & Slate
Shot
LOCATOR; 7.211.1
Btm (TVD)
Dena
(shotalfl
Top (hKB)
(hKBI
Zone
Date
)
Type
Com
8,024.03511.7
WS D, -
116/2005
4 ,O
SLO
Slotted Liner, altemating
SEALASSY:7111.86
1051-2
points of blank/slotted liner
for all DSand slots 2.5
t..
x.125 holes, 4 rows/ft
8,61 .0
.8
WS ,7 -
6 1 00
4 .0130
SLEEVE: 7240.D10512
9,331.
3,4864
, 1 -
6/16/200D
-SAND LINER LEM; 7,190.0-
10512
7A 25INTERMEDIATE;25.1-a.299.0
0, .0,
3,468.9
, 1 -
6/162005
40.0
SLOTS
10512
10512
11.41 _0
11,457-0
469W
,471.2
N09 D, 1E-
6/1 005
.0
S O S
10512
1051-2
12,6 8.0
1 , 3.0
3,41
15.
V796.1 -
6/162005
4
LO S
D -SAND LINER HH; 7,211 -
105L2
7,415 3
12.31500
12,9450
3,4 12.31
.'q'u
WS D' I E-
1051-2
6/1612005
400
SLOTS
12,988.0
i3,074.0
3,4 .9
.6
WS , tE-
162005
40.
SEbT
SLOTS: 0.024.0-0.399.0
1051-2
3,118.0
1.
0 .4
3.
WS
1 0
0.
SLO
1051-2
13,244.0
1 .0
,3
3, 02.7
3,
S D. -
6/162 5
40.0
S O S
SLOTS, 8.012.0-9.120.0
10512
13,3
13, 92.0
3,399.0
3.396.5
WS D, tE-
162005
40.0
SL S
1051-2
SLOTS: 0.331.0-G.7" O
Notes_. General
& Safety
End Dote
Annotation
6118 005 NOTE: 8.5' OPEN
HOLE BEHIND SLOTTED LINER
SLOTS: 10.181.0-10.002.0 - -
6/182005 NOTE TRI -LATERAL
WELL: A -SAND (11E-105), B -SAND (1E-1051-1), DSAND (1E-10511)
-
w 0
SLOTS. 10.587.0-11.070.0
1/292009 NOTE- View Schematic
w/ Alaska Schemalic9.0
9/11/2010 NOTE- MBE repair
w/9 bbls of 1 G I -2289E. 106 degree rnelipoini wax Q 8750'
/4/2011 N : PROFILE
MO IFI A N - PUMPED 2310 LBS (4MM) CRYSTAL SEAL IN B LATERAL M EIM8750
SLOTS: 11.41&0-1
SLOTS. 11.885.0-12.387.0
SLOTS, 12.088.0-12.773,0
SLOTS; 12,000 0-12.94S.0
SLOTS: 12.988.0-13.074.0
SLOTS; 13,118.0-13.201-0
SLOTS: 13244.0-13.329.0
SLOTS: 13,31416,0-13.492 0
D -SAND LINER: 7.370.9-
13,530,7
V-1 1 E-105 'D' Sand Liner Detail
ConocoPhillips 5-9/2" Slotted and Blank Liner
Alaska, Inc.
Well:
Date:
1 E-105
6/15/2001
DEPTH
A Number
Num of As
COMPLETE DESCRIPTION OF EQUIPMENT RUN
Page 1
LENGTH
TOPS
Running Tool Does not stay in hole
12.29
7358.58
Baker "HR" Liner Setting Sleeve, 7"
8.28
7370.87
7" BTCM, 26 ppf, L-80 PUP JT
4.30
7379.15
7" BTCM, 26 ppf, L-80 Blank Casing
41.19
7383.45
7" BTC Box X 5-1/2" BTC Pin Cross Over
1.16
7424.64
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
42.23
7425.80
Jts 129 to 141
13 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
556.59
7468.03
Jts 120 to 128
9 Jts
5-112" BTCM, 15.5 ppf, L-80 Slotted Casing
375.34
8024.62
Jts 115 to 119
5 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
212.59
8399.96
Jts 103 to 114
12 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Slotted Casing
507.93
8612.55
Jts 98 to 102
5 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
210.54
9120.48
Jts 87 to 97
11 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Slotted Casing
463.16
9331.02
Jts 78 to 86
9 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
387.40
9794.18
Jts 68 to 77
10 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Slotted Casing
420.78
10181.58
Jts 62 to 67
6 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
255.47
10602.36
Jts 57 to 61
5 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Slotted Casing
212.88
10857.83
Jts 49 to 56
8 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
344.55
11070.71
As 48 to 48
1 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Slotted Casing
42.67
11415.26
Jts 38 to 47
10 AS
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
427.23
11457.93
Jts 26 to 37
12 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Slotted Casing
501.92
11885.16
Jts 19 to 25
7 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
301.22
12387.08
Jts 17 to 18
2 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Slotted Casing
85.25
12688.30
Jts 15 to 16 1
2 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
86.64
12773.55
As 13 to 14
2 As
5-1/2" BTCM, 15.5 ppf, L-80 Slotted Casing
84.94
12860.19
Jts 12 to 12
1 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
43.39
12945.13
AS 10 to 11
2 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Slotted Casing
86.38
12988.52
Jts 9 to 9
1 AS
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
43.44
13074.90
As 7 to 8
2 As
5-1/2" BTCM, 15.5 ppf, L-80 Slotted Casing
83.16
13118.34
As 6 to 6
1 AS
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
43.39
13201.50
Jts 4 to 5
2 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Slotted Casing
84.88
13244.89
Jts 3 to 3
1 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
37.07
13329.77
As 1 to 2
2 Jts
5-1/2" BTCM, 15.5 ppf, L-80 Slotted Casing
84.13
13366.84
5-1/2" BTCM, 15.5 ppf, L-80 Slotted Casing (Insert @ Pin)
41.40
13450.97
5-1/2" BTCM, 15.5 ppf, L-80 Blank Casing
42.42
13492.37
5-1/2" Silver Bullet guide Shoe No float
1.87
13534.79
13536.66
8 1/2" Hole TD @ 13,530' MD / 3,396' TVD
Note; Tagged Btrn @ 13,536.66' when ran liner.
Ran total of 71 'ts Blank 3,034.17' and 73 'ts Slotted 3,074.82'w/ 10 2.5" long x 1/8" wide in
up Wt
215K
4 circumferential rows. Drifted casing to 4.825" w/ teflon rabbit.
Dn Wt
70K
Ave. MU Torque 5500 to 6000 Ft -Lbs, Ran Torque Rings on Liner
Block Wt
35K
16 Constrictors @ 12661', 12411', 11866', 11486', 11406', 11096', 10854', 10636', 10156', 9796', 9311', 9116'
8607', 8,406', 8006' & 7426'
Ran 141 Aluminum 5 1/2" x 7 5/8" x 8" solid Body Cent. 1/'t Floating 95- LH & 47- RH Cent.
Supervisors: Mike Thornton / Peter Wilson / Dan Lowe
l]6r M0 -]•121 -PI' 121 teams
ze6T w- r x 93,T 1\P
.M, 11i1�Dwrrn
Lateral Entry
� M,,.,os,df�u�le (LEM)
rxq4vzxPLawToP
Pecker with Ndd Dowels
Casing SeaboreReceptacle
4.75 10. 575 00
Td11ro Swivel4a1r
_— odMalnp Prom
Au6wna0c AliOwrwnt of LEM
P.M. Leaching COW
kldcat® Conecl Lorabm
Seal Bore for L"M
P.". -3.6or to
A— WYWow
P_ftive Lateral Access wa
Thru-Tubing Dk lw
o
lgd efor LatDr01
ls
Isoldin - 3d611'
ladaeun Sed Asatldr
4.75" 644100 3.975 Sed 11
r Length
Baler OB Yeah
CONFIDENTIAL
09 Ruenirw Tool StrYry
—cos eoe•wow.
11A6'Lsn.EU
aW Prtssure Mahe
11AP La,wwl
� Fbw-r6ry SrrirM
2Ie b� , Ubnl bontlan Dlrwkr
.M �:R9"u.w,I mwaaea
asap Nenap Oul
l Pmibn� albe�
LaMal wolalio,l--�
— 5112- Casing Sho.. 15.58. L 00 BTCM n2r Lw,Mm {•ab
�„� rMs•w-r Set 013530 MD, 3390 TVD Mye1k fLabe ""
164a]'w-raw<a Obeoa,rct Ydrtow Mamewa�
Sw-B LMran of a•AAaeee6M a,wn.w P.nM La•pmf Dir,mr war.
J.>6'aa/W �Ja/Laaoa,l ` L laalalm�
16nY MD-iWb. awl...l.,-1? MSRRrpoa, ,w wale
]e0Y w - Lalnal EWr a—
(LEh wbaP-PPI� w-o'�Y b�W was—u.. t9 n1,•aa l,,,al!
B -sand window top aBr Sand Lateral
at 7524' MD, 79 deg
/ Incl.
6 -In' 16.61. Lan wines um.
EwrY �na,Jwa s.ur 9•nlJwnc
nes• w -r assn•
s1,r e,e6. sl,e•
5-112" Casing Shoo, 15.50, L -1g) OTCM
sw wrR _ Set @ 13508' MD. -3479' TVD
3.V p7 1]z,P NO-Paeaoft
75?r*D-3Aa2"Da MOrb B,wMn.
Px6J,rxfrP iaM'w-
LYwTop Paeaw
/// asa•,wh
ur 6.,100
r x�oNn.. Loop
u,w. Aa.wrAyn afro
•. 26fYM0
Eauioment Snecifications
7- X 9.518•' HOOK Hanger
M—bore Drift: 7.00'
Malne.m Lldft, with dteeDer. a25
LEM DrUL no dvener W LEM: 6.211'
L.bnai Drift, wl Amner, no LEM; sir
Lalmilltalnbor. Divwtw OD: 8.50'
4.112" Lateral Entry Module
Mabdlwe Drift: 385'
McMae Dort, w,,-4xfion .1—: 250•
Lawal DrBf, wl Coll dhv .. Ur
OD of Divente and Si.we: M. 380"
�1 WSandUndulatina�teralUndulatina�teral�Dn"nrandSMwaungb:+r-,a
n•�Loaenw.sixm �� e-ta•Eeeeewa
GuY!{nee
26121 MD -Gaawa 6eaben
a.aerMel. J.lrM 5 -Set Casing'MD.- 623'DTCM
Set g 13519' MD, J623' TVD
9-510' Ceeing Shoe, 40.00, L-80 BTC uasr w- P.e,<n
a 829W MD, 3112' TVD wa
raaw naMwa moa. rnb wwww+raaraxa nw.rw.6wwrmMea b.e,b abrrLmarraeaw (80 deg incl Mce,.g.e...npw
eW rweelewm alMmbwrhenWl ls,edlq M,m^.rlba.na�a 2Nx rtlan abnne 2we aan
arwA .612.6,,... w aw:eae. bw.we..wwm.em. ree�t>aba iM�.n�ea i..�
h,w 16. ]aW WCD. KurA
I
Tu6irg, Special Drfa to .9- 580' MD
ConocoPhi l l i ps
503'MD-DB6Nippa,3.875
West Sak 9-5/8" Injector
------ 4217' MD - GLM, Cenlco NBG2-1R, 4-112• X 1'•
1 E-1 05
611T MD - GLM, C.—KBG2-1R, 4-112"X 1-
Tri -Lateral Completion
13-3111' Casing Slee,
7160 MD - CMU Sliding 56eve, wl 3.81" DO Nipple
680, DTC at @ 3905'
MD, 2285' TVD
wa.Pw., air o
Tubing String
/// lx4s•10-L,wrn L„trl Modub lLFMn
3195 1ieT4
L-80
/
In, 3.
195(1' 1D, Drat
833-
Da—d Window
N 7238' MD, 78
V Sand Lateral
lrarL�.T xser alP
rue•Yo-
eotlomafeM deg incl. -1 cl. r rew, Lab Neeea
r
ep raWw
,rq ROM ne+rs
Masbtr EverFfOUer JdM
lir MM06 lH•4i{P ywl4tlYD-Lln•j N �bl
rz BeetJwM
l]6r M0 -]•121 -PI' 121 teams
ze6T w- r x 93,T 1\P
.M, 11i1�Dwrrn
Lateral Entry
� M,,.,os,df�u�le (LEM)
rxq4vzxPLawToP
Pecker with Ndd Dowels
Casing SeaboreReceptacle
4.75 10. 575 00
Td11ro Swivel4a1r
_— odMalnp Prom
Au6wna0c AliOwrwnt of LEM
P.M. Leaching COW
kldcat® Conecl Lorabm
Seal Bore for L"M
P.". -3.6or to
A— WYWow
P_ftive Lateral Access wa
Thru-Tubing Dk lw
o
lgd efor LatDr01
ls
Isoldin - 3d611'
ladaeun Sed Asatldr
4.75" 644100 3.975 Sed 11
r Length
Baler OB Yeah
CONFIDENTIAL
09 Ruenirw Tool StrYry
—cos eoe•wow.
11A6'Lsn.EU
aW Prtssure Mahe
11AP La,wwl
� Fbw-r6ry SrrirM
2Ie b� , Ubnl bontlan Dlrwkr
.M �:R9"u.w,I mwaaea
asap Nenap Oul
l Pmibn� albe�
LaMal wolalio,l--�
— 5112- Casing Sho.. 15.58. L 00 BTCM n2r Lw,Mm {•ab
�„� rMs•w-r Set 013530 MD, 3390 TVD Mye1k fLabe ""
164a]'w-raw<a Obeoa,rct Ydrtow Mamewa�
Sw-B LMran of a•AAaeee6M a,wn.w P.nM La•pmf Dir,mr war.
J.>6'aa/W �Ja/Laaoa,l ` L laalalm�
16nY MD-iWb. awl...l.,-1? MSRRrpoa, ,w wale
]e0Y w - Lalnal EWr a—
(LEh wbaP-PPI� w-o'�Y b�W was—u.. t9 n1,•aa l,,,al!
B -sand window top aBr Sand Lateral
at 7524' MD, 79 deg
/ Incl.
6 -In' 16.61. Lan wines um.
EwrY �na,Jwa s.ur 9•nlJwnc
nes• w -r assn•
s1,r e,e6. sl,e•
5-112" Casing Shoo, 15.50, L -1g) OTCM
sw wrR _ Set @ 13508' MD. -3479' TVD
3.V p7 1]z,P NO-Paeaoft
75?r*D-3Aa2"Da MOrb B,wMn.
Px6J,rxfrP iaM'w-
LYwTop Paeaw
/// asa•,wh
ur 6.,100
r x�oNn.. Loop
u,w. Aa.wrAyn afro
•. 26fYM0
Eauioment Snecifications
7- X 9.518•' HOOK Hanger
M—bore Drift: 7.00'
Malne.m Lldft, with dteeDer. a25
LEM DrUL no dvener W LEM: 6.211'
L.bnai Drift, wl Amner, no LEM; sir
Lalmilltalnbor. Divwtw OD: 8.50'
4.112" Lateral Entry Module
Mabdlwe Drift: 385'
McMae Dort, w,,-4xfion .1—: 250•
Lawal DrBf, wl Coll dhv .. Ur
OD of Divente and Si.we: M. 380"
�1 WSandUndulatina�teralUndulatina�teral�Dn"nrandSMwaungb:+r-,a
n•�Loaenw.sixm �� e-ta•Eeeeewa
GuY!{nee
26121 MD -Gaawa 6eaben
a.aerMel. J.lrM 5 -Set Casing'MD.- 623'DTCM
Set g 13519' MD, J623' TVD
9-510' Ceeing Shoe, 40.00, L-80 BTC uasr w- P.e,<n
a 829W MD, 3112' TVD wa
raaw naMwa moa. rnb wwww+raaraxa nw.rw.6wwrmMea b.e,b abrrLmarraeaw (80 deg incl Mce,.g.e...npw
eW rweelewm alMmbwrhenWl ls,edlq M,m^.rlba.na�a 2Nx rtlan abnne 2we aan
arwA .612.6,,... w aw:eae. bw.we..wwm.em. ree�t>aba iM�.n�ea i..�
h,w 16. ]aW WCD. KurA
I
THE STATE
°fALASKA
GOVERNOR BILL WALKER
John Peirce
Sr. Wells Engineer
ConocoPhillips Alaska, Inc.
P.O Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E -105L2
Permit to Drill Number: 205-008
Sundry Number: 318-068
Dear Mr. Peirce:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax 907.276.7542
www.00gcc.ataska.gov
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 fizrther
time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
Hollis S. French
Chair
k II-
DATED this 216 day of February, 2018.
RBL'WIS U/ F-:2 2) 7 "t18
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
RECEIVED
FEB 21 2018
AOGCC
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑
Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. MARCIT D MBE Trtmnt Q ,
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
ConocoPhllll s Alaska Inc.
Exploratory ❑ Development ❑
Stratigmphic ❑ Service
205-008-
05-008-3.
3.Address:
6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510
50-029-23243-61
7. If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? N/A
KRU 1E -105L2 '
Will planned perforations require a spacing exception? Yes ❑ No (]
9. Property Designation (Lease Number):
10. Field/Pool(s):
ADL 25651, ADL 25660 •
Kuparuk River Field / West Sak 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):
. 13,530' 3,396' 13,530 3,396 1500psi
NONE NONE
Casing Length Size MD TVD
Burst Collapse
Conductor 139' 20" 170' 170'
Surface 3,875' 133/8 3,905' 2,586'
Intermediate 7,233' 95/8 7,258' 3,713'
D Sand Liner 5,900' 4112 7,492' 3,577'
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
8024-13492 MD
3533-3396 TVD
4.500"
L-80
7,229'
Packers and SSSV Type:
Packers and SSSV MD (ft) and TVD (ft):
PACKER = BAKER Payzone Packer
7307 MD and 3538 TVD
12. Attachments: Proposal Summary Wellbore schematic 0
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stmtigraphic ❑ Development ❑ Service R1
14. Estimated Date for 4/1/2018
15. Well Status after proposed work:
Commencing Operations:
OIL ❑ WINJ 21. WDSPL ❑ Suspended ❑
GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
16. Verbal Approval: Date:
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Name: John Peirce Contact Name: John Peirce
Authorized Title: Sr. Wells Engineer Contact Email: John.W. Peirce@cop.com
r� Contact Phone: (907) 265-6471
Authorized Z�/
Signature: Date: 2
COMMISSION USE ONLY
Conditions of approval: Notify Commissioill so that a representative may witness Sundry Number:
Z
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑
Other:
1/
Post Initial Injection MIT Req'd? Yes El No L7
Spacing Exception Required? Yes E]No LrJSubsequent Form Required:/Q — iLaRBDMS Vit, F7 i ? /l�8
APPROVED BY
\
Approved by: COMMISSIONER THE COMMISSION Date: •- I ^ I \e
Form 30-003 Revised 4/2017 Approved ap ca ion rs valid for 12 months from the date of approval.
Submit Form and
Attachments in Duplicate
�,��, 4L�1_M'(i'2_92_3'2d3'61 KUP INJ
Conn 4f L fillips Well Attributes
Aas9w.HC.
1E -105L2
ISSSV'. NIPPLE I I ILast WO 1 1 30.591 61202005
1E-,fPLi. i/aOpla ]:0f 03AM
Last Tag
o
AnnWtlon
DepM(MLBI Le[tMM By
----. ----
----
Last Tag:
Jeraldine,
13,018.0 N21MOS ImoSbor
Last Rev Reason
HANGER; 226
Annoblon
EnEOeb
WLMW By
Rev Reason: PULL D -sand iso sleeve,
8 -sand diveder, One plug
(MISSED) 8 SET TYPE II
92020D
ppr0ven
Cuing Strings
Leans Oland priono00n)
lO fnl T°PtM'el
sel Dept lrcRel see o"m mDL.. wIM1en 11... Ghee Top Th.
LCNDOOTOR: a, O.,]oo
D -SAND LINER HH 512 4.950 ),2604
],4163 3,558.2 15.50 L-80 BTCM
Liner Details
NIPPLE, Sit
Nominalto
Top {X1(81 7°,4(5101 {51518)
Tip Intl {'I Sam De[
Com Ilnl
O
7,260.4 3,528.5
78.19 HANGERBAKER
MODEL B-1 HOOK HANGER FOR LEM 3686
4
),28)8 6
803 XO BUSHING
CROSS OVER BUSHING 3.940
],306.91 6 b6b 41
78.69 PACKER
IBAKER PAYZONE EXTERNAL CASING PACKER 5.500
SJRFACE; 300-3,901
Gsbq Deuflplion Wond
ID lin) Top11d:B)
SH Oep,M1 (X1(8) Se, ""m RVDI__, wt'Len ll...GMa Top Tllreee
GAS LFT; a11T0
O AND LINER 512 4950 ),3]0.9
13,5367 15.50 LA0
Liner Details
GhS LIFT:4Tlza
x°min.l l0
Tip (MB) Tap INDHNKel
i
ToplMll') INm pea
Lom 9n)
SLEEVE; 71.a
7,3709 3,550.5
7961 JOLIEIEVE
ibAKER' HRLINER SETTING SLEEVE 5.000
Perforations & Slots
Shot
LMATOR;),2111
TO
B
De
'asunder
TOP)
am Me)
WS)
Me)
Zone
w b
Tow
cam
8.024.0
8,3990
3,533.0
3,511.]
WS D. 1E-
&162005
40.0
SLOTS
Slod¢n Liner, alMmating
9Ext Assq 72ue
10512
join of blanldslotled liner
for all DSand SIM 2.6
x.125 Mies, 4 r0wslR
8,612.0
9,1200
3,505.5
3,489.8
WS D, TE-
6116205
400
SLOTS
Ise s1EEVe 7240.o
105U
9,3310
9,]94,0
3,485.8
3,485.4
WS D, IE-
6116200
40.0
SLOTS
INTEesed..: 25.1-8.13
D.D LINER LEM', 7.140.6 �
Ta32.s10,181.0
10L2
10,60P.0
3.4756
3,468.9
WS D. IE-
gs z
Wl WO05
400
SLOTS
10,587.0
11,0700
3,4689
3,461,4
WS D. 1E-
8162005
400
SLOTS
10512
11,415.0
11,4570
3,4688
34712
WS D. 1E-
61162005
400
SLOTS
®
105(2
11,885.0
12,3870
3,4606
3,4306
AS D, 1E-
6116205
40.0
SLOTS
10512
bsAxO LINER W. 7]80.4
Tne]
12,6880
12,])30
3,419.9
3,4158
WS D, 1E-
105U
611612005
40.0
SLOTS
12,80.0
12,945.0
3,412.3
3,410.0
WS D, 1E-
6116200
40.0
SLOTS
105L2
sorra: e.ouoaasa.o—
12,9880
13,074.0
3,408,9
3,4076
WS D, 1E-
0511
61162005
40.0
SLOTS
13,1180
13,201.0
3,40.4
3,4036
WS D, 1E-
6116200
40.0
SLOTS
10512
13,2440
13.329B
3,402.7
3,402
W50, 1E-
0BW05
400
SLOTS
SLOT5:8.412.1mo—
105L2
�r
13,366.0
13,492.0
3,399.0
3,3965
WS5,1E-
8162005
40.0
SLOTS
LOTS, a,Y,108,)eao�
1D512
Notes: General
& Safety
Ene Ozm
Arminian,
SLOTS. 10,1610406020--
--
6/18/2005 NOTE: 8.5 OPEN
HOLE BEHIND SLOTTED
LINER
C
6/8/2005 NOTE:TRI-IATERALWELL
A-SAND(1E-105),B-SANO(1E-105L1),D-SANO(1E-105(2)
51182006 NOTE: B -SAND LEM
CONTAINS CAMCO'DB'
NIPPLE w13.92" ID @ 7578'
SLOTS;1O,Sn.,.O__
r—
12912(K9 NOTE. View ScRema4c
wl Alaska Spearhead)0
91112010 NOTE: MBE repair
wH We of 1 31-22B9E,
105 degree melmoire wax @8750'
r'
Ti NOTE: PROFILE
MODIFICATION -PUMPED 2310 LES(4MM) CRYSTAL SEAL IN B LATERAL MBE@8750
YOi5:1,A,Sb11,48/.0��
lr
BLGTa: ,,.aesb,zxTp—
r
F
$LOTS lZ.03 12T9.0-1
`
SLOTS: 12fi50.0.13p45O�
SLOTS: 1z8SSU613.OT4U�
SLOTS: 131180.13.510
SLOT3: 1324A0.13.3ID.0�
SLOTS:,3,3p).D13.4920�
0.3.4510 LINER:,7,%
13538.7
Proposal 1E -105L2 to 1E -126L2 D MBE Treatment with MARCIT Gel
1 E-105 Tri-Lat injector has 4.5" tubing and horizontal laterals in the West Sak A, B, and D sands.
1E -105L2 D Lat exists at 7258 - 13536' RKB with 5.5", L-80 slotted liner. A 1 E -105L1 B MBE
RPPG job was pumped 5/1/17 with A & D Lats isolated. Post RPPG FCO, the 'B Lat only' was BOI
for 1 month with offset 1E-126 showing lower WC% and rising BOPD, so the A Lat Plug & D Iso
Slv were pulled to gett all Lats back on injection, but this resulted an immediate spike up in 1 E-126
WC%. On 6/18/17, a 1E-105 mainbore IPROF saw 73% D, 26% B, 1% A (to suggest a D MBE).
On 9/18/17, a D ]PROF found all injection exited the D Lat at -7260' RKB at the D LEM junction,
with injection possibly flowing down backside of D Liner to top of the first slotted liner -764' below
the D LEM. The IPROF shows no down flow occurs in the first 764' of D Lat (blank liner section),
but there may be some upf]ow in this section back up to the leak at 7260' per Spinner responses.
We conclude all flow exits at D LEM, and some injection may flow -764' behind blank liner to enter
the D Lat at the first slots at -8024' RKB. We cannot quantify flow splits that may go to a D MBE
above 8024', or flow back into the D Lat below 8024', but the IPROF shows significant matrix
injection exists at 8024 to 9500' RKB. D MBE location is unknown, but IPROF results suggest that
an MBE (or very high perm thief) most likely exists somewhere behind the 764' blank liner section.
On 2/2/18, a Plug was set at 7578' RKB to isolate A Lat, a B Diverter was set at 7520' RKB, and a
D Iso-Slv was set. We would need to reconfigure 1E-105 for a proposed D Lat MARCIT MBE job.
It is proposed that MARCIT Gel be pumped through the leak at 7260' RKB at D LEM with intent
Of,
a) Halting all flow exiting D Lat at D LEM to restore all injection to the inside of D Lat liner, and to
b) Seal D MBE, or high perm thief, that likely exists behind blank liner section at 7260-8024' RKB.
Proposed Procedure:
Coil Tubing:
1) RIH & pull D Iso-Slv from D LEM at 7240' RKB.
2) RIH & pull B Diverter from B LEM at -7520' RKB.
3) RIH & set B Iso-Slv in B LEM at 7520' RKB.
4) RIH & set D Diverter at -7240' RKB.
Fullbore Pumping:
5) MIRU MARCIT Gel pumping equipment. Fullbore pump a Crosslinked Accelerated Viscosity
MARCIT Gel job down 4.5" Tubing at 0.6 - 1.0 bpm to meet objectives listed above as follows:
Pre -Flush with 50 bbls 2% KCL Brine, followed by 30 bbis Lead 10,000 ppm Linear Gel Spacer
mixed in 2% KCL Water, followed by -35 bbls of Accelerated MARCIT Gel at 10,000 ppm mixed in
2% KCL Water, followed by 35 bbls Tail 10,000 ppm Linear Gel Spacer mixed in 2% KCL Water,
followed by 28 bbls 2% KCL Water, followed by 47 bbls Diesel FP to 2000' TVD, followed by
Shutdown to complete a full displacement of all Accelerated X-linked MARCIT into the D MBE.
Leave well SI 5 days to let treatment cure.
Return 1 E-1051-2 to injection to 'D sand only' to evaluate results of the D MBE treatment, and to
consider performing another D lateral IPROF to verify any changes in D Lat injection performance.
JWP 2/21/2018
-LAS- 0o`‘
• zo5 64{
WELL LOG
TRANSMITTAL
PROACTIVE DiAqNosTic SERVICES, INC. —
To: AOGCC OCT 0 6 2017
Makana Bender DATA LOGGED
333 West 7th Avenue AOGCC ,0„.0,2°,1 Suite 100 K BENDER
Anchorage, Alaska 99501
(907)793-1225
RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT)
The technical data listed below is being submitted herewith. Please acknowledge receipt by
returning a signed copy of this transmittal letter to the attention of:
ProActive Diagnostic Services, Inc.
Attn: Ryan C.Rupe
130 West International Airport Road
Suite C
Anchorage, AK 99518
Fax: (907)245-8952
SCANNED
1) Injection Profile 21-Sep-17 1E-105 L2 Color Log/CD 50-029-23243-61
2)
Signed : � Date :
Print Name:
PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (907)245-8951 FAX: (907)245-8952
E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM
D:\Achives\MasterTemplateFi les\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx
•
~'= ---
MICROFILNAED
03/01/2008
~;
y,~.
DO NOT PLACE
ANY NEW 11~ATERIAL
UNDER THIS PACE
F:\LaserFiche\CvrPgs_InsertstMicrofilm Marlcer.~c
Permit to Drill 2050080
MD 13530
.J q J~k
DATA SUBMITTAL COMPLIANCE REPORT
7/2/2007
Well Name/No. KUPARUK RIV U WSAK 1E-105L2
Operator CONOCOPHILLlPS ALASKA INC
API No. 50-029-23243-61-00
TVD 3396
~
Completion Date 6/19/2005
Completion Status 1-01L
Current Status 1WINJ
REQUIRED INFORMATION
Samples No
Mud Log No
Directional su~
DATA INFORMATION
Types Electric or Other Logs Run: GRlRes
Well Log Information:
Log/
Data Digital
Type Med/Frmt
~ASC
C Lis
,
l
(data taken from Logs Portion of Master Well Data Maint
Electr e
Dataset Log Log Run Interval OH/
Number Name Scale Media No Start Stop CH Received Comments
Directional Survey 7175 13530 Open 7/29/2005 IIFR
Directional Survey 7175 13530 Open 7/29/2005 MWD
13428 Induction/Resistivity 3862 13492 Open 1/31/2006 GR/EWR4/ABIICNP/SLD/R
OP/ACAUPWD/GEOPILOT I
13428 LIS Verification 3862 13492 Open 1/31/2006 GRlEWR4/ABI/CNP/SLD/R
OP/ACALlPWD/GEOPILOT
15034 Induction/Resistivity 3862 13485 Open 4/17/2007 LIS Veri, GR, FET, ROP,
NPHI, FCNT, NCNT,
RHOB, DRHO, CALA
w/Graphics CGM, EMF,
PDF
Well Cores/Samples Information:
Name
Interval
Start Stop
Sample
Set
Number Comments
--
Sent
Received
ADDITIONAL INFOR.~ON
Well Cored? Y''\Y
Chips Received? ""y I N ~
Daily History Received?
{0N
(iN
Analysis
Received?
Comments:
Formation Tops
~
----
DATA SUBMITTAL COMPLIANCE REPORT
7/2/2007
Permit to Drill 2050080
Well Name/No. KUPARUK RIV U WSAK 1E-105L2
Operator CONOCOPHILLlPS ALASKA INC
MD 13530
TVD 3396
~ Date 6119/2<)05
Completion Status 1-01L
Current Status 1WINJ
API No. 50-029-23243-61-00
UIC Y
Date:
-1ðJ'lf) ~7
Compliance Reviewed By:
e
-
e
e
\VELL LOG TRAJ.~SMITT AL
To:
State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Librarian
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
April 16, 2007
RE: MWD Formation Evaluation Logs: IE-I05, Ll, L2 & PB2,
AK-MW-3677560
The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention
of:
Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518
IE-lOS, Ll, L2 & PB2:
LIS & Digital Log Images:
50-029-23243-00,60,61, 71.
1 CD Rom
.REC.E
c.
jJ.DP l' ''''/
-;ì f\ .. ~
à 1-.;._ n~ .'\'. .~"'.. "'. "",, r"" .. . .
~ ",,! iJ( ,~w,"', (\,;Crr~
A,,*rage
UI <! ~oS--Có(::,
it ) £D3d
u:::c c, 9-0S-- 00+
7f
ls-033
U:Lc-'- Sö')- -oo1r
~ lS-ó3 C{
..,;t- I 5035
t-1
'.
.
WELL LOG TRANSMITTAL
To:
State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Ceresa Tolley
333 West 7th Avenue, Suite 100
Anchorage, Alaska
November 14, 2005
RE:
MWD F onnation Evaluation Logs
I 34 )<6
9-05 - DOß
lE-105 L2, AK-MW-3677560
1 LDWG fonnatted Disc with verification listing.
API#: 50-029-23243-61
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL
LETTER TO THE ATTENTION OF:
Sperry Drilling Services
Attn: Rob Kalish
6900 Arctic Blvd.
Anchorage, Alaska 99518
Date: Ic9 /ï los
Signedt~)
e
e
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
2. Operator Name:
ConocoPhillips Alaska, Inc.
3. Address:
P. O. Box 100360, Anchorage, Alaska 99510
7. KB Elevation (ft):
RKB 94'
8. Property Designation:
Kuparuk River Unit
11. Present Well Condition Summary:
5. Permit to Drill Number: c!JI'1--
~
6. API Number:
50-029-23243-61
9. Well Name and Number:
1 E-105L2
10. Field/Pool(s):
Kuparuk River Field / West Sak Oil Pool
Total Depth
measured
13530'
3396'
feet
feet
feet
feet
Plugs (measured)
Junk (measured)
true vertical
Effective Depth
measured
true vertical
Casing
Structural
CONDUCTOR
SURFACE
INTERMEDIATE
PROD. CASING
Length
Size
MD
TVD
Burst
Collapse
170'
3811'
8196'
6166'
20"
13-3/8"
9-518"
5.5"
170'
3905'
8290'
13537'
170'
2285'
3712'
3396'
Perforation depth:
Measured depth: 8024'-13492'
true vertical depth: 3533'-3396'
RBDMS BFl SEP 1 5 2005
Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7229' MD.
Packers & SSSV (type & measured depth) no packer
SSSV= NIP SSSV= 503'
-~------rol'tT1fO=4Œ4-ReviSe004/20o-~-~--~-
--'-"~---~----~'---------~
Submit Original Only
It
e
1E-10SL2
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
9/6/200S Commencewd WINJ
- -----..--.-.. "'------------..--....
-- -------------,--.------_.._-----,------,...-,--------------_.-------~----
e
1f~lJΠ(ffi~
e
I
n ¡.'¡\ (fù!V7 '70
l1lA\ ~ ~~ ~J
FRANK H. MURKOWSKI, GOVERNOR
AI,ASIiA OIL AND GAS
CONSERVATION COMMISSION
333 W. ?fH AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Robert D. Christensen
Production Engineering Technician
ConocoPhillips Alaska, Inc.
P.O. Box 100360
~chorage,Alaska
F#'J... ðA
Re: Kuparuk 1E-105L2
Sundry Number: 305-253
Dear Mr. Christensen:
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.
Please provide at least twenty-four (24) hours notice for a representative of the
Commission to witness any required test. Contact the Commission's petroleum field
inspector at (907) 659-3607 (pager).
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such
further time as the Commission grants for good cause shown, a person affected by it may
file with the Commission an application for rehearing. A request for rehearing is
considered timely if it is received by 4:30 PM on the 23rd day llowing the date of this
letter, or the next working day if the 23rd day falls on a h äa or weekend. A person
may not appeal a Commission decision to S4perior nless rehearing has been
requested.
DATED this iday of September, 2005
End.
. .
/t.
e
C(l} W'O;
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMI :~SION
APPLICATION FOR SUNDRY API:tROVAL
20 MC 25.280
.Opel1lllonShu1¡;!OWrl '0
Pll,Ig Perforations 0
o
1i!v
.' R'e~lr¡i/$U "·0
,,Ii~:ullTl;\l:1io9, ~; . 0
"', D" .' ". ""~i~arO .
'.,0 .' ,TIm.'I;;¢\!rnaIO~,[] . p~~~r~~tQ WIN¡J
R~f"otØr:Sù~P(I¡'II;iedW~1I . :,0 .
5. Permit to Drill Number;
50-029-23243-61
9. ~ Jell Name and Number;
E·105L2
,
10. :'ietdIPool(s}:
Ku~ ¡Iruk River ~¡eld (West Sak Oil Pool
PRESENT WELL CONDITION Sl 'MMARY
Effective Depth TVD (ft); PluQ$ ITleasurèd); Junk (measured):
1,ty'p~~ot'ì î{aqM~~t: ',~Þin~?~
. ' " '. ". AI\~r~~lnll"
" ~,~\I~~I!,~~r<R'1I~,prqpra~"
2. Operator Name;
ConocoPhillips Alaska, Inc.
3. Addr$$~;
P. O. Box 100360, Anchora e, Alaska 99510
7. KB Elevation (ft):
RKB 94'
[J. .
,D
o
$u~p~nd'
~~rt¡¡1 i~
'Slimul ita·
, Per!Or¡¡IEI New Ppol
. 4.. C JrrentWèll,CI~.s S:·
Development El'
Scrallsri!lphic·d .
t'.1 "
8I~IQr;IOI)I'ÇJ
Se~ I~ : 0
5, Property Designation:
'1(\I~~F4k 'Rit.Jer Unit
11.
Total depth MD (ft):
13530'
CasJn
Total Depth lVD (ft): errectivB Depth MD (II):
3396'
Length
Other 0
205-008
6, API Number:
CONDUCTOR 170'
SURFACE 3811'
INTERMEDIATE 8196'
LINER D-SAND 6166'
20"
13-318"
9-5/8"
5-1/2"
MD TVIJ BIJr$t Collapse
170' 170
,
3905' ;2285
8290' 371:2
13537' 331a9
~\Dà-\S l \\.)\\\t\LO~L~
Si~e
Perforation Depth TVD (ft):
35:33'-3396'
Tubing !Size;
. ·-1/2"
Perforation Depth MD (ft):
SO~4'-13492'
Packers and SSSV Type:
ZXP Liner top pkr w/HRD
SSSV;¡ NIP
12, AttàcIÏIT1Ç,,!~:p~~l!;rlpt¡9n §ljfml'l'\arÿofPrQþo$~1
Oetailep Qper¡;¡tiQn5 PrcQr~fIiI 0 . ijOP ~ketch 0
14. ~:¡¡timätèd )äte for" .
.Commlilr:tcing QperliltiQI'I~: 08/29/015
16. V~r~al Approval: 'D~te¡: 0$/21:1/05
COlY1m~¡¡ion :RepÆl¡¡¡~nt~~iv,~: Tom Msunder
17. he~ebycEtrti~ that 'fhe fOfeÄQhi.g h. .true .u"Id Ï;orrBct' to the best of my knowll!dQe.
Printed N~ro bartD., ristEmsén
"
Packer$ and SSSV MD (ft)
Pkr = 7191'; 746~'
$$SV;¡ 5Q3'
13. Well Class after propo~edworl '
eXploratory 0 . ' De' Itlopmsnt 0
15. Well StatW$ after propo5ed wor ::
Oil 0 Gia5 [:r.
WAG 0 GINJ [J
Cpnt. ::t:
Title;
Phonl 659-7224
'~ . . .
Signature
Commission Use Onl
Condition:; of approval: Notify Commi$sion 50 that a representative may witness
Plug Integrity 0 BOP Test 0
Other: :r ~~"'-
~eChanlèa. II "",,1IyT.., ~. ...,. .
~ ~S \l'--.Q..L_~ t
Locatiofl Çlearancs 0
£1.1 39'\td
ÞIEL59gLø5
Tubing Grade:
L-80
TubingMD (ft}:
7229'
Sel'llice 0 '
Plugged 0
WINJ 0
,Abandoned 0
WDSPL 0
. MJ loVeland/Marie McConnel
Proþlem W.~II Supervl~or
Oa~e: q .
Sundry Number:
3o-S- ~.;;:lS~
Date:
Submit in DuglicéllB
1.19:51.1 91.11.16/81.1/51.1
"
e
e
~¡.
,
¡.
. .
STATE OF ALASKA
ALASKA Oil AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVAL
20 MC 25.280
G :1 0 2005
2. Operator Name:
ConocoPhillips Alaska, Inc.
3. Address:
P. O. Box 100360
7. KB Elevation (ft):
RKB 94'
8. Property Designation:
11.
Total depth MD (ft): Total Depth TVD (ft):
13530' 3396'
Casing Length
CONDUCTOR
SURFACE
INTERMEDIATE
LINER D-SAND
170'
3811'
8196'
6166'
20"
13-3/8"
9-518"
5-1/2"
Commission Use Only
so that a representative may witness
Sundry Number:
.3ðS>~.;l ~
Plug Integrity 0
Mechanical Integrity Test ~ Location Clearance
~\'Vc.",- ~ \" G. t. CD~'~ l·þ.. VQ ¿-J \3>
o
~\ t.Qa~L'{
Other: 1. ,,' \<.t '- ~C> ". G
Subsequent Form Required:
Form 10-403 Revis
OP'~.i~\lbL
\ \ ¡ U \ ¡ \í I ~ DER OF
COMMISSIONER THE COMMISSION
Date:
i Approved by:
INSTRUCTIONS ON REVERSE
Submit in Duplicate
e
e
1E-105L2
DESCRIPTION
SUMMARY OF PROPSAL
ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak
Well 1 E-1 05L2. This well was pre-produced for a 30 day period. Well 1 E-1 05L2 is the multi-
lateral wellbore which will provide pressure support for the West Sak D sand.
The 13-3/8" Surface casing (3905' tvd /2286' tvd) was cemented with 798 sx AS Lite followed
by 219 sx DeepCrete. The 9-5/8" Intermediate casing (8290' md /3713' tvd) was cemented
with 650 sx DeepCrete.
The injection tubing/casing annulus is isolated via ZXP 7" x 9-5/8" Liner Top Packer w/HRD
located @ 7619' md /3601' tvd. The D sand lateral injection tubing/casing annulus is isolated
via a lower ZXP 7" x 9-5/8" Liner Top Packer w/HRD located @ 7462' md /3572' tvd.
The top of West Sak D sand is located at 7260'md /3528' tvd. The top of West Sak B sand is
located at 7516'md /3582' tvd.
An MITIA was performed on 08/20/05; MITrA 3000 psi, 30 minutes, Passed
. .
"
r-"
ð
o
:J:
Ö
~~
-.
_.
:~=
'''i
Π.
.~.
~
I:
..
'"
"j "
"'~~
;; roM c,¡;,.
~{I}å
~ ~ g'
:::~~
ct.,æ"
" -
...
i¡'J
...
o
<h
~~
it
~fh
~~B
Wellhead I Tubing Head / Tree, 13-5/8" x
r 4-W' 5 000 ksi
, ,
Insulated Conductor
Casing, 20".94#. K55 X
34",0.312" wr@ \
+1- 80' MD
13-3/8",68#, lo80, BTC, R3 y
@ 3,905' MD 1 2,285' TVD ~ .
@ 71.86 degrees TD 16" hole
~l~~~¡I~~I~II¡~
Lateral Entry Modnle #2 (LEM),
Baker, with seal bore and ZXP
packer above.
i:r.t~¡.i~l~rl
La"ral Entry Modnle #1 (LEM),
Baker, with seal bore and ZXP
packer above.
~;III'j~~~I~~
Tubing, 4-\\" IBTM, from LEM to
A2 Liner, with seal stem and
CAMCO 3.562" "DB" nipple.
Seal bore and ZXP packer for A2 liner
+/a 90' below "an window
lE-l 05 FINAL:
ASP NAD 27Eastings: .550,300
ASPNAD 27Nortbings: .5,9.59,980
PadEIcvat:ion: 66.1' AMSL
TubingSmng: 4.1/2",12.6#,L.80,IBTM
Doyon Rig 141 Rig Floor (RF) @O'
Elevation: 94.11 AMSL
(I) 3.875" DB nipple set@500'
(I)GasLiftMandre~ CAMC04-1/2"xl" ModelKBG-
2, one (I) set at 67 deg, 4,217' MD, 2,415' TVD.
(I) Gas LiftMandre~ CAMCO 4-1/2" x I" ModeIKBG-
2, one (I) set at 68 deg, 6,712' MD, 3,380' TVD.
(I) Sliding Sleeve, willi 3.812" nipple, one (I) joint above
packer. 7,164' MD, 3,508' TVD
e
.
105 L2 "D" Sand Window
¡; @ 7,258'MD 13,527' TVD
76 degrees "D" Liner, 5-1/2", 15.5#, LBO, BTCM, R3
73 slotted and 7J blank, (0.125" x 2.5" slots, 32 per foo~ 5.9% open area),
ECP packer 16 consmctors @ 12,655', 12,405', 11,860', 11,480', 11,400', 11,090',
r @ 7,300' MD 1 3,536' T~D r 10,848',10,630',10,150',9,790',9,305',9,110', 8,601', 8,400', 8,000',
"W....'''..... / _ _ ,^W
:~W· .'
IE-105 L2:
8-1/2" D sand lateral
TD 13,530' MD 13,396' TVD 7
Angle 98.63 degrees
--.---.---
_v._.____.. _.__.
-----
.~. -- .-. -- -
.-.-
--- --
105Ll "B"SandWindow ''B''Liner 5.1/2" 155# L80 BTCM R3
r @ 7,524 MD/3,583'TVD 65jts slotted, 63 Its biank, (0:125" x2.5" slots, 32 perfoo~ 5.9% open
79 degrees r area), 18 cOJlSmctors @ 13,260', 12,710', 12,450', 12,245', 1J,890', 1J,641',
11,045',10,641', 10,400',9,910',9,650',9,300',9,050',8,700',8,500',
8,134',7,780',7,610'
#$~~~
!B-105 LI:
8-1/2" "B"sandlateraJ
TD 13,529'MD 13,479' TVD 1
Angle 98.07 degrees
e
9·5/8", 40#, lo80, BTCM, R3 Csg ~
@ 8,295' MD 1 3,713' TVD ~
@ 81.54 degrees TD 12-1/4" hole
e
e
KRU
1 E-1 05L2
C . ·Ph·Ui··· AI k I
..onocoLpS. H,a$~t .nc~
TUBING
(0-7229,
00:4.500,
ID:3.958)
Perf
:10181-10602)
Perf
:10587"11070)
:
.'"
~.
..
.......
..
......
ri~¡!¡::::¡:::!~::~\m~
..
...
III
:-:::11=;::::::::::::::=:11=::::
... ...
=HHHIH"H =
~:';:~;:;:;::::::;::.~:~
~ :::::;::::!;:::::~'.: ~
~ H..I.......H ~
1;,=
:::::H'H·IHHH =
~~;:i::i¡::::i::::i:: ~
~ !i!~!!!!:·:")~:.~
== :::::::::I:}:r'~
=::~;;;:::;;;;;;:;~
~"::::::::::~':::::::~
~.~
~~!;ti;~;;;~:~ ~
~~i:::II::::::::/ ~
..
Well Type: m
Orig
ComDletion:
Annular Fluid: Last W/O:
Reference Log: 28' RKB Ref Log Date:
Last Tag: TO: 13537 ftKB
Last T aa Date: Max Hole Anale: 99 dea (â) 11931
.Çij$iÌ'Íø$tlihóéCPMMÞN:$TRINß$}:::::::::::·········:······..........
Description Size Top Bottom TVD Wt
CONDUCTOR 20.000 0 170 170 94.00
SURFACE 13.375 0 3905 2286 68.00
INTERMEDIATE 9.625 0 8290 3513 40.00
LINER D-SAND 5.500 7371 13537 13537 15.50
I _ I Wt I Grade I
I 3521 I 12.60 I L-80 I
I
I
API: 500292324361
SSSV Type: NIPPLE
Anale (â) TS: dea (â)
Angle @ TO: 91 deg @ 13530
Rev Reason: GLV desian
Last UDdate: 7/10/2005
Grade
K-55
L-80
L-80
L-80
Thread
WELDED
BTC
BTCM
BTCM
Thread
IBTM
I Size I Top I Bottom
I 4.500 I 0 I 7229
Interval TVD Zone
8024 - 8399 3533 - 3512 WSD
8612 - 9120 3506 - 3490 WSD
9331 - 9794 3486 - 3487 WSD
10181 -10587 3476 - 3469 WSD
10587 - 10602 3469 - 3469 WSD
10602-11070 3469 - 3461 WSD
11415 -11457 3469 - 3471 WSD
11885 -12387 3460 - 3430 WSD
12688 - 12773 3420 - 3416 WSD
12860 - 12945 3412 - 3410 WSD
12988 - 13074 3409 - 3407 WSD
13118 -13201 3406 - 3404 WSD
13244 - 13329 3403 - 3400 WSD
13366 - 13492 3399 -3396 WSD
Status Ft SPF Date Type Comment
375 40 6/16/2005 IPERF Slotted Liner, alternating
joints of blank/slotted liner
for all D-Sand perfs, 2.5" x
.125" holes, 4 rows/ft
508 40 6/16/2005 IPERF
463 40 6/16/2005 IPERF
406 40 6/16/2005 IPERF
15 80 6/16/2005 IPERF
468 40 6/16/2005 IPERF
42 40 6/16/2005 IPERF
502 40 6/16/2005 IPERF
85 40 6/16/2005 IPERF
85 40 6/16/2005 IPERF
86 40 6/16/2005 IPERF
83 40 6/16/2005 IPERF
85 40 6/16/2005 IPERF
126 40 6/16/2005 IPERF
St MD TVD Man Man Type V Mfr V Type V OD Latch
Mfr
1 4217 2399 CAMCO KBG-2-1R GLV 1.0
2 6713 3383 CAMCO KBG-2-1R OV 1.0
:Øffiijb'Dlûåi,.l:JåØi6.;·.êt(MHØØMMØN..¡E~ÇRY.::·...:..·:.:.<:.·:i·········
Depth TVD Tvpe Description
23 23 HANGER VETCO GRAY MCA TOP CONNECTION HANGER
503 503 NIP CAMCO 'DB-6' LANDING NIPPLE
7164 3505 SLEEVEcC BAKER CMU 'DB-6' SLIDING SLEEVE - CLOSED 6/27/05
7211 3517 SEAL BAKER SBE SEAL ASSEMBL Y/GBH-22 LOCATOR
·Qtfi~t DI¡;¡a$'~all¡DÙ..Øt¢;)..HDH$ANDI..It.Mr::.:::>·:·::·:····:··
Depth TVD Tvpe
7191 3512 PACKER
7213 3517 SBR
7240 3524 D-SAND
LEM
SEAL BAKER SEAL ASSEMBLY
BK
BK
Port TRO Date
Run
0.188 1495 6/29/2005
0.313 0 6/29/2005
Vlv
Cmnt
ID
4.500
3.875
3.810
3.880
Description
ZXP 7" LINER TOP PACKER w/HRD PROFILE
190-47 CASING SEAL BORE RECEPTACLE
D-SAND LEM w/HOOK HANGERS
ID
7.500
4.750
3.688
3.880
7489
3568
Date Note
6/18/2005 TRI-LATERAL WELL w/A-SAND I1E-105), B-SAND I1E-105L 1), D-SAND I1E-105L2) LEGS
6/18/2005 8.5" OPEN HOLE BEHIND SLOTTED LINERS
6/18/2005 TREE: VETCO GRAY / Harz /4-1/16" 5M
TREE CAP CONNECTION: 9" OTIS
e
e
OPER & FIELD
·~05-CO(Q
Ò()s-oa,
'j()5 -OO.~·
-c.. \7 ~ 'C \L Q. \.J - ~~t..?+ ~ \s
\E - '-OS - \0 çL. 1. - \OS-L,:)(
) . l
HECHANI CAL INTEGRITY REPORT' '-.
'-""UD ...,.~_.
.::" u..-....:..:. :
--G ..,-~-.,..-
:....!.... r.....:.~..::.r_~~: .
w"ELL NUM:BER
~~LL DATA Ii:>: rSS\,\ .HD.. 3~d~ TVD j ?BTD: MD TVD
Cê.si~g: 9.5(<< Shoe: <6J1.D MD S~\J.TVDi DV: \-..)~ HD ~~ .TVl)
_:..:.e:[:
Shoe:
:;Joi:;g: 4~;'~ Packer ~\Io\ MD
MD
TVD¡
~'"'...,
.;.l.;,r :
t·m
':''':!D
TVD i See ë. t
'\ dd~
~ole Size anå
\J~\"-~'~~ L1.C: \5;}.3
Per£3 to
I
L:) ç: '\\ ~ \ o~" ~ \ <c. 55'S \ d' '- \~ '--\ ~ lot
:SC?.Þ..NIC;'.l, INTEGRITY - PART II
Annulus Press Test: ~p
IS min
j 30 min
Comments:
,-
:-Œ: CHJÜn CAL INTEGRITY - PART ! 2 ~ ~.) S~ ~ ~ \ ~
Cement: Volumes:' Þ-..mt. Liner Csg <.:, 'StJ')'( j DV
-+1:10 ",.,.." ~'t.w r C': \ ~
Ci:ijt ",Tol to covèr perfs ,:)'<;~ ('.".""- ~-.J.~"'L\(\i'~ ~C.D~t.\._~
'J.,j\~a~ <..\...~\ ~ SOC/ Q ')C)(~ '¥-.'->
,
Iheore tical TOC ~ ~01.'t;:. ~ ~ l...( <0 $.50
o...~~O~\'~ ~O \o~\\)' ~5OS.J..'=) '--\S'7c ~ ~ .
Cement Bo~d Log gar No) 5'J¡S,-a>'->,\'n'AOGCC File 'f.'t;":- ..,
-. . ~~O~~:-\C¡~.I'.Ç,~-Z0~. ~\V\.~\~
CBL :..valuat~on. :::one ê.DOVe perfs >\>'1\_" \. ·'U...."'....\.\_ \ '-.,.... .l,,-~-
. q4, \'" ,f,,1t.\'1t ,-\."'C'\~I:"\ "1 ~~~
Proåu~tion Log: Type
Evaluation
. ¡
j CONCLUSIONS: .
I ?art II, ~t'~l: <ü~oc.~ nl(~\" ~-\ s /~Oç. 'N~~~~ V\.\\" \'Ii:.~,
?ar:: :2: \'1\'I.. \~ \~\<-L.\'t~ ~~ ~\\\ ~~,"",~~~\It.~~~
.. -\.Q ~~........ '\seJ\~O ,"' jf) . _
.' ~~~{,\~üç
J:<b: wes~ ~aK iJC,-iU:J on lllJt:¡';LlUll Wllll UClca,-ll
e
Tom,
\t ---\QÇ èYDS'-C)CJ~
-\\)5 ~1. JOS-OG~
- \OS L~ i70S-~~
There has been no injection into this well prior to today.
Thanks,
Peter Nezaticky / HaL Hunt
ConocoPhillips Alaska Inc.
West Sak Production Engineer
Ph: (907) 659-7061
Fax: (907) 659-7314
" L ~
C\ r\..ì c)Ð!'_~~\...~~ ""~\¡,,\ \ ù"'-.ç,J \11'
\-~ 'Sit \¡~ ~ Sú..cs- S (\.'G:. \. '"
\ t:.-l () S- ~<i ~ \. ç-" \.Q:
kQ 7J11
q,(') '10 S-
----~Original Message-----
From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us]
Sent: Tuesday, September 06, 2005 4:21 PM
To: NSK West Sak Prod Engr
Subject: Re: West Sak lE-l0S on injection with defeated LPP
Thanks Pete. Had there been any injection into the well?? Since this is a baseline, likely not. I will
look forward to seeing the follow-up.
Tom Maunder, PE
AOGCC
NSK West Sak Prod Engr wrote, On 9/6/20053:58 PM:
Tom,
This email is to notify the AOGCC that 1 E-1 05, a West Sak pre-produced injector, has been placed
on injection 9/6/05. Per your request a base line temperature log has be run and is attached and a
second temperature log is planned in 1-2 weeks to confirm isolation.
«1E-105 Combined Press_Temp .zip»
This email is also notifying the AOGCC that the LPP was defeated in accordance with AOGCC Rule
Amendment No. C0406B.001 dated 6/14/05. The LPP has been tagged and recorded in the facility
safety defeat log. The well is injecting 1600 bwpd at 300 psi.
Thanks,
Peter Nezaticky / Hai Hunt
ConocoPhillips Alaska Inc.
West Sak Production Engineer
Ph: (907) 659-7061
Fax: (907) 659-7314
1 of 1
91712005 8:32 AM
KJ:',: lU-:Uj ~unary 1\ppncanons; VY(;ll lC-1WVJLl, IVJL¿
e
Tom,
I'll put it on our schedule.
Thank you!
MJ Loveland
ConocoPhillips
Problem Well Supervisor
659-7224
-----Original Message-----
From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us]
Sent: Friday, August 26, 200S 3:1S PM
To: Spenceley, Neil
Cc: NSK Problem Well Supv
Subject: Re: 10-403 Sundry Applications; Well lE-l0S, 10SL1, 10SL2
Neil,
I got the report and that is the information I needed. The well appears to have been pressure tested
satisfactorily.
MJ,
After the temperatures get equilibrated, please contact the Inspectors for a witnessed MIT.
Tom Maunder, PE
AOGCC
Spenceley, Neil wrote, On 8/26/2005 2:38 PM:
Tom,
I just faxed you a drilling report detailing a test of the top ZXP packer and a service report detailing an
MITIA on the well. Let me know if you need anything else. Thanks.
Neil
-----Original Message-----
From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us]
Sent: Friday, August 26, 200S 1:S3 PM
To: Spenceley, Neil
Cc: NSK Prod Engr Tech; Redman, R.Scott; Hunt, Hai L; Schwartz, Guy L
Subject: Re: 10-403 Sundry Applications; Well lE-lOS, 10SL1, 10SL2
Neil,
I have received the faxed cementing information. On the pressure test information, what I
need is the testing done at the end of the well when the tubing was run and packer set. That
10f3
9/7/2005 8:32 AM
~: lU-4Uj ;'Ullary AppnCallUflS; VVt:1J lC-lV.VJLl, IVJL...
..
e
would have occurred on the end of"L2".
Based on the information in the operations report and my review of the USIT log, I concur
with the plans you have proposed. I will look for the hard copies of the sundries. Please be
aware that I will be out of the office next week. If that doesn't present a problem, I will
address the sundries when I return.
Please advise if this is acceptable.
Tom Maunder, PE
AOGCC
Spenceley, Neil wrote, On 8/26/2005 10:39 AM:
Tom,
As per our discussion today mine and Guy Schwartz's opinion of the USIT log is that we
have good cement from 7006'-7022' with excellent cement from 7008'-7015'. As a result it is
likely that there is good isolation between the West Sak D sand and the UGNU. In order to
confirm this our recommendation is as follows;-
1. Run a baseline temperature log prior to injection
2. Place the well in water injection service
3. Run a temperature log and RST log 1-2 weeks following injection to confirm isolation
or identify any channeling that may exist
Guy Schwartz is tracking down the 407 completion report, the cement report for the 9 5/8"
casing and the pressure test information. Please give me a call at 263-4906 if you have any
questions. Thanks.
Neil
-----Original Message-----
From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us]
Sent: Friday, August 26,20059:51 AM
To: NSK Prod Engr Tech
Cc: Redman, R.Scott; Spenceley, Neil; Hunt, Hai L
Subject: Re: 10-403 Sundry Applications; Well 1E-105, 105L1, 105L2
Thanks Bob. I have included my message back to MJ yesterday. Did it get
forwarded to Neil or Hai??
Tom Maunder
-----Original Message-----
From: Thomas Maunder (mailto:tom maunder(ã¿admin.state.ak.us] Sent: Thursday,
August 25,20053:20 PM
To: NSK Problem Well Supv
Subject: IE-II4, et aI
MJ,
I have pulled the file on IE-I05. I don't have the 407 in my hands yet. I do have the
20f3
9/7/2005 8:32 AM
,Rb: lU-~Y3 Sundry Appl1catlOns; Well It-l.UJLl, lUJLL
e
USIT. If you all are sending in some information, I need the 9-5/8 cementing
information and the pressure tests conducted when the packer was set. Also, if Neil
or Hai could look at the USIT and let me know their thoughts on the "fluid channel"
around where the L2 junction was planned.
Thanks,
Torn Maunder, PE
AOGCC
NSK Prod Engr Tech wrote, On 8/26/20059:45 AM:
Here are the sundry applications (10-403) and schematics for Wsak 1E-105 105L 1,
and 105L2.
«1 E-1 05%20FINAL %20Schematic.pdf»
«1 E-1 05 10-403 08-25-05.xls» «1 E-1 05 Schematic.pdf»
«1E-105L 1 10-403 08-25-05.xls» «1E-105L 1 Schematic.pdf»
«1 E-1 05L2 10-403 08-25-05.xls» «1 E-1 05L2 Schematic.pdf»
Hardcopies are in the mail.
Bob Christensen
Greater Kuparuk Area
Production Engineering Technician
Office (907) 659-7535 NSK-69
Pager (907) 659-7000 (924)
300
9/7/2005 8:32 AM
· STATE OF ALASKA .
ALASKA OIL AND GAS CONSERVATION COM~ION
··~····e.'·'~FJ\./E'D.· .
R.~. '. \i '
AUl1 V 2 2005
WELL COMPLETION OR RECOMPLETION REPI '~ I '~As~~ommission
1 a. Well Status: Oil 0 Gas U Plugged U Abandoned D Suspended D WAG D 1b. Well class:~chOrage
20AAC 25.105 20AAC 25.110 Development.,¡ Exploratory D
GINJ D WlNJ D WDSPL D No. of Completions Other XXX Pre-produced Injector Service D Stratigraphic Test D
2. Operator Name: 5. Date Comp., Susp., it:¡ }t;, ~,¡)ç 12. Permit to Drill Number:
ConocoPhillips Alaska, Inc. or Aband.: June.Ä2005 ~ 205-008
3. Address: 6. Date SPudded:.J ~ t,' U1;;IÇ;!~ 13. API Number:
,-~ I - '.--
P. O. Box 100360, Anchorage, AK 99510-0360 ...April 29, 2005 {{, Z.ø"/ 50-029-23243-61
4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number:
Surface: 391' FSL, 224' FEL, Sec. 16, T11 N, R10E, UM June 14, 2005 ,/ 1E-105L2
At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s):
Horizon: 366' FNL, 369' FEL, Sec. 22, T11 N, R10E, UM 28' RKB Kuparuk River Field
Total Depth: 9. Plug Back Depth (MD + TVD): West Sak Oil Pool
1335' FNL, 418' FEL, Sec. 27, T11N, R10E, UM 8209' MD / 3699' TVD
4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation:
Surface: x- 550300 / 5959981 ' Zone- 4 13530' MD / 3396' TVD / ALK 25651/25660
y- ¡/
TPI: x- 555442 y- 5959260 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit:
Total Depth: x- 555428 - y- 5953011 / Zone- 4 n/a ADL 469/470
18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of
N/A feet MSL Permafrost: 4195' MD
21. Logs Run: ''iiI' ?~'t(, 7z..5"8, 'In D 3.$2.& "..,.v b
GRlRes '" ¿.-/.u . i ~ g.2Ò!;
22. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT
CASING SIZE CEMENTING RECORD
INT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED
20" 62.58# H-40 28' 108' 28' 108' 30" 225 sx AS I
13.375" 68# L-80 28' 3905' 28' 2285' 16" xx sx AS Lite, xx sx DeepCrete
9.625" 40# L-80 28' 8290' 28' 3712' 12.25" 650 sx DeepCrete
5.5" 15.5# L-80 7371' 13530' 3550' 3396' 8.5" slotted liner
5.5" 15.5# L-80 7254' 7416' 3527' 3557' 8.5" Hook Assembly
4.5" 12.6# L-80 7191' 7493' 3512' 3568' 8.5" LEM
23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD
Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET
4.5" 7229' 7190'
8024'-13492' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
40 slots/ft DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
n/a
26. PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
July 12, 2005 Pre-produced Injector - shares production with 1 E-1 05 and 1E-105L 1
~at~~cst Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-Oil RATIO
7/ 2005 14 hours Test Period --> 561 631 6 53 Bean 1191
Flow Tu'bing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr)
press. 464 psi 1204 24-Hour Rate -> 927 1104 11 not available
27. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary).
Submit core chips; if none, state "none".
RBDMs 8FL AUG 0 3 ZDD5 COMPlETiON
_ Då~
NONE h· f . oS-
~
(,~
á£
Form 10-407 Revised 12/2003
CONT,~f;lUEp 9.t':! ~EXE~S9\ L·
';:'; ej tt \~ p\
28.
29.
GEOLOGIC MARKERS
FORMATION TESTS
NAME
MD
TVD
Include and briefly summarize test results. List intervals tested, and
attach detailed supporting data as necessary. If no tests were
conducted, state "None".
1E-105L2
West Sak D
7261'
3529'
N/A
30. LIST OF ATTACHMENTS
Summary of Daily Operations, Directional Survey
31. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact:
Mike Greener @ 263-4820
7/?//oS-
Printed Name
Signature
Title:
Phone
Kuoaruk Drillina Team Leader
Date
-p112. -rJpfrlC'5 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.
Prepared by Sharon Allsup-Drake
Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water
supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with
production from each pool completely segregated. Each segregated pool is a completion.
Item 4b: TPI (Top of Producing Interval).
Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other
spaces on this form and in any attachments.
Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 20: True vertical thickness.
Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location
of the cementing tool.
Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item
23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to
be separately produced, showing the data pertinent to such interval).
Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection,
Shut-in, Other (explain).
Item 27: If no cores taken, indicate "none".
Item 29: List all test information. If none, state "None".
Form 10-407 Revised 2/2003
.
ç~
.
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1 E-1 05
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
4/25/2005 12:00 - 15:00 3.00 MOVE DMOB MOVE Disconnected boiler, motor, pump and pit complex's and prepared
same for move
15:00 - 00:00 9.00 MOVE MOVE MOVE Moved rig off Kokoda 5 and began moving boiler, motor, pump and pit
complex's to 2M pad, as of 24:00 hrs were at Alpine turn-off, worked on
other complex's on Kokoda 5 preparing them for move
4/26/2005 00:00 - 08:00 8.00 MOVE MOVE MOVE Peak continue moving boiler, motors, pumps and pit modules to 2M
pad. Arrived 2M @ 0500 hrs. Peak sows return to Kokoda for next
group. Preparing modules on Kokoda #5 location f/ move to 1 E-105.
Check and fuel. Prep pad f/ move.
08:00 - 12:00 4.00 MOVE MOVE MOVE Load counter weights on two Peak Sows f/ moving subbase. Load
rockwasher on peak trailer. Hook two sows to subbase and move off
well @ 1100 hrs. Clean up well area. Load two pipe shed halves.
12:00·00:00 12.00 MOVE MOVE MOVE Peak moving sub, rockwasher and 2 pipe shed halves f/ Kokoda #5
towards Kuparuk. At midnight leaving midway camp which is 26 miles f/
Kokoda #5.
4/27/2005 00:00 - 12:30 12.50 MOVE MOVE MOVE Peak moving sub, rockwasher and 2 pipe shed halves f/ Kokoda #5
towards Kuparuk. At midnight leaving midway camp which is 26 miles f/
C~ Kokoda #5. Arrived @ Alpine cutoff @ 0500 hrs. Arrive 2L pad @ 0830
hrs. Change up some loads @ 2m pad. Continue to 1 E pad. Arrived @
pad @ 1230 hrs.
12:30 - 00:00 11.50 MOVE POSN MOVE Spot sub over 1E-105. Spot Pits, pumps, motors. Return with Sows to
2M pad. Leave 2M pad @ 1800 hrs w/ 2 pipe sheds, rock washer and
boiler module. Sows leaving 1E pad to return to Kokoda 5 @ 2100 hrs.
Estimated to arrive @ 0100 hrs 4/28/05 to get camp modules.
APC Crane set Sperry Sun shack on top of pit module @ 1800 hrs.
Vetco gray work w/ crew on change out of upper and lower "0" ring seal
on diverter adapter@ 1800 hrs test to 300 psi f/10 min.,. Crew rigging
up modules, unloading trucks.
4/28/2005 00:00 - 12:00 12.00 MOVE RURD RIGUP Change out saver sub, tighten grabbers, service top drive. Slip and cut
38' of drilling line, adjust brakes, rig up interconnects. Prep pits, start
taking on water @ 0800 hrs and start mixing spud mud. NU Diverter @
0900 hrs. Unloading trucks. Prep f/ camp placement on 1 E pad. Rig on
highline @ 09:00 hrs.
12:00 - 00:00 12.00 MOVE RURD RIGUP Accept rig @ 12:00 hrs. Continue mixing spud mud. Camp arrived @
1600 hrs. Camp and shop set by 18:00 hrs. Camp on highline @ 18:00
hrs. Set pipe sheds and rock washer, berm up around rockwasher.
Loading dp into pipe shed. PU mousehole. Prep f/ PU of pipe and BHA.
4/29/2005 00:00 - 05:45 5.75 DRILL PULD SURFAC PUlMU 5" drill pipe, stand back in derrick 37 stands.
05:45 - 06:30 0.75 WELCT BOPE SURFAC Function test diverter system. Witness of test waived by AOGCC .
inspector Chuck Scheve. Initial pressure 2950 psi, after closing 1800
psi. Nitrogen bottles (5) avg 2325 psi. 200 psi buildup req 37 second,
full charge 3 min 1 sec. (25 seconds to close annular.)
06:30 - 08:30 2.00 DRILL PULD SURFAC Continue PU/MU 5" drill pipe, stand back in derrick 9 stands. Total of 46
stands of 5" dp. PU/MU 10 stands 5" HWDP w/ jars.
08:30 - 09:30 1.00 DRILL SFTY SURFAC PRE spud meeting w/ Rig Engineer Mike Greener, both crews attended,
and third party team members.
09:30 - 11 :30 2.00 DRILL PULD SURFAC MU 16" BHA #1 to drill out conductor and drill to 263'.
11 :30 - 12:00 0.50 DRILL OTHR SURFAC Fill conductor, check f/leaks. Pressure test mud line to 3000 psi. No
leaks.
l 12:00 - 13:30 1.50 DRILL REAM SURFAC Ream and clean out 20" conductor f/31' to 97'. 450 gpm @ 275 psi.
13:30 - 14:15 0.75 DRILL CIRC SURFAC Circ to shear mud.
14:15 - 16:00 1.75 DRILL REAM SURFAC Ream and clean out conductor f/97' to 170'. 450 gpm @ 275 psi. PU wt
47K, SO wt 54K, Rot wt 49k
Printed: 6/21/2005 1:33:38PM
ç~
.
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1 E-1 05
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
4/29/2005 16:00 - 18:30 2.50 DRILL DRLG SURFAC Drlg 16" hole f/ base of conductor@ 170' to 263'. PU wt 51k, SO wt
54k, Rot wt 54K, ADT 1.77 hrs
18:30 - 19:00 0.50 DRILL SURV SURFAC Halliburton wireline gyro. Gyro @ 100' and 200'.
19:00 - 21 :30 2.50 DRILL TRIP SURFAC POOH to change BHA.
21 :30 - 00:00 2.50 DRILL PULD SURFAC Pickup/MU BHA #2.
4/30/2005 00:00 - 00:30 0.50 DRILL RIRD SURFAC RU Halliburton WL in derrick f/ gyro.
00:30 - 00:45 0.25 DRILL TRIP SURFAC RIH w/ BHA to 263'
00:45 - 01 :00 0.25 DRILL SURV SURFAC Run gyro @ 260'
01 :00 - 02:30 1.50 DRILL DRLG SURFAC Drilled 16" hole from 263' to 351' MD/351' TVD (88') ART .77 hrs, AST
.32 hrs, 0-2K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure
1025 psi, rot wt 59K, up wt 56K, dn wt 60K.
02:30 - 03: 15 0.75 DRILL SURV SURFAC Run gyro @ 351 '. Ran survey twice.
03:15 - 04:30 1.25 DRILL DRLG SURFAC Drilled 16" hole from 351' to 441' MD/440' TVD (90') ART.6 hrs, AST
.58 hrs, 2-5K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure
1200 psi, on bottom torque 1-2k ftllb, rot wt 60K, up wt 60K, dn wt 62K.
04:30 - 05:00 0.50 DRILL SURV SURFAC Run gyro @ 441'.
05:00 - 06:15 1.25 DRILL DRLG SURFAC Drilled 16" hole from 441' to 531' MD/ 530' TVD (90') ART .43 hrs, AST
(-- .48 hrs, 2-8K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure
1225 psi, on bottom torque 1-2k ftllb, rot wt 65K, up wt 66K, dn wt 67K.
06:15 - 06:30 0.25 DRILL SURV SURFAC Run gyro @ 531'.
06:30 - 07:45 1.25 DRILL DRLG SURFAC Drilled 16" hole from 531' to 626' MD/625' TVD (95') ART .45 hrs, AST
.56 hrs, 8-10K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure
1225 psi, on bottom torque 2k ftllb, rot wt 69K, up wt 69K, dn wt 70K.
07:45 - 08:30 0.75 DRILL SURV SURFAC Run gyro @ 626'. Ran survey twice. Still no picture.
08:30 - 10:00 1.50 DRILL DRLG SURFAC Drilled 16" hole from 626' to 718' MD/715' TVD (92') ART .36 hrs, AST
.85 hrs, 8-12K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure
1300 psi, on bottom torque 2-4k ftllb, rot wt 74K, up wt 73K, dn wt 75K.
10:00 - 10:45 0.75 DRILL SURV SURFAC Run gyro @ 718', and 626'.
10:45 - 12:00 1.25 DRILL DRLG SURFAC Drilled 16" hole from 718' to 781' MD/776' TVD (63') ART .0 hrs, AST
1.01 hrs, 23K wob, 60 rpm's, 500 gpm, 9.0ppg mw, on btm pressure
1400 psi, on bottom torque2-4k ftllb, rot wt 82K, up wt 82K, dn wt 81 K.
12:00 - 00:00 12.00 DRILL DRLG SURFAC Drilled 16" hole from 781' to 1553' MD/1411.56' TVD (772') ART .41
hrs, AST 8.82 hrs, 1 0-40K wob, 60 rpm's, 500 gpm, 9.0-9.2ppg mw, on
btm pressure 1400-1600 psi, on bottom torque 2-6k ftllb, rot wt 82-88K,
up wt 82-93K, dn wt 81-85K.
5/1/2005 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drilled 16" hole from 1553' to 2328' MD/1734.99' TVD (775') ART 2.19
hrs, AST 6.28 hrs, 1 0-40K wob, 60 rpm's, 500-554 gpm, 9.2-9.3ppg
mw, on btm pressure 1600-1900 psi, on bottom torque 5-11 k ftllb, off
bottom torque 4-9k ftllb, rot wt 80-87K, up wt 93-102K, dn wt 84-70K.
12:00 - 00:00 12.00 DRILL DRLG SURFAC Drilled 16" hole from 2328' to 3174' MD/2024.2' TVD (846') ART 4.71
hrs, AST 3.63 hrs, 10-40K wob, 60 rpm's, 554-613 gpm, 9.3-9.4ppg
mw, on btm pressure 1900-2250 psi, on bottom torque 5-11 k ftIlb, off
bottom torque 4-9k ftllb, rot wt 80-83K, up wt 95-100K, dn wt 68-70K.
5/2/2005 00:00 - 07:00 7.00 DRILL DRLG SURFAC Drilled 16" hole from 3174' to 3607' MD/2176' TVD (433') ART 2.86
hrs, AST 2.44 hrs, 1 0-25K wob, 60 rpm's,613 gpm, 9.3-9.4ppg mw, on
btm pressure 2300 psi, on bottom torque 7-11 k ftIlb, off bottom torque
5-9k ftllb, rot wt 83-79K, up wt 100-115K, dn wt 70-62K.
07:00 - 08:00 1.00 DRILL CIRC SURFAC Circ at reduced rate (70 spm/900 psi), change shaker screens on all
three shakers f/140's to 11 O's.
C. 08:00 - 08:45 0.75 DRILL DRLG SURFAC Drilled 16" hole from 3607' to 3631' MD/2184.95' TVD (24') ART .38
hrs, AST 0.0 hrs, 1 0-25K wob, 60 rpm's, 613 gpm, 9.4ppg mw, on btm
pressure 2350 psi, on bottom torque 10k ftIlb, off bottom torque 9k ftIlb,
rot wt 79K, up wt 115K, dn wt 62K.
Printed: 6/21/2005 1 :33:38 PM
.
.
r--
t -
\
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
5/2/2005 08:45 - 09:15 0.50 DRILL CIRC SURFAC Circ at reduced rate (75 spm/950 psi), change shaker screens on all
three shakers f/11 O's to 84's.
09:15-12:00 2.75 DRILL DRLG SURFAC Drilled 16" hole from 3631' to 3748' MD/ 2228.7' TVD (117') ART .88
hrs, AST 0.0 hrs, 1 0-25K wob, 60 rpm's, 613 gpm, 9.4ppg mw, on btm
pressure 2300 psi, on bottom torque 1 Ok ftIlb, off bottom torque 5-9k
ftIlb, rot wt 85K, up wt 112-115K, dn wt 74-70K.
12:00 - 23:00 11.00 DRILL DRLG SURFAC Drilled 16" hole from 3748' to 4,395' MD/2,458.09' TVD (647') ART
3.99 hrs, AST 3.41 hrs, 0-28K wob, 60 rpm's, 613 gpm, 9.3-9.4ppg mw,
on btm pressure 2300-2325 psi, on bottom torque 9-1 Ok ftIlb, off bottom
torque 8-10k ftIlb, rot wt 85-91 K, up wt 112-131 K, dn wt 70-64K.
While drilling at 4,365' MD /2,447' TVD encounted gas. Gas was 249
units max.
23:00 - 23:15 0.25 DRILL CIRC SURFAC Monitored well. Took final surveys. Circulate to POOH.
23:15 - 00:00 0.75 DRILL TRIP SURFAC POOH and prepare to backream.
5/3/2005 00:00-01:15 1.25 DRILL CIRC SURFAC Circulate bottoms up @ 4368' w/613 gpm /2300 psi. Rotate and recip.
PU wt 132K, SO wt 65k, torque 9-12k. Max gas 70 units.
01:15 - 01:30 0.25 DRILL OBSV SURFAC Monitor well. OK.
01 :30 - 01 :45 0.25 DRILL TRIP SURFAC MU stand in derrick. RIH 27' to tag bottom @ 4395' with out pumps.
Pump out to 4368'.
01 :45 - 06:00 4.25 DRILL REAM SURFAC Backream out of hole f/4368' to 2574'. Lots of clay and sand while
reaming @ 2574' @ shakers. Reduce pump rate f/613gpm/2250 psi to
338 gpm/1000psi. 60 rpm. Continue back reaming, pulling slow to
2296'.
06:00 - 06:15 0.25 DRILL OTHR SURFAC Change out shaker screens on # 2 shaker.
06:15 - 08:00 1.75 DRILL REAM SURFAC Continue to backream f/2296' to 1493' wI 338 pgm /1000 psi, 60 rpm.
Change out shaker screens on #1 and #2 shaker.
08:00 - 08:30 0.50 DRILL REAM SURFAC Backream out f/1493' to 1089' w/338 gpm /1000 psi, 60 rpm.
08:30 - 08:45 0.25 DRILL OBSV SURFAC Monitor well. Static.
08:45 - 09:00 0.25 DRILL TRIP SURFAC Attempt to pull out of hole on elevators. Hole swabbing.
09:00 - 10:30 1.50 DRILL REAM SURFAC Backream out f/1 089' to 734' w/ 338gpm/1 000 psi, 60 rpm. Pump out f/
734' to 170' w/ 296 gpm/600 psi.
10:30 - 12:45 2.25 DRILL PULD SURFAC UD BHA #2.
12:45 - 13:45 1.00 DRILL OTHR SURFAC Clear rig floor.
13:45 - 15:15 1.50 CASE RURD SURFAC RU to run 13 3/8" 68 Ib/ft, L-80, BTC.
15:15 - 15:45 0.50 CASE SFTY SURFAC PJSM on running casing.
15:45 - 21 :45 6.00 CASE RUNe SURFAC Run 13 3/8" casing. Weatherford float shoe, 2 jts 13 3/8" 68#/ft L-80
BTC, weatherford float collar, check floats on jt #3, continue to run
casing. First 3 joints have weatherford bow spring centralizers over
stops 10' f/ pin end. First 3 joints were bakerlocked. Next 14 joints have
centralizers over box. Total of 17 centralizers. Running out of down wt
@ 2565'.
21 :45 - 00:00 2.25 CASE RUNC SURFAC Wash casing in hole w/ Frank's fillup tool. Wash f/ 2565' to 2804'. 5bpm
w/ 350 psi. 6 bpm w/ 400 psi. PU wt 185k, SO wt 65K.
21.5 bbls behind calc displacement @ 2804'
5/4/2005 00:00 - 02:45 2.75 CASE RUNe SURFAC Wash casing in hole wI Frank's fillup tool. Wash f/2804' to 3905'.
210bpm w/ 350 psi. 6 bpm w/400 psi. PU wt 185k, SO wt 65K.
02:45 - 09:30 6.75 CASE OTHR SURFAC 13 3/8" 68 #/ft L-80 BTC casing stuck @ 3905', Attempt to free casing
while circulating w/ Frank's fillup tool w/ 360 gpm /680 psi. Pull max
450k. Toolpusher attempted to push with a little top drive weight. No
( go. Circ and condition mud.
09:30 - 10:45 1.25 CASE OTHR SURFAC UD jt # 93. UD Frank's fillup tool. Blow down top drie.
10:45 - 12:00 1.25 CEMEN PULD SURFAC Clear rig floor. PU/MU 10' pup jt, 13 3/8" 68#/ft L-80 BTC. MU Dowell
cement head, and rig up equipment.
Printed: 6/21/2005 1:33:38 PM
.
.
C~.
f~=-~~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1 E-1 05
ROT - DRILLING
n 1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
0.75 CEMEN CIRC SURFAC Continue circ and condition mud and hole @ 315 gpm w/450 psi. Final
MW 9.3+, PV 20, YP 15, 10 sec gel 2, 10 min gel 3. PJSM w/ crew wI
continuing to circ.
2.25 CEMEN PUMP SURFAC Turn over to Dowell. Dowell pump 5 bbls water, test lines to 3500 psi.
pump 50 bbls CW100 @ 8.34 ppg, follow w/ 50 bbls Mudpush wI red
dye @ 10.5 ppg, drop bottom plug, mix and pump 604 bbls (762sx) lead
cement ASlite 10.7ppg @ 7bpm, mix and pump 94 bbls (214sx) tail
cement DeepCrete 12.0 ppg @ 7bpm, drop top plug, follow wI 20 bbls
water. Turn over to rig to finish displacement.
1.50 CEMEN DISP SURFAC Rig displace cement wI 9.3+ ppg mud @ 7 bpm. Mudpush w/ red dye
observed @ shakers wI 1270 stokes pumped, 10.8 ppg lead cement
observed @ shakers wI 2600 stokes pumped, slow pumps to 3 bpm @
5300 strokes pumped, bump plug @ 5449 strokes (calculated 5512
strokes). Final pumping pressure 720 psi, bumped plug w/1300 psi.
CIP 1635 hrs 5/4/2005. Hold f/ 5 min., bleed off to check floats. Floats
holding. Calculated 291 bbls 10.8 ppg cement circ to surface.
Flush stack, RID Dowell cement head.
Nipple down 16" diverter line. PU 21 1/4" diverter.
PU 13 3/8" casing to 305 k on weight indicator. Install Vetco Gray
emergency slips. Slack off to block weight of 35 K. Calculated weight of
casing in mud 226k.
Make hole in casing at +1' above starting head to drain jt #92. Make
rough cut @ 1.04' above starting head. Pull remainder of jt # 92 out of
hole, removed 31.10'.
Set diverter down. N/D 21 1/4" diverter.
Continue N/D 21 1/4" diverter. Welder making final cut @ 7 1/4" above
casing slips.
Welder start welding on Vetco/Gray Socket weld x Threaded flange
adapter.
PIN H109976-3 Rev N/C
H/N C8278
Bore 12.56"
UD 13 3/8" casing equipment f/ rig floor. Change out bales, service top
drive. Welder continue welding on head.
PJSM on PU 5" dp f/ pipe shed. RU mouse hole and iron roughneck
track. Welder continue welding on head.
PU 5" dp f/ pipe shed, stand back in derrick. Welder finished welding
head @ 0445 hrs.
Continue PU 5" dp f/ pipe shed, rabbit to 2.90", stand back in derrick.
Wrap head w/ insulation, let cool slowly. PU total of 39 stands f/ pipe
shed.
Clear rig floor. PU smaller pieces of BHA #3 to rig floor.
Test welds on Vetco/Gray Socket weld x threaded flange adapter to
1800 psi. Found 3 leaks in welds.
Welder reweld on Vetco/Gray Socket weld x threaded flange adapter.
Pressure test weld to 1800 psi f/10 min. OK.
Screw on flange to Vetco Gray adapter, NU Vetco/Gray Multibowl. NU
135/8" BOPE.
Test BOPE. Witness of test by AOGCC inspector John Crisp. Test
annular to 250 psi low f/ 5 min., test to 3500 psi high f/ 5 min. Test all
other componets including choke manifold and floor safety valves and
dart valve to 250 psi low f/ 5 min and 5000 psi high f/5 min. Test
accumulator.
5/4/2005
12:00 - 12:45
12:45 - 15:00
15:00 - 16:30
16:30 - 17:00 0.50 CEMEN OTHR SURFAC
17:00 - 18:30 1.50 CASE NUND SURFAC
( 18:30 - 21:30 3.00 CASE OTHR SURFAC
21 :30 - 23:00 1.50 WE LeT OTHR SURFAC
23:00 - 00:00 1.00 WELCT OTHR SURFAC
5/5/2005 00:00 - 02:00 2.00 WELCT NUND SURFAC
02:00 - 03:45 1.75 CASE OTHR SURFAC
03:45 - 04:15 0.50 DRILL SFTY SURFAC
04:15 - 04:45 0.50 DRILL PULD SURFAC
04:45 - 08:30 3.75 DRILL PULD SURFAC
08:30 - 10:30 2.00 DRILL SURFAC
10:30 - 11 :00 0.50 WELCT SURFAC
11 :00 - 12:15 1.25 WELCT SURFAC
12:15 - 12:30 0.25 WELCT SURFAC
12:30 - 16:00 3.50 WELCT SURFAC
16:00 - 20:45 4.75 WELCT SURFAC
Printed: 6/21/2005 1:33:38 PM
.
.
~
legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1 E-1 05
ROT - DRilLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
Rig down test equipment. Install wear bushing (12 5/16").
MU BHA #3 (121/4" bit). upload MWD.
5/6/2005 Note: During pre tour meeting 22:30 hrs 5/4/2005, crew discussed
picking up more drill pipe f/ pipe shed to stand back in derrick and to
still to keep track of Doyon 15's 5" dp( stands which avg's about 2'
longer than Doyon 14). By the dicscussion it was determined that we
had not drilled to the total depth of 4422' (2474' TVD). After adjusting
pipe tally, TD drilled too was 4395' (2458'TVD). All previous DIMS
reports f/ 4/29/2005 through 5/5/2005 have been corrected, surveys
have been corrected.
00:00 - 00:30 0.50 DRILL OTHR SURFAC RIH one stand of flex collars and one stand of 5" HWDP to 260'.
Strapping dp in hole.
00:30 - 00:45 0.25 DRILL OTHR SURFAC Shallow test MWD. Too much pump noise. Not a good test.
00:45 - 01 :30 0.75 DRILL TRIP SURFAC RIH to 910'. SLM on dp.
01 :30 - 01 :45 0.25 DRILL OTHR SURFAC Shallow test MWD. 132 strokes per minute (558 gpm), 1150 psi. All is
good.
01 :45 - 03:15 1.50 DRILL TRIP SURFAC RIH f/910' to 3786'. SLM on DP. No correction.
03:15 - 03:30 0.25 DRILL REAM SURFAC Break circ@ 5bpm (210 gpm) w/500 psi. Wash f/3786' to 3814'. Tag
( float collar. PU wt 120k, SO wt 60k.
03:30 - 04:30 1.00 DRILL CIRC SURFAC Circulate bottoms up after tagging plugs on top of float collar. Circ @ 65
spm (275 gpm) w/ 600 psi.
04:30 - 05:30 1.00 DRILL CIRC SURFAC Pull and set back a stand. RU testing equipment. Continue circ and
condition mud @ 65 spm (275 gpm) w/600 psi. Circulating through 2"
high pressure line. Circ total of 732 bbls. MW 9.1 +, 10 min gel 40, YP
21.
05:30 - 07:00 1.50 CASE DEQT SURFAC Test 13 3/8" 68#/ft, L-80, BTC casing. FC @ 3818' MD/2254' TVD.
Test wI 9.1 + ppg MW. Apply 3025 psi, hold f/ 30 min, chart test. No
bleed off. Good test.
07:00 - 07: 15 0.25 DRILL OTHR SURFAC Rig down test equipment.
07: 15 - 08:45 1.50 DRILL REAM SURFAC Drill out (2) cement wiper plugs, Float collar @ 3818', cement, Float
shoe @ 3905'.
08:45 - 10:45 2.00 DRILL REAM SURFAC Ream 16" hole below shoe f/3905' to 4072' MD. Appears to have
sidetracked 16" hole @ 4027' MD/ 2332.07' TVD.
10:45 - 12:00 1.25 DRILL CIRC SURFAC Circulate bottoms up @ 4072'. Pumping 600 gpm w/1800 psi.
12:00 - 12:45 0.75 DRILL LOT SURFAC POOH 2 stands f/ 4072' to 3886' inside of 13 3/8" casing shoe. RUI
Perform LOT using 9.1 ppg mud. RID testing equipment.
12:45 - 13:00 0.25 DRILL TRIP INTRM1 RIH f/3886' to 4072'.
13:00 -19:15 6.25 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 4072' to 4,722' MD/2591' TVD (650') ART
1.73 hrs, AST 2.96 hrs, 2-22K wob, 60-80 rpm's, 550-655 gpm, 9.1ppg
mw, on btm pressure 1600-2100 psi, on bottom torque 6-9k ftIlb, off
bottom torque 8-9k ftIlb, rot wt 89-95K, up wt 110-127K, dn wt 64-75K,
max gas units of 350 while drilling @ 4280'
19:15 - 19:30 0.25 DRILL CIRC INTRM1 Circ prior to short trip. Circulate @ 600 gpm w/1800 psi.
19:30 - 21:00 1.50 DRILL TRIP INTRM1 Pump out of hole 7 stands f/4722' to 3885' (13 3/8" shoe @ 3905' MD/
2285' TVD). Orient to high side prior to pulling out. Pumping 600 gpm
w/1800 psi. PU wt 105k.
21 :00 - 21 :45 0.75 DRILL TRIP INTRM1 RIH f/3885' to 4630'. MU top drive. Fill pipe, wash f/4630' to TD @
4722'. SO wt 75K.
21 :45 - 00:00 2.25 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 4722' to 4,908' MD/2656' TVD (186') ART .63
C hrs, AST .23 hrs, 1 0-15K wob, 80 rpm's, 634-651 gpm, 9.1 ppg mw, on
btm pressure 1600-2000 psi, on bottom torque 6-10k ftIlb, off bottom
torque 8-9k ftIlb, up wt 119-115K, dn wt 75-80K, rot wt 93-96K.
5/7/2005 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 4908' to 5836' MD/3019' TVD (928') ART 2.9
Printed: 6/2112005 1 :33:38 PM
.
.
t="
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1E-105
ROT - DRILLING
n 1334@ppco.com
Doyon 141
Start:
Rig Release:
Rig Number:
4/25/2005
6/20/2005
Spud Date: 4/29/2005
End: 6/20/2005
Group:
5/7/2005 00:00 - 12:00 12.00 DRILL DRLG INTRM1 hrs, AST 3.75 hrs, 5-25K wob, 80-90 rpm's, 550-668 gpm, 9.1 ppg mw,
on btm pressure 1900-2250 psi, off bottom pressure 1400-2000, on
bottom torque 6-12k ftllb, off bottom torque 6-12k ftllb, up wt 115-128K,
dn wt 80-86K, rot wt 95-103K.
12:00 - 00:00 12.00 DRILL DRLG I NTRM 1 Drilled 12 1/4" hole from 5836 to 6597' MD/3341' TVD (761') ART 1.3
hrs, AST 4.16 hrs, 0-30K wob, 95 rpm's, 672 gpm, 9.1 ppg mw, on btm
pressure 2150-2300 psi, off bottom pressure 2050-2200, on bottom
torque 10-13k ftllb, off bottom torque 10-16k ftllb, up wt 127-155K, dn
wt 86-83K, rot wt 104-1 07K.
5/8/2005 00:00 - 00:30 0.50 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 6597' to 6679' MD/3370' TVD (82') ART 0.0
hrs, AST .56 hrs, 10-15Kwob, 95 rpm's, 672 gpm, 9.1ppg mw, on btm
pressure 2300 psi, off bottom pressure 2200, on bottom torque 13-20k
ftIlb, off bottom torque 20-23k ftllb, up wt 155K, dn wt 84K, rot wt 112K.
00:30 - 04:45 4.25 DRILL REAM INTRM1 Backream out of hole f/ 6679' to 5468' @ 700 gpm w/2300 psi, 95 rpm.
Pulling 3'- 6'/min first 5 stands, then 10'-12'/min.
04:45 - 06:30 1.75 DRILL CIRC INTRM1 Pump 60 bbl hi vis sweep @ 680 gpm, 2300 psi, 95 rpm, pulling real
slow. Circ sweep to surf. Circ total of 2BU. Increase of cuttings 15%.
06:30 - 07:30 1.00 DRILL REAM INTRM1 Backream out of hole f/5282' to 4725' @ 700 gpm w/2175 psi, 95 rpm.
( Pulling 10-12'/min.
07:30 - 08:45 1.25 DRILL CIRC INTRM1 Pump 60 bbl hi vis sweep @ 680 gpm, 2100 psi, 95 rpm, pulling real
slow. Circ sweep to surf. Circ total of 2BU. Increase of cuttings 10-15%.
08:45 - 09:45 1.00 DRILL TRIP INTRM1 RIH f/4597' to 6584'.
09:45 - 10:00 0.25 DRILL REAM INTRM1 Fill pipe. Wash f/6584' to 6679'.
10:00 - 12:00 2.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 6679' to 6773' MD/3406' TVD (94') ART 0.0
hrs, AST .85 hrs, 1 0-15K wOb, 95 rpm's, 672 gpm, 9.1 ppg mw, on btm
pressure 2300 psi, off bottom pressure 2200, on bottom torque 15-18k
ftIlb, off bottom torque 15k ftllb, up wt 157K, dn wt 80K, rot wt 11 OK.
12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 6773' to 7442' MD/3568' TVD (669') ART 3.32
hrs, AST 3.81 hrs, 1 0-25K wob, 95 rpm's, 676 gpm, 9.1 ppg mw, on btm
pressure 2300-2400 psi, off bottom pressure 2200, on bottom torque
14-15k ftIlb, off bottom torque 14-17k ftllb, up wt 157-151 K, dn wt
76-80K, rotwt 107-110K.
5/9/2005 00:00 - 10:30 10.50 DRILL DRLG INTRM1 Drilled 12 1/4" hole from 7442' to 8295' MD/3713' TVD (853') ART 5.31
hrs, AST 1.24 hrs, 1 0-35K wob, 95 rpm's, 676 gpm, 9.1 ppg mw, on btm
pressure 2400-2500 psi, off bottom pressure 2200-2300, on bottom
torque 13-15kftllb, off bottom torque 14-18kftllb, upwt 151-154K, dn
wt 76-80K, rot wt 109-11 OK.
10:30 - 12:00 1.50 DRILL CIRC INTRM1 Pump 60 bbls weighted hi vis sweep @ 680 gpm w/2500 psi, rotating
95 rpm.
12:00 - 12:45 0.75 DRILL OBSV INTRM1 Monitor well.
12:45 - 18:45 6.00 DRILL REAM INTRM1 Backream out of hole f/ 8295' to 3850' w/ 680 gpm/2500- 1975 psi,
rotating 95 rpm. 133/8" shoe is @ 3905'. Mud weight is 9.2+.
18:45 - 21:15 2.50 DRILL CIRC INTRM1 Circulate, pump 60 bbls hi vis sweep, continue pumping to total of 2 1/2
BU after sweep to surf, and hole is clean. No increase in cuttings.
Pumping @ 680 gpm wI 1975 psi.
21:15-22:15 1.00 DRILL TRIP INTRM1 Monitor well. Pull 5 stands on elevators f/ 3905' to 3440'. Proper fill. RIH
5 stands f/ 3440' to 3905'.
22:15 - 22:45 0.50 DRILL CIRC INTRM1 Circ, spot lube pill EMI 920 (f/ metal to metal). Pump 226 bbls, follow w/
41 bbls mud, 20 bbls dry job, 10 bbls to chase dry job. Pumping @ 680
( gpm w/1975 psi. Mud weight is 9.4 ppg.
22:45 - 00:00 1.25 DRILL TRIP INTRM1 Blow down top drive. POOH on elevators f/3850' to 3150' @ midnight
to run 9 5/8" casing.
5/10/2005 00:00 - 01 :30 1.50 DRILL TRIP I NTRM 1 POOH from 3,150' to 177', stood back HWDP and jars, LD ghost
Printed: 6/21/2005 1 :33:38 PM
.
.
F'
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1 E-1 05
ROT - DRILLING
n,1334@ppco.com
Doyon 141
Start:
Rig Release:
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
4/25/2005
6/20/2005
06:00 - 07:45
07:45 - 08:00
08:00 - 13:45
1.75 CASE
0.25 CASE
5.75 CASE
RURD INTRM1
SFTY INTRM1
RUNe INTRM1
13:45 - 15:00 1.25 CASE CIRC INTRM1
15:00 - 16:30 1.50 CASE RUNe INTRM1
16:30 - 17:30 1.00 CASE CIRC INTRM1
17:30 - 20:00 2.50 CASE RUNe INTRM1
( 20:00 - 21 :30 1.50 CASE CIRC INTRM1
21 :30 - 00:00 2.50 CASE RUNe INTRM1
5/11/2005 00:00 - 01 :00 1.00 CASE RUNe INTRM1
01 :00 - 03:00 2.00 CEMEN CIRC INTRM1
03:00 - 03:30
03:30 - 05:30
0.50 CEMEN RURD INTRM1
2.00 CEMEN CIRC INTRM1
05:30 - 07: 15
1.75 CEMEN PUMP INTRM1
07:15 - 08:45
1.50 CEMEN DISP INTRM1
08:45 - 13:00
4.25 WELCT EQRP INTRM1
reamer
Downloaded MWD and LD BHA #3, LD NM flec DC's, MWD and motor
Pulled wear bushing and installed test plug
Changed out top set of 3 1/2" x 6" VBR's to 9 5/8" csg rams and tested
same to 250 psi low and 3,000 psi high
RU Doyon's 9 5/8" csg equipment and Franks fill up tool
Held PJSM with rig crew and tong operator on running of 9 5/8" csg
RIH with 9 5/8", 40#, L-80, BTC-M csg to 2,891', MU 9 5/8" Float shoe,
2 jts csg and float collar, thread locked btm 3 conn's and circ thru float
equip and ck ok, RIH with 72 add. jts along with pup jts for spacing out
to 2,891'
Circ btms up at 2,891', staged pump rate up to 6 bpm at 300 psi, st wt
up 120K, dn wt 62K
RIH with 9 5/8" csg from 2,891' to 3,894', (Csg Shoe at 3,905') RIH
with 26 add. jts, 100 total jts of csg in hole
Circ a csg cap at 3,894' (300 bbls), staged pump rate up to 6 bpm at
400 psi, st wt up 144K, dn wt 63K
RIH with an add 50 jts of 9 5/8" csg from 3,894' to 5,800' with no
problems, 150 total jts in the hole
Circ 200 bbls of mud to cond mud in open hole, staged pump rate up to
5 bpm at 380 psi, st wt up 207K, dn wt 70K
RIH with an add 45 jts of 95/8" csg from 5,800' to 7,520', 195 jts of 215
in the hole, no problems RIH, st wt up 247K, dn wt 79K
Fin RIH with 9 5/8" csg from 7,520' to 8,290' with no problems, ran a
total of 215 jts of 9 5/8", 40#, L-80, BTCM csg with 2 pup jts for space
out, total ran including float equipment 8,264.87'
Began circ and conditioning mud thru Franks fill up tool for cementing,
circ 1.5X btms up, staged pump rate from 3.5 bpm at 500 psi to 7 bpm
at 625 psi, st wt up 245K, dn wt 83K, reciprocated pipe with no
problems and full returns
LD Franks fill up tool and MU Dowells cement head
Fin circ and cond mud for cementing, circ at 7 bpm at 500 psi, st wt up
255K, dn wt 82K, initial MWout, 9.2+ ppg, 69 vis, PV 15, YP 30,
Conditioned mud to final MW of 9.2 ppg, 48 vis, 15 YP and 14 PV, Held
·th-Dowell. A2C vaG truck droc~d rig crew on cementing
csg while circ.
Dowell pumped 10 bbls CW 100 at 8.3 ppg, Pressure tested lines to
3,500 psi, Then pumped 30 add. bbls of CW 100, Pumped 38 bbls of
MudPush at 10.5 ppg, Dropped btm plug then pumped 260.5 bbls, (650
sxs) of DeepCrete cmt at 12.4 ppg, 2.26 yield with additives, ave 3.7
bpm at 450 psi, Reciprocated pipe with full returns, shut down, Washed
up and dropped top plug.
Rig displaced cement with 9.0 ppg MOBM, Bumped plug on calc
displacement after pumping 621 bbls (96% pump eff.) ave 8 bpm while
displacing cmt, Max pressure 1,230 psi, Slowed pump rate to 3 bpm
(700 psi) with 20 bbls left to pump and bumped plug to 1,200 psi, ck
floats and held, CIP at 08:42 hrs, Reciprocated pipe until 190 bbls cmt
was around shoe when hole began getting tight and stopped
reciprocating, Stopped reciprocating with csg with Shoe at 8,290' and
Float Collar at 8,208', Calc TOe @ 5,035', Had full returns thru out job
ND stack and RD cement head, PU on stack and installed 9 5/8" Vetco
Gray MB 222 (C-21) csg slips per well plan, PU and set slips with 75K
st wt, cut off csg and LD same, Installed 9 5/8" packoff, NU stack and
Printed: 6/21/2005 1 :33:38 PM
·
F-~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
tested packoff to 2,400 psi (80% of collapse) for 10 min and ck ok
RU and performed LOT on 13 3/8" x 9 5/8" annulus to 16.1 ppg EMW,
801 psi at 2,285' TVD with 9.4 ppg MW,
Flushed 13 3/8" x 9 5/8" annulus with 275 bbls water, initial rate 1.5
bpm at 850 psi, final rate 3 bpm at 960 psi, Sim-Ops, changed out top
set of pipe rams from 95/8" csg rams back to 3 1/2" x 6" VBR's
RU and tested 3 1/2" x 6" VBR's and 133/8" 5M flange to 250 psi low
and 3,500 psi high
RD 9 5/8" csg equipment and RU to PU 5" DP, installed wear bushing
Inspected 5" saver sub and ck ok, RU Little Red on 13 3/8" x 9 5/8"
annulus
PU 30-5" Lo- Tads to rig floor while Little Red freeze protected 13 3/8" x
9 5/8" annulus with 130 bbls diesel, ave 3 bpm at 1,100 psi
Held PJSM on PU 5" DP with Lo-Tads and PU Sperry Suns Geo Span
by-pass unit
PU and spotted Sperry Suns Geo Span by-pass unit on the off drillers
side of rig floor
PU and stood back 14 stds of 5" Dp with Lo-Tads
Fin PU and standing back 5" Dp with Lo-Tads, (PU an add. 46 stds, 60
stds total with Lo-Tads)
MU 8 1/2" BHA #4 and RIH to 85', MU bit #3, Geo-pilot rotary system
with Stratasteer LWD/MWD/PWD, oriented and uploaded MWD and
shallow tested tool
Held PJSM on loading of radioactive sources
Fin MU BHA #4 and RIH to 385', loaded radioactive sources, PU 3-6
3/4" NM flex Dc's and RIH with HWDP and jars to 385'
RIH from 385' to 8,100'
Slip and cut 104' of drlg line, circ btms up while cutting drlg line at 175
gpm at 500 psi, rot wt 102K, up wt 162K, dn wt 79K, 9.0 ppg MOBM in
and out
RIH from 8,100' and tagged up at 8,196', LD 1 single PU to 8,165' (Fit
Collar at 8,208')
RU and tested 9 5/8" csg to 3,000 psi for 30 min
PU single and RIH from 8,165' to 8,196', est circ and took SPR's
Cleaned out cement on top of plugs from 8,196' and began drilling out
plugs, drilling out plugs at 8,206' with 5-17 wob, 70 rpm's, 550 gpm at
2,750 psi, on btm torque 12-15K ft-Ibs, rot wt 110K, up wt 155K, dn wt
80K (fit Collar at 8,208')
1.75 CEMEN DSHO INTRM1 Fin drilling out plugs, fit collar at 8,208', shoe track, fit shoe at 8,290'
and drill 20' of new formation from 8,295' to 8,315' MD/ 3,718' TVD,
drilled out at 5-17K wob, 70 rpm's, 550 gpm at 2,750 psi, rot wt 11 OK,
up wt 155K, dn wt 80K, ADT .18 hrs
Circ btms up for LOT, circ at 550 gpm at 2,750 psi with 8.9 ppg MOBM
in and out, stood back 1 std
RU and performed LOT to 12.3 ppg EMW, 650 psi at 3,712' TVD with
8.9 ppg MOBM
Drilled 8 1/2" hole in A2 lateral from 8,315' to 8,683' (368') ADT 2.19 hrs
Circ btms up and est. PWD baseline, at 120 rpm's and 600 gpm, clean
hole ECD was 10.6 ppg
Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary
steerable system from 8,683' to 9,169' MD/3,692' TVD (486') ADT 3.41
hrs, 5-15K wob, 120 rpm's, 150 spm, 636 gpm, off btm pressure 3,500
psi, on btm pressure 3,570 psi, off btm torque 1 OK ft-Ibs, on btm 12K
13:45 - 15:45 2.00 DRILL OTHR INTRM1
15:45 - 16:45 1.00 WELCT BOPE INTRM1
16:45 - 18:00 1.25 DRILL RIRD INTRM1
18:00 - 18:30 0.50 RIGMNT RSRV INTRM1
18:30 - 20:00 1.50 DRILL PULD INTRM1
20:00 - 20:15 0.25 DRILL SFTY INTRM1
20:15-21:15 1.00 DRILL PULD INTRM1
21:15 - 00:00 2.75 DRILL PULD INTRM1
( 5/12/2005 00:00 - 08:00 8.00 DRILL PULD INTRM1
08:00 - 11 :00 3.00 DRILL PULD INTRM1
11:00 -11:15 0.25 DRILL SFTY INTRM1
11:15-12:00 0.75 DRILL PULD INTRM1
12:00 - 16:45 4.75 DRILL TRIP I NTRM 1
16:45 - 18:00 1.25 RIGMNT RSRV INTRM1
18:00 - 18:15 0.25 DRILL TRIP INTRM1
18:15 - 19:45 1.50 CASE DEQT INTRM1
19:45 - 20:00 0.25 DRILL TRIP INTRM1
20:00 - 00:00 4.00 CEMEN DSHO INTRM1
5/13/2005
00:00 - 01 :45
01 :45 - 02:30 0.75 DRILL CIRC INTRM1
02:30 - 03:15 0.75 DRILL LOT INTRM1
03:15 - 06:30 3.25 DRILL DRLG PROD
06:30 - 07:15 0.75 DRILL CIRC PROD
C 07:15 - 12:00 4.75 DRILL DRLG PROD
Printed: 6/21/2005 1:33:38 PM
.
.
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
5/13/2005 07:15 - 12:00 4.75 DRILL DRLG PROD ft-Ibs, rot wt 112K, up wt 165K, dn wt 78K, 9.0 ppg MOBM, ave ECD
10.9 ppg, ave BGG 150 units, max gas 430 units
12:00 - 00:00 12.00 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary
steerable system from 9,169' to 10,232' MD/3,703' TVD (1,063') ADT
7.03 hrs, 5-20Kwob, 120 rpm's, 150 spm, 636 gpm, offbtm pressure
3,600 psi, on btm pressure 3,625 psi, off btm torque 14-18K ft-Ibs, on
btm 13-20K ft-Ibs, rot wt 11 OK, up wt 193K, dn wt 72K, 9.0 ppg MOBM,
ave ECD 11.1 ppg, ave BGG 150 units, max gas 229 units, drilled thru
several concretions and using Sperry Sun's Stratasteering tool to aid in
geosteering
5/14/2005 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary
steerable system from 10,232' to 11,474' MD/3,648' TVD (1,242') ADT
7.21 hrs, 6-14K wob, 120 rpm's, 150 spm, 636 gpm, 3,625 psi, off btm
torque 16-20K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 11 OK, up wt 195K, dn
wt 60K, 9.0 ppg MOBM, ave ECD 11.2 ppg, ave BGG 150 units, max
gas 220 units, drilled thru several concretions and using Sperry Sun's
Stratasteering tool to aid in geosteering
12:00 - 20:00 8.00 DRILL DRLG PROD Drilled 8 1/2" hole in A2 sand lateral from 11,474' to 12,208' MD/3,717'
TVD (734') ADT 4.26 hrs, 5-15Kwob, 120 rpm's, 141 spm, 600 gpm,
3,600 psi, off btm torque 16-19K ft-Ibs, on btm 16-20K ft-Ibs, rot wt
111 K, up wt 220K, dn wt 60K, 9.0 ppg MOBM, ave ECD 11.3 ppg, ave
BGG 120 units, max gas 230 units, crossed fault at 11,420' MDI 3,650'
TVD as predicted and drilled thru btm lobe of A2 sand to determine
formation dip, btm of lower A2 sand at 12,125' MD/3,691' TVD, to
POOH and open hole sidetrack well per directional plan and geologist
20:00 - 22:30 2.50 DRILL REAM PROD Backreamed out of hole for open hole sidetrack from 12,208' to 11,297',
backreamed out at 100 rpm's, 445 gpm at 2,200 psi with 15-17K torque.
Note: Began changing out 6" liners in mud pumps over to 51/2" liners
while backreaming out
22:30 - 23:00 0.50 DRILL CIRC PROD Circ hole at 11,297' while fin. changing out liners on mud pumps to 5
1/2"
23:00 - 00:00 1.00 DRILL REAM PROD Began cutting trough for open hole sidetrack from 11,297' to 11,332'
MD/3,653' TVD, cutting trough at 120 rpm's, 176 spm, 625 gpm at
3,650 psi, rot wt 11 OK, up wt 195K, dn wt 60K, off btm torque 15-16K
ft-Ibs
5/15/2005 00:00 - 02:00 2.00 DRILL DRLG PROD Time drilled to sidetrack well from 11,332' to 11,341', sidetracked well
at 11,332' MDI 3,653' TVD, (9') ADT 1.93 hrs
02:00 - 12:00 10.00 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary
steerable system from 11,341' to 12,245' MDI 3,654' TVD (904') ADT
6.58 hrs, 8-20K wob, 120 rpm's, 176 spm, 625 gpm, 3,800 psi, off btm
torque 15-18K ft-Ibs, on btm 15-17K ft-Ibs, rot wt 108K, up wt 207K, dn
wt 57K, 9.0 ppg MOBM, ave ECD 11.4 ppg, ave BGG 100 units, max
gas 228 units, using Sperry Sun's Stratasteering tool to aid in
geosteering
12:00 - 16:00 4.00 DRILL DRLG PROD Drilled 8 1/2" hole from 12,245' to 12,627' MD/3,629' TVD (382') ADT
2.46 hrs, max gas 723 units
16:00 - 17:00 1.00 DRILL CIRC PROD Stood back 1 std and circ hole while trouble shoot MWD computer
problem, re-booted computers, circ and worked pipe from 12,622' to
12,595', circ at 500 gpm, 2,700 psi with 80 rpm's and 17K ft-Ibs torque
17:00 - 17:45 0.75 DRILL DRLG PROD Drilled 81/2" hole from 12,627' to 12,723' MD/3,625' TVD (96') ADT
.89 hrs, max gas 412 units
17:45 - 18:45 1.00 DRILL OTHR PROD Circ hole while geologist evaluated logs
18:45 - 00:00 5.25 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo pilot rotary
Printed: 6/21/2005 1 :33:38 PM
.
.
F-
"
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
5.25 DRILL DRLG PROD steerable system from 12,723'to 13,184'MD/3,631'TVD(461')ADT
2.8 hrs, 10-20K wob, 120 rpm's, 176 spm, 625 gpm, 4,050 psi, off btm
torque 18-19K ft-Ibs, on btm 16-17K ft-Ibs, rot wt 112K, up wt 217K, dn
wt 60K, 9.0 ppg MOBM, ave ECD 11.7 ppg, ave BGG 100 units, max
gas 219 units, began using 5" HWDP at 12,820'. NOTE: at 13,000'
taking several attempts to get survey and get Geo-pilot to cycle, slowed
MWD data rate to improve survey signal, changed out jet on Geo span
unit and clean screens on mud pumps and saw improvement in surveys
and down linking Geo span unit
Drilled 8 1/2" Hole in A2 sand lateral from 13,184' to 13,252' MDI 3,628'
(68') ADT .34 hrs when rig and camp lost high line power
Started rig generators and re-established circ and rotation with no
problem, NOTE: rig off high line from 00:45 to 04:45 hrs
Drilled 8 1/2" hole in A2 sand lateral from 13,252' to 13,539' MD/3,623'
TVD, A2 sand TD, (287') ADT 1.57 hrs, 8-12K wob, 120 rpm's, 625 gpm
at 4,100 psi, off btm torque 18-20K ft-Ibs, on btm 17 -18K ft-Ibs, rot wt
115K, up wt 220K, dn wt 68K with 60 stds of 5" DP with Lo-Tads and 8
stds of 5" HWDP in the hole, 9.1 ppg MOBM, ave ECD 11.8 ppg, ave
BGG 80 units, max gas 580 units,
0.25 DRILL CIRC PROD Circ hole to clear BHA, circ at 625 gpm at 4,000 psi
1.75 DRILL REAM PROD Backreamd out of hole from 13,539' to 12,911' and started packing off
at 12,911', backreamed out at 120 rpm's, 625 gpm at 4,100 psi
3.00 DRILL REAM PROD Backreamed out slow due to packing off from 12,911' to 12,725',
backreamed out at 600 gpm, 4,100 psi and 120 rpm's, pumped 30 bbl
wt'd hi vis sweep at 12,800' with slight increase in cuttings back from
sweep
Backkreamed out of hole (BROOH) from 12,725' to 11,488' and started
pulling tight and packing off at 11,488', would loose partial returns
when packing off then would slow pump rate
Worked thru tight spot from 11,488' to 11,393', RIH 1 std to 11,550',
Note: as of 12:00 hrs had lost 50 bbls of MOBM to formation while
backreaming out
BROOH from 11,550' to 10,500', no problems thru spot at 11,488',
began pulling tight and packing off at 10,500', backreamed out at 120
rpm's, 15K ft-Ibs torque, 595 gpm at 3,500 psi
Worked thru tight spot from 10,500' to 10,492', slowed pump rate due to
circ with only 50% returns, shut down pump and pulled 45K thru tight
spot, then RIH to 10,500' and backreamed thru spot with no problems
BROOH from 10,492' to 9,945' with no problems, backreamed at 120
rpm's, 15K ft-Ibs torque, 595 gpm at 3,200 psi
RIH from 9,945' to 10,615' with no problems
Pumped out of hole from 10,615' to 9,945' at 595 gpm, 3,200 psi with
no problems
BROOH from 9,945' to 8,709' and began to pull tight and packing off,
backreamed at 120 rpm's, 595 gpm 3,200 psi
Worked thru tight spot at 8,709' to 8,689', pulled 45-50K over and pulled
thru spot, RIH past spot and backreamed out thru spot with no
problems
BROOH from 8,689' to 8,285' with no problems (9 5/8" csg shoe at
8,290') NOTE: While backreaming out of hole found 3 small pin hole
wash outs, found 1 in middle of std # 102 and 1 between std #112-#113
and between #120-#121, lost an add 112 bbls of MOBM while
Backreaming out, total lost 162 bbls
5/15/2005
18:45 - 00:00
5/16/2005 00:00 - 00:45 0.75 DRILL DRLG PROD
00:45 - 01 :30 0.75 DRILL OTHR PROD
01 :30 - 04:30 3.00 DRILL DRLG PROD
c
04:30 - 04:45
04:45 - 06:30
06:30 - 09:30
09:30 - 11 :30 2.00 DRILL REAM PROD
11 :30 - 12:00 0.50 DRILL REAM PROD
12:00 - 14:00 2.00 DRILL REAM PROD
14:00 - 15:15 1.25 DRILL REAM PROD
15:15-16:00 0.75 DRILL REAM PROD
16:00 - 16:30 0.50 DRILL TRIP PROD
16:30 - 17:15 0.75 DRILL TRIP PROD
17:15 -19:30 2.25 DRILL REAM PROD
19:30 - 20:00 0.50 DRILL REAM PROD
20:00 - 20:45 0.75 DRILL REAM PROD
Printed: 6/21/2005 1 :33:38 PM
.
.
F~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
5/16/2005 20:45 - 21 :00 0.25 DRILL OBSV PROD Monitored well at shoe, well-static
21:00 - 22:15 1.25 DRILL CIRC PROD Pumped 35 bbl wt'd hi vis sweep at shoe and circ 2 complete circ and
was clean at shakers, had a slight increase in cuttings back from
sweep, circ at 625 gpm, 3,150 psi, 120 rpm's, 12-18K ft-Ibs torque, rot
wt 105K, up wt 180K, dn wt 76K
22:15 - 23:30 1.25 DRILL PULD PROD Swapped out 6 jts of 5" DP found to be washed out while BROOH
23:30 - 00:00 0.50 DRILL TRIP PROD RIH from 8,285' to 8,496'
5/17/2005 00:00 - 03:00 3.00 DRILL TRIP PROD RIH from 8,496' to 13,539', had 20K drag at 11,356' and no other
problems RIH
03:00 - 05:15 2.25 DRILL CIRC PROD Pumped 30 bbl wt'd hi vis sweep and circ hole clean, circ at 570 gpm at
4,100 psi, had no increase in cuttings back from sweep
05: 15 - 06:45 1.50 DRILL CIRC PROD Displaced hole over from 9.1 ppg MOBM to 9.0 ppg SFMOBM, circ hole
at 535 gpm at 3,450 psi, rot wt 11 OK, up wt 245K, dn wt 65K
06:45 - .07:00 0.25 DRILL OBSV PROD Monitored well-static
07:00 - 11 :30 4.50 DRILL TRIP PROD POOH on elevators from 13,539' to 8,206', (9 5/8" Shoe at 8,290') no
problems POOH
11:30 -11:45 0.25 DRILL OBSV PROD Monitored well inside csg shoe, well-static
11 :45 - 12:45 1.00 RIGMNT RGRP PROD Removed shot pin hydraulic assembly on top drive for repair due to
C leak, (shot pin is locking pin for pipe handler)
12:45 - 13:45 1.00 RIGMNT RSRV PROD Slip and cut 57' of drlg line
13:45 - 15:45 2.00 RIGMNT RSRV PROD Changed out 4 1/2" IF saver sub on top drive
15:45 - 16:15 0.50 RIGMNT RGRP PROD Re-installed shot pin assembly on top drive, Note: hole took 4 bbls of
mud in 4112 hrs
16:15 - 19:30 3.25 DRILL TRIP PROD Dropped 2 3/8" rabbit on a wire and POOH from 8,206' to BHA #4 at
385', LD ghost reamer
19:30 - 22:45 3.25 DRILL PULD PROD Stood back 2 stds NM flex Dc's, held PJSM and removed radioactive
sources, LD a NM flex Dc and downloaded MWD, LD remaining BHA
#4 with Geo-pilot and cleared rig floor, calc fill on trip out 117.6 bbls,
actual fill 146.7 bbls
22:45 - 23:00 0.25 LOG SFTY PROD Held PJSm with SWS and rig crew on RU of wire line and US IT logging
tool with WELL TEe tractor tool
23:00 - 00:00 1.00 LOG RURD PROD RU SWS wireline and MU USIT logging tools with tractor tool
5/18/2005 00:00 - 00:30 0.50 LOG RURD PROD Fin RU SWS wireline, hydraulic unit on winch failed
00:30 - 05:30 5.00 WAlTON EQIP PROD Attempted to repair hydraulic switch on winch with no success, W.O.
back up logging truck to arrive rig, RD sheaves, back up unit arrived at
04:30 hrs, RU sheaves and re-head wire line
05:30 - 10:15 4.75 LOG ELOG PROD RIH with US IT logging tool and tool stopped at 7,200', cont RIH using
tractor tool to 8,160', ran bond log from 8,160' to 4,792' and POOH with
wireline
10:15 - 10:45 0.50 LOG RURD PROD LD USIT and tractor tool & RD SWS wireline
10:45 - 11 :30 0.75 CASE RURD CMPL TN RU Doyons 5 1/2" liner running equipment
11:30-12:00 0.50 CASE SFTY CMPL TN Held PJSM with rig crew on running of liner (crew change)
12:00 - 16:00 4.00 CASE PULR CMPL TN PU and RIH with 51/2",15.5#, L-80, BTCM Liner per well program to
5,856' (137Jts total), ran 5 1/2" ROT silver bullet guide shoe with no
float, ran a total of 92 jts (3,944') of 51/2" 15.5#, L-80, BTCM blank
liner, ran 45 jts (1,881 ') of 5 1/2", 15.5# L-80 BTCM liner, ran 121 - 5
1/2" x 8 1/2" spiralglide centralizers 1/jt #3 thru # 123, ran 15 constrictor
packers placed on blank liner to cover shale sections.
16:00 - 16:45 0.75 CASE PULR CMPL TN MU Baker 190-47 seal bore ext, 9 5/8" x 7" Flexlock liner hanger with,
e "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to
5,909", st wt up 95K, dn wt 67K,
16:45 - 18:00 1.25 CASE RUNL CMPL TN RIH with liner on 5" DP to 8,283' (9 5/8" csg shoe at 8,290')
18:00 - 18:30 0.50 CASE CIRC CMPL TN Circ a DP capacity at the 9 5/8" csg shoe, circ at 3 bpm at 150 psi, st wt
Printed: 6/21/2005 1:33:38 PM
.
.
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
5/18/2005 18:00 - 18:30 0.50 CASE CIRC CMPL TN up 127K, dn wt 75, set torque limiter on top drive to 4,500 ft-Ibs torque,
pipe would not rotate unless pipe was moving, would rotate at 4 rpm's
at 4,500 ft-Ibs torque
18:30 - 21:45 3.25 CASE RUNL CMPL TN Cont to RIH with 5 1/2" liner on 5" DP from 8,283' and tagged btm at
13,539' with no problems RIH, PU liner to setting depth, ran liner with
11 stds of 5" DP slick, 60 stds of 5" DP w/Lo-Tads, 8 stds HWDP and 1
std of slick 5" DP , st wt up 200K, dn wt 75K
21 :45 - 22:30 0.75 CASE RUNL CMPL TN Dropped 1 3/4" ball and pumped down to seat, pumped at 5 bpm at 590
p$i, with ball on seat pressured up to 2,000 psi to set Flexlock hanger,
slacked off 25K, cont to set packer, pressured up to 4,000 psi and set
ZXP packer and release HR running tool, no problems setting hangerl
packer, set "A2" sand liner with TOL @ 7,619' MD/3,601' TVD and
shoe at 13,519' MD/3,624' TVD
22:30 - 22:45 0.25 CASE DEQT CMPL TN Tested ZXP packer to 1,000 psi for 5 min & checked ok
22:45 - 23:45 1.00 CASE CIRC CMPL TN PU and sat back down to reconfirmed TOL at 7,619', PU from 7,619' to
7,555' and circ btms up, circ at 336 gpm at 800 psi, no gas at btms up,
st wt up after setting liner 170K, 1 OOK dn
23:45 - 00:00 0.25 CASE OTHR CMPL TN Monitored well-static, preparing to POOH
~ 5/19/2005 00:00 - 04:30 4.50 DRILL TRIP CMPL TN POOH wet with liner running tool from 7,555' to 50', SLM out no corr.
( 04:30 - 05:15 0.75 DRILL PULD CMPL TN LD Baker running tool and cleaned rig floor
05:15 - 05:45 0.50 DRILL PULD CMPL TN Pulled wear bushing
05:45 - 08:45 3.00 WELCT OTHR PROD2 RU & attempted to set test plug, had trouble setting same, flushed out
wellhead and changed out seal ring and finally got to hold pressure
08:45 - 13:00 4.25 WELCT PROD2 Tested rams, valves and manifold to 250 psi low and 3,500 psi high,
tested annular to 250 psi and 2,800 psi, NOTE: Jeff Jones with AOGCC
waived witnessing of test
13:00 - 13:15 PROD2 Installed wear bushing
13:15 -16:45 PROD2 Held PJSM, PU & MU Baker 9 5/8" whipstock assembly BHA #5 and
RIH to 205', MU seal assembly, locator sub, unloader sub, then PU
2-DP pup jts & 1 jt of 5" DP for space out and RIH with seal assembly,
MU whipstock, milling assembly with MWD, oriented and uploaded
MWD and RIH to 205'
16:45 - 21 :00 PROD2 RIH with whipstock assembly on 5" DP from 205' to 6,767'
21 :00 - 21 :30 PROD2 Made MADD pass from 6,767' to 6,817 (sensor depth 6,610'-6,660')'
and correlated MWD to K-13, no corr. circ at 450 gpm's at 1,425 psi, st
wt up 147K, dn wt 80K
21 :30 - 22:00 PROD2 Cont to RIH from 6,817' , oriented whipstock and tagged TOL at 7,619'
22:00 - 23:00 PROD2 Oriented whipstock 12 deg left of high side, tagged TOL at 7,619', set
whipstock and sheared off from same, top of whipstock at 7,524'
MD/3,583' TVD, st wt up 160K, dn wt 92K, RIH with whipstock milling
assembly with 11 stds of slick 5" DP, 60 stds of 5" DP with Lo-tads, 8
stds and 1 single of 5" HWDP
23:00 - 00:00 1.00 WINDO PROD2 Displaced out 9.0 ppg SFMOBM with re-conditioned 9.0 ppg MOBM,
circ at 535 gpm at 2,200 psi
5/20/2005 00:00 - 15:15 15.25 WINDO PROD2 Milled 8 1/2" window in "B" sand lateral from 7,524' to 7,540', cont to
mill to 7,5550' when P-rate slowed to less than 1 'Ihr, possibly due to
concretion, ADT 14.91 hrs, milled at 2-40K wob, 65-80 rpm's, 437 gpm
at 1,625 psi, off btm torque 1 OK ft-Ibs, on btm 7 -16K ft-Ibs, rot wt 120K,
up wt 162K, dn wt 92K, pumped several wt'd hi vis sweep while milling
window with no increase in cuttings back from sweeps, took 4 hrs to mill
window, 10.91 hrs drilling formation below window
15:15-16:00 0.75 WINDO IRe PROD2 Circ btms up while working mills thru window, circ at 437 gpm at 1,625
psi
Printed: 6/21/2005 1 :33:38 PM
.
.
F
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
Monitored well-static, pumped dry job
POOH from 7,550' to whipstock milling BHA #5 at 106'
POOH and LD MWD and mills, gauged mills and lower 8" mill and
upper 8 1/2" mill was in gauge, starting mill went in at 8" and came out
at 7 1/2" and worn on btm due to possibly drilling on concretion, calc fill
on trip out 67 bbls, actual fill 76.5 bbls
MU BHA #7 with 8 1/2" bit #5 and lower and upper mills with flex jt, 1-jt
HWDP, bumper and oil jars RIH to 76'
RIH from 76' to 6,888'
RIH with BHA #6,81/2" bit with lower and upper whipstock mills from
6,888' to 7,501'
Est circ and rotation, rotated down thru whipstock and window with no
problems, TOW at 7,524', BOW at 7,540', tagged gauge hole at 7,541'
and cleaned out to 7,550', rot wt 116K, up wt 145K, dn wt 100K, 80
rpm's, 9K ft-Ibs torque, circ at 455 gpm at 1,500 psi
Drilled 8 1/2" hole from 7,550' to 7565' MD/3,589' ADT .8 hrs, drilled
with 25-28K wob, 90 rpm's, 1 OK ft-Ibs torque, 455 gpm at 1,500 psi,
drilled 3' of concretions from 7,550' to 7,553 before being able to drill to
7,565'. drilled a total of 25' of gauge hole from BOW for Geo-Pilot BHA
Circ btms up while working mills thru window, circ at 455 gpm at 1,500
psi
Monitored well-static, pumped dry job
POOH from 7,565' to BHA #6 at 76'
POOH LD BHA #6, 8 1/2" bit and upper mill in gauge, LD mills, jars, flex
jt and jt of HWDP, cleared rig floor
Pulled wear bushing and flushed out BOP stack after milling window,
re-installed wear bushing
MU 8 1/2" BHA #7 and RIH to 384', MU bit #6, Geo-pilot rotary system
with Stratasteer LWD/MWD/PWD, oriented and uploaded MWD and
shallow tested tool, held PJSM and loaded radioactive sources and RIH
with HWDP and jars to 384'
2.75 DRILL TRIP PROD2 RIH with BHA #7 from 384' to 7,424', PU 2-8 1/2" ghost reamers while
RIH, 1 reamer is 1,008' back from the bit and the 2nd one is 2,499'
back
1.00 RIGMNT RSRV PROD2 Slip and cut 62' of drlg line and serviced top drive and drawworks
0.75 DRILL CIRC PROD2 Est circ and rotation, circ at 125 gpm at 550 psi and 10 rpm's, rotated
down thru whipstock and window with no problems then washed to btm
at 7,565', rot wt 110K, up wt 145K, dn wt 90K
7.00 DRILL DRLG PROD2 Drilled 81/2" hole in "B" sand lateral with Geo-Pilot assembly from
7,565' to 7,659' MD/3,598" TVD (94') ADT 6.35 hrs, 5-17K wob, 30-100
rpm's, 182 spm, 650 gpm, 3,100 psi, off btm torque 10K, on btm torque
11 K ft-Ibs, rot wt 110K, up wt 145K, dn wt 90K, 9.0 ppg MOBM, ave
ECD 10.2 ppg, ave BGG 50 units, Drilled thru concretions from 7,568'
to 7,570' and from 7,590' to 7,598'
12.00 DRILL DRLG PROD2 Directionally drilled 81/2" hole in "B" sand lateral with Geo pilot rotary
steerable system from 7,659' to 8,446' MD/3,567' TVD (787') ADT 8.54
hrs, 5-15K wob, 100 rpm's, 173 spm, 615 gpm, 3,000 psi, off btm
torque 11-14K ft-Ibs, on btm 11-15K ft-Ibs, rot wt 104K, up wt 157K, dn
wt 75K, 9.0 ppg MOBM, ave ECD 10.7 ppg, ave BGG 100 units, max
gas 303 units. NOTE: While Drlg at 8,030' light on Geo-pilot panel
came on showing out of oil, decision was made by Sperry Sun to drill
ahead till tool quits, back up tool was delivered to location. Drilled out of
zone from 7,800' MD/3,610' TVD to 8,122' MD/3,600' TVD (322')
20:00 - 21 :00 PROD2
21 :00 - 00:00 PROD2
5/21/2005 00:00 - 00:30 PROD2
00:30 - 01 :15 PROD2
01:15-02:00
( 02:00 - 02:45 PROD2
02:45 - 03:00 PROD2
03:00 - 06:30 PROD2
06:30 - 07:30 PROD2
07:30 - 09:00 PROD2
09:00 - 12:30 3.50 DRILL PULD PROD2
12:30-15:15
15:15 - 16:15
16:15 - 17:00
17:00 - 00:00
5/22/2005
00:00 - 12:00
Printed: 6/2112005 1 :33:38 PM
.
.
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1E-105
ROT - DRILLING
n 1334@ppco.com
Doyon 141
Start:
Rig Release:
Rig Number:
4/25/2005
6/20/2005
Spud Date: 4/29/2005
End: 6/20/2005
Group:
5/22/2005 12:00 - 00:00 12.00 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral from 8,446' to 9,657'
MD/3,530' TVD (1,211') ADT 8.94 hrs, 5-15K wOb, 120 rpm's, 186 spm,
660 gpm, 3,550 psi, off btm torque 14.5K ft-Ibs, on btm 13K ft-Ibs, rot wt
104K, up wt 163K, dn wt 70K, 9.0 ppg MOBM, ave ECD 11.0 ppg, ave
BGG 170 units, max gas 376 units. Drilled thru several concretions last
24 hrs
5/23/2005 00:00 - 12:00 12.00 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral with Geo pilot rotary
steerable system from 9,657' to 10,388' MD/3,518' TVD (731') ADT
10.14 hrs, 5-15K wob, 120 rpm's, 186 spm, 660 gpm, 3,600 psi, off btm
torque 12-16K ft-Ibs, on btm 11-15K ft-Ibs, rot wt 104K, up wt 170K, dn
wt 63K, 9.0 ppg MOBM, ave ECD 11.0 ppg, ave BGG 100 units, max
gas 183 units. NOTE: Rig and Camp went off highline at 08:00 hrs to
add additional breakers to system for Doyon 15
12:00 - 00:00 12.00 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral from 10,388' to
11,287' MD/3,536' TVD (899') ADT 9.53 hrs, 5-25K wob, 120 rpm's,
186 spm, 660 gpm, 3,800 psi, off btm torque 15.5K ft-Ibs, on btm
12-18K ft-Ibs, rot wt 105K, up wt 186K, dn wt 52K, 9.0 ppg MOBM, ave
ECD 11.5 ppg, ave BGG 175 units, max gas 368 units. Cont to Drill thru
C concretions in "B" Lat
5/24/2005 00:00 - 10:30 10.50 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral from 11287' to 11,976'
MDI 3,504' TVD (689') ADT 8.28 hrs, 4-25K wob, 120 rpm's, 173-186
spm, 615- 660 gpm, 3450-3950 psi, off btm torque 16K ft-Ibs, on btm
14-18K ft-Ibs, rot wt 105K, up wt 194K, dn wt 53K, 9.0 ppg MOBM, ave
ECD 11.5 ppg, ave BGG 260 units, max gas 321 units. Cont to Drill thru
concretions in "B" Lat
10:30 - 11 :00 0.50 DRILL OTHR PROD2 Trouble shoot geo-pilot failure.
11 :00 - 12:15 1.25 DRILL CIRC PROD2 Pump 30 bbl weighted Hi-vis sweep surf -surf @ 660 gpm wI 3900 psi
and 120 rpm rotation. PU wt 180k, SO wt 53k, Rot wt 104k, torque 17k.
12:15 - 14:30 2.25 DRILL REAM PROD2 Backream out of hole f/11 ,976' to 11,194' @ 40'/min., 11,194' to
10,700' @ 20'/min due to packing off
14:30 - 16:45 2.25 DRILL TRIP PROD2 POOH on elevators f/10,700' to 7409'. No problems.
16:45 - 17:00 0.25 DRILL OBSV PROD2 Monitor well- static. Pump dry job.
17:00 - 19:30 2.50 DRILL TRIP PROD2 POOH fl7 409' to 108'.
19:30 - 20:00 0.50 DRILL SFTY PROD2 PJSM on removing RA sources.
20:00 - 20: 15 0.25 DRILL OTHR PROD2 Remove RA sources.
20:15 - 22:45 2.50 DRILL TRIP PROD2 Download MWDILWD tools. UD Geopilot and bit #6, FSF2565 ser #
10684400
22:45 - 00:00 1.25 DRILL TRIP PROD2 PUlMU new geo-pilot and rebuilt bit. Bit # 7, FSF2565 ser # 10676838.
Upload MWDILWD tools.
5/25/2005 00:00 - 00:30 0.50 DRILL TRIP PROD2 Upload MWDILWD tools. PJSM on loading nuke sources. PU NMflex
drill collar.
00:30 - 01 :00 0.50 DRILL OTHR PROD2 Break in seals on Geo-pilot. Shallow test MWD.
01:00 - 01:15 0.25 DRILL OTHR PROD2 Load nuke sources.
01:15 - 04:30 3.25 DRILL TRIP PROD2 RIH, fill pipe every 25 stands. Test MWD, OK. RIH to 7426'.
04:30 - 05:00 0.50 RIGMNT RSRV PROD2 Service top drive and drawworks.
05:00 - 06: 15 1.25 RIGMNT RGRP PROD2 Repair hyd fitting on top drive.
06: 15 - 09:00 2.75 DRILL TRIP PROD2 Continue RIH f/7426' to 11,230'. Fill pipe every 25 stands. Tag up @
11,230'. Rotated w/1 0 rpm and 3 bpm pump to go through window @
7524'.
09:00 - 09:45 0.75 DRILL REAM PROD2 Wash and ream in hole f/11 ,230' to 11,480'. Pump @ 462 gpm wI 2300
psi. Rot wt 95k, torque 15-17k.
09:45 - 10:15 0.50 DRILL TRIP PROD2 Continue RIH f/11 ,480' to 11,866'.
10:15 - 10:30 0.25 DRILL REAM PROD2 Precautionary ream f/11 ,866' to TD @ 11,976'. PU wt 180k, SO wt 60k,
Printed: 6/21/2005 1 :33:38 PM
.
.
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
5/25/2005 10:15 - 10:30 0.25 DRILL REAM PROD2 Rot wt 109k, torque 15k, no pumps.
10:30 - 12:00 1.50 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral from 11976' to 12056'
MD/3,501' TVD (80') ADT .51 hrs, 7K wob, 120 rpm's, 185 spm, 657
gpm, 4100 psi, off btm torque 15K ft-Ibs, on btm 17K ft-Ibs, rot wt 104K,
up wt 183K, dn wt 53K, 9.1 ppg MOBM, ave ECD 11.5 ppg, ffiax gas
180 units. Cont to Drill thru concretions in "B" Lat
12:00 - 13:45 1.75 DRILL DRLG PROD2 Directionally drilled 81/2" hole in "B" sand lateral from 12,056' to 12170'
MD/3,501'TVD(114')ADT1.17hrs, 7-15Kwob, 120rpm's, 185spm,
657 gpm, 4100 psi, off btm torque 15K ft-Ibs, on btm 17K ft-Ibs, rot wt
104K, up wt 183K, dn wt 53K, 9.1 ppg MOBM, ave ECD 11.5 ppg, max
gas 202 units. Cont to Drill thru concretions in "B" Lat
13:45 - 14:15 0.50 DRILL OTHR PROD2 Reboot MWD computer, trouble shoot geo-pilot. Stand back 1 stand.
14:15 - 15:30 1.25 DRILL CIRC PROD2 Circ two bottoms @ 660 gpm wI 4050 psi. Rotate @ 120 rpm. torque
15k. Set deflection to zero on geo-pilot.
15:30 - 17:30 2.00 DRILL TRIP PROD2 Monitor well - static. POOH on elevators f/12, 156' to 10,595'. Pump dry
job.
17:30-21:00 3.50 DRILL TRIP PROD2 POOH on elevators f/10595' to 384'. No problems.
21 :00 - 00:00 3.00 DRILL TRIP PROD2 Rack back HWDP and jars. Rack back NM flex DC's. PJSM on
( removing sources. remove sources. Download MWD. Change out
Neutron density tool.
Calc displ 96 bbls, actual 125.75 bbls.
5/26/2005 00:00 - 00:15 0.25 DRILL TRIP PROD2 Break biU UD geo-pilot. Change one of the 16/32 jets to a 18/32.
00:15 - 00:30 0.25 DRILL OTHR PROD2 Clean rig floor.
00:30 - 01 :00 0.50 DRILL PULD PROD2 PU/MU BHA #9. PU/MU geopilot, bit and MWD.
01 :00 - 02:00 1.00 DRILL OTHR PROD2 Upload MWD/LWD.
02:00 - 02:45 0.75 DRILL OTHR PROD2 Shallow test MWD, ÞU 1 NM flex DC, PJSM on loading nuke sources,
load sources.
02:45 - 06:00 3.25 DRILL TRIP PROD2 RIH wI BHA #9/bit7rr1 , fill pipe every 25 stands.
06:00 - 07:00 1.00 RIGMNT RSRV PROD2 Slip and cut 64', 1 1/4" drilling line.
07:00 - 09:15 2.25 DRILL TRIP PROD2 Con't RIH f/7427' to 12060', filling pipe every 25 stands. PU wt 167k,
SO wt 75k.
09:15 - 09:45 0.50 DRILL REAM PROD2 Precautionary wash and ream f/12060' to 12170'. Pumping 636 gpm wI
4000 psi, rotating 120 rpm w/15k torque.
09:45 - 12:00 2.25 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral from 12,170' to 12324'
MD/3,505' TVD (154') ADT 1.65 hrs, 5-15K wob, 90-120 rpm's,
179-185 spm, 636-657 gpm, 3700-4100 psi, off btm torque 16K ft-Ibs,
on btm 15K ft-Ibs, rot wt 105K, up wt 183-188K, dn wt 55-45K, 9.0 ppg
MOBM, ave ECD 11.5 ppg, max gas 133 units. Cont to Drill thru
concretions in "B" Lat
12:00 - 00:00 12.00 DRILL DRLG PROD2 Directionally drilled 81/2" hole in "B" sand lateral from 12,324' to 13004'
MD/3,479' TVD (680') ADT 7.6 hrs, 5-25K wob, 120 rpm's, 185 spm,
657 gpm, 4000-4100 psi, off btm torque 16-17K ft-Ibs, on btm 15-19K
ft-Ibs, rot wt 103-105K, up wt 188-190K, dn wt 35-51 K, 9.0 ppg MOBM,
ave ECD 11.6 ppg, max gas 186 units. Cont to Drill thru concretions in
"B" Lat
5/27/2005 00:00 - 02:00 2.00 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral from 13004' to 13105'
MD/3,478' TVD (101') ADT 1.12 hrs, 7-17K wob, 120 rpm's, 185 spm,
657 gpm, 4000 psi, off btm torque 16K ft-Ibs, on btm 15-19K ft-Ibs, rot
wt 102-1 03K, up wt 190K, dn wt 35-45K, 9.0 ppg MOBM, ave ECD 11.6
ppg, max gas 186 units. Cont to Drill thru concretions in "B" Lat
02:00 - 04:00 2.00 DRILL OTHR PROD2 Trouble shoot MWD. Tools not working.
04:00 - 06:45 2.75 DRILL DRLG PROD2 Directionally drilled 81/2" hole in "B" sand lateral from 13105' to 13304'
MD/3,476' TVD (199') ADT 1.85 hrs, 5-17K wob, 120 rpm's, 185 spm,
Printed: 6/21/2005 1 :33:38 PM
.
.
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1 E-1 05
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
5/27/2005 04:00 - 06:45 2.75 DRILL DRLG PROD2 657 gpm, 4000-4150 psi, off btm torque 16K ft-Ibs, on btm 16K ft-Ibs,
rot wt 103-1 05K, up wt 190K, dn wt 35-45K, 9.0 ppg MOBM, ave ECD
11.6 ppg, max gas 186 units. Cont to Drill thru concretions in "B" Lat
06:45 - 07:30 0.75 DRILL OTHR PROD2 Confirm wI town on loss of survey's, as to how far to drill.
07:30 - 10:00 2.50 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral from 13304' to 13529'
MD/3,479' TVD (225') ADT 1.62 hrs, 5-14K wob, 120 rpm's, 185 spm,
657 gpm, 4150-4300 psi, off btm torque 16-17K ft-Ibs, on btm 15K
ft-Ibs, rot wt 105-1 09K, up wt 190-200K, dn wt 35-53K, 9.0 ppg MOBM,
ave ECD 11.6 ppg, max gas 186 units. Cont to Drill thru concretions in
"B" Lat
10:00 - 10:30 0.50 DRILL CIRC PROD2 Circ 15 min, attempt to get survey, no luck. SPR's, monitor well.
10:30 - 12:00 1.50 DRILL REAM PROD2 Backream out of hole f/13529' to 12422'. Rotate 120 rpm, circ @ 620
gpm.
12:00 - 12:30 0.50 DRILL WIPR PROD2 POOH on elevators f/12422' to 11866'. Hole fill ok.
12:30 - 13:45 1.25 DRILL WIPR PROD2 RIH f/11866' to 13482', fill pipe, wash f/13482' to TD @ 13529'.
13:45 - 15:45 2.00 DRILL CIRC PROD2 Circ weighted 35 bbl hi-vis sweep, follow wI 3 BU @ 660 gpm wI 3850
psi. PU wt 220k, So wt 47k, torque 20k. Rotate @ 120rpm.
15:45 - 17:45 2.00 DRILL CIRC PROD2 Monitor well- static. Displace wI 947 bbls SFOBM @ 420 gpm w/21 00
( psi. Stand back 1 stand while circ. Over disp by 60 bbl, returns were
80% SFOBM/20% MOBM
17:45 - 18:00 0.25 DRILL OBSV PROD2 SPR's, monitor well-OK. Blow down top drive.
18:00-21:30 3.50 DRILL TRIP PROD2 POOH f/13479' to 7925'. No problems. Calc displacement 43.6 bbls,
actual 60.1
21 :30 - 22:30 1.00 DRILL OTHR PROD2 Madd pass f/7925' bit depth to 7810' bit depth (115'). Logging tool fl
7840' to 7725' (115'). Good SFOBM by 75 bbls pumped. Pumping @
500 gpm wI 2050 psi, 40 rpm. Hole started packing off.
22:30 - 00:00 1.50 DRILL CIRC PROD2 Working tight spot @ 7810-7818', hole packing off, increase rotary to
120 rpm, pumping 500 gpm. MU stand, work down to 7900' wI good
circ. Circ 1 1/2 BU while working up to 7810'.
5/28/2005 00:00 - 00:45 0.75 DRILL CIRC PROD2 Working tight spot @ 7810-7818', hole packing off, rotary @ 120 rpm,
pumping 500 gpm. Work down to 7900' wI good circ. Circ while working
up to 7810'. Hole still packing off @ 7818'. RIH to below where started
circulating. RIH to 9194', no problems..
00:45 - 02:00 1.25 DRILL TRIP PROD2 POOH on elevators f/8194'-7500', to inside 9 5/8" casing. No
problems. Monitor well.
02:00 - 05:45 3.75 DRILL TRIP PROD2 POOH f/7500' to 381'.
05:45 - 06:30 0.75 DRILL TRIP PROD2 Rack back stand of HWDP wI jars, PU a jt of dp- rack back 2NM flex
drill collars, PJSM, remove nuke sources.
06:30 - 07:00 0.50 DRILL PULD PROD2 Attempt to download MWD. No luck. UD MWD to download in pipe
shed.
07:00 - 08:00 1.00 DRILL PULD PROD2 Continue to work - LD BHA.
08:00 - 08:30 0.50 DRILL PULD CMPL T2 Clean rig floor. PU whipstock retrieving tools fl beaver slide.
08:30 - 09:00 0.50 FISH PULD CMPL T2 MU BHA to retrieve whipstock.
09:00 - 12:00 3.00 FISH TRIP CMPL T2 RIH, fill pipe every 25 stands. RIH to 6318'.
12:00 - 12:30 0.50 FISH TRIP CMPL T2 PU 15 jts 5" HWDP, RIH to 7529'. PU wt 190k, SO wt 103k.
12:30 - 13:45 1.25 FISH FISH CMPL T2 Hook and pull free whipstock assembly. Stand back 1 stand.
13:45 - 14:30 0.75 FISH CIRC CMPL T2 CBU @ 515 gpm wI 2950 psi.
14:30 - 18:45 4.25 FISH TRIP CMPL T2 Monitor well- static. POOH wI whipstock assembly. Rabbit 75 stands dp
wI 2.4" rabbit.
( 18:45 - 19:30 0.75 FISH PULD CMPL T2 UD Whipstock retrieving assembly. No whipstock assembly recovered.
calc fill 68 bbls, actual 83 bbls
19:30 - 20:00 0.50 FISH OTHR CMPL T2 Clean rig floor. Functioned blind rams.
20:00 - 20:45 0.75 RIGMNT RSRV CMPL T2 Service rig and top drive.
Printed: 6/21/2005 1:33:38 PM
.
.
1-
t~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1 E-1 05
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
5/28/2005 20:00 - 20:45 0.75 RIGMNT RSRV CMPL T2 Note: While picking 6 1/4" Bowen jars back up from ground to floor via
beaver slide, Derrickman Jon Larson hurt left arm tailing jars through to
floorhands on rig floor.
20:45 - 21:15 0.50 FISH PULD CMPL T2 PU/MU BHA to retrieve whipstock assembly.
21 :45 - 00:00 2.25 FISH TRIP CMPL T2 RIH wI whipstock retrieving BHA #2, fill pipe every 25 stands. RIH to
6319'.
5/29/2005 00:00 - 00:30 0.50 FISH TRIP CMPL T2 Con't RIH wI whipstock retrieving BHA #2 f/6319' to 7510', PU single
dp. PU wt 185k, SO wt 105k
00:30 - 00:45 0.25 FISH FISH CMPL T2 Attempt to engage key slot in whipstock. Rotate 1/4 turn each time,
latched in on 3rd attempt.
00:45 - 01 :00 0.25 FISH JAR CMPL T2 Pull to 225k on weight indicator, allow jars to hit, pull to 275k on
indicator. Re-cock jars, PU and jar wI 300k on indicator, pull to 325k on
indicator. Re-cock jars, PU and jar wI 300k on indicator, pulled
whipstock free wI 318k on indicator. Continue PU to break off single.
Dragging to as much as 235k fl first 20'. UD single dp.
01 :00 - 01: 15 0.25 FISH TRIP CMPL T2 Pull one stand HWDP-slow. Check fl swabbing, OK.
01:15-02:15 1.00 FISH CIRC CMPL T2 Circ one and a half BU (561 bbls) @ 420 gpm wI 1450 psi. Lost 22.2
bbls mud while circ.
( 02:15 - 02:30 0.25 FISH OTHR CMPL T2 Monitor well.
-'-- .- 02:30 - 07:00 4.50 FISH TRIP CMPL T2 POOH slow wI whipstock retrieval assembly #2. Cal fill 65.04 bbls,
actual 75.2 bbls.
07:00 - 09:00 2.00 FISH PULD CMPL T2 UD whipstock assembly (98.5') consisting of: 9 5/8" whipstock slide,
debris barrier sub wI cup, ported drain sub, shear disconnect, bottom
trip anchor, blanking sub, 1 jt 5" dp, 2- 5" dp pup jts, unloader sub,
crossover, locator sub, seal assembly.
09:00 - 09:45 0.75 CASE RURD CMPL T2 Clean rig floor, RU casing equip to run 5.5" Blat liner.
09:45 - 10:00 0.25 CASE SFTY CMPL T2 PJSM wI all team members in running 5.5" liner.
10:00 - 12:00 2.00 CASE RUNC CMPL T2 PUlMUlRIH wI 5.5" L-80 BTCM slotted and blank liner per detail. Baker
5.5" guide shoe(no float), 5.5" 15.5 #/ft L-80 BTCM blank bent joint, 5
jts 5.5" blank, 1 jt slotted wI insert bushing @ pin end, 11jts 5.5" slotted,
7 jts 5.5" blank, 4 jts 5.5" slotted, 9 jts 5.5" blank, 5 jts 5.5" slotted, 15
jts 5.5" blank, 9 jts 5.5" slotted, 6 jts 5.5" blank, 11 jts 5.5" slotted, 7 jts
5.5" blank, 7 jts, 5.5" slotted, 7 jts, 5.5" blank, 7 jts 5.5" slotted, 6 jts
5.5" blank, 8 jts 5.5" slotted, 9 jts 5.5" blank, 3 jts 5.5" slotted, 21' blank
5.5" marker jt, 1 jt 5.5" blank, 3.77' blank 5.5" pup jt, 5.5" casing swivel,
5.5" x 7" crossover bushing, Baker Model B-1 hook hanger 9 5/8" x 7".
Total length 5986.74'. Total of 18 constrictor packers were run to be
placed @ 13260', 12710', 12450', 12245', 11890', 11641', 11045',
10641', 10400',9910',9650',9300',9050',8700',8500', 8134', 7780',
and 7610'. Ran total of 53 jts in hole @ noon.
12:00 - 13:45 1.75 CASE RUNC CMPL T2 Continue running 5.5" L-80 BTCM 15.5 ppf L-80 slottted and blank "B"
lateral liner. Total of 137+ insert + bent jt+ marker jt.
13:45 - 14:30 0.75 CASE RURD CMPL T2 RID Doyon casing tools. RU to PU Baker model B-1 Hook Hanger on 5"
dp. PU/MU hook hanger. PU 93k, SO wt 63k
14:30 - 15:45 1.25 CASE RUNL CMPL T2 Run liner on 5" dp fl 5994' to 7530'.
15:45 - 18:00 2.25 CASE OTHR CMPL T2 Orient bent joint to exit window.
18:00 - 23:15 5.25 CASE RUNL CMPL T2 Run 5.5" liner on open hole on 5" dp f/7530' to 13512'. PU wt 205k, SO
wt 65k. Calc displacement 108 bbls, actual 119 bbls.
23: 15 - 00:00 0.75 CASE OTHR CMPL T2 Orient to hook Baker B-1 95/8" x 7" hook hanger. Working pipe fl
13481' to 13515'. Turning pipe 1/4 turn, work torque and attempt to
hook window.
5/30/2005 00:00 - 01 :30 1.50 CASE OTHR CMPL T2 Orient to hook Baker B-1 95/8" x 7" hook hanger. Working pipe fl
13481' to 13515'. Turning pipe 1/4 turn, work torque and attempt to
Printed: 6/2112005 1 :33:38 PM
.
.
~-
r---==----o
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-105
1E-105
ROT - DRILLING
n 1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
1.50 CASE OTHR CMPL T2 hook window. PU wt 205-225k, SO wt 75-55k. Hooked window wI 61 ' in
(4.23' low shows btm of window @ 7544.23') on stand 79. Hole taking
weight on first 3 attempts to hook hanger and giving false hooks.
Turned pipe 14 times until good confirmed hook. Hooked 3 times in the
only place that would hook wI 61 ' in. Top of Baker hook hanger @
7523.18', Baker guide shoe @ 13509.92'. Set all available weight to
verify down--35k on indicator).
0.50 CASE CIRC CMPL T2 Break off top drive. Drop Baker's ball. Circ ball down @ 2bpm wI 225
psi, increase to 4bpm wI 625 psi. Slow down to 3bpm @ 1000 strokes
wI 400 psi, con't pumping @ 3 bpm, ball reached seat @ 1540 strokes,
increasing presure, ball seat blew @ 1725 psi.
0.50 CASE OTHR CMPL T2 Work left hand torque in pipe to release hook hanger running tool. Work
pipe f/35k to 200k. Once finally released, PU wt 190-195k wlo liner. Set
back down. Tag top with all OP wt available. Top in same spot--7523'
(61.3' in on stand 79 w/35k on wt indicator)
Pull stand 79 and set back (Pulled 61' out of hole+ 3' above floor in
slips= 64'). Bottom of hook hanger ball seat, circ sub orifice BPV and
guide assembly @ 7501 '. PU wt 185k to 190k
Circulate bottoms up @ 444 gpm wI 1500 psi. Circ total of 440 bbls.
Monitor well.
POOH wI Baker B-1 hook hanger running assembly.
Service breaks and lay down liner running tools and ball sear, circ sub
orifice BPV, and guide assemble.
Clean rig floor.
RU Doyon casing tools to run 4 1/2" LEM.
PJSM on running LEM.
PUlMU LEM assembly: Baker Seal assembly, 4 1/2" 12.6 ppf IBT box X
STL pin x-o jt, (2) joints 41/2" 12.6 ppf L-80 IBT tubing, Camco 41/2"
DB nipple wI 3.563" ID profile, (1) jt 41/2" 12.6 ppf L-80 IBT tubing,
LEM,4 1/2" 12.6 ppf L-80 IBT pup joint, 4 1/2" 12.6 ppf, IBT casing
swivel, X-O bushing 51/2" hydril563 box x 41/2" IBT pin, Baker 190-47
casing Seal Bore Receptacle (4.75" ID), X-O 7" hydril 563 box x 5 1/2"
hydril 563 pin, Baker ZXP (7" hydril 563 pin), Baker Hydraulic setting
tool, Baker running tool. While making up and lowering seals into top of
X-O below ZXP, seals hung up; ZXP sheared, slips moved to set
position.
RUlLD LEM BHA.
Clean rig floor.
RU to test BOPE. Witness of BOP test waived by AOGCC inspector
John Crisp.
Pull riser to check annular preventor, visual inspection.
14 day BOPE test. Tested annular to 250 psi low and 2800 psi high.
Tested rams and valves to 250 psi low and 3500 psi high. Held each
test 5 min. Tested accumulator. Tested IBOP valves and floor safety
valves 250/3500, held each test 5 min.
0.50 WELCT OTHR CMPL T2 Rig down test equipment.
0.50 CMPL TN SFTY CMPL T2 PJSM on running LEM.
1.00 CMPL TN PULD CMPL T2 PU/MU LEM assembly: Baker Seal assembly, 4 1/2" 12.6 ppf IBT box X
STL pin x-o jt, (2) joints 4 1/2" 12.6 ppf L-80 IBT tubing, Camco 4 1/2"
DB nipple wI 3.563" 10 profile, (1) jt 4 1/2" 12.6 ppf L-80 IBT tubing,
LEM,4 1/2" 12.6 ppfL-80 IBT pup joint, 4 1/2" 12.6 ppf, IBT casing
swivel, X-O bushing 51/2" hydril563 box x 41/2" IBT pin, Baker 190-47
casing Seal Bore Receptacle (4.75" 10), X-O 7" hydril563 box x 51/2"
5/30/2005 00:00 - 01 :30
01 :30 - 02:00
02:00 - 02:30
02:30 - 02:45 0.25 CASE OTHR CMPL T2
C 02:45 - 03:30 0.75 CASE CIRC CMPL T2
03:30 - 03:45 0.25 CASE OTHR CMPL T2
03:45 - 07:00 3.25 CASE OTHR CMPL T2
07:00 - 07:30 0.50 CASE OTHR CMPL T2
07:30 - 07:45 0.25 CASE OTHR CMPL T2
07:45 - 08:30 0.75 CMPL TN RURD CMPL T2
08:30 - 08:45 0.25 CMPL TN SFTY CMPL T2
08:45 - 10:30 1.75 CMPLTN PULD CMPL T2
10:30 - 12:00 1.50 CMPL TN PULD CMPL T2
12:00 - 12:30 0.50 CMPL TN OTHR CMPL T2
12:30 - 13:00 0.50 WELCT BOPE CMPL T2
13:00 - 13:45 0.75 WE LeT CMPL T2
13:45 - 18:30 4.75 WE LeT CMPL T2
18:30 - 19:00
19:00 - 19:30
19:30 - 20:30
Printed: 6/21/2005 1 :33:38 PM
.
.
/...--
r-~-
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
5/30/2005 19:30 - 20:30 1.00 CMPL TN PULD CMPL T2 hydril 563 pin, Baker ZXP (7" hydril 563 pin), Baker Hydraulic setting
tool, Baker running tools.
20:30 - 21 :00 0.50 CMPL TN RURD CMPL T2 RID casing tools.
21 :00 - 00:00 3.00 CMPL TN TRIP CMPL T2 RIH wI LEM to 5016'
5/31/2005 00:00 - 01 :30 1.50 CMPL TN TRIP CMPL T2 RIH wI LEM f/5016' to 7545'. PU wt 180K, SO wt 101K
01 :30 - 04:30 3.00 CMPL TN OTHR CMPL T2 Tag up @ 7545'. Orient and work through hook hanger.
04:30 - 05:00 0.50 CMPL T TRIP CMPL T2 Con't RIH wI LEM assembly f/7545' to 7619'. Tag up @ 7619'. Attempt
to work through- no luck. PU wt 195k, SO wt 105k.
05:00 - 07:15 2.25 CMPL T OTHR CMPL T2 Tag up @ 7619'. Attempt to work through- no luck. PU wt 195k, SO wt
105k.
07:15 - 12:00 4.75 CMPLTN TRIP CMPL T2 Monitor well, POOH f/7619' to 216'.
12:00 - 13:30 1.50 CMPL TN PULD CMPL T2 RU and UD LEM assembly.
13:30 - 13:45 0.25 CMPL TN OTHR CMPL T2 Clean Rig Floor.
13:45 - 15:00 1.25 CMPL TN PULD CMPL T2 PU seal assembly wI a bent joint 41/2" tbg, + rest of LEM assembly.
15:00 - 20:00 5.00 CMPL TN TRIP CMPL T2 RU to RIH wI LEM assembly, RIH wI LEM assembly to 7619'.
20:00 - 21:15 1.25 CMPL T OTHR CMPL T2 Tag up @ 7619'. Try to work by top of liner hanger- no luck. PU wt
185K, SO wt 107K, Rot wt 130k.
21 :15 - 22:30 1.25 RIGMNT RSRV CMPL T2 Pull partial stand and 10' pup jt. Stand 77 in hole. Slip and cut 65'
e drilling line.
22:30 - 00:00 1.50 RIGMNT RSRV CMPL T2 Service top drive, inspect saver sub, clean rig floor. Prepare to take Oil
base mud into pits. Prepare to remove solids free oil base mud fl pits
and store into uprights.
6/1/2005 00:00 - 01 :00 1.00 CMPLT OTHR CMPL T2 Prepare to take 9.0 ppg MOBM into Pits, remove 9.0 ppgSolids free oil
base mud fl pits. Transfer to upright storage.
01 :00 - 02:30 1.50 CMPL TN CIRC CMPL T2 Displace solids free 9.0 ppg to Mineral oil base mud 9.0 ppg @ 89 spm
(7.5 bpm) wI 900 psi. 35 bbls interface put in MOBM.
02:30 - 02:45 0.25 CMPL TN OTHR CMPL T2 SPR, monitor well.
02:45 - 07:00 4.25 CMPL TN TRIP CMPL T2 POOH with LEM assembly f/7566' to 207'.
07:00 - 08:30 1.50 CMPLT PULD CMPL T2 RU and UD LEM assembly.
08:30 - 09:30 1.00 FISH OTHR CMPL T2 Clean Rig Floor. PU Baker tools to floor to handle 2 7/8" equiptment.
09:30 - 11 :30 2.00 FISH PULD CMPL T2 MU Cleanout BHA: 4 11/16" x 3 518" Junk basket mill shoe, 3 5/8" Junk
basket extension, 35/8" rev circ jet bushing, x-o , 14 jts 2 7/8" PAC drill
pipe, x-o, Bowen bumper sub, Bowen Super jar, x-o (6.25" OD).
11 :30 - 14:30 3.00 FISH TRIP CMPL T2 RIH f/465' to 7615' wI cleanout assembly on 5" DP. Tag up @ 7615'.
PU wt 156k, SO wt 106k, Rot wt 130k.
14:30 - 15:00 0.50 FISH CIRC CMPL T2 Drop ball. Circ @ 210 gpm wI 900 psi ball to activate rev circ junk
basket
15:00 - 16:45 1.75 FISH MILL CMPL T2 Milling f/7615' to 7619' w/210 gpm @ 1050 psi. Rotate wI 50 rpm,
torque 10-12k. Mill to 7649'.
16:45 - 18:30 1.75 FISH OTHR CMPL T2 RIH wI mill-no rotation f/7649' to 8071'. Circ @ 210 gpm wI 1000 psi.
18:30 - 19:45 1.25 FISH CIRC CMPL T2 Pump Hi-vis sweep @ 320 gpm wI 2000 psi.
19:45 - 20:00 0.25 FISH OTHR CMPL T2 SPR, Monitor well
20:00 - 21 :00 1.00 FISH TRIP CMPL T2 POOH slow f/8071' to 7503'.
21 :00 - 21 :45 0.75 FISH TRIP CMPL T2 RIH f/7503', took wt @ 7617', push to 7627', PU to 7580', RIH tag @
7627',
21 :45 - 00:00 2.25 FISH MILL CMPL T2 Rotate @ 50 rpm, 284 gpm wI 1650 psi. Milling fl 7627' to 7635, slide fl
7635' to 7644', taking wt @ 7644', Rotate 7643' to 7646'. Torquing up
@ 7646'.
6/2/2005 00:00 - 00:45 0.75 FISH MILL CMPL T2 Pull f/7646' to 7500' (up above hook hanger), RIH f/7500' to 7645',
( taking wt @ 7645',
00:45-01:15 0.50 FISH MILL CMPL T2 Pull up above 7645', start pumping 80 spm wI 1650 psi, rotate 50 rpm,
Mill on junk f/7644' to 7645', torqued up @ 7645', Pull up to 7640', free
rotating, ran 7640' to 7648', taking a little wt @ 7648', PU, ran to 7712'
Printed: 6/21/2005 1 :33:38 PM
.
.
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1 E-1 05
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
6/212005 00:45 - 01:15 0.50 FISH MILL CMPL T2 without rotation.
01 :15 - 02:30 1.25 FISH MILL CMPL T2 Start rotating @ 7708' to 7729'. Slide f/7729' wlo rotation to 7837',
then took wt. PU and slide to 8010'. PU , slide fl 8010; to 8052' taking a
little extra wt @ 7977', slide to 8052'. PU, slide f/8052' -8078', Rotate fl
8078' to 8087, torquing @ 8087'. PU wt 165-170K, SO wt 112k.
02:30 - 04:30 2.00 FISH CIRC CMPL T2 PU f/8087' to 8078'. Pump 30 bbl hi-vis sweep@ 89 spm (316 gpm) wI
2000 psi. Calc surf-surf 6219 strokes (526 bbls). Surf to mill 112 bbls.
Pump total of 9532 strokes (806.4 bbls).
04:30 - 05:15 0.75 FISH TRIP CMPL T2 Monitor well, POOH f/8087' to 7500'.
05:15 - 05:45 0.50 FISH TRIP CMPL T2 RIH fl 7500' to 8030'
05:45 - 06:45 1.00 FISH TRIP CMPL T2 POOH f/8030' to 7500'. Pull tight @ 7973',7-8 k over pull. Con't POOH
to above hook hanger.
06:45 - 07:45 1.00 FISH TRIP CMPL T2 RIH f/7500' to 8089'. Slight bobble @ 7647'.
07:45 - 09:30 1.75 FISH CIRC CMPL T2 Pump hi vis sweep. Pumping @ 90 spm, 320 gpm, wI 2050 psi.
09:30 - 10:30 1.00 FISH TRIP CMPL T2 POOH f/8060' to 7500'. PU wt 165k. Pull tight @ 7647',12 k over, work
pipe through, OK.
10:30 - 11: 15 0.75 FISH TRIP CMPL T2 RIH f/7500' to 8089'. Tag up @ 7648', work pipe, con't to 8089'.
11 :15 - 12:00 0.75 FISH TRIP CMPL T2 POOH fl 8089' to 7823'. No problems. PU wt 170K, SO wt 114k while
( on bottom.
12:00 - 15:45 3.75 FISH TRIP CMPL T2 Continue POOH wI Cleanout BHA: 4 11/16" x 3 518" Junk basket mill
shoe, 35/8" Junk basket extension, 35/8" rev circ jet bushing, x-o , 14
jts 2 7/8" PAC drill pipe, x-o, Bowen bumper sub, Bowen Super jar, x-o
(6.25" OD).
15:45 - 16:15 0.50 FISH OTHR CMPL T2 Clean rig floor.
16:15 - 18:30 2.25 FISH PULD CMPL T2 RU Baker small tongs to lay down small BHA. UD 14 jts 2 7/8" DP,
Break junk sub. Recovered over 1 Ib of steel junk fl 5.5" x 8.25"
Weatherford spiralglider. Recovered some rubber fl Easy Solutions
swell packer and ID metal fl swell packer.
18:30 - 19:00 0.50 FISH OTHR CMPL T2 Clear Baker small tools fl rig floor.
19:00 - 19:30 0.50 FISH OTHR CMPL T2 Clean rig floor.
19:30 - 19:45 0.25 CMPL T SFTY CMPL T2 RU and PJSM on running Lateral Entry Module.
19:45 - 21:00 1.25 CMPL T PULD CMPL T2 PUlMU LEM assembly: Baker4 3/4" Seal assembly, 41/2" 12.6 ppf IBT
box X STL pin x-o jt(bent), (2) joints 4 1/2" 12.6 ppf L-80 IBT tubing,
Camco 41/2" DB nipple wI 3.563" ID profile, (1) jt 41/2" 12.6 ppf L-80
IBT tubing, LEM, 4 1/2" 12.6 ppf L-80 IBT pup joint, 4 1/2" 12.6 ppf pup
jt, IBT casing swivel, X-O bushing 5 1/2" hydril 563 box x 4 1/2" IBT pin,
Baker 190-47 casing Seal Bore Receptacle (4.75" ID), X-O 7" hydril563
box x 5 1/2" hydril 563 pin, Baker ZXP (7" hydril 563 pin), Baker
Hydraulic setting tool, Baker running tools.
21 :00 - 00:00 3.00 CMPL TN TRIP CMPL T2 RIH wI LEM assembly on 5" DP fl 207' to 5499'
6/3/2005 00:00 - 01 :30 1.50 CMPL TN TRIP CMPL T2 RIH wI LEM assembly on 5" DP fl 5499' to 7619'. Pu wt 170K, SO wt
110K.
01 :30 - 02:45 1.25 CMPL T TRIP CMPL T2 RIH wI LEM assembly on 5" DP fl 7619' to 7649' w/95k on wt
indicator.:: Took slight amount of wt @ 7635' (RS nipple), worked pipe,
Run to 7647' (x-o bushing), set down 15K, worked pipe down to 7649'
wI 95k on indicator. Saw some over pull to 195k when picked up (25k
over).
02:45 - 04:15 1.50 CMPL TN TRIP CMPL T2 Work LEM down f/7649' to 7655' w/95k on indicator.:: Taking a little
weight @ 7652', work down to 7655', then to 7655' w/95k on indicator.
Picked up wI 170K. SO wt 111 k.
04:15 - 06:15 2.00 CMPL TN TRIP CMPL T2 PU f/7655' to 7500', rotate pipe 1/2 round, slack off, tag up @ 7647'
(x-o bushing), work, then PU again, rotate 1/4 turn, Tag up again, PU
to 7500', turn 1/4, slack off to 7655' wI 95k on indicator. Dragging to
Printed: 6/21/2005 1 :33:38 PM
.
.
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1 E-1 05
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
185-190k wI PU, then free.
Work pipe while circ @ 56 spm (199 gpm) wI 500 psi. PU wt 170k, SO
wt 106, set down 65k, no extra movement down. 7655' final depth
reached wI mule shoe and 95k on wt indicator..
08:30 - 12:00 3.50 CMPLT TRIP CMPL T2 Monitor well, POOH fl 7655' to 4307'. PU wt 172k, SO wt 11 OK
12:00 - 13:30 1.50 CMPL TN TRIP CMPL T2 Continue POOH wI LEM assembly f/4307' to 207'.
13:30 - 15:30 2.00 CMPL T PULD CMPL T2 RU small tools and ready floor, Lay down 4 1/2" LEM assebly.
15:30 - 16:00 0.50 CMPL TN OTHR CMPL T2 Clear and clean rig floor.
16:00 - 17:00 1.00 WELCT EQRP CMPL T2 Change bottom pipe rams f/5" to 2 7/8", RU to test rams.
17:00 - 17:45 0.75 WELCT BOPE CMPL T2 Test bottom pipe rams to 250 psi low and 3500 psi high. Chart test.
17:45 - 19:00 1.25 FISH RURD CMPL T2 RU to MU small tool string to clean out A2 liner.
19:00 - 19:15 0.25 FISH SFTY CMPL T2 PJSM on picking up small string to clean out liner.
19:15-19:45 0.50 FISH PULD CMPL T2 MU 411/16" x 3 518" JS mill shoe, 3 5/8" junk basket extension, 35/8"
rev circ jet bushing, x-o, x-o.
19:45 - 00:00 4.25 FISH TRIP CMPL T2 PU/MU 198 jts 2 718" 6.4ppf, L-80, hydril 511 tubing.
6/4/2005 00:00 - 02:45 2.75 FISH TRIP CMPL T2 Con't PUlMU 198 jts 2 7/8" 6.4ppf, L-80, hydril 511 tubing to 5823'. PU
wt 57k, SO wt 45k
- Drifted 2 7/8" wI 2" rabbit.
/'
( 02:45 - 03:15 0.50 FISH OTHR CMPL T2 Rig down tongs fl handling 2 7/8". RU to handle a jt of 3 1/2" dp.
03:15 - 04:30 1.25 FISH PULD CMPL T2 PU/MU Baker tools.:: double pin x-o, (2) boot baskets, bit sub, x-o,
Bowen bumper sub, Bowen super jar, x-o. SO wt 47k
04:30 - 04:45 0.25 FISH TRIP CMPL T2 SLM, RIH 70' of first stand of 5" DP.
04:45 - 05:15 0.50 FISH CIRC CMPL T2 Circ drill string volume plus a little (50 bbls). 61 spm = 1850 psi. Check
out torque. 50 rpm 1 k torque. PU wt 60k, SO wt 48k, rot wt 53k.
05:15 - 06:00 0.75 FISH TRIP CMPL T2 RIH wI cleanout assembly on 5" dp. Taking a little weight @ 7650'.
06:00 - 06:45 0.75 FISH TRIP CMPL T2 Taking a little weight @ 7650'. Continue till through CSR (bottom @
7669'), then again @ 7708'. PU wt 90k, SO wt 69K, slack off to as
much as 60K. Screw into 5", establish rotation wI 2000 ftIlb torque. Rot
wt 79k.
06:45 - 07:30 0.75 FISH TRIP CMPL T2 Continue RIH wI cleanout assembly on 5" DP f/7708' to 8080'. No
problems
07:30 - 09: 15 1.75 FISH CIRC CMPL T2 RU to displace well fl MOBM to solids free oil base mud @ 8080'. Circ
@ 55 spm (4.65 bpm) (195 gpm) wI 1800 psi.
09:15 - 09:30 0.25 FISH OTHR CMPL T2 Check fl flow, OK.
09:30 - 10:00 0.50 FISH CIRC CMPL T2 Drop 5/8" ball to activate rev basket jet. Pump ball down @ 60 spm (5
bpm) (213 gpm) wI 2050 psi.
10:00 - 11 :30 1.50 FISH MILL CMPL T2 Mill f/8093' to 8098'. PU wt 90k, SO wt 65k, Rot wt 83k, torque
2500-3000 ftIlb. Pump 60 spm (5 bpm) (213 gpm) wI 2100 psi. 50 rpm
11 :30 - 12:00 0.50 FISH OTHR CMPL T2 Continue w/4 11/16" mill and rev basket cleanout assembly f/8098' to
8189'.
8226'
12:00 - 00:00 12.00 FISH OTHR CMPL T2 Continue wI 4 11/16" mill and rev basket cleanout assembly fl 8189' to
12050'. Tagging collars every +1-42'. PU wt 155k, SO wt 63k.
Tag @ 8226', mill @ 8224', then slide to next collar 8268', then slide to
8562' then to 8718', slide 8718'-9028',9072' took wt, work past to
10214', work past, slide to 10345', worked past, slide to 10515', work
past to 10645', work past, slide to 11200', hung up @ 11240', worked
thru, slide to 11460'.
6/5/2005 00:00 - 02:45 2.75 FISH OTHR CMPL T2 Continue wI 4 11/16" mill and rev basket cleanout assembly f/12050' to
13155'. Pumping 60 spm (5 bpm) w/21 00-2400 psi. PU wt 190-195k,
SO wt 82K
02:45 - 03:00 0.25 FISH OTHR CMPL T2 Continue wI 4 11/16" mill and rev basket cleanout assembly f/13155' to
13341'. Pumping 60 spm (5 bpm) wI 2475 psi. PU wt 190-195k, SO wt
Printed: 6/21/2005 1 :33:38 PM
.
.
,-r-'
r"-
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1 E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
6/512005
02:45 - 03:00
0.25 FISH
OTHR CMPL T2
03:00 - 04:00
1.00 FISH
OTHR CMPL T2
04:00 - 06: 15
2.25 FISH
CIRC CMPLT2
06: 15 - 06:30 0.25 FISH OTHR CMPL T2
06:30 - 12:00 5.50 FISH TRIP CMPL T2
12:00 -12:15 0.25 FISH TRIP CMPL T2
12:15-13:00 0.75 FISH PULD CMPL T2
C 13:00 -14:00 1.00 FISH RURD CMPL T2
14:00 - 14:15 0.25 FISH SFTY CMPL T2
14:15 - 21:15 7.00 FISH PULD CMPL T2
21:15 - 21:45 0.50 FISH PULD CMPL T2
21 :45 - 22:30 0.75 FISH RURD CMPL T2
22:30-23:15 0.75 FISH OTHR CMPL T2
23: 15 - 00:00 0.75 WELCT EQRP CMPL T2
6/6/2005 00:00 - 01 :30 1.50 WELCT BOPE CMPL T2
01 :30 - 02:00 0.50 WELCT BOPE CMPL T2
02:00 - 02:15 0.25 CMPL TN RURD CMPL T2
02:15 - 02:30 0.25 CMPL TN SFTY CMPL T2
02:30 - 04:30 2.00 CMPL TN RUNT CMPL T2
04:30 - 04:45
04:45 - 10:00
0.25 CMPL TN RURD CMPL T2
5.25 CMPL TN TRIP CMPL T2
(
'-.
10:00-11:15
1.25 CMPL TN PCKR CMPL T2
82K Rot wt 127k, torque 13-14k to rotate.
Note: Insert bushing is @ 13247' in "B" lateral. Insert bushing in
A2 is @ 13452')
SLM of 78 stands 2.35' longer. No correction
Approaching top of hook hanger wI upper mill (7.4" OD). Slack off 9.5',
PU to 205K then free. Slack off while rotating, slight indication of top @
8' in while rotating (13349.73'), rotate to 10' in (13251.73'). PU, start
rotation again and slack off to 11' in (13352.73). PU wI 215k. Free up.
Circ Hi-Vis sweep wI 4 11/16" mill @ 13350' (8' in on jt after stand 78).
Therfore the 7.4" mill is @ 7521.65'. Calculated surf- surf 641.8 bbls
(7586 strokes). Circ @ 60 spm (5 bpm) 213 gpm wI 2500 psi.. ANN
velocity in 5 1/2" x 2 7/8" = 316 ftlmin. 9 5/8" csg x 27/8" = 73 ftlmin. 9
5/8" x 5" dp = 97 ftlmin. PU wt 193k, SO wt 85k.
Monitor well. OK.
POOH wI cleanout assembly f/13350' to 6355'
Continue POOH wI cleanout assembly f/6355' to 5889'.
UD 31/2" dp & Baker tools.:: double pin x-o, (2) boot baskets, bit sub,
x-o, Bowen bumper sub, Bowen super jar, x-o. SO wt 47k
RID 3 1/2" handling tools, RU to UD 2 7/8" tubing.
PJSM on laying down 2 7/8" tubing.
UD 198 jts of 2 7/8" 6.4 ppf L-80 Hydril 511 tubing.
Break and UD 4 11/16" x 3 518" JB mill shoe, 35/8" junk basket
extension, 3 5/8" rev circ jet bushing, x-o, x-o. Clean out junk basket.
Recovered 18 pounds 3 oz of metal fl 5 1/2" x 8 1/4" Weatherford
spiralgliders.
RID tools fl handling 2 7/8". RID Doyon double stack tongs.
Clean rig floor.
Pull wear bushing, set test plug. Prepare to change rams f/2 7/8" to 5"
in lower BOPE.
Change lower rams f/2 7/8" to 5". RU test equip. Test lower rams to
250 psi low and 3500 psi high, 5 min each. Charted test. Called
AOGCC inspector Jeff Jones.
Pull test plug, install Vetco Gray wear bushing, UD tools.
RU to run Baker LEM.
PJSM on running Baker LEM assembly.
PUlMU LEM assembly: Baker4 3/4" Seal assembly, 41/2" 12.6 ppf IBr
box X STL pin x-o jt(bent), (2) joints 4 1/2" 12.6 ppf L-80 IBT tubing,
Cameo 4 1/2" DB nipple wI 3.563" ID profile, (1) jt 4 1/2" 12.6 ppf L-80
IBT tubing, LEM, 4 1/2" 12.6 ppf L-80 IBT pup joint, 41/2" 12.6 ppf pup
jt, IBT casing swivel, X-O bushing 5 1/2" hydril 563 box x 41/2" IBT pin,
Baker 190-47 casing Seal Bore Receptacle (4.75" ID), X-O 7" hydril 563
box x 5 1/2" hydril 563 pin, Baker ZXP (7" hydril 563 pin), Baker
Hydraulic setting tool, Baker running tools.
RID equip.
RIH wI LEM assembly on 5" DP f/207' to 7523' ( Fill pipe every 25
stds). Run assy through Hook Hanger to 7544' tag up bttm of window.
PU and orient string 1/4 turn. RIH and only saw a few small bobbles on
indicator. RIH to top of A2 ZXP@ 7619'. Up wt 189K, DN wt 105K.
Work seals and set LEM in place. Had good solid location on depth and
showed 20K release from locator ring when PU. Top of LEM @ 7509'
MD ( end of seals @ 7662' MD) Seals buried 12.57' in CSB 19.48' long.
Drop Ball and pump to seat - Set ZXP Packer - Pressure up to 2500 psi
and hold for 3-4 min. Work psi up to 4000 psi in 500 psi steps holding
Printed: 6/21/2005 1:33:38 PM
.
.
f-
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1 E-1 05
ROT - DRILLING
n 1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
11:15-13:30
13:30 - 14:45
c
14:45 - 20:45
CMPL T2
1.25 CMPL T PCKR CMPL T2
6.00 CMPL TN TRIP CMPL T2
20:45 - 21:15 0.50 CMPL TN OTHR CMPL T2
21:15-21:45 0.50 CMPL TN PULD CMPL T2
21:45 - 23:15 1.50 RIGMNT RSRV CMPL T2
23:15 - 00:00 0.75 RIGMNT RSRV CMPL T2
6/7/2005 00:00 - 02:00 2.00 CMPL T OTHR CMPL T2
02:00 - 02:15 0.25 FISH PULD CMPL T2
02:15 - 03:45 1.50 FISH TRIP CMPL T2
03:45 - 05:00 1.25 FISH TRIP CMPL T2
05:00 - 06:30 1.50 FISH TRIP CMPL T2
06:30 - 07:45 1 .25 FISH TRIP CMPL T2
07:45 - 12:30
12:30 - 14:30
(
4.75 FISH
TRIP CMPLT2
2.00 FISH
PULL CMPL T2
each 3-4 min. Had no indication of packer set. Work wt from 50k DN ,
205K up
Con't to attempt to set packer with pressure. Worked pressure from
2500 psi to 4000 psi 2 times without any sign of setting. Attempt to
pressure up csg ann pumping down back side. Will not pressure up.
Pumped 73 stks (6.2 bbls) 425psi. Worked pressure from 2500 psi to
4500 psi 3 times with no indication of packer setting. At this point we
tryed to surge drill string. Pressuring up to 1000 psi and then release
the pressure swiftly to surge the drill string. Afterword we attempted to
pressure up 2500 psi to 4500 psi again to set packer. No indication. We
attempted to pressure up again on the csg ann. Will not test, Pumped
65 stks (5.5 bbls) During all attempts worked wt from 50K DN wt, 205K
Upwt.
After discussion with Baker Supv, Well Engineer and Rig Supv it was
decided to safety off the ZXP with left had torq. The baker procedure on
this tool is to work the wt from neutral point, torq string with left hand
from 1/2 to 3/4 turn while working wt from 60K to 210K. 6114 rounds of
torque was worked down the string with no indication of a release. The
LEM snap out up wt remained 220k and no sign of release was seen.
Monitor well, POOH wI LEM assembly (inspecting Lo-Tads on 5" dp,
cahnged out Lo-tad on stand #10, #8 & #6). Drill string started pulling
dry @ 896'. Calc displ 71.4 bbls, actual 89.7 bbls. No LEM assembly on
end of DP. Running tools only.
Clean rig floor.
Break and lay down Baker running tool.
Slip and cut drilling line. Service top drive.
Recalibrate block height fl Sperry Sun MWD fl depth tracking.
Cleaned rig floor. Change out dies in rig tongs and on iron roughneck
while waiting on running tool
MU Baker HRD liner running tool to retrieve LEM assembly.
RIH wI Baker LEM retrieval tools on 5" DP f/20' to 2415'., fill pipe @ 25
stands (2415', PU wt 75k, SO wt 69K, circ @ 22 spm (78 gpm) wI 100
psi.)
Con't RIH wI Baker LEM retrieval tools on 5" DP f/2415' to 4829'., fill
pipe @ 25 stands (4829', PU wt 110k, SO wt 74K, circ @ 22 spm (78
gpm) wI 180 psi.)
Con't RIH wI Baker LEM retrieval tools on 5" DP f/4829' to 6737'., mud
started running over the top once started running HWDP (6360'), runs
over 10' above floor, PU wt 155k, SO wt 92K,
Con't RIH wI Baker LEM retrieval tools on 5" DP f/6737' t07386' and
latched onto LEM, mud running over top 10' above floor, PU wt 189k,
SO wt 105K, - Tag up solid at 7386' (This point by calulation would be
the coupling at the top of the seals (21' up from mule shoe) tagging out
at the 4.86" ID XO bushing 8.62' below bttm of window "B" Lat.
POOH with fish from 7,386' to running tool at 210', st wt up wt 195K -
Appears to have additional weight to equal LEM assy, Pulling speed
was kept slow to reduce swabbing. Hole took proper fill
LD running tool and LEM, at surface it was seen the retreiving tool
worked as designed, made full insertion and latched. No damage was
notep on the LEM assy only minor scoring. The seal assy did have
scoring around the packing stem and the seals had to be replaced. All
scoring marks were dressed with emery cloth to remove all sharp
edges. Remove all tools and clean OBM from rig floor.
Printed: 6/21/2005 1:33:38 PM
.
.
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
Remove old tools from shed and load in new ZXP packer, Finished
installing new seals.
15:15-15:30 CMPL T2 Held PJSM with Baker rep on MU LEM assembly.
15:30 - 16:45 CMPL T2 PU LEM assembly #2 with ZXP packer and RIH to 210'
16:45 - 21 :30 CMPL T2 RIH with LEM assembly on 5" DP from 210' to 7,523' to hook hanger, st
wt up 195K, dn wt 105K
21 :30 - 22:00 CMPL T2 Oriented LEM and located hook hanger at 7,523' and landed same with
ZXP packer top at 7,462', snapped in & out of hanger several times to
verify on depth and latching into hook hanger
22:00 - 23:00 Dropped 1 3/4" phenolic ball and pumped down to seat, pumped down
at 3.5 bpm at 380 psi, pressured up to 2,500 psi to set packer, then
pressured up to 4,000 psi to release from setting tool, no problems
setting packer
23:00 - 23:15 0.25 CMPL TN DEQT CMPL T2 Pressure tested ZXP packer and annulus to 1,000 psi for 5 min, good
test
23:15 - 23:30 0.25 CMPL TN PCKR CMPL T2 PU out of ZXP packer, then rotated DP while setting 75K st wt down on
packer, rotated at 15 rpm's with 14K ft-Ibs torque with 128K rot wt
23:30 - 00:00 0.50 CMPL TN TRIP CMPL T2 Began POOH with running tool, POOH from 7,462' to 7,382'
C 6/8/2005 00:00 - 02:45 2.75 CMPL TN TRIP CMPL T2 POOH with Baker LEM running tool from 7,382' to 20'
02:45 - 03:30 0.75 CMPLTN PULD CMPL T2 Made service breaks on running tool and LD same, cleared rig floor
03:30 - 03:45 0.25 WINDO FTY PROD3 Held PJSM with Baker Rep, Sperry Sun and crew on PU & MU of
whipstock assembly
03:45 - 09:00 ULD PROD3 MU Baker 9 5/8" btm trip whipstock assembly BHA #15 and RIH to
580', MU seal assembly, locator sub, un loader sub, then PU 1-DP pup
jt & 5 jts of 5" DP for space out and RIH with seal assembly, MU
whipstock, milling assembly with MWD, oriented and uploaded MWD,
PU 9-6 3/4" Dc's and RIH to 580'
09:00 - 13:30 PROD3 RIH with whipstock assembly from 580' to 6,850', RIH with 13 stds of 5"
HWDP above 6 3/4" Dc's
13:30 - 13:45 IRC PROD3 Made MADD pass from 6,850' to 6,885 (sensor depth 6,600'-6,635')
and correlated MWD to K-13, circ at 450 gpm's at 2,100 psi
13:45 - 14:15 PROD3 RIH from 6,885' to 7,145'
14:15 - 14:45 PROD3 Oriented whipstock 15 deg's left of high side and tagged top of LEM at
7,462', set whipstock and sheared off from same, top of whipstock at
7,258' MD/3,528' TVD, st wt up 200K, dn wt 83K, RIH with whipstock
milling assembly with 3 stds 6 3/4" Dc's, 13 stds of 5" HWDP and 57
stds of 5" DP with Lo-tads
14:45 - 16:00 PROD3 Displaced hole over from 9.0 ppg SFMOBM to 9.05 ppg MOBM, circ at
568 gpm at 3,000 psi
16:00 - 21 :30 PROD3 Milled 8 1/2" window for "D" sand lateral from 7,258' to 7,274', cont to
mill to 7,304' MD/3,539' TVD (46'), ADT 5.5 hrs, milled at 2-10K wob,
90-120 rpm's, 490 gpm at 2,350 psi, off btm torque 13K ft-Ibs, on btm
8-20K ft-Ibs, rot wt 118K, up wt 185K, dn wt 85K, (20' of gauge hole
below window for Geo-Pilot) last 2' took 15K wob to drill due to possible
concretion
21 :30 - 23:00 IRC PROD3 Pumped 30 bbl weighted hi vis sweep and circ hole clean while working
mills thru window, circ at 500 gpm at 2,400 psi, worked mills thru
window without pumping and window looks good.
23:00 - 23:15 0.25 WINDO PROD3 Monitored well-static, pumped dry job
23:15 - 00:00 0.75 WINDO PROD3 POOH with whipstock milling assembly from 7,304' to 6,886'
6/9/2005 00:00 - 03:00 3.00 WINDO PROD3 POOH with whipstock milling assembly from 6,886' to 380', stood back
HWDP
03:00 - 03:45 0.75 WINDO PROD3 POOH LD 9-6 3/4" Dc's from 380' to 104'
Printed: 6/21/2005 1 :33:38 PM
.
.
L'-
r~~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
Downloaded MWD and LD same, cont. to POOH and LD Mills, upper 8
1/2" mill in gauge, cleared rig floor, note inspected saver sub while
clearing rig floor and sub ck ok
Pulled wear bushing and flushed out BOP stack after milling window,
re-installed wear bushing
MU 8 1/2" BHA #16 and RIH to 105', MU bit #11 on Geo-pilot rotary
system with Stratasteer LWD/MWD/PWD, uploaded MWD and shallow
tested tool, held PJSM and loaded radioactive sources RIH to 105'
RIH with BHA #16 from 104' to 7,231', RIH with flex Dc's, HWDP, jars
and 5" DP, note ran 1 ghost reamer 1,042' back from bit and 2nd ghost
reamer 2,533' back from bit.
RIH from 7,231' to top of window at 7,258', washed down from 7,258' to
7,304', no problems going thru window, washed down at 500 gpm at
2,125 psi, rot wt 106K, up wt 150K, dn wt 80K
Directionally drilled 8 1/2" hole in "D" sand lateral with Geo pilot rotary
steerable system from 7,304' to 8,235' MD/3,514' TVD (931') ADT 6.88
hrs, from 7,304' to 7,808' drilled at 10-20K wob, 60-120 rpm's, 500 gpm,
off btm pressure 2,200 psi, on btm 2,300 psi, from 7,808' drilled at
1 0-20K wob, 130 rpm's, 165 spm, 585 gpm, 2,900 psi, off btm torque
13K ft-Ibs, on btm 11 K ft-Ibs, rot wt 101 K, up wt 165K, dn wt 65K, 9.0
ppg MOBM, ave ECD 10.7 ppg, ave BGG 130 units, max gas 265 units.
Drilled out of zone from 7,450' MD/3,563' TVD to 7,884' MD/3,549'
TVD (434')
12.00 DRILL DRLG PROD3 Directionally drilled 81/2" hole in "D" sand lateral with Geo pilot rotary
steerable system from 8,235' to 9,200' MD/3,486' TVD (965') ADT 7.75
hrs, 5-20K wob, 130 rpm's, 170 spm, 600 gpm, 3,100 psi, off btm
torque 14-15K ft-Ibs, on btm 13-14K ft-Ibs, rot wt 105K, up wt 185K, dn
wt 65K, 9.0 ppg MOBM, ave ECD 10.8 ppg, ave BGG 175 units, max
gas 669 units.
12.00 DRILL DRLG PROD3 Directionally drilled 81/2" hole in "D" sand lateral from 9,200' to 9,625
MD/3,490' TVD (425') ADT 6.41 hrs, while drilling concretions would
drill with 25-35K wob, 90 rpm's, 510 gpm at 2,300 psi, while drilling
sand would drill at 5-15K wob, 130 rpm's, 175 spm, 620 gpm at 3,175
psi, off btm torque 15-17K ft-Ibs, on btm 13-14K ft-Ibs, rot wt 105K, up
wt 173K, dn wt 65K, 9.0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 120
units, max gas 487 units.
3.00 DRILL DRLG PROD3 Directionally drilled 8 1/2" hole in "D" sand lateral from 9,625' to 9,736
MDI 3487' TVD (111 ') ADT 2.36 hrs, while drilling concretions would
drill with 20-35K wob, 80-90 rpm's, 510 gpm at 2,300 psi, while drilling
sand would drill at 1 0-15K wob, 130 rpm's, 175 spm, 620 gpm at 3,175
psi, off btm torque 14-17K ft-Ibs, on btm 14K ftIlbs, rot wt 105K, up wt
175K, dn wt 65K, 9.0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 120
units, max gas 345 units. After drlg thru concretion attempted to build
angle by adjusting rpm's and pump rates and was unable to get
acceptable build rate, no oil light came on the Geo-Pilot tool at 00:35
hrs
Monitored well-static, backreamed out of hole from 9,736' to 8,674' MD.
90 rpm's 90, 600 gpm at 3,000 psi and 14k ft-Ibs torque
POOH on elevators from 8,674' to 7,518', had small tight spot @ 7615,
pulled 20K over pull and wipe clean, hole taking proper fill, pulled
25-30K over at 7,518' and swabbed and packed off slightly
Pumped out of hole from 7,518' to 7,231' and clean up balled stab's at
window, pumped out at 318 gpm at 1,100 psi. Assembly clean and
05:30 - 06:30 PROD3
06:30 - 10:15 3.75 DRILL PULD PROD3
10:15-13:45 3.50 DRILL TRIP PROD3
13:45 - 14:15 0.50 DRILL REAM PROD3
14:15 - 00:00 9.75 DRILL DRLG PROD3
C
6/10/2005
00:00 - 12:00
12:00 - 00:00
6/11/2005
00:00 - 03:00
03:00 - 05:30 2.50 DRILL TRIP PROD3
05:30 - 07:15 1.75 DRILL TRIP PROD3
07:15 - 08:30 1.25 DRILL TRIP PROD3
Printed: 6/21/2005 1:33:38 PM
.
.
~~
\
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1 E-1 05
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
6/11/2005 07:15 - 08:30 1.25 DRILL TRIP PROD3 pulling good, hole taking proper fill.
08:30 - 08:45 0.25 DRILL OBSV PROD3 Monitored well above window and well was static, pumped dry job and
blow down Top drive.
08:45 - 12:30 3.75 DRILL TRIP PROD3 POOH from 7,231' to 381'
12:30 - 15:15 2.75 DRILL PULD PROD3 Stood back HWDP, jars and flex Dc's, held PJSM and removed
radioactive sources, downloaded MWD and LD BHA #16 and cleared
rig floor, found seals to have gone out of Geo-Pilot tool. Calc hole fill
63.5 bbls, Actual fill 72.25 bbls
15:15 - 15:30 0.25 DRILL PULD PROD3 Pulled Wear bushing
15:30 - 21 :30 6.00 WELCT BOPE PROD3 RU and tested valves, rams and manifold to 250 psi high, 3,500 psi low,
tested annular to 250 psi low and 2,800 psi high, tested LEL & H2S
alarms along with high flow and trip tank alarms, Note: Chuck Scheve
with AOGCC waived witnessing of test
21 :30 - 21 :45 0.25 DRILL PULD PROD3 Installed wear bushing
21 :45 - 00:00 2.25 DRILL PULD PROD3 MU 8 1/2" BHA #17 and RIH to 123', MU bit #12 on Geo-pilot rotary
system with Stratasteer LWDIMWDIPWD, uploaded MWD and shallow
tested tool breaking in bearings on Geo-pilot
6/12/2005 00:00 - 00:15 0.25 DRILL PULD PROD3 Held PJSM and loaded radioactive sources
( 00: 15 - 03:45 3.50 DRILL TRIP PROD3 RIH with flex Dc's, HWDP and jars with BHA #17 from 123' to 7,039',
While RIH began to take 10-15K dn weight at 7,060', PU to 7,039'
03:45 - 05:00 1.25 RIGMNT RSRV PROD3 Slip and cut 71' of drlg line
05:00 - 05:15 0.25 DRILL REAM PROD3 Washed down from 7,039' to 7,138', washed down at 500 gpm, 2,200
psi, st up wt 165K, dn wt 80K
05: 15 - 07:00 1.75 DRILL TRIP PIROD3 RIH from 7,138' to 9,260', no problems going thru window, while RIH at
9,260' string dn wt was down to 50K
07:00 - 08:45 1.75 DRILL REAM PIROD3 Precautionary washed and reamed down from 9,260' to btm at 9,736',
initial circ rate 200 gpm at 700 psi and staged circ rate up to 500 gpm at
2,500 psi and 100 rpm's, no problems washing to btm
08:45 - 12:00 3.25 DRILL DRLG PROD3 Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable
from 9,736' to 10,082' MD/3,483' TVD (346') ADT 1.9 hrs, 12-15K wob,
120 rpm's, 130 spm, 460 gpm, 2,250 psi, off btm torque 13K ft-Ibs, on
btm 11-12K ft-Ibs, rot wt 103K, up wt 185K, dn wt 55K, 9.1 ppg MOBM,
ave ECD 11.0 ppg, ave BGG 100 units, max gas 285 units
12:00 - 00:00 12.00 DRILL DRLG PROD3 Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable
from 10,082' to 11,435' MD/3,470' TVD (1,353') ADT 7.93 hrs, varied
drilling perimeters in attempt to get Geo-pilot to steer due to soft sands
and concretions, 1 0-25K wob, 90 - 130 rpm's, 130 spm, 460 gpm at
2,350 psi to 170 spm, 600 gpm at 3,550 psi, off btm torque 14-16K
ft-Ibs, on btm 14-15K ft-Ibs, rot wt 104K, up wt 205K, dn wt 40K, 9.05
ppg MOBM, ave ECD 11.5 ppg, ave BGG 150 units, max gas 1008
units, NOTE: Re-positioned camp on 1 E pad for Doyon 15 to move onto
pad, camp off highline from 10:00 to 17:00 hrs
6/13/2005 00:00 - 02:45 2.75 DRILL DRLG PROD3 Drilled 8 1/2" hole in "D" sand Lateral from 11,435' to 11,672' MDI
3,480' TVD (237') ADT 2.33 hrs, crossed fault at 11,334' MD/3,465'
TVD, anticipated throw 30', actual 20', while attempting to built angle
with no succes drilled down into "C" shale, Drilled into "c" shale at
11,625' MDI 3,488' TVD and drilled out of "c" back into "D" at 11,753'
MD/3,477' TVD
02:45 - 04:00 1.25 DRILL REAM PROD3 Backreamed out of hole slow while geologist evaluated log, began
l backreaming out at 600 gpm and at 11,650', #1 mud pump had a valve
problem, cont to backream out to 11,358' at 355 gpm, 1,500 psi at 130
rpm's, circ a calc btms up, repaired valve on pump, found a piece of
camlock rubber in valve
Printed: 6/21/2005 1:33:38 PM
.
.
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-105
1E-105
ROT - DRILLING
n 1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
6/13/2005 04:00 - 04:45 0.75 DRILL REAM PROD3 Washed down from 11,385' to 11,672', washed down at 142 gpm at 500
psi due to little down wt and drag
04:45 - 12:00 7.25 DRILL DRLG PROD3 Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable
from 11,672' to 12,094' MD/3,435' TVD (422') ADT 4.27 hrs, varied
drilling perimeters in attempt to get Geo-pilot to build angle, while
drilling in "c" shale was able to get adequate build rate, drilled with
1 0-25K wob, 90 - 130 rpm's, 130 spm, 460 gpm at 2,500 psi to 170
spm, 600 gpm at 3,600 psi, off btm torque 16K ft-Ibs, on btm 15K ft-Ibs,
rot wt 104K, up wt 180K, dn wt 50K, 9.0 ppg MOBM, ave ECD 11.6
ppg, ave BGG 150 units, max gas 670 units,
12:00 - 00:00 12.00 DRILL DRLG IPROD3 Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable
from 12,094' to 12,688' MD/3,420' TVD (416') ADT 5.77 hrs, drilled
with 9-25K wob, 130 rpm's, 146 spm, 520 gpm at 2,800 psi to 170 spm,
600 gpm at 3,700 psi, off btm torque 16K ft-Ibs, on btm 15K ft-Ibs, rot wt
109K, up wt 195K, dn wt 35K, 9.0 ppg MOBM, ave ECD 11.4 ppg, ave
BGG 200 units, max gas 895 units, began PU 5" HWDP at 12,343'
6/14/2005 00:00 - 12:00 12.00 DRILL DRLG PROD3 Drilled 8 1/2" hole in "D" sand lateral with Geo-pilot rotary steerable
from 12,688' to 13,530' MD/3,396' TVD (842') (T.D.) ADT 6.79 hrs,
( drilled with 10-25K wob, 90-130 rpm's, 166 spm, 590 gpm at 3,850 psi,
,- off btm torque 18-20K ft-Ibs, on btm 20-22K ft-Ibs, rot wt 125K, up wt
230K, dn wt 35K, (Blk Wt) 9.0 ppg MOBM, ave ECD 11.4 ppg, ave
BGG 200 units, max gas 1,065 units, Cont to PU HWDP to TD well,
drilled thru numerous concretions, lost approx 73 bbls MOBM while drlg
12:00-12:15 0.25 DRILL OBSV PROD3 Monitored well-static
12:15 - 00:00 11.75 DRILL REAM PROD3 Backreamed out of hole from 13,530' to 7,775', BROOH at drlg rate at
130 rpm's, 586 gpm, ICP 3,900 psi, FCP 2,750 psi, rot wt 100K, up wt
180K, dn wt 78K, packed of while BROOH at 11,783', 11,575', 11,216',
10,690' and 7,858', lost approx 88 bbls of 9.0 ppg MOBM while BROOH
6/15/2005 00:00 - 00:30 0.50 DRILL REAM PROD3 Pumped 35 bbl weighted hi vis sweep and BROOH from 7,775' to
7,718', BROOH at 500 gpm, 2,400 psi and 100 rpm's, had 30%
increase in cuttings back from sweep rot wt 100K, up wt 180K, dn wt
78K
00:30 - 04:00 3.50 LOG DLOG PROD3 MADD pass for caliper log from 7,718' to 7,250', logged at 400 gpm,
1,400 psi and 50 rpm's, packed off at 7,560', 7,480' and 7,425' while
logging out, POOH thru window to 7,138' with no problems in window
04:00 - 06:00 2.00 DRILL CIRC PROD3 Circ hole clean above window at 7,138', circ at 620 gpm, 2,800 psi, 130
rpm's with 1 0-12K ft-Ibs torque, circ 4X btms up and clean at shakers,
had a large amount of shale back at btms up
06:00 - 07:00 1.00 RIGMNT RGRP PROD3 Repaired hyd. leak on filter housing on top drive
07:00 - 07:30 0.50 RIGMNT RSRV PROD3 Serviced top drive and drawworks
07:30 - 11 :30 4.00 DRILL TRIP PROD3 RIH from 7,138' to 13,530', no problems RIH and going thru window,
changed out 3 Lo-tads while RIH
11 :30 - 13:30 2.00 DRILL CIRC PROD3 Pumped 35 bbl weighted hi vis sweep and circ 2 1/2X btms up and was
clean at shakers, saw no increase in cuttings back from sweep, circ at
160 spm, 568 gpm, 3,925 psi, 100 rpms with 17-18K ft-Ibs torque
13:30 - 14:45 1.25 DRILL CIRC PIROD3 Displace hole over from 9.0 ppg MOBM to 9.1 ppg SFMOBM, initial circ
rate 568 gpm at 3,925 psi, final circ rate 547 gpm at 3,925 psi at 130
rpm's, rot wt 125K, up wt 225K, dn wt 55K
14:45 - 15:00 0.25 DRILL OBSV PROD3 Monitored well-static, obtained SPR's
15:00-19:15 4.25 DRILL TRIP PROD3 POOH on elevators from 13,530' to 7,230', no problems in open hole or
pulling thru window
19:15 - 19:30 0.25 DRILL OBSV PROD3 Monitored well at window, well-static, dropped 2" rabbit
19:30 - 22:15 2.75 DRILL TRIP PROD3 POOH from 7,230' to BHA at 385'
Printed: 6/21/2005 1:33:38 PM
.
.
f:~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1 E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
6/15/2005 22: 15 - 00:00 1.75 DRILL PULD PROD3 POOH LD 5 jts HWDP and jars, LD 2-NM Flex Dc's, held PJSM and
removed radioactive sources, plugged into MWD and began
downloading MWD, POOH to 139', calc fill on trip out 114 bbls, actual
fill 140 bbls
6/16/2005 00:00 - 02:15 2.25 DRILL PULD PROD3 Fin downloading MWD and LD remaining BHA #17, MWD and
Geo-pilot, cleared rig floor
02:15 - 02:45 0.50 CASE RURD CMPL T3 RU Doyon's liner running equipment and held PJSM with rig crew and
tong operator
02:45 - 07:15 4.50 CASE PULR CMPL T3 PU and RIH with 5 1/2",15.5#, L-80, BTCM Liner with torque rings per
well program to 6,068' (144 Jts total), ran 5 1/2" ROT silver bullet guide
shoe with no float, ran a total of 71 jts (3,034') of 51/2" 15.5#, L-80,
BTCM blank liner, ran 73 jts (3,075') of 51/2", 15.5# L-80 BTCM slotted
liner, ran 141 - 5 1/2" x7 5/8" x 8" aluminum solid body centralizers 1/jt
#2 thru #143, ran 16 constrictor packers placed on blank liner to cover
shale sections.
07:15 - 07:45 0.50 CASE PULR CMPL T3 PU 1 jt of 7" 26#, L-80 BTC liner then MU Baker 7" HR liner setting
sleeve, RIH to 6,178', liner up wt 95K, dn wt 65K
07:45 - 08:15 0.50 CASE RURD CMPL T3 RD Doyon's liner running equipment
C 08:15 - 13:15 5.00 CASE RUNL CMPL T3 RIH with 5 1/2" liner on 5" DP from 6,178' and tagged btm at 13,536'
DP measurement, no problems RIH, took liner weights & torque
readings at 6,640' and above window at 7,223'. At 6,640' liner wt up
103K, dn wt 68K, rot wt 82k, at 10 rpm's had 4K ft-Ibs torque and at 20
rpm's had 4,500 ft-Ibs torque. At 7,223' liner up wt 115K, dn wt 75K, rot
wt 89K, at 10 rpm's had 5K ft-Ibs torque and at 20 rpm's had 4-6K ft-Ibs
torque. Liner wt on btm, up wt 215K, dn wt 70K, with torque limiter set
at 14,500 ft-Ibs was unable to rotate liner, calc liner displacement 87
bbls, actual 64 bbls, Ran liner with 5 stds slick 5" DP, 60 stds 5" DP
with Lo-tads and 10 stds of HWDP
13:15 - 15:00 1.75 CASE RUNL CMPL T3 Dropped 1 1/2" ball and pumped down to seat, pumped down at 4 bpm
at 600 psi then slowed to 1 bpm, with ball on seat pressured up to
3,000 psi to release running tool, then pressured up to 3,900 psi and
blew ball seat, PU and st wt up was 175K, dn wt 105K, stood back 1 std
with setting tool at 7,268', top of HR setting tool landed at 7,370.87'
15:00 - 16:15 1.25 CASE CIRC CMPL T3 Circ btms up at 7,268', circ across whipstock face while circ btms up,
circ at 70 spm, 250 gpm at 500 psi, 9.15 ppg SFMOBM in and out
16:15 - 16:30 0.25 CASE OTHR CMPL T3 Monitored well-static
16:30 - 20:00 3.50 DRILL TRIP CMPL T3 POOH from 7,268' and LD Baker running tool, cleared rig floor, calc fill
on trip out 69 bbls, actual 75 bbls
20:00 - 21:15 1.25 RIGMNT RSRV CMPL T3 Slip and cut 79' of drlg line and serviced top drive
21:15 - 21:45 0.50 FISH PULD CMPL T3 Held PJSM and MU fishing BHA #18, MU Baker retrieving hook, 1 jt 5"
HWDP, float sub, bumper and oil jars RIH to 61'
21 :45 - 00:00 2.25 FISH TRIP CMPL T3 RIH with fishing BHA #18 from 61' to 4,466'
6/17/2005 00:00 - 00:45 0.75 FISH TRIP CMPL T3 RIH with whipstock retrieving BHA #18 from 4,496' to 7,237' st up wt
175K, dn wt 105K
00:45 - 01 :30 0.75 FISH FISH CMPL T3 Hooked whipstock at 7,263 on 3rd attempt. Worked whipstock pulling
1 OOK over with no movement, Pulled to 125k over st wt and hit jars,
after 2nd hit pulled 330K st wt and whipstock came free, PU and stood
back std, had 222K drag up wt, after standing back std string wt
dropped to 179K
01 :30 - 02:30 1.00 FISH CIRC CMPL T3 Circ btms up at 7,230', circ at 420 gpm, 1,375 psi, max gas 60 units at
btms up
02:30 - 07:30 5.00 FISH TRIP CMPL T3 POOH slow with whipstock from 7,263' to BHA at 60'
07:30 - 09:30 2.00 FISH PULD CMPL T3 POOH and LD bumper jars, oil jars, whipstock, 1-5', 5 jts 5" DP and
Printed: 6/21/2005 1:33:38 PM
.
.
~,
\
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1 E-1 05
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
6/17/2005 07:30 - 09:30 2.00 FISH PULD CMPL T3 seal assembly, cleared rig floor, calc fill on trip out 64 bbls, actual 77
bbls
09:30 - 10:00 0.50 CASE RURD CMPL T3 RU Doyon's liner running equipment
10:00 - 10:15 0.25 CASE SFTY CMPL T3 Held PJSM with rig crew and tong operator on running of PU and
running of hook hanger with ECP pkr
10:15 -11:30 1.25 CASE PULR CMPL T3 MU "D" lateral hook hanger assembly with ECP Pkr RIH to 162', MU 5
1/2" bent jt, 1-6' pup jt, 1-jt of 5 1/2" 15.5#, L-80 IBTM blank liner, ECP,
1-6' pup jt and hook hanger assembly
11:30-17:00 5.50 CASE RUNL CMPL T3 RIH with hook hanger assembly from 162' to top of window at 7,258', st
wt up 175K, dn wt 106K
17:00 - 18:45 1.75 CASE OTHR CMPL T3 Worked bent jt thru window after 4th attempt, RJH and tagged XO in HR
setting sleeve at 7,425', did not see ECP Pkr go thru window, st wt up
185K, dn wt 104K
18:45 - 20:00 1.25 CASE OTHR CMPL T3 Oriented hanger to btm of window, after 6 attempts hooked hanger. PU
and unhooked hanger, worked hanger by turning pipe 1/4 turn,
rehooked and unhooked hanger 6 times while turning hanger to verify
btm of window, btm of window @ 7,275.31. Top of Baker hook hanger
C @ 7,254.41' with 5 1/2" bent jt at 7,416', spaced out 9' above 7" x 5 1/2"
XO at 7, 425', Set 30K wt down on hook
20:00 - 21 :15 1.25 CASE CIRC CMPL T3 Dropped 29/32" ball and pumped down to seat, pumped at 4 bpm, 525
psi and slowed to 1 bpm at 200 psi, with ball on seat at calc strokes,
pressured up to 500 psi then bled off
21:15 - 22:30 1.25 CASE OTHR CMPL T3 Turned over to Dowell, pressure tested lines to 3,500 psi, then
pressured up on ECP Pkr to 2,200 psi, bled off, pressured back up to
2,500 psi and didn't see valve shear, cont to slowly increase pressure
up to 3,800 psi, bled off, pressured up to 4,300 psi and blew ball seat.
PU out of assembly to 7,144'. NOTE: Looking at Dowell chart it
appears valve may have opened at 1,555 psi and closed at 2,000 psi
taking 0.8 bbls to pressure up and set packer
22:30 - 23:15 0.75 CASE CIRC CMPL T3 Circ btms up at 7,144', circ at 295 gpm at 650 psi, no gas at btms up, st
wt up 170K, dn wt 102K
23:15 - 23:30 0.25 CASE OTHR CMPL T3 Monitored well-static
23:30 - 00:00 0.50 CASE RUNL CMPL T3 POOH with hook hanger running tool from 7,144' to 6,328'
6/18/2005 00:00 - 02:00 2.00 CASE RUNL CMPL T3 POOH with hook hanger assembly running tool from 6,328' to 70'
02:00 - 03:00 1.00 CASE OTHR CMPL T3 POOH LD running tool and cleared rig floor, calc fill on trip out 65 bbls,
actual fill 73 bbls
03:00 - 03:30 CMPL T3 RU Doyon's tubing handling equipment
03:30 - 03:45 CMPL T3 Held PJSM with rig crew on running of LEM
03:45 - 05:00 CMPL T3 MU "D" sand LEM assembly with ZXP packer and RIH to 312'
05:00 - 10:00 CMPL T3 RIH with LEM from 312' to 7,250: to above hook hanger, st wt up 173K,
dn wt 103K
10:00-10:15 CMPL T3 Oriented LEM and located hook hanger at 7,254' and landed same with
ZXP packer top at 7,191' and end of seals at 7,493', snapped in & out
of hanger 1 time to verify on depth and latching into hook hanger,
Rehook and pull test 10K over to verify possitive hook, Set down 30K
wt. on hook assembly.
10:15 -11:00 0.75 CMPL TN CIRC CMPL T3 Dropped 1 3/4" phenolic ball and pumped down to seat, pumped down
at 4 bpm at 350 psi, pressured up to 2,500 psi to set packer, then
pressured up to 3,900 psi to release from setting tool, no problems
("- setting packer
11:00 -11:15 0.25 CMPL TN DEQT CMPL T3 Tested ZXP packer and annulus to 1,000 psi for 5 min, good test
11:15-12:15 1.00 CMPL TN CIRC CMPL T3 PU out of ZXP packer and set back down with dog sub to verify packer
setting depth and circ btms up, circ at 285 gpm at 675 psi
Printed: 6/21/2005 1:33:38 PM
.
.
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-1 05
1E-105
ROT - DRILLING
n1334@ppco.com
Doyon 141
12:15 - 12:30
12:30 - 15:00
15:00 - 15:45
15:45 - 16:00
16:00 - 16:30
16:30 - 22:00
22:00 - 23:00
23:00 - 00:00 1.00 CMPL TN RURD CMPL T3
6/19/2005 00:00 - 02:30 2.50 WE LeT NUND CMPL T3
02:30 - 06:30 4.00 DRILL CMPL T3
06:30 - 08:30 2.00 WELCT CMPL T3
( 08:30 - 09:30 1 .00 WELCT CMPL T3
'-
09:30 - 16:45 7.25 DRILL PULD CMPL T3
16:45 - 18:00 1.25 WELCT EQRP CMPL T3
18:00 - 22:15 4.25 DRILL PULD CMPL T3
22:15 - 00:00 1.75 DRILL OTHR CMPL T3
6/20/2005 00:00 - 01 :30 1.50 DRILL OTHR CMPL T3
Start: 4/25/2005
Rig Release: 6/20/2005
Rig Number:
Spud Date: 4/29/2005
End: 6/20/2005
Group:
Monitored well-static
POOH with LEM running tool from 7,191' to 45'
POOH LD LEM running tool
Pulled wear bushing
RU Doyon's tbg handling equipment and held PJSM
Ran 4 1/2" 12.6#, L-80 IBTM tbg with completion assembly to 7,217',
RIH and tagged no-go at 7,217' tbg measurement, ran a total of 230 jts,
7,106' of 4 1/2" tbg
Spaced out completion string, MU Vetco Gray tbg hanger and landed
tbg at 7,229', RILDS, landed tbg with open CMU sliding sleeve at
7,164', btm GLM at 6,713', upper GLM at 4,217' and DB-6 nipple at
504', st wt up 95K, down wt 57K, tested hanger seals to 5,000 psi for 15
min, good test, installed TWC
RD Doyon's tbg handling equipment and landing jt, cleared rig floor
ND BOP's, began to set back when one of the bridge crane's wouldn't
work
LD 144 jts of 5" DP from derrick while repairing bridge crane
Set back BOP's and NU Vetco Gray 13 5/8" x 4 1/8" 5M Tree
Tested tree to 500 psi low then to 5,000 psi high for 15 min, good test,
pulled TWC
Cont to LD DP from the derrick, LD 132 jts of 5" DP, 39 jts of 5" HWDP
and 44 Lo-Tads, Sim-Ops: held PJSM and RU little Red, displaced hole
over from 9.1 ppg SFMOBM to diesel thru choke manifold and open
CMU sliding sleeve at 7,164', RU scaffolding over well
RU lubricator and installed BPV, RD lubricator and secured well, RD I
scaffolding and began cleaning out SFMOBM in pits, SITP 400 psi, IA
400 psi, OA 160 psi
Fin LD DP from the derrick, LD 123 jts of 5" DP and 16 Lo-Tads, LD a
total of 408 jts of 5" DP, 39 jts HWDP and 60 Lo-Tads, RD mouse hole
Cont to clean mud pits, Sim-Op: Slip and cut 52' of drlg line, rig off
highline at 22:15 hrs
Fin. cleaning mud pits and rock washer, Sim-Ops: changed out 4 1/2"
IF saver sub on top drive. RELEASED RIG @ 01 :30 Hrs 6/20105
Printed: 6/21/2005 1:33:38 PM
.
Halliburton Sperry-Sun
Western North Slope
ConocoPhillips
Kuparuk 1 E
1E-105L2
Surveyed: 14 June, 2005
Job Ho. AK-ZZ-0003677560,
Survey Report
30 June, 2005
.
< Your Ref: API 500292324361
Suñace Coordinates: 5959980.60 H, 550300.48 E (700 18' 05.1619'" H, 149035' 33.3322'"
Grid Coordinate System: HAD27 Alaska State Planes, Zone 4
Survey Ref: svy2178
W)
Suñace Coordinates relative to Project H Reference: 959980.60 H, 50300.48 E (Grid)
Suñace Coordinates relative to Structure: 217.60 H, 412.44 E (True)
Kelly Bushing Elevation: 93.58ft above Mean Sea Level
Kelly Bushing Elevation: 93.58ft above Project V Reference
Kelly Bushing Elevation: 93. 58ft above Structure
&p&!...........y-EUI'1
DRILLING Sit & Fe V' c: & Sit
A HaUibulton ComPflny
Halliburton Sperry-Sun
Survey Report for Kuparuk 1E - 1E-105L2
Your Ref: API 500292324361
Job No. AK-ZZ-0003677560, Surveyed: 14 June, 2005
ConocoPhillips
Western North Slope
Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft)
7175.65 76.140 173.860 3414.56 3508.14 672.56 S 5127.62 E 5959342.39 N 555432.48 E 672.56 Tie-On Point
7258.00 76.030 173.840 3434.36 3527.94 752.03 S 5136.18 E 5959262.97 N 555441.58 E 0.136 752.03 Window Point
7295.05 78.520 174.420 3442.53 3536.11 787.98 S 5139.87 E 5959227.05 N 555445.51 E 6.892 787.98
7385.57 79.820 175.830 3459.53 3553.11 876.56 S 5147.43 E 5959138.52 N 555453.66 E 2.098 876.56
7489.02 83.690 177.450 3474.37 3567.95 978.74 S 5153.42 E 5959036.38 N 555460.34 E 4.049 978.74 .
7582.96 89.400 178.910 3480.03 3573.61 1072.42 S 5156.39 E 5958942.72 N 555463.94 E 6.273 1072.42
7678.70 94.910 180.400 3476.43 3570.01 1168.05 S 5156.97 E 5958847.10 N 555465.15 E 5.961 1168.05
7778.43 95.380 181.960 3467.48 3561.06 1267.36 S 5154.93 E 5958747.78 N 555463.77 E 1.628 1267.36
7875.89 97.310 183.480 3456.71 3550.29 1364.10S 5150.33 E 5958651.01 N 555459.83 E 2.515 1364.10
7970.21 96.600 184.950 3445.29 3538.87 1457.47 S 5143.45 E 5958557.59 N 555453.57 E 1.720 1457.47
8068.26 95.380 186.480 3435.06 3528.64 1554.50 S 5133.74 E 5958460.50 N 555444.51 E 1.989 1554.50
8164.27 94.820 185.930 3426.52 3520.10 1649.57 S 5123.40 E 5958365.37 N 555434.81 E 0.816 1649.57
8256.96 92.270 182.320 3420.79 3514.37 1741.82 S 5116.75 E 5958273.08 N 555428.78 E 4.762 1741.82
8311.52 91.1 00 179.780 3419.19 3512.77 1796.34 S 5115.75 E 5958218.55 N 555428.15 E 5.124 1796.34
8354.63 90.480 179.210 3418.59 3512.17 1839.44 S 5116.13 E 5958175.45 N 555428.81 E 1.954 1839.44
8404.71 90.740 177.450 3418.06 3511.64 1889.50 S 5117.59 E 5958125.41 N 555430.61 E 3.552 1889.50
8452.88 91.600 178.170 3417.08 3510.66 1937.62 S 5119.43E 5958077.29 N 555432.77 E 2.328 1937.62
8504.80 91.350 179.040 3415.74 3509.32 1989.51 S 5120.70 E 5958025.42 N 555434.38 E 1.743 1989.51
8548.77 92.350 178.750 3414.32 3507.90 2033.45 S 5121.54 E 5957981.49 N 555435.52 E 2.368 2033.45
8644.60 91.900 180.340 3410.77 3504.35 2129.20 S 5122.31 E 5957885.74 N 555436.92 E 1.723 2129.20
8739.76 92.030 179.530 3407.50 3501.08 2224.31 S 5122.41 E 5957790.63 N 555437.67 E 0.862 2224.31 .
8837.13 92.150 179.000 3403.95 3497.53 2321.60 S 5123.66 E 5957693.35 N 555439.57 E 0.558 2321.60
8931.62 90.860 177.600 3401.47 3495.05 2416.02 S 5126.46 E 5957598.96 N 555443.00 E 2.014 2416.02
9030.84 91.610 178.200 3399.33 3492.91 2515.14S 5130.10 E 5957499.86 N 555447.30 E 0.968 2515.14
9127.81 92.530 179.620 3395.83 3489.41 2612.03 S 5131.94E 5957402.98 N 555449.79 E 1.744 2612.03
9223.54 90.480 177.510 3393.31 3486.89 2707.69 S 5134.34 E 5957307.35 N 555452.83 E 3.072 2707.69
9321.59 90.680 178.370 3392.32 3485.90 2805.67 S 5137.86 E 5957209.39 N 555457.01 E 0.900 2805.67
9416.70 91.070 178.240 3390.87 3484.45 2900.72 S 5140.68 E 5957114.35 N 555460.46 E 0.432 2900.72
9513.48 88.290 179.360 3391.41 3484.99 2997.47 S 5142.70 E 5957017.62 N 555463.13 E 3.097 2997.47
9609.90 88.460 178.800 3394.14 3487.72 3093.84 S 5144.25 E 5956921.27 N 555465.33 E 0.607 3093.84
9705.79 91.620 178.690 3394.08 3487.66 3189.69 S 5146.35 E 5956825.43 N 555468.07 E 3.297 3189.69
9803.35 89.880 180.890 3392.80 3486.38 3287.23 S 5146.71 E 5956727.89 N 555469.08 E 2.875 3287.23
9898.78 90.690 182.630 3392.33 3485.91 3382.61 S 5143.78 E 5956632.50 N 555466.79 E 2.011 3382.61
9993.63 91.800 181.200 3390.26 3483.84 3477.38 S 5140.61 E 5956537.71 N 555464.25 E 1.908 3477.38
10090.61 92.970 181.360 3386.23 3479.81 3574.25 S 5138.44 E 5956440.82 N 555462.74 E 1.218 3574.25
30 June, 2005 - 14:46
Page 2 of4
DrillQuest 3.03.06.008
Halliburton Sperry-Sun
Survey Report for Kuparuk 1E -1E-105L2
Your Ref: API 500292324361
Job No. AK-ZZ-0003677560, Surveyed: 14 June, 2005
ConocoPhillips
Western North Slope
Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft)
10188.10 92.280 182.360 3381.76 3475.34 3671.59 8 5135.28 E 5956343.47 N 555460.23 E 1.245 3671.59
10284.57 92.410 181.710 3377.82 3471.40 3767.928 5131.86 E 5956247.12 N 555457.45 E 0.687 3767.92
10383.60 90.430 181.550 3375.36 3468.94 3866.87 8 5129.04 E 5956148.15 N 555455.30 E 2.006 3866.87
10481.53 89.760 183.380 3375.20 3468.78 3964.71 8 5124.83 E 5956050.29 N 555451.74 E 1.990 3964.71
10576.53 90.070 184.000 3375.34 3468.92 4059.51 8 5118.72E 5955955.45 N 555446.26 E 0.730 4059.51 .
10673.57 89.950 182.900 3375.32 3468.90 4156.378 5112.88 E 5955858.55 N 555441.07 E 1.140 4156.37
10769.94 90.940 182.600 3374.58 3468.16 4252.63 8 5108.26 E 5955762.27 N 555437.09 E 1.073 4252.63
10867.36 92.670 183.750 3371.51 3465.09 4349.84 8 5102.86 E 5955665.02 N 555432.35 E 2.132 4349.84
10964.83 90.990 182.870 3368.40 3461.98 4447.10 S 5097.24 E 5955567.73 N 555427.38 E 1.946 4447.10
11060.01 89.750 181.290 3367.78 3461.36 4542.21 8 5093.78 E 5955472.59 N 555424.56 E 2.110 4542.21
11158.17 89.630 179.380 3368.31 3461.89 4640.36 8 5093.21 E 5955374.44 N 555424.64 E 1.950 4640.36
11250.26 89.260 176.440 3369.20 3462.78 4732.37 8 5096.57 E 5955282.45 N 555428.62 E 3.218 4732.37
11351.58 87.460 177.240 3372.10 3465.68 4833.49 8 5102.15 E 5955181.37 N 555434.87 E 1.944 4833.49
11446.25 86.600 174.670 3377.01 3470.59 4927.798 5108.82 E 5955087.12 N 555442.17 E 2.859 4927.79
11543.03 86.560 174.070 3382.78 3476.36 5023.93 S 5118.30 E 5954991.04 N 555452.29 E 0.620 5023.93
11640.34 89.030 176.980 3386.53 3480.11 5120.868 5125.88 E 5954894.17 N 555460.53 E 3.921 5120.86
11735.63 93.730 177.330 3384.23 3477.81 5215.978 5130.61 E 5954799.09 N 555465.89 E 4.946 5215.97
11832.76 97.940 177.230 3374.36 3467.94 5312.478 5135.19 E 5954702.63 N 555471.12 E 4.336 5312.47
11930.87 98.630 176.990 3360.22 3453.80 5409.438 5140.09 E 5954605.70 N 555476.66 E 0.744 5409.43
12024.97 96.720 177.220 3347.66 3441.24 5502.57 8 5144.80 E 5954512.60 N 555482.00 E 2.044 5502.57
12122.78 92.580 177.260 3339.73 3433.31 5599.92 8 5149.49 E 5954415.28 N 555487.34 E 4.233 5599.92 .
12220.25 90.240 178.550 3337.33 3430.91 5697.29 8 5153.05 E 5954317.94 N 555491.55 E 2.741 5697.29
12310.35 89.450 180.650 3337.57 3431.15 5787.388 5153.68 E 5954227.85 N 555492.79 E 2.490 5787.38
12403.34 91.750 182.740 3336.60 3430.18 5880.31 8 5150.93 E 5954134.90 N 555490.66 E 3.342 5880.31
12494.43 92.300 184.020 3333.38 3426.96 5971.188 5145.56 E 5954044.00 N 555485.90 E 1.529 5971.18
12586.23 91.920 183.110 3330.00 3423.58 6062.748 5139.86 E 5953952.40 N 555480.81 E 1.074 6062.74
12677.93 92.170 183.750 3326.73 3420.31 6154.228 5134.38 E 5953860.89 N 555475.94 E 0.749 6154.22
12767.69 93.230 184.540 3322.50 3416.08 6243.64 8 5127.90 E 5953771.42 N 555470.06 E 1.472 6243.64
12861.43 91.480 180.730 3318.65 3412.23 6337.188 5123.59 E 5953677.86 N 555466.38 E 4.469 6337.18
12952.82 91.610 179.700 3316.18 3409.76 6428.54 8 5123.25 E 5953586.50 N 555466.65 E 1.136 6428.54
13042.98 90.550 181.940 3314.48 3408.06 6518.678 5121.96 E 5953496.37 N 555465.96 E 2.748 6518.67
13135.96 92.360 184.950 3312.12 3405.70 6611.43 8 5116.38E 5953403.56 N 555461.00 E 3.776 6611.43
13227.17 91.050 185.640 3309.41 3402.99 6702.21 8 5107.96 E 5953312.73 N 555453.20 E 1.623 6702.21
13319.35 92.040 186.200 3306.92 3400.50 6793.87 8 5098.46 E 5953221.02 N 555444.31 E 1.234 6793.87
13414.72 91.230 185.080 3304.20 3397.78 6888.738 5089.09 E 5953126.09 N 555435.57 E 1.449 6888.73
30 June, 2005 - 14:46
Page 30f4
DrillQuest 3.03.06.008
Halliburton Sperry-Sun
Survey Report for Kuparuk 1E -1E-105L2
Your Ref: API 500292324361
Job No. AK-ZZ-0003677560, Surveyed: 14 June, 2005
Western North Slope
Measured True Sub-Sea Vertical Local Coordinates Global Coordinates
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings
(ft) (ft) (ft) (ft) (ft) (ft) (ft)
13497.77 90.680 183.620 3302.82 3396.40 6971.53 S 5082.79 E 5953043.25 N 555429.83 E
v 13530.00 90.680 183.620 3302.44 ' 3396.02 .- 7003.69 S 5080.76 E 5953011.08 N 555428.01 E
All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well. Northings and Eastings are relative to Well.
Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4.
The Dogleg Severity is in Degrees per 100 feet (US Survey).
Vertical Section is from Well and calculated along an Azimuth of 180.000° (True).
Based upon Minimum Curvature type calculations, at a Measured Depth of 13530.00ft.,
The Bottom Hole Displacement is 8652.50ft., in the Direction of 144.041° (True).
Comments
Measured
Depth
(ft)
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
Comment
7175.65
7258.00
13530.00
3508.14
3527.94
3396.02
672.56 S
752.03 S
7003.69 S
Tie-On Point
Window Point
Projected Survey
5127.62 E
5136.18E
5080.76 E
Survev tool oroaram for 1E-105L2
From
Measured Vertical
Depth Depth
(ft) (ft)
To
Measured Vertical
Depth Depth Survey Tool Description
(ft) (ft)
0.00
722.00
719.95 CB-SS-Gyro (1E-105PB1)
3396.02 MWD+IIFR+MS+SAG (1E-105PB1)
0.00 722.00
719.95 13530.00
Dogleg
Rate
(O/100ft)
1.878
0.000
ConocoPhillips
Vertical
Section Comment
6971.53
7003.69 Projected Survey
.
.
30 June, 2005 - 14:46
Page 4 of4
DrillQuest 3.03.06.008
.
.
15-Jul-05
AOGCC
Helen Warman
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
DEFINITIVE
Re: Distribution of Survey Data for Well 1 E-1 05 L2
Dear Dear Sir/Madam:
Enclosed is one disk with the *.PTT and *.PDF files.
Tie-on Survey:
Window / Kickoff Survey:
Projected Survey:
7,175.65' MD
7,258.00' MD
13,530.00' MD
(if applicable)
PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO
CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND
RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE
ATTENTION OF:
Sperry-Sun Drilling Services
Attn: Carl Ulrich
6900 Arctic Blvd.
Anchorage, AK 99518
Date }(j JQ.") J.ß..U\'
Signed 2L-r..J D 4tJ
Please call me at 273-3545 if you have any questions or concerns.
Regards,
Carl Ulrich
Survey Manager
Attachment(s)
;) \.; )->- ü ~8
Fll
.
.
AOGCC
Helen Warman
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
Re: Distribution of Survey Data for Well 1 E-1 05 L2 MWD
Dear Dear Sir/Madam:
Enclosed is one disk with the *.PTT and *.PDF files.
Tie-on Survey:
Window / Kickoff Survey:
Projected Survey:
7,175.65' MD
7,258.00' MD
13,530.00' MD
(if applicable)
PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO
CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND
RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE
ATTENTION OF:
Sperry-Sun Drilling Services
Attn: Carl Ulrich
6900 Arctic Blvd.
Anchorage, AK 99518
Date J ~ A W) À,dc ç Signed
I
I
/~ , /';ßL
... ¡ 1~"1!/Y, I( lit. ../.
Please call me at 273-3545 if you have any questions or concerns.
Regards,
Carl Ulrich
Survey Manager
AUachment(s)
15-Jul-05
;z (Ù~'- {J Ü ~ f=, it.
...
. .
~~~~Πffi)~ ~~~~[K\~
.
AItASHA. OIL AND GAS
CONSERVATION COMMISSION
FRANK H. MURKOWSKI, GOVERNOR
333 W. 7'" AVENUE. SUITE 100
ANCHORAGE. ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Randy Thomas
Kuparuk Drilling Team Leader
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, Alaska 99510-0360
Re: Kuparuk lE-105L2
ConocoPhillips Alaska, Inc.
Pennit No: 205-008
Surface Location: 391' FSL, 224' FEL, SEC. 16, TUN, RI0E, UM
Bottomhole Location: 1338' FNL, 345' FEL, SEC. 27, TIIN, RlOE, UM
Dear Mr. Thomas:
Enclosed is the approved application for pennit to drill the above referenced development well.
The pennit is for a new wellbore segment of existing well KRU lE-105, Pennit No. 205-006,
API 50-029-23243-00. Production should continue to be reported as a function of the original
API number stated above.
In your application it was stated that the original wellbore and the subsequent multi-lateral
wellbores would be pre-produced and then converted to injection service after a minimum of 30
days production. Regulation 20 AAC 25.402(c)(15) requires determination of the mechanical
condition of any well penetrating the injection zone within a one-quarter mile radius of a
proposed injection well. In the case of lE-105, there are a number of West Sak: wells and at least
one Kuparuk well within one-quarter mile of the proposed trajectory.
As currently planned, lE-105 and the subsequent multi-lateral wellbores are designed to meet the
requirements for injection wells as specified in 20 AAC 25.412. However, prior to converting
lE-l 05 and the multi-laterals to injection service CPAI must provide infonnation sufficient for
the Commission to detennine that all of the surrounding wells were satisfactorily cemented to
confine any fluids within the West Sak: sands.
This pennit to drill does not exempt you from obtaining additional pennits or approvals required
by law from other governmental agencies, and does not authorize conducting drilling operations
until all other required pennits and approvals have been issued. In addition, the Commission
reserves the right to withdraw the pennit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the
Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure
to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska
Administrative Code, or a Commission order, or the tenns and conditions of this pennit may
result in the revocation or suspension of the pennit. Please provide at least twenty-four (24)
""
.
.
.
hours notice for a representative of the Commission witness any required test. Contact the
Commission's petroleum field inspector at (907) 65 60 (pager).
BY ORDER QF THE COMMISSION
DATED thisI day of February, 2005
cc: Department ofFish & Game, Habitat Section w/o end
Department of Environmental Conservation w/o encI.
conoc~illips
Alaska
.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Randy Thomas
Phone (907) 265-6830
Email: Randy.L.Thomas@conocophillips.com
RECEIVED
JAN 11 2005
Alask/;! Oil & Ga:;
Am:homge
January ih, 2005
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
Re: Applications for Pennit to Drill, West Sak Injector, IE-I 05, IE-105 Ll, IE-105 L2
Dear Commissioners:
ConocoPhillips Alaska, Inc. hereby applies for Pennits to Drill for a pre-produced onshore injection well, a Tri-
lateral horizontal well in the West Sak "A2", "B" and "0" sands. The main bore of the well will be designated IE-
105, the "B" sand lateral will be designated IE-I 05 Ll, and the "0" sand lateral will be designated IE-I 05 L2.
Please find attached for the review of the Commission fonns 10-401 and the infonnation required by 20 ACC
25.005 for each of these well bores.
The expected spud date of IE-I 05 is February 5th, 2005.
If you have any questions or require any further infonnation, please contact Mike Greener at 263-4820.
Sincerely,
~\~
Randy Thomas
Greater Kuparuk Area Drilling Team Leader
Æ¡
t'r
.
.'
RECE
JAN 11 2005
.Mash Oil &
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
ExploratoryU Development Oil U Am:;hm1Øl!!lJPle Zone 0
Service 0 Development Gas 0 Single Zone 0
5, Bond: ~ Blanket U Single Well 11. Well Name and Number:
Bond No. 59-52-180 1E-105L2
6, Proposed Depth: 12. Field/Pool(s):
MD: 13634' / TVD: 3399' Kuparuk River Field
7. Property Designation: ,- 1/' $~
ALK 25651/25660 West Sak Pool Lc.k-.yA.(
1a. Type of Work: Drilll,:Q Redrill U
Re-entry 0
2. Operator Name:
ConocoPhillips Alaska, Inc.
3. Address:
1 b. Current Well Class:
Stratigraphic Test
o
P.O. Box 100360 Anchorage, AK 99510-0360
4a. Location of Well (Governmental Section):
SuITace:391'FSL,224'FEL,Sec. 16, T11N,R10E, UM
Top of Productive Horizon:
)!,p
"/~S
13. Approximate Spud Date:
2/5/2005
8. Land Use Permit:
235' FNL, 386' FEL, Sec. 22, T11 N, R10E, UM
Total Depth:
1338' FNL, 345' FEL, Sec. 27, T11 N, R10E, UM
4b. Location of Well (State Base Plane Coordinates):
ADL 469/470
14. Distance to
Nearest Property: 10174
9. Acres in Property:
,/
/
2560
15. Distance to Nearest _"'..,..,' ,p.
t.'Vü ' (l.'t"
Well within PQ.ol: 1E-114,~' @ 5!!,ú
10. KB Elevation
550300 <'
5959981 '
SUITace: x-
Zone-
4 (Height above GL): 28 feet
17. Anticipated Pressure (see 20 MC 25.035)
Max. Downhole Pressure: 1575 psig I Max. SUITace Pressure: 1190 psig
Setting Depth Quantity of Cement
Bottom c. f. or sacks
TVD MD TVD (including stage data)
28' 108' 1 08' 225 sx AS I
28' 4537' 2474' 870 sx AS Lite, 210 sx DeepCrete
28' 8180'.; 3675' 630 sx DeepCrete
~ ~ ~ slotted liner
1'-\<\c.. \~~"" "S~C\<; "ŸL -. I 'I:r,
(To be completed for Redrill and Re-Entry Operations)
Effective Depth MD (ff): Effective Depth TVD (ff): Junk (measured)
y-
16. Deviated wells:
Kickoff depth: 7242
18. Casing Program
Size
Maximum Hole Angle:
ft.
96°
Top
Specifications
Grade Coupling
H-40 Welded
L-80 BTC
L-80 BTCM
L-80 DWC
Length MD
80' 28'
4537' 28'
8180' 28'
5473' ~
lØŠ<\ ~ ""é)&.t\
PRESENT WELL CONDITION SUMMARY
Total Depth TVD (ff): Plugs (measured)
Casing
20"
Hole
30"
16"
Weight
62.5#
68#
40#
15.5#
13.325"
9-5/8 "
12.25"
8.5"
5.5"
19
Total Depth MD (ft):
Casing
Structural
Conductor
SUITace
Intermediate
Production
Liner
PeIToration Depth MD (ft):
Length
Cement Volume
Size
TVD
MD
PeIToration Depth TVD (ft):
I }
'-~..- BOP Sketch ~
o Ö· Diverter Sketch 0
Drilling Program 8.J
Seabed Report 0
Time v. Depth Plot [J
Drilling Fluid Program 0
Date:
Shallow Hazard Analysis U
20 MC 25.050 requirements 0
20. Attachments: Filing Fee
Property Plat
21. Verbal Approval: Commission Representative:
22. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Printed Name
Contact Mike Greener @ 263-4820
Title Kuparuk Drilling Team Leader
Phone 'l.G )'13 ~ ò Date l r, (0 r
p
Randy Thomas
...-~
. \ -
~l
\
Signature
~
~
-==0..
hamn AI/.~uD-Drake
Commission Use Only
Permit to Drill API Number: Permit Approval
Number: 2.D5-008 50- 6'2..'1- Z32..'-I3-tol Date: dhÞ~
Conditions of approvah2: S I\'les required 0 Yes I}(I No Mud log required
ydrþgen sulfide measures ~ Yes [j No Directional survey required
Othec ~ ~ / ~"""'\" ~ "" / þ. 'ID;)!":>. ..,,()(::(:)~ ~~ -I"<5~ . ~~+d<-\,,\u-oc.\ ~I '-I,~ :
L ( ~ r ~,,/ A BY ORDER OF 'L/-?, / r
Approved tf I~.f/ \. _ COMMISSIONER THE COMMISSION Date, tr'l-r I ø
I I
See cover letter
for other requirements
DYes 131. No
~ Yes 0 No
~.
L/
--
n R·· I r I ~~!^
~ ,! ~ ~.., I ,; O,{ ,,-¡,
~~::'_.;,,/';' ~ lJ ti . ~) t; '"
Submit in duplicate
Form 10-401 Revised 3/2003·
·
.ation for Permit to Drill, We1l1E-105 L2
Revision No.O
Saved: 10-Jan-05
Permit It - West Sak Well #lE-IOS L2
Application for Permit to Drill Document
Mäximizl;
Well Vglue
Table of Contents
1. Well Name........ ................... .......... ...... ... ............ ...... ............. .... ..... ...... ......... ...... ............ ... ...... 2
Requirements of 20 AAC 25.005 (f)... ........... ............ ..... .......... .... ..... .......... ....... ............ .... ........... ............ ..............2
2. Location Summary . ..... ..... ..... ... ............ ............. ........ ........ ...... ........ ........ ..................... ..... ....... 2
Requirements of 20 AA C 25. 005( c)(2).. .... ........ ................. .......... ...................... .................. ..... ......... ....... ..... ..... ....2
Requirements of 20 AA C 25. 050(b) ...... .......... .......... ... ......... .......... ..... .............. ................... .... ........; .... ...... ..... .... ..2
3. Blowout Prevention Equipment Information .......................................................................3
Requirements of 20 AA C 25. 005( c)( 3).. ..... ..... ...... .... ..... ................................ ............... ........ ............. ....... ..... ..... ....3
4. Drilling Hazards Information.... ..... ........ ..... ..... ... ............... ......... ....... ............ ... ..... .... ..... ...... 3
Requirements of 20 AAC 25.005 (c)( 4 )...................................................................................................................3
5. Procedure for Conducting Formation Integrity Tests......................................................... 3
Requirements of 20 AAC 25.005 (c)( 5)...... .................. ......... ............. .......... .... ............. .......... ....... .... ............ ..... ....3
6. Casing and Cementing Program............................................................................................ 3
Requirements of 20 AA C 25. 005( c)( 6) .............. ...... ......... ........ ....... ............... ...... .... .......... ................ ............ .........3
7. Diverter System Information .................................................................................................4
Requirements of 20 AAC 25. 005( c )(7).. ............ ........ .............................. .... ..... ........ .... ........ ......... ..... ......... ..... .......4
8. Drilling Fluid Program ....... ... .............. ...... ..... .......... ... ................... ............. ...... ..... .... ... ......... 4
Requirements of 20 AA C 25. 005( c)( 8).. ..... ..... ............ ..... ..... ....... ..... ..... ..... ..... .......... .......... .................... ............ ...4
Lateral Mud Program (MI VersaPro Mineral Oil Base)........................................................................................4
9. Abnormally Pressured Formation Information ................................................................... 5
Requirements of 20 AA C 25.005 (c)(9)...... ..... ........ ....... ....... ......... ...... ....... ....... ...... ...... ...... .... ..... ....... .... ...............5
10. Seismic Analysis........... ........... ............ ........ ..... ..... ........... ....... ............... ...... ......... ... .... .......... ... 5
Requirements of 20 AAC 25.005 (c)( 1 0 ).................................................................................................................5
11. Seabed Condition Analysis. ..... ....... ....... ......... .................. ............................ ..... ........... ..... ..... 5
Requirements of20 AAC 25.005 (c)( 11 ).................................................................................................................5
12. Evidence of Bonding ... ... ..... ..... ... ..... ...... ...... ........ ..... ........ .................. ..... ................. ........... ... 5
Requirements of20 AAC 25.005 (c)( I 2 ).................................................................................................................5
1E-105 L2 PERMIT IT. doc
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OR 1 GH'~J-\ L
·
.ation for Permit to Drill, Well 1 E-1 05 L2
Revision No.O
Saved: 10-Jan-05
13. Proposed Drilling Program . ....... ... ..... ......... .... ....... ....... ............ ....... ......... ... .................... ...... 5
Requirements of20 MC 25.005 (c)( 1 3 ).................................................................................................................5
14. Discussion of Mud and Cuttings Disposal and Annular Disposal...................................... 6
Requirements of20 MC 25.005 (c)( 1 4 ).................................................................................................................6
15. A ttachmen 18 ............. .... .......... ... .......... ............... .............. ....... ... ... .... ........... ...... ......... ... ..... ..... 6
Attachment 1 Doyon 141 West Sak 2004 3 ksi BOP Configuration (1 page) ........................................................6
Attachment 2 Directional Plan (6 pages) ..............................................................................................................6
Attachment 3 Drilling Hazards Summary (1 page)................................................................................................6
Attachment 4 Well Schematic (1 page) ..................................................................................................................6
1. Well Name
Requirements of20 MC 25.005 (f)
Each well must be identified by a unique name designated ¡IY the operator and a unique API number assigned by ¡he cummission under 20 A.iíC
25.040(b). For a well with multiple we!1 branches. each branch IIIIISI similarly hc identified by a unique name and API number by adding a sujJ7x
{(I the name designated jÒr the well by the operator and to the number assigned 10 ¡he well by the cOInlilission.
The well for which this Application is submitted will be designated as lE-105 L2.
2. Location Summary
Requirements of20 MC 25.005(c)(2)
An application '/Ór a Permit to Drilf must be accompanied by each of the fi¡/!owing items, except jÒr an item already on file with the commission
and identified in the application:
(2) a p!at identilying the property and the property's owners and shuwing
(iI)the c{Jordinat"'~ of the proposed location (~fthe well at the sUl1t/ce. at the lop of eaell oI!iective formation, and at total depth, r<:{erenced to
governmentai section line,')',
(/J) the coordinates of the proposed location of the wefl at the swjìiCe, referenced to the state plane coordinate systemjÓr this stal(' as maintained
by the Nationa! Geodetic SUI1'ey in the Nationa! Oceanic and Atmospheric Administration;
(Cj tÍle proposed depth of the wÛ! at the top of each ohjectivefoTination and at total depth:
Location at Surface I
ASP Zone 4 NAD 27 Coordinates
Northings: 5,959,981 Eastings: 550,300
4,889' FNL, 224' FEL, Section 16, TUN, RlOE
I RKB Elevation I 94.1' AMSL
I Pad Elevation I 66.1' AMSL
Location at Top of
Productive Interval (West 235' FNL, 386' FEL, Section 22, TUN, RlOE
Sak "D" Sand)
ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 7,241
Northings: 5,959,391 Eastings: 555,424 Total Vertical Depth, RKB: 3,499
Total Vertical Depth, SS: 3,405
Location at Total Depth I 1,338' FNL, 345' FEL, Section 27, TUN, RlOE
ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 13,634
Northings: 5,953,009 Eastings: 555,521 Total Vertical Depth, RKB: 3,399
Total Vertical Depth, SS: 3,305
and
(D) other inforrnation required by 20 ¡lAC 25.050(b);
Requirements of20 MC 25.050(b)
If a well is to be intentionally deviated. the application for a Permit to Drill (Form lO-401) must
(1.1 include a plat. drawn 10 a suitable scale. showing thf: path (!l the proposed Yo·eUbore, including all ar!jacent wellbores within 200feel of any
portion of the proposed we!l;
Please see Attachment I: Directional Plan
1E-105 L2 PERMIT IT.doc
Page 2 of 6
Printed: 10-Jan-05
¡r<. ¡ td A L
¡M ¡' ",
i,.J.t\! \
·
Aeation for Permit to Drill, Well 1 E-105 L2
Revision No.O
Saved: 10-Jan-05
and
(2 )/or all wells within 2(Xj feet of the proposed wellbore
(A) list the nailles {if'tlte operators (!f those wells, to tlte extent that those names are known or discoverable in public records, amlshow that
each named operator has been furnished a copy (If the application by certified mail; or
(B) Slate that the applicant is the only affected owner,
The Applícant is the only affected owner.
3. Blowout Prevention Equipment Information
Requirements of20 AAC 25.005(c)(3)
An application for II Permit to Drill must be accompanied by each {!t' the !(¡!luwing items, exceptfár all item already on file with the commission
and identified in the application;
(3i a diagram and description ('{the blowout prevention equipment (BOPE¡ as required by 20 AAC 25.035,20 AAC 25.036, or 20 AA.C 25.037,
as applicable:
An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete welllE-105. Please see
information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission.
4. Drilling Hazards Information
Requirements of 20 AA C 25.005 (c)( 4)
An application jÒr a Permit to Drill must be accompanied by each of the following items, aceptjÒr an item already onfile witlt the commission
and identified in the application;
({) Ù~f(¡rmation on drilling hazards, including
(Ai the maximum dm·vnlwle pressure that müy be encountered, criteria used to determine it, and nunimum potential surfäce pressure based on
a methane gradient:
The expected reservoir pressures in the West Sak sands in the 1E-105 L2 area vary from 0.42 to 0.45 psi/ft, or 8.0 to
8,6 ppg EMW (equivalent mud weight).
The maximum potential surface pressure (MPSP) is 1,190 psi. Based on the above maximum pressure gradient, a
methane gradient (0.11) and the deepest planned vertical depth of the West Sak A2 sand formation is 3,499'.
The MPSP is calculated thusly:
MPSP = (3,499 ft)(0.45 - 0.11 psi/ft)
=1,190 psi
(B) data on potential gas wnes:
The well bore is not expected to penetrate any gas zones.
lÍnd
(C) data concerning potentÙJl callses of hole problems slIch as abnorrruÛly geo-pressured strata. lost circulation zones, (Jnd zones that have a
propensity/ur differential sticking:
Please see Attachment 2: Drilling Hazards Summary.
5. Procedure for Conducting Formation Integrity Tests
Requirements of20 AAC 25.005 (c)(5)
An applicatlon/Ór a Permit to Drill must be accompanied by each uf the jÓllowing items, except for tm item alrea(¡'y 011 jïle with tfte commission
and identified ill the applicaÜon:
(5) a description of the procedure jilr conductingjimnation imegrity tests, as required under 20 AAC 25.030(/):
No formation integrity test will be performed in the drilling of lE-105 L2.
6. Casing and Cementing Program
Requirements of20 AAC 25.005(c)(6)
All application jìJr a Permit to Drilllllust be accompanied by each ol the /Óllowing i£e¡Il~. except/ill' an item already on.file with the commission
and identified in the application:
(6) (/ cOlnple!e proposed casing and cementing program_ as required by 20 AAC 25Jì30> and a de5cription- qf any slotted liner. pre-peljÓra!ed
liner, or screm to be installed:
1E-105 L2 PERMIT IT-doc
Page 3 of 6
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ORIGINAL
·
.ation for Permit to Drill, We1l1E-105 L2
Revision No.O
Saved: 10-Jan-05
Casing and Cementing Program I
See also Attachment 3: Cement Summary
Hole Top Etm
Csg/l'bg Size Weight Length MDIIVD MDIIVD
aD (in) (in) ( lbJft) Grade Connection (fr) (ft) (ft) Cement Proj?ram
20" 40" 62.5 H-40 Welded 80 28' /28' 80' / 80' Cemented to surface with 260 cf
ArcticCRETE
Cemented to Surface with
13-3/8" 16" 68 L-80 BTC 4,537 28' /28' 4,537' /2,474' 870 sx ArcticSet lite Lead,
210 sx DeepCRETE Tail
Cement Top planned @ 5,033'
9-5/8" 12-1/4" 40 L-80 BTCM 8,180 28' /28' 8,180' /3,675' MD 12,655' TVD. Cemented
wI
630 sx DeepCRETE
5-1/2 8-1/2" A2 Sand 15.5 L-80 BTCM 5,473 7,562' /3,560' 13,653' /3,625' Slotted- no cement
slotted Lateral (1E-105)
5-1/2 8-1/2" B Sand Lateral 15.5 L-80 BTCM 6,168 7,472' /3,552' 13,640' /3,453' Slotted- no cement
slotted (1E-105 Ll)
5-1/2 8-112" D Sand Lateral 15.5 L-80 BTCM 6,392 7,242' /3,499' 13,634' /3,399' Slotted- no cement
slotted (1E-105 L2)
7. Diverter System Information
Requirements of20 AAC 25.005(c)(7)
An application jÌJr a Permit to Dríllmi/st be accompanied by each of'thefallowing iteIiL~. except for an item already on!ile with ¡he commission
and identified in the application:
(7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under
20 AAC 25JJ35(h)(2i;
No diverter system will be used during operations on lE-105 L2.
8. Drilling Fluid Program
Requirements of 20 AA C 25. 005( c)( 8)
An applicationjÌJr a Permit to Drill mi/st be accompanied by each of'thefo!lowing iterns, except jur an item alreadv onlile with the commission
and ident(lf-ed in the application:
(8) a drilling .fluid program, including a diagram and description of'the drilling .fluid system, as required by 20 AAC 25.033;
Drilling will be done with muds having the following properties over the listed intervals:
Lateral Mud Program (MI VersaPro Mineral Oil Base)
Value
9.0
Densi ( )
Plastic Viscostiy
(lb/100 s J
Yield Point
(cP)
15-25
18- 28
HTHP Fluid loss
(ml/30 min @
200 si & 1500
Oil / Water Ratio
Electrical
Stabili
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see
information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141.
<4.0
80:20
>600
nRI·GIN'Al
U J. . .." ,
1E-105 L2 PERMIT IT-doc
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·
.ation for Permit to Drill, We1l1E-105 L2
Revision No.O
Saved: 10-Jan-05
9. Abnormally Pressured Formation Information
Requirements of20 AAC 25.005 (c)(9)
An applicationjÓr a Permit to Drill must be accompanied by each oithefollowing items. except for an item a/read'! onfile with the commission
and identified in the application:
(9) for an exploratOlY or stratigraphic test wel!, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by
20 AAC 25JI33if);
Not applicable: Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
Requirements of20AAC 25.005 (c)(10)
An application for a Permi¡ to Drill must be accorrqJtmied by each ofthefÒllowing hems. except for an item alreadY' onJUe with the commission
and identijied in the application:
(JOì/Ór an exploratory or stratigraphic test well. a seismic r(fraction or reflection analysis as required by 20 AAC 25.06l(a);
Not applicable: Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
Requirements of 20 AA C 25.005 (c)( 11 )
An application JìJr a Permit to Drill must be accompanied by each of the following items. except for an item already ontile with the commission
and identified in the application:
(11 )fÒr a wet! drilledJh}m an (dt:vhore platform, mobile buttom-jìmnded slmcture, jack-·up rig, or.floating drilling vessel, an analysis of seabed
conditions as !t'<jiÚred by 20AAC 25.061 (b);
Not applicable: Application is not for an offshore well.
12. Evidence of Bonding
Requirements of 20 AA C 25.005 (c)( 12)
lin application for a Permit to Drill must be dccompanied by each of the /Ó!lowing items, except/or an item already on JUe wit/¡ the commission
and iden/ijied in the applicalion:
(12) evidence sh(fwing that the requirements o.{20 AAC 25.025 (Bonding}have been met;
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
Requirements of 20 AA C 25.005 (c)( 13)
An application jÓr a Permit to Drill must be accompanied by each at the fallowing items. except for an item already on
and identified in the application:
The proposed drilling program is listed below. Please refer also to Attachment 4
/
Note: Previous operations are covered under the lE-105 Application Permit to Drill.
lOt of7,562' MD / 3,560' TVD, the top of the
1.
Run and set Baker WindowMaster whipstock system, at window
"D" sand.
2.
3.
4.
5.
6.
7.
~tQ'~ \I'J-'-t
Pick up 8-1/2" drilling assembly with LWD an WD and PWD. RIH.
Drill to TD of "D" sand lateral at 13,634' D / 3,399' TVD, as per directional plan.
Mill 8-1/2" window. POOH.
POOH, back reaming out of latera OOH.
RIH with whipstock retrieva 01. Retrieve whipstock and POOH.
8. Orient hanger to window and land hanger.
9. running tool. POOH.
10. Make up.' nction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set
packe top assembly and release from assembly. POOH.
H, laying down drill pipe as required.
1E-105 L2 PERMIT IT. doc
Page 5 of 6
Printed: 10-Jan-05
OR1GIN.AL
.
.
Application for Permit to Drill, Well 1 E-1 05
Revision No.O
Saved: 27-Jan-05
++'25. PU and run 5-1/2" slotted liner.
l'i-I
r-
hanger @ +/- 7,650' MD / 3,582'. POOH.
Note: Remaining operations are covered under the 1E-105 Ll and 1E-105 L2 Applicationfor Permit to Drill, and are
provided here for information only.
+9.27. Run and set Baker WindowMaster whipstock system, at window point of~ MD / ~O' TVD, the top of
the "B" sand.
~28. Mill 8-1/2" window. POOH. '\~'" '). ~55::>-
ft29. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD. RIH.
.,. ...".
22-,30. Drill to TD of"B" sand lateral at 13,640' MD / 3,453' TVD, as per directional plan.
;g,3 I . POOH, back reaming out of lateral. POOH.
;64.;32. RIH with whipstock retrieval tool. Retrieve whipstock and POOH.
~.º.J3,...]U and run 5-1/2" slotted liner.
;M.,34. RIH, until liner hanger is just above window. Orient hanger to window and land hanger.
n35. Release hanger running tool. POOH.
2-8,36. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and
set packer atop assembly and release from assembly. POOH. ~
~9.:;.,2z.,..........Run and set Baker WindowMaster whipstock system, at window point of~MD / ~O' TVD, the top of
the "D" sand. '3 '-\<1~
*38. Mill 8-1/2" window. POOH. "1;)'-\ \ T~ "\ ~ D~~ ,\.-\-
3-L39. Pick up 8-1/2" drilling assembly with L WD and MWD and PWD. RIH. \
Y"" .;'
~40. Drill to TD of"D" sand lateral at 13,634' MD / 3,399' TVD,as per directional plan. ~ OS ~Ü OC/'
;»41. POOH, back reaming out oflateral. POOH. 0
;;4.;42. RIH with whipstock retrieval tool. Retrieve whipstock and POOH.
3SA3. PU and run 5-1/2" slotted liner.
3644. RIH, until liner hanger is just above window. Orient hanger to window and land hanger.
3...z:.1.~-,-......_Release hanger running tool. POOH.
3&A6. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and
set packer atop assembly and release from assembly. POOH.
~9..d:.7.,_._POOH, laying down drill pipe as required.
4448. PU injection as required and RIH to depth. Land tubing. Set BPV.
4+A9. Nipple down BOPE, nipple up tree and test. Pull BPV.
42-:50. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and
allowing to equalize.
±.h5J.,____Set BPV and move rig off
44·,52. Rig up wire line unit. Pull BPV.
#-'53. Set gas lift valves in mandrels. Operate well on gas lift for +/- -f-&{.ì 30 days. Shut well in.
46,54. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection.
1 E-105 PERMIT IT Revised with suspension.doc1E 105 P¡::RMiT iT. doc
Page 7 of 8
Printed: 27-Jan-05
12. PU injection as required and RIH to depth. Land tub'
13. Nipple down BOPE, nipple up tree and te .
14. Freeze protect well with diesel b mping into 4-112" x 9-5/8" annulus, taking returns from tubing and allowing to
equalize. ~ )(i)r-~(t~ t (;;> ~
15. ~ -" - ,
16.
.ation for Permit to Drill, Well 1 E-1 05 L2
Revision No.O
Saved: 10-Jan-05
.'
17.
Rig up wir
lift valves in mandrels. Operate well on gas lift for +/- 180 days. Shut well in.
Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection.
4. Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AA C 25.005 (c)( J 4)
An application '/Òr a Permit to Drill musk' be accompanied by each of the JÓlìowing items. except fur an item already on file with the collunission
and identified in the application:
(14j a gencml descriplÙm of how the operator plans to di.q?Ose o{driiling mud and cuttings and a state¡rænt 'if' ",;fœt}¡er the operator intends to
reque.n authorization under 20 AilC 25.080fo1" an annular disposal operaTion in the well.;
Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a
permitted annulus on IE Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will
be disposed of either down a permitted annulus on IE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for
temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for
hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in
accordance with a permit from the State of Alaska.
ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal
operations.
15. Attachments
Attachment 1 Doyon 141 West Sak 2004 3 ksi BOP Configuration (1 page)
Attachment 2 Directional Plan (6 pages)
Attachment 3 Drilling Hazards Summary (1 page)
Attachment 4 Well Schematic (1 page)
G!~. !A.·L
',,", , , ~"
1 E-1 05 L2 PERMIT IT. doc
Page 6 of 6
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IE-IO* Drillin2; Hazard~ummary"
(SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS)
8-1/2" Open Hole / 5-1/2" Liner Interval
Hazard
Abnormal Reservoir
Pressure
Stuck Pipe
Risk Level
Low
Low
Miti ation Strate
Stripping drills, shut-in drills, increased mud
wei ht.
Good hole cleaning, PWD tools, hole opener
runs, decreased mud wei ht
Reduced urn rates, mud rheolo ,LCM
Trip speeds, proper hole filling (use of trip
sheets), urn in out, backreamin
Lost Circulation
Hole Swabbing on Trips
Low
Moderate
D
f\
! ~IA
., 'j ~,j i
1E-105 L2 Drilling Hazards Summary. doc
prepared by Steve McKeever
1/4/200510:19 AM
@O'
3-518'
lE-105 L2:
8~1/2" D s.and lateral
3.634' MD 1 3.399' TVD
lE-105 LI:
"B" sand lateral
3.640' MD 1 3.453' TVD
TD
TD
L80, BTCM, R3
2.5" slots
above,
o
105 L2 "D" Sand Window
7.241' MD 1 3.499' TVD
def,fTe-es
(
L-80, IBTM
500'
Gas Lift Mandrels, CAMCO 4-112" x 11' Mode
one (1) set at <72 deg, TVD,
nipple,
3812'
12,6
nipplt\Set
DB
Vr'ellhe.ad ! Tubing Hèad ¡ Tree.,
, 5.000 ksi
3,875'
---..
~
!!¡,
.... :ii:
~
....
~
C
<J'I
~
Drill String Valves
To be tested to 250 psi and 3,000 psi at initial
installation and every 14 days thereafter.
~
13-5 Annular
__________ To be tested to 250 psi and 1,500 psi at initial
~ installation and every 14 days thereafter.
13-5 Double Ram
Upper Rams: 3-%" to 6" variables
To be tested to 250 psi and 3,000 psi at initial
installation and every 14 days thereafter.
...
Lower Rams: Blind
To be tested to 250 psi and 3,000 psi at initial
installation and every 14 days thereafter.
Choke and Kill Line Valves
+- To be tested to 250 psi and 3,000 psi at initial
installation and every 14 days thereafter.
~ 13-5 Single Ram
Rams to fit Intermediate Casing: 7-5/8" or 9-5/8"
To be tested to 250 psi and 3,000 psi only before
running casing.
~ Wellhead Valves
tested to 3,000 psi upon assembly
Conoc~hillips
Alaska
Doyon 141 West Sak 3 ksi
BOP Configuration
13-5 BOP 3K diagram.vsd
Sheet 1 of 1
prepared by Steve McKeever
8/11/2004
OR}G1~J¡A.t"
.
.
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A Halliburton Company
ConocJP'hillips
Alaska
ConocoPhillips Alaska Inc.(Kuparuk)
Kuparuk River Unit
Kuparuk 1 E Pad
Plan 1 E-1 05
Plan 1 E-1 05 L2
Plan: 1E-105 L2 (wp02)
Proposal Report
05 January, 2005
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ConoêôPhilliJ",)$·-¡ a"LLIM.,.~IIIVfe:~,.
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Vertical Section at 180.00' (1200 ftlin)
-600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200
-3000 -3000
Project: Kuparuk River Unit
Site: Kuparuk 1 E Pad
-2400 Well: Plan 1E-105 -2400
Wellbore: Plan 1E·105 L2
Plan: 1E-105 L2 (wp02)
-1800 -1800
-1200 -1200 .
-600 -600
0 A 0
-f
2
'"
600 600 ~
do
hl
0
'"
'0
1200 1200 9'
~
N
0
0
~
1800 1800 ~
2400 2400 .
41/2"
3000 3000
1E·10S L2 (wp02)
3600 3600
4200 4200
4800 4800
-600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200
Vertical Section at 180.00' (1200 ftlin)
.
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ConocoPhillif1S
,.ðJåSkå
Project: Kuparuk River Unit
Site: Kuparuk 1E Pad
Well: Plan 1E-105
WeUbore: Plan 1E-105 L2
Plan: 1E-105 L2 (wp02)
..~..,~
lil"fL~f.. .. ..~y,c...
.I!O.....~
West(-)/East(+) (1000 Win)
-500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500
500 133/8" Casing 500
....
0 0
Top of Window - Assume 13.6° OLS oft whipstock - 235'FNL & 386'FEL:
Bottom of Window (7258'md,3503'tvd)
-500 L -500
Begin Build @ 6°/100ft (7278'md,3507'tvd)
-1000 -1000
Continue Build @ 5°/100ft (7520'md.3531'tvd)
-1500 -1500
Sail @ 97.5° (7602'md,3525~vd)
-2000 Begin Oir@ 4°/100ft (7855'md.3500~vd) -2000
-2500 Begin Geosteering in 0 -Lateral (7958'md,3493~vd) -2500
ê C/)
~ 0
c
0 .ê:
0 -3000 ~
0 -3000
.,..
0
+ ;::¡.
'E :::T
t ~
0 -3500 -::;
~ -3500 0
0
'E 0
'5 Estimated Intersection Fault #1 (11292'md,3464'lvd) <:!:
0 -4000 2:
(f) -4000
-4500 -4500
-5000 -5000
-5500 -5500
-6000 -6000
-6500 BHL: 1338'FNL & 345'FEL: SEC 27-T11N-R10E (13635'md,3399'tvd) -6500
-7000 -7000
-500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500
West(-)/East(+) (1000 Win)
.
.
ConocJPhillips
Alaska
Halliburton Company
Planning Report - Geographic
s¡p....,,...y-.LJI1
QAILLING S.AVICI!!S
A Halliburton Company
Map System:
Geo Datum:
Map Zone:
US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Alaska Zone 04
System Datum:
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Position Uncertainty
o.OOOft
O.OOOft
0.000 ft
Northing:
Easting:
Wellhead Elevation:
5,959,980.600 ft
550,300.480 ft ,/
ft
Latitude:
Longitude:
Ground Level:
70018' 05.162" N
149035' 33.332" W
66.100ft
Well Position +N/-S
+EI-W
1/5/2005 4:36:31PM
Page 2 of 6
COMPASS 2003.11 Build 48
.
.
ConocóPhillips
Alaska
Halliburton Company
Planning Report - Geographic
ssp&IrT1V-SUI1
O"'L;LINI:I SEAVICIIS
A Halliburton Company
7,241.633 75.000 177.901 3,499.100 3,405.00 -623.947 5,119.955 5,959,391.000 555,424.000 0.00 623.95
Top of Window - Assume 13.6' DLS off whipstock - 23S'FNL & 386'FEL : SEC22-T11N-R10E : (7242'md,3499'tvd) - 9 S/8H
7,258.133 77.244 177.901 3,503.057 3,408.96 -639.954 5,120.542 5,959,374.999 555,424.694 13.60 639.95
Bottom of Window (72S8'md,3S03'tvd)
7,278.133 77.244 177.901 3,507.473 3,413.37 -659.447 5,121.256 5,959,355.513 555,425.539 0.00 659.45
Begin Build @ 6°/100ft (7278'md,3S07'tvd)
7,300.000 78.554 177.901 3,512.057 3,417.96 -680.814 5,122.040 5,959,334.154 555,426.465 5.99 680.81
7,400.000 84.554 177.901 3,526.735 3,432.63 -779.618 5,125.661 5,959,235.386 555,430.747 6.00 779.62
7,500.000 90.554 177.901 3,530.997 3,436.90 -879.415 5.129.318 5,959,135.626 555,435.072 6.00 879.41
7,519.549 91.729 177.901 3,530.607 3,436.51 -898.947 5,130.034 5,959,116.101 555,435.919 6.01 898.95
Continue Build @ S'/10OO (7S20'md,3S31'tvd)
7,600.000 95.752 177.900 3,525.360 3,431.26 -979.156 5.132.975 5,959,035.921 555,439.396 5.00 979.16
7,601.805 95.842 177.900 3,525.178 3,431.08 -980.950 5,133.041 5,959,034.128 555,439.473 5.00 980.95
Sail @ 97.S· (7602'md,3S2S'tvd)
7,700.000 95.842 177.900 3,515.183 3,421.08 -1,078.570 5,136.620 5,958,936.543 555,443.706 0.00 1,078.57
7,800.000 95.842 177.900 3,505.005 3,410.91 -1,177.983 5,140.265 5,958,837.166 555,448.016 0.00 1,177.98
7,855.117 95.842 1 77. 900 3,499.395 3,405.30 -1 ,232.777 5,142.275 5.958,782.392 555,450.392 0.00 1,232.78
Begin Dir @ 4'/1000 (78SS'md,3500'tvd)
7,900.000 94.048 177.900 3,495.527 3,401.43 -1,277.461 5,143.913 5,958,737.724 555,452.329 4.00 1,277.46
7,957.936 91.729 177.901 3,492.609 3,398.51 -1,335.281 5,146.032 5,958,679.925 555,454.835 4.00 1,335.28
Sail @91.7· (79S8'md,3493'tvd)
8,000.000 91.729 177.901 3,491.339 3,397.24 -1,377.298 5,147.572 5,958,637.924 555,456.656 0.00 1,377.30
8,007.936 91.729 177.901 3,491.100 3,397.00 -1,385.225 5.147.863 5,958,630.000 555,457.000 0.00 1,385.22
Begin Dir@ 3'/1000 (8008'md,3491'tvd) - 1E-10S L2 T1
8,065.188 91.675 179.618 3,489.399 3,395.30 -1,442.436 5,149.101 5,958,572.804 555,458.621 3.00 1,442.44
Sail @ 91.7' (806S'md,3489'tvd)
8,100.000 91.675 179.618 3,488.382 3,394.28 -1,477.232 5,149.333 5,958,538.013 555,459.086 0.00 1,477.23
8,200.000 91.675 179.618 3,485.459 3,391.36 -1,577.187 5,149.999 5,958,438.075 555,460.421 0.00 1,577.19
8,300.000 91.675 179.618 3,482.536 3,388.44 -1,677.142 5,150.664 5,958,338.136 555,461.755 0.00 1,677.14
8,400.000 91.675 179.618 3,479.613 3,385.51 -1,777.097 5,151.330 5,958,238.198 555,463.090 0.00 1,777.10
8,500.000 91.675 179.618 3,476.690 3,382.59 -1,877.053 5,151.996 5,958,138.259 555,464.425 0.00 1,877.05
8,600.000 91.675 179.618 3,473.768 3,379.67 -1,977.008 5,152.661 5,958,038.320 555,465.759 0.00 1,977.01
8,700.000 91.675 179.618 3,470.845 3,376.74 -2.076.963 5,153.327 5,957,938.382 555,467.094 0.00 2,076.96
8,800.000 91.675 179.618 3,467.922 3,373.82 -2,176.918 5,153.992 5,957,838.443 555,468.428 0.00 2,176.92
8,900.000 91.675 179.618 3,464.999 3,370.90 -2,276.873 5,154.658 5.957,738.504 555,469.763 0.00 2,276.87
9,000.000 91.675 179.618 3,462.076 3,367.98 -2,376.828 5,155.324 5,957,638.566 555,471.098 0.00 2,376.83
9,067.607 91.675 179.618 3,460.100 3.366.00 -2,444.405 5,155.774 5,957,571.000 555,472.000 0.00 2,444.40
Begin Dir @ 3'/100 (9068'md,3460'tvd) -1E-10S L2 T2
9,100.000 90.886 179.053 3,459.376 3.365.28 -2,476.787 5,156.149 5,957,538.624 555,472.592 3.00 2,476.79
1/5/2005 4:36:31PM Page. 3 COMPASS 2003.11 Bui/d 48
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~; ::',:} ;1~ .'~>~'
.
.
ConocóPhUlips
Alaska
Halliburton Company
Planning Report - Geographic
IiiipEi!r'l""'y-su,.,
DAIL.LING SI!!AVICI!!S
A Halliburton Company
EDM 2003.11 Single User Db
Conocophillips Alaska Inc.(Kuparuk)
Kuparuk River Unit
Kuparuk 1 E Pad
Plan 1E-105
Plan 1E-105 L2
1 E-1 05 L2 (wp02)
9,112.387 90.583 178.836 3,459.218 3,365.12 -2,489.170 5,156.378 5,957,526.244 555,472.903 3.01 2,489.17
Sail @ 90.6° (9113'md,3459'tvd)
9,200.000 90.583 178.836 3,458.327 3,364.23 -2,576.761 5,158.157 5,957,438.675 555,475.269 0.00 2,576.76
9,300.000 90.583 178.836 3,457.309 3,363.21 -2,676.735 5,160.189 5,957,338.727 555,4 77 .970 0.00 2,676.74
9,400.000 90.583 178.836 3,456.292 3,362.19 -2,776.709 5,162.220 5,957,238.778 555,480.670 0.00 2,776.71
9,500.000 90.583 178.836 3,455.275 3,361.18 -2,876.684 5,164.251 5,957,138.829 555,483.370 0.00 2,876.68
9,600.000 90.583 178.836 3,454.258 3,360.16 -2.976.658 5.166.282 5,957,038.881 555,486.070 0.00 2,976.66
9,700.000 90.583 178.836 3,453.241 3,359.14 -3,076.632 5,168.314 5,956,938.932 555,488.771 0.00 3,076.63
9,800.000 90.583 178.836 3,452.223 3,358.12 -3,176.606 5,170.345 5,956,838.983 555,491.471 0.00 3,176.61
9,900.000 90.583 178.836 3,451.206 3,357.11 -3,276.580 5,172.376 5,956,739.035 555,494.171 0.00 3,276.58
10,000.000 90.583 178.836 3,450.189 3,356.09 -3,376.555 5,174.408 5,956,639.086 555,496.872 0.00 3,376.55
10,100.000 90.583 178.836 3,449.172 3,355.07 -3,476.529 5,176.439 5,956,539.137 555,499.572 0.00 3,476.53
10,200.000 90.583 178.836 3,448.155 3,354.05 -3,576.503 5,178.470 5,956,439.189 555,502.272 0.00 3,576.50
10,300.000 90.583 178.836 3,447.137 3,353.04 -3,676.477 5,180.502 5,956,339.240 555,504.973 0.00 3,676.48
10,400.000 90.583 178.836 3,446.120 3,352.02 -3,776.451 5,182.533 5,956,239.292 555,507.673 0.00 3,776.45
10,500.000 90.583 178.836 3,445.103 3,351.00 -3,876.426 5,184.564 5,956,139.343 555,510.373 0.00 3,876.43
10,600.000 90.583 178.836 3,444.086 3,349.99 -3,976.400 5,186.596 5,956,039.394 555,513.073 0.00 3,976.40
10,700.000 90.583 178.836 3,443.069 3,348.97 -4,076.374 5,188.627 5,955,939.446 555,515.774 0.00 4,076.37
10,800.000 90.583 178.836 3,442.052 3,347.95 -4,176.348 5,190.658 5,955,839.497 555,518.474 0.00 4,176.35
10,893.545 90.583 178.836 3,441.100 3,347.00 -4,269.869 5,192.559 5,955,746.000 555.521.000 0.00 4,269.87
Begin Dir @ 3°/100ft (10894'md,3441'tvd) -1E-105 L2 T3
10,900.000 90.402 178.903 3,441.045 3,346.94 -4.276.322 5.192.686 5,955,739.548 555,521.171 2.98 4,276.32
11,000.000 87.590 179.946 3,442.799 3,348.70 -4,376.291 5,193.690 5,955,639.599 555,522.844 3.00 4,376.29
11,068.396 85.665 180.662 3,446.823 3,352.72 -4,444.563 5,193.328 5,955,571.332 555,522.939 3.00 4,444.56
Sail @ 85.7° (11069'md,3447'tvd)
11,100.000 85.665 180.662 3,449.213 3,355.11 -4,476.075 5,192.964 5,955,539.821 555,522.786 0.00 4,476.07
11,200.000 85.665 180.662 3,456.772 3,362.67 -4,575.782 5,191.812 5,955,440.118 555,522.302 0.00 4,575.78
11,292.000 85.665 180.662 3,463.726 3,369.63 -4,667.513 5,190.753 5,955,348.392 555,521.856 0.00 4,667.51
Estimated Intersection Fault #1 (11292'md,3464'tvd)
11,300.000 85.665 180.662 3,464.331 3,370.23 -4,675.489 5,190.661 5,955,340.415 555,521.818 0.00 4,675.49
11,400.000 85.665 180.662 3,471.890 3,377. 79 -4,775.197 5,189.509 5,955,240.712 555,521.334 0.00 4,775.20
11,468.917 85.665 180.662 3,477.100 3,383.00 -4,843.912 5,188.715 5,955,172.000 555,521.000 0.00 4,843.91
1E-105 L2 T4
11,469.917 85.695 180.661 3,477.175 3,383.08 -4,844.909 5,188.704 5,955,171.003 555,520.995 3.00 4,844.91
Begin Dir @ 3°/10Oft (11469'md,3477'tvd)
11,500.000 86.595 180.624 3,479.198 3,385.10 -4,874.922 5,188.367 5.955,140.992 555,520.860 3.00 4,874.92
11,600.000 89.593 180.504 3,482.521 3,388.42 -4,974.850 5,187.384 5,955,041.068 555,520.545 3.00 4,974.85
11,700.000 92.590 180.383 3,480.614 3,386.51 -5,074.818 5,186.611 5,954,941.108 555,520.441 3.00 5,074.82
11,779.774 94.983 180.286 3,4 75.345 3,381.25 -5,154.410 5,186.146 5,954.861.521 555.520.509 3.00 5,154.41
Sail @95° (11780'md,3475'tvd)
11,800.000 94.983 180.286 3,473.588 3,379.49 -5,174.560 5,186.045 5,954,841.374 555,520.543 0.00 5,174.56
11,900.000 94.983 180.286 3,464.903 3,370.80 -5,274.180 5,185.547 5,954,741.762 555,520.712 0.00 5,274.18
12,000.000 94.983 180.286 3,456.217 3,362.12 -5,373.801 5,185.049 5,954,642.149 555,520.881 0.00 5,373.80
1/5/2005 4:36:31PM Page 4 of 6 COMPASS 2003.11 Build 48
OR'
, I'
.
.
ConocòP'hillips
Alaska
Halliburton Company
Planning Report - Geographic
sµ&r1....y-.LJI1
DAIL.LING SI!AVICIIS
A Halliburton COmpany
12,070.422 94.983 180.286 3,450.100 3.356.00 -5,443.957 5,184.698 5,954,572.000 555,521.000 0.00 5,443.96
Begin Dir@ 3·/10Oft (12071'md,3450'tvd) -1E-10S L2 TS
12,100.000 94.098 180.318 3,447.759 3,353.66 -5,473.441 5,184.543 5,954,542.518 555,521.042 3.00 5,473.44
12,180.346 91.687 180.405 3,443.706 3,349.61 -5,553.677 5,184.036 5,954,462.289 555,521.072 3.00 5,553.68
Sail @91.7· (12180'md,3444'tvd)
12,200.000 91.687 180.405 3,443.127 3,349.03 -5,573.322 5,183.897 5,954,442.645 555,521.065 0.00 5,573.32
12,300.000 91.687 180.405 3,440.183 3,346.08 -5,673.276 5,183.190 5,954,342.698 555,521.027 0.00 5,673.28
12,370.736 91.687 180.405 3,438.100 3,344.00 -5,743.979 5,182.690 5,954,272.000 555,521.000 0.00 5,743.98
Begin Dir@ 3·/100 ft (12371'md,3438'tvd) -1E-10S L2 T6
12,391.574 92.312 180.383 3,437.373 3,343.27 -5,764.804 5,182.547 5,954,251.176 555,520.996 3.00 5,764.80
Sail @ 92.3· (12392'md,343Ttvd)
12,400.000 92.312 180.383 3,437.033 3,342.93 -5.773.223 5,182.490 5,954,242.758 555,520.996 0.00 5,773.22
12,500.000 92.312 180.383 3,432.999 3,338.90 -5,873.140 5,181.823 5,954,142.849 555,520.998 0.00 5,873.14
12,600.000 92.312 180.383 3,428.964 3,334.86 -5,973.056 5,181.155 5,954,042.940 555,520.999 0.00 5,973.06
12,671.005 92.312 180.383 3,426.100 3,332.00 -6,044.002 5,180.681 5,953,972.000 555,521.000 0.00 6,044.00
Begin Dir@3·/10Oft (12671'md,3426'tvd) -1E-10S L2 T7
12,694.840 91.597 180.384 3,425.287 3,331.19 -6,067.822 5,180.522 5,953,948.181 555,521.000 3.00 6,067.82
Sail @ 91.6· (1269S'md,342S'tvd)
12,700.000 91.597 180.384 3,425.143 3,331.04 -6,072.980 5,180.487 5,953,943.024 555,521.000 0.00 6,072.98
12,800.000 91.597 180.384 3,422.356 3,328.26 -6,172.939 5.179.818 5,953,843.072 555,521.000 0.00 6,172.94
12,900.000 91.597 180.384 3,419.569 3,325.47 -6,272.898 5,179.149 5.953,743.121 555,521.000 0.00 6,272.90
13,000.000 91.597 180.384 3,416.782 3,322.68 -6,372.857 5,178.480 5,953,643.169 555,521.000 0.00 6,372.86
13,100.000 91.597 180.384 3,413.996 3,319.90 -6,472.816 5,177.811 5.953,543.218 555,521.000 0.00 6,472.82
13,200.000 91.597 180.384 3,411. 209 3,317.11 -6,572.774 5,177.141 5,953,443.267 555,521.000 0.00 6,572.77
13,300.000 91.597 180.384 3,408.422 3,314.32 -6,672. 733 5,176.472 5,953,343.315 555,521.000 0.00 6,672. 73
13,400.000 91.597 180.384 3,405.635 3,311.53 -6,772.692 5,175.803 5,953,243.364 555,521.000 0.00 6,772.69
13,500.000 91.597 180.384 3,402.848 3,308. 75 -6,872.651 5.175.134 5,953,143.412 555,521.000 0.00 6,872.65
13,600.000 91.597 180.384 3,400.061 3,305.96 -6,972.610 5,174.464 5,953,043.461 555,521.000 0.00 6,972.61
13,634.478 91.597 180.384 3,399.100 3,305.00 -7,007.073 5,174.234 5,953,009.000 555,521.000 0.00 7,007.07
BHL: 1338'FNL & 34S'FEL : SEC 27-T11N-R10E (1363S'md,3399'tvd) - 41/2" - 1E-10S L2 Toe
1/5/2005 4:36:31PM
Page 5 of 6
COMPASS 2003.11 Build 48
ORJ
.
.
ConocóP'hillips
Alaska
Halliburton Company
Planning Report - Geographic
!ilpEilrof""V-SUl1
QAILLING SE!!RVICII.
A Halliburton Company
EDM 2003.11 Single User Db
ConocoPhiUips Alaska Inc.(Kuparuk)
Kuparuk River Unit
Kuparuk 1 E Pad
Plan 1 E-105
1E-105 L2
05 L2 (wp02)
3,450.100 1E-105 L2 T5 -5,443.957 5,184.698 5,954,572.000 555,521.000
- Point
3,426.100 1E-105 L2 T7 -6,044.002 5,180.681 5,953,972.000 555,521.000
- Point
3,438.100 1E-105 L2 T6 -5,743.979 5,182.690 5,954,272.000 555,521.000
- Point
3,441.100 1E-105 L2 T3 -4,269.869 5,192.559 5,955,746.000 555,521.000
- Point
3,460.100 1E-105 L2 T2 -2,444.405 5,155.774 5,957,571.000 555,472.000
- Point
3,491.100 112-105 L2 T1 -1,385.225 5,147.863 5,958,630.000 555,457.000
- Point
3,477.100 112·105 L2 T4 -4,843.912 5,188.715 5,955,172.000 555,521.000
- Point
3,399.100 112-105 L2 Toe -7,007.073 5,174.234 5,953,009.000 555,521.000
- Point
3,404.100 1E-105 L2 T8 -6,967.070 5,174.502 5,953,049.000 555,521 .000
- Point
4,537.135
7,241.700
13,634.477
2,474.100
3,499.117
3,399.100
13-3/8
9-518
4-112
16
12-1/4
8-1/2
1/5/2005 4:36:31PM
Page 6 of 6
COMPASS 2003.11 Build 48
OR' ~,
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WELLDETAILS ANTI.COlliSION SETTINGS
+N/-S +BI-W Northing &<ting Latitude Longitude- SJot Interpolation Meth( å.:MD Interval; 25.000
lan1B-105 217.648 412.464 5959980.60 550300.48 7W18'05.162N 149"35'33.332W NIA Depth Range. Pmm: 7241 632 To 13634.499
MlIXinnun Range.; 10000.OOORefe. 'enc.e~ Plan: 1E-105 L2 (wp02)
6
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50
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18
LEGEND
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lE-114i1B-114),MajorRiSk
1&1141E-114Ll),MaJC1rRisk
1£.1141E-114L2),MaJorRisk
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1E-126 (1E-126L2), MajQTRisk
- Plan IJ.I66¡U-l66L1),Ma~orRisk
- Plan IJ-I66 U-I66U:),MaJorRisk
- P1an1J.l66IJ-166),MajorRisk
- PianIJ-170(planlH4LatA),MajorR.isk
- Plan lE-l05 L2
- lE-105L2(wpOZ)
Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [25ft/in]
COMPANY DETAILS
SURVEY I'ROGRAM
Dep1bPro~ío~
1241-633 136M.SOD PlIØleÒ:JE-JOSU(wp02)V5
WEl1.PAßI DErAIlS
PlatllE-1CISU.
PartmWdJpri¡; P1m 1E-IOSPBi
"fie.on}.( ); 7241.633
Conoc.oPhiIJjps AJa.ska In¢.
Enginemng
Alpin<
CalculationM&hod: Minimum~.
Error System: ISCWSA
Scan Method: Trav CVlindtr Narth
w~~t= re~Was:f35ing
T""
"""
From Colour ToMD
7242 7441
7441 7541
7541 7641
7641 7891 0
7891 8141 30.0
8141 8391
8391 8891
8891 9391
0 9391 9891 25.0
9891 10391
10391 10891
10891 11891
11891 12891 20.0
12891 13635
15.0
10.0
5.0
0 27
5.0
90 10.0
15.0
20.0
25.0
30.0
""
Rtf. Dab¡¡;
V.&diOJl
...,
18;(1.00(10
28.000
lE-10S 94.100ft
~ +~ ~
From Colour ToM
7242 7441
7441 7541
7541 7641
7641 7891
7891 8141
8141 8391
8391 8891
8891 9391
9391 9891
9891 10391
0391 10891
891 11891
I 12891 .
0- 13635
90
.
Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [15ft/in]
SECI10NDETAILS
Sec. M!) In, ^" 1VD +NI.s +EI-W Dug TF= VS" T_
1 7241.633 75.000 177.901 3499.100 -623.948 51l9.955 0.00 0.000 623.949
2 7258.133 77.244 177.901 3503.057 -639.955 5120.542 13.60 0.000 639.955
3 7278.133 77.244 177.901 3507.473 -659.448 5121.256 0.00 0.000 659.448
4 7519..549 91.729 177.901 3530.607 -898.948 5130.034 6.00 0.000 898.948
5 7601.805 95.842 177.900 3525.178 -980.951 5133.Q.41 5.00 -0.013 980.951
6 7855.11795.842 177.900 3499.395 -1232779 5142.274 0.00 0.000 1232779
7 7957.936 91.729 177.901 3492.609 -1335.283 5146.032 4.00 179.987 1335.283
8 8007.936 91.729 177.901 3491.100 -1385.226 5147.863 0.00 0.000 1385.226 lE-l05L2Pt1 (vI)
9 8065.189 91.675 179.618 3489.399 ·144l438 5149.101 3.00 91.779 1442438
10 9067.607 91.675 179.618 3460.100 -2444.406 5155.773 0.00 0.000 2444.406 lE-105UPt2(v1)
11 9112.387 90.583 178.836 3459.218 -2489.172 5156.377 3.00 -144.376 2489.172
12 10893.545 90.583 178.836 3441.100 -4269.870 5192558 0.00 0.000 4269.871 1&105 L2 PO (vi)
13 11068.396 85.665 180.662 3446.823 -4444.565 5193.317 3.00 159.666 444""
14 11468.917 85.665 180.662 3477.100 -4843.913 5188.715 0.00 0.000 4843.913 lE-105UPt4(vl)
15 11779.774 94.983 180.286 3475.345 -5154.412 5186.145 3.00 -2308 5154.412
1. 12070.423 94.983 180.286 3450.100 -5443.958 5184.697 0.00 0.000 5443.958 lE-105UPt5(vl)
17 12180.346 91.687 180.405 3443.706 -5553.678 5184.035 3.00 177.9>4- 5553.678
18 12370.73691.687 18Q.405 3438.100 -5743.981 5182.689 0.00 0.000 5743.981 1.B-l05 UPt6 (vI)
19 12400.423 92.322 179.780 3437.062 -5773.649 5182641 3.00 -44575 5773.649
20 12671.021 92.322 179.780 3426.too -6044.023 5183.680 0.00 0.000 6044.023 1E-I05UPt7(vt)
21 12707.029 91.592 180.577 3424.870 -6080.009 5183.568 3.00 132.458 6080.009
22 13634.500 91.592 180.577 3399.100 -7007,(175 5t74.232 0.00 0.000 7007.075 IE-I05 L2 Toe (vi)
.
.
7241.630 3499.099
13634.500 3399.100
Halliburton Company
Anticollision Report
9.625
5.500
12.250
8.500
95/8"
5 1/2"
Principal: Yes
Plan: 1 E-105 L2 (wp02)
Date Composed:
Version:
Tied-to:
12/12/2004
5
From: Definitive Path
Kuparuk 1 D Pad
Kuparuk 1 D Pad
Kuparuk 1 E Pad
Kuparuk 1 E Pad
Kuparuk 1 E Pad
Kuparuk 1 E Pad
Kuparuk 1 E Pad
Kuparuk 1 E Pad
Kuparuk 1J Pad
Kuparuk 1J Pad
Kuparuk 1J Pad
Kuparuk 1J Pad
Site:
Well:
Wellpath:
1D-126
10-127
1 E-114
1 E-114
1 E-114
1E-126
1E-126
1E-126
Plan 1J-166
Plan 1 J-166
Plan 1J-166
Plan 1J-170
9415.511 6300.000 1015.681 232.479
11230.306 7250.000 ~ 841.690 322.491
7261.273 6225.000 "566.826 139.233
7261.281 6225.000 566.829 136.121
7261.278 6225.000 566.829136.153
8843.191 7325.000 1097.644250.048
11629.522 10100.000 1176.488420.423
12398.906 10875.000 1233.942474.681
13597.663 10825.000 1284.262400.264
13589.666 10825.000 1279.111 405.388
13589.064 10850.000 1297.530406.400
783.201
519.199
427.593
430.708
430.676
847.596
756.065
759.261
883.998
873.723
891.130
Major Risk
0.000 ft
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Out of range
10-126 V2
10-127 V2
1E-114 V1
1E-114L 1 V1
1 E-114L2 VO
1E-126V1
1 E-126L 1 V1
1E-126L2 V1
1J-166 L 1 V1 Plan: 1J-
1J-166 L2 V2 Plan: 1J-
1J-166 V3 Plan: 1J-166
Plan 1J-L4 LatA VO
Kuparuk 10 Pad
10-126
10-126 V2
Rule Assigned:
Inter-Site Error:
7826.988 3502.258 900.000 852.255 28.826 1.505116.611 298.711 9.625 5545.157 127.303 5417.854 Pass
7831.527 3501.796 925.000 871.407 28.868 1.620 116.505 298.605 9.625 5522.816 127.532 5395.284 Pass
7836.310 3501.309 950.000 890.161 28.913 1.739 116.403 298.503 9.625 5500.308 127.804 5372.505 Pass
7841.331 3500.798 975.000 908.511 28.961 1.851 116.306 298.406 9.625 5477.646128.127 5349.519 Pass
7846.587 3500.263 1000.000 926.445 29.010 1.967 116.214 298.314 9.625 5454.839 128.447 5326.392 Pass
7852.116 3499.701 1025.000 943.971 29.062 2.094 116.127 298.226 9.625 5431:923128.790 5303.133 Pass
7855.117 3499.395 1050.000 961.094 29.090 2.222116.043 298.143 9.625 5408.925 129.051 5279.874 Pass
7855.117 3499.395 1075.000 977.805 29.090 2.352 115.964 298.064 9.625 5385.860129.218 5256.642 Pass
7855.117 3499.395 1100.000 994.101 29.090 2.487 115.890 297.990 9.625 5362.739 129.399 5233.340 Pass
7855.117 3499.395 1125.000 1010.023 29.090 2.627 115.819 297.919 9.625 5339.565 129.603 5209.962 Pass
7855.117 3499.395 1150.000 1025.573 29.090 2.766115.753 297.853 9.625 5316.345129.807 5186.537 Pass
7868.239 3498.119 1175.000 1040.745 28.913 2.895115.693 297.793 9.625 5293.041 129.833 5163.208 Pass
7870.928 3497.873 1200.000 1055.519 28.876 3.039115.636 297.736 9.625 5269.718130.027 5139.690 Pass
7873.677 3497.626 1225.000 1069.863 28.839 3.183115.584 297.684 9.625 5246.328130.225 5116.102 Pass
7876.485 3497.379 1250.000 1083.768 28.801 3.327 115.538 297.638 9.625 5222.881 130.423 5092.458 Pass
7879.350 3497.133 1275.000 1097.229 28.762 3.4 71 115.497 297.597 9.625 5199.387130.620 5068.768 Pass
7882.258 3496.889 1300.000 1110.253 28.723 3.619 115.462 297.562 9.625 5175.846130.832 5045.014 Pass
7885.193 3496.648 1325.000 1122.846 28.683 3.766115.432 297.532 9.625 5152.256 131.044 5021.211 Pass
7888.155 3496.412 1350.000 1135.003 28.643 3.913 115.408 297.508 9.625 5128.626131.258 4997.368 Pass
7900.000 3495.527 1375.000 1146.724 28.483 4.047115.390 297.489 9.625 5104.989131.335 4973.654 Pass
7900.000 3495.527 1400.000 1158.140 28.483 4.192115.375 297.475 9.625 5081.357131.593 4949.763 Pass
7900.000 3495.527 1425.000 1169.308 28.483 4.337115.363 297.463 9.625 5057.793131.851 4925.942 Pass
7900.000 3495.527 1450.000 1180.228 28.483 4.482 115.354 297.454 9.625 5034.304 132.110 4902.195 Pass
OR'G'!~JAL.
Revision to IE-I 05 Permit to Drill package.
.
.
Hi Tom -
Please find attached a revision to the proposed drilling program for 1E-105. The
revision includes the steps to be done after the intermediate hole section is cased and
cemented, so that the rig can be released for the exploration work in mid-February.
As I mentioned on the phone our plan is to case and cement the intermediate hole
section of 1E-105, move Rig 141 to NPRA for exploration work, move back to 1E pad in
late April, drill and complete 1E-117, and then move back onto 1E-105 to complete the
remaining drilling operations. Additionally I have include the steps we will take with
regard to 1E-105PB1, a well bore we will drill and abandon in order to gain geologic
information in order to better geo-steer the 1E-105 well bore.
With regard to the Area of Review for the nearby wells, we will complete this review
and send the AOGCC the required information in the near future. My conclusion from
our recent conversation is that the AOGCC will issue Permits to Drill for 1E-105,
1E-105L1, and 1E-105L2 (assuming all other issues have been adequately addressed and
resolved) without the Area of Review being completed. However such Permits to Drill
would have a stipulation that the well could not be operated as an injector until the
integrity of nearby wells was verified. If my conclusion is incorrect and we need to
provide some more information before the Permits to Drill can be issued, please let me
know ASAP.
«1 E-1 05 Drilling Program Revision.pdf»
Steve McKeever
Senior Drilling Engineer
ConocoPhillips Alaska, Inc.
700 "G" Street
Anchorage, Alaska 99501
steve.mckeever@conocophillps.com
office: 907/265-6826
fax: 907/265-1535
pager: 907/275-0369
liThe short fortune-teller who escaped from prison was a small medium at large."
lE-105 Drilling Program
C t t D . t· . lE-105 Drilling Program
on en - escnp Ion. R .. df
eVISlOn. p
Content- Type: application/octet-stream
Content-Encoding: base64
20f2
1/27/20058:06 PM
IE-105. -105Ll, -105L2
.
.
Subject: IE-I05, -105LI, -105L2
From: Thomas Maunder <tom_maunder@admin.state.ak.us>
Date: Mon, 24 Jan 2005 09:38:40 -0900
To: Mike.R.Greener@conocophillips.com
CC: Gary Targac <Gary.Targac@conocophillips.com>, Randy Thomas
<Randy.L. Thomas@conocophillips.com>
Mike and Gary,
With regard to these wells, is there a plan to pre-produce??
Since the wells will ultimately be injectors, the Area of Review task must be
done. AOR means that the cementing record of any penetration that falls within 1/4
mile distance of the planned wellbore track must be examined to assure that such
penetrations do not provide a potential conduit out of the intended zone. The
pertinent beginning "point" is where the motherbore penetrates the top of the West
Sak and the ending "point" is the furthest extent of the toe of any of the
laterals.
Based on our preliminary review of the trajectory, the WS wells you potentially
need to examine are: 1E-114 and laterals, 1D-123, 1D-126, 1D-127, 1E-126 and
laterals, 1E-168 and laterals. The potential Kuparuk wells are 1E-33, 1E-33PB1,
1J-09, 1E-34 and 1E-22. 1E-03 or 1E-103 may also need to be checked. I can't
determine the name on the plot I am looking at. My source of the information is a
plan view of the proposed well trajectories. A few of the wells, 1E-34, 1J-09 and
1E-22 will likely fallout since their WS penetrations are probably outside the 1/4
mile distance. The only "wild card" that you also need to consider are any "lost"
hole sections that may have been drilled.
Please call or message with any questions.
Tom Maunder, PE
AOGCC
1 of 1
1/24/2005 10:38 AM
KRU 1E..105L2
Proposed Service
West Sak nDn Sand
2050080
SfD
1/1212005
.
.
TRANSMIT AL LETTER CHECK LIST
CIRCLE APPROPRlA TE LETTERIP ARAGRAPHS TO
BE INCLUDED IN TRANSMITTAL LETTER
WELL NAME kI~¿(~? / E ~/O S- L 2
PTD# 2-0~ -'ø8
Exploration
Stratigraphic
Development
1// Service
CHECKWHAT ADD-ONS ~'CLUE"·
APPLIÈS (OPTIONS)
MULTI The permit is for a new weJlbore segment of
LATERAL existing weD k.ß;/< It; - /0> ,
~' Permit No~"SZ>~DAP] No. 5õ-D2"t-~3.zq~ -ð
(If API number Production. should continue to be repor1ed as
last two, (2) digits a function 'of tbe original API number. stated
are between 60-69) above.
PILOT HOLE In accordance witb ' 20 AAC 25.005(1), all
(PH) records, data and logs acquired for the pilot
bole must be dearly differentiated In both
Dame (name on permit plus PH)
.' and API Dumber (50 -
70/80) from records, data and logs acquired
for well (name OD permit).
SPACING Tbe permit is approved subject ·to full
EXCEPTION compliance witb 20 AAC 25.,OSS~ Approval to
perforate and produce is contingent upon
issuance of ~ conservation order approving a
spa dug ex ception.
(Company Name) assumes tbe Jiability of any
protest to tbe spacing .~Jception tbat mllY
occur.
DRY DITCH AU dry ditcb sample sets submitted to tbe
SAMPLE Commission must be in no greater 1han 30'
" sample intervals from below tbe permafrost
or from wbere samples are first caught and
] 0' sample j¡jter-vals tbrough target zones.
.'
ò
D
Well bore seg
Annular Disposal
Qn
Program SER
On/Off Shore
E-105L2
Unit jjjQ(l
20 MC _25.005(e)
inADl-025660.
Well Name: KUPARUK RIV U WSAK
PEND GeoArea 890
Multilatß(at well_sßgment; feewajvßd per
TQpprQductive inteNal in ADL 025651; TO
SER
KRU West SakOjl Pool, goyerned by QonseNation_ Order No, 4Q6ß
No restricHons as_ to wßIl spaciog in CO_ 4_066
.
Arßa InjeçijonQrder No. 2B
1:;-126_ & La_terals, J E-114 ~Hatß(als,
27
0-1
m-12~, 10-12_6,
E:33,
_1
11:;-16.8_& Laterals,
NA
Y!3S
_Y!3S
Y!3S
Y!3S
Yes
Yes
Y!3S
Y!3S
Y!3S
Yes
Y_es
Yes
Yes
Y!3S
Y!3S
NA
Initial ClasslType
490150
KUPARUK RIVER, WEST SAK OIL
NC
Field & Pool
_VY~I
Well
indrilliog un
iocJuded
acrßageayailable
js weJlbQre plat
_Opß(ator onl)' affectßd party
_Opß(ator bas_appropriate_ bond inJorce
(For
incpmmeots)
P!3rmit c_an be issu_ed witbQut co.nserva_tion order
P!3rmit can be issued wjtbQut admioistratilleapprpvaJ
"-- ""-~it '-- -""--,,,--' '--'-,'- 15-day wait
ec I : 'ataauthorized by 1-'" # (put 10#
litl I : reyißW id!3otifißd (F servjC!3 wel on I)') _ _
ÇE i I lof pœ-produc;tioo I s than 3 montbs (For
IJ'I;;; ,............""v.....U uvlvl.....
v,.....,.........,
._.wc;tioo Ord_er
sßr:vice WßII QnJy)
Conduc;torsetio motherborß, lE~105..
All aquifers exempted <10 cm :147.102(b)(3)
Surface ca.sing instalJedio 11:;-1Q5,
installed jn
E-10,5.
Intermediate casing cement plaon!3d above aoy/all hysroC<!rbons.
Intermedjate_ c;asing
Slotted
lioercompletion plaoned.
wel
I
NQ reseJllepjtplanoed. All waste toanapprOlled _aonuJu.spr Class
Rig is equippe_dwith st!3el.pits.
O_nly _close appro_ach is ß _saod_ section ,- _50'Jvct beJow~
60¡::> stack wi in plac;e.
61-\¡::> expßctect beiween 8..3.- .8.,6.ppg EMW.
¡::>ro~imit)' analysis performe_d
alœady_be
.
S_at<.
West
io
F'lanned MW9..Q PP-9
to tßstto 3000 psi
CPAI plans
208 psi
MAS¡=> calc;u!ate_d,at
Low lellel1-\2S in WS ha_s .bßen. rßportßd on 1 I:; pad, Mud .sbould_preclude H2S on (ig. .Rig bassßosprsand alarm
Prelimioary (eyiew otAOR well.s _does.n,ot indicate any probtems. CPAUo provide_ c;ornpteteAOR. .
---
measured between _2 and 12 pp_m 1-\2S
in20Q4,
1/<1 mile to east
b!3drilled wjtb 9.0 ppg oil-based mud.
D~127 Je.ss thao
8.6_ ppg EMW; wi
KRU 10-123, j D-J 26 and
EXPßctect r_eSEUllojr pre_ssuJe i.s8.3
NA
NA
NA
NA
No_
Yes
Yes
NA
Yes
NA
Yes
Y_es
Yes
Yes
Yes
No
No_
No,
Y!3S
NA
NA
NA
CQn_si.stencyhas bee,nissued forJbis project
ACMP F'indjng .of
Conductor
_Sulfacecasing protec;ts al
stringprQvided
& surtc.sg
known USDWs
.CMT vot adequ,ate, to circ.utate_o.n .cood.uçtor_
tie-in .long _string to surf csg_
,CMT v.ot adeq u_ate. to
koo.wn _pro_ductiye borizon_s
C,T, B& permafrost
CMT will còyera]
.C.asing designs ad_equate fPr
Adequatetankageor reserye pit
be!3O apprQved
IfaJe-drilt has a 10-403 fQr abandQnment
,Adequate well bore separatio,n ,proposed, ,
'''~ it meet reguJatioos
Ißmatic& ec¡.uip Jistadequat!3
Ifdiverter rec¡.uired, dQ_,..
DriUiog f]ujd program
BOPEs,do
they meet reg ulatioo
.B,OPE.press
in _commßots)
test to ,(puJ psig
(May 84)
ratiog appropriate;
_operatjonsbutdQwn
H2S gas_ probablß
Mecbanicalcoodition of wells withio AOR yerified (For s_ervice welJ on!)')
P!3rmit fee attached
,Lßas!3 ,number .appropriate
,U,nique well n,arn!3 ,and oumb,er
WeJIIQcated in.a, d,efil1e,d .pool
'^,"'lJocat!3d proper ,distançe from driJling uoitbpuod,ary,
IQcat!3d proper _distance_ from otber Wßlls
çieot' t
liiatßc
Choke manifold complies w/API RF'-53
WQrk will occur without
Is presence_ of
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
Administration
Date
1/12/2005
Appr
SFD
Engineering
Date
1/27/2005
~~~
Appr
TEM
P!3rmit can be issued w/o hyd(ogen sulfide meas].J(es
,Data,preseoted on potential overpressurß ,zooe.s
35
36
37
38
39
Geology
Date
1/12/2005
Appr
SFD
_Seismic an a Iysjs_ of .shallow gaszooes
(if off-shore)
_S!3abedcoodjtioo survey
CQntact
Date
r7/~
weekly progress reports [exploratory only]
Public
~;O""
Date
Engineering
Commissioner:
oamelphoneJor
) Is
Date:
?-I
Geologic
Commissioner:
Dtç
.
.
Well Histol)' 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 fìnding infonnation, 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 infonnation.
.
.
Sperry-Sun Drilling Services
LIS Scan Utility
/34~8
$Revision: 3 $
LisLib $Revision: 4 $
Mon Nov 14 14:16:27 2005
c!)OS - DOg
Reel Header
Service name............ .LISTPE
Date. . . . . . . . . . . . . . . . . . . . .05/11/14
Origin. . . . . . . . . . . . . . . . . . .STS
Reel Name............... . UNKNOWN
Continuation Number..... .01
Previous Reel Name...... . UNKNOWN
Comments................ .STS LIS Writing Library. Scientific Technical Services
Tape Header
Service name............ .LISTPE
Date.................... .05/11/14
Origin.................. .STS
Tape Name............... . UNKNOWN
Continuation Number..... .01
Previous Tape Name...... .UNKNOWN
Comments................ .STS LIS Writing Library. Scientific Technical Services
Physical EOF
Comment Record
TAPE HEADER
Kuparuk
MWD/MAD LOGS
#
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
#
JOB DATA
lE-105 L2
500292324361
ConocoPhillips Alaska, Inc.
Sperry Drilling Services
14-NOV-05
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWDRUN 2
MW0003677560
E. QUAM
D. GLADDEN
MWD RUN 9
MW0003677560
E. QUAM
D. GLADDEN
MWD RUN 10
MW0003677560
E. QUAM
D. GLADDEN
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 11
MW0003677560
E. QUAM
D. GLADDEN
#
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
16
11
10
391
224
93.58
66.10
#
WELL CASING RECORD
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
OPEN HOLE
BIT SIZE (IN)
12.250
8.500
CASING
SIZE (IN)
13.375
9.625
DRILLERS
DEPTH (FT)
3905.0
7258.0
#
REMARKS:
1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE
.
.
NOTED. THESE DEPTHS ARE
BIT DEPTHS.
2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD).
3. THIS WELLBORE EXITS THE lE-l05 PB2 WELLBORE AT
7258'MD/3528'TVD, BY MEANS
OF A WHIPSTOCK.
4. MWD RUN 1 (COMPRISING lE-l05 PB1) WAS DIRECTIONAL
ONLY AND IS NOT PRESENTED
5. MWD RUNS 2,10,11 COMPRISED DIRECTIONAL, DUAL GAMMA
RAY (DGR) UTILIZING
GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC
WAVE RESISTIVITY PHASE-4
(EWR4). RUNS 10 & 11 ALSO INCLUDED GEO-PILOT ROTARY
STEERABLE BHA (GP),
AZIMUTHAL LITHO-DENSITY (ALD) , COMPENSATED THERMAL
NEUTRON POROSITY (CTN) ,
ACOUSTIC CALIPER (ACAL), AND PRESSURE WHILE DRILLING
(PWD). NO VALID SEXP
DATA WERE ACQUIRED DURING MWD RUN 2 DUE TO TOOL
PROBLEMS. THE PURPOSE OF
MWD RUN 9 WAS TO POSITION THE WHIPSTOCK, MILL THE
WINDOW, AND DRILL A BIT
OF RAT HOLE. ONLY SROP DATA ARE PRESENTED.
6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL,
DATED 12/16/04, FROM M.
WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE
CONSIDERED PDC.
7. MWD RUNS 1,2,9-11 REPRESENT WELL lE-l05 L2 WITH
API#:50-029-23243-61. THIS
WELL REACHED A TOTAL DEPTH (TD) OF
13530'MD/3396'TVD.
SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRC SMOOTHED GAMMA RAY COMBINED.
SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA
SHALLOW SPACING) .
SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW
SPACING) .
SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM
SPACING) .
SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP
SPACING) .
SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING) .
TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SST LITHOLOGY,
VARIABLE HOLE SIZE) .
CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE.
CTNA SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE.
ACAL ACOUSTIC CALIPER.
SBD2 SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT
BIN) .
SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) .
SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC
ABSORPTION FACTOR
(LOW-COUNT BIN) .
SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS.
SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR
DEPTHS.
PARAMETERS USED IN POROSITY LOG PROCESSING:
HOLE SIZE: ACAL-DERIVED (8.5" BIT)
MUD WEIGHT: 9.0 - 9.1 PPG
MUD SALINITY: 41,000 - 50,000 PPM CHLORIDES
FORMATION WATER SALINITY: 11,000 PPM CHLORIDES
FLUID DENSITY: 1.0 G/CC
MATRIX DENSITY: 2.65 G/CC
LITHOLOGY: SANDSTONE
$
.
.
File Header
Service name............ .STSLIB.001
Service Sub Level Name. . .
Version Number.......... .1.0.0
Date of Generation...... .05/11/14
Maximum Physical Record. .65535
File Type. . . . . . . . . . . . . . . . LO
Previous File Name...... .STSLIB.OOO
Comment Record
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
Depth shifted
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
GR
FET
RPS
RPM
RPD
ROP
NPHI
FCNT
NCNT
RHOB
PEF
DRHO
CALA
RPX
$
1
and clipped curves; all bit runs merged.
.5000
START DEPTH
3862.0
3880.0
3880.0
3880.0
3880.0
4028.0
7258.0
7258.0
7258.0
7258.0
7258.0
7258.0
7259.0
7261. 5
STOP DEPTH
13492.5
13485.0
13485.0
13485.0
13485.0
13529.5
13438.0
13438.0
13438.0
13452.0
13452.0
13452.0
13440.5
13485.0
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
BASELINE DEPTH
$
#
MERGED DATA SOURCE
PBU TOOL CODE
MWD
MWD
MWD
MWD
$
#
REMARKS:
BIT RUN NO
2
9
10
11
MERGED MAIN PASS.
$
MERGE TOP
3862.0
7258.5
7303.0
9736.0
MERGE BASE
7258.0
7303.0
9736.0
13530.5
#
Data Format Specification Record
Data Record Type..................O
Data Specification Block Type.....O
Logging Direction. . . . . . . . . . . . . . . . . Down
Optical log depth units.... ...... .Feet
Data Reference Point...... ....... .Undefined
Frame Spacing............... ......60 .1IN
Max frames per record............ .Undefined
Absent value..................... .-999
Depth Units. . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD FT/H 4 1 68 4 2
GR MWD API 4 1 68 8 3
RPX MWD OHMM 4 1 68 12 4
RPS MWD OHMM 4 1 68 16 5
RPM MWD OHMM 4 1 68 20 6
RPD MWD OHMM 4 1 68 24 7
FET MWD HOUR 4 1 68 28 8
NPHI MWD PU-S 4 1 68 32 9
FCNT MWD CNTS 4 1 68 36 10
NCNT MWD CNTS 4 1 68 40 11
RHOB MWD G/CM 4 1 68 44 12
.
.
DRHO MWD
PEF MWD
CALA MWD
G/CM
BARN
INCH
4
4
4
1 68
1 68
1 68
48
52
56
13
14
15
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 3862 13529.5 8695.75 19336 3862 13529.5
ROP MWD FT/H 0.02 708.42 191.324 19004 4028 13529.5
GR MWD API 23.76 134.65 71.94 19262 3862 13492.5
RPX MWD OHMM 5.92 2000 64.6902 12448 7261.5 13485
RPS MWD OHMM 2.71 2000 38.943 19211 3880 13485
RPM MWD OHMM 4.49 2000 37.4206 19211 3880 13485
RPD MWD OHMM 0.13 2000 46.6246 19211 3880 13485
FET MWD HOUR 0.1 93.81 2.3834 19211 3880 13485
NPHI MWD PU-S 8.4 55.24 36.4836 12361 7258 13438
FCNT MWD CNTS 570 4150 971.245 12361 7258 13438
NCNT MWD CNTS 106744 203167 136084 12361 7258 13438
RHOB MWD G/CM 1.806 3.065 2.20869 12389 7258 13452
DRHO MWD G/CM -0.639 0.415 0.0527658 12389 7258 13452
PEF MWD BARN 0.55 12.04 2.0599 12389 7258 13452
CALA MWD INCH 8.43 10.03 8.8147 12364 7259 13440.5
First Reading For Entire File......... .3862
Last Reading For Entire File... ........13529.5
File Trailer
Service name............ .STSLIB.001
Service Sub Level Name. . .
Version Number.......... .1.0.0
Date of Generation..... ..05/11/14
Maximum Physical Record. .65535
File Type. . . . . . . . . . . . . . . . LO
Next File Name. ... ...... .STSLIB.002
Physical EOF
File Header
Service name...... ...... .STSLIB.002
Service Sub Level Name. . .
Version Number.......... .1.0.0
Date of Generation...... .05/11/14
Maximum Physical Record..65535
File Type. . . . . . . . . . . . . . . . LO
Previous File Name...... .STSLIB.001
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
GR
RPS
RPM
RPD
FET
ROP
$
2
header data for each bit run in separate files.
2
.5000
START DEPTH
3862.0
3880.0
3880.0
3880.0
3880.0
4028.0
STOP DEPTH
7258.0
7258.0
7258.0
7258.0
7258.0
7258.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
09-MAY-05
Insite
66.37
Memory
7258.0
.
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type..................O
Data Specification Block Type.....O
Logging Direction. . . . . . . . . . . . . . . . .Down
Optical log depth units.......... .Feet
Data Reference Point............. .Undefined
Frame Spacing..................... 60 .1IN
Max frames per record............ .Undefined
Absent value..................... .-999
Depth Units. . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
4027.0
7258.0
63.4
81. 5
TOOL NUMBER
126027
116184
12.250
3905.0
LSND
9.00
74.0
9.0
350
4.1
3.500
2.420
5.000
6.000
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD020 FT/H 4 1 68 4 2
GR MWD020 API 4 1 68 8 3
RPS MWD020 OHMM 4 1 68 12 4
RPM MWD020 OHMM 4 1 68 16 5
RPD MWD020 OHMM 4 1 68 20 6
FET MWD020 HOUR 4 1 68 24 7
Name
DEPT
ROP
GR
RPS
RPM
RPD
FET
Service Unit
FT
MWD020 FT/H
MWD020 API
MWD020 OHMM
MWD020 OHMM
MWD020 OHMM
MWD020 HOUR
Max
7258
708.42
134.65
2000
2000
2000
93.81
Min
3862
3.04
23.76
2.71
4.49
0.13
0.18
First Reading For Entire File......... .3862
Mean
5560
183.241
70.4177
12.1633
13.6368
14.239
4.91251
Nsam
6793
6461
6793
6757
6757
6757
6757
.
68.0
101.2
68.0
68.0
First
Reading
3862
4028
3862
3880
3880
3880
3880
Last
R<:=ading
7258
,7258
7258
7258
7258
7258
7258
.
Last Reading For Entire File.......... .7258
File Trailer
Service name.. ... ....... .STSLIB.002
Service Sub Level Name. . .
Version Number.......... .1.0.0
Date of Generation. ..... .05/11/14
Maximum Physical Record. .65535
File Type. . . . . . . . . . . . . . . . LO
Next File Name....... ....STSLIB.003
Physical EOF
File Header
Service name..... ....... .STSLIB.003
Service Sub Level Name...
Version Number.. ........ .1.0.0
Date of Generation...... .05/11/14
Maximum Physical Record. .65535
File Type............ ... .LO
Previous File Name... ... .STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
ROP
$
3
.
header data for each bit run in separate files.
9
.5000
START DEPTH
7258.5
STOP DEPTH
7303.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
$
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
08-JUN-05
Insite
66.37
Memory
7303.0
7258.0
7303.0
.0
76.0
TOOL NUMBER
8.500
3905.0
oil Based
9.00
92.0
.0
120000
.0
.000
.000
.000
.000
.0
102.0
.0
.0
.
#
HOLE CORRECTION (IN)
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type..................O
Data Specification Block Type.....O
Logging Direction.... ............ .Down
Optical log depth units.......... .Feet
Data Reference Point... .......... .Undefined
Frame Spacing..................... 60 .1IN
Max frames per record.. ...... .....Undefined
Absent value..................... .-999
Depth Units. . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
Name Service Order
DEPT
ROP MWD090
Name Service Unit
DEPT FT
ROP MWD090 FT/H
Units Size Nsam Rep Code Offset Channel
FT 4 1 68 0 1
FT/H 4 1 68 4 2
Min
7258.5
0.22
Max
7303
53.59
Mean
7280.75
25.2468
First Reading For Entire File......... .7258.5
Last Reading For Entire File.......... .7303
File Trailer
Service name............ .STSLIB.003
Service Sub Level Name. . .
Version Number.......... .1.0.0
Date of Generation...... .05/11/14
Maximum Physical Record. .65535
File Type. . . . . . . . . . . . . . . . LO
Next File Name.......... .STSLIB.004
Physical EOF
File Header
Service name............ .STSLIB.004
Service Sub Level Name. . .
Version Number.......... .1.0.0
Date of Generation...... .05/11/14
Maximum Physical Record. .65535
File Type. . . . . . . . . . . . . . . .LO
Previous File Name...... .STSLIB.003
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
NPHI
FCNT
NCNT
RHOB
PEF
DRHO
RPD
FET
4
Nsam
90
90
.
First
Reading
7258.5
7258.5
Last
Reading
7303
7303
header data for each bit run in separate files.
10
.5000
START DEPTH
7258.0
7258.0
7258.0
7258.0
7258.0
7258.0
7258.5
7258.5
STOP DEPTH
9647.0
9647.0
9647.0
9661.0
9661.0
9661.0
9693.5
9693.5
.
RPS
GR
RPM
CALA
RPX
ROP
$
7258.5
7258.5
7258.5
7259.0
7261.5
7303.5
9693.5
9701.0
9693.5
9647.5
9693.5
9736.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
CTN
ALD
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
COMP THERMAL NEUTRON
Azimuth. Litho-Den
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type............. ... ..0
Data Specification Block Type.....O
Logging Direction. . . . . . . . . . . . . . . . .Down
Optical log depth units.......... .Feet
Data Reference Point........ ..... . Undefined
Frame Spacing.................... .60 .1IN
Max frames per record............ . Undefined
Absent value..................... .-999
Deptl;t Units. . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
.
ll-JUN-05
Insite
66.37
Memory
9736.0
7303.0
9736.0
78.5
97.3
TOOL NUMBER
163686
125889
179954
10640599
8.500
3905.0
oil Based
9.00
73.0
.0
57000
3.1
.000
.000
.000
.000
.0
134.6
.0
.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD100 FT/H 4 1 68 4 2
GR MWD100 API 4 1 68 8 3
RPX MWD100 OHMM 4 1 68 12 4
RPS MWD100 OHMM 4 1 68 16 5
.
.
RPM MWD100 OHMM 4 1 68 20 6
RPD MWD100 OHMM 4 1 68 24 7
FET MWD100 HOUR 4 1 68 28 8
NPHI MWD100 PU-S 4 1 68 32 9
FCNT MWD100 CNTS 4 1 68 36 10
NCNT MWD100 CNTS 4 1 68 40 11
RHOB MWD100 G/CM 4 1 68 44 12
DRHO MWD100 G/CM 4 1 68 48 13
PEF MWD100 BARN 4 1 68 52 14
CALA MWD100 INCH 4 1 68 56 15
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 7258 9736 8497 4957 7258 9736
ROP MWD100 FT/H 0.02 339.19 172.677 4866 7303.5 9736
GR MWD100 API 40.95 119.19 69.6793 4886 7258.5 9701
RPX MWD100 OHMM 5.92 2000 107.552 4865 7261.5 9693.5
RPS MWD100 OHMM 5.98 2000 77.7259 4871 7258.5 9693.5
RPM MWD100 OHMM 6.19 1809.23 67.3016 4871 7258.5 9693.5
RPD MWD100 OHMM 6.61 2000 96.8859 4871 7258.5 9693.5
FET MWD100 HOUR 0.15 25.91 1.09843 4871 7258.5 9693.5
NPHI MWD100 PU-S 8.4 55.24 37.6628 4779 7258 9647
FCNT MWD100 CNTS 570 4150 945.416 4779 7258 9647
NCNT MWD100 CNTS 106744 203167 134723 4779 7258 9647
RHOB MWD100 G/CM 1.806 3.065 2.18872 4807 7258 9661
DRHO MWD100 G/CM -0.639 0.415 0.0513145 4807 7258 9661
PEF MWD100 BARN 0.55 12.04 2.01757 4807 7258 9661
CALA MWD100 INCH 8.43 10.03 8.78385 4778 7259 9647.5
First Reading For Entire File.... ......7258
Last Reading For Entire File.. ........ .9736
File Trailer
Service name..... ........STSLIB.004
Service Sub Level Name. . .
Version Number.......... .1.0.0
Date of Generation...... .05/11/14
Maximum Physical Record. .65535
File Type............... .LO
Next File Name.......... .STSLIB.005
Physical EOF
File Header
Service name. ........... .STSLIB.005
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .05/11/14
Maximum Physical Record..65535
File Type. . . . . . . . . . . . . . . . LO
Previous File Name...... .STSLIB.004
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
FCNT
NCNT
NPHI
CALA
RHOB
PEF
DRHO
RPX
5
header data for each bit run in separate files.
11
.5000
START DEPTH
9647.5
9647.5
9647.5
9648.0
9661.5
9661.5
9661.5
9694.0
STOP DEPTH
13438.0
13438.0
13438.0
13440.5
13452.0
13452.0
13452.0
13485.0
.
RPS
RPM
RPD
FET
GR
ROP
$
13485.0
13485.0
13485.0
13485.0
13492.5
13530.5
96 94 . 0
96 94 . 0
9694.0
9694.0
9701.5
9736.5
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
CTN
ALD
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
COMP THERMAL NEUTRON
Azimuth. Litho-Den
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type. . . . . . . . . . . . . . . . . .0
Data Specification Block Type.....O
Logging Direction. . . . . . . . . . . . . . . . . Down
Optical log depth units.......... .Feet
Data Reference Point.... ......... . Undefined
Frame Spacing..................... 60 .1IN
Max frames per record............ . Undefined
Absent value. . . . . . . . . . . . . . . . . . . . . . -999
Depth Units. . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block .sub-type...O
.
14-JUN-05
Insite
66.37
Memory
13530.0
9736.0
13530.0
86.6
98.6
TOOL NUMBER
149206
127479
179954
10640599
8.500
7524.0
Oil Based
9.00
75.0
.0
46000
.0
.000
.000
.000
.000
.0
135.0
.0
.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWDllO FT/H 4 1 68 4 2
GR MWDllO API 4 1 68 8 3
RPX MWD110 OHMM 4 1 68 12 4
RPS MWDllO OHMM 4 1 68 16 5
.
.
RPM MWD11 0 OHMM 4 1 68 20 6
RPD MWD11 0 OHMM 4 1 68 24 7
FET MWD11 0 HOUR 4 1 68 28 8
NPHI MWD11 0 PU-S 4 1 68 32 9
FCNT MWDII0 CNTS 4 1 68 36 10
NCNT MWD110 CNTS 4 1 68 40 11
RHOB MWD11 0 G/CM 4 1 68 44 12
DRHO MWD110 G/CM 4 1 68 48 13
PEF MWDII0 BARN 4 1 68 52 14
CALA MWDII0 INCH 4 1 68 56 15
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 9647.5 13530.5 11589 7767 9647.5 13530.5
ROP MWDII0 FT/H 0.13 487.52 212.091 7589 9736.5 13530.5
GR MWDII0 API 48.96 124.56 74.7604 7583 9701. 5 13492.5
RPX MWD11 0 OHMM 6.62 166.05 37.1914 7583 9694 13485
RPS MWDII0 OHMM 6.69 136.25 37.8932 7583 9694 13485
RPM MWD11 0 OHMM 6.55 141. 6 39.4193 7583 9694 13485
RPD MWD11 0 OHMM 6.61 146.74 43.1969 7583 9694 13485
FET MWDII0 HOUR 0.1 30.8 0.955177 7583 9694 13485
NPHI MWD11 0 PU-S 11 44.45 35.7403 7582 9647.5 13438
FCNT MWDII0 CNTS 703 4007 987.526 7582 9647.5 13438
NCNT MWDII0 CNTS 117900 202685 136943 7582 9647.5 13438
RHOB MWD 11 0 G/CM 2 2.723 2.22136 7582 9661.5 13452
DRHO MWDII0 G/CM -0.058 0.308 0.053686 7582 9661.5 13452
PEF MWDII0 BARN 0.73 5.3 2.08673 7582 9661.5 13452
CALA MWDII0 INCH 8.44 9.62 8.83412 7586 9648 13440.5
First Reading For Entire File......... .9647.5
Last Reading For Entire File.......... .13530.5
File Trailer
Service name. ........... .STSLIB.005
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .05/11/14
Maximum Physical Record. .65535
File Type......... ...... .LO
Next File Name....... ....STSLIB.006
Physical EOF
Tape Trailer
Service name............ .LISTPE
Date.................... .05/11/14
Origin.................. .STS
Tape Name............... . UNKNOWN
Continuation Number..... .01
Next Tape Name.......... . UNKNOWN
Comments......... ... .... .STS LIS Writing Library. Scientific Technical Services
Reel Trailer
Service name............ .LISTPE
Date........ ............ .05/11/14
Origin. . . . . . . . . . . . . . . . . . . STS
Reel Name............... .UNKNOWN
Continuation Number..... .01
Next Reel Name.......... . UNKNOWN
Comments................ .STS LIS Writing Library. Scientific Technical Services
Physical EOF
Physical EOF
End Of LIS File
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