Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout197-1451a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test
2.Operator Name:6.Date Comp., Susp., or 14.Permit to Drill Number / Sundry:
Aband.:
3. Address: 7.Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8.Date TD Reached: 16.Well Name and Number:
Surface:
Top of Productive Interval: 9.Ref Elevations: KB: 17.Field / Pool(s):
GL: N/A BF: N/A
Total Depth: 10.Plug Back Depth MD/TVD: 18.Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5.Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 (ft MSL)
22.Logs Obtained:
23.
BOTTOM
33" - 229'
26" - 306'
13-3/8" K-55 1,318'
9-5/8" P-110 4,091'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
L - 458 bbls / T - 37 bbls12-1/4"
TUBING RECORD
N/A
SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
L - 299 bbl / T - 49.3 bbls
Cond
Surface 306' Driven
Driven
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
9/14/2019
2437' FNL, 1303' FWL, Sec 13, T10N, R12W, SM, AK
962' FSL, 232' FWL, Sec 13, T10N, R12W, SM, AK
197-145
Granite Point Field / Middle Kenai Oil Pool
132'
4,997' MD / 4,091' TVD
HOLE SIZE AMOUNT
PULLED
50-733-20479-00-00
Granite Point 55
263339 2544494
N/A
CEMENTING RECORD
N/A
SETTING DEPTH TVD
2542643
BOTTOM TOP
17-1/2"
Surface
CondSurface
CASING WT. PER
FT.GRADE
54#
N/A
262221
TOP
SETTING DEPTH MD
Surface
Surface
Per 20 AAC 25.283 (i)(2) attach electronic information
68#
4,997'
Surface
Surface
DEPTH SET (MD) PACKER SET (MD/TVD)
-
-
229'
Surface 1,318'
Gas-Oil Ratio:Choke Size:Water-Bbl:
PRODUCTION TEST
N/A
Date of Test:
Flow Tubing
Oil-Bbl:
suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray,
caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation
record. Acronyms may be used. Attach a separate page if necessary
N/A
N/A
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
August 24, 1997
August 19, 1997
ADL018761
LOCI 19-001
N/A
4,997' MD / 4,091' TVD75
N/A
5,011' MD / 4,100' TVD
WINJ
SPLUG Other Abandoned Suspended
Stratigraphic Test
No
No
(attached) No
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
By Samantha Carlisle at 9:19 am, Nov 03, 2020
/319-360
HEW
RBDMS HEW 11/5/2020
Abandonment Date
9/14/2019
HEW
xG
Abandoned
gls 12/12/20
SFD 11/5/2020
DLB11/5/20
DSR-11/5/2020
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Top of Productive Interval N/A
Mid Kenai
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Cody Dinger
Contact Email:cdinger@hilcorp.com
Authorized Contact Phone: 777-8389
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
Authorized Name: Monty Myers
Authorized Title: Drilling Manager
Permafrost - Base
29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS
Permafrost - Top
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
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.
TPI (Top of Producing Interval).
Yes No
Well tested? Yes No
28. CORE DATA
If yes, list intervals and formations tested, briefly summarizing test results.
Attach separate pages to this form, if needed, and submit detailed test
information, including reports, per 20 AAC 25.071.
NAME
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Formation at total depth:
Wellbore Schematic, P&A report.
Signature w/Date:
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
INSTRUCTIONS
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
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).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
No
NoSidewall Cores: Yes No
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2020.11.03 09:13:26 -09'00'
Monty M
Myers
Updated by CJD 11/3/2020
Granite Point Field
Well Name: GP-55
P&A Date: 9/14/2019
PTD: 197-145
API: 50-733-20479-00
P&A SCHEMATIC
Size Type Wt/ Grade Top Btm CONN ID Cement/Other
33” Conductor Surf 229’ Driven
26” Conductor Surf 306’ Driven
13-3/8” Surface 68#, K-55 Surf 1,318’ BTC 12.415”
299bbl 12.9ppg
lead, 49.3bbl
15.8ppg tail
9-5/8” Production 53.5#, P-
110 Surf 4,997’ BTC 8.535”
458bbl 12.9ppg
lead, 37bbl
15.8ppg tail
Drill GP55RD
Activity Date Ops Summary
6/23/2019 Remove dry hole tree, N/U riser to well head. N/U Mud Cross, Double gate BOPE and Annular to riser.;Rig up jacks and skid rig over well GP-55. Run power
cable and connect same to Accumulator building.
06/24/19 Witness of Initial BOP test verbally waived by Jim Regg 06/23/19 @ 16:02.;PJSM. Raise and scope up mast. R/U floor, beaver slide, stairs etc. R/U
Accumulator hoses.;Build 3.5" test joint, attempt shell test of BOPE, chase leaks. Fill pits with FIW
6/24/2019 Complete tightening of hub flange on riser. Shell test BOPE w/ 2500 psi.;Test BOPE as per AOGCC & Hilcorp requirements. AOGCC witness waived by Jim
Regg 6-23-19 @ 16:02 hr. Test w/ 3.-1/2" test jt. Bag 250 low / 2500 high. Blind rams, pipe rams, ck. & kill line valves & ck. manifold 250 low / 3500 high.
Function test accumulator, manual & remote ck. valves . Good Test.;Pull test plug and rig down test equipment.;HPU down with bad wire. C/O units and swap
hoses to new unit.;Break down test joint and valves with HawkJaw.;L/D test joint and load pipe in Beaver slide. Crane Swapping out full ISO tanks with empties off
of boat between loads.;P/U 9-5/8" scraper assembly, 8.5" bit and RIH picking up 3-1/2 in. 12.95# PH-6 work string;Fix hydraulic leak on accumulator hose, fitting
leaking on kill line. Replace hose;RIH picking up 3-1/2 in. 12.95# PH-6 work string to 3430FT. Stop at 2500Ft and establish reverse circulation. Continue to
check reverse circulation every 20 joints, check up and down weight every 10 joints;RIH picking up 3-1/2 in. 12.95# PH-6 work string from 3430FT to 4,864'.
Tagged plug R/U to circulate out WBM and swap to FIW
6/25/2019 PJSM with all parties involved on displacing WBM to ISO tanks with FIW.;Reverse circulate out 9.6# WBM w/FIW taking returns to ISO tanks. Initial circulating
pressure 1150 psi @ 3 bpm, at highest pressure was 1840 psi @ 2.2 bpm. Final pressure was 490 psi @ 4 bpm.;Waiting on tide to swap out ISO tank on boat.
Service rig and rig up to test casing while waiting.;Complete displacement of 9.6# WBM w/ FIW. 670 psi @ 5 bpm.;POOH to 4761';Set up test pump, fluid pack
well and begin pressuring up for casing test.;Test 9-5/8 casing to 3500 psi for 30 minutes - Charted. Good Test;POOH laying down 3-1/2" work string. L/D 9 5/8"
scraper and 8.5" bit;Clean and clear the rig floor. R/D wind walls, stairs, rig floor, beaver slide. R/D accumulator lines and checked pre-charge pressures in
accumulator bottles. Prep for scoping down derrick;Scope derrick down to half mast. Skid rig 12ft north to allow access to GP-52 with crane;N/D GP-52 wellhead
and remove tree with crane;N/D BOPE from GP-55 and N/U to GP-52;N/U Wellhead on GP-55. R/U Accumulator, choke, and kill lines. Fluid pack wellhead for
test;R/U and test wellhead to 1500 psi
9/13/2019 Prep and move rig f/GP-53RD to GP-55RD.;N/D Dry Hole tree from well head. Install 13-5/8" 5K Hub by 11" 5K Flange adapter spool.;Land riser w/ 11” 5 k X 13-
5/8” 10 k DSA on wellhead adapter spool and M/U bolts on same.;Set BOP on riser and M/U bolts on same. Install bell nipple. Check hub and all flange bolts
again after BOP's in place.;Change out Top Drive saver sub, lower IBOP valve and dies in "grabber". Re-sequence hydraulics to break out, had to C/O 2 of 4
sequencing cartridges. C/O swivel pkg. Simultaneously cleaning starb. flow trough.;Clean 5" liner run tools from last well, make ready ship to beach, clean and
clear rig floor all unecessary equipment, clean wellhead room, clean trough to shakers, C/O shaker screens to 170s.;P/U 8-3/8 c lean out BHA, stand back in
mast.;M/U test plug in prep for BOP test.
9/14/2019 R/U and shell test BOPE w/ 3500 psi- Good Test, Checked accumulator bottles pressures and calibrated gas alarm sensors.;Straighten and clean up rig floor
while waiting on Brian Bixby w/ AOGCC to arrive to witness initial BOP test.;Test BOPE per Hilcorp, Spartan and AOGCC standards. Test Rams, Valves and
Annular to 250 psi low / 3500 psi high f/ 5 min each on chart. Perform function test on Accumulator, PVT and gas detector alarms, manual and both hyd. chokes.
No Failures. Witnessed by AOGCC Inspector Brian Bixby.;R/D test equipment and clear rig floor of same.;Install wear bushing .;R/U and M/U 8-3/8" clean out
BHA, P/U 3 jt. 5" HWDP and 12 jt. 5" DP. Continue to RIH w/ 5" pipe out of the derrick, tag up at 4875 ft.;PJSM all personnel including GP platform foreman.
Topic: Displace wellbore OBM, contingencies and possible hazards.;Commence displace 9-5/8 wellbore to OBM. Total 301 bbls, linear pressures, no stops or re-
starts. Fluids balanced DP and annulus.;PJSM, test 9-5/8 csg 2500 psi - 10 min. Test successful, no re-tests.;Drill cmt and float equip 4875 - 5031 ft. Hard, dense
cement.;Drill ahead 8-3/8 hole new formation for FIT, 5031 - 5044 ft.
n (LAT/LONG):
evation (RKB):
API #:
Well Name:
Field:
County/State:
GPF GP-55
Granite Point
Hilcorp Energy Company Composite Report
, Alaska
Contractor
AFE #:
AFE $:
Job Name:1911669D GP-55RD Drilling
Spud Date:
-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
py pgp
Replace hose;RIH picking up 3-1/2 in. 12.95# PH-6 work string to 3430FT.
gp p
;Test 9-5/8 casing to 3500 psi for 30 minutes
pp
Drill cmt and float equip 4875 - 5031 ft. Hard, densegp
cement.;Drill ahead 8-3/8 hole new formation for FIT, 5031 - 5044 ft.
yj p
Tagged plug R/U to circulate out WBM and swap to FIW
pgg
;Test BOPE per Hilcorp, Spartan and AOGCC standards.
ppg
Witnessed by AOGCC Inspector Brian Bixby.
Prep and move rig f/GP-53RD to GP-55RD.;N---------------------------------------------------------
Spartan 151
gp
;Commence displace 9-5/8 wellbore to
note: Drill through shoe track in 9 5/8" to start new well GP 55RD. PTD 219-103
Rig 404 prep for sidetrack
R/U and shell test BOPE w/ 3500 psi- Good
06/24/19 Witness of Initial BOP test verbally waived by Jim Regg 06/
;Test BOPE as per AOGCC & Hilcorp requirements.
rig 404
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
Monty Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Re: Granite Point Field, Middle Kenai Oil Pool, Granite Point 55
Permit to Drill Number: 197-145
Sundry Number: 319-360
Dear Mr. Myers:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
W .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,
&1/-�
Daniel T. Seamount, Jr.
Commissioner
DATED this _ day of August, 2019.
RBDMS � AUG 13 2019
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
RECEIVED
AUG 0 5 2019
1. Type of Request: Abandon Q ' Plug Perforations
❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑
Suspend ❑ Perforate
❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
Plug for Redrill ❑ Perforate New Pool
❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Drill out existing csgQ
2. Operator Name:
4. Current Well Class: .
5. Permit to Drill Number:
Hilcorp Alaska, LLC
Exploratory ❑ Development Q
Stratigraphic ❑ Service ❑
r
197-145
3. Address:
6. API Number:
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
50-733-20479-00-00
7. If perforating:
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
Granite Point 55
9. Property Designation (Lease Number):
10. Field/Pool(s):
ADLO18761
Granite Point Field /Middle Kenai Oil Pool
it. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
5,011' 4,100' 4,864' 4,007' N/A N/A N/A
Casing Length Size MD TVD Burst Collapse
Structural 229' 33" 229' 229'
Conductor 306 26" 306' 306'
Surface 1,318' 13-3/8" 1,318' 1,318' 3450 psi 1950 psi
Intermediate 4,997' 9-5/8'. 4,997' 4,091' 10900 psi 7950 psi
Production
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
N/A
N/A
N/A
N/A
N/A
Packers and SSSV Type: N/A
Packers and $SSV MD (ft) and TVD (ft): N/A
12. Attachments: Proposal Summary Q Wellbore schematic ❑✓
13. Well Class after proposed work: _
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stratigraphic ❑ Development Q Service ❑
14. Estimated Date for
15. Well Status after proposed work:
Commencing Operations: 8/26/2019
OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑
GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
16. Verbal Approval: Date:
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned Q '
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: Monty Myers Contact Name: Monty Myers
Authorized Title: Drilling Manager Contact Email: MMyerS0bhjIcorD.com
Contact Phone: 777-8431
Authorized Signature: Date: S • D f / y
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number: / O
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑
Other:
Post Initial Injection MIT Req'd? Yes ❑ No ❑
3
j�BDMSg06 1
Spacing Exception Required? Yes ❑ No Subsequent Form Required: 2019
APPROVED BY CJl / O /
if
Approved by: COMMISSIONER THE COMMISSION Date: lJ ` o
F r 10-403 Rev�'SEd 42017 Approved pp application is v►Iftl R1 J3t1s Trdhrth! L of a Submit Form and
pp pproval. � Attachments in Duplicate
8r l )YPA 816/rq
H
Hilcorp
Encs Compmy
f WAW
Monty Myers
Drilling Engineer
Commissioner
Alaska Oil & Gas Conservation Commission
333 W. 7th Avenue
Anchorage, Alaska 99501
Re: GP -55
Dear Commissioner,
Hilcorp Alaska, LLC
P.O. Box 244027
Anchorage, AK 99524-4027
Tel 907 777 8431
Email mmyers@hilcorp.com
The purpose of the attached Sundry is to properly and administratively abandon GP -55. A permit to
drill has been issued for GP-55RD (PTD #219-103).
General sequence of operations pertaining to this sundry:
1. Spartan 151 will be skid over (GP 55).
2. NU BOPE and test.
3. RIH with clean out assembly and swap well to 9.0 ppg oil based drilling mud
4. Drill shoe 20' of new formation at 5,014'.
Operations are expected to commence 8/26/19.
If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at
777-8369.
Sincerely,
Monty Myers
Drilling Engineer
Hilcorp Alaska, LLC Page 1 of 1
WB : 43.44'.
26" @
r '
i
13a8'@
1,318'
5,011'
PBTD=4,8MrVD(4,00T TVD)
TD=5,011 VD(4,100'TVD)
Directional Data:
max hole angle = 51.3°
SCHEMATIC
Granite Point Field
Well Name: GP -55
Completion Date: 8/26/1997
PTD: 197-145
API: 50-733-20479-00
Size
Type
Wt/ Grade
Top
Btm
CONN
ID
Cement/Other
33"
Conductor
Surf
229'
Driven
26"
Conductor
Surf
306'
Driven
2991bbl 12.9ppg
13-3/8"
Surface
68#, K-55
Surf
1,318'
BTC
12.415"
lead, 49.3bbl
15.8ppg tail
53.5#, P-
458bbl 12.9ppg
9-5/8"
Production
110
Surf
4,997'
BTC
8.535"
lead, 37bbl
15.8ppg tail
Updated by AL 07/17/2019
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Abandon LJ Plug Perforations Ll Fracture Stimulate LJ Pull Tubing LJ Operations shutdown Li
Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑
Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other: C/O Int casing for redrill ❑✓
2. Operator
4. Well Class Before Work:
5. Pernit to Drill Number:
Name: Hilcorp Alaska, LLC
Development ❑Q Exploratory ❑
Stratigraphic ❑ Service ❑
197-145
3. Address: 3800 Centerpoint Drive, Suite 1400
6. API Number:
Anchorage, AK 99503
50-733-20479-00-00
7. Property Designation (Lease Number):
8. Well Name and Number:
ADL0018761
Granite Point 55
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):
10. Field/Pool(s):
N/A
Granite Point Field / Middle Kenai Oil Pool
11. Present Well Condition Summary:
Total Depth measured 5,011 feet Plugs measured N/A feet
true vertical 4,100 feet Junk measured N/A feet
Effective Depth measured 4,864 feet Packer measured N/A feet
true vertical 4,007 feel true vertical N/A feet
Casing Length Size MD TVD Burst Collapse
Conductor 229' 33" 229' 229'
Conductor 306' 26" 306' 306'
Surface 1,318' 13-3/8" 1,318' 1,318' 3,450 psi 1,950 psi
Intermediate
Production 4,997' 9-5/8" 4,997' 4,091' 10,900 psi 7,950 psi
Liner
Perforation depth Measured depth N/A feet
True Vertical depth N/A feet
Tubing (size, grade, measured and true vertical depth) NIA
Packers and SSSV (type, measured and true vertical depth) N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
N/A
Treatment descriptions including volumes used and final pressure:
N/A
13. Representative Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation: 0 00 27 27
Subsequent to operation: 0 0 0 0 0
14. Attachments (required per 20 AAc 25.070, 25.071, &25.283)
15. Well Class after work:
Daily Report of Well Operations El
Exploratory ❑ Development Service ❑ Stratigraphic ❑
16. Well Status after work: Oil Gas ❑ WDSPL ❑
Copies of Logs and Surveys Run ❑
Printed and Electronic Fracture Stimulation Data ❑
GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP Q SPLUG ❑
17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
319-270
Authorized Name: Stan W. Golis Contact Name: Dan Marlowe
Authorized Title: Operations Manager Contact Email: dmadowePhilcom.com
tk'� A� Date: � Contact Phone: (907)283-1329
Authorized Signature:
Form 10-404 Revised 4/2017 , ,/RMS- '/JUL Z 3 2019 Submit Original Only
ff
Hileory Alaska, LLC
WIN
33" @
229
26 @
306
13-3'8 @
1.318'
SCHEMATIC
Granite Point Field
Well Name: GP -55
Completion Date: 8/26/1997
PTD: 197-145
API: 50-733-20479-00
Size
Type
Wt/ Grade
Top
Btm
I CONN
ID
Cement/Other
33"
Conductor
Surf
229'
Driven
26"
Conductor
Surf
306'
Driven
2991bbl 12.9ppg
13-3/8"
Surface
68#, K-55
Surf
1,318'
BTC
12.415"
lead, 49.3bbl
15.8ppg tail
458bbl 12.9ppg
9-5/8"
Production
53.5#, P-
Surf
4,997'
BTC
8.535"
lead, 37bbl
110
15.8ppg tail
PE0D=A864'ND(4,00T TVD)
TD=5,011'ND(4,1W TVD)
Directional Data:
max hole angle
Updated by JLL 07/17/2019
Hilcorp Alaska, LLC
Well Operations Summary
Well Name Rig
API Number
Well Permit Number
Start Date End Date
Granite Pt St 55 HAK 404
1 50-733-20479-00-00
1 197-145
6/23/19 1 6/25/19
Daily Operations:
06/23/19 -Sunday
Remove dry hole tree, N/U riser to well head. N/U Mud Cross, Double gate BOPE and Annular to riser. Rig up jacks and
skid rig over well GP -55. Run power cable and connect same to Accumulator building. 06/24/19 Witness of Initial BOP
test verbally waived by Jim Regg 06/23/19 @ 16:02. PJSM. Raise and scope up mast. R/U floor, beaver slide, stairs etc.
R/U Accumulator hoses. Build 3.5" test joint, attempt shell test of BOPE, chase leaks. Fill pits with FIW.
06/24/19 - Monday
Complete tightening of hub flange on riser. Shell test BOPE w/ 2500 psi. Test BOPE as per AOGCC & Hilcorp
requirements. AOGCC witness waived by Jim Regg 6-23-19 @ 16:02 hr. Test w/ 3-1/2" test jt. Bag 250 low / 2500 high.
Blind rams, pipe rams, ck. & kill line valves & ck. manifold 250 low / 3500 high. Function test accumulator, manual &
remote ck. valves . Good Test. Pull test plug and rig down test equipment. HPU down with bad wire. C/O units and swap
hoses to new unit. Break down test joint and valves with HawkJaw. L/D test joint and load pipe in Beaver slide. Crane
Swapping out full ISO tanks with empties off of boat between loads. P/U 9-5/8" scraper assembly, 8.5" bit and RIH
picking up 3-1/2 in. 12.95# PH -6 work string. Fix hydraulic leak on accumulator hose, fitting leaking on kill line. Replace
hose. RIH picking up 3-1/2 in. 12.95# PH -6 work string to 3430FT. Stop at 2500Ft and establish reverse circulation.
Continue to check reverse circulation every 20 joints, check up and down weight every 10 joint. RIH picking up 3-1/2 in.
12.95# PH -6 work string from 3430FT to 4,864'. Tagged plug R/U to circulate out WBM and swap to FIW.
06/25/19 -Tuesday
PJSM with all parties involved on displacing WBM to ISO tanks with FIW. Reverse circulate out 9.6# WBM w/FIW taking
returns to ISO tanks. Initial circulating pressure 1150 psi @ 3 bpm, at highest pressure was 1840 psi @ 2.2 bpm. Final
pressure was 490 psi @ 4 bpm. Waiting on tide to swap out ISO tank on boat. Service rig and rig up to test casing while
waiting. Complete displacement of 9.6# WBM w/ FIW. 670 psi @ 5 bpm. POOH to 4761'. Set up test pump, fluid pack
well and begin pressuring up for casing test. Test 9-5/8 casing to 3500 psi for 30 minutes ; Charted. Good Test. POOH
laying down 3-1/2" work string. L/D 9 5/8" scraper and 8.5" bit. Clean and clear the rig floor. R/D wind walls, stairs, rig
floor, beaver slide. R/D accumulator lines and checked pre -charge pressures in accumulator bottles. Prep for scoping
down derrick. Scope derrick down to half mast. Skid rig 12ft north to allow access to GP -52 with crane. N/D GP -52
wellhead and remove tree with crane. N/D BOPE from GP -55 and N/U to GP -52. N/U Wellhead on GP -55. R/U
Accumulator, choke, and kill lines. Fluid pack wellhead for test. R/U and test wellhead to 1500 psi.
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
Stan W. Golis
Operations Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Re: Granite Point Field, Middle Kenai Oil Pool, Granite Point 55
Permit to Drill Number: 197-145
Sundry Number: 319-270
Dear Mr. Golis:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.00gcc.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,
Daniel T. Seamount, Jr.
Commissioner
DATED this�q&ay of May, 2019.
RBDMSI*' MAY 3 0 2019
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
MAY 2 8 2019
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
t
❑ ❑ v ❑ Other: C/O ace casino ❑�
Plug for Redrill ❑
Perforate New Pool Re-enter Susp Well Alter Casing for reda L
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
Hilcorp Alaska, LLC
Exploratory ❑ Development Q •
Stratigraphic ❑ Service ❑
197-145
3. Address: 3800 Centerpoint Drive, Suite 1400
6. API Number:
Anchorage, AK 99503
50-733-20479-00-00
7. If perforating:
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 ❑�
Granite Point 55
9. Property Designation (Lease Number):
10. Field/Pool(s):
ADL0018761
Granite Point Field / Middle Kenai Oil Pool
it. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
5,011 4,100 4,864 4,007 1,599 psi N/A N/A
Casing Length Size MD TVD Burst Collapse
Conductor 229' 33" 229' 229'
Conductor 306' 26" 306' 306'
Surface 1,318' 13-3/8" 1,318' 1,318' 3,450 psi 1,950 psi
Intermediate
Production 4,997' 9-5/8" 4,997' 4,091' 10,900 psi 7,950 psi
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
N/A
N/A
N/A
N/A
N/A
Packers and SSSV Type:
Packers and SSSV MD (ft) and TVD (ft):
N/A
N/A
12. Attachments: Proposal Summary Q Wellbore schematic
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑�
Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑
14. Estimated Date for
15. Well Status after proposed work:
Commencing Operations: 6/15/2019
OIL ❑ WINJ ❑ 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: Stan W. Golis Contact Name: Dan Marlowe
Authorized Title: Operations Manager Contact Email: dmarlowe hilcor .Com
Contact Phone: (907) 283-1329
�i
Authorized Signature: r.� d`•�-• Date: N4
COMMISSION USE ONLY
6
Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �t l Z-7
—7 y
/✓,
Plug Integrity ❑ BOP Test [/ Mechanical Integrity Test E-1Location Clearance ❑
�
Other: 7r 3S�O� �Sc_ �Ql
Post Initial Injection MIT Req'd? RBDMS N�MAY 3 0 2019
Yes ❑ No ❑ l�qq �/
Ll
Spacing Exception Required? Yes El No Subsequent Form Required: V — O
APPROVED BY
Approved IbYZIZ55��, COMMISSIONER THE COMMISSION Date: 51 2-T I %
#/n"�Y,��� (,,,'� S�� • 7 (' 1 Submit Form and
d _0403 Revise 4/20n Approved appl ation4/VV /// 1 f r t I Ape data of approval. e is in plicate
UUUV 4r � C-ZL5-/
H
Hflmrp AWkw LLC
Well Work Prognosis
Well Name:
Granite Point GP -55
API Number:
50-733-20479-00
Current Status:
Suspended
Leg:
Leg #4
Estimated Start Date:
June 15, 2019
Rig:
HAK 404
Reg. Approval Req'd?
403
Date Reg. Approval Rec'vd:
Regulatory Contact:
Juanita Lovett (8332)
Permit to Drill Number:
197-145
First Call Engineer:
Dan Marlowe
(907) 283-1329 (0)
(907) 398-9904 (M)
Second Call Engineer:
Stan Golis
(907) 777-8356 (0)
(281) 450-3071 (M)
Current Bottom Hole Pressure: 2,000 psi @ 4,006' TVD 0.499 lbs/ft (9.6 ppg) Based on current mud weight
Maximum Expected BHP: 2,000 psi @ 4,006' TVD 0.499 lbs/ft (9.6 ppg) Based on current mud weight
Maximum Potential Surface Pressure: 1,599 psi Using 0.1 psi/ft gradient per 20AAC25.280(b)(4)
Brief Well Summary
GP -55 was drilled in August 1997 to a total depth of 5,011' (4,100' TVD). The 13-3/8" surface casing was
cemented to surface and the 9-5/8" intermediate casing was set at 4.997' and cemented with 1,415
sacks of cement. A bit was ran in the well and tagged cement at 4,864'. The well was then suspended
without a CBL being ran. This project will clean out the surface casing in preparation for the jack-up drill
well program scheduled for this summer.
Last Casing Test:
N/A
Procedure:
Phase I
1. MIRU Rig HAK-404.
2. Monitor well to ensure it is static. FIW will be circulated as necessary to balance well, BOP's
will be closed as needed to circulate the well.
3. ND Wellhead.
4. NU BOP and test to 250psi low/3,50Opsi high. (Note: Notify AOGCC 48 hours in advance of
test to allow them to witness test).
5. Monitor well to ensure it is static.
6. Pickup workstring and RIH with cleanout assembly to +/-4,864' (top of cement).
7. Displace well to clean FIW.
wh c 8. Pressure test 9-5/8" to 3,500 psi for 30 minutes, chart test.
`- 9. POOH.
10. ND BOPE and NU dry hole tree and test.
11. Rig down.
12. RU E -line. RIH with CBL / GR tool to 4,800'. Log well to surface. RD E -line.
13. Suspend operations until drilling rig moves on location.
'Remaining Procedure to be included on the Permit to Drill for the sidetrack'
Phase II
General sequence of operations pertaining to drilling procedure: (informational only)
KWell Work Prognosis
Hikoq I. Ax, LLC
14. Resume operations with drilling rig.
15. MIRU drilling rig.
16. Monitor well to ensure it is static.
17. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 48 hours
in advance of test to allow them to witness test).
18. PU Drilling BHA and RIH to TOC.
19. Swap well to drilling fluid.
20. Drill 20' of new hole.
21. Swap to drilling PTD.
Attachments:
1. Well Schematic Current
2. Well Schematic Proposed
3. Wellhead Schematic Current
4. BOP Drawing— HAK 404
5. Fluid Flow Diagrams — HAK 404
6. RWO Sundry Revision Change Form
R
Hilrora Alaska, LLC
33" @
26„ @ .�
3os'
1338" @
1,318'
k
r1
ti
9.6 ppg
6,01'
PSID=4,864'ND(4,00T TVD)
TD=5,011'ND(4,100' TVD)
Directional Data:
max hole angle = 51.30 @ 4,667'
SCHEMATIC
Granite Point Field
Well Name: GP -55
Completion Date: 8/26/1997
PTD: 197-145
API: 50-733-20479-00
Size
Type
WUGrade
Top
Btm
CONN
ID
Cement/Other
33"
Conductor
Surf
229'
Driven
26"
Conductor
Surf
306'
Driven
299bbl 12.9ppg
13-3/8"
Surface
68#, K-55
Surf
1,318'
BTC
12.415"
lead, 49.3bb1
15.8ppg tail
535#, P-
.
458bbl 12.9ppg
9-5/8"
Production
110
Surf
4,997'
BTC
8.535"
lead, 37bbl
15.8ppg tail
Updated by JILL 05/24/19
33
229'
26'
306'
H
Nilmrp Alaska, LLC
1338" a
1,318'
5,011'
5.01'
PEnD= 4,864'ND (4,o0T TVD)
TD=5,(nl'ND(AlW TW)
Directional Data:
max hole angle
PROPOSED
Granite Point Field
Well Name: GP -55
Completion Date: 8/26/1997
PTD: 197-145
API: 50-733-20479-00
Size
Type
WY Grade
Top
Btm
CONN
ID
Cement/Other
33"
Conductor
Surf
229'
Driven
26"
Conductor
Surf
306'
Driven
299bbl 12.9ppg
13-3/8°
Surface
68#, K-55
Surf
1,318'
BTC
12.415"
lead, 49.3bbl
15.8ppg tail
53.5#, P-
458bb1 12.9ppg
9-5/8"
Production
110
Surf
4,997'
BTC
8.535"
lead, 37bbl
15.8ppg tail
Updated by JILL 05/24/19
R
Hiin rp Al ... ka. l.L(:
Unihead, National
SMS, 3 step system,
13 5/8 SM API Hub
top X 13 3/8 BTC
casing bottom, w/ 2-
2" LPO,
4- 2 1/16 SM SSO
Granite Point Platform
GPP-55 Current
06/24/2015
H
Hilrv,rp Alueka, MA:
BOP Stack
HAK 404
5.5
eea
I valves
M
RIG #404
FLUID FLOW DIAGRAM
NORMAL OPERATIONS
CIRCULATING DOWN TUBING, UP CASING ANNULAS
"THE LONG WAY"
STANDPIPE
PANIC
r-19LINE
RIG FLOOR #,2
SUPER #S
CHOKE
3 STRIPPER #3 ys #7 #�O
HEAD II
MUD
#4 #2 PUMP STOCK #4 1T #6 #T
#1 #, MANUAL)
`\ CHOKE
C `HCR
LP VALVE
SUCTION #�
GAS LINE
BUSTER
FLUID TANK/PIT
Valve Position
o/c)
Standpipe Pump Manifold l(PM1I 0
Manifold Pump Manifold 21PM21 C
Pump Manifold 3 PING) O
Pump Manlfold0(PM4I C
Pump Manifold 5IPM61 O
Mud
Kill Line O
Cross Kill Line O
HCR valve (Choke Line l) C
Choke Line 0
Choke Choke Manifold 1(CMl) 0
Manifold Choke Manifold 21CM2) C
Choke Manifold 31CM3) 0
Choke Manifold 41CM41 C
Choke Manifold ICMS) 0
Choke Manifold 61CM6) C
Choke Manifold ] ICM71 0
Choke Manifold
elCM81
C
Choke Manifoltl 91CM91
[
Choke Manifold 101CM10)
0
Super Choke
[
Manual Choke
C
Rig Floor
Safety Valve
O
RIG #404
FLUID FLOW DIAGRAM
NORMAL OPERATIONS
CIRCULATING DOWN TUBING, UP CASING ANNULAS
"THE LONG WAY"
STANDPIPE
PANIC
r-19LINE
RIG FLOOR #,2
SUPER #S
CHOKE
3 STRIPPER #3 ys #7 #�O
HEAD II
MUD
#4 #2 PUMP STOCK #4 1T #6 #T
#1 #, MANUAL)
`\ CHOKE
C `HCR
LP VALVE
SUCTION #�
GAS LINE
BUSTER
FLUID TANK/PIT
Valve Position
o/c)
Standpipe Pump Manifold l(PM1I 0
Manifold Pump Manifold 21PM21 C
Pump Manifold 3 PING) O
Pump Manlfold0(PM4I C
Pump Manifold 5IPM61 O
Mud
Kill Line O
Cross Kill Line O
HCR valve (Choke Line l) C
Choke Line 0
Choke Choke Manifold 1(CMl) 0
Manifold Choke Manifold 21CM2) C
Choke Manifold 31CM3) 0
Choke Manifold 41CM41 C
Choke Manifold ICMS) 0
Choke Manifold 61CM6) C
Choke Manifold ] ICM71 0
Choke Manifold
Valve Position
RIG #404 (DSC)
Standpipe Pump Manifold 11PM1) 0
FLUID FLOW DIAGRAM Manifold Pump Manifold 2(PM2) 0
NORMAL OPERATIONS Pump Manifold 3(PM3) C
Pump Manifold 4(PM4( 0
CIRCULATING DOWN CASING, UP TUBING Pump Manifold 5(PMSI C
'REVERSE CIRCULATING' Mud Kill Line O
Cross Kill Line O
STANDPIPE HCR valve (Choke Line 1) C
Choke Line 2 0
Choke Choke Manifold 1(CM1) 0
Manifold Choke Manifold 2 (CM2) C
Choke Manifold 3 (CM3) 0
Choke Manifold 4(CM4) C
Choke Manifold 5 (CMS) O
❑ Choke Manifold 6(CM6) C
PANIC Choke Manifold 7(CM7) 0
LINE Choke Man'rfold8(CME) C
RIG FLOOR Choke Manifold 9(CM9) C
#2 Choke Manifold 10(CM30) 0
Super Choke C
Manual Choke C
SUPER #J
CHOKE Rig Floor Safety Valve 0
#3 STRIPPER #3 #5 #7 #1D
HEAD
MUD
#4 #2 UMP FOP
STACK #4 #6 #B
#5 _
#1 MANUAL
CHOKE
W
LP 11R
SUCTION
SUCTION VALVE #�
cns LINE P„v, '"ILTLR„fILF,
BUSTER
FLUID TANK/PIT
Rig 404
BOP Test Procedure
na�rN AmAa, ci.c Attachment #1
Attachment #1
Hilcorp Alaska, LLC - BOP Test Procedure:
Rig 404, WO Program — Oil Producers, Water Injectors
Pre Rig Move
1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere
2) Load well with FIW to kill well.
• Note: Fluid level will fall to a depth that balances with reservoir pressure.
3) Shoot fluid level at least 24 hours before moving on well.
4) Shoot fluid level again, right before ND/NU. Confirm that well is static.
Initial Test (i.e. Tubing Hanger is in the Wellhead)
If BPV profile is good
1) Set BPV. ND Tree. NU BOP.
2) MU landingjoint. Pull BPV. Set 2 -way check in hanger.
3) Space out test joint so end of tubing (EOT) is just above the blind rams.
4) Set slips, mark same. Test BOPE per standard test procedure.
If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded
and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case:
BPV profile and landing threads are bad.
1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level.
2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and
the tree must be removed with no BPV. As approved in the sundry, proceed as follows:
a) ND tree with no BPV
b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift -threads to accept landing joint to
hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and
a wire brush or wheel.
c) Set 2 -way check valve by hand, or MU landing (test)joint to lift -threads
d) For ESP wells - Ensure that cap is on cable penetrator
e) NU BOP. Test BOPE per standard procedure.
3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify
Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the
wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As
outlined and approved in the sundry, proceed as follows:
a) Nipple Up BOPE
b) With stack out of the test path, test choke manifold per standard procedure
c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface
equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.)
d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the
pumping rate and pressure.
e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal
test procedure (floor valves, gas detection, etc.)
H
Hilcnry Al...k , LLC
Rig 404
BOP Test Procedure
Attachment ill
f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile /
penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items,
pressures and rates.
4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing
with kill weight fluid.
5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing.
Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure.
Subsequent Tests (i.e. Test Plug can be set in the Tubing -head)
1) Remove wear bushing.
a) Use inverted test plug to pull wear busing. MU to joint of tubing.
b) Thread into wear bushing
c) Back out hold down pins
d) Pull and retrieve wear bushing.
2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump -in sub w/ test line plus
an open TIW or lower Kelly valve in top of test joint w/ open IBOP.
3) Test BOPE per standard procedure.
STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set)
1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump -in sub below safety
valve and IBOP in test joint assembly.
2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap
pressure and read same with chart recorder (test pressures will be indicated in Sundry).
3) Referencing the attached schematics test rams and valves as follows.
a) Close 1" valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular
preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and
2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open
annular.
b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside
valve on kill side of mud cross, open 1" valve of standpipe, close valves 3, 4 & 9 on choke manifold, open
valves 1 & 2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes
after 5 minutes on each, bleed off pressure back to tank.
c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by
picking up two test joints with dual elevators and lowering them into stack and position them properly in
the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5
minutes on each, bleed off pressure back to tank.
d) Close inside valve/ open outside valve on kill side of mud cross, close valves 5 & 6/ open valves 3 &4 on
choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on
each, bleed off pressure back to tank.
e) Close manual and super choke / open valves 5 & 6 on choke manifold. Pressure up to — 1200 psi and bleed
off 200 — 300 #s recording change and stabilization. If passes after 5 minutes, bleed off pressure back to
tank.
f) Close HCR (outside valve on choke side of mud cross), open manual & super choke. Test to 250 psi for 5
minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank.
H
Hikc p Alaska, LLC
Rig 404
BOP Test Procedure
Attachment #1
g) Close inside valve / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and
3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank.
h) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug / 2 -way check in place.
Close blind rams and attach test line to valve 10 on choke manifold, close valve 7 & 8 / open valve 10 on
choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on
each, bleed off pressure back to tank.
i) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary.
STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR)
1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps.
2) Record "Accumulator Pressure". It should be +/- 3,000 psi.
3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams).
Open the lower pipe rams to simulate the closing volume on the blinds.
4) Allow pressures to stabilize.
5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e.
Report might read "10 bottles at 2,150 psi").
6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume
remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre -
charge pressure of 1,000 psi).
7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator
gauge. This is usually +/- 30 seconds.
8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the
pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note:
Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically.
9) Open all rams and annular and close HCR to place BOPE back into operating position for well work.
10) Fill out AOGCC report.
FINAL STEP, FINAL CHECK
1) Test Gas Alarms
2) Double check all rams and valves, for correct operating position
3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett.
Document both the rolling test and the follow up tests.
HHilcorp Alaska, LLC
Hilcorp Alaska, LLC
Changes to Approved Rig Work Over Sundry Procedure
Subject: Changes to Approved Sundry Procedure for Well: Granite Point 55 (PTD 197-145)
Sundry #: XXX -XXX
Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the
AOGCC by the rig workover (RWO) "first calf' engineer. AOGCC written approval of the change is required before implementing the change.
Sec
Page
Date
Procedure Change
New 403
Required?
Y / N
HAK
Prepared
By
Initials
HAK
Approved
By
Initials
AOGCC Written
Approval Received
(Person and Date)
Approval:
Prepared:
Asset I earn Operations Manager
Date
First Call Operations Engineer Date
RECEIVED
STATE OF ALASKA
AIDA OIL AND GAS CONSERVATION COMikION SEP 2 8 2015
REPORT OF SUNDRY WELL OPERATIONSACGCG
1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate El Pull Tubing❑ Operations shutdown ❑
Performed: Suspend ❑ Perforate El Other Stimulate ❑ Alter Casing❑ Change Approved Program Cl
Plug for Redrill ❑ Perforate New Pool LI Repair Well ❑ Re-enter Susp Well❑ Other: Suspended Well Inspection ❑
2.Operator 4.Well Class Before Work: 5.Permit to Drill Number:
Name: Hilcorp Alaska,LLC Development I] Exploratory❑ 197-145
3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ID Service❑ 6.API Number:
Anchorage,AK 99503 50-733-20479-00
7.Property Designation(Lease Number): 8.Well Name and Number:
ADL0018761 Granite Point 55
9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):
N/A Granite Point Field/Middle Kenai Oil Pool
11.Present Well Condition Summary:
Total Depth measured 5,011 feet Plugs measured N/A feet
true vertical 4,100 feet Junk measured N/A feet
Effective Depth measured 4,864 feet Packer measured N/A feet
true vertical 4,006 feet true vertical N/A feet
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 306' 26" 306' 306'
Surface 1,318' 13-3/8" 1,318' 1,318' 3,450 psi 1,950 psi
Intermediate
Production 4,997' 9-5/8" 4,997' 4,091' 10,900 psi 7,930 psi
Liner 1
Perforation depth Measured depth N/A feet i�`AN E`j JAN 2 0 L u j
True Vertical depth N/A feet
Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A
Packers and SSSV(type,measured and true vertical depth) N/A&N/A
12.Stimulation or cement squeeze summary:
Intervals treated(measured):
N/A
Treatment descriptions including volumes used and final pressure:
N/A
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: 0 0 0 0 0
Subsequent to operation: 0 0 0 0 0
14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work:
Daily Report of Well Operations LI Exploratory❑ Development[] Service ❑ Stratigraphic ❑
Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑
Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP0 SPLUG❑
17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt:
310-359
Contact Dan Marlowe Email dmarlowet hilcorp.com
Printed Name D n Marlowe Title Operations Engineer
Signature Phone (907)283-1329 Date 6/0/6
Form 10-404 Revised 5/2015 A f /l/�/'/� RBDMS JL Z 9 2015 Submit Original Only
` . •
Suspended Well Inspection Data
Well: GPP 55
Surface Location: 2437' FNL, 1303' FWL, Sec 13, T10N, R12W S.M.
Permit to Drill: 197-145
API: 50-733-20479-00
AOGCC Inspection Date: 9/25/15
AOGCC Inspector: Matt Herrera
Size Pressure(psi)
Tubing 0/0
Casing IA 0/0
OA 0/0
*Note: Wellhead pressures to be recorded monthly at minimum.
Other Notes:
• Condition of Wellhead: Good
• Condition of Surrounding Surface Location: Good
• Follow Up Actions needed: None/ Readings psi
Attachments:
• Current Well Schematic
• Picture(s)
• Plat- 1/4mile radius of wellbore
• Correspondence/Suspended Well Inspection Report
, ,...
1 ''''..,',::.,::,.:•,...:,:i...,.:::,,,..;;.;.;:1,.:.,.,,., '',:-' T. If 1 ''',.:,
I
tVIistIin$-ia1, .'•
' -
,•''
1
, t•
. „, ...
.,„•i-
.i:
•• .. .
..
' • ...,....... - .-. .
le,,
.. ....... . .
...
_ . _ ..,.... .
. „...., ,... ...
., .
,... . ..,
. ...
_
.
, .
........ .. . . .
.„..„...,, ,
. ......,, „...... . ,. ... ...
. .. .
. ...
1... .. , . . „„,,,„,,,.....„.„.„,„.„, ,.,.....„..„ ........„,, . ...,,.....,
. .
,, . ...
. .,
... ,„,, . ..
...,..,.. .i . . .,
. ,.. .
... . ,.: . ,
. .
Oil
„,...
,Lf
......
i •I,. ,..,:i , 0...1-, 8 --,,,-;-,:•'.---
„I.-!
, -•:F - -,---• ,_#* •-,•-:i.''',';',':',':-:',.,..,$,,f,',•-•''..
..,:i.
I'#1117
...-
I
..,, • i ,'
• ::
.. .„ .- .. •i.', t .
iliall
w 0
i
P1) - r
.„.
.......
.. , ,...
.., ..
., . . .. .
t '
...
.,.
) ” / ,'-'• ",
„-.
.. ..
.. .., .„
.....,
/,,,..
. . .-,.... -,,,.. .,,. „.. ... . .:.
...
.._ ... .
. .,
.--• ...,;..m. ...
, . „.
,....-
,-- .„-.....-------
.,..„...,,,,,,... ,,,,,,...,. .
, .
.,. ...„-,..,:,. •
.„...
. ....
. . ,
..., .
. .
.....,„„
. ,..
,,,.. ,...„.
..,
.....,...,..„
-.......--...-- .,,..„. .. :, , .
. ...., -,,,,•,,; •,..,-- '
„...., ..
,.....„,
. ,,.....,..
. Nil
..„..,..„.. ,
. ..,...
,..
>.,
-
'41•::‘,,,..,'',..i,•,•,.-•!'-'•:',7•!••''''',,,,Ii-41,#•,,..-, .
*,,,• ..„
. ,
..,
. ,.,,,," ,_ ''''*,''''''''' '',`''','"'„;',','..-''..,..:F77'....:!-,,,,,,, ..,.:..,e.-..,',F,;:il..4,',1;.?.,;,....,'''.:,,-.,,•...,,5,,I:-:,.1.1,.,,,itf3t;;: "'''.110030%.,1- . ..' .
''''''!'''''''''
•
• •
•
hammy Granite Point Platform
1.,g,or,
01.11rr031p Well # GP-55 Final
"g""'r°` 8/26/1997
teras rat'un
RK/143A4'
„ 1
[
Size Type Wt/Grade Top Btm CONN ID Cement/Other
26"@ 26" Conductor Surf 306' Driven
305 299bb1 12.9ppg
13-3/8” Surface 68#,K-55 Surf 1,318' BTC 12.415" lead,49.3bbl
15.8ppg tail
53.5#,P- 458bb1 12.9ppg
9-5/8" Production 110 Surf 4,997' BTC 8.535" lead,37bb1
15.8ppg tail
9.6ppg
\ABM
Z.
13-3/8"@
1,318'
.42
9-5/8"@ A, •�
5,011'
PBTD=4,864'ND(4,006'TVD)
TD=5,011'MD(4100'TVD)
Directional Data:
max hole angle=51.3°@ 4,667'
Updated by DRT 6-23-15
I '/°
0.. ��
. "11111 cz
iii
���
se
r.
KN
/�-
/
CI
�____-__'_--__- -_-__ -__-__-_ ___-__-__----'__'__-__-__'__-___
N�
en
� ~~ •
a � /
12. \ . � ' /
•
t: .11.
i C., -, r\\\,, t'llie:1111*....iiiiiiiifr. dpril..- 'II
ti4"— r
~ ��
C:5 0 �r ~ OW fii
� s r
(...1
UJ ` 111 9
.�
„AL. Slle el
/ ;
4\I 10, ,.., .
Ifi — --Lwow— ' .ilvir
.....,/
„.....
____________
....
„..
� ---- At* \
7? m/ � 4
11
CLI
t. * �� 0
-•-...,,
CL
el
eV
0 `N
--_--_--_-_'-__ '-_'-_.--_--_--_'___---_'—_''__'--__----'__—_'--_—'_—'-- ----_—'
• •
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Suspended Well Inspection Report
Date Inspected: 09/25/15
Inspector: Matt Herrera Operator: HILCORP
Well Name: Granite Pt 55 Oper.Rep: James Madrid
PTD No.: 1971450 Oper.Phone: 907-776-6650
Location Verified? Yes Oper.Email: jmadridahilcorp.com
If Verified,How? LAT/LONG
Onshore/Offshore: Offshore
Suspension Date: 08/26/97 Date AOGCC Notified: 09/23/15
Sundry No.: Well Completion Report Type of Inspection: Subsequent
Wellbore Diagram Avail.? Yes
Well Pressures(psi): Tubing 0 Photos Taken? Yes
IA 0
OA 0 •
Condition of
Wellhead:
Good,Gauges operable '
Condition of
Surrounding Surface
Location: Good no standing water or oil sheen discoloration around well head or in cellar area -
Follow Up Actions
Needed: Monitor IA and OA pressure and visually inspection by Operator
Comments:
No SSV
Attachments: Photo(1) SCANNED SEPREVIEWED BY:
15 2��6 Insp.Supry �-(Z'IZE )/S
Comm
PLB 12/2014 2015-0925_Suspend_GranitePt_55 mh.xlsx
•
•
•
IM .,
A
• .. i ••••,..4444.11;„.......0.... ..,e. ....,.... .
, . .go ' . .r
0116 . 14 . .., cr" lit..
4.
o
0.1
4
,
v, ,c
U
b
CI
Ili I
i. • i 4
O
it �..---- "
. - rtt�
xh
r
0500., -
I,__,
• M I$11— 1111 t ,.., ; 9 •--)
s
V1 a O� s N P,
• •
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Suspended Well Inspection Report
Date Inspected: 09/25/10
Inspector: Lou Grimaldi Operator: Union Oil Company
Well Name: GP -55 Oper. Rep: Jerry Collins
PTD No.: 197 -145 Oper. Phone: 776 -6650
Location Verified? Yes Oper. Email:
If Verified, How? Other (specify in comments)
Onshore / Offshore: Offshore
Suspension Date: 08/26/97 Date AOGCC Notified: unknown
Sundry No.: Well Completion Report Type of Inspection: Initial
Wellbore Diagram Avail.? No
Well Pressures (psi): Tubing 0 Photos Taken? Yes
IA 0
OA 0/0
e, i :.ray
Condition of
Wellhead: Clean and secure
Condition of
Surrounding Surface Granite Pt Platform; Wellroom clean and secure
Location:
Follow Up Actions None
Needed:
Attachments: Photo REVIEWED BY: pp,�
Insp. Supry .dal 7/4/
Comm
PLB 09/2010 2010- 0925 _Suspend_Granite_Pt_55_Ig.xls
Suspended Well Inspection — Granite Pt 55 (Granite Pt Platform)
PTD 1971450
Photo by AOGCC Inspector L. Grimaldi
9/25/2010
,,,,,r \
•
} I
'3 j
e . _
.,,. .
... „.„.,.
.., . , , GP 5
e
jr " T ''' ' Ak .: o : ,. 'i t
. *
a
SEAN PARNELL, GOVERNOR
a
I ii
ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100
CONSERVATION CO1r USSION ANCHORAGE, ALASKA 99501 -3539
PHONE (907) 279 -1433
FAX (907) 276 -7542
Timothy C. Brandenburg
Drilling Manager
Union Oil Company of California N NOV
PO Box 196247
Anchorage, AK 99519
Re: Granite Point Field, Middle Kenai Oil Pool, Granite Point 55
Sundry Number: 310 -359
Dear Mr. Brandenburg:
Enclosed is the approved Application for Sundry Approval relating to the above
referenced well. Please note the conditions of approval set out in the enclosed
form.
As provided in AS 31.05.080, within 20 days after written notice of this
decision, or such further time as the Commission grants for good cause shown,
a person affected by it may file with the Commission an application for
reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the
next working day if the 23rd day falls on a holiday or weekend.
Sincere
or
m sioner
DATED this day of November, 2010.
Encl.
STATE OF ALASKA �, OCT 2 8 2010
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS 9X ? x s UPS. '� 31011
20 AAC 25.280 behatage
1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑
Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑
Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Reauest for Suspended Well
Renewal
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Union Oil Company of California Development ❑� Exploratory ❑ 197 -145 .
3. Address: Stratigraphic ❑ Service ❑ 6. API Number:
PO Box 196247, Anchorage, AK 99519 50- 733 - 20479 -00
7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number:
property line where ownership or landownership changes:
Spacing Exception Required? Yes ❑ No El Granite Point 55 '
9. Property Designation (Lease Number): 10. Field / Pool(s):
ADL 4 [Granite Point Platform] r C `' n �� . R' Granite PT Field / Middle Kenai Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD ( � Total Depth TVD (ft): sqt' Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
"ti' 489f 4,864 4,006 N/A N/A
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 306' 26" 306' 305'
Surface 1,318' 13 -3/8" 1,318' 1,317' 3,450 psi 1,950 psi
Intermediate
Production 4,997' 9 -5/8" 4,997' 4,091' 10,900 psi 7,930 psi
Liner
Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft):
N/A N/A N/A N/A N/A
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
N/A / N/A N/A / N/A
12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Service ❑
14. Estimated Date for N/A 15. Well Status after proposed work:
Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended 1
16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned El
Commission Representative: GSTOR El SPLUG El
17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263 -7831
Printed Name Timothy C. Brandenbur Title Drilling Manager
17
Signature Phone 276 -7600 Date L t:z, . 2 C . 2A L
COMMISSION USE ONLY 2
Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ✓ )o
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑
Other:
Subsequent Form Required:
APPROVED BY
Approved by: COM ONER THE COMMISSION Date:
RBDAAS NOV 19 214 � � 16
Form 10-403 Revised 1/2010 / O RIGINAL Submit in Duplicate
Suspended Well Data
Well: GP -55
Surface Location: 2437' FNL, 1303' FWL, Sec 13, T10N, R12W S.M.
Permit to Drill: 196 -045
API: 50- 733 - 20479 -00
AOGCC Inspection Date: 9/25/10
AOGCC Inspector: Lou Grimaldi
Size Pressure (psi)
Tubing N/A N/A
Casing 9 -5/8" 0
13 -3/8" 0
*Note: Wellhead pressures to be recorded daily.
Other Notes:
• Inspector's comments: Wellhead clean, secure. Well room clean.
• The well was suspended on August 26, 1997. The well had been drilled to depth of
5,011' when the decision was made to cease operations and suspend the well at that
point. This depth is well above the productive reservoirs within the Granite Point Field.
• The well does not currently exhibit any well head pressure.
• Wellhead pressures will continue to be monitored on a daily basis.
• It is proposed that well GP -55 be maintained in a suspended status until the Granite
Point Platform production is shut -in and the platform abandonment commences.
Attachments:
• Current Well Schematic
• 3 Year TIO Plot
hevro
Granite Point Platform Completion
GP -55 Date: 8/26/97
RFC: 43A4
Casing Detail
2 s "@ Size Type Wt/ Grade Top Btm CONN Cement/Other
/ID
26" Conductor Surface 306' Driven
13 -3/8" Surface 68 #, K -55 Surface 1,318' BTC 299bbl 12.9ppg lead,
49.3bbl 15.8ppg tail
9 -5/8" Production 53.5 #, P -110 Surface 4,997' BTC 458bbl 12.9ppg lead,
37bbl 15.8ppg tail
9.6 ppg
VVBM
13-3/8"@
1,318
t'
95/8" @
5,011'
PBTD= 4A64'ND(4,006' TVD)
TD= 4,99TND (4,091' TVD)
Directional Data:
max hole angle = 51.3 @ 4,667'
GP -55 Schematic 10- 6- 10.doc __ Updated by CVK 10 -6 -10
Pressure
N
N ? O OD O N A O Oo O
O O O O O O O O O O O
10/17/07
1/17/08 ( I
c w Ln
0 w --
5' � o0
oo =
4/17/08
1 7/17/08
b
O
10/17/08 b
O
0 1/17/09
4/17/09
y
i
7/17/09
b
10/17/09 (�
1/17/10
4/17/10
7/17/10
10/17/10
STATE OF ALASKA
ALASKSL AND GAS CONSERVATION COMMISSO4
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Abandon Ll Repair Well Li Plug Perforations Ll Stimulate Ll Other L/ Suspended Well
Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Inspection
Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑
2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Nrmit to Drill Number:
Name: Development 21 Exploratory ❑ 197 -145
3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API (Lumber:
50- 733 - 20479 -00 0
7. Property Designation (Lease Number): 8. Well Name and Number:
ADL0374644 [Granite Point Platform] Granite Point 55
9. Field /Pool(s): `
Granite PT Field / Middle Kenai Oil Pool
10. Present Well Condition Summary:
Total Depth measured 4,997 feet Plugs (measured) N/A feet
true vertical 4,091 feet Junk (measured) N/A feet
I
Effective Depth measured 4,864 feet Packer (measured) N/A feet
true vertical 4,006 feet (true vertical) N/A feet
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 306' 26" 306' 305'
Surface 1,318' 13 -3/8" 1,318' 1,317' 3,450 psi 1,950 psi
Intermediate
Production 4,997' 9 -5/8" 4,997' 4,091' 10,900 psi 7,930 psi
Liner �y r
Perforation depth: Measured depth: N/A NO V 1 � I�
True Vertical depth: N/A
Tubing (size, grade, measured and true vertical depth): N/A N/A N/A N/A
Packers and SSSV (type, measured and true vertical depth): N/A N/A ♦ S N/A
11. Stimulation or cement squeeze summary: cq
Intervals treated (measured):' 0 2010
N/A
Treatment descriptions including volumes used and final pressure:��
N/A Aj;�catage
12. Representative Daily Average Production or Injection Data
Oil -Bbl Gas -Mcf I Water -Bbl I Casing Pressure Tubing Pressure
Prior to well operation: 0 0 10 10 psi N/A
Subsequent to operation: 0 0 10 10 psi N/A
13. Attachments: 14. Well Class after work:
Copies of Logs and Surveys Run N/A Exploratory❑ Devel ment❑� Service ❑
Daily Report of Well Operations N/A 15. Well Status after work: Oil El Gas WDSPL LJ
Well Remains in'SUSP' Status = => GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑
16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
N/A
Contact Chris Kanyer 263 -7831
Printed Name Timothy C. Brandenburg Title Drilling Manager
Signature Phone 276 -7600 Date 10/11/10
c
- RBDAAS OCT x
Form 10 -404 Revised 7/2009 Submit Original Only
Suspended WeU Inspection Data
Well: GP -55
Surface Location: 2437' FNL, 1303' FWL, Sec 13, T10N, R12W S.M.
Permit to Drill: 196 -045
API: 50- 733 - 20479 -00
AOGCC Inspection Date: 9/25/10
AOGCC Inspector: Lou Grimaldi
Size Pressure (psi)
Tubing N/A N/A
Casing 9 -5/8" 0
13 -3/8" 0
*Note: Wellhead pressures to be recorded monthly at minimum.
Other Notes:
• Wellhead clean, secure. Wellroom clean.
Attachments:
• Current Well Schematic
• Picture(s)
• Plat - 1 /4mile radius of wellbore
• Correspondence /Suspended Well Inspection Report
evro
Granite Point Platform Completion
GP-55 Date: 8/26/97
RKB aaaa
Casing Detail
26 "@ Size Type Wt/ Grade Top Btm CONN Cement/Other
3w' /I D
26" Conductor Surface 306' Driven
13 -3/8" Surface 68 #, K -55 Surface 1,318' BTC 299bbl 12.9ppg lead,
49.3bbl 15.8ppg tail
9 -5/8" Production 53.5 #, P -110 Surface 4,997' BTC 458bbl 12.9ppg lead,
37bbl 15.8ppg tail
9.6 ppg
WBM
13318" @
1,318
t
5,011'
PBTD= 4,864'MD(4,0067 TVD)
TD = 4,99TND (4,091' TVD)
Directional Data:
max hole angle = 51.3° @ 4,667'
GP -55 Schematic 10- 6- 10.doc Updated by CVK 10 -6 -10
GRANITE POINT PLATFORM
WELLSLOT DIAGRAM
01/01/10
MUCI -1
MUCI -2
S/I S/I
D 8 22 -13RD2 3 4'
S/I 32 -13RD
s GP -51 S/
6 5
0 31 -13 1 GP -50 S/I
t 1 6� 24 -13RD
4 2 11 - 13RD 9 TP &A 7
3 B�
42 -23RD
11 -24
Leg #2 Leg #3
North Corner East Corner
Producer Dual Gas Well Injector
Completion CD
a
6
12-24 54
CL
55
S/I SCI su ended e
7 8i 32 -23 3 4
4
co
4 -11 S/I 53
(Disp. s' 2 S/I
in
Well) 6
a
12 12 !
10 L s 13 -13 10 52
CL
1
31 -14 S/I 6
RD2 11 11 suspen ed
tn
si s
L a
`4 s S/I 44 -14 9 7
31-23 3i a a
33 -14RD
Leg #1 Leg #4
West Corner South Corner
0
s
, f u
• r
t
&t "
g ;
t �
L
E ms*
A
� e
I
.. r f t f M''t NJOCX I,
\ l d
a;
N j
E
"
MR
j�
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Suspended Well Inspection Report
Date Inspected:
Inspector: /-0(-) -nf Operator.
Well Name:
Oper. Rep:
PITD No.:
Oper. Phone:
Location Verified? Oper. Email:
If Verified, How?
Onshore I Offshore:
Suspension Date: Date AOGCC Notified:
Sundry No.: Type of Inspection:
Wellbore Diagram Avail.?
Well Pressures (psi): Tubing Photos Taken?
IA
OA
Condition of
Wellhead: Aj —
Condition of
Surrounding Surface
Location:
Follow Up Actions d
Needed:
Attachments REVOMM BY:
Map. SLjpry
Comm
PL80912010 S wet Inspection Form x1s.
THE MATERIAL UNDER THIS COVER
HAS BEEN
MICROFILMED
ON OR BEFORE
JANUARY 03 2001
PL
M ATE
THIS
E
W
IA L U N D ER
M A R K E R
C:LORIEMFILM.DOC
AOGCC
Geological
Materials
Inventory
PERMIT 97-145
Log Data
DRY CTTN~_______~_~ 1320-5010
10-407 Completion Date ~P/~ ~,/~ '~
Daily ~vell ops ~/[(~/~- ~ _ ~/~1 {~/~
Are dry ditch samples required? yes
Was the well cored? yes
'x no
Are tests required? yes/~r
Well iS in compliance
Initial
Comments
UNOCAL
Sent Recieved
9/23/97 9/26/97
Box
.~_.._n_no And received? ~es no
Analysis description recieved?
Received? 2____~w~-~--~mtr---
Tuesday, August 31, 1999 Page 1 of 1
......STATE OF ALASKA -
~ ,, ALASKA O.,_ AND GAS CONSERVATION C,.,MMISSION
" WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL: GAS: SUSPENDED:X ABANDONED: SERVICE:
2. Name of Operator 7. Permit Number
Unocal 97-145
3. Address .......... .~..,..... 8. APl Number
P.O. Box 196247 Anchorage, AK 99519 i -;-~:~.:'~'?~-~,-~'~ 50- 733-20479
4. Location ofwell at surface :; "~'~':' '~:~--~" 9. Unit or Lease Name
2437' FNL, 1303' FWL, Sec. 13, T10N, R12W, SM ~ %,.-..~~~.~_ .j] Granite Point Field
At Top Producing Interval ! ~,~'~.' 10. Well Number
N/A~~ GP #55
At Total Depth 11. Field and Pool
962' FSL, 232' FWL, Sec. 13, T10N, R12W, SM Granite Point Field/Middle Kenai "C" Sands
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No.
114.75 RKB (MLLW) ADL 18761,374044, 374045
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions
8/19/97 8/24/97 8/26/97 75 feet MSLI 0
17'T°ta'Depth{rv1D+TVD> 18' P'ug Back Depth {MD+TVD> I 19' Directi°naI SurveY 20' Depth where SSSV set I 21'¥hicl~ness°fPermafr°st5011'/4100' 4864'/4007' Yes: X No: N/A feet MD N/A
22. Type Electric or Other Logs Run
Mud Logging
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
13-3/8" 68 K-55 44 17-1/2" N/A
9-5~8" 54 P-110 44 4997 12-1/4" 1415 sacks
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
N/A
N/A
ORIGINAL 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
N/A
27. PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
I
N/A
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO
I
TEST PERIOD =>
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE =>
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
Interbedded sandstones; conglomerates, claystones and coals. Pay zone is a sandy conglomerate averaging 12% r i s t
sw of 39%.
S~-p 2 4 1997'
'~las~'.Ojl & Gas Cons. 6ommiss,'
Form 10-407
Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate
29. 30.
~' GEOLOGIC MARKERS FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
N/A N/A
31. LIST OF A'I-['ACHMENTS
Daily Operations Summary
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
DaleA. Haines /~)~ ~. '~\ ~ Drilling Manager Sept. 22,97
Signed Title Date
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other space on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval.
Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
lng and the location of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Form 10-407
Item 28: If no cores taken, indicate "none".
GRANITE POINT 55
DAY 1(8/18/97)
296/0 MD/TVD
SKID RIG TO WELL #55. SET IN 30' RISER AND SECURE SAME. RIG RISER
DRAIN LINES. RIG TOP DRIVE. OFF LOADING 5" DP & MIS SPUD
EQUIPMENT. PICK UP 5" DP.
DAY 2 (8/19/97)
747/O MD/TVD
BOTTOM @ 242'. CLEAN OUT CONDUCTOR AND DRILL TO 306'. ROTARY
DRILL 17-1/2" HOLE FROM 306' TO 398'. RIH WITH KEEPER AND TAK
SURVEY. SURVEY @ 348'.
DAY 3 (8/20/97)
1329'/0
ROTARY DRILL 17-1/2" HOLE WITH 9-1/2" MOTOR FROM 747'-1329'.
SURVEY W/GYRO ON APRS'S WIRELINE. ClRC FOR TRIP. POOH. RIH
W/13-3/8" CASING. SET DWN @ 227'. WASH DOWN TO 247'. CONT
RUNNING CSG TO TD. LAND WELLHEAD, ClRC ONE HOLE VOLUME.
PUMP 299 BBLS OF 12.9 PPG LEAD CMT W/RETURNS TO SURFACE.
PUMP 49.3 BBLS OF 15.6 PPG TAIL CMT. DISPLACE CMT W/178.5 BBLS OF
MUD @ 6.5 BPM. ClP @ 21:55 HRS. FLOATS HOLDING. PU WELLHEAD
RUNNING TOOL. RELEASE WELLHEAD RUNNING TOOL. ND RISER.
WELLHEAD 4" OFF CONDUCTOR.
DAY 4 8/21/97
1724' MD
NU RISER AND BOPE. TEST BOPE. RIH WITH 12-1/4"BIT AND MACH 1C
MOTOR WITH ANDERGAUGE STABILIZER. DRILL CEMENT FROM 1255' TO
1296'. PRESSURE TEST CASING TO 2875 PSI. DRILL FLOAT SHOE AT
1316' AND NEW FORMATION TO 1339'. PERFORM LOT AT 28.3 PPG EMW.
DRILL TO 1724'.
DAY 5-9 (8/22-8/26/97)
CURRENT DEPTH 5,011'
DRILL 12-1/2" HOLE TO 5,011'. POOH. RIH WITH 9-5/8" 53.5 LB/FT P-110
CSG TO 4,996'. PUMP 458 BBLS OF 12.9 LEAD CEMENT AND 37 BBLS OF
15.8 PPG TAIL CEMENT AND DISPLACE WITH WBM--BUMPED PLUGS.
SET CSGING HANGER PACK-OFF. CHANGE TOP RAMS TO 5" AND RIH
WITH 8-1/2" USED BIT. TAG CEMENT @ 4,864'. TEST CASING TO 3,500 PSI
FOR 30 MIN--OK. POOH. ND BOPE AND NU TREE. LD 5" DRLLPIPE.
DECIDED TO STOP DRILLING AND SUSPEND OPERATIONS. MOVE RIG TO
GP 53.
DirectiOnal Survey For
UWI
L~-~ DatUm Elevation
X Surface Location
Y Surface Location
Longitude
Latitude
Operator
Total Depth
Completion Date
Common Well Name
: GP-5
: 50733~047900
: 115.0000
: 263330.09
2544503.29
: -151.33161
: 60.95801
: UNOCAL
: 5011.00
:
: GP-55
MEASURED
TVD
0
90
180
206
350
440
528
614
704
796
886
975
1064
1152
1273
1459
1524
1594
1684
1738
1871
1965
2058.00
2152.00
2246.00
2339.00
2432.00
2523.00
2618.00
2712.00
2806.00
2898.00
2992.00
3082.00
3175.00
3267.00
3360.00
3453.00
3547.00
3640 00
3733 00
3824 00
3917 00
4011 00
4197 00
4479.00
4667.00
4802.00
4956.00
5011.00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
0.00
90.00
180.00
206.00
350 00
439 99
527 98
613 96
703 91
795 88
885 86
974 84
1063 82
1151 79
1272.77
1458.73
1523.71
1593 63
1683 31
1737 01
1868 18
1959 26
2048 13
2136 92
2223 76
2307 22
2388 58
2465 99
2543 79
2616 96
2685 62
2748 32
2809 87
2868 47
2928 59
2987 72
3047 81
3108 60
3170 24
3230.54
3290.59
3349.25
3408.85
3468.82
3586.68
3764.28
3882.06
3967.10
4065.17
4100.29
Common Well Name : GP-55
MEASURED Inclination
X Offset
0 00
0 10
0 32
0 25
-0 28
-0 62
-1 81
-3 71
-6 31
-7 12
-6 12
-4 62
-3 12
-1 75
-0 09
3 10
4 13
4 38
2 07
-0 12
-11 31
-24 03
-38 56
-55 06
-74 59
-97 12
-122 34
-148 78
-177 68
-207 65
-239 93
-275.09
-313.09
-349.75
-386.93
-422.40
-457.84
-493.50
-529.93
-566.31
-602.97
-640.03
-677.93
-715.40
-789.90
-901.81
-976.25
-1029.09
-1087.81
-1108.65
Azimuth
0.00 0.00 0.00
90.00 0.28 154.70
Y Offset
-0 04
-0 29
-0 04
-0 04
-0 04
0 71
1 46
0 96
-0 29
-2 29
-3 79
-5 04
-6 29
-7 79
-9 29
-11 54
-12 79
-15 79
-23 04
-28 29
-46 79
-66 04
-89 29
-115 54
-145 54
-179 79
-217 29
-257 04
-303 29
-354 04
-409 54
-466 79
-526 79
-584 54
-644 79
-705 79
-767.29
-828.04
-888.79
-949.54
-1010.54
-1069.29
-1129.79
-1191.79
-1314.79
-1503.04
-1629.29
-1719.79
-1823.04
-1860.04
M C OF LM D
X Coordinate Y Coordinate
263330.09
263330.19
263330.41
263330.34
263329.81
263329 47
263328 28
263326 38
263323 78
263322 97
263323 97
263325 47
263326 97
263328 34
263330 00
263333 19
263334 22
263334 47
263332 16
263329 97
263318 78
263306 06
263291 53
263275 03
263255 50
263232 97
263207 75
263181 31
263152 41
263122 44
263090 16
263055 00
263017 00
262980 34
262943 16
262907 69
262872 25
262836 59
262800 16
262763 78
262727 12
262690 06
262652 16
262614 69
262540 19
262428 28
262353 84
262301 00
262242 28
262221 44
2544503
2544503
2544503
2544503
2544503
2544504
2544504
2544504
2544503
2544501
2544499
2544498
2544497
2544495
2544494
2544491
2544490
2544487
2544480
2544475
2544456
2544437
2544414
2544387
2544357
2544323
2544286
2544246
2544200
2544149
2544093
2544036
2543976
2543918
2543858
2543797
2543736
2543675
2543614
2543553
2543492
2543434
2543373
2543311
2543188
2543000
2542874
2542783
2542680
2542643
25
00
25
25
25
00
75
25
00
00
50
25
00
50
00
75
50
50
25
00
50
25
00
75
75
50
00
25
00
25
75
50
50
75
50
50
00
25
50
75
75
00
50
50
50
25
00
50
25
25
189.00
206.00
350.00
440.00
528.00
614. O0
704.00
796.00
886.00
975.00
1064 O0
1152 O0
1273 O0
1459 O0
1524 O0
1594 00
1684.00
1738.00
1871.00
1965.00
2058.00
2152.00
2246.00
2339.00
2432.00
2523.00
2618.00
2712.00
2806.00
2898.00
2992.00
3082 O0
3175 O0
3267 O0
3360 O0
3453 O0
3547 O0
3640.00
3733.00
3824.00
3917.00
4011.00
4197.00
4479.00
4667.00
4802.00
4956.00
5011.00
0
0
0
0
0
1
1
1
1
1
1
1
1
1
1
4
5
6
12
16
17
20
24
27
30
33
36
40
45
48
49
49
50
49
49
4
4
4
4
5
5
5
5
5
5
5
5
5
.23
.20
.46
.89
.92
69
95
O0
33
18
45
01
.19
24
39
O0
64
50
20
35
94
35
60
72
23
18
82
92
22
84
34
41
.04
.97
54
8 82
9 23
9 93
9 63
0 09
0 21
0 5O
0 86
1 07
1 35
0.56
0.33
0.30
335 90
173 70
353 50
326 40
260 60
252 40
236 60
164 10
125 40
131 20
132 O0
133 40
132 90
117 20
150 80
197 30
196 30
206 54
213 53
210 77
210 80
211 59
212 O1
212 37
213 35
211 44
210 33
208 47
209 57
211 07
211.27
211.32
209.57
208.55
209.02
209.53
209 93
209 59
210 22
211 86
209 96
210 04
210.00
209.13
209.59
208.61
208.36
208.30
Report Date ~ : 01-0 1997
Cartographic System : state plane 4
Directi~onal Survey For : GP-52
UWI
Log Datum Elevation
X Surface Location
Y Surface Location
Longitude
Latitude
Operator
Total Depth
Completion Date
: 507332047200
: 115.0000
: 263335.15
: 2544509.92
: -151.33158
: 60.95803
: UNOCAL
: 1122.00
:
Common Well Name
: GP-52
MEASURED
TVD
X Offset
0 00
90 00
180 00
264 00
382 00
443 00
531.00
591 00
668 00
678 00
767 00
887 00
1076 00
1122.00
0.00
90.00
180.00
264.00
381 99
442 99
530 93
590 83
667 73
677 72
766 70
886.69
1075.66
1121.66
0.01
0.19
0 32
0 66
0 32
0 10
0 35
1 48
3 16
3 35
5 01
6 85
9 60
9 79
Common Well Name
: GP-52
MEASURED Inclination
Azimuth
0.00
90.00
180.00
264.00
382.00
443.00
531.00
591.00
668.00
678.00
767.00
887.00
1076.00
1122.00
0.00
0.36
0.46
0.24
0.31
0.65
3 25
3 55
2 15
1 84
0 54
1 38
0 50
0.30
0.00
139.20
190.80
21.40
224.10
187 20
160 60
160 60
144 70
137 60
85 30
49 80
143 70
145 00
Y Offset
0 O8
-0 17
-0 92
-0 92
-0 67
-1 17
-4 17
-7 42
-10 92
-11 17
-11 92
-11 17
-11 42
-11 92
X Coordinate
263335 16
263335 34
263335 47
263335 81
263335 47
263335 25
263335 50
263336 63
263338 31
263338 50
263340 16
263342 00
263344 75
263344 94
Y Coordinate
2544510 00
2544509 75
2544509 00
2544509 00
2544509 25
2544508 75
2544505 75
2544502 50
2544499 00
2544498 75
2544498 00
2544498 75
2544498 50
2544498 00
UNOCAL
Granite Point Platform
Cook Inlet, Alaska
Leg #4, Slot #5
Well #GP55
Directional &
Navigation Drilling
Completion Report
DDS: T DUNN, D YOUNG
Job Number' 450-87818
Start Date' 16-Aug-97
SbrR~E~C'ALbOLAfrOfl AhCl FI~6 o KShffET .o..o. 0450-87810 Sidetrack No. ___. Page .... ~__ of .... ~ ......
~ ; [1[~: I ~ Company UNOCAL Rig Contractor & No. Nabors Alaska- E156 Field G~NITE POINT FIELD ~
Well Name & No. GRANITE POINT P~TFORM/GP55 Su~ey Section Name Definitive Suwey BHI Rep. T DUNN, D YOUNG
WELL DATA ~
._
Target ~D (~ Target Coord. N/S Slot Coord. N/S -2427.97 Grid Correction 0.000 Depths Measured From: RKB ~] MSL~ SS~
Target Description Target Coord. E~ Slot Coord. E~ 1297.85 Magn. Declination 22.090 Calculation Method MINIMUM CURVATURE
Target Direction (DD) Build~Walk~DL per: 10~ 30mO 10mO Ve~. Sec. Azim. 210.58 Magn. to Map Corr. 22.090 Map No~h to: OTHER
i
SURVEY DATA
Suwey Suwey Incl. Hole Course Ve,ical Total Coordinate Build Rate Walk Rate
Date Tool Depth Angle Direction Length ~D Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment
Type (~ (DD) (DD) (~ (~ (~ (~ (per..100 ~ Drop (-) Left (-)
0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT
19-AUG-97 GSS 90.00 0.28 154.70 90.00 90.00 0.12 -0.20 0.09 0.31 0.31 ~ ....
--
19-AUG-97 GSS 180.00 0.23 335.90 90.00 180.00 0.14 -0.23 0.11 0.57 -0.06
19-AUG-97 GSS 206.00 0.20 173.70 26.00 206.00 0.15 -0.23 0.10 1.63 -0.12
19-AU G-97 GSS 350.00 0.46 353.50 144.00 350.00 -0.11 0.09 0.06 0.46 0.18
19-AUG-97 GSS 440.00 0.89 326.40 90.00 439.99 -0.70 1.04 -0.37 0.58 0.48
19-AUG-97 GSS 528.00 0.92 260.60 88.00 527.98 -0.55 1.49 -1.44 1.12 0.03
19-AUG-97 GSS 614.00 1.69 252.40 86.00 613.96 0.84 0.99 -3.33 0.92 0.90
......
19-AUG-97 GSS 704.00 1.95 236.60 90.00 703.91 3.21 -0.25 -5.88 0.63 0.29
20-AUG-97 GSS 796.00 1.00 164.10 92.00 795.89 5.17 -1.88 -6.96 2.07 -1.03
' 20-AUG-97 GSS 886.00 1.33 125.40 90.00 885.87 5.79 -3.25 -5.90 0.92 0.37
20-AU G-97 GSS 975.00 1.18 131.20 89.00 974.85 6.05 -4.45 -4.37 0.22 -0.17
20-AUG-97 GSS 1064.00 1.45 132.00 89.00 1063.83 6.44 -5.80 -2.84 0.30 0.30
20-AUG-97 GSS 1152.00 1.01 133.40 88.00 1151.81 6.83 -7.08 -1.45 0.50 -0.50
20-AUG-97 GSS 1273.00 1.19 132.90 121.00 1272.78 7.34 -8.67 0.25 0.15 0.15
21-AUG-97 GSS 1459.00 1.24 117.20 186.00 1458.74 7.63 -10.90 3.45 0.18 0.03
21-AUG-97 GSS 1524.00 1.39 150.80 65.00 1523.73 7.99 -11.91 4.46 1.19 0.23
21-AUG-97 MWD 1594.00 4.00 197.30 70.00 1593.65 10.79 -14.99 4.15 4.58 3.73
_ .,
21-AUG-97 MWD 1684.00 5.64 196.30 90.00 1683.33 18.13 -22.23 1.98 1.82 1.82 -1.11
21-AUG-97 ~ MWD 1738.00 6.50 206.54 54.00 1737.03 23.75 -27.51 -0.14 2.55 1.59 18.96
~-AUG-97 MWD 1871 .~ 12.20 213.53 133.00 1868.21 45.32 -45.98 -11.27 4.36 4.29 5.26
....
~UG-97 MWD 1~5.~ 16.35 210.77 94.00 1959.29 68.48 -65.63 -23.53 4.47 4.41 -2.94
~-AUG-97 ~D ~.~ 17.94 210.80 93.00 2048.15 95.89 -89.18 -37.56 1.71 1.71 0.03
._
.....................................................................................................................
~-AUG-97 ~D 2152.~ ~.35 211.59 94.00 2136.95 126.71 -115.55 -53.54 2.58 2.56 0.84
i ~
· ;[l[~: I ::(---1 Company UNOCAL Rig ContractOr & No, Nabors Alaska - #156 Field GRANITE POINT FIELD
Well Name & No, GRANITE POINT PLATFORM/GP55 Survey Section Name Definitive Survey BHI Rep, T DUNN, D YOUNG
WELL DATA
Target TVD (F'r) Target Coord. N/S Slot Coord, N/S -2427,97 Grid Correction 0,000 Depths Measured From: RKB
SS~
Target Description Target Coord, E/W Slot Coord. E/W 1297.85 Magn, Declination 22,090 Calculation Method MINIMUM CURVATURE
Target Direction (DB) Build\Walk\DL per: 100ft[~ 30m~ 10mo Vert. Sec. Azim. 210,58 Magn. to Map Corr, 22,090 Map North to: OTHER
i
SURVEY DATA
Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate
Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment
Type (FT) (DD) (DD) (F'I~ (IT) (F'r) (FT) (Per 100 FT) Drop (-) Left (-)
22-AUG-97 MWD 2246,00 24.60 212.01 94,00 2223.79 162.63 -146.07 -72,48 4,52 4,52 0,45
22-AUG-97 MWD 2339.00 27,72 212,37 93,00 2307.25 203.61 -180,76 -94,33 3,36 3,35 0,39
22-AUG-97 MWD 2432.00 30,23 213.35 93.00 2388,60 248,62 -218,60 -118,78 2,75 2.70 1,05
--
22-AUG-97 MWD 2523,00 33.18 211,44 91,00 2466,02 296.41 -258,99 -144,37 3,42 3.24 -2.10
22-AUG-97 MWD 2618.00 36.82 210,33 95,00 2543,82 350,89 -305,75 -172,31 3,89 3,83 -1,17
22-AUG-97 MWD 2712,00 40,92 208.47 94,00 2617,00 409,85 -357,15 -201,23 4,53 4,36 -1.98
22-AUG-97 MWD 2806,00 45,22 209,57 94,00 2685,65 474.00 -413,26 -232,38 4,64 4,57 1,17
22-AUG-97 MWD 2898,00 48.84 211.07 92.00 2748.35 541,30 -471.34 -266.38 4.11 3,93 1.63
22-AUG-97 MWD 2992,00 49,34 211,27 94,00 2809,91 612,34 -532.12 -303,15 0,56 0.53 0,21
22-AUG-97 MWD 3082.00 49,41 211.32 90.00 2868,51 680.64 -590,49 -338,63 0,09 0,08 0.06
22-AUG-97 MWD 3175,00 50,05 209.57 93,00 2928,63 751.60 -651,67 -374,58 1,59 0,69 -1,88
22-AUG-97 MWD 3267.00 49,97 208.55 92,00 2987,75 822,06 -713,28 -408.82 0,85 -0,09 -1,11
-- __
22-AUG-97 MWD 3360.00 49.54 209.02 93,00 3047.83 893.01 -775,49 -443.00 0,60 -0,46 0,51
--
--
22-AUG-97 MWD 3453,00 48.82 209.53 93.00 3108.63 963,37 -836,88 -477,41 0.88 -0,77 0,55
23-AUG-97 MWD 3547.00 49,23 209,93 94,00 3170.27 1034,33 -898.51 -512.61 0,54 0.44 0.43 ~.:-
: 23-AUG-97 MWD 3640.00 49,93 209.59 93.00 3230,56 1105.12 -959.97 -547,75 0.80 0.75 -0,37 ,~::
__
23-AUG-97 MWD 3733.00 49,63 210.22 93.00 3290.62 1176,13 -1021.53 -583,15 0.61 -0.32 0.68 '_-:~. ,. :, ...
23-AUG-97 MWD 3824,00 50,09 211,86 91.00 3349,28 1245.69 -1081,1 3 -619,02 1,47 0,51 1,80 ~ ' ~' -- !~'~
,
23-AUG-97 MWD 3917,00 50.21 209.96 93.00 3408.88 1317.08 -1142.38 -655.70 1.57 0.13 -2.04 .-.
,.-. ~-_-.. ·
23-AUG-97 MWD 4011,00 50.50 210.04 94.00 3468.85 1389.46 -1205,07 -691.89 0.32 0.31 0,09 ~i '~':' : '"'
23-AUG-97 MWD 4197.00 50.86 210.00 186.00 3586.71 1533.34 -1329.66 -763.88 0,19 0,19 -0,02 . .~.
,~'~?
23-AUG-97 MWD 4479.00 51.07 209.13 282,00 3764,32 1752.35 -1520,18 -871.95 0.25 0,07 -0.31
--
23-AUG-97 MWD 4667.00 51.35 209,59 188.00 3882.09 1898.85 -1647.89 -943.80 0,24 O, 15 0.24
23-AUG-97 MWD 4802.00 50,56 208.61 135.00 3967,13 2003,66 -1739,50 -994,79 0,81 -0.59 -0.73
- $ORVEYCALCULATION AND FIELD WORKSHEET ' Job No. 0.50-87619Sidetrack No. Page.... .3.__ of 3
Company UNOCAL Rig Contractor & No. Nabors Alaska- #156 Field GRANITE POINT FIELD
Well Name & No. GRANITE POINT PLATFORM/GP55 Survey Section Name Definitive Survey BHI Rep. T DUNN, D YOUNG
WELL DATA
Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -2427.97 Grid Correction 0.000 Depths Measured From: RKB ~1 ~" MSL [-] SSI
Target Description Target Coord. E/W Slot Coord. E/W 1297.85 Magn. Declination 22.090 Calculation Method MINIMUM CURVATURE
Target Direction (OD) Build\Walk\DL per: 100ft~ 30m[--] lomE] Vert. Sec. Azim. 210.58 Magn. to Map Corr. 22.090 Map North to: OTHER
i
SURVEY DATA
Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate
Date Tool Build (+) Right (+) Comment
Type Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL
(F'r) (DD) (DD) (Fl') (F-r) (FT) (FT) (Per ~00 FT) Drop (-) Left (-)
23-AUG-97 MWD 4956.00 50.33 208.36 154.00 4065.20 2122.32 -1843.86 -1051.42 0.19 -0.15 -0.16
; 23-AUG-97 MWD 5011.00 50.30 208.30 55.00 4100.33 2164.61 -1881.12 -1071.51 0.10 -0.05 -0.11
--
--
,
--
--
--
--
- _
--
Uno~al Agricultural Products
Diversified Business Group
909 West 9th Ave.
Anchorage, AK 99501
Tele: (907) 263-7889
Fax: (907) 263-7828
E-maih childersd@orion, unocal, com
UNOCAL
Debra Childers
Geoscience C/erk
DATA TRANSMITTAL 97-32
September 23, 1997
To:
Laurie Taylor
3001 Porcupine
Anchorage, AK 99501
Alaska Oil & Gas
From:
Debra Childers
909 W. 9th Avenue
Anchorage, AK 99519-6247
Unocal
Transmitting the following items'
,-.
Granite Point 22-13 RD 2 11550-12810 ~'
.... : :'~ 12810-13934 "'
Granite Point 53 1080-2130-'
: ~. ',~ ~: 2130-2970 '
2970-3480 -~
3480-4410 '
4410-5250 -
5250-6480 '
6480-7320 '
7320-8400"
8400-9480
9480-10560'
10560-11640
11640-12660 '
12660-13540"
13540-13950'
Granite Point 53, C5 Lateral 13380-14460"
,_
14460-15540
15540-16657-
Granite Point 53, Sidetrack 1 13880-14556
Granite Point 54 ;% - ' ,'.: 9000-11160
Granite Point 55 1320-2400
: ,-,.',, " 2430-3480
3510-4560
4590-§5t0
Please acknowled§¢ ?eceipt by si__clninq and returninq one copy of this transmittal or FAX to (907) 263-7828 .
Received by: , ~'~"<-~-'~'-'¢,'-"~--,. ~-:~¢ ~'~-~---,, Date:
TONY KNOWLE$, GOVERNOR
ALASKA OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
August 7. 1997
Dale Haines
Drilling Manager
Union Oil Company of California
P O Box 196247
Anchorage, AK 99519
Re:
Granite Point Field GP #55
Union Oil Company of California
Permit No: 97-145
Sur. Loc. 2437'FNL, 1303'FWL, Sec. 13. T10N, RI2W, SM
Btmhole Loc. 2350'FNL, 500 'FEL. Sec. 27, T10N. R12W. SM
Dear Mr. Haines:
Enclosed is the approved application for permit to drill the above referenced well.
The pe~Tnit to drill does not exempt you from obtaining additional permits required by law from
other governmental agencies, and does not authorize conducting drilling operations until all other
required permitting determinations are made. The waivers for reduced directional survey points
and no diverter while drilling 17 1/2".hole are approved.
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035.
Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the
surface casing shoe must be given so that a representative of the Commission may witness the
test. Notice may be given by contacting the Commission at 279-1433.
·
Chairman
BY ORDER OF THE COMMISSION
dlf/Enclosures
CC'
Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
STATE OF ALASKA
ALAS OIL AND GAS CONSERVATION COM~ SION
PERMIT TO DRILL
20 AAC 25.005
la. Type of work Drill ~ Redrill B lb. Type of well. ExploratoryB Stratigraphic Test B Development OilB
Re-Entry BI Deepen BI Service E] Development Gas B Single Zone'-] Multiple Zone~]
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
Union Oil Company of California (Unocal) 114.75 RKB feet Granite Point Field
3. Address 6. Property Designation
ADL 18761 Middle Kenai "C" Sands
P.O. Box 196247, Anchorage, AK 99519 ADL 374044 & 374045
4. Location of well at surface Granite Point Pltf. Slot 4, Condr 1 7. Unit or property name 11 .Type Bon (SEE 20 ACC 25.025)
2,437' FNL, 1,303' FWL, Sec 13, T10N, R12W, SM Granite Point Field AK Statewide Oil & Gas Bond
At top of productive interval 15,141' 8. Well number Number
50' FSL, 11,00' FWL, Sec 23, T10N, R12W, SM GP #55 U62 - 9269
At total depth 18,141' 9. Approximate spud date Amount
2,350' FNL, 500' FEL, Sec 27, T10N, R12W, SM 7/15/97 $200,000
12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed dep' (MD and TVD)
property line
50 feet See Clearance Report feet 10209 18,060'/10,735' feet
16. To be completed for deviated wells 17. Anticipated Pressur~ (see 20 AAC 25.035 (e)(2))
Kickoff depth 1,90o feet Maximum hole angle 79 Maximum surface psig At total depth (TVD) 986 psig
18. Casing program I Setting Depth
size Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
17-1/2" 13-3/8" 68 K-55 BTC 1,053 47 47 1100 1100 2500 ft3
12-1/4" 9-5/8" 47 L-80 BTC 4,453 47 47 4500 4146 3383 ft3
8-1/2" 7" 29 P-110/L-80 TKC BTC 15,083 47 47 15130 10113 500 ft3
6" 5" 15 L-80 SC-BTC 3,341 14800 ;10015' 18141 10735 410 ft3
19. To be completed for Redrill, Re-entry, and Deepen Operations
Present well condition summary
Total depth: true measured vertical feet feet Plugs(measured) 0RI$INAL
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented Measured depth True vertical depth
Structural
Conductor 294' 26" Driven 294' RKB
Surface il) ,.~"
Intermediate
Production
Liner :JUL
Perforation depth: measured See attached
true vertical See attached ' *~- ' '
20. Attachments Filing fee ~ Property plat k~ BOP Sketci[~ Siverter SketchE] Drilling program [~
Drilling fluid program 0 Time vs depth plot [] Refraction analysis--~ Seabed report [] 20 AAC 25.050 requirements~
21. I hereby certity that the toregoing is true and correct to the best ot my knowledge
Signed ~/;..~(~, (_.. ¢~1 ~ Title Drilling Manager Date 07/1/97
Commission Use Only
Permit Number I API number I Appro~al.~da~ I See cover letter
<~7_//~2,_,~''' 50-~',,~'-' ~-.-O ~"//~' ,-. ~7 for other requirements
Conditions of approval Samples required F---] Yes,~] No Mud log required E] Yes"J~] No
Hydrogen sulfide measures [~ Yes E] No Directional survey required ,~ Yes D No
Required workingpressureforlCOPE E~ 2M; E] 3M; ~ 5M; n 10M;E] 15M
Other: Original Signed By by the order of
Approved by David W. Johnston commissioner the commission gat~ ""
· ..
Form 10-401 Rev. 12-1-85 Submit in triplicate
Unocal Corporation
Agricultural Products
909 West 9th Avenue, P.O. Box 196247
Anchorage, Alaska 99519-6247
Telephone (907~276-7600
UNOCAL
June 28, 1997
AOGCC
Attn: Mr. Robert Crandall
3001 Porcupine Drive
Anchorage, AK 99501
Dear Mr. Crandall:
This letter is in reference to UNOCAL's previous requests for a variance from Article i 20
AAC25.050 Deviation--concerning survey frequency.
AOGCC Regulation Article 1 20 AAC25.050 requires surveys to be taken at least 100 ft apart
while drilling Granite Point #55. We are then requesting a variance; so that we can survey at
least 500 ft apart during the four tangent sections. The first tangent section will start at 950 ft
(MD) and will end at 1,900 ft (MD). The section tangent section will start ~ 4,470 ft (MD) and
will end at 6,100 ft (MD). The third tangent section will start ~ 7,735 ft (MD) to 15,131 ft
(MD). The fourth and final tangent section will start ~ 15,500 ft (MD) to 18,141 ft (MD).
The proposals listed above are in reference to the Proposed AOGCC Regulations (see page 29
Dated 10/4/96). We thank you for the opportunity to submit this proposal and will be happy to
answer any of your questions. Please contact Mitchell Damm ~ 263-7679 if further details are
required.
Sincerely,
Dale Haines
Drilling Manager
mwd '
RECEIVED
JUL. i 0:199~
~aska 0il & Gas Cons, Cornmissiort
Anchorage
RKB = 115'; 43.44~ Rig Floor to Wellhead
Kvaerner SMS Wellhead
5
6
7
8
TOL @ 14,800'
GRAN~ POINT PLATFORM
WELL 4/55
PROPOSED COMPLETION:
CASING AND TUBING DETAIL
SIZE WT GRADE CONN TOP BOTTOM
33" Outside conductor 47 229
26" Inside Conductor 47 294
13-3/8 68 K~55 BTC 47 1,100
9-5/8 47 L-80 BTC 46 73
9-5/8 53.5 P-110 BTC 73 4,500
7" 29 P~ 110 TKC-BTC 45 6,000
7" 29 L-80 TKC-BTC 5,960 15,130
5" 15 L-80 SC-KC-BTC 14,800 18,141
Baker 5" HMC liner hanger Ca 14,800'
3-l/2" 9.2 L-80 SC BTC
44 14,820
JEWELRY DETAIL
NO. ITEM DEPTH
1
2
3
4
5
6
7
8
Kvaerner Tubing Hanger 44'
(AB TC-4S Up X STD VAM DWN)
3.6' STD VAM x Buttress Pup JT
HES XXO Safety Valve Landing 300'
Nipple (il) = 2.813")
McMm-ry-MACCO SMO- 1 Gas Lift Mandrels with
1- l/2" Valves:
HES Seal Assembly with Nitrile/Flourel
molded seals
HES Packer
HES "X' Nipple ID = 2.813"
Wireline Muleshoe Re-entry Guide
C-5 SAND
PERFORATION DATA
TOP BTM ZONE SPF DATE COMMENTS
15,130 18,141 C-5 6
TCP
PDTD = 18~060
MAX HOLE ANGLE = 79° @ 15,477'
O:\DRILLING\SCIlEMAT1C\GP\GPP\Gp55 prop l,doc
RF!VISED: 6/25/97
DRAWN BY: MW[)
1997 GRANITE POINT DRILL'~NG PROGRAM
C-5 STRUCTURE MAP
FIIJ,-UP ~ ~
ANN~
BOP
13%'3000 pm
PIPE RAMS
13%'§000 psi
BLIND RAMS
FLOW
I{/I.I. [7'.,.~/[IT-~/1]- SPOOL -F'-..~
~E 5000 psi ,I I{ 4" 5000
psi
I
1
P~E ~S
13%"5000 pm ~
RISER
lS ~y~"
5000 psi
COOK INL ET PLATFORMS
BOP STACK
13%~ 5000 psi
HEADER SEC TION
FRONT VIEW
BUFFER TANK
FRONT VIEW
TOP
OAUGE & REIm,tOIE PANEL
I'RANSMITTER
SAU(.;E FLANGE
BEHIND lEADER
3 ~
3A
5 2
$ 2
7
Bl:l.nd. Flange, 4 1/15" -
9 1
'l'r'S:lL~L=~Sr FIG', 2 1/16w
50O0t w/ 2 - 2" LPT
wlllla chc~ w! NP$ ~
10 2
9/16" -
11 3
5 - ~ 17P.q f. lcn~ bloc~,
4X4X3X3X2
17 ].
UNOCAL
GRANITE POINT PLATFORM
WELL #55
DEPTH INTERVAL
MUD TYPE
MUD ADDITIVES
POTENTIAL PROBLEMS
0 - 1000' MD, 1000' TVD
17-1/2" HOLE
13-3/8" CASING
GENERIC MUD //2
M-I GEL / M-I BAR/SODA ASH /
CAUSTIC SODA / LIME/INLET WATER
HOLE CLEANING/GRAVEL / GAS KICK /
LOST CIRCULATION
TREATMENTS/PROCEDURES
1. Drill this interval with inlet water and vis¢osified sweeps. Build sweeps as
required by hole conditions.
2. Use Durogel and/or FIo-Vis to viscosify inlet water for sweeps.
3. Drill hole.
4. After reaching T.D. for this interval it may be necessary to spot a viscous pill
on bottom prior to running casing.
Mud Density
Funnel Viscosity
Plastic Viscosity
Yield Point
Gels
Fluid Loss (APl)
Ph
8.8 - 9.4 ppg
44 - 100 sec/qt
10 - 15 cps
10 - 30 #/100 ft2
8- 20
No Control
8.5- 9.5
NOTE: DO NOT EXCEED M.A.C. of products or use products not approved in the
discharge permit. See letter requesting authorization for list of approved products
and M.A.C.
DM-229
(61261971BM)
UNOCAL
GRANITE POINT PLATFORM
WELL #55
DEPTH INTERVAL
4500' MD, 4146' TVD 12 ¼" hole
10,115' MD, 8030' TVD 8 ¼" hole
MUD TYPE /11 GENERIC MUD /12
MUD ADDITIVES
M-I GEL / M-I BAR / SODA
ASH/POLYPAC / SPERSENE / SODIUM
BICARBONATE/ CAUSTIC SODA/
INLET WATER
MUD TYPE /12- NO DISCHARGE MAPCO 200 OIL BASE
MUD ADDITIVES
POTENTIAL PROBLEMS
VG-69/ M-I BAR/ MAPCO 200/
LOWATE/VERSAWET/
VERSACOAT/VERSA HRP/VERSAMOD/
ALCOMER 274/LIME/CACL2
HOLE CLEANING / TIGHT HOLE / BIT
BALLLING / GUMBO CLAYS / HOLE
ENLARGEMENT / GAS KICKS / COAL
SLOUGHING
TREATMENTS/PROCEDURES
1. Use inlet water to drill the 13 3/8" cement, float collar and casing shoe.
2. Drill the first part of the 12 ¼" interval with inlet water and viscosified
sweeps.
,
Displace to Mapco 200 oil base mud in open hole. Displacement depth should
be between 2000' and 3000'. If possible displacement should occur at the
beginning of a new bit run.
4. Displacement Procedure:
NOTE: Use large mesh shaker screens (30-40) during displacement and for up
to two circulations thereafter. Monitor pump strokes and pump rates
continuously during displacement.
a. Conduct a rig team meeting discussing all aspects of displacement.
NOTE: Rig operations should dictate optimum displacement time.
b. Pump a50bbl brine viscous sweep. Pump a 25 bbl Mapco 200 oil mud
viscous sweep. Pump oil mud system stored in beam tank from GP53.
c. Displace in turbulent flow if possible.
d. Reciprocate and rotate drill pipe.
DM-230
(6/26/97/BM)
5~
Drill the 12 ¼" section to T.D. If there are indications that a cuttings bed has
been deposited in the wellbore, the most effective method to clean the
cuttings bed is with mechanical agitation by rotating and reciprocating the drill
string. Maintaining high Iow shear rate rheologies will minimize the formation
of a cuttings bed. Low shear rate rheologies will minimize the formation of a
cuttings bed. Low shear rate rheologies can be elevated with Versamod, Versa
HRP, AIcomer 274 and VG-69. If required, pump high mud weight/high
viscosity sweeps. The 6 and 3 rpm should be maintained at values greater
than 13.
6. Optimize mixing of "dry jobs" in order to minimize the number of wet trips and
any unnecessary increase in mud weight.
OIL MUD MIXING PROCEDURES
7. Build Mapco 200 oil mud system utilizing the following recommendations:
a. Premix and store 10.8 ppg calcium chloride brine.
b. Place Mapco 200 oil in clean mixing tank.
c. Add VG-69 and lime slowly through shear pump to minimize bailing. Shear
for 30 minutes.
d. Add primary emulsifier, Versacoat.
e. Blend for a minimum of 30 minu. tes.
f. Add calcium chloride brine. Blend for a minimum of 30 minutes.
h. Add Versawet/check rheology/add Versamod.
i. Add barite to required mud weight.
-j. Blend for a minimum of 30 minutes.
NOTE:
The most important aspect in mixing an oil mud is the amount of mixing
energy put into the fluids while the brine is being added. The more shear
put into the fluid the smaller the water droplets become and the more
viscous the fluid. The emulsions become more stable as more shear is put
into the fluid.
8. After reaching TD, condition the hole for logging by rotating and reciprocating
the drill string. If required, pump high mud weight/high viscosity sweeps.
9. Run and cement the 9 5/8" casing.
lO.Clean 9 5/8"
as possible.
weight.
casing and drill 8 ~" hole. Mud weights should be kept as Iow
Centrifuge 8 ~" hole mud and add Mapco 200 to reduce mud
DM-229
(61261971BM)
11. Maintain Iow shear rate values with VG-69, Versamod, Alcomer 274 and
Versa HRP. Run and cement 7" casing.
Mud Weight ppg
PV
YP
Gels
O/W
E.S.
HTHP @ 225° F
3 rpm
6 rpm
8.5
15- 22
15- 20
12/25
80/20
800 +
6 cc
>10
>10
9.5
25- 35
15- 20
12/40
80/20
800 +
6 cc
>10
> 10
Mapco 200 bbl
VG-69 ppb
Lime ppb
Versacoat ppb
Versawet ppb
Versamod ppb/Versa HRP/Alcomer
274
CaCI2
Barite/Lowate ppb
Varies w/MW & O/W ratio
4-8
2
4-6
1-2
0-1
34
As Required
NOTE: This mud program is a guideline only. Hole conditions should dictate
actual mud properties.
DM-229
(61261971BM)
4
UNOCAL
Casing Design Summary
Well: GP 55 Field: Granite Point Date: 6/25/97
Casing Mud WT M.S.P.
Size (PPG) (psi)
Design by: Mitchell Damm
Max. Kick Tolerance
(BBLS)
13-3/8" 9 339 95
9-5/8" 9 986 72
7" 7.8 849 326
4-1/2" 7.8 NA NA
Casing Bottom Top Length Wt Grade Thread
Size (FEET) (FEET) (FEET) (LB/FT) Connection
26" 329 47 282
TVD 329 47 282
13-3/8" 1,100 47 1,053 68 K-55 Buttress
TVD 1,100 47 1,053
9-5/8" 4,500 47 4,453 47 L-80 Buttress
TVD 4,145 47 4,098
7" 6,000 47 5,953 29 P- 110 TKC-Buttress
TVD 4,987 47 4,940
7" 15,130 6,000 9,130 29 L-80 TKC-Buttress
TVD 10,115 4,987 5,128
5" 18,141 14,800 3,341 15 L-80 SC: TKC-Buttress
TVD 10,735 9,921 814
Casing Weight Tension Minimum *Collapse *Collapse Collapse
Size W/O BF Top of Strength TDF Pressure #1 Pressure #2 Resist.
Section Tension ~ Bottom ~ Bottom Tesnsion
(LBS) (LBS) (1,000/LBS) (psi) (psi) (psi)
CDF #1 CDF #2
**Burst
Pressure
(psi)
Minimum
Yield
Strength
(psi)
BDF
13-3/8" 71,604 71,604 1,069 14.9 315 NA 1,950
9-5/8" 209,291 209,291 1,086 5.2 1,185 NA 4,760
7" P-110 438,770 438,770 797 1.8 2,893 3,928 8,530
7" L-80 264,770 264,770 587 2.2 2,893 3,928 7,030
4-1/2" 50,115 50,115 289 5.8 NA NA NA
6.2 NA
4.0 NA
2.9 2.2
2.4 1.8
NA NA
2,073
2,023
2,147
2,147
NA
3,450
6,870
9,520
8,160
NA
1.7
3.4
4.4
3.8
NA
* Collapse pressures are calculated using two methods (checks).
l) Difference between two cement slurries (i.e. AVG of a 15.8 PPG (tail) & 14.2 PPG (lead) = 15 PPG.
Subtract a mud of 9.5 PPG = 5.5 PPG = .286 psi/PT gradient X TVD of the casing string.)
2) Difference between Mud Weight on the outside and gas lift gas (0.0 psi/PT) on the inside.
(i.e. Multiply (.052 X MW - 0.0 psi/PT) X the TVD of the Top of Cement.
** Burst pressure is calculated. (BHP ~ the depth of the next casing X TVD next casing) X (0.5 = half of wellbore evacuated).
Kick Tol GP55.xls
6/25/97
Maximum Surface Pressure Calculations
Well: GP 55
Casing Size: 13-3/8"
Depth Interval: 0'-4,500'
Hole Size: 12.25
General Information:
Anticipated Mud Weight (MW): 9.0 PPG
Shoe Depth (Dsho~): 1100 MD
Estimated Fracture Gradient (at the Shoe):
Total Depth (Dm): 4500 MD
Bottom Hole Pressure Gradient (BHPG):
Gas Gradient (GG); (assumes worse case):
Maximum Gas Column Height in wellbore when top of gas is at the shoe (Ht):
0.468 psi/FT
1100 TVD
0.85 psi/FT
4145 TVD
0.45 psi/FT
0.10 psi/FT
1,125 Feet
anticipated Mud Weight)
Maximum Surface Pressure Calculations:
The wellbore volume is determined using the height of gas column in wellbore when top of gas bubble is at the shoe--
during a gas kick situation. A percentage of the gas column height (Hr), found in the Maximum Kick Tolerance Calculations, is used.
Maximum Surface Pressure = Maximum Bottom Hole Pressure - Hydrostatic Pressure (Gas Volume +Mud Volume)
MSP = Pm~x~m- GG*Ht - .052*MW*(Dm-Ht)
MSP = 339 psi
Hydrostatic Pressure at the Shoe Calculations:
The greatest hydrostatic pressure at the shoe (Pshoe) is when the gas bubble reaches the shoe. Assuming a constant
bottom hole pressure is applied while circulating out the gas kick. A conservative estimate would be the maximum
surface pressure plus the hydrostatic pressure at the Shoe Depth (Dshoe).
Pshoe = MSP + .052*MW*Dsho~
Pshoe-- 854 psi FP~hoe= 935 psi
The pressure at the shoe (Pshoe) is less than the fracture pressure at the same shoe.
Therefore the shoe integrity is sufficient to adequately handle a gas kick.
Pressure Differential Across the Shoe:
Pressure differential across the casing shoe = Pshoe - Maximum pore pressure at shoe
DPshoe = Pshoe - Pmax ~ shoe = Pshoe - BHPG * Dshoe
DP shoe= 359 psi
The DPshoe is less that the internal yield of the casing.
At~chora5:.,;.
Kick Tol GP55.xls 13-38" MSP 6/25/97
Maximum Kick Toleran~¢ Calculations
Well: GP 55 Casing Shoe: 13-3/8"
General Information Variables
1 13-3/8" Casing Shoe (from RT)+B6 1,100 Feet (TVD) Dshoe
2 Fracture pressure Gradient 0.85 psi/FT FPG
3 Fracture pressure at the 26" Shoe 935 psi FPshoe
4 Proposed TD of the 9-5/8" Casing Shoe (TVD) 4,145 Feet (TVD) DTD
5 Pore pressure gradient 0.450 psi/FT PpG
6 Maximum anticipated pore pressure @ TD 1,865 psi Pmax@TD
7 Mud Weight See table PPG MW
8 Gas Gradient 0.10 ipsi/FT GG
9 Average open hole size 12.25 Inches ODo.
10 Drillpipe OD 5.00 Inches ODDP
11 Capacity of open hole by drillpipe 0.1214 BBL/FT CAP
12 Height of gas column in wellbore when top of gas is at the shoe HT Feet (TVD) Ht
Assumptions for Granite Point Field:
Fracture Pressure Gradient = .9 PSI/FT.
All calculations assume that water based mud is used and does not take into account gas solubility in oil based mud.
Gas bubble height in wellbore (HO calculation with gas bubble top at 13-3/8" shoe.
FPshoe + Pgas bubble + Pmud = Pmax~ TD
FPshoe + GG*Ht + .052*MYJ*(DrD-Dshoe-Ht) = Pmax@TD
Gas Volume (GV) calculation at 13-3/8" shoe.
GV = CAP* Ht
Kick Tolerance calculation: Gas volume in wellbore at TD.
P 1V1 = P2V2. Assume constant temperature.
Kick Tolerance * Pmax@ TD = GV * FP
Mud Weight Gas Bubble Height Gas Volume~Shoe Kick Tolerance
(PPG) (Fee0 (BBLS) (BBLS)
8.4 1,187 144 72
8.6 1,243 151 76
8.8 1,295 157 79
9.0 1,345 163 82
9.2 1,391 169 85
9.4 1,436 174 87
9.6 1,477 179 90
9.8 1,517 184 92
10.0 1,555 189 95
10.2 1,591 193 97
10.4 1,625 197 99
10.6 1,658 201 101
10.8 1,689 205 103
11.0 1,719 209 105
Kick Tol GP55.xls
6/25/97
,i .... '"-;'~ ()ii ,~. Gar.: Con.,.;.
Maximum Surface Pressure Calculations
Well: GP 55
Casing Size: 9-5/8"
Depth Interval: 0'-15,130'
Hole Size: 8.50 "
General Information:
Anticipated Mud Weight (MW): 9.0 PPG
Shoe Depth (Dsho~): 4500 MD
Estimated Fracture Gradient (at the Shoe):
Total Depth (DT~): 15,130 MD
Bottom Hole Pressure Gradient (BHPG):
Gas Gradient (GG); (assumes worse case):
Maximum Gas Column Height in wellbore when top of gas is at the shoe (HO:
0.468 psi/FI'
4145 TVD
0.85 psi/FI'
10115 TVD
0.50 psi/FT
0.10 psi/FT
1,800 Feet
anticipated Mud Weight)
Maximum Surface Pressure Calculations:
The wellbore volume is determined using the height of gas column in wellbore when top of gas bubble is at the shoe--
during a gas kick situation. A percentage of the gas column height (Hr), found in the Maximum Kick Tolerance Calculations, is used.
Maximum Surface Pressure = Maximum Bottom Hole Pressure - Hydrostatic Pressure (Gas Volume +Mud Volume)
MSP = Pm~x~'r~ - GG*Ht - .052*MW*(DTr~-Ht)
MSP = 986 psi
Hydrostatic Pressure at the Shoe Calculations:
The greatest hydrostatic pressure at the shoe (Pshoe) is when the gas bubble reaches the shoe. Assuming a constant
bottom hole pressure is applied while circulating out the gas kick. A conservative estimate would be the maximum
surface pressure plus the hydrostatic pressure at the Shoe Depth (Dshoe).
Pshoe = MSP + .052*lVlV~*Dshoe
Pshoe= 2,926 psi FP~hoe= 3,523 psi
The pressure at the shoe (Pshoe) is less than the fi'acture pressure at the same shoe.
Therefore the shoe integrity is sufficient to adequately handle a gas kick.
Pressure Differential Across the Shoe:
Pressure differential across the casing shoe = Pshoe - Maximum pore pressure at shoe
DPshoe = Pshoe - Pmax ~ shoe = Pshoe - BHPG * Dshoe
DP shoe = 853 psi
The DPshoe is less that the internal yield of the casing.
Kick Tol GP55.xls 9-58" MSP 6/25/97
Maximum Kick Tolerance Calculations
Well: GP 55 Casing Shoe: 9-5/8"
General Information Variables
1 9-5/8" Casing Shoe (from RT) 4,145 Feet (TVD) Dshoe
2 Fracture pressure Gradient 0.85 psi/FT FPG
3 Fracture pressure at the 9-5/8" Shoe 3,523 psi FPshoe
4 Proposed TD of the 7" Casing Shoe (TVD) 10,115 Feet (TVD) DTv
5 Pore pressure gradient 0.50 psi/FT PpG
6 Maximum anticipated pore pressure ~ TD 5,058 psi PmaxC~TD
7 Mud Weight See table PPG MW
8 Gas Gradient 0.10 psi/FT GG
9 Average open hole size 8.50 Inches ODoH
10 Drillpipe OD 5.00 Inches ODDP
11 Capacity of open hole by drillpipe 0.0459 BBL/FT CAP
12 Height of gas column in wellbore when top of gas is at the shoe HT Feet (TVD) Ht
Assumptions for Granite Point Field:
Fracture Pressure Gradient = .9 PSFFT; and Maximum Pore Pressure Gradient = .52 PSI/FT. (GP 13-13; 1967)
All calculations assume that water based mud is used and does not take into account gas solubility in oil based mud.
Gas bubble height in wellbore (HO calculation with gas bubble top at 9-5/8" shoe.
FPshoe + Pgas bubble + Pmud = Pmax~ TD
FPsho~ + GG*Ht + .052*MW*(DTD-Dsho~-Ht) = Pma~OXo
Gas Volume (GV) calculation at 9-5/8" shoe.
GV = CAP*Ht
Kick Tolerance calculation: Gas volume in wellbore at TD.
P 1V1 = P2V2. Assume constant temperature.
Kick Tolerance * Pm~xO zv = GV * FP
Mud Weight Gas Bubble Height Gas Volume ~ Shoe Kick Tolerance
(PPG) (Feet) (BBLS) (BBLS)
8.4 3,187 146 102
8.6 3,271 150 105
8.8 3,349 154 107
9.0 3,423 157 109
9.2 3,493 160 112
9.4 3,559 163 114
9.6 3,622 166 116
9.8 3,682 169 118
10.0 3,738 172 119
10.2 3,792 174 121
10.4 3,844 176 123
10.6 3,893 179 124
10.8 3,940 181 126
11.0 3,984 183 127
Kick Tol GP55.xls 6/25/97
Maximum Surface Pressure Calculations
Well: GP 55
Casing Size: 7"
Depth Interval: 0'-18,141'
Hole Size: 6.00
General Information:
Anticipated Mud Weight (MW):
Shoe Depth (Dsho~):
Estimated Fracture Gradient (at the Shoe):
Total Depth (Dm): 18,141 MD
Bottom Hole Pressure Gradient (BHPG):
Gas Gradient (GG); (assumes worse case):
Maximum Gas Column Height in wellbore when top of gas is at the shoe (Ht):
7.8 PPG
15,130 MD
0.406 psi/FT
10115 TVD
0.85 psi/FT
10735 TVD
0.20 psi/FT
0.10 psi/FT
10,000 Feet
anticipated Mud Weight)
Maximum Surface Pressure Calculations:
The wellbore volume is determined using the height of gas column in wellbore when top of gas bubble is at the shoe--
during a gas kick situation. A percentage of the gas column height (Hr), found in the Maximum Kick Tolerance Calculations, is used.
Maximum Surface Pressure = Maximum Bottom Hole Pressure - Hydrostatic Pressure (Gas Volume +Mud Volume)
MSP = Pm~m- GG*Ht - .052*MW*(Dm-Ht)
MSP = 849 psi
Hydrostatic Pressure at the Shoe Calculations:
The greatest hydrostatic pressure at the shoe (Pshoe) is when the gas bubble reaches the shoe. Assuming a constant
bottom hole pressure is applied while circulating out the gas kick. A conservative estimate would be the maximum
surface pressure plus the hydrostatic pressure at the Shoe Depth (Dshoe).
Pshoe = MSP + .052*lVFvV*Dshoe
Pshoe= 4,952 psi FPshoe= 8598 psi
The pressure at the shoe (Pshoe) is less than the fracture pressure at the same shoe.
Therefore the shoe integrity is sufficient to adequately handle a gas kick.
Pressure Differential Across the Shoe:
Pressure differential across the casing shoe = Pshoe - Maximum pore pressure at shoe
DPshoe = Pshoe - Pmax ~ shoe = Pshoe - BHPG * Dshoe
DP shoe= 2,929 psi
The DPshoe is less that the internal yield of the casing.
Kick Tol GP55.xls 7" MSP 6/25/97
Maximum Kick Tolerance Calculations
Well: GP 55 Casing Shoe: 7"
General Information Variables
1 7" Casing Shoe (from RT) 10,115 Feet (TVD) Dshoe
2 Fracture pressure Gradient 0.85 psi/FT FPG
3 Fracture pressure at the 7" Shoe 8,598 psi FPsho~
4 Proposed TD of the 5" Casing Shoe (TVD) 10,735 Feet (TVD) DTD
5 Pore pressure gradient 0.20 psi/FT PpG
6 Maximum anticipated pore pressure ~ TD 2,147 psi Pmax@TD
7 Mud Weight See table PPG MW
8 Gas Gradient 0.10 psi/FT GG
9 Average open hole size 6.00 Inches ODoH
10 Drillpipe OD 3.50 Inches ODDP
11 Capacity of open hole by drillpipe 0.0231 BBL/FT CAP
12 Height of gas column in wellbore when top of gas is at the shoe HT Feet (TVD) Ht
Assumptions for Granite Point Field:
Fracture Pressure Gradient = .9 PSI/FT; and Maximum Pore Pressure Gradient = .52 PSI/FT. (GP 13-13; 1967)
Ail calculations assume that water based mud is used and does not take into account gas solubility in oil based mud.
Gas bubble height in wellbore Ott) calculation with gas bubble top at 7" shoe.
FPshoe + Pgas bubble + Pmud = Pmax~ TD
FPshoe + GG*Ht + .052*MVq*(DTD-Dshoe-Ht) = Pmax@TO
Gas Volume (GV) calculation at 7" shoe.
GV = CAP*Hr
Kick Tolerance calculation: Gas volume in wellbore at TD.
P1V1 = P2V2. Assume constant temperature.
Kick Tolerance * Pmax@ ~'~) = GV * FP
Mud Weight Gas Bubble Height Gas Volume ~ Shoe Kick Tolerance
(PPG) (Feet) (BBLS) (BBLS)
7.6 22,682 523 2,095
7.8 21,931 506 2,025
8.0 21,230 490 1,960
8.2 20,573 474 1,900
8.4 19,957 460 1,843
8.6 19,378 447 1,789
8.8 18,832 434 1,739
9.0 18,318 422 1,691
9.2 17,831 411 1,647
9.4 17,371 401 1,604
9.6 16,935 390 1,564
9.8 16,520 381 1,526
10.0 16,127 372 1,489
10.2 15,752 363 1,455
10.4 15,395 355 1,422
10.6 15,054 347 1,390
10.8 14,729 340 1,360
11.0 14,418 332 1,331
Kick Tol GP55.xls 6/25/97
Unocal Alaska Business Unit
Granite Point Platform
Well #55
Prepared by: Mitch Damm Date: 6/14/97 Revision #2
Estimate for Grass Roots Oil Well.
UNOCAL )
No. Preliminary Procedure Time CUM CUM Depth Depth
Estimate Time Time In Out
(Hours) (Hours) (Days) (Feet) (Feet)
Move and prep rig.
Change out liners
Skid rig over slot 4-4.
Cut open conductor and weld squinch joint to producition deck.
Cuttings line rerouting. Extra time required due to piping configuration.
Clean pits.
Install Riser and Bell Nipple.
Total Rig Mobilization. 42.0 42 1.8 294
42 1.8 294
17-1/2" Hole Section 42 1.8 294
1 PU 5" drillpipe, drill collars, and HWDP 14.0 56 2.3 294
2 MU BHA#1 3.0 59 2.5 294
3 RIH. Circulate well clean. 2.0 61 2.5 294
4 RU scientific. Gyro Conductor. 4.0 65 2.7 294
5 Rotary drill from 294' to 1,100' taking single shot surveys. 15.0 80 3.3 294 1,200
6 Circ and condition hole. 1.0 81 3.4 1,200
7 POOH with BHA #1. 1.5 83 3.4 1,200
8 LD BHA. 2.0 85 3.5 1,200
9 RU Casing Crew 2.0 87 3.6 1,200
10 RIH with 13-3/8" Casing to 1,100'. 5.0 92 3.8 1,200
11 PU wellhead and land wellhead. 1.0 93 3.9 1,200
12 RU to pump cement 2.0 95 3.9 1,200
13 Pump cement job taking returns to surface. 4.0 99 4.1 1,200
14 Release and LD running tools. RD cementing Eq. 2.0 101 4.2 1,200
15 LD riser. Cut off squinch joint. 3.0 104 4.3 1,200
16 NU XO spool, riser and 13-5/8" BOPE. 10.0 114 4.7 1,200
17 Test BOPE. 4.0 118 4.9 1,200
118 4.9 1,200
12-1/4" Hole Section 118 4.9 1,200
18 MUBHA#2. (MWD and Motor) 4.0 122 5.1 1,200
19 RIHwithBHA. 2.0 124 5.1 1,200
20 Drill cement. Test casing. 1.5 125 5.2 1,200
21 Drill out of shoe and perform leak-off test. 2.5 128 5.3 1,200
22 Drill 12-1/4" hole f/1,100' to 5,000'. 80.0 208 8.6 1,100 5,000
23 CBU and condition hole 2.0 210 8.7 5,000
24 POOH with BHA. 3.0 213 8.9 5,000
25 LD BHA. 2.0 215 8.9 5,000
26 Change pipe rams and test BOPE. 2.0 217 9.0 5,000
27 RUcasing crew 1.5 218 9.1 5,000
28 RIH with 9-5/8" casing. 10.0 228 9.5 5,000
29 Land hanger and circulate 1.0 229 9.5 5,000
30 Pump Cement Job 5.0 234 9.8 5,000
31 Release running tool. RIH with wash tool. 2.5 237 9.9 5,000
32 RIH with CSG hanger packoff. 5.0 242 10.1 5,000
Estimated
Date
15-Jul-97
16-Jul-97
16-Jul-97
16-Jul-97
17-Jui-97
17-Jul-97
17-Jul-97
17-Jul-97
18-Jul-97
18-Jul-97
18-Jul-97
18-Jui-97
18-Jul-97
18-Jul-97
18-Jul-97
18-Jul-97
19-Jul-97
19-Jul-97
19-Jul-97
19-Jui-97
19-Jul-97
19-Jul-97
19-Jul-97
20-Jul-97
20-Jul-97
20-Jul-97
20-Jul-97
23-Jul-97
23-Jul-97
23-Jul-97
23-Jul-97
24-Jul-97
24-Jul-97
24-Jul-97
24-Jul-97
24-Jul-97
24-Jul-97
25-Jul-97
GP55 AFE est 2.XLS Page 1 of 6 7/1/97
Unocal Alaska Business Unit
Granite Point Platform
Well #55
Prepared by: Mitch Damm Date: 6/14/97 Revision #2
Estimate for Grass Roots Oil Well.
UNOCAL
No. Preliminary Procedure Time CUM CUM Depth Depth
Estimate Time Time In Out
(Hours) (Hours) (Days) (Feet) (Feet)
33 Run wear bushing 0.5 242 10.1 5,000
10.1 5,000
8-1/2" Hole Section 242 l 0.1 5,000
34 Clean pits for OBM and transfer OBM from Beam tanks. 7.0 249 10.4 5,000
35 Change Rams. TestBOP's 4.0 253 10.5 5,000
36 MUBHA#4 4.0 257 10.7 5,000
37 RIH with BHA 3.0 260 10.8 5,000
38 Drill Cement and pressure test casing 3.0 263 11.0 5,000
39 Drill out of shoe and perform leak off test. 2.0 265 11.0 5,000 5,010
40 Drill 8-1/2"hole. 125.0 390 16.3 5,010 10,010
41 CBU. 1.0 391 16.3 10,010
42 POOH with BHA. 6.0 397 16.5 10,010
43 BHA handling. 3.0 400 16.7 10,010
44 Cut and strip drilling line. 1.0 401 16.7 10,010
45 Routine Rig Maintenance 1.0 402 16.8 10,010
46 Test BOPE. 5.0 407 17.0 10,010
47 RIH with BHA 4.0 411 17.1 10,010
48 Ream to bottom. 2.0 413 17.2 10,010
49 Drill 8-1/2"hole 84.8 498 20.7 10,010 12,300
50 POOH 8.0 506 21.1 12,300
51 BHAHandling 2.0 508 21.2 12,300
52 RIH with BHA 5.0 513 21.4 12,300
53 Ream to bottom. 2.0 515 21.5 12,300
54 Drilling 8-1/2" hole. 88.9 604 25.2 12,300 13,900
55 POOH 9.0 613 25.5 13,900
56 BHA Handling 2.0 615 25.6 13,900
57 RIH with BHA 6.0 621 25.9 13,900
58 .Ream to bottom. 3.0 624 26.0 13,900
59 Drilling 8-1/2" hole· 76.9 701 29.2 13,900 15,130
60 Circulate bottoms up. 2.0 703 29.3 15,130
61 POOH 10.0 713 29.7 15,130
62 Change pipe rams and test. Pull wear bushing 3.0 716 29.8 15,130
63 RU casing crew 3.0 719 29.9 15,130
64 Run 7" casing 24.0 743 30.9 15,130
65 Land hanger and RU cementing equipment. 2.0 745 31.0 15,130
66 Pump cementjob. 6.0 751 31.3 15,130
67 Release running tool. RIH with wash tool. 1.0 752 31.3 15,130
68 RIH with CSG hanger packoff. 2.0 754 31.4 15,130
69 Run wear bushing 1.0 755 31.4 15,130
70 Lay down 5" drillpipe. Prepare for 8.2 PPG OBM. 18·0 773 32.2 15,130
71 PU 3-1/2" drilpipe 22.0 795 33·1 15,130
~. ¥- }.? 33.1 15,130
6" C-5 Lateral :~ ~ x · ,~ ~ .....
~'~. ~ ~'~' ' 14.0 otalHl~ 33.1 15,130
Estimated Bit Performance = .~ ~ g'~' 160.0 Total FT 33.1 15,130
Page 2 of 6
GP55 AFE est 2.XLS
Estimated
Date
25-Jul-97
25-Jul-97
25-Jul-97
25-Jul-97
25-Jul-97
25-Jul-97
25-Jul-97
25-Jul-97
26-Jul-97
31-Jul-97
31-Jul-97
31-Jul-97
31 -Jul-97
31-Jul-97
31-Jul-97
31-Jul-97
1-Aug-97
1 -Aug-97
4-Aug-97
5-Aug-97
5-Aug-97
5-Aug-97
5-Aug-97
9-Aug-97
9-Aug-971
9-Aug-97
9-Aug-97
9-Aug-97
13-Aug-97
13-Aug-97
13-Aug-97
13-Aug-97
13-Aug-97
14-Aug-97
15-Aug-97
15-Aug-97
15-Aug-97
15-Aug-97
15-Aug-97
16-Aug-97
17-Aug-97
17-Aug-97
17-Aug-97
17-Aug-97
7/1/97
Unocal Alaska Business Unit
Granite Point Platform
Well #55
Prepared by: Miteh Damm Date: 6/14/97 Revision #2
Estimate for Grass Roots Oil Well.
UNOCAL )
No. Preliminary Procedure Time CUM CUM Depth Depth
Estimate Time Time In Out
(Hours) (Hours) (Days) (Feet) (Feet)
71 MU BHA 3.0 798 33.2 15,130
72 RIHwithBHA. 6.0 804 33.5 15,130
73 Drill cement and pressure test casing. 3.0 807 33.6 15,130
74 Drill 10' of formation and perform LOT. 2.0 809 33.7 15,130 15,140
75 Change over to 8.2 PPG OBM. 4.0 813 33.9 15,140
76 Drill 6" hole 14.0 827 34.4 15,140 15,360
77 POOH 5.0 832 34.6 15,360
78 BHA handling. 2.0 834 34.7 15,360
79 RIH with BHA. 6.0 840 35.0 15,360
80 Ream to bottom. 1.0 841 35.0 15,360
81 Drill 6" hole 14.0 855 35.6 15,360 15,520
82 POOH 5.0 860 35.8 15,520
83 BHA handling. 2.0 862 35.9 15,520
84 RIHwithBHA. 6.0 868 36.1 15,520
85 Ream to bottom. 1.0 869 36.2 15,520
86 Drill 6" hole 14.0 883 36.8 15,520 15,680
87 POOH 5.0 888 37.0 15,680
88 BHA handling. 2.0 890 37.1 15,680
89 RIH with BHA. 6.0 896 37.3 15,680
90 Ream to bottom. 1.0 897 37.4 15,680
91 ,Drill 6" hole 14.0 911 37.9 15,680 15,840
92 iPOOH 5.0 916 38.1 15,840
93 BHA handling. 2.0 918 38.2 15,840
94 RIHwithBHA. 6.0 924 38.5 15,840
95 Ream to bottom. 2.0 926 38.6 15,840
96 Drill 6" hole 14.0 940 39.1 15,840 16,000
97 POOH 5.0 945 39.4 16,000
98 BHA handling. 2.0 947 39.4 16,000
99 RIH with BHA. 6.0 953 39.7 16,000
100 Ream to bottom. 2.0 955 39.8 16,000
101 Drill 6"hole 14.0 969 40.4 16,000 16,160
102 POOH 5.0 974 40.6 16,160
103 BOP Test 4.0 978 40.7 16,160
104 BHA handling. 2.0 980 40.8 16,160
105 RIH with BHA. 6.0 986 41.1 16,160
106 Ream to bottom. 2.0 988 41.1 16,160
107 Drill 6" hole 14.0 1002 41.7 16,160 16,320
108 POOH 5.0 1007 41.9 16,320
109 BHA handling. 2.0 1009 42.0 16,320
110 RIH with BHA. 6.0 1015 42.3 16,320
111 Ream to bottom. 2.0 1017 42.4 16,320
112 Drill 6" hole. 14.0 1031 42.9 16,320 16,480
113 POOH 5.0 1036 43.1 16,480
114 BHA handling. 2.0 1038 43.2 16,480
Estimated
Date
17-Aug-97
17-Aug-97
17-Aug-97
17-Aug-97
17-Aug-97
18-Aug-97
18-Aug-97
18-Aug-97
18-Aug-97
19-Aug-97
19-Aug-97
19-Aug-97
19-Aug-97
20-Aug-97
20-Aug-97
20-Aug-97
20-Aug-97
21-Aug-97
21-Aug-97
21-Aug-97
21-Aug-97
22-Aug-97
22-Aug-97
22-Aug-97
22-Aug-97!
23-Aug-97
23-Aug-97
23-Aug-97
23-Aug-97
23-Aug-97
24-Aug-97
24-Aug-97
24-Aug-97
24-Aug-97
25-Aug-97
25-Aug-97
25-Aug-97
25-Aug-97
26-Aug-97
26-Aug-97
26-Aug-97
26-Aug-97
27-Aug-97
27-Aug-97
GP55 AFE est 2.XLS Page 3 of 6 7/1/97
Unocal Alaska Business Unit
Granite Point Platform
Well #55
Prepared by: Mitch Datum Date: 6/14/97 Revision #2
Estimate for Grass Roots Oil Well.
UNOCAL
No. Preliminary Procedure Time CUM CUM Depth Depth
Estimate Time Time In Out
(Hours) (Hours) (Days) (Feet) (Feet)
115 RIH with BHA. 6.3 1044 43.5 16,480
116 Ream to bottom. 3.0 1047 43.6 16,480
117 Drill 6" hole. 15.0 1062 44.2 16,480 16,640
118 POOH 5.3 1067 44.5 16,640
119 BHA handling. 2.0 1069 44.5 16,640
120 RIH with BHA. 6.3 1075 44.8 16,640
121 Ream to bottom. 3.0 1078 44.9 16,640
122 Drill 6" hole. 15.0 1093 45.6 16,640 16,800
123 POOH 5.3 1099 45.8 16,800
124 BHA handling. 2.0 1101 45.9 16,800
125 RIH with BHA. 6.3 1107 46.1 16,800
126 Ream to bottom. 3.0 1110 46.2 16,800
127 Drill 6" hole. 15.0 1125 46.9 16,800 16,960
128 POOH 5.3 1130 47.1 16,960
129 BHA handling. 2.0 1132 47.2 16,960
130 RIH with BHA. 6.5 1139 47.4 16,960
131 Ream to bottom. 3.0 1142 47.6 16,960
132 Drill 6" hole. 15.0 1157 48.2 16,960 17,120
133 POOH 5.5 1162 48.4 17,120
134 BHA handling. 2.0 1164 48.5 17,120
135 RIH with BHA. 6.5 1171 48.8 17,120
136 Ream to bottom. 3.0 1174 48.9 17,120
137 Drill 6" hole. 15.0 1189 49.5 17,120 17,280
138 BOP test 4.0 1193 49.7 17,280
139 POOH 5.5 1198 49.9 17,280
140 BHAhandling. 2.0 1200 50.0 17,280
141 RIH with BHA. 6.5 1207 50.3 17,280
142 Ream to bottom. 3.0 1210 50.4 17,280
143 Drill 6" hole. 15.0 1225 51.0 17,280 17,440
144 POOH 5.5 1230 51.3 17,440
145 BHA handling. 2.0 1232 51.3 17,440
146 RIH with BHA. 6.5 1239 51.6 17,440
147 Ream to bottom. 3.0 1242 51.7 17,440
148 Drill 6" hole. 15.0 1257 52.4 17,440 17,600
149 POOH 5.5 1262 52.6 17,600
150 BHA handling. 2.0 1264 52.7 17,600
151 RIH with BHA. 6.5 1271 52.9 17,600
152 Ream to bottom. 3.0 1274 53.1 17,600
153 Drill 6II hole.
.~, ~ ~. ~,~~ ~ ~ ~ 15.0 1289 53.7 17,600 17,760
154 POOH ~,- ~ '~-' ~ 5.5 1294 53.9 17,760
155 BI-IA handling. ~ .~ ,~_.~- 2.0 1296 54.0 17,760
156 RIH with BHA. :~,li_~ ~:~'~ ~ 6.5 1303 54.3 17,760
157 Ream to bottom. - ',~' 3.0 1306 54.4 17,760
158 Drill 6" hole.
"': ~z', ~:~-~, ' -..~. 15.0 1321 55.0 17,760 17,920
Estimated
Date
27-Aug-97
27-Aug-97
28-Aug-97
28-Aug-97
28-Aug-971
28-Aug-97
28-Aug-97
29-Aug-97
29-Aug-97
29-Aug-97
30-Aug-97
30-Aug-97
30-Aug-97
31-Aug-97
31-Aug-97
31-Aug-97
31-Aug-97
1-Sep-97
1-Sep-97
1-Sep-97
1-Sep-97
1-Sep-97
2-Sep-97
2-Sep-97
2-Sep-97
3-Sep-97
3-Sep-97
3-Sep-97
4-Sep-97
4-Sep-97
4-Sep-97
4-Sep-97
4-Sep-97
5-Sep-97
5-Sep-97
5-Sep-97
5-Sep-97
6-Sep-97
6-Sep-97
6-Sep-97
7-Sep-97
7-Sep-97
7-Sep-97
8-Sep-97
GP55 AFE est 2.XLS Page 4 of 6 7/1/97
Unocal Alaska Business Unit
Granite Point Platform
Well #55
Prepared by: Mitch Damm Date: 6/14/97 Revision #2
Estimate for Grass Roots Oil Well.
UNOCAL )
No. Preliminary Procedure Time CUM CUM Depth Depth
Estimate Time Time In Out
(Hours) (Hours) (Days) (Feet) (Feet)
159 POOH 5.5 1326 55.3 17,920
160 BHA handling. 2.0 1328 55.3 17,920
161 RIH with BI-IA. 6.5 1335 55.6 17,920
162 Ream to bottom. 3.0 1338 55.7 17,920
163 Drill 6" hole. 15.0 1353 56.4 17,920 18,080
164 CBU 3.0 1356 56.5 18,080
165 POOH with BHA 10.0 1366 56.9 18,080
166 LD motor and MWD 4.0 1370 57.1 18,080
167 RU SWS WLU for DP conveyed logs. 2.0 1372 57.1 18,080
168 RIH with logging tools: DIL, FDC, CNL, DT, GR, CCL 8.0 1380 57.5 18,080
169 Install side door entry sub. RIH with wet connect. 8.0 1388 57.8 18,080
170 Log C-5 8.0 1396 58.1 18,080
171 ND side-door entry sub. POOH with wireline 3.0 1399 58.3 18,080
172 POOH with logging tools 9.0 1408 58.6 18,080
173 RU casing crews for 5" liner 1.5 1409 58.7 18,080
174 RIH with 5" liner 5.0 1414 58.9 18,080
175 Continue to RIH with 5" liner on drillpipe 9.0 1423 59.3 18,080
176 Circulate and condition hole for cement. 3.0 1426 59.4 18,080
177 RU for cement job. 1.0 1427 59.5 18,080
178 Pump cement job and set liner hanger. 4.0 1431 59.6 18,080
179 POOH and circulate out cement. Continue to POOH. 7.0 1438 59.9 18,080
180 MU 6" bit and 7" casing scraper. 1.0 1439 60.0 18,080
181 RIH with 7" cleanout assembly. 6.0 1445 60.2 18,080
182 Wash and drilll cement to liner top. Circualte hole. 2.0 1447 60.3 18,080
183 iPOOH. 7.0 1454 60.6 18,080
184 LD BHA. PU mill and 5" casing scraper. 2.0 1456 60.7 18,080
185 RIH with 7" cleanout assembly. 8.0 1464 61.0 18,080
186 Wash and drilll cement to liner top. 3.0 1467 61.1 18,080
187 Circulate hole clean. 6.0 1473 61.4 18,080
188 RUandtest5" linerlap. 2.0 1475 61.5 18,080
189 Changewell overto diesel. 8.0 1483 61.8 18,080
190 Transfer OBM. 1.0 1484 61.8 18,080
191 Clean mud pits. 5.0 1489 62.0 18,080
192 POOH with cleanout assembly. 10.0 1499 62.5 18,080
193 LD 2-7/8" DP and drill collars. 3.0 1502 62.6 18,080
1502 62.6 18,080
Perforate 5" Liner and Run 3-1/2" Gas Lift Completion. 1502 62.6 18,080
194 PU 3-3/8" TCP guns andjewerly. 3.0 1505 62.7 18,080
195 RIH with TCP guns on 3-1/2" DP. 10.0 1515 63.1 18,080
196 Set packer. RU surface EQ. Fire guns. Circulate Well. 4.0 1519 63.3 18,080
197 POOH with TCP Guns 10.0 1529 63.7 18,080
198 LD TCP Guns 5.0 1534 63.9 18,080
199 RU SWS WLU. 1.5 1536 64.0 18,080
200 PU packer and tail pipe. 1.0 1537 64.0 18,080
Estimated
Date
8-Sep-97
8-Sep-97
8-Sep-97
8-Sep-97
9-Sep-97
9-Sep-97
9-Sep-97
10-Sep-97
10-Sep-97
10-Sep-97
10-Sep-97
11-Sep-97
11-Sep-97
11-Sep-97
11-Sep-97
11-Sep-97
12-Sep-97
12-Sep-97
12-Sep-97
12-Sep-97
12-Sep-97
12-Sep-97
13-Sep-97
13-Sep-97
13-Sep-97
13-Sep-97
14-Sep-97
14-Sep-97
14-Sep-97
14-Sep-97
14-Sep-97
14-Sep-97
15-Sep-97
15-Sep-971
15-Sep-97
15-Sep-97
15-Sep-97
15-Sep-97
16-Sep-97
16-Sep-97
16-Sep-97
16-Sep-97
16-Sep-97
17-Sep-97
GP55 AFE est 2.XLS Page 5 of 6 7/1/97
Unocal Alaska Business Unit
Granite Point Platform
Well #55
Prepared by: Mitch Datum Date: 6/14/97 Revision #2
Estimate for Grass Roots OH Well.
UNOCAL )
No. Preliminary Procedure Time CUM CUM Depth Depth
Estimate Time Time In Out
(Hours) (Hours) (Days) (Feet) (Feet)
201 RIH with packer and set on wireline. 6.0 1543 64.3 18,080
202 POOH 2.5 1545 64.4 18,080
203 RD SWS WLU. 0.5 1546 64.4 18,080
204 RU to run 3-1/2" completion. 1.0 1547 64.4 18,080
205 PU, rabbit and run 3-1/2" gas lift completion. 16.0 1563 65.1 18,080
206 Space out, install SCSSV, control line, and PU hanger. 6.0 1569 65.4 18,080
207 Land hanger and install packoff. 1.0 1570 65.4 18,080
208 ND BOPE. 4.0 1574 65.6 18,080
209 Install 3-1/8" block tree and test. 4.0 1578 65.7 18,080
210 RU slickline. RIH and pull SCSSV sleeve. 2.0 1580 65.8 18,080
211 Turnwell overto Production. 0.0 1580 65.8 18,080
1580 65.8 18,080
212 LD drillpipe and load out eq. on boat. 24.0 1604 66.8 18,080
213 Demob Rig 24.0 1628 67.8 18,080
Estimated
Date
17-Se?-97
17-Sep-97
17-Sep-97
17-Sep-97
18-Sep-97
18-Sep-97
18-Sep-97
18-Sep-97
18-Sep-97
18-Sep-97
18-Sep-97
18-Sep-97
19-Sep-97
20-Sep-97
20-Sep-97
GP55 AFE est 2.XLS Page 6 of 6 7/1/97
UNOCAL
Grantie Point Field Well #55
Depth vs. Time Summary
1,000
2,000
3,000
4,000
5,000
6,000
7,000
~, 8,000
~ 9,000
~o,ooo
11,000
12,000
13,000
14,000
15,000
16,000
17,000
18,000
t
GP55 AFE est 2.XLS
10
15
20
25
30
35
Time (Days)
40 45 50 55 60 65 70
7111971 9:30 AM
UNOCAL
UNOCAL )
Created by jones Structure : GRANITE POINT Platform Well : GP55
Date plotted : 27-Jun-g7 J
Plot Reference is GP55 Version #2. Il Field : Granite Point Field Location : Cook Inlet. Alosko
Caerdlnates are in feet reference slot
True Verdcel Depth~ce RKB (Rig: #156).I
tN"rB~ I <- West (feet)
81 O0 7200 6300 5400 4500 5600 2700 1800 §00 0 gO0
WELL PROFILE DATA
MD Inc air -I~/D North East V. SectDER/1 O0
0.00 0.00 8.00 0.00 0.00 0,00 0.00 0.00
350.00 0.00 8.00 550.00 0.00 0.00 0.00 0.00
550.00 2.00 8.00 54-g.96 3.46 0.4-9 -3.1.3 1.00
750.00 2.00 8.00 749.84- 10.37 1.46 -9.39 0.00
950.00 0.00 0.00 949.80 13.82 1.94- -12.52 1.00
1900.00 0.00 340.00 1899.80 13.82 1.94- -12.52 0.00
2000.00 2.50 340.00 1999.77 15.87 1.20 -13.79 2.50
2102.99 5.00 330.00 2102.53 21.87 -1.82 -17.05 2.50
..... Point .....
Tie on
End of Hold
End of Build
End of Hold
End of Drop/Turn
KOP
End of Hold
Continue Turn
Begin D'nl Nudge
9 5/8 Casing Pt C
Begin Turn to Tarc
End of Turn
End of Build//Turn 4470.00 55.88 200.004128.79 -892.23 -426.98 977.69 2.50
End of Hold 6100.00 55.88 200.005043.10 -2160.27-888.51 2285.34 0.00
End of Build/Turn7735.63 55.88 219.795966.80 -5324.68-1557.913624.49 1.00
Target GP55 C5 Rvsd 11 15131.74 55.88 219.7910115.00 -8029.94-5476.519719.67 0.00
End of Build/Turn15477.22 79.41 213.6810245.56 -8284.92-5665.0010036.-5~ 7.00
i.D. & Torqet GP55 TDR 18141.23 79.41 213.6810735.00 -10464.05 -7117.1812655.05 0.00
900
2700
3600
Q.) 4500
5400
6300
7200
I
8100
26 Conductor
90O
0
9O0
1800
2700
3600
4500
5400
6300
V
1 Be in D'nl Nude
.00 En~ Angle Buil~
1.50 Begin Angle Drop
900 L End D'nl Nudge 7200
1,3 5/8 Casing Pt
~/./~ TARGET- 7 Casing Pt
1800 KOP Final EOC/q GP55 C5 Rvsd 11-Jun-97 8100
3.81 /
5.48
, 9.77 DLS: 2.50 dog per 100 ft
900-
)~ 14.52 ~,~/ u
~ 19.39
x. 24.31
/ 9900
EOC ~ 54.14 9 5/8 Casing Pt ,/TO
v ~ GP55 TD Rvsd 11-Jun-g710800
Begin - Turn to Target ~ 55.79
~ 55.54 DLS: 1.00 der per 100 ft
%-. 55'~.~2 214.29 Azimuth
EnO of Turn~,. 1;3655'(To TD)
~ ***Plane of Proposal***
TANGENT ANGLE %..
9ooo 55.88 DEG ~ 7 casing
9900 J
TARGET ANGLE ~,~
'°~°°t 79.41 DEG
11700 / ~ , , i i i i
go0 0 900 1800 2700 5600 4500 5400 6500 7200 81 O0 9000 9900 10800 1 1700 12600 13500
Vertical Section (feet) ->
Azimuth 214.29 with reference 0.00 N, 0.00 E from slot #4-1
Created by jones
Ogre pJotted : 27-Jun-g7
P!o[ Reference is CPS5 Version ~t2.
Coerd~notes ore ;n feet reference slot f4--1.
iJTrve Ve~icel Oept.~s. are reference RKB (Rig:
I UNOCAL
Structure : GRANITE POINT Plotform Well : GP55
Field : Granite Point Field
Location : Cook inlet, Alaska
UNOCALe
East (feet) ->
70 60 50 4-0 30 20 10 0 10 20 50 40 50 60 70 80 90
, x-,'o 1700 3goo
1500
60 ~ 1300 .3700 900 60
~ 1100
I 5500
50 t 2900 50
700
40 1 1C 40
L
! 30
2500.,/"
1
'~ 2100
·
1300 ~ 900
¢ 700
70O
430C ~) 110C
goo/ I 5300
/
!
5500
700
900
11 O0
1300
1300,
1900
1100 2100
4~0 30 2'0 10 ; 10 20 3'0
East (feet) ->
7OO
' i
2700/
.j~ 20 q "
o
CFJ 3o
, /
V
' /
so ~,
I
] ~2100
7o ~
~00~
110q
120 ,
~o ia ' ~o'
100
7O0
20
700
t900
lO 0
L -
20
I
v
50
F
P 70
F 8O
i
· ~.,, ~ !:I~,,;
~[~ '. It':: FIO0
":. ,, ,._. ~ ;; .-; i'
~ , ~ ~ 120
i ~ ,
50 6'0 7~0 8'0 90
UNOCAL
Structure : GRANITF POINT Platform
Well : GP55
Field : Granite Point Field Location : Cook Inlet. Alaska
UNOCAL
Creoted by jones
Oate plotted : 27--Jun-g7
/
Plot Reference is GP55 Version ~2.
Cccrd[nates ore in feet reference slot f4--1.
Vertical Depths ore re[erence RKB (Rig:
'
I
--- Baker Hughes INTEO ---
I
<- Wesf (feet)
320 500 280 260 240 220 200 180 160 140 120 1 O0 gO 60 40 20
! i i i
,,' 4
1,300
~I00
111
5700
2500
5900
/'
/
.,,'
;,,
2100
·
/
6300
O0
2o 1
I ,bob(bO 57C
t3 _-...
20 1'---~ ' q.,'bo(b 1500 1300
/
60 -q
700 ,,
/
/
/
1 700 ,'
/
100]
/
/!
/
I 3100./
120i /" 1700
/
t 4-0 q ,,
! ,,
I 1900 ,,
! ,
/
160i
/
/
180 ~ ,"
] ,'
q
20o ~ 3300//
i ~100 / 1900
220 ~
240 ~
280 ~
3CO ~ // 6500
] . 3soo/'
520 ~
40
18(3 160 140 120 100 8~ I 610 40 2~
<- Wesf (feel)
100
}- 120
160
180
200
22O
~- 240
-260
L
280
p 300
L
.,L 320
f$40
56O
Created ",y jones
Dote plotted : 27--Jun--g7
Plot Reference ~S GP55 Version ~2.
Coordlnotes are in feet reference slot ~---1_
True VertJcat Depths are reference RgB (Rig:
240
280
.320
360
¢00
4-80
520
550
~00
640
720
600
i I
11700
760
8OO
84-0
880
920
960
1000
68O
640
I I
floc)
Sfrucfu
UNOCAL
re : GRANITE POINT Platform
Well : GP55
Field : Granite Point Field
Location : Cook Inlet, Alaska
550 520 480
<- West (feet)
44-0 400 360 320 280 240
I I i I I I I I
500
700
UNOCAL )
200 160 120 80
250O
OO
560
/
/
3500
~900
/ /2soo
2700 / /
7900/ ,/
I I I I I l
520 480 440 400 360 320 280 240 200
<- West (feet)
2300
650O
240
280
320
36O
400
4-40
480
52O
560
500
640
680
720
760
800
0
(-
' 8:0
840
880
920
960
1000
UNOCAL
Structure : GRANITE POINT Platform Well : GP55
Field : Granite Point Field Location : Cook Inlet, Alaska
UNOCALe
Octe plotted : 27--Jun-97
Plot Reference is GP55 Version ~2.
Coord[notes ore ;n feet reference slot ~&-l.
;True Ve~ical Depths are reference RKB (Rig:
3200 3OO0 2800 2600 2400 2200 2000 1800 1600 1400 1200 1 ODD 800 600 400 200 O
!000
1200
!400
1600 1
1800 i
20OO d.
2200 -q
2400 i
2600 t
/8100
2800 1
~ O0
3000 J
5200 ~0
3400
3600
3800
4000
4200
4900
5300
570(
%
41 O0
3700
4500
3100
4900
5500
5300
5900 /"
/
/
6100/'
5700 '300
/!
5100 7700 ,,"' 7700
/
61 O0 6500
,'
5700/
/
/
/
,/
/
t'
,00
4100
,/
/ 4100
/
/
/
/
/
/
/ 4500
¢900 /
49000'
/
·
/
/
/
~300 /
/ 4900
/
¢,
/
/
/
,
,
5300/
/
~t/
/
/
/
/
1 ogo0
5009700
3300
3700
800
Il ODD
1200
14oo
5300/ [ 1800
~ 5700 g 200O
/
5100 L
220O
6500
L 2400
i
? O
2600 "+'
2800 (1)
7700
~- ~ooo I
v
L 3200
h 3400
- 3600
.L 3800
3200 3000 2z~O0 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0
<- Wesf (feel)
..," 8100 ~ 4ooo
IQO" 85 ~100 F
~aOo .,
~5oo I
UNOCAL
Structure : GRANITE POINT Platform
Field : Granite Point Field
~!C~te plotted : 27--Jun-g7 ]
! P~c[ ~eferenc, is GP55 Version ~2- /
i Ccora;mates ore ;n feet reference slot ~4--t. /
~ ---. .... ...... ,.~. --- J <- West (feet)
Well : GP55
Location : Cook Inlet, Alaska
UNOCAL )
5200 5000 4800 4600 4400 4200 4000 ..t800 5600 5400 3200 3000 2800 2600 2400 2200
4-000 ! I I I I I I I i I I I I I I I I I I I I I I .I I I
4200 ]
4400 ]
4600 j
-J /11:Yl O0
4800 i
5200 ~
5400 ~
5600 4
'--'
.q-.. ,
~-- 5800 1 O0
-I 5000 ~ "
0 500 ,,
/
[ 62C0 /'8500
V /900 i ""'
6400 ! ~300 .,"'"'/
-~ 700 ,'
6600
6800 J ~01 O0 /,,,/
·
7000 'q ,"
4 .-'~300
/'
7200 :l ,,,-
/'
7400 ~
,,'
.,'~700
7600 I ,'""
7800 4,
t
9700
7700;'
,,
/'
/
6500
9300
~Oo
~/oo
,,'"9300
4000
8100
4200
101008 900~f 46004400
, ~"7000 1 4800
f5200
5400
~?00 ~ 5600
5800
~ 6000
-6200
-6400
- 6600
68O0
-7000
P 7200
_
,
7600
7800
I t I i I t I S I ~ I I I I i I ~ I I i I I i ~ I i I I , ] ]
5200 5000 4800 4600 4400 4200 4000 .~800 ..3600 3400 3200 3000 2800 2600 2400 2200
<- West (feet)
Creotecl ~)¥ jones
Oote plotted : 27-Jun-g7
Plot Reference is GP55 Version ~2.
--- Ba~er Hughes [NTEQ ---
520
5i0
500
UNOCAL
Structure : GRANITE POINT Platform Well : GP55
Field : Granite Point Field Location : Cook Inlet, Alaska
33O
34O
TRUE NORTH
550 0 10
70
2O
~700
5O
UNOCAL )
4O
50
290
280
8O
270
260
go
100
240
o 110
120
230
220 210
' g0
190
I aa
5O
180 ~go 1 70
150
1.30
1 40
Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well
Created Dy jones
Oete plotted : 27-Jun-97
Plot Re(erence ~s GP55 Version
Coord;notes are ;n feet reference slot ~f4-i.
True Vcd~col Oepths ore reference RKB (Rig: ~156)1
i
UNOCAL
510
300
290
ruc ure : GRANITE POINT Platform
Field : Granite Point Field
Well : GP55
Location : Cook inlet, Alaska
4500
1900
340
TRUE NORTH
350 0 10
3300
2!0 50
320 ~oo
UNOCAL )
3300
3100
7O
280
8O
270
260
}0 1;PO 9 3 15oo AC 0
~ + 90
100
250
110
240
120
23,~goo
220
' 130
1900
5900 1
21 1 50 ~1oo
1700
190
1 7( 7o~ 60
2700
Normal Plane Travelling Cylinder - Feet Ali depths shown ore Measured depths on Reference We!l
UNOCAL
GRA/~ITE POINT Platform
GP55
slot #4-1
Granite Point Field
Cook Inlet, Alaska
PROPOSAL LISTING
Baker Hughes iNTEQ
Your ref = GP55 Version
Our ref = prop2063
License =
Date printed = 2?-Jun-97
Date created = 12-Feb-97
Last revised = 12-Jun-9?
Field is centred on n60 59 36.731,w151 18 33.112
Structure is centred on n60 57 52.745,w151 20 20.066
Slot location is n60 57 28.961,w151 19 53.805
Slot Grid coordinates are N 2544516.089, E 263329.223
Slot local coordinates are 2415.19 S 1296.72 E
Projection type= alaska - Zone 4, Spheroid= Clarke - 1866
Reference North is True North
UNOCAL
GRANITE POINT Platform, GP55
Granite Point Field, Cook Inlet, Alaska
PROPOSA~ LISTING Page 1
Your ref : GP55 Version #2
Last revised : 12-Jun-97
Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert
Depth Degrees Degrees Depth C O 0 R D I N A T E S Deg/100ft Sect
0.00 0.00 8.00 0.00 0.00 N 0.00 E 0.00
350.00 0.00 8.00 350.00 0.00 N 0.00 E 0.00
450.00 1.00 8.00 449.99 0.86 N 0.12 E 1.00
550.00 2.00 8.00 549.96 3.46 N 0.49 E 1.00
750.00 2.00 8.00 749.84 10.37 N 1.46 E 0.00
0.00
0.00 Begin D'nl Nudge
-0.78
-3.13 End Angle Build
-9.39
750.16 2.00 8.00 750.00 10.37 N 1.46 E 1.00
800.00 1.50 8.00 799.81 11.88 N 1.67 E 1.00
900.00 0.50 8.00 899.80 13.61 N 1.91 E 1.00
950.00 0.00 0.00 949.80 13.82 N 1.94 E 1.00
950.20 0.00 340.00 950.00 13.82 N 1.94 E 0.00
-9.39 Begin Angle Drop
-10.76
-12.32
-12.52
-12.52 End D'nl Nudge
1000.00 0.00 340.00 999.80 13.82 N 1.94 E 0.00
1100.00 0.00 340.00 1099.80 13.82 N 1.94 E 0.00
1200.00 0.00 340.00 1199.80 13.82 N 1.94 E 0.00
1300.00 0.00 340.00 1299.80 13.82 N 1.94 E 0.00
1400.00 0.00 340.00 1399.80 13.82 N 1.94 E 0.00
-12.52 13 3/8" Casing Pt
-12.52
-12.52
-12.52
-12.52
1500.00 0.00 340.00 1499.80 13.82 N 1.94 E 0.00 -12.52
1600.00 0.00 340.00 1599.80 13.82 N 1.94 E 0.00 -12.52
1700.00 0.00 340.00 1699.80 13.82 N 1.94 E 0.00 -12.52
1800.00 0.00 340.00 1799.80 13.82 N 1.94 E 0.00 -12.52
1900.00 0.00 340.00 1899.80 13.82 N 1.94 E 0.00 -12.52 KOP
2000.00 2.50 340.00 1999.77 15.87 N 1.20 E 2.50 -13.79
2100.00 4.93 330.15 2099.55 21.65 N 1.69 W 2.50 -16.93
2102.99 5.00 330.00 2102.53 21.87 N 1.82 W 2.50 -17.05
2200.00 3.81 301.95 2199.26 27.24 N 6.67 W 2.50 -18.75
2300.00 4.00 264.70 2299.04 28.68 N 12.96 W 2.50 -16.39
2400.00 5.48 239.77 2398.71 25.95 N 20.56 W 2.50 -9.86
2500.00 7.51 226.77 2498.07 19.07 N 29.45 W 2.50 0.84
2600.00 9.77 219.50 2596.93 8.05 N 39.61 W 2.50 15.67
2700.00 12.12 214.98 2695.11 7.10 S 51.02 W 2.50 34.61
2800.00 14.52 211.92 2792.41 26.34 S 63.67 W 2.50 57.64
2900.00 16.94 209.72 2888.66 49.64 S 77.52 W 2.50 84.69
3000.00 19.39 208.05 2983.67 76.95 S 92.55 W 2.50 115.72
3100.00 21.85 206.75 3077.26 108.22 S 108.74 W 2.50 150.67
3200.00 24.31 205.70 3169.24 143.39 S 126.05 W 2.50 189.48
3300.00 26.79 204.84 3259.46 182.40 S 144.44 W 2.50 232.07
3400.00 29.26 204.11 3347.73 225.16 S 163.89 W 2.50 278.36
3500.00 31.74 203.48 3433.88 271.60 S 184.36 W 2.50 328.26
3600.00 34.22 202.94 3517.76 321.64 S 205.80 W 2.50 381.68
3700.00 36.71 202.46 3599.20 375.17 S 228.18 W 2.50 438.51
3800.00 39.20 202.03 3678.04 432.09 S 251.45 W 2.50 498.65
3900.00 41.68 201.65 3754.14 492.29 S 275.58 W 2.50 561.98
4000.00 44.17 201.30 3827.36 555.67 S 300.51 W 2.50 628.39
4100.00 46.66 200.98 3897.55 622.09 S 326.19 W 2.50 697.74
4200.00 49.15 200.69 3964.58 691.44 S 352.58 W 2.50 769.90
4300.00 51.64 200.42 4028.32 763.58 S 379.63 W 2.50 844.74
4400.00 54.14 200.17 4088.65 838.37 S 407.29 W 2.50 922.11
4470.00 55.88 200.00 4128.79 892.23 S 426.98 W 2.50 977.69 EOC
4500.00 55.88 200.00 4145.62 915.57 S 435.47 W 0.00 1001.76 9 5/8" Casing Pt
5000.00 55.88 200.00 4426.08 1304.54 S 577.05 W 0.00 1402.88
5500.00 55.88 200.00 4706.55 1693.50 S 718.62 W 0.00 1804.00
All data is in feet unless otherwise stated.
Coordinates from slot #4-1 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level).
Bottom hole distance is 12655.06 on azimuth 214.22 degrees from wellhead.
Total Dogleg for wellpath is 108.79 degrees.
Vertical section is from wellhead on azimuth 214.29 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
UNOCAL
GRANITE POINT Platform, GP55
Granite Point Field, Cook Inlet, Alaska
Measured Inclin. Azimuth True Vert R E C T A N G U L A R
Depth Degrees Degrees Depth C O 0 R D I N A T E S
6000.00 55.88 200.00 4987.01 2082.47 S 860.19 W
6100.00 55.88 200.00 5043.10 2160.27 S 888.51 W
6200.00 55.79 201.20 5099.26 2237.72 S 917.62 W
6300.00 55.71 202.41 5155.55 2314.46 S 948.32 W
6400.00 55.64 203.62 5211.94 2390.47 S 980.61 W
PROPOSA~ LISTING Page 2
Your ref : GP55 Version #2
Last revised : 12-Jun-97
Dogleg Vert
Deg/100ft Sect
0.00 2205.11
0.00 2285.34 Begin Turn to Target
1.00 2365.72
1.00 2446.42
1.00 2527.41
6500.00 55.59 204.83 5268.41 2465.72 S 1014.47 W 1.00 2608.66
6600.00 55.54 206.04 5324.96 2540.21 S 1049.89 W 1.00 2690.15
6700.00 55.51 207.25 5381.57 2613.89 S 1086.85 W 1.00 2771.85
6800.00 55.49 208,46 5438.21 2686.75 S 1125.36 W 1.00 2853.75
6900.00 55.48 209.68 5494.87 2758.76 S 1165.40 W 1.00 2935.80
7000.00 55.49 210.89 5551.53 2829.91 S 1206.95 W 1.00 3017.99
7100.00 55.50 212.10 5608.18 2900.18 S 1250.01 W 1.00 3100.30
7200.00 55.53 213.32 5664.80 2969.53 S 1294.55 W 1.00 3182.70
7300.00 55.57 214.53 5721.37 3037.96 S 1340.57 W 1.00 3265.15
7400.00 55.62 215.74 5777.87 3105.43 S 1388.05 W 1.00 3347,65
7500.00 55.69 216.95 5834.29 3171.93 S 1436.98 W 1.00 3430.16
7600.00 55.76 218.16 5890.61 3237.44 S 1487.34 W 1.00 3512.66
7700.00 55.85 219.36 5946.81 3301.94 S 1539.12 W 1.00 3595.12
7735.63 55.88 219.79 5966.80 3324.68 S 1557.91 w 1.00 3624.49 End of Tuz-n
8000.00 55.88 219.79 6115.08 3492.86 S 1697.98 W 0.00 3842.36
8500.00 55.88 219.79 6395.51 3810.95 S 1962.89 W 0.00 4254.41
9000.00 55.88 219.79 6675.94 4129.04 S 2227.80 W 0.00 4666.47
9500.00 55.88 219.79 6956.37 4447.13 S 2492.71 W 0.00 5078.52
10000.00 55.88 219.79 7236.80 4765.22 S 2757.62 W 0.00 5490.57
10500.00 55.88 219.79 7517.23 5083.31 S 3022.53 W 0.00 5902.62
11000.00 55.88 219.79 7797.66 5401.40 S 3287.44 W 0.00 6314.68
11500.00 55.88 219.79 8078.09 5719.49 S 3552.35 W 0.00 6726.73
12000.00 55.88 219.79 8358.53 6037.58 S 3817.25 W 0.00 7138.78
12500.00 55.88 219.79 8638.96 6355.67 S 4082.16 W 0.00 7550.84
13000.00 55.88 219.79 8919.39 6673.77 S 4347.07 W 0.00 7962.89
13500.00 55.88 219.79 9199.82 6991.86 S 4611.98 W 0.00 8374.94
14000.00 55.88 219.79 9480.25 7309.95 S 4876.89 W 0.00 8787.00
14500.00 55.88 219.79 9760.68 7628.04 S 5141.80 W 0.00 9199.05
15000.00 55.88 219.79 10041.11 7946.13 S 5406.71 W 0,00 9611.10
15131.74 55.88 219.79 10115.00 8029.94 S 5476.51 W 0.00 9719.67 GP55 C5 Rvsd il-Jun-97
15200.00 60.51 218.39 10150.96 8074.96 S 5513.06 W 7.00 9777.47
15300.00 67.32 216.55 10194.91 8146.23 S 5567.63 W 7.00 9867.09
15400.00 74.14 214.89 10227.90 8222.83 S 5622.68 W 7.00 9961.39
15477.22 79.41 213.68 10245.56 8284.92 S 5665.00 W 7.00 10036.53 Final EOC
15500.00 79.41 213.68 10249.75 8303.56 S 5677.42 W 0.00 10058.93
16000.00 79.41 213.68 10341.61 8712.55 S 5949.97 W 0.00 10550.39
16500.00 79.41 213.68 10433.47 9121.55 S 6222.53 W 0.00 11041.85
17000.00 79.41 213.68 10525.33 9530.54 S 6495.08 W 0.00 11533.31
17500.00 79.41 213.68 10617.19 9939.53 S 6767.64 W 0.00 12024.77
18000.00 79.41 213.68 10709.05 10348.53 S 7040.19 W 0.00 12516.23
18141.23 79.41 213.68 10735.00 10464.05 S 7117.18 W 0.00 12655.05 GP55 TD Rvsd 11-Jun-97
All data is in feet unless otherwise stated.
Coordinates from slot #4-1 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level),
Bottom hole distance is 12655.06 on azimuth 214.22 degrees from wellhead.
Total Dogleg for wellpath is 108.79 degrees.
Vertical section is from wellhead on azimuth 214.29 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
UNOCAL
GP, ANITE POINT P1atform, GP55
Granite Point Field, Cook Inlet, Alaska
PROPOSAL LISTING Page 3
Your ref : GP55 Version #2
Last revised : 12-Jun-97
Comments in wellpath
MD TVD Rectangular Coords. Comment
350.00 350.00 0.00 N 0.00 E Begin D'nl Nudge
550.00 549.96 3.46 N 0.49 E End Angle Build
750.16 750.00 10.37 N 1.46 E Begin Angle Drop
950.20' 950.00 13.82 N 1.94 E End D'nl Nudge
1000.00 999.80 13.82 N 1.94 E 13 3/8" Casing Pt
1900.00 1899.80 13.82 N 1.94 E KOP
4470.00 4128.79 892.23 S 426.98 W EOC
4500.00 4145.62 915.57 S 435.47 W 9 5/8" Casing Pt
6100.00 5043.10 2160.27 S 888.51 W Begin Turn to Target
7735.63 '5966.80 3324.68 S 1557.91 W End of Turn
15131.74 10115.00 8029.94 S 5476.51 W GP55 C5 Rvsd 11-Jun-97
15477.22 10245.56 828%.92 S 5665.00 W Final EOC
18141.23 10735.00 10464.05 S 7117.18 W GP55 TD Rvsd 11-Jun-97
Casing positions in string 'A'
==============================
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
0.00 0.00 0.00N 0.00E 294.00 294.00 0.00N 0.00E 26" Conductor
0.00 0.00 0.00N 0.00E 1000.00 999.80 13.82N 1.94E 13 3/8" Casing
0.00 0.00 0.00N 0.00E 4500.00 4145.62 915.57S 435.47W 9 5/8" Casing
0.00 0.00 0.00N 0.00E 15131.74 10115.00 8029.94S 5476.51W 7" Casing
Targets associated with this wellpath __
Target name Geographic Location T.V.D. Rectangular Coordinates Revised
GP55 C5 Rvsd ll-Jun- 257690.000,2536600.000,0.0000 10115.00 8029.94S 5476.51W 12-Feb-97
~P55 TD Rvsd 11-Jun- 256000.000,2534200.000,0.0000 10735.00 10464.05S 7117.18W 12-Feb-97
UNOCAL
GRANITE POINT P1atform,GP55
Granite Point Field, Cook Inlet, Alaska
PROPOSAL LISTING Page 1
Your ref : GP55 Version #2
Last revised : 12-Jun-97
Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert
Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect
0.00 0.00 8.00 0.00 2415.19 S 1296.72 E 0.00
350.00 0.00 8.00 350.00 2415.19 S 1296.72 E 0.00
450.00 1.00 8.00 449.99 2414.33 S 1296.84 E 1.00
550.00 2.00 8.00 549.96 2411.74 S 1297.20 E 1.00
750.00 2.00 8.00 749.84 2404.82 S 1298.17 E 0.00
0.00
0.00 Begin D'nl Nudge
-0.78
-3.13 End Angle Build
-9.39
750.16 2.00 8.00 750.00 2404.82 S 1298.17 E 1.00
800.00 1.50 8.00 799.81 2403.31 S 1298.39 E 1.00
900.00 0.50 8.00 899.80 2401.58 S 1298.63 E 1.00
950.00 0.00 0.00 949.80 2401.37 S 1298.66 E 1.00
950.20 0.00 340.00 950.00 2401.37 S 1298.66 E 0.00
-9.39 Begin Angle Drop
-10.76
-12.32
-12.52
-12.52 End D'nl Nudge
1000.00 0.00 340.00 999.80 2401.37 S 1298.66 E 0.00
1100.00 0.00 340.00 1099.80 2401.37 S 1298.66 E 0.00
1200.00 0.00 340.00 1199.80 2401.37 S 1298.66 E 0.00
1300.00 0.00 340.00 1299.80 2401.37 S 1298.66 E 0.00
1400.00 0.00 340.00 1399.80 2401.37 S 1298.66 E 0.00
-12.52 13 3/8" Casing Pt
-12.52
-12.52
-12.52
-12.52
1500.00 0.00 340.00 1499.80 2401.37 S 1298.66 E 0.00 -12.52
1600.00 0.00 340.00 1599.80 2401.37 S 1298.66 E 0.00 -12.52
1700.00 0.00 340.00 1699.80 2401.37 S 1298.66 E 0.00 -12.52
1800.00 0.00 340.00 1799.80 2401.37 S 1298.66 E 0.00 -12.52
1900.00 0.00 340.00 1899.80 2401.37 S 1298.66 E 0.00 -12.52 KOP
2000.00 2.50 340.00 1999.77 2399.32 S 1297.91 E 2.50 -13.79
2100.00 4.93 330.15 2099.55 2393.54 S 1295.03 E 2.50 -16.93
2102.99 5.00 330.00 2102.53 2393.32 S 1294.90 E 2.50 -17.05
2200.00 3.81 301.95 2199.26 2387.95 S 1290.05 E 2.50 -18.75
2300.00 4.00 264.70 2299.04 2386.51 S 1283.76 E 2.50 -16.39
2400.00 5.48 239.77 2398.71 2389.24 S 1276.16 E 2.50 -9.86
2500.00 7.51 226.77 2498.07 2396.12 S 1267.27 E 2.50 0.84
2600.00 9.77 219.50 2596.93 2407.15 S 1257.11 E 2.50 15.67
2700.00 12.12 214.98 2695.11 2422.29 S 1245.69 E 2.50 34.61
2800.00 14.52 211.92 2792.41 2441.53 S 1233.05 E 2.50 57.64
2900.00 16.94 209.72 2888.66 2464.83 S 1219.20 E 2.50 84.69
3000.00 19.39 208.05 2983.67 2492.14 S 1204.16 E 2.50 115.72
3100.00 21.85 206.75 3077.26 2523.41 S 1187.98 E 2.50 150.67
3200.00 24.31 205.70 3169.24 2558.58 S 1170.67 E 2.50 189.48
3300.00 26.79 204.84 3259.46 2597.59 S 1152.27 E 2.50 232.07
3400.00 29.26 204.11 3347.73 2640.35 S 1132.82 E 2.50 278.36
3500.00 31.74 203.48 3433.88 2686.80 S 1112.36 E 2.50 328.26
3600.00 34.22 202.94 3517.76 2736.83 S 1090.92 E 2.50 381.68
3700.00 36.71 202.46 3599.20 2790.36 S 1068.54 E 2.50 438.51
3800.00 39.20 202.03 3678.04 2847.28 S 1045.26 E 2.50 498.65
3900.00 41.68 201.65 3754.14 2907.49 S 1021.14 E 2.50 561.98
4000.00 44.17 201.30 3827.36 2970.86 S 996.21 E 2.50 628.39
4100.00 46.66 200.98 3897.55 3037.29 S 970.52 E 2.50 697.74
4200.00 49.15 200.69 3964.58 3106.63 S 944.13 E 2.50 769.90
4300.00 51.64 200.42 4028.32 3178.77 S 917.08 E 2.50 844.74
4400.00 54.14 200.17 4088.65 3253.56 S 889.43 E 2.50 922.11
4470.00 55.88 200.00 4128.79 3307.42 S 869.74 E 2.50 977.69 BOC
4500.00 55.88 200.00 4145.62 3330.76 S 861.24 E 0.00 1001.76 9 5/8" Casing Pt
5000.00 55.88 200.00 4426.08 3719.73 S 719.67 E 0.00 1402.88
5500.00 55.88 200.00 4706.55 4108.70 S 578.10 E 0.00 1804.00
All data is in feet unless otherwise stated.
Coordinates from NW Corner of Sec. 13, T10N, R12W SM and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level).
Bottom hole distance is 12655.06 on azimuth 214.22 degrees from wellhead.
Total Dogleg for wellpath is 108.79 degrees.
Vertical section is from wellhead on azimuth 214.29 degrees.
Calculation uses the n~inimum curvature method.
Presented by Baker Hughes INTEQ
UNOCAL
GRANITE POINT Platform, GP55
Granite Point Field, Cook Inlet, Alaska
Measured Inclin. Azimuth True Vert R E C T A N G U L A R
Depth Degrees Degrees Depth C O O R D I N A T E S
6000.00 55.88 200.00 4987.01 4497.67 S 436.52 E
6100.00 55.88 200.00 5043.10 4575.46 S 408.21 E
6200.00 55.79 201.20 5099.26 4652.91 S 379.10 E
6300.00 55.71 202.41 5155.55 4729.65 S 348.39 E
6400.00 55.64 203.62 5211.94 4805.66 S 316.11 E
PROPOSAL LISTING Page 2
Your ref : GP55 Version #2
Last revised : 12-Jun-97
Dogleg Vert
Deg/100ft Sect
0.00 2205.11
0.00 2285.34 Begin Turn to Target
1.00 2365.72
1.00 2446.42
1.00 2527.41
6500.00 55.59 204.83 5268.41 4880.92 S 282.25 E 1.00 2608.66
6600.00 55.54 206.04 5324.96 4955.40 S 246.83 E 1.00 2690.15
6700.00 55.51 207.25 5381.57 5029.08 S 209.86 E 1.00 2771.85
6800.00 55.49 208.46 5438.21 5101.94 S 171.35 E 1.00 2853.75
6900.00 55.48 209.68 5494.87 5173.96 S 131.32 E 1.00 2935.80
7000.00 55.49 210.89 5551.53 5245.11 S 89.77 E 1.00 3017.99
7100.00 55.50 212.10 5608.18 5315.37 S 46.71 E 1.00 3100.30
7200.00 55.53 213.32 5664.80 5384.72 S 2.17 E 1.00 3182.70
7300.00 55.57 214.53 5721.37 5453.15 S 43.85 W 1.00 3265.15
7400.00 55.62 215.74 5777.87 5520.62 S 91.34 W 1.00 3347.65
7500.00 55.69 216.95 5834.29 5587.12 S 140.27 W 1.00 3430.16
7600.00 55.76 218.16 5890.61 5652.63 S 190.63 W 1.00 3512.66
7700.00 55.85 219.36 5946.81 5717.13 S 242.41 W 1.00 3595.12
7735.63 55.88 219.79 5966.80 5739.87 S 261.20 W 1.00 3624.49 End of Turn
8000.00 55.88 219.79 6115.08 5908.05 S 401.27 W 0.00 3842.36
8500.00 55.88 219.79 6395.51 6226.14 S 666.17 W 0.00 4254.41
9000.00 55.88 219.79 6675.94 6544.23 S 931.08 W 0.00 4666.47
9500.00 55.88 219.79 6956.37 6862.32 S 1195.99 W 0.00 5078.52
10000.00 55.88 219.79 7236.80 7180.41 S 1460.90 W 0.00 5490.57
10500.00 55.88 219.79 7517.23 7498.51 S 1725.81 W 0.00 5902.62
11000.00 55.88 219.79 7797.66 7816.60 S 1990.72 W 0.00 6314.68
11500.00 55.88 219.79 8078.09 8134.69 S 2255.63 W 0.00 6726.73
12000.00 55.88 219.79 8358.53 8452.78 S 2520.54 W 0.00 7138.78
12500.00 55.88 219.79 8638.96 8770.87 S 2785.45 W 0.00 7550.84
13000.00 55.88 219.79 8919.39 9088.96 S 3050.36 W 0.00 7962.89
13500.00 55.88 219.79 9199.82 9407.05 S 3315.27 W 0.00 8374.94
14000.00 55.88 219.79 9480.25 9725.14 S 3580.18 W 0.00 8787.00
14500.00 55.88 219.79 9760.68 10043.23 S 3845.08 W 0.00 9199.05
15000.00 55.88 219.79 10041.11 10361.32 S 4109.99 W 0.00 9611.10
15131.74 55.88 219.79 10115.00 10445.13 S 4179.79 W 0.00 9719.67 GP55 C5 Rvsd 11-Jun-97
15200.00 60.51 218.39 10150.96 10490.15 S 4216.34 W 7.00 9777.47
15300.00 67.32 216.55 10194.91 10561.42 S 4270.91 W 7.00 9867.09
15400.00 74.14 214.89 10227.90 10638.03 S 4325.96 W 7.00 9961.39
15477.22 79.41 213.68 10245.56 10700.12 S 4368.28 W 7.00 10036.53 Final EOC
15500.00 79.41 213.68 10249.75 10718.75 S 4380.70 W 0.00 10058.93
16000.00 79.41 213.68 10341.61 11127.75 S 4653.25 W 0.00 10550.39
16500.00 79.41 213.68 10433.47 11536.74 S 4925.81 W 0.00 11041.85
17000.00 79.41 213.68 10525.33 11945.73 S 5198.37 W 0.00 11533.31
17500.00 79.41 213.68 10617.19 12354.72 S 5470.92 W 0.00 12024.77
18000.00 79.41 213.68 10709.05 12763.72 S 5743.48 W 0.00 12516.23
18141.23 79.41 213.68 10735.00 12879.24 S 5820.46 W 0.00 12655.05 GP55 TD Rvsd 11-Jun-97
All data is in feet unless otherwise stated.
Coordinates from NW Corner of Sec. 13, T10N, R12W SM and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level).
Bottom hole distance is 12655.06 on azimuth 214.22 degrees from wellhead.
Total Dogleg for wellpath is 108.79 degrees.
Vertical section is from wellhead on azimuth 214.29 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
UNOCAL
GRA/~ITE POINT Platfoz-m,GP55
Granite Point Field, Cook Inlet, Alaska
PROPOSAL LISTING Page 3
Your ref : GP55 Version #2
Last revised : 12-Jun-97
Comments in wellpath
MD TVD Rectangular Coords. Comment
350.00 350.00 2415.19 S 1296.72 E Begin D'nl Nudge
550.00 549.96 2411.74 S 1297.20 E End Angle Build
750.16 750.00 2404.82 S 1298.17 E Begin Angle Drop
950.20 950.00 2401.37 S 1298.66 E End D'nl Nudge
1000.00 999.80 2401.37 S 1298.66 E 13 3/8" Casing Pt
1900.00 1899.80 2401.37 S 1298.66 E KOP
4470.00 4128.79 3307.42 S 869.74 E EOC
4500.00 4145.62 3330.76 S 861.24 E 9 5/8" Casing Pt
6100.00 5043.10 4575.46 S 408.21 E Begin Turn to Target
7735.63 '5966.80 5739.87 S 261.20 W End of Turn
15131.74 10115.00 10445.13 S 4179.79 W GP55 C5 Rvsd 11~Jun-97
15477.22 10245.56 10700.12 S 4368.28 W Final E0C
18141.23 10735.00 12879.24 S 5820.46 W GP55 TD Rvsd 11~Jun-97
Casing positions in string 'A'
==============================
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
0.00 0.00 2415.19S 1296.72E 294.00 294.00 2415.19S 1296.72E 26" Conductor
0.00 0.00 2415.19S 1296.72E 1000.00 999.80 2401.37S 1298.66E 13 3/8" Casing
0.00 0.00 2415.19S 1296.72E 4500.00 4145.62 3330.76S 861.24E 9 5/8" Casing
0.00 0.00 2415.19S 1296.72E 15131.74 10115.00 10445.13S 4179.79W 7" Casing
Targets associated with this wellpath
Target name Geographic Location T.V.D. Rectangular Coordinates Revised
GP55 C5 Rvsd 11-Jun- 257690.000,2536600.000,0.0000 10115.00 10445.13S 4179.79W 12-Feb-97
GP55 TD Rvsd ll-Jun- 256000.000,2534200.000,0.0000 10735.00 12879.24S 5820.46W 12-Feb-97
UNOCAL
GRA/~ITE POINT Platform, GP55
Granite Point Field, Cook Inlet, Alaska
PROPOSAL LISTING Page 1
Your ref : GP55 Version #2
Last revised : 12-Jun-97
Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S
Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing
0.00 0.00 8.00 0.00 0.00N 0.00E 0.00 0.00 263329.22 2544516.09
350.00 0.00 8.00 350.00 0.00N 0.00E 0.00 0.00 263329.22 2544516.09
450.00 1.00 8.00 449.99 0.86N 0.12E 1.00 -0.78 263329.36 2544516.95
550.00 2.00 8.00 549.96 3.46N 0.49E 1.00 -3.13 263329.78 2544519.53
750.00 2.00 8.00 749.84 10.37N 1.46E 0.00 -9.39 263330.89 2544526.43
750.16 2.00 8.00 750.00 10.37N 1.46E 1.00 -9.39 263330.89 2544526.43
800.00 1.50 8.00 799.81 11.88N 1.67E 1.00 -10.76 263331.13 2544527.93
900.00 0.50 8.00 899.80 13.61N 1.91E 1.00 -12.32 263331.41 2544529.66
950.00 0.00 0.00 949.80 13.82N 1.94E 1.00 -12.52 263331.45 2544529.87
950.20 0.00 340.00 950.00 13.82N 1.94E 0.00 -12.52 263331.45 2544529.87
1000.00 0.00 340.00 999.80 13.82N 1.94E 0.00 -12.52 263331.45 2544529.87
1100.00 0.00 340.00 1099.80 13.82N 1.94E 0.00 -12.52 263331.45 2544529.87
1200.00 0.00 340.00 1199.80 13.82N 1.94E 0.00 -12.52 263331.45 2544529.87
1300.00 0.00 340.00 1299.80 13.82N 1.94E 0.00 -12.52 263331.45 2544529.87
1400.00 0.00 340.00 1399.80 13.82N 1.94E 0.00 -12.52 263331.45 2544529.87
1500.00 0.00 340.00 1499.80 13.82N 1.94E 0.00 -12.52 263331.45 2544529.87
1600.00 0.00 340.00 1599.80 13.82N 1.94E 0.00 -12.52 263331.45 2544529.87
1700.00 0.00 340.00 1699.80 13.82N 1.94E 0.00 -12.52 263331.45 2544529.87
1800.00 0.00 340.00 1799.80 13.82N 1.94E 0.00 -12.52 263331.45 2544529.87
1900.00 0.00 340.00 1899.80 13.82N 1.94E 0.00 -12.52 263331.45 2544529.87
2000.00 2.50 340.00 1999.77 15.87N 1.20E 2.50 -13.79 263330.74 2544531.94
2100.00 4.93 330.15 2099.55 21.65N 1.69W 2.50 -16.93 263327.98 2544537.77
2102.99 5.00 330.00 2102.53 21.87N 1.82W 2.50 -17.05 263327.85 2544537.99
2200.00 3.81 301.95 2199.26 27.24N 6.67W 2.50 -18.75 263323.12 2544543.46
2300.00 4.00 264.70 2299.04 28.68N 12.96W 2.50 -16.39 263316.85 2544545.02
2400.00 5.48 239.77 2398.71 25.95N 20.56W 2.50 -9.86 263309.20 2544542.46
2500.00 7.51 226.77 2498.07 19.07N 29.45W 2.50 0.84 263300.17 2544535.76
2600.00 9.77 219.50 2596.93 8.05N 39.61W 2.50 15.67 263289.79 2544524.94
2700.00 12.12 214.98 2695.11 7.10S 51.02W 2.50 34.61 263278.07 2544510.03
2800.00 14.52 211.92 2792.41 26.34S 63.67W 2.50 57.64 263265.03 2544491.06
2900.00 16.94 209.72 2888.66 49.64S 77.52W 2.50 84.69 263250.71 2544468.05
3000.00 19.39 208.05 2983.67 76.95S 92.55W 2.50 115.72 263235.12 2544441.05
3100.00 21.85 206.75 3077.26 108.22S 108.74W 2.50 150.67 263218.30 2544410.12
3200.00 24.31 205.70 3169.24 143.39S 126.05W 2.50 189.48 263200.28 2544375.31
3300.00 26.79 204.84 3259.46 182.40S 144.44W 2.50 232.07 263181.09 2544336.69
3400.00 29.26 204.11 3347.73 225.16S 163.89W 2.50 278.36 263160.77 2544294.33
3500.00 31.74 203.48 3433.88 271.60S 184.36W 2.50 328.26 263139.36 2544248.32
3600.00 34.22 202.94 3517.76 321.64S 205.80W 2.50 381.68 263116.90 2544198.73
3700.00 36.71 202.46 3599.20 375.17S 228.18W 2.50 438.51 263093.43 2544145.68
3800.00 39.20 202.03 3678.04 432.09S 251.45W 2.50 498.65 263069.00 2544089.24
3900.00 41.68 201.65 3754.14 492.29S 275.58W 2.50 561.98 263043.65 2544029.55
4000.00 44.17 201.30 3827.36 555.67S 300.51W 2.50 628.39 263017.44 2543966.70
4100.00 46.66 200.98 3897.55 622.09S 326.19W 2.50 697.74 262990.40 2543900.81
4200.00 49.15 200.69 3964.58 691.44S 352.58W 2.50 769.90 262962.60 2543832.02
4300.00 51.64 200.42 4028.32 763.58S 379.63W 2.50 844.74 262934.08 2543760.45
4400.00 54.14 200.17 4088.65 838.37S 407.29W 2.50 922.11 262904.91 2543686.24
4470.00 55.88 200.00 4128.79 892.23S 426.98W 2.50 977.69 262884.12 2543632.80
4500.00 55.88 200.00 4145.62 915.57S 435.47W 0.00 1001.76 262875.15 2543609.64
5000.00 55.88 200.00 4426.08 1304.54S 577.05W 0.00 1402.88 262725.67 2543223.66
5500.00 55.88 200.00 4706.55 1693.50S 718.62W 0.00 1804.00 262576.18 2542837.68
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #4-1 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level).
Bottom hole distance is 12655.06 on azimuth 214.22 degrees from wellhead.
Total Dogle~ for wellpath is 108.79 degrees.
Vertical section is from wellhead on azimuth 214.29 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
UNOCAL
GRANITE POINT Platform, GP55
Granite Point Field, Cook Inlet, Alaska
PROPOSAL LISTING Page 2
Your ref : GP55 Version #2
Last revised : 12-Jun-97
Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O 0 R D S
Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing
6000.00 55.88 200.00 4987.01 2082.475 860.19W 0.00 2205.11 262426.70 2542451.70
6100.00 55.88 200.00 5043.10 2160.275 888.51W 0.00 2285.34 262396.80 2542374.50
6200.00 55.79 201.20 5099.26 2237.725 917.62W 1.00 2365.72 262366.11 2542297.67
6300.00 55.71 202.41 5155.55 2314.465 948.32W 1.00 2446.42 262333.85 2542221.57
6400.00 55.64 203.62 5211.94 2390.475 980.61W 1.00 2527.41 262300.02 2542146.24
6500.00 55.59 204.83 5268.41 2465.725 1014.47W 1.00 2608.66 262264.63 2542071.69
6600.00 55.54 206.04 5324.96 2540.215 1049.89W 1.00 2690.15 262227.70 2541997.95
6700.00 55.51 207.25 538i.57 2613.895 1086.85W 1.00 2771.85 262189.23 2541925.05
6800.00 55.49 208.46 5438.21 2686.755 1125.36W 1.00 2853.75 262149.24 2541852.99
6900.00 55.48 209.68 5494.87 2758.765 1165.40W 1.00 2935.80 262107.75 2541781.81
7000.00 55.49 210.89 5551.53 2829.915 1206.95W 1.00 3017.99 262064.75 2541711.52
7100.00 55.50 212.10 5608.18 2900.185 1250.01W 1.00 3100.30 262020.27 2541642.16
7200.00 55.53 213.32 5664.80 2969.535 1294.55W 1.00 3182.70 261974.32 2541573.73
7300.00 55.57 214.53 5721.37 3037.965 1340.57W 1.00 3265.15 261926.91 2541506.26
7400.00 55.62 215.74 5777.87 3105.435 1388.05W 1.00 3347.65 261878.07 2541439.78
7500.00 55.69 216.95 5834.29 3171.935 1436,98W 1.00 3430.16 261827.79 2541374.29
7600.00 55.76 218.16 5890.61 3237.445 1487.34W 1.00 3512.66 261776.10 2541309.82
7700.00 55.85 219.36 5946.81 3301.945 1539.12W 1.00 3595.12 261723.02 2541246.40
7735.63 55.88 219.79 5966.80 3324.685 1557.91W 1.00 3624.49 261703.76 2541224.05
8000.00 55.88 219.79 6115.08 3492.865 1697,98W 0.00 3842.36 261560.30 2541058.77
8500.00 55.88 219.79 6395.51 3810.955 1962.89W 0.00 4254.41 261288.95 2540746.17
9000.00 55.88 219.79 6675.94 4129.045 2227.80W 0.00 4666.47 261017.61 2540433.57
9500.00 55.88 219.79 6956.37 4447.135 2492,71W 0.00 5078.52 260746.27 2540120.97
10000.00 55.88 219.79 7236.80 4765.225 2757.62W 0.00 5490.57 260474.92 2539808.37
10500.00 55.88 219.79 7517.23 5083.315 3022.53W 0.00 5902.62 260203.58 2539495.77
11000.00 55.88 219.79 7797.66 5401.405 3287.44W 0.00 6314.68 259932.24 2539183.17
11500.00 55.88 219.79 8078.09 5719.495 3552.35W 0.00 6726.73 259660.89 2538870.57
12000.00 55.88 219.79 8358.53 6037.585 3817.25W 0.00 7138.78 259389.55 2538557.97
12500.00 55.88 219.79 8638.96 6355.675 4082.16W 0.00 7550.84 259118.21 2538245.37
13000.00 55.88 219.79 8919.39 6673.775 4347,07W 0.00 7962.89 258846.87 2537932.77
13500.00 55.88 219.79 9199.82 6991.865 4611.98W 0.00 8374.94 258575.52 2537620.17
14000.00 55.88 219.79 9480.25 7309.955 4876.89W 0.00 8787.00 258304.18 2537307.56
14500.00 55.88 219.79 9760.68 7628.045 5141.80W 0.00 9199.05 258032.84 2536994.96
15000.00 55.88 219.79 10041.11 7946.135 5406,71W 0.00 9611.10 257761.49 2536682.36
15131.74 55.88 219.79 10115.00 8029.945 5476,51W 0.00 9719.67 257690.00 2536600.00
15200.00 60.51 218.39 10150.96 8074.965 5513,06W 7.00 9777.47 257652.54 2536555.73
15300.00 67.32 216.55 10194.91 8146.235 5567.63W 7.00 9867.09 257596.53 2536485.60
15400.00 74.14 214.89 10227.90 8222.835 5622,68W 7.00 9961.39 257539.92 2536410.14
15477.22 79.41 213.68 10245.56 8284.925 5665.00W 7.00 10036.53 257496.35 2536348.93
15500.00 79.41 213.68 10249.75 8303.565 5677.42W 0.00 10058.93 257483.55 2536330.55
16000.00 79.41 213.68 10341.61 8712.555 5949.97W 0.00 10550.39 257202.71 2535927.22
16500.00 79.41 213.68 10433.47 9121.555 6222.53W 0.00 11041.85 256921.86 2535523.90
17000.00 79.41 213.68 10525.33 9530.545 6495,08W 0.00 11533.31 256641.02 2535120.57
17500.00 79.41 213.68 10617.19 9939.535 6767.64W 0.00 12024.77 256360.17 2534717.25
18000.00 79.41 213.68 10709.05 10348.535 7040.19W 0.00 12516.23 256079.33 2534313.92
18141.23 79.41 213.68 10735.00 10464.055 7117.18W 0.00 12655.05 256000.00 2534200.00
Coordinates from slot #4-1 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea
Bottom hole distance is 12655.06 on azimuth 214.22 degrees from wellhead.
Total Dogleg for wellpath is 108.79 degrees.
Vertical section is from wellhead on azimuth 214.29 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid~
Presented by Baker Hughes INTEQ
UNOCAL
GRANITE POINT Platform
GP55
slot #4-1
Granite Point Field
Cook Inlet, Alaska
3-D
MINIMUM DISTANCE CLEARANCE
by
Baker Hughes INTEQ
REPORT
Your ref : GP55 Version
Our ref : prop2063
License :
Date printed : 27-Jun-97
Date created : 12-Feb-97
Last revised : 12-Jun-97
Field is centred on n60 59 36.731,w151 18 33.112
S=ructure is cen=red on n60 57 52.745,w151 20 20.066
Slot location is n60 57 28.961,w151 19 53.805
Slot Grid coordina=es are N 2544516.089, E 263329.223
Slot local coordinates are 2415.19 S 1296.72 E
Projection ty~e: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is Tr~e North
Report is limited to clearances less than 500 feet
DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4*
Object wellpath
PMSS <11236 - 14086'>,,Gp54St1,GP, A/qITE POINT P
PMSS <1130 - 11944'>,,GP54,GRANITE POINT Platf
MSS <8630-11376'>,,33-23,GRANITE POINT Platfor
G~S <O-12000'>,,32-23,GRANITE POINT Platform
GMS <8900-11986'>,,32-23Rd, GRANITE POINT Platf
GMS <7100-10225'>,,22o13,GRANITE POINT Platfor
PMSS <11453 - 13821'>,,22-13Rd,GRANITE POINT P
GCT Gyro <0-7002'>,,22-13,GRA~TIT~ POINT Platfo
PMSS <6738 - 12036'>,,22-13Rd,GP, ANITE POINT P1
PMSS <11395-13934'>,,22-13Rd2,GR~NITE POINT P1
G~MS <2700 - 11450'>,,33-13,GRANITE POINT Platf
PMSS <9437 - 10270'>,,32-13Rd,GRANITE POINT P1
PGMS <0-10200'>,,32-13,GRANITE POINT Platform
PMSS <8478 - 12563'>,,32-13Rd#2,GRANITE POINT
PGMS <0-12163'>,,GP-50,GRANITE POINT Platform
PG~MS <0-11560'>,,11-13Rd,GP~%NITE POINT Platfor
GMS <4025-11653'>,,11-13,GRARTTE POINT Platfor
GMS <O-10191'>,,31-14Rd#2,GRANI~'?E POINT Platfo
GMS/MSS <0-8876'>,,31-14,GRA/~ITE POINT Platfor
GMS <0-11011'),,31-14Rd%i,GRANITE POI~ Pla~fo
GMS <O-11473'>,,33-14,GRA.NITE POINT Platform
GMS <9200-11410'>,,33-14Rd,GRA~V/TE POINT Platf
GMS <O-10560'>,,24-13,GRANITE POINT Platform
GMS <9700-10640'>,,24-13Rd,GRANITE POINT Platf
GMS/MSS <0-11150-15715'>,,MUC i-i,GRA-NITE POIN
Closest approach with 3-D Minimum Distance method
Last revised Distance M.D.
2.6 500.0
2.6 500.0
44.5 950.2
44.5 950.2
44.5 950.2
84 8 320.0
84 8 320.0
84 8 320.0
84 8 320,0
84 8 320.0
85 7 600.1
85 7 600.1
85.7 600.1
85.7 600.1
44.0 2103.0
46.6 2233.3
46.6 2233.3
61.1 660.0
61.1 660.0
61.1 660.0
57.9 260.0
57.9 260.0
75.7 560.0
75.7 560.0
81.9 500.0
23-Jan-97
15-Apr-97
7-Nov-96
7oNov-96
7-Nov-96
25-Apr-96
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
11-Aug-95
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
Diverging from M.D.
12820.0
5700.0
6300.0
6300.0
6300.0
320.0
13322.0
320.0
13322.0
13322.0
1600.2
1600.2
1600.2
1600.2
2103.0
2233.3
2233.3
660.0
660.0
660.0
260.0
260.0
560.0
560.0
500.0
GMS <0-10830'>,,MUC I-2,GRANITm POINT Platform
G~S <0-11200'>,,31-23,GRANITE POINT Platform
GMS/MSS/GMS <0-12471'>,,44-11,GRANITE POINT P1
GMS <0-10850 >,,44-14,GRANITE POINT Platform
CMS <0-10874 >,,31-13,GRANITE POINT Platform
CMS <0-11800 >,,11-24,GRANITE POINT Platform 7
G~MS <0-12200 >,,12-24,G1~ANITE POINT Platform 7
GMS <0-11839 >,,GP-51,GRANITE POINT Platform 7
GMS <0-10572 >,,13-13,GRANITE POINT Platform 7
GMS/MSS/GMS (0-14544'>,,42-23,GRANITE POINT P1 7
PMSS <7367 - 13940'>,,42-23Rd, GRANITE POINT P1 7
PMSS <1145 - ????>,,GP53,GRANITE POINT Pla:for 24
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
7-Nov-96
-Nov-96
-Nov-96
-Nov-96
-Nov-96
-Nov-96
-Nov-96
-Ju~-97
76.5
61.9
63.0
54.5
79.6
27.5
21.0
65.8
15.7
67.1
67.1
11.3
1933.:
200.0
775.1
100.0
620.0
950.2
720.0
2103.0
1400.0
700.0
700.0
160.0
1933.3
4780.0
775.1
4200.0
620.0
4720.0
4560.0
2103.0
2500.0
12400.0
12680.0
160.0
Unocal Alaska Business Unit
Granite Point Platform
Well #55
Prepared by: Mitch Damm Date: 6/14/97 Revision/12
Estimate for Grass Roots Oil Well.
UNOCAL
No. Preliminary Procedure Time CUM CUM Depth Depth
Estimate Time Time In Out
(Hours) (Hours) (Days) (Feet) (Feet)
Move and prep rig.
Change out liners
Skid rig over slot 4-4.
Cut open conductor and weld squinch joint to producition deck.
Cuttings line rerouting. Extra time required due to piping configuration.
Clean pits.
Install Riser and Bell Nipple.
Total Rig Mobilization. 42.0 42 1.8 294
42 1.8 294
17-1/2" Hole Section 42 1.8 294
1 PU 5" drillpipe, drill collars, and HWDP 14.0 56 2.3 294
2 MU BHA#1 3.0 59 2.5 294
3 RIH. Circulate well clean. 2.0 61 2.5 294
4 RU scientific. Gyro Conductor. 4.0 65 2.7 294
5 Rotary drill from 294' to 1,100' taking single shot surveys. 15.0 80 3.3 294 1,200
6 Circ and condition hole. 1.0 81 3.4 1,200
7 POOH with BHA #1. 1.5 83 3.4 1,200
8 LD BHA. 2.0 85 3.5 1,200
9 RUCasing Crew 2.0 87 3.6 1,200
10 RIH with 13-3/8" Casing to 1,100'. 5.0 92 3.8 1,200
11 PU wellhead and land wellhead. 1.0 93 3.9 1,200
12 RU to pump cement 2.0 95 3.9 1,200
13 Pump cement job taking returns to surface. 4.0 99 4.1 1,200
14 Release and LD running tools. RD cementing Eq. 2.0 101 4.2 1,200
15 LD riser. Cut offsquinchjoint. 3.0 104 4.3 1,200
16 NU XO spool, riser and 13-5/8" BOPE. 10.0 114 4.7 1,200
17 Test BOPE. 4.0 118 4.9 1,200
118 4.9 1,200
12-1/4" Hole Section 118 4.9 1,200
18 MU BHA #2. (MWD and Motor) 4.0 122 5.1 1,200
19 RIH with BHA. 2.0 124 5.1 1,200
20 Drill cement. Test casing. 1.5 125 5.2 1,200
21 Drill out of shoe and perform leak-off test. 2.5 128 5.3 1,200
22 Drill 12-1/4" hole f/1,100' to 5,000'. 80.0 208 8.6 1,100 5,000
23 CBU and condition hole 2.0 210 8.7 5,000
24 POOH with BHA. 3.0 213 8.9 5,000
25 LD BHA. 2.0 215 8.9 5,000
26 Change pipe rams and test BOPE. 2.0 217 9.0 5,000
27 RUcasing crew 1.5 218 9.1 5,000
28 RIHwith 9-5/8" casing. 10.0 228 9.5 5,000
29 Land hanger and circulate 1.0 229 9.5 5,000
30 Pump Cement Job 5.0 234 9.8 5,000
31 Release running tool. RIH with wash tool. 2.5 237 9.9 5,000
32 RIH with CSG hanger packoff. 5.0 242 10.1 5,000
Estimated
Date
15-Jul-97
16-Jul-97
16-Jul-97
16-Jul-97
17-Jul-97
17-Jul-97
17-Jul-97
17-Jul-97
18-Jul-97
18-Jul-97
18-Jul-97
18-Jul-97
18-Jul-97
18-Jul-97
18-Jul-97
18-Jul-97
19-Jul-97
19-Jul-97
19-Jul-97
19-Jul-97
19-Jui-97
19-Jul-97
19-Jul-97
20-Jul-97
20-Jul-97
20-Jul-97
20-Jul-97
23-Jul-97
23-Jul-97
23-Jul-97
23-Jul-97
24-Jul-97
24-Jul-97
24-Jul-97
24-Jul-97
24-Jul-97
24-Jul-97
25-Jul-97
GP55 AFE est 2.XLS Page 1 of 6 6/25/97
Unocal Alaska Business Unit
Granite Point Platform
Well #55
Prepared by: Mitch Damm Date: 6/14/97 Revision #2
Estimate for Grass Roots Oil Well.
UNOCAL )
No. Preliminary Procedure Time CUM CUM Depth Depth
Estimate Time Time In Out
(Hours) (Hours) (Days) (Feet) (Feet)
33 Run wear bushing 0.5 242 10.1 5,000
10.1 5,000
8-1/2" Hole Section 242 10.1 5,000
34 Clean pits for OBM and transfer OBM from Beam tanks. 7.0 249 10.4 5,000
35 Change Rams. TestBOP's 4.0 253 10.5 5,000
36 MUBHA#4 4.0 257 10.7 5,000
37 RIHwithBHA 3.0 260 10.8 5,000
38 Drill Cement and pressure test casing 3.0 263 11.0 5,000
39 Drill out of shoe and perform leak off test. 2.0 265 11.0 5,000 5,010
40 Drill 8-1/2"hole. 125.0 390 16.3 5,010 10,010
41 CBU. 1.0 391 16.3 10,010
42 POOH with BHA. 6.0 397 16.5 10,010
43 BHA handling. 3.0 400 16.7 10,010
44 Cut and strip drilling line. 1.0 401 16.7 10,010
45 RoutineRig Maintenance 1.0 402 16.8 10,010
46 Test BOPE. 5.0 407 17.0 10,010
47 RIH with BHA 4.0 411 17.1 10,010
48 Ream to bottom. 2.0 413 17.2 10,010
49 Drill 8-1/2"hole 84.8 498 20.7 10,010 12,300
50 POOH 8.0 506 21.1 12,300
51 BHA Handling 2.0 508 21.2 12,300
52 RIHwithBHA 5.0 513 21.4 12,300
53 Ream to bottom. 2.0 515 21.5 12,300
54 Drilling 8-1/2" hole. 88.9 604 25.2 12,300 13,900
55 POOH 9.0 613 25.5 13,900
56 BI-IA Handling 2.0 615 25.6 13,900
57 RIHwithBHA 6.0 621 25.9 13,900
58 Ream to bottom. 3.0 624 26.0 13,900
59 Drilling 8-1/2" hole. 76.9 701 29.2 13,900 15,130
60 Circulate bottoms up. 2.0 703 29.3 15,130
61 POOH 10.0 713 29.7 15,130
62 Change pipe rams andtest. Pull wear bushing 3.0 716 29.8 15,130
63 RU casing crew 3.0 719 29.9 15,130
64 Run 7" casing 24.0 743 30.9 15,130
65 Land hanger and RU cementing equipment. 2.0 745 31.0 15,130
66 Pump cement job. 6.0 751 31.3 15,130
67 Release running tool. RIH with wash tool. 1.0 752 31.3 15,130
68 RIH with CSG hanger packoff. 2.0 754 31.4 15,130
69 Run wear bushing 1.0 755 31.4 15,130
70 Lay down 5" drillpipe. Prepare for 8.2 PPG OBM. 18.0 773 32.2 15,130
71 PU 3-1/2" drilpipe 22.0 795 33.1 15,130
33.1 15,130
6" C-5 Lateral 14.0 otal HR~ 33.1 15,130
Estimated Bit Performance = 160.0 Total FT 33.1 15,130
Estimated
Date
i
25-Jul-97
25-Jul-97
25-Jul-97
25-Jul-97
25-Jul-97
25-Jui-97
25-Jul-97
25-Jul-97
26-Jul-97
31-Jul-97
31-Jul-97
31-Jul-97
31-Jul-97
31-Jul-97
31-Jul-97
31-Jul-97
1 -Aug-97
1 -Aug-97
4-Aug-97
5-Aug-97
5-Aug-97
5-Aug-97
5-Aug-97
9-Aug-97
9-Aug-97
9-Aug-97
9-Aug-97
9-Aug-97
13-Aug-97
13-Aug-97
13-Aug-97
13-Aug-97
13-Aug-97
14-Aug-97
15-Aug-97
15-Aug-97
15-Aug-97
15-Aug-97
15-Aug-97
16-Aug-97
17-Aug-97
17-Aug-97
17-Aug-97
17-Aug-97
GP55 AFE est 2.XLS Page 2 of 6 6/25/97
Unocal Alaska Business Unit
Granite Point Platform
Well #55
Prepared by: Mitch Damm Date: 6/14/97 Revision #2
Estimate for Grass Roots Oil Well.
UNOCAL
No. Preliminary Procedure Time CUM CUM Depth Depth
Estimate Time Time In Out
(Hours) (Hours) (Days) (Feet) (Feet)
71 MU BHA 3.0 798 33.2 15,130
72 RIH with BHA. 6.0 804 33.5 15,130
73 Drill cement and pressure test casing. 3.0 807 33.6 15,130
74 Drill 10' of formation and perform LOT. 2.0 809 33.7 15,130 15,140
75 Change overto 8.2 PPG OBM. 4.0 813 33.9 15,140
76 Drill 6" hole 14.0 827 34.4 15,140 15,360
77 POOH 5.0 832 34.6 15,360
78 BHA handling. 2.0 834 34.7 15,360
79 RIH with BHA. 6.0 840 35.0 15,360
80 Ream to bottom. 1.0 841 35.0 15,360
81 Drill 6" hole 14.0 855 35.6 15,360 15,520
82 POOH 5.0 860 35.8 15,520
83 BI-IA handling. 2.0 862 35.9 15,520
84 RIH with BHA. 6.0 868 36.1 15,520
85 Ream to bottom. 1.0 869 36.2 15,520
86 Drill 6" hole 14.0 883 36.8 15,520 15,680
87 POOH 5.0 888 37.0 15,680
88 BHA handling. 2.0 890 37.1 15,680
89 RIHwith BHA. 6.0 896 37.3 15,680
90 Ream to bottom. 1.0 897 37.4 15,680
91 Drill 6" hole 14.0 911 37.9 15,680 15,840
92 POOH 5.0 916 38.1 15,840
93 BHA handling. 2.0 918 38.2 15,840
94 RIH with BHA. 6.0 924 38.5 15,840
95 Ream to bottom. 2.0 926 38.6 15,840
96 Drill 6" hole 14.0 940 39.1 15,840 16,000
97 POOH 5.0 945 39.4 16,000
98 BHAhandling. 2.0 947 39.4 16,000
99 RIH with BHA. 6.0 953 39.7 16,000
100 Ream to bottom. 2.0 955 39.8 16,000
101 Drill 6" hole 14.0 969 40.4 16,000 16,160
102 POOH 5.0 974 40.6 16,160
103 BOP Test 4.0 978 40.7 16,160
104 BHA handling. 2.0 980 40.8 16,160
105 RIH with BHA. 6.0 986 41.1 16,160
106 Ream to bottom. 2.0 988 41.1 16,160
107 Drill 6" hole 14.0 1002 41.7 16,160 16,320
108 POOH 5.0 1007 41.9 16,320
109 BHAhandling. ~ ~ ('~ ~iV ~ ~ 2.0 1009 42.0 16,320
110 RIHwithBHA. ~,~ ~ .~, ~ "~- ~'~ 6.0 1015 42.3 16,320
111 Ream to bottom. 2.0 1017 42.4 16,320
112 Drill 6" hole.
~2 L'; !_ ~ ~o~[ 14.0 1031 42.9 16,320 16,480
113 POOH 5.0 1036 43.1 16,480
114 BHA handling. ~-~,,~:~ .... Cq} ~:: f~a.~ [,-art,,.' ~ {~0Bi~i$$i0II 2.0 1038 43.2 16,480
GP55 AFE est 2.XLS -~3~llgh°ra~° Page 3 of 6
Estimated
Date
17-Aug-97
17-Aug-97
17-Aug-97
17-Aug-97
17-Aug-97
18-Aug-97
18-Aug-97
18-Aug-97
18-Aug-97
19-Aug-97
19-Aug-97
19-Aug-97
19-Aug-97
20-Aug-97
20-Aug-97
20-Aug-97
20-Aug-97
21-Aug-97
21-Aug-97
21-Aug-97
21-Aug-97
22-Aug-97
22-Aug-97
22-Aug-97
22-Aug-97
23-Aug-97
23-Aug-97
23-Aug-97
23-Aug-97
23-Aug-97
24-Aug-97
24-Aug-97
24-Aug-97
24-Aug-97
25-Aug-97
25-Aug-97
25-Aug-97
25-Aug-97
26-Aug-97
26-Aug-97
26-Aug-97
26-Aug-97
27-Aug-97
27-Aug-97
6/25197
Unocal Alaska Business Unit
Granite Point Platform
Well #55
Prepared by: Mitch Damm Date: 6/14/97 Revision #2
Estimate for Grass Roots Oil Well.
UNOCAL )
No. Preliminary Procedure Time CUM CUM Depth Depth
Estimate Time Time In Out
(Hours) (Hours) (Days) (Feet) (Feet)
115 RIH with BHA. 6.3 1044 43.5 16,480
116 Ream to bottom. 3.0 1047 43.6 16,480
117 Drill 6" hole. 15.0 1062 44.2 16,480 16,640
118 POOH 5.3 1067 44.5 16,640
119 BHA handling. 2.0 1069 44.5 16,640
120 RIH with BHA. 6.3 1075 44.8 16,640
121 Ream to bottom. 3.0 1078 44.9 16,640
122 Drill 6" hole. 15.0 1093 45.6 16,640 16,800
123 POOH 5.3 1099 45.8 16,800
124 BHA handling. 2.0 1101 45.9 16,800
125 RIH with BHA. 6.3 1107 46.1 16,800
126 Ream to bottom. 3.0 1110 46.2 16,800
¥27 Drill 6" hole. 15.0 1125 46.9 16,800 16,960
128 POOH 5.3 1130 47.1 16,960
129 BHA handling. 2.0 1132 47.2 16,960
130 RIH with BHA. 6.5 1139 47.4 16,960
131 Ream to bottom. 3.0 1142 47.6 16,960
132 Drill 6" hole. 15.0 1157 48.2 16,960 17,120
133 POOH 5.5 1162 48.4 17,120
134 BHA handling. 2.0 1164 48.5 17,120
135 RIH with BHA. 6.5 1171 48.8 17,120
136 Ream to bottom. 3.0 1174 48.9 17,120
137 Drill 6" hole. 15.0 1189 49.5 17,120 17,280
138 BOP test 4.0 1193 49.7 17,280
139 POOH 5.5 1198 49.9 17,280
140 BI-IA handling. 2.0 1200 50.0 17,280
141 RIH with BHA. 6.5 1207 50.3 17,280
142 Ream to bottom. 3.0 1210 50.4 17,280
143 Drill 6" hole. 15.0 1225 51.0 17,280 17,440
144 POOH 5.5 1230 51.3 17,440
145 BHA handling. 2.0 1232 51.3 17,440
146 RIH with BHA. 6.5 1239 51.6 17,440
i47 Reamto bottom. 3.0 1242 51.7 17,440
148 Drill 6" hole. 15.0 1257 52.4 17,440 17,600
149 POOH 5.5 1262 52.6 17,600
150 BHA handling. 2.0 1264 52.7 17,600
151 RIH with BHA. 6.5 1271 52.9 17,600
152 Ream to bottom. 3.0 1274 53.1 17,600
153 Drill 6" hole. 15.0 1289 53.7 17,600 17,760
154 POOH 5.5 1294 53.9 17,760
155 BHA handling. 2.0 1296 54.0 17,760
156 RIH with BHA. 6.5 1303 54.3 17,760
157 Ream to bottom. 3.0 1306 54.4 17,760
158 Drill 6" hole. 15.0 1321 55.0 17,760 17,920
Estimated
Date
27-Aug-97
27-Aug-97
28-Aug-97
28-Aug-97
28-Aug-97
28-Aug-97
28-Aug-97
29-Aug-97
29-Aug-97
29-Aug-97
30-Aug-97
30-Aug-97
30-Aug-97
31-Aug-97
31-Aug-97
31-Aug-97
31-Aug-97
1-Sep-97
1-Sep-97
1-Sep-97
1 -Sep-97
1-Sep-97
2-Sep-97
2-Sep-97
2-Sep-97
3-Sep-97
3-Sep-97
3-Sep-97
4-Sep-97
4-Sep-97
4-Sep-97
4-Sep-97
4-Sep-97
5-Sep-97
5-Sep-97
5-Sep-97
5-Sep-97
6-Sep-97
6-Sep-97
6-Sep-97
7-Sep-97
7-Sep-97
7-Sep-97
8-Sep-97
GP55 AFE est 2.XLS Page 4 of 6 6/25/97
Unocal Alaska Business Unit
Granite Point Platform
Well/155
Prepared by: Mitch Datum Date: 6/14/97 Revision #2
Estimate for Grass Roots Oil Well.
UNOCAL )
No. Preliminary Procedure Time CUM CUM Depth Depth
Estimate Time Time In Out
(Hours) (Hours) (Days) (Feet) (Feet)
159 POOH 5.5 1326 55.3 17,920
160 BHA handling. 2.0 1328 55.3 17,920
161 RIH with BHA. 6.5 1335 55.6 17,920
162 Ream to bottom. 3.0 1338 55.7 17,920
163 Drill 6" hole. 15.0 1353 56.4 17,920 18,080
164 CBU 3.0 1356 56.5 18,080
165 POOH with BHA 10.0 1366 56.9 18,080
166 LD motor and MWD 4.0 1370 57.1 18,080
167 RU SWS WLU for DP conveyed logs. 2.0 1372 57.1 18,080
168 RIH with logging tools: DIL, FDC, CNL, DT, GR, CCL 8.0 1380 57.5 18,080
169 Install side door entry sub. RIH with wet connect. 8.0 1388 57.8 18,080
170 Log C-5 8.0 1396 58.1 18,080
171 ND side-door entry sub. POOH with wireline 3.0 1399 58.3 18,080
172 POOH with logging tools 9.0 1408 58.6 18,080
173 RU casing crews for 5" liner 1.5 1409 58.7 18,080
174 RIH with 5" liner 5.0 1414 58.9 18,080
175 Continue to RIH with 5" liner on drillpipe 9.0 1423 59.3 18,080
176 Circulate and condition hole for cement. 3.0 1426 59.4 18,080
177 RU for cement job. 1.0 1427 59.5 18,080
178 Pump cement job and set liner hanger. 4.0 1431 59.6 18,080
179 POOH and circulate out cement. Continue to POOH. 7.0 1438 59.9 18,080
180 MU 6" bit and 7" casing scraper. 1.0 1439 60.0 18,080
181 RIH with 7" cleanout assembly. 6.0 1445 60.2 18,080
182 Wash and drilll cement to liner top. Circualte hole. 2.0 1447 60.3 18,080
183 POOH. 7.0 1454 60.6 18,080
184 LD BI-IA. PU mill and 5" casing scraper. 2.0 1456 60.7 18,080
185 RIH with 7" cleanout assembly. 8.0 1464 61.0 18,080
186 Wash and drilll cement to liner top. 3.0 1467 61.1 18,080
187 Circulate hole clean. 6.0 1473 61.4 18,080
188 :RU and test 5" liner lap. 2.0 1475 61.5 18,080
189 Change well over to diesel. 8.0 1483 61.8 18,080
190 Transfer OBM. 1.0 1484 61.8 18,080
191 Clean mud pits. 5.0 1489 62.0 18,080
192 POOH with cleanout assembly. 10.0 1499 62.5 18,080
193 LD 2-7/8" DP and drill collars. 3.0 1502 62.6 18,080
1502 62.6 18,080
Perforate 5" Liner and Run 3-1/2" Gas Lift Completion. 1502 62.6 18,080
194 PU 3-3/8" TCP guns andjewerly. 3.0 1505 62.7 18,080
195 RIH with TCP guns on 3-1/2" DP. 10.0 1515 63.1 18,080
196 Set packer. RU surface EQ. Fire guns. Circulate Well. 4.0 1519 63.3 18,080
197 POOH with TCP Guns 10.0 1529 63.7 18,080
198 LD TCP Guns 5.0 1534 63.9 18,080
199 RU SWS WLU. 1.5 1536 64.0 18,080
200 PU packer and tail pipe. 1.0 1537 64.0 18,080
Estimated
Date
8-Sep-97
8-Sep-97
8-Sep-97
8-Sep-97
9-Sep-97
9-Sep-97
9-Sep-97
10-Sep-97
10-Sep-97
10-Sep-97
10-Sep-97
11-Sep-97
11-Sep-97
11-Sep-97
11-Sep-97
11-Sep-97
12-Sep-97
12-Sep-97
12-Sep-97
12-Sep-97
12-Sep-97
12-Sep-97
13-Sep-97i
13-Sep-97
13-Sep-97
13-Sep-97
14-Sep-97
14-Sep-97
14-Sep-97
14-Sep-97
14-Sep-97
14-Sep-97
15-Sep-97
15-Sep-97
15-Sep-97
15-Sep-97
15-Sep-97
15-Sep-97
16-Sep-97
16-Sep-97
16-Sep-97
16-Sep-97
16-Sep-97
17-Sep-97
GP55 AFE est 2.XLS Page 5 of 6 6/25/97
Unocal Alaska Business Unit
Granite Point Platform
Well #55
PrePared by: Mitch Damm Date: 6/14/97 Revision #2
Estimate for Grass Roots Oil Well.
UNOCAL )
No. Preliminary Procedure Time CUM CUM Depth Depth
Estimate Time Time In Out
(Hours) (Hours) (Days) (Feet) (Feet)
201 RIH with packer and set on wireline. 6.0 1543 64.3 18,080
202 POOH 2.5 1545 64.4 18,080
203 RD SWS WLU. 0.5 1546 64.4 18,080
204 RU to run 3-1/2" completion. 1.0 1547 64.4 18,080
205 PU, rabbit and run 3-1/2" gas lift completion. 16.0 1563 65.1 18,080
206 Space out, install SCSSV, control line, and PU hanger. 6.0 1569 65.4 18,080
207 :Land hanger and install packoff. 1.0 1570 65.4 18,080
208 ND BOPE. 4.0 1574 65.6 18,080
209 Install 3-1/8" block tree and test. 4.0 1578 65.7 18,080
210 RU slickline. RIH and pull SCSSV sleeve. 2.0 1580 65.8 18,080
211 Turn well over to Production. 0.0 1580 65.8 18,080
1580 65.8 18,080
212 LD drillpipe and load out eq. on boat. 24.0 1604 66.8 18,080
213 Demob Rig 24.0 1628 67.8 18,080
Estimated
Date
17-Sep-97
17-Sep-97
17-Sep-97
17-Sep-97
18-Sep-97
18-Sep-97
18-Sep-97
18-Sep-97
18-Sep-97
18-Sep-97
18-Sep-97
18-Sep-97
19-Sep-97
20-Sep-97
20-Sep-97
GP55 AFE est 2.XLS Page 6 of 6 6/25/97
FOR INQUIRIES CONTACT LOCATION WH.~,R_ E INVOICES WF'-~-',$UBMI'I-I'ED VEF'''~ NO. DATE CHECK NO.
1031548 07-01-97 2002326
ICF-JC ~ .~; ; UCHER NO:. GROSS DISCOUNT NET
30-JUN-97 DRILLPERMITGP55 07973000001 100.00 100.00
FORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A.
DETACH ~TUB BFFORI~ DF:PCJ,qITIkI~ ~HFP, K 100. O O 10 0. 0 0
WELL PERMIT CHECKLIST0o A.Y /
WE L L NAM, E~f~4~./~,~/~/../~ ~'-~ PROGRAM= expr] dev~redrlF] servr] wellbore segn ann disp pa:~n
1-~,,/ c~.OL gA, ~2~C> u~# ~ ~ O,/OFF SHOR~. O37
ADMI N I STRAT I ON
REMARKS
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
DA~I;E ) 1. 2.
ENGINEERING
]4
15
16
17
18
19
2O
21
22
23
24
25
26
27
28
29.
Lease number appropriate ...............
Unique well name a~d number
Well located proper distance from other wells
drilling
Operator only affected party .............
Operator has appropriate bond in force ........
Permit can be issued without conservation order.. . .
Permit can be issued without administrative approval..~
Can permit be approved before 15-day wait ........
Conductor string provided ...............
Surface casing protects all known USDWs ........
CMT vol adequate to circulate on conductor & surf csg.
CMT vol adequate to tie-in long string to surf csg . .
CMT will cover all known productive horizons ......
Casing designs adequate for C, T, B & permafrost ....
Adequate tankage or reserve pit ............
If a re-drill, has a 10-403 for abndnmnt been approved.
Adequate wellbore separation proposed .........
If diverter required, is it adequate ...........
Drilling fluid program schematic & equip list adequate
BOPEs adequate ....................
BOPE press rating adequate; test to ~ psig.~
Choke manifold complies w/API ~-53 (May 84) ......
Work will occur without operation shutdown .......
Is presence of H2S gas probable .............
GEOLOGY
TE
30. Permit can be issued w/o hydrogen sulfide measures .... Y N/~_
Data presented on potential overpressure zones ..... Y
31 ' Seismic analysis of shallow gas zones .........
32.
33. Seabed condition survey (if off-shore) ....... .//. Y N
34. Contact name/phone for weekly progress reports ..... Y N
[exploratory only]
GEOLOGY: ENGINEERING: COMMISSION:
Comments/Instructions:
HOWldlf · A:\FORMS\cheklist rev 01/97
