Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout197-1411a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: _1 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: 29.97' BF:
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- 4 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
20"117'
13-3/8" L-80 2689'
9-5/8" L-80 7786'
7" L-80 8733'
4-1/2" L-80 8798'
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
9/15/1997
9/9/1997
ADL 028304
89-111
1900' (Approx.)
7987' / 7786'N/A
None
10065' / 8799'
MWD, DIR, GR, 4-Phase RES
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
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
Set Whipstock
Water-Bbl:
PRODUCTION TEST
Not on Production
Date of Test:
Flow Tubing
Conductor
68#
117'
36' 7987'
Gas-Oil Ratio:Choke Size:
9285'
Per 20 AAC 25.283 (i)(2) attach electronic information
47#
9198'
36'
7657'
DEPTH SET (MD)
8987' / 8615'
PACKER SET (MD/TVD)
38'
CASING WT. PER
FT.GRADE
26#
665317
664576
TOP
SETTING DEPTH MD
39'
SETTING DEPTH TVD
5974866
BOTTOM TOP
12-1/4"
39'
17-1/2"
HOLE SIZE AMOUNT
PULLED
50-029-21781-01-00
PBU E-26A
664479 5975544
1892' FNL, 328' FWL, Sec. 05, T11N, R14E, UM, AK
CEMENTING RECORD
5975190
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
3/21/2022
1520' FNL, 501' FWL, Sec. 06, T11N, R14E, UM, AK
2200' FNL, 421' FEL, Sec. 06, T11N, R14E, UM, AK
197-141 / 321-540
Prudhoe Bay Field / Prudhoe Oil Pool
67.7'
9285' / 8758'
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp North Slope, LLC
WAG
Gas
12.6#
38' 2689' 3723 cu ft Permafrost
6"9045' 10063'
1865 cu ft Class 'G'
8654'
7833'
9044'4-1/2" 12.6# L-80
SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
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,
230 cu ft Class 'G'8-1/2"
TUBING RECORD
Uncemented Slotted Liner
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
By Meredith Guhl at 2:56 pm, Apr 04, 2022
xG
Abandoned
3/21/2022
MDG
RBMDS 4/4/2022 MDG
DSR-4/4/22DLB 04-26-2022MGR18AUG2022
FEL DLB
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Top of Productive Interval 9225' 8743'
9225' 8743'
Sag River 9225' 8743'
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Joe Lastufka
Contact Email:joseph.lastufka@hilcorp.com
Authorized Contact Phone: 777-8400
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: 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.
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).
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:
Summary of Pre-Rig Work, Daily Report, Wellbore Schematic
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
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
Sag River
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.
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
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
4.4.2022Digitally 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: 2022.04.04 11:53:15 -08'00'
Monty M
Myers
5
ACTIVITYDATE SUMMARY
1/22/2022
***WELL S/I ON ARRIVAL*** (CTD)
TAG 4-1/2" XN NIPPLE W/ 3.80" SWAGE AT 9,001' SLM / 9,031' MD (Ring from xn
no-go).
DRIFT TO DEVIATION AT 9,206' MD W/ 3.70" x 20' DUMMY WHIPSTOCK.
TIGHT SPOT AT 9,054' MD, LIGHTLY WORKED BY, ~300# OVER-PULL TO PULL
BACK THRU.
***LDFN, WELL S/I & SECURED, CONTINUED ON 1/23/22 WSR***
1/23/2022
***CONTINUED FROM 1/22/22 WSR*** (CTD)
LRS LOADED IA W/ 443 BBLS OF CRUDE & TUBING W/ 165 BBLS OF CRUDE.
SET 4-1/2" PX PLUG BODY & P-PRONG IN X NIPPLE AT 8,978' SLM / 9,011' MD.
LRS ATTEMPTED PRESSURE TEST ON TUBING TO 1000 PSI (IA
communication).
LRS PERFORMED SUCCESSFUL CMIT-T x IA TO 2518 PSI (Tubing / IA bled to
300 psi).
SET 4-1/2" WHIDDON CATCHER SUB ON 4-1/2" PX PLUG AT 9,011' MD.
***LDFN, WELL S/I & SECURED, CONTINUED ON 1/24/22 WSR***
1/23/2022
T/I/O=2400/675/0 Temp= S/I LRS Unit #72 (CTD) Assist slickline with L&T. Pumped
443 BBL's of 100* crude down the IA to load. Pumped 165 BBL's of 100* crude down
the TBG to load. Slickline set TTP. Pressured up TBG to 1100 psi with 1.4 bbls crude
to test plug. CMIT-TxIA ***Passed*** to 2559/2518 psi. Pressure T/IA to 2608/2597
psi with 7 BBL's of crude. 1st 15 min T/IA lost 30/55 psi, 2nd 15 min T/IA lost 19/24
psi, for a total loss of 49/79 psi in 30 min. Bled T/IA to 300/300 psi and recovered 6
BBL's. Slickline in control of well upon LRS departure. IA OA = OTG.
1/24/2022
***CONTINUED FROM 1/23/22 WSR*** (CTD)
PULL RK-OGLV FROM ST #1 (6,902' MD) & RK-LGLV FROM ST #2 (4,176' MD).
SET RK-DGLV'S AT ST #2 (4,176' MD) & ST #1 (6,902' MD).
PERFORMED SUCCESSFUL PRESSURE TEST ON TUBING TO 1276 PSI (~1000
psi differential to IA).
PULL EMPTY 4-1/2" WHIDDON CATCHER SUB FROM 8,964' SLM.
PULL P-PRONG & 4-1/2" PX PLUG BODY FROM X-NIPPLE AT 8,978' SLM / 9,011'
MD.
***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS***
1/31/2022
T/I/O = 1880/120/Vac. Temp = SI. TBG FL (E-line request). No AL. TBG FL @
4700' (71 bbls).
SV, SSV, WV = C. IA, OA = OTG. 20:00
2/1/2022
***WELL SHUT IN ON ARRIVAL*** (Mill)
MIRU HES E-LINE.
RIH W/ WELLTEC MILLING BHA W/ 3.802" MILL.
MILL THRU XN-NIPPLE AT 9031'. DRY DRIFT THRU CLEAN. POOH.
AT SURFACE MILL GAUGED TO 3.80".
RDMO E-LINE.
***JOB COMPLETE / WELL LEFT S/I***
2/19/2022
T/I/O = 2500/120/Vac. Temp= SI. Bleed WHPs to 0 psi (pre rig). No AL. T FL @
8920' (wet gas). IA FL @ surface. Bled IAP to BT from 500 psi to Vac in 20 min, 0.6
bbls. Monitor for 30 min. During monitor WHPs unchanged. Final WHPs =
2440/Vac/Vac.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:30
Daily Report of Well Operations
PBU E-26A
MILL THRU XN-NIPPLE AT 9031'. DRY DRIFT THRU CLEAN. POOH.
AT SURFACE MILL GAUGED TO 3.80"
Daily Report of Well Operations
PBU E-26A
2/21/2022
T/I/O=SI/0/0. PRE CTD. Remove tree cap assembly and companion flange. Installed
CDR kill line and tapped blind flange. Torqued to specs. Tessted tree and kill line 300
low and 5000 high [Passsed]. Tested flange to top of SV 300 low and 3500 high[
Passed]
Activity Date Ops Summary
3/16/2022 Continue rig move to E-26B Both modules on location. Spot modules and being backing in. Switch to stompers due to tight location. Lower stairs and landings.
Hook up Putz and flow line. Lay out cellar liner and put down duck ponds. Spot return tank and rig up return line - PT to 4250 psi RU steam lines and begin
warming up rig. Safe out cellar and chink. Install pressure bulkhead on coil reel - MEG good. Leak Test tree. Remove tree cap. Install 4 1/16" x 7 1/16" adaptor
flange. Stab BOP's. NU BOP's and MPD line.
3/17/2022 Finish nipple up of BOPE and MPD line. Reconfigure risers. Service BOPE stack and choke manifold. Make up test joint for Big hole stack. Electrician
troubleshooting connection issue between BHI and Bulkhead. Bad cable end from putz. Begin fluid pack on stack. Ram door leaking. Vac out stack. Replace door
seal on 3" pipe/ slips(off drillers side). Begin shell test of BOPE again Ram door leaking. Replace door seal on 3" pipe/slips(drillers side). Test Gas alarms: Pit H2S
Fail / Recalibrate / Pass Begin BOP test per PTD/Sundry. Test 1:C7, C9, C10, C11. Test 2: B/S, R2, B2, C15. Install Tree cap with 2-3/8" x 3.0" Multi joint. Test 3:
Annular, TIW, B1, B4. Test 4: 2-3/8" Upper P/S, TIW #2, B2, B3. Test 5: Lower 2-3/8" P/S, C5, C6, C8, TV2. Test 6: Choke A, Choke C. Drawdown test on
Accumulator Test 7: C1, C4, TV 1. Test8: 3" P/S, C2, C3 LD test joint and BOP test equipment. Clear and Clean rig floor. Swap out test riser for drilling riser. Install
drip pan on riser. Measure RKB's. MU injector to well Begin fluid packing coil. Pump ~ 5 bbls of MeOH followed by fresh water. Pump coil volume of fresh water.
Test Inner Reel Valve to 3500 psi. Test Pack-offs to 3500 psi.
3/18/2022 RU Off drillers side PDL, Pressure test 3500#. RU Driller side PDL, Pressure test to 3500#. Test MPD line also. Install floats. Test to 3500# Good test. Install test
cap on UQC. Pressure stack to 3500#. Line up down coil. Pressure up to 6750# on Inner reel iron and bulkhead. Good test. Finish loading reel with 1% KCL.
Calibrate MM's. PJSM for Bullhead ops. Load MPD line up to stack with MEOH spear. Pause- Let Highline crew finish putting us on highline power. On highline @
16:45. Pressure up to 2700#. Open well with 2390# wellhead pressure. Bullhead kill. 10 bbls Methanol spear. 120 bbls away @ 0 psi. 250 bbls away @ 5 psi. Shut
down and monitor. Troubleshoot frozen return line to TT. Continue to fill hole with 1% KCL using charge pump. Return line thawed out. Confirm with air to Tiger
Tank. Pressure test return line to 4250 psi. Attempt to fill hole and unable to keep up with loss rate. Pumped 80bbls and no returns at surface. Discuss options with
Drilling Engineer and CTD Foreman. Prep to pump Polyswell pill for LCM. Pump 30 bbl, 20 ppb polyswell stage. Pump 15 bbl Fresh Water tail. Chase polyswell
and fresh water with 1% S KCL. Pump until tail of fresh water is ~ 9300'. 5 bpm and 1900 psi final pressure during placement of polyswell. Wait 1 hr and attempt to
fill hole. Wait one hour for polyswell to set. Pump down tubing with 1% S KCL for hole fill. Pump 11 bbls and tubing started to pressure up. Shut down pump and
flow check well. Pumped 7 bbls after 15 minutes to fill well. Well taking ~ 28 bph. MU Baker 4 1/2" mono bore whipstock. MU BHI CoilTrak BHA. RIH w/BHA #1:
Baker 4 1/2" monobore whipstock. Taking weight @ 9100' 5k down. Attempt to PUH and over pull 18k(70k coil weight). Pump 1 bpm through open EDC. Attempt to
orient and free BHA. Stop pumping and close EDC. Pull -15k WOB and hold tension Pull free with 20k over pull. POOH and discuss plan forward with Drilling
Engineer.
3/19/2022 Puh dragging. Took weight at 9058' MD. Orient without issue. PUH to -20K. Pulled free. Pooh with whipstock BHA. Using caution with possible whipstock issue.
PJSM. Perform 10 min no flow / loss rate. Fill hole after 15 min. Took 7 bbls. Lay down BHA#1. Whipstock setting tool. Discuss with drilling engineer. Never tied in
before whipstock was pre set. Rih with BHA#2 MWD and 2.75" JSN with 3/4" ball on seat. - Rate: 0.56 bpm in, 0.12 bpm out. Circ pressure: 275 psi. Mud Weight:
8.4 ppg in, 8.4 ppg out. Log down for tie-in from 8890’ to 8940.47’ MD (JB Marker) with -10'’ correction. Log CCL from 8930.47' to 9031' MD. Compared. Log CCL
from 8930.47' to 9031' MD. Compared depths to tubing tally. On depth. Rih slowly and find whipstock at 9045' MD. WLEG at 9044.1', Top of scoop guide at 9045'
MD. PU off whipstock. Bring rate up to 2.5 bpm. Circulate 2 bottoms up. Nothing seen. Pooh. Rate:2.5 bpm in, 1.80 bpm out. Mud Weight: 8.4 ppg in, 8.4 ppg out
OOH - flow check well. Fill hole after 15 min. ~ 40 bph loss rate. LD nozzle and recover ball. MU Baker whipstock fishing BHA RIH w/BHA #3 Baker Skirted Catch G
Spear. Loss rate on trip in hole ~ 40 bph Log Tie-In from 8890' Correct -4.5'. PUW @ 8900' = 46k. RIW = 28k. Attempt to engage whipstock fish @ 9043.8' with
5k WOB. PU Clean - no fish. RIH and pushed whipstock to 9088'. Set weight and attempt to PU. PU clean. PUH to 9000' and no indication of fish through TT or
jewelry. RIH to set down again and able to RIH freely. WT CK @ 9150' = 50k. Tag @ 9170' with 7k down weight. Repeat @ 9175'. POOH to check for whipstock
fish. Rate 1.94 bpm in, 1.07 bpm out. Mud Weight: 8.41 in, 8.51 out. OOH - fill well and break QTS. LD BHI BHA. LD fishing tools and whipstock FISH. MU and RIH
w/BHI Milling BHA w/3.79" D311 and string reamer. Fill coil and verify motor differential pressure. Continue RIH @ 9000'.
3/20/2022 Cleanout run. Log down for tie-in from 8950’ to 9012.48' MD (JB Marker) with -9' correction. Free spin: 1800 psi, 2.73 bpm. Rate: 2.73 bpm in, 2.08 bpm out. Circ
pressure: 1800 psi. Mud weight: 8.39 ppg in, 8.40 ppg out, ECD: 8.61 ppg. 9170' bobble of motor work. PU clean with 45K. Wash down to 9400' with no sign of
anything. Minimal motor work seen. PU and log tie in to SAG markers +4.5' correction. Pump 20 bbls of 130K LSRV Sweep. Out bit at 9400'. Chase up and out.
Polyswell / Paraffin coming back. Come offline on pump. Log CCL / Dry drift from 9000' MD to 9408' MD. Clean pass all the way down. Everything coming in 3'
deep. PU and verify tie in to SAG markers. Tie in 0' correction. Pump 26 bbl of 130K LSRV sweep. Chase out of hole from 9370'MD. Pull 30 fpm up to above
jewelry. Sweep at surface. Nothing to note. Clean sweep. Pooh. Mud Weight: 8.41 ppg in, 8.52 ppg out. Rate: 2.71 bpm in, 1.82 bpm out. Perform 150' jog at
surface. Open EDC. Perform 10 min flow / loss check. Losing 28 bph. Fill hole while tagging up. BHA swap. Lay down Cleanout BHA#4. Swap mill and string
reamer out for window mill and reamer. Stand-back. Swap out lowers on MWD package. Make up BOT whipstock. Tag up. Verify EDC open. RIH with BOT
Whipstock BHA #5. Rate: 0.92 bpm in, 0.73 bpm out. Circ pressure: 552 psi. Mud Weight: 8.39 ppg in, 8.43 ppg out. Log down for tie-in from 9235’ to 9280.13’ MD
(SAG Marker) with -7’ correction. PUW 46K, SOW 27K Rih to set depth of 9297.45' (9285' Top). Pressure up to 3600 psi and release from whipstock. TOWS:
9285’ md. BOWS: 9297.45’ md. Set 180° ROHS. Confirm set with 3.3k down weight. Pick off clean. Pooh. Mud Weight: 8.40 ppg in, 8.40 ppg out. Rate: 1.30 bpm
in, 0.61 bpm out. LD whipstock setting tool. MU window milling BHA. RIH w/BHA #6 - Window Milling BHA. Mud Weight: 8.39 ppg in, 8.51 ppg out. Rate: .51 bpm
in, .37 bpm out. Fix injector counter issues - gummed up wheel. Log Tie-In from 8930' - correct +30'. Dry tag top of whipstock @ 9283'. Establish free spin and get
parameters. 47k PUW. Free Spin @ 2.5 bpm = 1740 psi. Mud Weight: 8.38 ppg in, 8.42 ppg out. Rate: 2.51 bpm in, 1.87 bpm out. Begin milling window per BOT
representative from 9282.3'. Continue milling window from 9285.1'. Mud Weight: 8.40 ppg in, 8.52 ppg out. Rate: 2.49 bpm in, 1.91 bpm out.
50-029-21781-02-00 / -03-00API #:
Well Name:
Field:
County/State:
PBW E-26B/C
Prudhoe Bay West
Hilcorp Energy Company Composite Report
, Alaska
3/21/2022Spud Date:
TOWS:
9285’ md. BOWS: 9297.45’
3/21/2022 Continue Milling 3.80” window in 4-1/2” liner per BOT 9285.1’ md to 9288.6’ md. Rate: 2.49 bpm in, 1.92 bpm out. Mud Weight: 8.40 ppg in, 8.51 ppg out.
DWOB: 3.0-4.0klbs. Circ pressure: 2526 psi. Appear we are out. Let string reamer mill out. Mill rathole 9289.6-9299.6. Rate: 2.47 bpm in, 1.91 bpm out. Mud
Weight: 8.40 ppg in, 8.51 ppg out. DWOB: 0.5- 2.0 klbs. Circ pressure: 2726 psi. ROP 12 fph. Looks like we are drilling formation. Perform reaming passes.
Attempt dry drift. Took weight at 9284'. Perform 4 more passes. Mild motor work. seen initially. Cleaned up. Dry drifted clean. Pumped 15 bbls HiVis sweep. Pooh
from TD. SAG sample confirmed. Pooh. - Mud Weight: 8.40 ppg in, 8.51 ppg out. Rate: 2.80 bpm in, 2.79 bpm out Perform 10 min no-flow. Fill hole Loss rate 24
bph. Lay down BHA#6. Mill and reamer both 3.79" No-Go MU and deploy BHA #7 - Build BHA. 2 7/8" ULS Motor and 3.75" x 4.25" Bi-Center Bit RIH w/BHA #7. In
Rate = .55 bpm, Out Rate = .38 bpm. MW In = 8.45 ppg, MW out = 8.51 ppg. Log Tie-In from 9210' Correct -6'. Displace coil and well to PowerPro drilling mud
system. Close EDC and begin drilling build section Tag bottom of rat hole @ 9301'. Begin drilling build section from 9298'. In Rate = 2.53 bpm , Out Rate = 1.45
bpm. MW In = 8.64 ppg , MW Out = 8.71 ppg. Free spin = 2600 psi. ROP = 50 - 70 fph. PUH and investigate tool failure - cycled power and came back on
Continue drilling build section from 9380' to 9430'. In Rate = 2.51 bpm , Out Rate = 1.99 bpm. MW In = 8.68 ppg , MW Out = 8.81 ppg. Free spin = 2600 psi. ROP
= 12 - 20 fph. WOB = 3k. Continue drilling build section from 9430' to 9443'. In Rate = 2.48 bpm , Out Rate = 1.99 bpm. MW In = 8.69 ppg , MW Out = 8.85 ppg.
Free spin = 2688 psi. ROP = 12 - 20 fph. WOB = 3k. IA = 393, OA = 0 Coil counter gummed up and slipping. Clean and confirm working. Wiper trip to window to
Tie-In. Log tie-in and correct -6' Continue drilling build section from 9437' to 9451'. In Rate = 2.45 bpm , Out Rate = 2.03 bpm. MW In = 8.71 ppg , MW Out = 8.85
ppg. Free spin = 2641 psi. ROP = 5 - 20 fph. WOB = 2.5 - 3k. IA = 254, OA = 0.
1. Type of Request: Abandon 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: ___________________
2.Operator Name:4.Current Well Class:5.Permit to Drill Number:
Exploratory Development
3.Address:Stratigraphic Service 6. API Number:
7. If perforating:8.Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require a spacing exception?Yes No
9.Property Designation (Lease Number):10.Field/Pool(s):
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD):
10,065'None
Casing Collapse
Structural
Conductor
Surface 2,670psi
Intermediate 4,760psi
Liner 5,410psi
Liner 7,500psi
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary 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:OIL WINJ WDSPL Suspended
16.Verbal Approval:Date:GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name: Trevor Hyatt
Monty Myers Contact Email:
Contact Phone:777-8396
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
9,045' - 10,040'
1,365'
4-1/2"
8,654' - 8,797'
January 1, 2022
9,045' - 10,063'1,018'
4-1/2" 12.6#
8,654' - 8,798'
4-1/2" Baker S Packer
7,953'
2,653'
7,833' - 9,198'
Perforation Depth MD (ft):
7,987'
20"
13-3/8"
80'
7,786'
117'
2,689'
7,657' - 8,733'7"
9-5/8"
Length Size
L-80
TVD Burst
9,044'
7,240psi
MD
6,870psi
4,930psi
117'
2,689'
PRESENT WELL CONDITION SUMMARY
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 028304
197-141
3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21781-01-00
Hilcorp North Slope, LLC
PBU E-26A
Prudhoe Bay Field / Prudhoe Oil Pool
8,430psi
Tubing Grade: Tubing MD (ft):
8,987' / 8,615'
Perforation Depth TVD (ft): Tubing Size:
17. I hereby certify that the foregoin g is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
AOGCC USE ONLY
Drilling Manager
trevor.hyatt@hilcorp.com
8,798'10,065'8,798'2,388 None
ory
Statu
Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval.
10.12.2021
By Samantha Carlisle at 3:47 pm, Oct 12, 2021
321-540
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: 2021.10.12 14:43:58 -08'00'
Monty M
Myers
SFD 10/12/2021 DSR-10/12/21
10-407
BOPE test to 3500 psi.
Variance to 20 AAC 25.112(i) Approved for alternate plug placement.
MGR14OCT2021
JLC 10/14/2021
Jeremy Price Digitally signed by Jeremy Price
Date: 2021.10.14 14:31:09 -08'00'
RBDMS HEW 10/19/2021
To: Alaska Oil & Gas Conservation Commission
From: Trevor Hyatt
Drilling Engineer
Date: October 8, 2021
Re: PBU E-26A Sundry Request
Sundry approval is requested to set a whipstock in E-26A with the rig as part of the drilling
and completion of the proposed E-26B CTD lateral.
Proposed plan for E-26B (and contingency E-26C) Producer:
Prior to drilling activities, screening will be conducted to drift for whipstock, dummy mandrels and MIT-IA. E-line
will then mill the XN-nipple.
See the E-26B PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the
Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. A 4-1/2" whipstock will be set with the rig and a
single string 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Sag, build through
the Ivishak and land in Zone 2. The lateral will continue in Zone 1 and 2 to TD (this well is E-26B WP09). If it is
determined the primary target is not sufficient to produce from, a billet will be set and the well sidetracked to the
contingency target and directional plan. This plan also drills in Zone 1 and 2 to TD (this well is E-26C WP07). The
proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr solid liner, cemented in place and
selectively perforated post rig. This completion will completely isolate and abandon the parent Sag slotted liner.
This Sundry covers plugging the existing Sag slotted liner via the liner cement job or liner top packer, if the liner
lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)).
Pre-Rig Work - (Estimated to start in January 2022):
1. Slickline: Dummy WS drift and dummy all mandrels
a. Drift past whipstock setting location
b. Dummy all 4-1/2” GLMs
2. Fullbore: MIT-IA to 2,500 psi
3. E-line: Mill XN-nipple at 9,031’ MD
a. Mill nipple to 3.80” ID
4. Valve Shop: Pre-CTD Tree Work as necessary
Rig Work:
x Reference PBU E-26B and E-26C PTD submitted in concert with this request for full details.
x General work scope of Rig work:
1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,388 psi
2. Set 4-1/2” flow through whipstock
a. Top of whipstock set at 9,285’ MD (top of window - pinch point)
b. Oriented 180° ROHS
3. Mill Window
4. Drill Build and Lateral
5. Run and Cement Liner*
6. Freeze Protect and RDMO
7. Set LTP* (if needed), RPM log and perforate post rig
* Approved alternate plug placement per 20 AAC 25.112(i)
Trevor Hyatt CC: Well File
Drilling Engineer Joseph Lastufka
907-223-3087
I concur, the well produces with a GOR of ~100,000 scf/stb and thus has very low on time. Sidetracking the well should allow for improved
recovery from this portion of the field. DSR-10/12/21
Sundry 321-540
PTD 221-084
Well Bighole Date
Quick Test Sub to Otis -1.1 ft
Top of 7" Otis 0.0 ft
Distances from top of riser
Excluding quick-test sub
Top of Annular 6.0 ft
Top of Annular Element 6.7 ft
Bottom Annular 8.0 ft
CL Blind/Shears 9.3 ft
CL 2-3/8" Pipe/Slips 10.1 ft
B1 B2 B3 B4 Choke Line
Kill Line
CL 3" Pipe/Slips 12.6 ft
CL 2-3/8" Pipe/Slips 13.4 ft
CL of Top Swab 16.0 ft
Swab Test Pump Hose
T1 T2
Swab 1
CL of Flow Cross 17.4 ft
Master
CL of Master 18.8 ft
LDS
IA
OA
LDS
Ground Level
CDR2-AC 4 Ram BOP Schematic 15-Jan-21
CDR2 Rig's Drip Pan
7-1/16" 5k Flange X 7" Otis Box
Hydril 7 1/16"
Annular
2-3/8" Pipe/Slips
7-1/16"
5k Mud
Cross
2-3/8"Pipe/Slips
Blind/Shear
7-1/16"
5 Mud
Cross
3" Pipe/Slips
Sundry Application
Plug for Re-drill Wells
Work Flow
This process is used to identify wells that are suspended for a very short time prior to being
re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and
assigned a current status of "Suspended."
Step Task Responsible
1 The initial reviewer will check to ensure that the "Plug for Redrill" box
in the upper left corner of Form 10-403 is checked. If the "Abandon" or
"Suspend" boxes are also checked, cross out that erroneous entry and
initial it on both copies of the Form 10-403 (AOGCC's and operator's
copies).
Geologist
2 If the “Abandon” box is checked in Box 15 (Well Status after proposed
work) the initial reviewer will cross out that erroneous entry and initial it
on both copies of the Form 10-403 (AOGCC's and operator's copies).
Instead, check the "Suspended" box and initial that change.
The drilling engineers will serve as quality control for steps 1 and 2.
Geologist
then
Drrilling
Engineer
(QC)
3 When the Stat Tech receives "a Form 10-403 with a check in the "Plug
for Redrill" box, they will enter the Typ_Work code "IPBRD" into the
History tab for the well in RBDMS. This code automatically generates
a comment in the well history that states "Intent: Plug for Redrill."
Stat Tech
4 When the Stat Tech receives any Form 10-407, they will check the
History tab in RBDMS for the "Intent: Plug for Redrill" code
(IPBRD). If present and there is no evidence that a subsequent re-drill
has been COMPLETED, the Stat Tech will assign a status of
SUSPENDED to the well bore in RBDMS no matter what status is
listed on the 10-407. The Stat Tech will also change the status on the
10-407 form to SUSPENDED, and date and initial this change. If the
Stat Tech does not see the "Intent: Plug for Redrill" comment or code,
they will enter the status listed on the Form 10-407 into RBDMS.
Stat Tech
5 When the Form 10-407 for the redrill is received, the Stat Tech will
change the original well's status from SUSPENDED to ABANDONED.
Stat Tech
6 The first week of every January and July, the Stat Tech and one of the
Geologists will check the "Well by Type Work Outstanding" user
query in RBDMS to ensure that all of the Plug for Redrill wells have
been handled properly. At this same time, they will also review the list
of suspended wells for accuracy.
Stat Tech
Geologist
SFD 10/12/2021
SFD 10/12/2021
PBU E-26A
197-141
•
•
~~~und~r, Th~r~a~ ~ D~~4
From: Preble, Gary B (SAIC) [Gary.Preble@bp.com]
Sent: Monday, July 13, 2009 1:23 PM
To: Maunder, Thomas E (DOA)
Subject: Emailing: 15-07C-203-097-WORK SUMMARY-REV.PDF, H-02A-202-160-WORK
SUMMARY-REV. PDF
Attachments: 15-07C-203-097-WORK SUMMARY-REV.PDF; H-02A-202-160-WORK SUMMARY-
REV.PDF
q, 1~ ,~~
~ `
~s
i~-o~c-zv~-c~~-w~-c~z~,-2flz-~~-wo
3(2K ~UMMAFtY-RE..2K SU#MM,~#2Y-3t~V..
Tom, Sorry for the error.
E-26a was correct and the attachments contain the corrected data for H-02A 202-160 and
15-07c 203-097. Giad you are still reading everything.
The message is ready to be sent with the following file or link
attachments:
15-07C-203-097-WORK SUMMARY-REV.PDF
H-02A-202-160-WORK SUMMARY-REV.PDF
Note: To protect against computer viruses, e-mail programs may prevent sending or
receiving certain types of file attachments. Check your e-mail security settings to
determine how attaeh~ents are handled.
«15-07C-203-097-WORK SUMMARY-R~V.PDF» «H-02A-202-160-WORK SUMMARY-REV.PDF»
Page 1 of 1
~~'~~~ J~~. ~:f ~ ~:D~~
~~und~r, Thomas E (DOA)
frorr~: f~Aaunder, Thomas E (~OA)
Sent: Mqnday, July 13, 2009 10:19 AM
To: Ga~r Preble (SA1C)
SubjeCt: E-26A (197-141) H-02A (202-160), D~ 15-07C (20~-097)
Gary, ~
I am reviewing the 40as fior the recent ~urmanite st~rting head r~pa+rs r~n these wei~s. Operations ~ummaries
were attached Mow~ver it appears, for the most part, that the summaries are identical. The same summaries are
attachEd to all 3 40~s for activitiss si~ated to occur May 18 - June 4, 2009. Identical operations arE described for
May 7- May 17 fflr pS 15-fl7C ar~d ~-26A. There ~re some unique activities d~scribed at the b~ginning of DS
15r07C and #he end of H-02A.
Pd appreciate your reconciling the~e reports. While I car~ understand similar overalf pperations, it is not valid for
the operations to agree down to the individual pressurE readings or water level soundings in the celiar. Thanks in
advan~e.
Tom Maunder, PE
AQGCC
" ` " ' ° STATE OF ALASKA
ALAS~IL AND GAS CONSERVA710N COMMIS~N
REPORT OF SUNDRY WELL OPERATIONS
.s~~
~ /PJ G~
1. Operations Abandon ~ Repair Well Q Plug Perforations ~ Stimulate ~ Other ~ Furmanite Wrap `
Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~
Change Approved Program ~ Operat. Shutdown ~ PerForate ~ Re-enter Suspended Well ~
2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number:
rvame: De~elopment ~ . Exploratory ~~ 197-1410 _
3. Address: P.O. Box 196612 Stratigraphic C~ Service [~ 6. API Number:
Anchorage,AK 99519-6612 50-029-21781-01-00~
7. KB Elevation (ft): 9. Well Name and Number:
67.7 KB - PBU E-26A -
8. Property Designation: 10. Field/Pool(s): -
ADLO-028304 " PRUDHOE BAY Field/ PRUDHOE OIL Pool
11. Present Well Condition Summary:
Totai Depth measured 10065 . feet Plugs (measured) None
true vertical 8798.41 _ feet Junk (measured) None
Effective Depth measured 10065 - feet
trae vertica! 8798 . feet
Casing Length Size MD TVD Burst Collapse
Conductor 110 20" Surface - 110 Surface - 110
Surface 2689 13-3/8" 68# I-80 Surface - 2689 Surface - 2689 4930 2270
Production 7987 9-5/8" 47# I-80 Surface - 7987 SurFace - 7785 6870 4760
Liner 1365 7" 26# I-80 7833 - 8198 7657 - 8733 7240 5410
SL Liner 1018 4-1/2" 12.6# I-80 9045 - 10063 8654 - 8798 8430 7500
PerForation depth: Measured depth: SEE ATTACHED - _ _ _ _
True Vertical depth: _ _ _ _ _
Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 9044'
0 0 -
Packers and SSSV (type and measured depth) 7"X4-1/2" S PKR 8987'
7"X4-1/2" TIW HORZ PKR 9045'
0
~~~~~~GD
0
12. Stimulation or cement squeeze summary: ~,~`~ S~ ,a la,~i~~ v?~j~~j ~~ 2~a9
~
Intervals treated (measured):
~
~i ~i~;ax,~ ~+,. ;~ ~~~ :~c}~ti. Cummission
Treatment descriptions irtcluding volumes used and final pressure: ji 7
~t~iG~d6.Fi ~ti`~~;
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure
Prior to well operation: SI
Subsequent to operation: 1085 48207 1 1136
14. Attachments: 15. Well Class after aroposed work:
Copies of Logs and Surveys Run Exploratory ~ Dev~elopment ~- Service ~
Daily Report of Well Operations X 16. Well Status after proposed work:
Oil ~~ Gas ~ WAG ~ GINJ r WINJ ~ WDSPL ~
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
N/A
Contact Gary Preble
Printed Name Gary Preble Title Data Management Engineer
Signature Phone 564-4944 Date 6/29/2009
Form 10-404 R~ed 04/2006 ~~~ ~llL ~ 4 2009 ~j,~.t~,~ Submit Original Only
E-26A
197-141
PERF ATTACHMENT
~
Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base
E-26A 9/17/97 SL 9,045. 10,040. 8,653.76 8,796.63
AB ABANDONED PER PERF
APF . ADD PERF RPF REPERF
BPP BRIDGE PLUG P ULLED SL SLOTTED LINER
BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED
FCO FILL CLEAN OUT SPS SAND PLUG SET
FIL FILL SQF SQUEEZE FAILED
MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE
MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED
MLK MECHANICAL LEAK STO S7RADDLE PACK, OPEN
OH OPEN HOLE
~
•
•
E-26A
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
EVENT SUMMARY
~ •
~ 5/21/2009 T/I/O = 10/40/100. Temp = SI. Hold open bleed for Furmanite wrap (Furmanite
~ wrap). OA FL near surface. N2 cap installed on OA. 5-6" of fluid in sump
F drain. Vac truck vac'd fluid before Com ositech sand blasted SH (10:30 AM .
~ Bled AP to 0 si in 30 seconds all as . Furmanite installed com osite wra
~
~ ~
~ on SH. Held open OA bleed for 8 hrs. Pass down to night shift.
SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP.
~
~
~ ~
~. ~
I
~
5/21/2009 ~
T/I/0=10/40/90. Temp=Sl. Prep cellar for Furmanite wrap (Furmanite wrap). ~
~ No AL. Sampled cellar gravel & removed 1/2 yd to provide a sump drain (3'-
j 11") for surface water inflow for upcoming work. Final T/I/0=10/40/90.
~ ~ SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP.
_....._ _.~~ _
j 5/21/2009`
~ T/I/0= 10/40/0. Temp= SI. Hold open bleed for Furmanite wrap (Furmanite
~ wrap). No AL. Continued open bleed on OA for 11 hours. No changes in
? ~ WHPs. WHPs= 10/40/0. ~
~ ~
3
~
~
t ~ SV,WV=closed. SSV,MV=open. IA,OA=open to gauge. NOVP. ;
€
~
3
' ~5/22/2009 {
i
T/I/O = 100/50/0. Temp = SI. Hold open bleed on OA for Furmanite wrap
~ i (Furmanite wrap). IAP increased 10 psi overnight. Held open bleed on OA for ~
~ 12 hrs while furmanite wrapped SH.
~ ~
j ~
1
l ~ ~
SV, WV=Shut. SSV, MV=Open. IA&OA=OTG. NOVP.
~
~ ~
[
~ E
i
~.~ ~
E
j 5/22/2009
~ T/I/0= 15/50/0. Temp= SI. Hold open bleed on OA for Furmanite wrap
j (Furmanite Wrap). No AL. Kept open bleed on OA for 11 hours, WHPs ~
[ ~ unchanged. Heater trunk still installed in wellhouse cellar. Final WHPs=
~ ~ 15/50/0.
j
i
~
~ ~
f ~
; 3
~..._.... SV,WV=closed. SSV,MV=open. IA,OA=open to gauge. NOVP.
~
~
• •
l 5/23/2009 T/I/0= 15/50/0. Temp= SI. Hold open bleed on OA for Furmanite wrap ~~
(Furmanite Wrap). No AL. Kept open bleed on OA for 12 hours, TP & IAP both ~
~ increased 5 psi. Heater trunk still installed in wellhouse cellar. Final ~
~ WHPs=20/55/0.
~SV,WV=closed. SSV,MV=open. IA,OA=open to gauge. NOVP.
~ ~
~ F
~ 1
~j
I i
~ ............. }
; 5/23/2009=T/I/O = 10/50/0. Temp = SI. Hold open bleed for Furmanite wrap (Furmanit~
~ wrap). Furmanite installed final stage of composite wrap (10:OOa~. Held ~
~ open OA bleed for 12 hours. Changed out with night shift. ~
; SV, WV=C. SSV MV=O. IA, OA=OTG. NOVP.
~ ; . ~
~ ,
3 ;
~ j
~
; ;
;
~ j
~ 5/24/2009 T/I/O - 20/50/0. Temp - SI. Hold open bleed for Furmanite wrap (Furmanite
4 ~ ~
~wrap). Held open bleed on OA for 12 hrs, change out with night shift. ~
j ~SV, WV=Shut. SSV, MV=Open. IA&OA=OTG. NOVP. ~
~ ~ I
~ ~
~
~
~
; ~ i
i i
~ ~
' ~.~„~....~_ ~ _ ..~,,.~. __.... ~
~~~ ~~ 5/24/2009 `T/I/0= 20/55/0. Temp= SI. Hold open bleed on OA for Furmanite wrap ~
~(Furmanite Wrap). No AL. Kept open bleed on OA for 12 hours. IAP
' increased 5 psi. Heater trunk still installed in wellhouse cellar. Final WHPs= ~
20/60/0.
~ SV,WV=closed. SSV,MV=open. IA,OA=open to gauge. NOVP.
~
~
~ ~
i ~ ~
; ~ ~
i ~
~~~ 5/25/2009 T/I/O = 24/59/0. Temp = SI. Hold open bleed for Furmanite wrap (Furmanite
; ~wrap). Held open bleed for 3 hrs. SI OA bleed, monitored for 30 mins. TP & I
3 ; IAP unchanged, OAP increased 2 psi. Heater left in wellhouse per Furmanite. ~
3 ~ Final WHPs = 24/59/2. ~
~SV, WV=Shut. SSV, MV=Open. IA&OA=OTG. NOVP. ~
~
; ~
~
~ ~
~
E
.
~ ~.~ ~ ~ _ __.._.. ~ __ ~ ~___ ____.__ ~ ~.~ _ ~ _~ _._ ~__.~ ._..~ _._
~ ~
~ ~~ 5/26/2009~T/I/O = 24/59/2. Temp = SI. Monitor cellar water inflow (post Furmanite wrap). ~
~ WHPs unchanged overnight. Water depth in cellar is -4".
SV, WV=Shut. SSV, MV=Open. IA&OA=OTG. NOVP.
,
~
~ ~ 3
I ~ ~
~ ~ ;
i ~
~~5/27/2009`T/I/0= 20/59/2. Temp= SI. Monitor cellar water inflow, ensure that heater is
~still on well (post Furmanite wrap). TP decreased 4 psi, IAP & OAP unchanged ~
E overnight. Heater working properly. water depth in cellar is 3".
?SV,WV= C. SSV,MV= O. IA,OA= OTG. NOVP. ~
~ ~
i
1
3 (
:
' ~ ~
~ ~ i
j ~ ~
]_- ~ ~ ~ _ _ ___~~__. _ ~ ~.. .. _ _ ~
; 5/28/2009~T/I/O = 30/60/5. Temp = S1. Monitor cellar water inflow, ensure heater is still ~
~on well (post Furmanite wrapj. TP increased 10 psi, IAP increased 5 psi. ;
~ ~ Heater online blowing in cellar. Water is 3" deep @ 6:00. ~
a ~SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP.
~ ~ ~
E ~
~ ~
i
~ ~
~ ~
E
;~ ~~ 5/29/2009~T/I/O = 20/50/9. Temp=Sl. Monitor cellar water inflow, ensure that heater is ~~
1 still on well (Post Furmanite wrap). No AL. OAP increased 4 psi overnight. ~
3 Water level in cellar @ 4" @ marker (6:00 position). ~
SV,WV=Closed. SSV,MV=Open. IA,OA=OTG. NOVP ~
~
j ~ ~
I ~
~ ~
;A.,~..~~ ... __ ..w.F.
' ~~ ~ ~.~~._
; 5/30/2009~ ~ I/0=30/65/10. Temp=Sl. Monitor cellar water inflow, ensure that heater is
` still on well (post Furmanite wrap). TP icreased 10 psi, IAP increased 15 psi,
~ OAP increased 1 psi overnight. Water level in cellar is 4" @ 6 O'Clock position
marker.
j ~SV, WV=Closed. SSV, MV=Open. IA, OA=OTG. NOVP. {
~ ~ i
E ~
[ ; ~
i ~
~m ~ ~ _- --._~~~ _~__e_ .__~ .~_.~___ __~ ~~ ___ ~ ~ __ ~__ __~ _~
~ „ .~ . o - ~ ~
~ 5/31/2009 T/I/0=31/66/11. Temp=Sl. Monitor cellar water inflow, ensure heater is still on
~ well. (Post Furmanite wrap). TP, IAP & OAP all increased 1 psi overnight.
~ Cellar water is 5" deep at the 6 O'clock position. Heater is still on the well.
' ~SV & WV = CLOSED. SSV & MV = OPEN. IA & OA = OTG. NOVP.
~ ~ ~
~ ;
~ ~ ~
~ ~ I
( ~ I
;
~ __
; 6/4/2009~T/I/0= 30/60/0. Temp= SL~*PASSED* MIT-OA TO 1200 psi w/ triplex (repair t
; ~ SH leak). No AL. OA FL near su ace. ncrease rom psi o 0
~ ~psi, OAP lost 100 psi. Repressured OAP to 1200 psi with 2.5 bbl of diesel
; ~(total), lost 20 psi the first 15 min, and 10 psi the second 15 min, for a total loss s
~ ~of 30 psi in 30 min. No visible leaks detected on Furmanite wrap on SH. During~
~ ~MIT IAP increased 40 psi. Bled OAP from 1200 psi to 0 psi in 15 min. During ~
~bleed IAP decreased 40 psi. Monitored for 30 min. Final WHPs= 30/70/0. ~
~ ~SV,WV= C. SSV,MV= O. IA,OA= OTG. NOVP. ~
j E
Z ~
~ I
%
i
~
......_...., __~`__,> . .. .,....~..._~.r~ _.._._~.___.a ~_. ,.,_. ..._....~~.........._...._..-..._.._...._...~._.....e..._...~ ................. ............._.. ~
THE MATER/AL UNDER THIS COVER HAS
ON OR BEFORE
BEEN
2001
PL
E
W
M A T E IA L U N D E R
T H I S M --'-----
~ A R K E R~-~
C:LORAMI~ILMDOC ~-'~--~'~
AOGCC Geological Materials Inventory
PERMIT
Log
8152
MWD SRVY
NGP-MD
NGP-TVD
t-4'lJ-407 Completion Date
Are dry ditch samples required?
9 7-141 BP EXPLORATION
Data Sent Recieved Box
t,,~P~RRY GR 10/22/97 10/22/97
~"~ RRY 7975.98-10065. 12/4/97 12/5/97
.
i>~)')5-10065 10/29/97 10/30/97
/I'776-8798 10/29/97 10/30/97
yes ~~o And received? ~~,_no
Was the well cored?
Are tests required?
_ .
Well is in compliance
Comments
yes
yes ~-~no
Initial
Analysis _description recieved?
R ' 9
ece~ved. ........... ~ ..... no-
Thursday, September 23, 1999 Page 1 of 1
Transmittal
State of Alaska
Alaska Oil & Gas Conservation Comm.
Atten: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
of Final Prints. Please sign and return copy to:
Western Altas Logging Services
Pouch 340013
Prudhoe Bay, AK 99734-0013
17-Feb-98
Well Name Services Bluelines R/F Sepia Film
MPK-43 A Injection Profile I 1 · 0
MPK-18 A Injection Profile 1 1 0
Received by: .""1 /
Date
Contact Rebecca Lange if you have a question concerning this transmittal
at (907) 659-2816 or Fax (907) 659-2602.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
z,. ~ ~...~'...~
~-L."~..~
1. Status of Well Classification of Se'~ Well
[~Oil E~Gas i--~ Suspended i--i Abandoned [--I Service '~ O,~¢r,
2. Name of Operator 7. Permit Number
BP Exploration (Alaska)Inc. 97-141 '/~'~,o/'-,
3. Address 8. APl Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 ~,.._,,.,,,,~, 50-029-21781-01
4. Location of well at surface ~' .r'~Qmi~ 9. Unit or Lease Name
1520' SNL, 501' WEL, SEC. 06, T11N, R14E, UPM t '.~~ Prudhoe Bay Unit
At top of productive interval ['~rr~ i 0. Well Number
1905' SNL, 333' EWL, SEC. 05, T11N, R14E, UPM~ ~,¢-~-_--""~¢.,. ,~,~~ E-26A
At total depth~-"-~ ! 11. Field and Pool
2212' SNL, 414' WEL, SEC. 06, T11N, R14E, UPM Prudhoe Bay Field / Prudhoe Bay
5. Elevation in feet (indicate KB, DF, etc.) ! 6. Lease Designation and Serial No. Pool
KBE = 67.70'I ADL 028304
12. Date Spudded 113. Date i.D. Reached i 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions
9/9/97 9/15/97 9/18/97 N/A MSLI One
i17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost
10065 8798 FTI ' 10065 8798 FTI I~Yes I--INoI (Nipple) 2197' MDI 1900' (Approx.)
22. Type Electric or Other Logs Run
MWD, DIR, GR, 4-Phase RES
23. CASING~ LINER AND CEMENTING RECORD
CASING SETTING DEPTH HOLE
SIZE WT. PER ET. GRADE TOP BO'I-rOM SIZE CEMENTING RECORD AMOUNT PUL~ED
20" Conductor Surface 110' 8 cu )/ds Concrete
13-3/8" 68# L-80 Surface 2689' 17-1/2" 3723 cu ft Permafrost
9-5/8" 47# L-80 Surface 7987' 12-1/4" 1865 cu ft Class 'G'
7" 26# L-80 7833' 9198' 8-1/2" 230 cu ft Class 'G'
4-1/2" 12.6# L-80 9045' 10063 6" Uncemented Slotted Liner
24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD
Bottom and interval, size and number) -SIZE DEPTH SET (MD) PACKER SET (MD)
4-1/2" Slotted Liner 4-1/2", 12.6, L-80 9044' 8987'
MD TVD MD TVD
9342' - 9753' 8764' - 8797'
9874' - 10038' 8791' - 8797' 26. Acc, FRACTURE, CEMENT SQUEEZE, ETC.
" .. . '. DeleTE iNTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
.
· Freeze Protect with 14~ Bbls of Diesel
27, PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
October 9, 1997 I Flowing
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO
TEST PERIOD
I
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-DEL OIL GRAViTY-APl (COBH)
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.
Form 10-407 Rev. 07-01-80 Submit In Duplicate
29. Geologic Markers 30. Formation Tests
,,
Measured True Vertical Include interval tested, pressure data, all fluids
Marker Name Depth Depth recovered and gravity, GOR, and time of each phase.
Sag River 9225' 8742'
31. List of Attach'me~ts
Summary of Dally Drilling Reports, Surveys .
32' I her'eby cert~e.~~is true and c°rrect tO the best Of my knOwledg'eSigned - ~/~'/~<~
Jame~S~ith "-' ~,.-"(/~ Title Senior Drilling Engineer, Acting Date ,
1~-26A
97-141 Prepared By Name/Number: Terrie Hubble, 564-4628
Well Number Permit No. / Approval No.
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, stea .m injection, air injecti .0n, ~ait water, disposal, water
supply:[er injectio, n, observation, injection for iri-§itu combustion. .. ' '
ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces
on this form and in any attachments.
ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item
16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional
interval to be separately produced, showing the data pertinent to such interval.
ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of
the cementing tool.
ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In,
Other-explain.
ITEM 28: If no cores taken, indicate 'none'.
Form 10-407 Rev. 07-01-80
Progress Report
Facility PB E Pad
Well E-26A
Rig Doyon # 9
Page 1
Date 24 October 97
Date/Time
05 Sep 97 12:00-12:30
12:30-16:30
16:30-21:00
21:00-21:30
21:30-00:00
06 Sep 97 00:00-00:30
00:30-01:00
01:00-02:00
02:00-05:30
05:30-06:00
06:00-06:30
06:30-10:30
10:30-12:00
12:00-12:30
12:30-13:00
13:00-14:00
14:00-16:30
16:30-20:30
20:30-21:30
21:30-22:00
22:00-00:00
07 Sep 97 00:00-00:30
00:30-03:30
03:30-04:00
04:00-06:00
06:00-06:30
06:30-12:00
12:00-12:30
12:30-16:30
16:30-17:00
17:00-20:30
20:30-22:00
22:00-00:00
08 Sep 97 00:00-00:30
00:30-06:00
06:00-07:30
07:30-09:30
09:30-11:00
11:00-12:00
12:00-12:30
12:30-13:00
13:00-21:00
21:00-22:00
22:00-00:00
09 Sep 97 00:00-00:30
00:30-02:30
02:30-03:30
03:30-06:00
06:00-06:30
06:30-10:00
10:00-11:00
11:00-12:00
12:00-12:30
12:30-14:00
Duration
1/2 hr
4hr
4-1/2 hr
1/2 hr
2-1/2 hr
1/2 hr
1/2 hr
lhr
3-1/2 hr
1/2 hr
1/2 hr
4hr
1-1/2 hr
1/2 hr
1/2 hr
lhr
2-1/2 hr
4hr
lhr
1/2 hr
2hr
1/2 hr
3hr
1/2 hr
2hr
1/2 hr
5-1/2 hr
1/2 hr
4hr
1/2 hr
3-1/2 hr
1-1/2 hr
2hr
1/2 hr
5-1/2 hr
1-1/2 hr
2hr
1-1/2 hr
lhr
1/2 hr
1/2 hr
8hr
lhr
2hr
1/2 hr
2hr
lhr
2-1/2 hr
1/2 hr
3-1/2 hr
lhr
lhr
1/2 hr
1-1/2 hr
Activity
Held safety meeting
Rig moved 100.00 %
Rig moved 100.00 %
Held safety meeting
Circulated at 8150.00 ft
Held safety meeting
Circulated at 8150.00 ft
Installed Hanger plug
Rigged up BOP stack
Rigged up High pressure lines
Rigged up High pressure lines (cont...)
Tested BOP stack
Removed Hanger plug
Held safety meeting
Retrieved Hanger plug
Installed Drillpipe retrieval string
Rigged up Tubing handling equipment
Laid down 4500.00 ft of Tubing
Repaired Handling equipment
Serviced Drillfloor / Derrick
Laid down 6000.00 ft of Tubing
Held safety meeting
Laid down 8150.00 ft of Tubing
Rigged down Tubing handling equipment
Tested Kelly cocks
Tested Bottom ram (cont...)
Set downhole equipment (wireline)
Held safety meeting
Retrieved Seal assembly
Tested Casing - Via annulus
Rigged up Wellhead primary components
Made up BHA no. 1
R.I.H. to 1500.00 ft
Held safety meeting
R.I.H. to 7000.00 ft
Repaired Drillstring handling equipment
R.I.H. to 7957.00 ft
Took MWD survey at 8012.00 ft
Circulated at 7987.00 ft
Held safety meeting
Circulated at 7987.00 ft
~ Milled Casing at 7986.00 ft
Reamed to 7986.00 ft
Pulled out of hole to 5000.00 ft
Held safety meeting
Pulled out of hole to 110.00 ft
Pulled BHA
Serviced Top ram
Serviced Top ram (cont...)
Made up BHA no. 2
Serviced Block line
R.I.H. to 2000.00 ft
Held safety meeting
R.I.H. to 7970.00 ft
RECEIVED
Alaska Oil & Gas Cons. Commission
Anchorage
Facility
PB E Pad
Progress Report
Well E-26A
Rig Doyon # 9
Page
Date
2
24 October 97
Date/Time
10 Sep 97
11 Sep 97
12 Sep 97
13 Sep 97
14:00-14:30
14:30-00:00
00:00-00:30
00:30-06:00
06:00-12:00
12:00-12:30
12:30-14:00
14:00-14:30
14:30-15:00
15:00-15:30
15:30-00:00
00:00-00:30
00:30-06:00
06:00-12:00
12:00-12:30
12:30-13:00
13:00-14:30
14:30-15:15
15:15-16:00
16:00-17:30
17:30-21:00
21:00-23:00
23:00-00:00
00:00-00:30
00:30-03:30
03:30-06:00
06:00-07:30
07:30-08:00
08:00-08:30
08:30-10:00
10:00-11:00
11:00-11:30
11:30-12:00
12:00-13:00
13:00-17:30
17:30-19:00
19:00-21:00
21:00-00:00
00:00-00:30
00:30-02:30
02:30-03:30
03:30-04:00
04:00-06:00
06:00-09:30
09:30-12:30
12:30-13:00
13:00-19:30
19:30-20:00
20:00-20:30
20:30-21:30
21:30-22:00
22:00-22:30
22:30-23:30
23:30-00:00
Duration
1/2 hr
9-1/2 hr
1/2 hr
5-1/2 hr
6hr
1/2 hr
1-1/2 hr
1/2 hr
1/2 hr
1/2 hr
8-1/2 hr
1/2 hr
5-1/2 hr
6hr
1/2 hr
1/2 hr
1-1/2 hr
3/4 hr
3/4 hr
1-1/2 hr
3-1/2 hr
2hr
lhr
1/2 hr
3hr
2-1/2 hr
1-1/2 hr
1/2 hr
1/2 hr
1-1/2 hr
lhr
1/2 hr
1/2 hr
lhr
4-1/2 hr
1-1/2 hr
2hr
3hr
1/2 hr
2hr
lhr
1/2 hr
2hr
3-1/2 hr
3hr
1/2 hr
6-1/2 hr
1/2 hr
1/2 hr
lhr
1/2 hr
1/2 hr
lhr
1/2 hr
Activity
Washed to 8027.00 ft
Drilled to 8242.00 ft
Held safety meeting
Drilled to 8430.00 ft
Drilled to 8560.00 ft (cont...)
Held safety meeting
Drilled to 8656.00 ft
Circulated at 8656.00 ft
Pulled out of hole to 7400.00 ft
R.I.H. to 8656.00 ft
Drilled to 8909.00 ft
Held safety meeting
Drilled to 9100.00 ft
Drilled to 9164.00 ft (cont...)
Held safety meeting
Drilled to 9193.00 ft
Circulated at 9193.00 ft
Pulled out of hole to 7980.00 ft
R.I.H. to 9150.00 ft
Circulated at 9198.00 ft
Pulled out of hole to 1058.00 ft
Pulled BHA
Rigged up Tubing handling equipment
Held safety meeting
Ran Liner to 1365.00 ft (7in OD)
Ran Drillpipe in stands to 6000.00 ft
Ran Drillpipe in stands to 6000.00 ft (cont...)
Circulated at 7986.00 ft
Ran Liner in stands to 9198.00 ft
Circulated at 9198.00 ft
Mixed and pumped slurry - 41.000 bbl
Reverse circulated at 7986.00 ft
Reverse circulated at 7832.00 ft
Circulated at 7832.00 ft
Pulled Drillpipe in stands to 7839.00 ft
Rigged up BOP stack
Tested BOP stack
Repaired BOP stack
Held safety meeting
Repaired BOP stack
Tested BOP stack
Repaired Choke manifold
Tested BOP stack
Tested BOP stack (cont...)
Made up BHA no. 3
Held safety meeting
R.I.H. to 8500.00 ft
Tested Kelly cocks
R.I.H. to 9027.00 ft
Drilled cement to 9101.00 ft
Circulated at 9101.00 ft
Tested Liner - Via annulus and string
Held drill (Kick (well kill))
Tested Liner - Via annulus and string
Facility
PB E Pad
Progress Report
Well E-26A Page
Rig Doyon # 9 Date
3
24 October 97
Date/Time
14 Sep 97
15 Sep 97
16 Sep 97
17 Sep 97
00:00-00:30
00:30-01:30
01:30-02:00
02:00-04:00
04:00-04:30
04:30-05:30
05:30-06:00
06:00-08:00
08:00-12:00
12:00-12:30
12:30-00:00
00:00-00:30
00:30-06:00
06:00-07:00
07:00-09:00
09:00-12:00
12:00-12:30
12:30-14:30
14:30-16:30
16:30-17:00
17:00-17:30
17:30-19:00
19:00-19:30
19:30-20:00
20:00-21:00
21:00-21:30
21:30-00:00
00:00-00:30
00:30-02:30
02:30-04:00
04:00-04:30
04:30-05:30
05:30-06:00
06:00-07:00
07:00-10:00
10:00-12:00
12:00-12:30
12:30-16:00
16:00-17:30
17:30-18:30
18:30-19:00
19:00-22:00
22:00-23:00
23:00-03:00
03:00-06:00
06:00-09:00
09:00-09:30
09:30-11:00
11:00-12:00
12:00-12:30
12:30-13:00
13:00-14:00
14:00-14:30
14:30-15:30
Duration
1/2 hr
lhr
1/2 hr
2hr
1/2 hr
lhr
1/2 hr
2hr
4hr
1/2 hr
11-1/2 hr
1/2 hr
5-1/2 hr
lhr
2hr
3hr
1/2 hr
2hr
2hr
1/2 hr
1/2 hr
1-1/2 hr
1/2 hr
1/2 hr
lhr
1/2 hr
2-1/2 hr
1/2 hr
2hr
1-1/2 hr
1/2 hr
lhr
1/2 hr
lhr
3hr
2hr
1/2 hr
3-1/2 hr
1-1/2 hr
lhr
1/2 hr
3hr
lhr
4hr
3hr
3hr
1/2 hr
1-1/2 hr
lhr
1/2 hr
1/2 hr
lhr
1/2hr
lhr
Activity
Held safety meeting
Drilled cement to 9116.00 ft
Held drill (Kick (well kill))
Drilled cement to 9198.00 ft
Drilled to 9118.00 ft
Circulated at 9118.00 ft
Circulated at 9218.00 ft
Circulated at 9218.00 ft (cont...)
Drilled to 9303.00 ft
Held safety meeting
Drilled to 9639.00 ft
Held safety meeting
Drilled to 9830.00 ft
Drilled to 9876.00 ft (cont...)
Circulated at 9876.00 ft
Drilled to 9939.00 ft
Held safety meeting
Drilled to 10065.00 ft
Circulated at 10065.00 ft
Pulled out of hole to 9150.00 ft
R.I.H. to 10065.00 ft
Circulated at 10065.00 ft
Pulled out of hole to 9500.00 ft
Circulated at 9500.00 ft
Pulled out of hole to 7600.00 ft
Circulated at 7600.00 ft
Pulled out of hole to 3200.00 ft
Held safety meeting
Pulled out of hole to 190.00 ft
Pulled BHA
Rigged up Handling equipment
Rigged up Tubing handling equipment
Ran Liner to 4-1/2in (300.00 ft OD)
Ran Liner to 300.00 ft (4-1/2in OD) (cont...)
Ran Tubing to 1001.00 ft (2-1/16in OD)
Ran Drillpipe in stands to 4000.00 ft
Held safety meeting
Ran Drillpipe in stands to 10065.00 ft
Set Permanent packer at 9048.00 ft with 1950.0 psi
Tested Permanent packer - Via annulus
Retrieved Liner hanger
Circulated at 10055.00 ft
Laid down 900.00 ft of 5in OD drill pipe
Circulated at 9045.00 ft
Laid down Drillpipe of 5500.00 ft
Laid down 9044.00 ft of Drillpipe (cont...)
Rigged up Tubing handling equipment
Laid down 800.00 ft of Tubing
Ran Drillpipe in stands to 1000.00 ft
Held safety meeting
Laid down 900.00 ft of 3-1/2in OD drill pipe
Serviced Block line
Serviced Draw works
Rigged up Top ram
Facility
PB E Pad
Progress Report
Well E-26A
Rig Doyon # 9
Page
Date
4
24 October 97
Date/Time
18 Sep 97
15:30-22:00
22:00-22:30
22:30-00:00
00:00-00:30
00:30-04:00
04:00-05:30
05:30-06:00
06:00-09:00
09:00-09:30
09:30-10:00
10:00-11:00
11:00-11:30
11:30-12:00
12:00-12:30
12:30-14:30
14:30-16:00
16:00-21:30
21:30-22:00
22:00-00:00
Duration
6-1/2 hr
1/2 hr
1-1/2 hr
1/2 hr
3-1/2 hr
1-1/2 hr
1/2 hr
3hr
1/2 hr
1/2hr
lhr
1/2 hr
1/2 hr
1/2 hr
2hr
1-1/2 hr
5-1/2 hr
1/2 hr
2hr
Activity
Ran Tubing to 7072.00 f't (4-1/2in OD)
Installed SCSSSV control line
Ran Tubing to 7500.00 ft (4-1/2in OD)
Held safety meeting
Ran Tubing to 9044.00 ft (4-1/2in OD)
Space out tubulars
Circulated at 9044.00 ft
Circulated at 9044.00 ft (cont...)
Installed Tubing hanger
Set packer at 8987.00 ft with 4000.0 psi
Tested Tubing
Tested Casing
Functioned Other sub-surface equipment
Held safety meeting
Removed BOP stack
Installed Surface tree
Freeze protect well - 145.000 bbl of Diesel
Installed Accessories
Serviced Xmas tree
A~aska 0il & Gas Cons, Commission
Anchorage
SPEF -SUN DRILLING SERVICES
ANCHOR_AGE ALASKA
SHARED SERVICES DRILLING
DBU / E-26A
500292178101
NORTH SLOPE BOROUGH
COMPUTATION DATE: 9/19/97
PAGE
DATE OF SURVEY: 091197
MWD SURVEY
JOB NUMBER: AK-MM-70260
KELLY BUSHING ELEV. = 67.70 FT.
OPERATOR: BP EXPLORATION
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS COURSE DLS TOTAL
INCLN DIRECTION RECTANGULAR COORDINATES VERT.
DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT.
7975.98 7775.90 7708.20
7995.95 7792.50 7724.80
8027.75 7818.96 7751.26
8059.62 7845.57 7777.87
8091.59 7871.42 7803.72
32 49 S 72.33 E .00 177.99S 767.12E -505.85
34 43 S 72.33 E 9.51 181.36S 777.70E -512.27
32 38 S 75.91 E 9.04 186.20S 794.65E -522.90
34 9 S 78.48 E 6.49 190.08S 811.75E -534.23
37 54 S 80.80 E 12.48 193.44S 830.24E -546.99
8123.63 7895.91 7828.21
8155.32 7918.64 7850.94
8187.50 7940.86 7873.16
8219.30 7962.21 7894.51
8251.20 7983.38 7915.68
42 23 S 82.92 E 14.65 196.34S 850.68E -561.57
45 54 S 84.84 E 11.85 198.69S 872.62E -577.69
46 47 S 86.63 E 4.88 200.41S 895.84E -595.20
48 52 S 89.04 E 8.62 201.30S 919.39E -613.49
47 56 N 89.61 E 4.30 201.42S 943.24E -632.47
8283.23 8005.43 7937.73
8315.06 8028.43 7960.73
8346.93 8052.39 7984.69
8378.92 8077.33 8009.63
8410.86 8103.21 8035.51
45 3 S 88.74 E 9.74
42 22 S 87.43 E 8.89
40 7 S 86.29 E 7.47
37 25 S 83.78 E 9.76
34 19 S 81.24 E 10.76
201.59S 966.47E -650.93
202.31S 988.45E -668.05
203.46S 1009.43E -684.12
205.18S 1029.38E -699.03
207.60S 1047.94E -712.40
8442.79 8130.03 8062.33 31 26
8474.69 8157.65 8089.95 28 34
8506.68 8186.14 8118.44 25 31
8538.56 8215.23 8147.53 22 44
8569.47 8243.99 8176.29 20 21
S 77.65 E 10.89
S 73.28 E 11.28
S 67.43 E 12.64
S 61.49 E 11.59
S 53.17 E 12.51
210.76S 1064.97E -724.11
214.73S 1080.41E -734.06
219.58S 1094.11E -742.08
225.16S 1105.87E -748.13
231.24S 1115.43E -752.11
8601.61 8274.36 8206
8633.94 8305.21 8237
8664.79 8334.71 8267
8696.71 8365.17 8297
8728.56 8395.34 8327
8759.48 8424.17 8356
8791.40 8453.25 8385
8823.27 8481.58 8413
8855.18 8509.43 8441
8887.29 8536.92 8469
.66 17 57
.50 17 1
.01 17 4
.47 17 54
.64 19 41
.47 22 40
.55 26 3
.88 28 36
.73 29 52
.22 32 26
S 41.70 E 13.86
S 27.79 E 13.22
S 12.89 E 14.13
S 3.03 W 15.17
S 15.08 W 13.38
S 24.06 W 14.25
S 33.29 W 15.92
S 42.99 W 16.06
S 51.71 W 13.91
S 58.17 W 13.12
238.29S 1123.21E -754.08
246.21S 1128.73E -753.73
254.62S 1131.85E -751.16
264.10S 1132.64E -746.09
274.17S 1130.98E -738.71
284.65S 1127.19E -729.38
296.14S 1120.83E -717.39
307.58S 1111.78E -703.28
318.09S 1100.33E -687.81
327.59S 1086.73E -671.23
8919.23 8563.33 8495
8951.31 8588.59 8520
8981.98 8611.37 8543
9011.66 8632.01 8564
9043.61 8652.87 8585
.63 36 3 S 64.99 W 16.50
.89 40 0 S 69.76 W 15.31
.67 44 4 S 72.38 W 14.45
.31 47 47 S 75.85 W 15.11
.17 50 42 S 77.61 W 9.99
336.09S 1070.92E -653.49
343.65S 1052.68E -634.37
350.30S 1033.26E -614.85
356.11S 1012.75E -594.97
361.66S 989.19E -572.82
SPET -SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
SHARED SERVICES DRILLING
PBU / E-26A
5oo2921781o1
NORTH SLOPE BOROUGH
COMPUTATION DATE: 9/19/97
DATE OF SURVEY: 091197
MWD SURVEY
JOB NUMBER: AK-MM-70260
KELLY BUSHING ELEV. = 67.70
OPERATOR: BP EXPLORATION
FT.
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS
INCLN
DG MN
COURSE DLS TOTAL
DIRECTION RECTANGULAR COORDINATES
DEGREES DG/100 NORTH/SOUTH EAST/WEST
VERT.
SECT.
9075.51 8672.39 8604.69 53 48
9107.44 8690.51 8622.81 57 2
9140.24 8707.55 8639.85 60 20
9183.04 8727.03 8659.33 65 30
9215.13 8739.28 8671.58 69 35
S 78.26 W 9.88 366.93S 964.53E -549.94
S 81.43 W 13.03 371.55S 938.66E -526.49
S 82.83 W 10.67 375.38S 910.90E -502.01
S 83.04 W 12.06 380.06S 873.09E -468.99
S 83.19 W 12.78 383.62S 843.66E -443.33
9247.12 8749.15 8681.45 74 26
9279.11 8756.40 8688.70 79 21
9310.02 8760.92 8693.22 83 48
9342.24 8763.94 8696.24 85 27
9373.96 8766.53 8698.83 85 9
S 83.34 W 15.17 387.18S 813.45E -417.05
S 81.55 W 16.29 391.28S 782.57E -389.92
S 82.76 W 14.88 395.45S 752.29E -363.22
S 85.65 W 10.31 398.69S 720.38E -335.77
S 85.80 W 1.06 401.05S 688.85E -309.17
9406.30 8769.39 8701.69 84 40
9438.37 8772.76 8705.06 83 16
9470.45 8776.68 8708.98 82 40
9502.24 8780.88 8713.18 82 8
9533.08 8784.99 8717.29 82 32
S 84.51 W 4.24 403.77S 656.76E -281.89
S 81.43 W 10.50 407.67S 625.11E -254.26
S 79.95 W 4.96 412.82S 593.69E -226.06
S 79.52 W 2.14 418.43S 562.68E -197.91
S 79.18 W 1.70 424.08S 532.65E -170.51
9564.90 8788.99 8721.29 83 1
9597.15 8792.56 8724.86 84 16
9629.24 8795.13 8727.43 86 33
9661.16 8796.56 8728.86 88 17
9692.90 8797.12 8729.42 89 41
S 78.21 W 3.39 430.27S 501.69E -142.06
S 75.69 W 8.67 437.51S 470.47E -112.77
S 72.95 W 11.09 446.15S 439.68E -82.97
S 70.03 W 10.64 456.28S 409.45E -52.72
S 67.46 W 9.22 467.78S 379.87E -22.18
9723.38 8797.03 8729.33 90 40 S 64.02 W 11.73
9755.53 8796.51 8728.81 91 11 S 61.03 W 9.44
9787.79 8795.74 8728.04 91 31 S 57.62 W 10.62
9819.53 8794.52 8726.82 92 52 S 54.29 W 11.31
9851.60 8792.62 8724.92 93 55 S 52.84 W 5.56
9883.59 8790.71 8723.01 92 54 S 49.50 W 10.90
9915.67 8790.14 8722.44 89 8 S 48.53 W 12.10
9947.70 8791.14 8723.44 87 16 S 46.48 W 8.64
9979.67 8792.82 8725.12 86 43 S 46.06 W 2.19
10007.24 8794.47 8726.77 86 25 S 46.02 W 1.10
480.30S 352.09E 7.55
495.13S 323.57E 39.25
511.58S 295.84E 71.30
529.33S 269.56E 102.97
548.34S 243.81E 134.98
568.36S 218.94E 166.89
589.40S 194.73E 198.88
611.02S 171.13E 230.75
633.09S 148.06E 262.45
652.19S 128.25E 289.77
10065.00 8798.39 8730.69 85 47 S 45.93 W 1.10 692.24S 86.81E 346.95
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
HORIZONTAL DISPLACEMENT = 697.66 FEET
AT SOUTH 7 DEG. 8 MIN. EAST AT MD = 10065
VERTICAL SECTION RELATIVE TO WELL HEAD
VERTICAL SECTION COMPUTED ALONG 233.03 DEG.
TIE IN SURVEY AT7975.98' MD
WINDOW POINT AT 7995.00' MD
PROJECTED SURVEY AT 10065.00'
MD
RECEIVED
DEr3 - 5 1997'
Alaska 011 & 6~s O~r,~, Oommissior~
A~]chorage
SPE~ -SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 3
SI-DARED SERVICES DRILLING
PBU / E-26A
500292178101
NORTH SLOPE BOROUGH
COMPUTATION DATE: 9/19/97
DATE OF SURVEY: 091197
JOB NUMBER: AK-MM-70260
KELLY BUSHING ELEV. = 67.70 FT.
OPERATOR: BP EXPLORATION
INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES MD-TVD VERTICAL
NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION
7975.98
8975.98
9975.98
10065.00
7775.90 7708.20
8607.03 8539.33
8792.61 8724.91
8798.39 8730.69
177.99 S 767.12 E 200.08
349.03 S 1037.20 E 368.95 168.87
630.53 S 150.71 E 1183.38 814.43
692.24 S 86.81 E 1266.61 83.24
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
SPEt
-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
SHARED SERVICES DRILLING
PBU / E-2SA
500292178101
NORTH SLOPE BOROUGH
COMPUTATION DATE: 9/19/97
DATE OF SURVEY: 091197
JOB NUMBER: AK-MM-70260
KELLY BUSHING ELEV. = 67.70 FT.
OPERATOR: BP EXPLORATION
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA TOTAL
MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD
DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE
VERTICAL
CORRECTION
7975.98 7775.90 7708.20 177.99 S 767.12 E 200.08
8086.97 7867.70 7800.00 192.96 S 827.54 E 219.27
8227.65 7967.70 7900.00 201.39 S 925.67 E 259.95
8366.65 8067.70 8000.00 204.47 S 1021.82 E 298.95
19.19
40.67
39.01
8486.03 8167.70 8100.00 216.39 S 1085.39 E 318.33
8594.60 8267.70 8200.00 236.70 S 1121.68 E 326.90
8699.37 8367.70 8300.00 264.93 S 1132.52 E 331.67
8807.60 8467.70 8400.00 301.99 S 1116.44 E 339.90
8924.74 8567.70 8500.00 337.41 S 1067.84 E 357.04
19.38
8.57
4.78
8.23
17.14
9067.74 8667.70 8600.00 365.65 S 970.58 E 400.04
9387.48 8767.70 8700.00 402.11 S 675.43 E 619.78
9415.98 8770.33 8702.63 404.77 S 647.17 E 645.65
43.00
219.73
25.88
THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN
THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS
~ALASKA~
BP Exploration / Arco
To: Alaska Oil & Gas Conservation Commission
Date: February 5, 1998
From:
Subject:
Terrie Hubble
Technical Assistant
Permit ~/97-141, E-26A
Enclosed, in duplicate, are revised copies of the above listed Well Completion
Report and Log. An error was found in the Section at Total Depth.
The well histories and logs have previously been filed with the Commission and
there are no changes.
Thank you.
/tlh
0 F:! I I_1_ I IM G S I:: !:t L/I 1-- E S
WEIJ, LOG TRANSMITTAL
To: State of Alaska October 29, 1997
Alaska Oil and Gas Conservation Comm.
Atm.: Loft Taylor ..... : .......
3 001 Porcupine Drive
Anchorage, Alaska 99501
MWD Formation Evaluation Logs E-26A,
AK-MW-70260
The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a
signed copy of this of this transmittal letter to the attention of~
Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518
E-26A:
2" x 5"MD Gamma Ray Logs:
50-029-21781-01
2"x 5" TVD Gamma Ray Logs:
50-029-21781-01
1 Blueline
1 Rev Folded Sepia
1 Blueline
1 Rev Folded Sepia
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252
A Dresser Industries, Inc. Company
r'I I::! I L_I_ I [NI G S I:: F! ~./I I-- I:: S
WELL LOG TRANSMITTAL
To: State of Alaska October 22, 1997
Alaska Oil and Ctas Conservation Comm.
Atm.: Loft Taylor
3001 Porcupine Dr.
Anchorage, Alaska 99501
MWD Formation Evaluation Logs
E-26A, AK-MW-70260
The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a
signed copy of this transmittal letter to the attention off
Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518
1 LDWG formatted Disc with verification listing.
APl#: 50-029-21781-01.
OCT 22 1997
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252
A Dresser Industries, Inc. Company
TONY KNOWLE$, GOVERNOR
ALASKA OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE '-
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
Julv 31. 1997
Dan Stoltz
Senior Drilling Enginccr
BP Exploration (Alaska), Inc.
PO Box 196612
Anchorage, AK 99519-6612
ae~
Prudhoc Bav Unit E-26A
BP Exploration (Alaska). Inc.
Permit No. 97-141
Sur. Loc.: 1520'SNL.501'WEL. SEC 06.T1 IN.RI4E. UM
Btmholc Loc: 2216'SNL.407'WEL.SEC 06,T 11N,R 14E.UM
Dear Mr. Stoltz:
Encloscd is thc approved application for permit to rcdrill thc above rcfcrcnccd xvell.
Thc permit to rcdrill docs not cxcmpt you from obtaining additional permits required bx' law from
other governmental agencies, and does not authorize conducting drilling operations until all other
rcquircd permitting dctcrminations arc made.
Blowout prcvcntion equipment (BOPE) must be tested in accordance with 20 AAC 25.035.
Sufficient notice (approximately 24 hours) of thc BOPE test pcrformcd before drilling below the
surface casing shoc must bc given so that a representative of thc Commission may witness the test.
Notice ma,,' be given bx' contacting thc Commission pctrolcum ficld inspcctor on thc North Slope
pager at 659-3607.
Chairman
BY ORDER OF THE COMMISSION
dllTenclosures
CCi
Depamncnt ol'!:ish & (}~;111i2. t!abit.t! Section w o cncl.
Depa.'lment el' l';nviromncnt Conservation w'o cncl.
--- STATE OF ALASKA -
ALASKA L,,L AND GAS CONSERVATION CON,,,,ISSION
PERMIT TO DRILL
20 AAC 25.005 Revised: 07/28/97
la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil
[] Re-Entry [] DeepenI []Service [] Development Gas []Single Zone [] Multiple Zone
i2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
BP Exploration (Alaska) Inc. Plan RKB = 67.97' Prudhoe Bay Field / Prudhoe
3. Address 6. Property Designation Bay Pool
P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028304
14. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025)
1520' SNL, 501' WEL, SEC. 06, T11N, R14E, UPM Prudhoe Bay Unit
At top of productive interval 8. Well Number Number 25100302630-277
1929' SNL, 5094' WEL, SEC. 05, T11N, R14E, UPM E-26A
Attotal depth ~'~ ~ 9. Approximate spud date Amount $200,000.00
2216' SNL, 407' WEL, SEC..j;~5~, T11 N, R14E, UPM 08/19/97
12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
ADL 028299, 2216' MDI No Close Approach 2560 10032' MD / 8720' TVD
16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)}
Kick Off Depth 8000' MD Maximum Hole Angle 92° Maximum surface 3300 psig, At total depth (TVD) 8662' / 3450 psig
18. Casing Program Setting Depth
Size Specifications Top Bottom Quantity of Cement
Hole Casing Weight Grade Coupling Length MD 'I-VD MD TVD (include stage data)
8-1/2" 7" 26# L-80 IBT-Mod 1491' 7850' 7433' 9341' 8710' 180 sx Class 'G'
6" 4-1/2" 12.6# L-80 IBT-Mod 841' 9191' 8672' 10032' 8720' Uncemented Slotted Liner
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured 9775 feet Plugs (measured)
true vertical 9298 feet
Effective depth: measured 9732 feet Junk (measured)
true vertical 9262 feet
Casing Length Size Cemented M D TVD
Structural
Conductor 110' 20" 8 cu yds 147' 147'
Surface 2652' 13-3/8" 3817 cu ft 2689' 2689'
Intermediate 9012' 9-5/8" 1865 cuft 9049' 8685'
Production
Liner 978' 7" 342 cu ft 469' - 9298'
JUL 28 1997
Perforation depth: measured 9108' - 9148', 9450' - 9460', 9517' - 9524'
Sqzd: 9440' - 9450', 9460' - 9470', 9498' - 9508'
.0it
Gas
Cons.
C0r~rA~is~
true vertical subsea 8736- 8959' - 9021' (three intervals) ~,nchor~ge
20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program
[] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements
Contact Engineer Name/Number: Growl West, 564-4803 Prepared By Name/Number: Torrid Hubble, 564-4628
21.1 hereby certify that t/be'"~o/egoin,,~s/u¢/,~d correct to the best of my knowledge
Signed I /., _2' // I//
Dan Stoltz ~/~./~/¢~~'~-/ Title Senior Drilling Engineer Date
;,:.,. .... ~.- -r-~,~ Commission Use Only
Permit Number ~7-'/~// IAP' Number IApproval Date Isee cover letter
50-029-21781-01. -~ ,..~_./----~--'/ for other requirements
Conditions of Approval: Samples Required ~,Yes _~.N.o Mud Log Required .~__Yes
Hydrogen Sulfide Measures ,,J~Yes [] No Directional Survey Required ,J~Yes'l~No
Required Working Pressure fdr BOPE 1-12M; r-13M; []5M; I-I 10M; I--I
Other: drlg~nal Sign~
David W. Johnston by order of
Approved By Commissioner the commission Date
Form 10-401 Rev. 12-01-85 Submit In Triplicate
I we, Name: IE.26A I
Sidetrack Plan Summary
Type of Redrill (producer or injector): I Shut in Producer
Surface Location: 1520' FNL, 501' FEL, T11 N, R14E, S6
X = 664479, Y - 5975544
Target Location: 1929' FNL, 5094' FEL, T11N, R14E, S5
X = 665175, Y = 5975150
Bottom Hole Location: 2216' FNL, 407' FEL, T11N, R14E, S6
X = 664590, Y - 5974850
I AFE Number: I 4P0977 I
Estimated Start Date: I 8/19/97
IMD: I10032' I
I Well Design (conventional, slimhole, etc.):
Rig: I Doyon 9
I TVD:
Operating days to complete: I 17
18720' ss I [RKB ~67.97'
I Conventional ultra-slimhole horizontal sidetrack
Objective: I Access expected Sag reserves of 826 MSTB.
Mud Program
ISpecial design considerations
Whipstock drilling with 6% KCL Gel Free Sidetrack Fluid. Pump two I
hi-vis sweeps after milling.
Initial whipstock/Sidetrack Mud
Properties:
9-5/8" whipstock kickoff with Gel-Free Fluid
Density Funnel LSR HTHP pH
(PPG) Viscosity YP
10.0 45-60 >6 <10 cc 8.5-9.0
10.5-11.0 55-65 >10 <10 cc 8.5-9.0
The sidetrack fluid for this interval must be built with 2 ppb baranex and 5 ppb baratrol due to the Kingak
shales to be drilled.
Production Mud Properties:I Solids Free Quikdriln
Density Viscosity LSR LSRV Filtrate pH
(PPG) YP
8.7-8.9 55-65 14-20 35000-55000 NC 8.5-9.0
Keep Sand content at less than 0.25% in the production interval
Directional
KOP: +8,000' MD (estimated)
Maximum Hole Angle: +92°
Close Approach Well: None
Formation Markers
Formation Tops MD TVD (SS)
8,000' 7,700' Window kick off point
Top LCU 8,062' 7768'
Top Kingak 8,062' 7,768'
TJH 8,062' 7,768'
TJG 8,062' 7,768'
TJF 8,100' 7,806'
THE 8,293' 7,939'
TJ D 8,562' 8,175'
TJC 8,729' 8,336'
TJ B 8,872' 8,467'
~JA 8,972' 8,547'
TSAG 9,167' 8,662'
9,341' 8,710' Target Polygon Begins, 7" casing
TD 10,032 8,720' Target Polygon Ends
Casinc./Tubin_c_ Proc. ram
Hole Size Csg Wt/Ft Grade Conn Length Top Btm
MD/TVDss MD/TVDss
Existing 9-5/8" 47# L-80 BTRS 9,012' surface 9,049'/8685'
8-1/2" 7" 26# L-80 IBT-MOD 1,491' 7,850'/7,433' 9,341 '/8,710'
6" 4.5" 12.6# L-80 IBT-MO D 841' 9,191 '/8,672' 10,032'/8,720'
Tubing 4.5" 12.6# L-80 IBT-MO D 9,191' surface 9,191 '/8,672'
Cement
Lead Cement Tail Cement
Casing/Liner Sx / Wt / Yield Sx / Wt I Yield Comments
P&A 97/15.8/1.15 P&A'd with 20 bbls bullhead in pre-rig,
pressure test to 2500 psi good, TOC
@8720' (tagged 6/29/97)
7" 180/15.8/1.15 Class G: 50% excess in OH; TOC at 1000'
above Sag, Pump Time 4+ hrs
4-1/2" None None Slotted Liner
Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as listed.
Logging Program
..Logs: None Planned
8-1/2" Hole MWD directional / GR
6" Hole MWD directional / GR / 4 Phase Resistivity ~"~.~
Cased Hole: None Planned
Well Control
Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be
installed and will be capable of handling maximum potential surface pressures.
Diverter, BOPE and mud fluid system schematics on file with AOGCC.
Hazards
Sag River pressures could be as high as _+3,450 psi at 8,662' TVDss or _+7.7 ppg EMW.
The target polygon is bounded to the north and south by east/west faulting (25-150 ft of throw). The sag is
downthrown and juxtaposed against the Ivishak 1000' to the east and 2000' to the west.
E Pad is not a designated H2S pad; the last sample taken was 16ppm (12/95)
E-26A Short Well Summary
Pre-Rig Work:
Pre-Rig Operations: Note: original KBE was 67.72', BF elevation was 31.12'
NOTE: Pre-Rig Operations have been completed. Summary as follows.
.
,
,
.
,
.
,
,
9.
10.
SI well and bullhead 20 bbls SW. Mix and bullhead 20 bbls cement at 2.5 bpm. Displaced
with 160.5 bbls of seawater at 5 bpm. Pressure test cement plug w diesel to 2500 psi for 30
minutes. Test good. Tag cement top at @8720' WLMD. Pulled DV from STA#1.
Circulate well through STA#1 with 612 bbls seawater and freeze protect with 135 bbls of
diesel. Freeze protected flow line with 20 bbls of methanol. Final pressures SIWHP-0 psig,
lAP=0 psig, OAP=0psig (6/30/97)
Make a 3-7/16" GOEX supper cutter jet cut on the 4-1/2" 12.6# L80 tubing at 8150'mdBKB in
the first joint below the #1 GLM. (KOP is planned at 8000'MD).
Secured Well with BPV and prepared for rig arrival. IAP=0psig, OAP--0psig (7/7/97)
Rig Work Summary:
MIRU. Pull BPV.
Circulate the well to remove freeze protection and any trapped gas. Set and test TWC to
1000 psi. ND tree, NU and test BOPE. Circulate Seawater.
Pull and LD 5-1/2" x 4-1/2" L80 tubing to pre-rig cut depth (,-,8150' MD).
Run and set a 9-5/8" EZSV on Baker 20 setting tool (w/CCL) at 8030'MD. Replace the 9-5/8"
packoff. Once the EZSV is set perform a casing integrity test to 3500 psi for 30 minutes.
PU Baker anchor/whipstock assembly with MWD for 9-5/8" casing. RIH and set whipstock on
top of EZSV at 35 degrees left of high side.
Mill out of 9-5/8" casing string plus 29' of new formation. Trip for 8-1/2"" steerable BHA and
drill ahead with GR and MWD directional as per directional plan to 9341'MD. Run and
cement 7" 26# L80 liner. Drill 6" hole with MWD GR and 4 phase resistivity as per directional
plan to TD at ,-,10032'MD.
Run 4-1/2" slotted L-80 liner to TD with 150' lap into the 7" casing. Test liner top packer and
liner to 3500 psi for 30 minutes.
Run 4-1/2" 12.6#, L-80 tubing and completion with 2-GLM's.
ND stack, NU tree and test. Set BPV.
Secure well, release rig.
15:19 9075637252 b~b.l<~Y-bUh rH~L uu
hared Services Drillingi
eld: Prudhoe Bay Location: Alaska
7600
7700
7800
7go0
8000
8100
8200
· -- 8300
I
-~_.
~ 8400
Z~ 85oo
I 8600
II
88OO
8900 '
9000
9100
--400 -300 -200
~S
Kick off Point
E~d of Bm'id
~nd of i-to~.
I--.,,~--- WELL PROFILE DATA
~ ~ 107.91 7~8 -~lz ~ o,oo
[~1~ ~17 ~ ~7~ ~ -415 S13
r~ g7gO i~ 2~ 6~ ~610 Z~ IZ,~
g 5/8" Packer
-100 0 100 200 300 400 500 600 700 800 900 10
S C 0 J e 1 ' 1 0.0. O0 vertical Sectk~n on Zo 1.Z2 oZimull~ .Hh reterena,. 0.00 N, o.oo £ frorri;-~$A
997 lb: iU 9875637252
SPERRY-SUN PAGE
88
N
IShared Services Drilling
Sfrucfure: PB £ Pod
I Field; Prudhoa Boy
I
Well · E-Z6A
Location · Alaska
--1
A
Scale 1" 100.00 .
Eas. f
->
0 100 200 ,300 400 500 600 700 800 900
e26a~
o 100- 200
E-28~id
Scale 1 ' 100.00
...
-500' 6O0
.
East
..
300 400
700
.
. ..
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-800 . 900
1000
1 000
1100
1 2OO
0
--100
--
--200
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.-.~
6oo :5--'
-800 -.
·
1-900. o
1100 1200
16:19
ghared services Drxllxn~ pROPO~Ab LISTING pa~e 1
Depth
8000,00 32.6o
9021,36
810o.OO 42.21
8176-69
9200,00 50-$~
8~1-85 50,57
8300.00 41.59
~400,00 ~0.3~
8500,00 19.99
8600.00 12.64
~00.00 14,27
6800-00~ 2~.06
8900,00
9000.00
Inclin. Azx~=h True VmS.
Degrees De~jreea Depth
R E C T A N G U ~. A R D091~3
C 0 O R D I N A T E S Deg/100FC
~07,94 7796.16 181,90 S 779.32 E O.0O
105.00 7814.02 ~85.22 $ 790.S6 E 10.00
97.4~ vevs.ee- 194.35 $ $3e.1~ ~ 12.00
92.09 7928.74 198.76 S 893.~8 ~ 12.00
92.09 T~A~-5~ 199.42 S 911.37 ~ 0.00
~2.09
103L23
~17,~$
152.80
105.?$
232.23
243,63
~49.90
254.07
297,24
261.00
270.06
8011.S9
6092.42
9279.00
8376,6o
8471.41~
8559.29
8699.33
9745,39
8783.2o
e?e4.e~
· G798,42 -
9792.23
200.0~ S 926-24 E 0.O0
203,79 S 964-32 E 12.00
213.00 8 1042,17 E 12.00
226..~ S. 1082.07 E 12,00
244.50 $ 1102.28 E 12.00
265.41S 1101.9~ E 12,00
298,59 $ 1051.02 E 12,00
313.03 S 1040.47 E 12.00
361.40 S 909.~1 E 12.00
393.21S 822,49
402.~5 g 738.31
414.57 $ 629;79
270,06 414.911S ' 574,61
264.79 416.8~ 9 530.27
253.00 9~97.89 43&.01 S 432.49
241,25 . 9~99.35 4~4.91 s 340.52
231.45
225,42
.219,%0
217,45-.
9796,77
879'3.10
0789.24
8787.97
ss~os s ase:as.g
671.07 g 115,9S E
696~29 S 95~94 E
-.
~9200.00
9300.00 ~O.Oe
9341,90 85.00
94QO,OO 84.67
941~,16 84.59
9455.43
9500,00 85.59
'9~00.00 87.95
9700-00 90.39
976~,96 92,00
9~00.00.' 92,04
9900~00 92,16
10000,00 '92-25
10032~2~ 92,29
Seco
-113.49
-122.18
-139.07
-14~.97
-149-~1
o166-~0
-178.66
-180.26
-171.05
-151.&~
-122.25
-8~,79
9.13
12.00 59.53
12,00
12,00
12.00 164.97
0,00 17e.70.
12.00 196,62
12.00 249.9~
1~,00 319.36
1~.00 ~72.56
.6,0H'"
6,02 490,49
6.D2 .593,60
6.o~ 614.36
-, , '
.
[.
CoorchnaCee are fr~n:26A and'-TVDe ace fr~wellhead,
Venial eecCX~ tG f~N'O,O0'~ O.o0 ~ =c~CA 201,22
Cal~laci~uaee the~~~Gb~ge~ch~.
WELL PERMIT CHECKLIST COMPANY ~:)P WELL NAME /'~/~_./' ,~-2(~/~ PROGRAM: ~ I'~ [] wellbore r_~j ann.
· . exp [] dev redrll serv seg disposal para req [~.:1
FIELD & POOL ~:> ~/~:) ] 5' ~ INIT CLASS Z~.Z../ /"~--P, 7 GEOL AREA oc~?c--~ UNIT# ///o~' ,,d'~:::) ON/OFF SHORE ~ ~..)
ADMINISTRATION
1. Permit fee attached .......................
2. Lease number appropriate ...................
3. Unique well name and number ..................
4. Well located in a defined pool ...................
5. Well located proper distance from drilling unit boundary ....
6. Well located proper distance from other wells ..........
7. Sufficient acreage available in drilling unit ............
8. If deviated, is wellbore plat included ...............
9. Operator only affected party ...................
10. Operator has appropriate bond in force .............
11. Permit can be issued without conservation order ........
12. Permit can be issued without administrative approval ......
13. Can permit be approved before 15-day wait ...........
ENGINEERING
REMARKS
14. Conductor string provided ................... Y N
15. Surface casing protects all known USDWs ........... Y N /'/,..)
16. CMT vol adequate to circulate on conductor & surf csg ..... Y N
17. CMT vol adequate to tie-in long string to surf csg ........ Y N
18. CMT will cover all known productive horizons ..........
19. Casing designs adequate for C, T, B & permafrost .......
20. Adequate tankage or reserve pit .................
21. If a re-drill, has a 10-403 for abandonment been approved ..... ~ ~,t~~
22. Adequate wellbore separation proposed .............
23. If diverter required, does it meet regulations ..........
( ~U
24. Drilling fluid program schematic&equip list adequate ..... -.~~/M,~~_~N
25. BOPEs, do they meet regulatiOnte, st.t(~ ' ' '~' ' (~i-~.N. ~.
26. BOPE press rating appropriate;
27. Choke manifold complies w/APl RP-53 (May 84) .......... L-
28. Work will occur without operation shutdown ...........
29. Is presence of H2S gas probable .................
GEOLOGY
APPR DATE
30. Permit can be issued w/o hydrogen sulfide measures ..... ~N ' YY N/'/~"'/'-////
31. Data presented on potential overpressure zones ....... ~
32. Seismic analysis of shallow gas zones .............
33. Seabed condition survey (if off-shore) ............. //Y N
34. Contact name/phone for weeklypro_aress reports ...... / Y N
[exploratory only] ~'
GEOLOGY:
ENGINEERING: COMMISSION:
Comments/Instructions:
HOW/Ijt - A:\FORMS\cheklist rev 07/97
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
· No special effort has been made to chronologically
organize this category of information.
Sperry-Sun Drilling Services
LIS Scan Utility
Thu Oct 16 13:32:21 1997
Reel Header
Service name ............. LISTPE
Date ..................... 97/10/16
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Previous Reel Name ....... UNKNOWN
Comments ................. STS LIS Writing Library.
Technical Services
Tape Header
Service narae ............. LISTPE
Date ..................... 97/10/16
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Previous Tape Name ....... UNKNOWN
Comments ................. STS LIS Writing Library.
Technical Services
Scientific
Scientific
Physical EOF
Comment Record
TAPE HEADER
PRUDHOE BAY UNIT
~qD/MAD LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
MWD RUN 2
AK-MW-70260
J. FOLEY
MIKE WHITELE
ELEVATION (FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
M C OF LM D
E-26A
500292178101
BP EXPLORATION (ALASKA), INC.
SPERRY-SUN DRILLING SERVICES
16-0CT-97
MWD RUN 3
AK-MW-70260
J. FOLEY
MIKE WHITELE
6
liN
14E
1520
501
67.70
.00
.00
RECE vb
OCT 22 1997'
Oil & Gas Oo..s. C~m~
WELL CASING RECORD
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
REMARKS:
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
8.500 7.000 9197.0
6.000 10065.0
1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE
NOTED.
2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED.
3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED.
4. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH SCINTILLATION
TYPE GAMMA RAY (NGP) .
5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS
PER THE PHONE
CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING
SERVICES AND
TAVE PERUZZI OF BP EXPLORATION (ALASKA), INC. ON 06
OCTOBER, 1997.
6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10065'MD,
8798'TVD.
SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRD = SMOOTHED GAMMA RAY.
$
File Header
Service name ............. STSLIB,001
Service Sub Level Na~ae,..
Version Number ........... 1,0.0
Date of Generation ....... 97/10/16
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.000
Comment Record
FILE HEADER
FILE NUMBER: 1
EDITED MERGED MWD '
Depth shifted and clipped curves; all bit runs merged.
DEPTH INCREMENT: .5000
FILE SUMMARY
PBU TOOL CODE START DEPTH STOP DEPTH
GR 7966.5 10004.0
ROP 8028.0 10066.5
$
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
BASELINE DEPTH
$
MERGED DATA SOURCE
PBU TOOL CODE
MWD
MWD
$
EQUIVALENT UNSHIFTED DEPTH
BIT RUN NO MERGE TOP MERGE BASE
2 8028.0 9201.0
3 9201.0 10066.0
REMARKS: MERGED MAIN PASS.
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .lin
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD AAPI 4 1 68 4 2
ROP MWD FT/H 4 1 68 8 3
First
Name Min Max Mean Nsam Reading
DEPT 7966.5 10066.5 9016.5 4201 7966.5
GR 45.5583 452.547 96.6715 4076 7966.5
ROP 7.7706 2681.87 69.8198 4078 8028
Last
Reading
10066.5
10004
10066.5
First Reading For Entire File .......... 7966.5
Last Reading For Entire File ........... 10066.5
File Trailer
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/16
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.002
Physical EOF
File Header
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/16
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.001
Comment Record
FILE HEADER
FILE NUMBER: 2
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 2
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
GR 7966.5
ROP 8028.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
STOP DEPTH
9140.5
9200.5
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
NGP NATURAL GAM1FLA PROBE
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT) :
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3) :
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
REMARKS:
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
ll-SEP-97
ISC 5.06
NGP 5.74/DEPII 2.042
MEMORY
9201.0
8025.0
9201.0
17.1
60.3
TOOL NUMBER
NGP SPC 176
8.500
8.5
6%KCL POLYMER
10.40
47.0
8.7
29500
· 4.8
.000
.000
.000
.000
65.6
.6
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .lin
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 2 AAPI 4 1 68 4 2
ROP MWD 2 FT/H 4 1 68 8 3
First
Name Min Max Mean Nsam Reading
DEPT 7966.5 9200.5 8583.5 2469 7966.5
GR 45.5583 171.814 92.2217 2349 7966.5
ROP 8.9956 778.339 52.0448 2346 8028
Last
Reading
9200.5
9140.5
9200.5
First Reading For Entire File .......... 7966.5
Last Reading For Entire File ........... 9200.5
File Trailer
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/16
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.003
Physical EOF
File Header
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/16
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER: 3
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 3
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
GR 9135.0
R0P 9200.0
STOP DEPTH
10004.0
10066.5
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DO~[NHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM) :
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
NGP NATURAL GAMMA PROBE
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM) :
FLUID LOSS (C3) :
RESISTIVITY (OHNiM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
REMARKS:
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .lin
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
15-SEP-97
ISC 5.06
NGP 5.74/DEPII 2.042
MEMORY
10065.0
9201.0
10065.0
65.5
93.9
TOOL NUMBER
NGP SPC 317
6.000
6.0
QUIKDRIL-N
8.70
47.0
8.0
30000
10.6
.000
.000
.000
.000
49.5
.6
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 3 AAPI 4 1 68 4 2
ROP MWD 3 FT/H 4 1 68 8 3
First
Name Min Max Mean Nsam Reading
DEPT 9135 10066.5 9600.75 1864 9135
GR 59.6817 452.547 102.563 1739 9135
ROP 7.7706 2681.87 93.9228 1734 9200
Last
Reading
10066.5
10004
10066.5
First Reading For Entire File .......... 9135
Last Reading For Entire File ........... 10066.5
File Trailer
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/16
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.004
Physical EOF
Tape Trailer
Service name ............. LISTPE
Date ..................... 97/10/16
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Next Tape Name ........... UAIKNOWN ~
Comments ................. STS LIS Writing Library.
Technical Services
Reel Trailer
Service name ............. LISTPE
Date ..................... 97/10/16
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Next Reel Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Technical Services
Scientific
Scientific
Physical EOF
Physical EOF
