Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
201-030
Imag~' 'roject Well History' File Cover ~', ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. (~ ~ ~_- .{~DWell History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~ WINDY Scanning Preparation ] x 30 = ~ {~ BY: BEVERLY ROBIN VINCENT SHERYL,~~INDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~" YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES (SCANNING IS coMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO ReScanned (indhddua! page ~,~.pecial att~,nf¢~n] .sc~nning i:on~ple~ed) RESCANNEDB?': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /SI Quality Checked 12/10/02Rev3NOTScanned.wpd e e C~ "'-; '" " ~ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Memorandum State of Alaska Oil and Gas Conservation Commission To~ Re~ Well File 201-030 Expired Permit Action WELL: Trailblazer G-01XX Permit Issued: 3/15/2001 DATE March 15, 2003 API# 50-103-20366-00 This memo will remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to drill. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting redrills and or multilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to drill. The well number for a cancelled or expired permit is modified with an appended XX. EXPIRED PERMITS ARE RELEASABLE 2 years from the approval date on the application approved by the commission, unless the operator ask for extended confidentiality. AOGCC database has been changed to reflect these changes to this permit. Steve McMains Statistical Technician ALASKA OIL A~D GAS CO~SI~R¥&TIO~/COMMISSION Tim Bums Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Trailblazer Pad G No. 1 BP Exploration (Alaska) Inc. Permit No: 201-030 Sur. Loc. 184'NSL, 2,793'WEL, Sec. 06, TllN, R2W, UM Btmhole Loc. 184'NSL, 2,793'WEL, Sec. 06, T1 IN, R2W, UM Dear Mr. Burns: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. The Commission grants BP exemption from the H2S requirements found in 20 AAC 25.065(c) for the Trailblazer G-1 well upon the condition that: 1. H2S monitoring complies with 20 AAC 25.066, 2. H2S gas levels are monitored continuously and recorded hourly during drilling easing operations, and 3. 'recorded levels of H2S gas are submitted to the Commission in report form within 30 days after completion, suspension, or abandonment of the well. Because of the possibility of encountering gas in the shallow portion of the Trailblazer G- 1 wellbore, the Commission requires mudlogging services, including standard gas monitoring equipment, be operational at all times from surface to the total depth of the well. Gas measurements must be monitored and recorded continuOusly, and these measurements will be submitted to the Commission in report form within 30 days after completion, suspension, or abandonment of the well. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught (when drill rate permits) and 10' sample intervals through target zones and/or any hydrocarbon shows. Mr. Tim Bums ~! 2 Trailblazer Pad G No. 1 Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. The AOGCC would like to thank the BP NPRA Exploration team for the high quality information package filed as a supplement to the Trailblazer Pad A Well 1 permit to drill application. The supplemental information was comprehensive and contained a level of detail that facilitated commission review and evaluation. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this fi9''-~( day of March, 2001 dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. cc: Mr. Mike Miller, Drilling Superintendent BP Exploration (Alaska) Inc. Alaska Drilling & Wells Group Subject: Re: Hole Size Change Date: Tue, 27 Feb 2001 11:26:15-0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Johnson, Frederick C" <JohnsoFC~BP.com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Tim and Fred, Thanks for the information. This change is considered minor and capturing it in the completion report is appropriate. I imagine there will be some minor changes in cement volumes, but again the change should be small. I understand that the rig is presently moving toward the A location and you might be ready for a diverter inspection around March 5. Please have the company man stay in touch with the slope inspector to coordinate the diverter inspection. We do have it as a goal to witness/inspect as many exploration activities as we are able. If you have any questions, please call. Tom Maunder "Johnson, Frederick C" wrote: >> .... Original Message ..... From: Bums, Tim A Sent: Monday, February 26, 2001 5:07 PM To: Tom Maunder (E-mail) Cc: Johnson, Frederick C; PBU, Drlg Rig 22E; Hughes, Katherine M; Hubble, Terrfe L Subject: Hole Size Change Following up on our exchange of phone messages, this e-mail note will serve as BP's official notice of intent to change the production hole sizes on the Trailblazer A No. 1, H No. 1 and G No. I wells from 8-1/2"to 8.3/4". BP will also ensure the actual production hole size is captured on the final completion reports. If you have any questions, please give me (or Fred) a call at your earliest convenience. Thanks again, Tim A. Bums Alaska Drilling & Wells Office: (907') 564-5268 Fax: (907') 564-4516 Cell: (907') 240-8091 bumsta@bp.com 1 of 2 2/27101 11:37 AM o., CONFIDENtiaL ALASK..'~ .L AND GAS CONSERVATION COM__. ~ION ' PERMIT TO DRILL <~I ¢'/'~ "/':F~/'<~__ 20 ~C 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [][] Re-EntryDrill [][] RedfillDeepen lb. Type of well [] Sen/ice [] Development Gas [] Single Zone [] Multiple Zone , 2. Name of Operator 5. Datum Elevation (DF or KB) I10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 147' Undefined ,3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 AA081748 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O AAC 25.025) 184' NSL, 2,793' WEL, Sec. 6, T11N, R2W, UM Exploration At top of productive interval 8. Well Number 184' NSL, 2,793' WEL, Sec. 6, T11N, R2W, UM Trailblazer Pad G No. 1 Number 2S100302630-277 At total depth 9. Approximate spud date 184' NSL, 2,793' WEL, Sec. 6, T11N, R2W, UM March 25, 2001 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) AA081749 2,111 feetI No Close Approach 5,623 7,547' MD / 7,547' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} o Kick Off Depth N/A Maximum Hole Angle N/A Maximum surface 3,143 psig, At total depth (TVD) 7,547' / 3,492 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' Surface Surface 80' 80' 260 sx Arctic Set (Approx.) , 12-1/4" 9-5/8" 40# L-80 BTC 2,496' Surface Surface 2,496' 2,496' 590 sx PF, 300 sx Class G 8-1/2" 7" 26# L-80 IBT-Mod 7,547' Surface Surface 7,547,' 7,547' 280 sx Class G 19. To be cornplet'ed for Redriil', Re-entry, and Deepen Operations.' .......................... Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production LinerRECEIVED DEC B 2 7_000 Perforation depth: measured true vertical Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments .... []"Filing Fee ............. I~ll' F'~6pe~ Plat [] BoP 'sketch ' ' [] Dive~te~ Sketch ~'Drilling Program ' [] Drilling Fluid Program [] Time v$ Depth Pict [] Flefraotion Analysis [] Seabed Flepo~ [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Tim Burns]/564-526~ / ) Fred Oohn~on: 564-5427" Prepared By Name/Number: Terrie Hubble, 564-4628 21.1 hereby certify that' the 'fore/8,~J~is'''' "'~'/t~ue~'h~rect io 'the 'besi of my knowledge .............. Signed Tim A. Burns L.~'f~ ~ ,/r~,'i,-- Title Senior Drilling Engineer Date j · "': ' '.".:: ::: '.'~:' ::'..' '"':' ' "..,"::"' ':' "::,.:':"."..:"' :':. :' :'": i'i'?, :':..,..:!,::.::::!.:'i..:::':::..L'.:.:'~;.¢o~tnlision'.:,,us~,'.'oni¥.':...,',.','i .... , .., . . . , . ....... ..... :.:.:;,.:.::. :i.::..,. :.. ,....:".'.: .;....;.,:.,, !.......,:.... ~..:.:..,.:. :.... :.:,:..!.. :::.:;..,::......: :..:. ,...: ..:,:, .,, ..., .. Permit Number lAP, Number I Approval Date I See cover'etter '~.z.T..)./--" (._~.~r.~ 50- ~/(:~ .~--" :2_.~..~.'~::::~- (..~:~ .... ~__.~.--,/,,_~'-'- ~:~// forother requirements Conditions of Approval: Samples Required .l~'es [] No Mud Log Required I~Yes [] No Hydrogen Sulfide Measures I~"tYes [] No Directional Survey Required [] Yes .l~! No Required Working Pressure for BOPE [] 2K [] 3K [] 4K ~5K [] 10K [] 15K [] 3.5K psi for CTU Other: ORIGINAL :S!GNEE), 8Y by order of rc~;~,~.<..~' ..,Approved By L') T~ylor Seamount Commissioner the commission Date ~'~/,...~'-~ , , , , , , Submit In Triplicate BP CONFIDENTIAL CONFIDENTIAL Trailblazer Pad G #1 Well Plan Summary I MD= I 7,547' I I TVDss: I 7,400' I I KB Elev (est): I 147' I Type of Well: I Exploration Formation Markers Measured TVD Formation Tops Depth, ft TVDss (RKB) Comments Colville Surface Base Permafrost 847 700 847 Nanushuk 1,763 1,616 1,763 *Illuminator* 3,143 2,996 3,143 Possible at G Pad Torok Formation 3,225 3,078 3,225 HRZ 6,640 6,493 6,640 Kuparuk C 6,845 6,698 6,845 potential oil/gas LCU 6,912 6,765 6,912 Alpine 7,183 7,036 7,183 potential oil/gas Berg 7,233 7,086 7,233 potential oil/gas Nuiqsut 7,492 7,345 7,492 TD 7,547 7,400 7,547 Maximum anticipated depth Casin.q/Tubing Program: (all depths in feet, RKB) Hole Size Csg/Tbg Wt/R Grade Conn. Length Top Btm OD MD/TVD MD/TVD 30" 20" 94# H-40 WLD 80 'GL 200/200 12 1/4" 9 5/8" 40# L-80 BTC 2,496 GL 2,496/2,496 8 1/2" 7" 26# L-80 BTC-M 7,547 GL 7,547/7,547 Tubing 3 1/2" 9.3# L-80 EUE-Mod 6,400 GL TBD Casing Desiqn Design Factors Design Factors 9-5/8", 40#, BTC BP Minimum Actual 7", 26#, BTC-Mod BP Minimum Actual Burst 1.1 1.92 Burst 1.1 1.6 Collapse 1.0 6.18 Collapse 1.0 1.36 Axial 1.4 3.81 Axial 1.4 2.27 Triaxial 1.25 2.26 Triaxial 1.25 1.97 RECEIVED DEC g 2 2000 Alaska Oil & Gas Cons. Commission Anchorage 12/15/OO Trailblazer Pad G #1 BP CONFIDENTIAL Lo.qRin.q/Formation Evaluation Proqram Production MWD/GR; PWD; Resistivity/Density-Neutron Wireline (contin.qent upon well results): Run #1' Dipole Sonic, FMI, GR Run #2: CMR, MDT, Spectral GR Contingent Logs: Spectral GR, Array Induction w/SP*, Litho-density* (*contingent upon quality of LWD logs) Checkshot or VSP (contingent upon well results and available time) Coring: Percussion or Rotary Side Wall Cores (contingent on timing) Cased Hole Logs: Sonic, GR, (production open hole logs pulled through surface casing) Mud Logs: Collect wet/dry samples at 60' intervals from surface to TD; below surface casing, collect samples @ 10' intervals if in sand intervals and/or in any hydrocarbon shows. Mud Proqram Surface Hole (12 ~A"): Drill the surface hole with a 6% KCI/PHPA/Clayseal mud spud mud weighted at 9.5-10.0 ppg. The mud weight will then be maintained in this range unless hole conditions (gas hydrates or shallow gas) dictate otherwise. The primary focus for surface hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity for efficient hole cleaning. Density Viscosity Interval (ppg) (seconds) YP PV Gel-10 sec APl FL Initial 8.5-9.5 100 - 150 45 - 55 12 - 20 12 - 25 <15 Final 9.5-10.5 65 - 85 20 - 40 20 - 25 15 - 55 <10 Production Hole (8-1/2") After drilling out of surface casing, the mud system will be displaced with a 6% KCI/GEM mud. This system will be maintained to TD. Mud weights will be maintained in the 9.5-10.5 ppg range in anticipation of wellbore stability problems (swelling shales). Density Fluid Mud Interval (ppg) yp PV 10 S. Gel Loss PH Chlorides Initial 9.5-10.0 15-25 10-20 5-10 <10 (APl) 9-9.5 25-30K HRZ 9.5-10.5 15-25 10-20 5-10 <10 (150° 8.5-9.0 25-30K HPHT) TD 9.5-10.5 15-25 10-15 5-10 <10 (150° 8.5-9.0 25-30K HPHT) RECEIVED DEC B ?.000 Alaska Oil & Gas Cons. Commission 2 Anchorage 12/15/00 Trailblazer Pad G #1 BP CONFIDENTIAL Mud Disposal Mud and cuttings will be disposed offsite. Cuttings will be temporarily stored in a temporary ice pad lay down area (on location) until such time they are frozen and can be safely and economically hauled-off. Waste Primary Disposal Site Alternate Disposal Site PBU Pad 3 N/A Class 1 Liquids Class 1 Solids Class 2 Liquids Class 2 Solids PBU Pad 3 KRU 1R Facility PBU G&I Facility N/A PBU G&I Facility N/A Casing/Cementing ProRram The cellar ring and conductor casing will be pre-installed prior to rig arrival. The conductor will be cemented to surface. Surface casing will equipped with a minimum of three (3) centralizers--one per joint starting on the shoe joint. The surface casing will be cemented to surface using a lead and tail slurry and cementing stage tool, if necessary. The total cement volume proposed is based on annular volume plus 30% from the casing shoe to the base of the permafrost and annular volume plus 250% from the base of the permafrost to surface. The tail slurry is designed to cover 750' vertical feet above the surface casing shoe. Production casing will be cemented with sufficient volume to fill from the casing shoe to a minimum of 500' above any hydrocarbon bearing formations. Centralization shall be sufficient to ensure competent annular isolation. If any shallow hydrocarbons are detected in the wellbore, the top of cement (TOC) in the production casing annulus will be adjusted accordingly (minimum of 500 vertical feet above any hydrocarbon shows). A stage cementing tool may be utilized if the required top of cement is higher than anticipated. Casing Hole Category Size/Depth Volume Type of Cement Properties Conductor 20" @ 270 ft 3 Type 3, -- Casing 80' GL (25% excess) High Early Yield Lead Lead Lead 1,262 ft 3 Permafrost Cement Den 12.0 ppg 590 sx Yield 2.17 ft 3/sx Surface 9 5/8" @ (250% excess Water 11.6 gps Casing 2,496' above base PF) Tail Tail Tail 339 ft 3 Class "G" w/ 300 sx 0.2 % Dispersant Den 15.8 ppg Yield 1.15 ft 3/sx (30% excess) 0.2 % Fluid Loss Water 5.0 gps 320 ft 3 Class "G" w/ Production 7" @ 280 sx 0.2 % Dispersant Den 15.8 ppg Casing 7,547' (35% excess) 0.2 % Fluid Loss Yield 1.15 ft 3/sx TOC = -6,000' 0.1% Retarder Water 5.0 gps RECEIVED DEC 2, 2 ZOO0 3 12/15/OO Alaska 0ii & Gas Cons. Commission Anchorage Trailblazer Pad G #1 BP CONFIDENTIAL Drilling Hazards/Risks Hydrogen Sulfide i'H_~S) Five offset wells were reviewed for potential exposure to H2S (see table below). Of the five wells, only the Inigok Test Well No. 1 (28 miles from Trailblazer Pad G) encountered any H2S. While drilling below 9-5/8" intermediate casing (set into the Shublik), significant quantities of H2S were encountered at a depth of 17,570' MD in the lower Lisburne (just above the Endicott Formation). The penetrated interval contained significant quantities of very heavy hydrogen sulfide, (H2S9). While circulating and conditioning the mud after weight up, drillpipe became stuck approximately 4,230' off bottom (with BHA -824' into open hole). Drilling operations over the next 78 days involved several pipe recovery attempts and numerous encounters with H2S, including solid sulfur in the cuttings samples. Ultimately, the entire BHA fish was recovered and found full of solidified sulfur. Maximum detected H2S during circulation was 300 ppm. Maximum detected H2S while laying down the BHA (packed with solid sulphur) was 600 ppm. Generic Lisburne Formation thickness varies throughout the region. Lisburne Formation thickness in the vicinity of the Trailblazer prospect is expected to mirror closely that at West Fish Creek No. 1 and East Teshekpuk (800' and 970' respectively). Lisburne Formation thickness in the Inigok Test Well No. 1 was 3,890' and the H2S interval was encountered in the lowermost interval. This lowermost Lisburne interval is not present in the Trailblazer prospect area. Even if potential vertical faults (extending into the Lisburne) are encountered, the risk of encountering H2S is believed to be extremely remote. No other H2S encounters have been documented in any offset NPR-A wells and the encounter in the Inigok Test Well No. 1 was confirmed from the lower Lisburne interval. The Trailblazer NPR-A wells will be drilled to a maximum depth of -8,800' MD. This depth is considerably more shallow than the Lisburne Formation (prognosed at -10,100' MD in vicinity of Pad A). Well Name Legal Distance Total (rig release) Location To Pad G Depth H2S Comments East Teshekpuk 17.5 miles 10,664' MD Penetrated Sag, Ivishak, No. 1 Sec. 16, T14N, R4W to the NW 10,664' TVD No Lisburne and Kekiktuk (May 1976) West Fish 10.5 miles 11,427' MD Penetrated Sag, Ivishak, Creek No. 1 Sec. 11, T11N, R1W to the ESE 11,427' TVD No Lisburne and Endicott (April 1977) North Kalikpik 16.5 miles 7,395' MD Reached TD in Kingak, above Test Well No. 1 Sec. 3, T13N, R2W to the ENE 7,395' TVD No the Sag (May 1978) Inigok Test Well 28 miles 20,102' MD See discussion above. No. 1 Sec. 34, T8N, R5W to the SSW 20,102' TVD Yes Penetrated Sag, Ivishak, (May 1979) Lisburne and Kekiktuk North Inigok 9.0 miles 10,170' MD Penetrated the Kingak, Shublik Test Well No. 1 Sec. 36, T11 N, R4W to the SSW 10,170' '/'VDNo and reached TD in the Sag. .... ................................................................................................................................................................................................................................................................................................ i H_H_~S Summary Statement 'i H2S is not anticipated in the Trailblazer NPR-A prospect area, however Standard Operating 'Procedures for H2S detection will be in place on the rigsite and H2S precautions will be observed at all times. BPXA has not included an H2S contingency plan with this Application and requests an exemption from the H2S requirements found in 2r~~~)~,~re~q;:)art (c). i CC.L.,C i v r" DEC 2 2000 4 12/15/0O Alaska Oil & Gas Cons. Commission Anchorage Trailblazer Pad G #1 BP CONFIDENTIAL Drillinq Close Approach There are no drilling or surface close approach issues. The nearest offset well (North Inigok Test Well No. 1) is 9 miles to the SSW. Abnormal Pressure The formation pressure gradient is estimated at 0.4628 psi/ft and is based on RFT data from Alpine area exploration wells--Alpine #1, Alpine #3, Berg #1, Fiord #1 and Fiord #3 and pore pressure predictions using localized seismic stacking velocity data. A comparison of sonic logs and mud weights used to drill the Alpine area wells versus mud weights required to drill nearby offset NPR-A wells indicate similar pressure profiles. Based on this pressure gradient, the maximum anticipated surface pressure is 3,143 psi at 7,547' MD - assuming a full gas column (0.1 psi/ft) to surface. Shallow Gas A seismic analysis using seismic stacking velocities is attached. Although the Illuminator Formation is not prognosed in the vicinity of G Pad, penetration of the mapped southern edge is possible 'and as such, all shallow hydrocarbon precautions established for other proposed Trailblazer wells will remain in effect for the Pad G #1 Well. Surface casing will be set ±500' above this interval to ensure this interval is penetrated with BOP equipment in place. Surface Hole Instability/Hydrates Pea gravels and/or hydrates are an unknown risk in the Trailblazer project area. There are no reports of such encounters on nearby NPR-A offset wells. Shale Instability- Stuck Pipe Shale instability has been observed in nearby offset wells both above the HRZ and again from the HRZ through the Kingak. Shale instability above the HRZ in offset wells to the east may be attributable to the Fish Creek Slide geologic feature. The Trailblazer wells are located in an area west of this mapped geologic feature. Established shale drilling Recommended Practices will be observed to minimize the risk of stuck pipe. Mud weights may be raised, mud properties adjusted and shale inhibition added to aid wellbore instability. Geoloqic Faultinq - Lost Circulation/Stuck Pipe Faulting is anticipated in the Torok Formation interval, but most faulting is expected to be shale on shale and may not be evident on logs. If sand on shale sequences do occur in this interval, lost circulation is possible. There are also potential vertical faults in the deeper Kingak intervals, but vertical separation is undetectable on seismic. Adequate surface volumes and LCM should be maintained on location at all times. If not controlled, lost circulation could lead to other problems (stuck pipe, well control, etc). RECEIVED DEC 2 2 2000 Alaska Oil & Gas Cons. Commission Anchorage 5 12/15/OO Trailblazer Pad G #1 CONFIDENTIAL Proposed Completion and Testing Pro.qram Completion The well will be completed via the drilling rig with 3-1/2" production tubing, a permanent production packer and will include three GLM's and three X nipple profiles. Final packer setting depth (to be determined from open hole logs) will be a minimum of 200' above the uppermost interval that may be production tested. See attached completion schematic. Well Testinq This exploratory well targets four prospective producing intervals. Due to time constraints, testing will most likely be limited to two target intervals. Well testing will utilize a portable test separator, flare and portable tank battery. The tank battery will be bermed to contain 110% of the tank battery volume. Total estimated well test duration is 7-10 days per interval. If the well will not flow to surface on it's own, Nitrogen (N2) will be used to "kick off" the well. The target intervals will be tested starting with the lowermost interval. Each interval will be abandoned prior to commencing additional uphole testing. Two testing options (for each interval) are currently proposed: Test Option 1 If the perforated interval is capable of producing >500 bopd, the well test will consist of the following: - a minimum 3 day well test (maximum controlled rate of 2,000 bopd); - a minimum 2 day shut-in/pressure build up; - a production test to determine the absolute open flow potential; Test Option 2 If the perforated interval is incapable of producing >500 bopd, the interval will be stimulated with a hydraulic fracture treatment designed to place a propped fracture with a half length of ~100'. Following the fracture stimulation, the well will be flowed until clean (0-2 days). The well will then be tested for an additional 24 hours to determine the absolute open flow potential. Produced Fluids Surface samples will be collected from a test separator periodically during any flow test. Any produced liquids brought to surface will be either be collected and hauled to an existing facility in Prudhoe Bay or Milne Point or the fluids will be re-injected back into the producing formation. Any produced gas brought to surface will be flared. Abandon mentJSuspension In the event the well cannot be tested during the current drilling season, it will be suspended in a manner consistent with BLM and AOGCC requirements. If the decision is made to abandon the well, it will be abandoned in a manner consistent with BLM and AOGCC requirements. RECEIVED DEC 2 2 2000 Alaska Oil & Gas Cons. Commission 6 12/15/OO Trailblazer Pad G #1 ,. CONFIDENTIAL Well Control Bottom Hole Pressure Maximum anticipated bottom hole pressure (BHP) is 3,492 psi (8.9 ppg EMW). surface pressure, assuming a full column of gas (0.1 psi/ft) is 3,143 psi. Maximum Proposed BOP test pressure is 5,000 psi. Diverter System The diverter system will consist of a 21-1/4" x 2,000 psi annular preventer and a 16" OD non- bifurcated vent line. The vent line valve will be full opening and integrated with the annular in the fail safe design. The vent line termination point will be a minimum of 75' from any fixed source of ignition. BOP System The BOP preventer stack will consist of a 13-5/8" x 5,000 psi annular preventer, a 13-5/8" x 5,000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13-5/8" x 5,000 psi drilling spool (mud cross) with 3-1/8" x 5,000 psi outlets and a 13-5/8" x 5,000 psi single gate ram type preventer with pipe rams. Choke Manifold The choke manifold will be rated 3-1/8" x 5,000 psi. It will include a remote hydraulic actuated superchoke and a hand adjustable choke. Other Equipment At a minimum, a poor-boy gas buster and a vacuum-type degasser will be included. The flow line will contain sensors to measure flowrate and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will include readouts accessible at the driller's console on the rig floor. BOP, diverter and choke manifold schematics are attached. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 7 12/15/OO Trailblazer Pad G #1 , CONFIDENTIAL Operations Summary 20" conductor is planned to be set and cemented to surface prior to rig arrival on location. See casing/cementing program for details. . , , . . , 10. 11. MIRU drilling rig Nabors 22E. NU and function test diverter. Spud well and drill vertical 12-1/4" hole to 2,496' MD. Run and cement 9-5/8" casing to surface. Pressure test surface casing to 2,500 psi. ND diverter, NU and pressure test BOPE to 250 psi Iow and 5,000 psi high. PU 8-1/2" bit, BHA and drill 20' of new hole and perform LOT. Note: LOT not to exceed 16.0 ppg EMW. Drill vertical well to a maximum total depth (TD) of 7,547' MD. Note: If lowermost geologic tops come in shallow (or not at all), TD may be called early. TD will not be extended without additional agency approvals. Run open hole logs as defined in Logging/Formation Evaluation section. If well is to be production tested, continue to step 8. If well is to abandoned, a detailed program will be prepared in accordance with BLM and AOGCC requirements. Run and cement 7" casing. TOC will be a minimum of 500' above the uppermost hydrocarbon show. Pressure test casing to 3,000 psi. Run 3-1/2" completion. Set packer and pressure test tubing to 4,000 psi. Pressure test tubing x casing annulus to 3,000 psi. Freeze protect well. ND BOP and NU tree assembly. Pressure test tree assembly to 5,000 psi. Secure well and release rig. Attachments · Proposed Completion Design · Trailblazer Pressure Profile · As staked surface location plats; · Trailblazer Lease/Property plats; · Nabors 22E BOP, Diverter and choke manifold schematics; · Trailblazer typical Pad layout; · Shallow Hazard Analysis/Pore Pressure Prediction Study; RECEIVED Alaska Oil & Gas Cons. Corem/ss/on Contacts: Office Home Pager Alaska Drilling & Wells Drilling Superintendent Mike Miller 564-5066 348-0595 240-8066 Drilling Engineer Tim Burns 564-5268 345-9515 240-8091 Drilling Engineer Fred Johnson 564-5427 696-7570 240-8059 8 12/15/OO Trailblazer Pad G #1 c3P CONFIDENTIAL Trailblazer Pad G #1 Summary of Drilling Hazards POST THIS NOTICE IN THE RIG FLOOR DOGHOUSE . . . . . . H2S is not expected. Standard Operating procedures for H2S detection will be in place on the rigsite and H2S precautions will be observed at all times. Note wind direction and Muster areas at the beginning of each tour and any time changes are observed/made. No abnormal pressures are anticipated. Although not prognosed, the Illuminator Formation may be present in the vicinity of Pad G and as such, the potential for shallow hydrocarbons should not be ignored (-2,996' MD). Surface casing will be set and BOPE installed and tested prior to this depth. After performing the LOT below the 9-5/8" casing shoe, kick detection drills shall be completed prior to penetrating the Illuminator Formation. There is a Iow to moderate risk of stuck pipe in the faulted Torok interval due to shale instability and/or potential faulting. Stuck pipe is also possible in the HRZ and Kingak Formations due to shale instabilities. Observe established Recommended Practices for shale drilling to minimize this risk. Mud weight may be increased and/or mud properties adjusted to aid in wellbore stability. Lost circulation is a Iow to moderate risk in the faulted Torok interval. Most faulting is prognosed to be shale on shale, but should sand on shale faults be encountered, lost circulation is a possibility. Maintain adequate surface volumes and LCM on location at all times. Differential sticking is a Iow to moderate risk if lost circulation occurs or if the drill string is left stationary for extended periods of time. Potential hydrocarbon bearing intervals are: Illuminator Kuparuk C Alpine Berg Humpback 3,143' MD (Not prognosed, but possible) 6,845' MD 7,183' MD 7,233' MD Not penetrated Consult the final well plan for additional information. RECEIVED DEC 2 Z000 Alaska Oil & Gas Cons. Commission Anchorage 12/15/O0 Trail Blazer Pad G #1 Proposed Completion Design K.B. = -147' · ~, 20", 94#, H-40 Conductor @ 80' MD ~ k ~-~,,, ~o#, ,-~o ~ ~,~' u[~ I X Nipples GLM's I -2,000' MD -4,000' MD -6,350' MD -5,000' MD I -6,450' MD -6,200' MD 3-1/2", 9.3#, L-80 Production Tubing ~ ~ 3-1/2" x 7" Packer @ -6,400' MD Primary Targets Kuparuk 6,698' TVDss Alpine 7,036' TVDss ~ ~, 7,26#, L-80 @ 7,547' MD Estimated TD = 7,547' MD RECEIVED DEC 2 2 ?000 Alaska Oil & Gas Cons. Commission Armhorage Trailblazer Pressure Profile Equivalent Mud Weight, ppg 8 9 10 11 12 13 14 15 16 17 18 ~ ~ ~ Formation Gradient --'-~ Mud Weight ~ ~Frac Gradient c -X ~a°i /IPermafr°'~ '~,~ Nar ishuk ~ ~ 9-5,? Csg Iluminator Formation at Pad A = 2,996' TVDss (possible at Pad G, not predicted at Pad H) Potential for shallow hydrocarbons ~ ~ Tord < Formatiol Notee: ~ Nu~4 ~ut t. Formation Pressure &Frac Gradient ~ Nec~ e~ik based on offset and Alpine area wells. 2. MW in surface hole for gas hydrates in ~ i the Nanushuk. 3. Higher MWs from HRZ to TD may be ~ Lo~ ~r Kingak required for welibore stability. ~ 7" ~g 2-NORTH 797.97' R~#~ NOR~ '4~S~'~ ~ TO ~AIL BLA~ER 'G- AD NO, 1 5,972,312,54-' AS-STAKED G-PAD NO, 600' NOTES 1. DATE OF SURVEY: AUGUST 26, 2000. 2. REFERENCE FIELD BOOKS: LEGEND WELL LOCATED WITHIN PROTRACTED SEC. 06, T. 11 N., R. 02 W., UMIAT MERIDIAN, ALASKA ASP ZONE 5 UTM ZONE 5 jNAD27 OEODETICINAD85 GEODE~C GROUND SECTION COORDINATES COORDINATES I POSITION(DMS)I POStT[ON(DMS) ELEVATION OFFSETS Y= 5,972.468.97' N= 7,802,548.78mI 79'19'46.988" I 79'19'45.655" 117,1' 184-' FSL X= 685,926.,¢6' E= 519,989.15mI 152'29'39.895"I 152'29'~2.241" 2,795' FEL NAME TRAIL BLAZER PAD-G No. 1 ~ BP E×PLORAT~ON AS-STAKED WELL CONDUCTOR of 1 ts ~,x'~'O~o~_ ,3 .~,~ ~ sPx~o~ AAd~81739 CHEVRON 30°/~~ ~ ~ -~ ~Y~ ~ A~ADARKO PHiL ~PS ~o ~ ~ ~ ..,~ ~.~ ~s ~ ~ ~ A An 1752 ~.~ 50% PHI~K ~ ~ ~ ~l qn% ANADARKO 22~ BPX 50% ~' '~"~- 2~" - o pHILLIPS ~ - TI~N ' 5 ~ **no4~o ,~ ~ AA 81748' ~1827 .... ~o/ - BPX 50% PH ~K78~ ¢~umn~l ~n% CH~VRON.~ . ANADARKO 22 Yo PHILLIPS 20% PHILLIPS 20Yo ~/ V~V PHIl AK 78% PHf~K 78~ PHI~K 78% ~ ~ .'~'*'&%2~n ¢¢~z ~aDARKO 22~ ANADARKO 2~ r~ ~ ' ~ ,¢ ~ ~o BP EXPLORATION (A~S~) INC. Distance to Lease ~081755 = 5,093 Feet TRAILB~ZER PAD G ~i8~O" to Lease ~081749 = 2,111 Feet 81 SURFACE LOCATION Pad G Well No, 1 "As Staked,, location 184' FSL, 2,793' FEL, Section 06, TI 2N, R2W, UM~ DecemberDATE:2000 1" SCALE:= 1 MILE _ FIGURE;3 WALLS SURFACE DIVERTER PIPING CONFIGURATION PLAN VIEW BOP STACK ELEVATION FAB,~-YAI_VE 16' FIG. 36 SURFACE DIVERTER CONFIGURATION Proposed . /ce RoadAcces · . BP EXPLORATION (ALASKA)INC. TRAILBLAZER TYPICAL PAD LAYOUT DATE: September 2000 SCALE: 1" = 40 Meters FIGURE: 9 ex14289typ.dgn To: From: Subject: Date: Steve Davies (A.O.G.C.C.) James G. Brewton & James Seccombe (BP Exploration Alaska) Shallow Hazard Analysis of Trailblazer Pads A, G and H for 2001 NPRA Drilling December 11, 2000 Steve, This letter documents BPXA's shallow drilling hazard analysis for the proposed winter 2001 NPR-A drilling locations, Trailblazer Pads A, G and H. It is always the intent of BPXA to conduct our operations in a safe and environmentally responsible manner. The following are major summaries of the hazard analysis: NPR-A wells in the vicinity of our proposed locations show no indication of over-pressured strata or shallow permafrost hydrate issues. The wells analyzed were the North Inigok, the East Teshekpuk and the West Fish Creek as they are on structural trend with our proposed pad locations. Mud and wireline logging information were used in the analysis. Stacking velocities from the 1998 and 1999 merged NPR-A 3D datasets show no indication of either velocity regression due to over-pressured strata or shallow hydrate (trapped gas) in the three proposed BPXA pad locations. Velocity data is analyzed primarily.for seismic imaging and is probably unreliable in the shallow, permafrost zones because the seismic data is low-fold at these depths. Drilling conditions at the proposed BPXA pad locations (Trailblazer Pads A, G and H) are expected to be similar to the existing wells within the merged NPR-A 3D seismic survey (North Inigok and West Fish Creek) because of the good tie from stacking velocity to sonic velocity for the section from the base of permafrost to proposed total depth at the pad locations (see figure 1). Analysis of seismic attributes in the shallow section indicate the presence of either gas bearing strata or hard streaks from between 2900 - 3100 feet subsea and also at approximately 4300 feet subsea, in both Trailblazer Pad A and Pad G locations. BP Exploration plans on setting surface casing down to 2400 feet at each Trailblazer Pad and then drilling ahead with blow-out preventers on. The Trailblazer Pad H location showed no indication of shallow, gas-bearing strata. Table 1 lists the estimated mud weights and pressures at the three proposed BPXA pad locations. Although a rigorous analysis has been carried out on both the well data and seismic data, the results are not definitive. BP Exploration will work on assumption that the possibility that drilling hazards exist and establish procedures that mitigate associated risks. · We will ensure that all personnel associated with our winter 2001 NPR-A drilling operations, both in Anchorage and at the rig sites, are aware of the possibility of encountering drilling hazards. Attached to this letter is a report containing detail on the shallow hazards analysis carried out at the proposed locations. Should you have any questions or further issues, please contact either Greg Brewton (907-564-4802) or Jim Seccombe (907-564-4814). Thank you, (.nes G. Brewton RECEIVED ......... "ii,i'ii'?f'' James C Seccombe Alaska Oil & Gas Cons. Commission ,.: ......... Anchorage feet 1000 2000 3000 4000 TrailblazerPad A ----- East Teshekpuk - sonic --~- N Inigok * sonic ---' W Fish Creek - sonic Pad A - seismic velocity 6000 i i i 7000 8000 ~ooo2;; TraveFTime, ps/ft feet Trailblazer Pad G 1000 2000 3000 4ooo 8ooo 6O00 -- East Teshekpuk ~ sonic N Inigok * sonic W Fish Creek - sonic ~' Pad G - seismic velocity · 7000 5O 9OOO21© Travel-Time, ps/ft 5O feet Trailblazer Pad H I 1000 2000 iii 3ooo 4000 5000 East Teshekpuk - sonic N Inigok * sonic 6000 7OOO 8OOO 50 TraveFTime, ps/ft Trailblazer Pad A est. Pressures Trailblazer Pad G est. Pressures Trailblazer Pad H est. Pressures Depth (fi,ss) Mud (ppg) Pressure (psi) Depth (fi,ss) Mud (ppg) Pressure (psi) Depth (fi,ss) Mud (ppg) Pressure (psi) 751 8.86 346 757 8.85 348 766 8.86 352 917 8.85 422 926 8.86 426 930 8.86 428 1078 8.86 496 1093 8.85 503 1088 8.86 500 1236 8.86 568 1268 8.86 578 1240 9.53 614 1388 8.96 646 1413 8.85 650 1385 9.83 707 1540 8.85 709 1566 9.63 763 1530 10.00 794 1693 9.60 845 1716 10.10 901 1676 10.15 884 1846 9.45 906 1864 10.41 1008 1824 10.10 957 2001 9.98 1037 2013 10.59 1108 1976 10.20 1047 2161 9.03 1014 2167 9.93 1118 2133 9,19 1019 2325 8.98 1085 2326 9.86 1192 2297 9.20 1097 2496 8.86 1148 2491 9.27 1199 2465 8.86 1134 2670 9.22 1279 2657 10.21 1409 2636 9.60 1314 2845 8.85 1309 2828 9.07 1332 2808 8.87 1294 3025 9.25 1453 3002 9.65 1504 2982 9.89 1533 3206 8.86 1475 3182 8.85 1464 3159 9.30 1527 3392 9.01 1587 3367 8.94 1564 3340 9.25 1605 3577 9.32 1731 3554 9.11 1681 3527 8.85 1622 3768 8.85 1733 3744 8.86 1722 3722 8.86 1712 3965 8.86 1824 3943 8.86 1814 3922 8.86 1804 4165 8.86 1916 4143 8.86 1906 3927 8.86 1806 4167 8.86 1917 4148 8.86 1908 4127 8.86 1898 4367 8.86 2009 4348 8.86 2000 4138 8.86 1903 4372 8.86 2011 4357 8.86 2004 4338 8.86 1995 4572 8.86 2103 4557 8.86 2096 4349 8.85 2001 4578 8.86 2106 4569 8.86 2102 4549 8.85 2093 4778 8.86 2198 4769 8.85 2194 4561 8.86 2098 4791 8.85 2204 4788 8.86 2203 4761 8.86 2190 4991 8.85 2296 4988 8.86 2295 4778 8.86 2198 5010 8.86 2305 5014 8.86 2306 4978 8.86 2290 5210 8.86 2397 5214 8.86 2398 4999 8.85 2300 5237 8.86 2409 5248 8.86 2414 5199 8.85 2392 5437 8.86 2501 5448 8.86 2506 5229 8.85 2405 5472 8.85 2517 5493 8.85 2527 5429 8.85 2497 5672 8.85 2609 5693 8.85 2619 5468 8.85 2515 5713 8.86 2628 5741 8.86 2641 5668 8.85 2607 5913 8.85 2720 5941 8.86 2733 5708 8.85 2626 5961 8.85 2742 5993 8.86 2757 5908 8.85 2718 6161 8.85 2834 6193 8.86 2849 5953 8.85 2738 6213 8.86 2858 6245 8.85 2873 6153 8.85 2830 6413 8.86 2950 6445 8.86 2965 6204 8.86 2854 6467 8.85 2975 6494 8.86 2987 6404 8.86 2946 6667 8.85 3067 6694 8.86 3079 6463 8.86 2973 6719 8.86 3091 6740 8.86 3101 6663 8.86 3065 6919 8.86 3183 6940 8.86 3193 6731 8.86 3096 6963 8.85 3203 6984 8.85 3213 7259 8.85 3339 7163 8.85 3295 7164 8.85 3305 7459 8.85 3431 7194 8.85 3309 7225 8.86 3323 7498 8.86 3449 7394 9.65 3705 -'/':~o 7425 8.86 3415 7698 9.24 3695 7414 9.72 3744 7460 8.85 3431 7724 9.29 3726 7614 9.40 3717 7660 8.85 3523 7924 9.95 4095 7631 9.37 3714 7696 8.85 3540 7944 10.01 4133 7831 8.91 3626 7896 8.85 3632 8144 10.04 4250 7858 8.85 3615 7937 8.86 3651 8165 10.05 4262 8058 8.85 3707 8137 8.86 3743 8365 9.73 4230 8096 8.85 3724 8180 8.85 3763 8389 9.70 4226 8296 8.85 3816 8380 8.86 3855 8589 8.97 4003 8344 8.86 3838 8422 8.85 3874 8621 8.86 3968 8544 8.86 3930 8622 8.85 3966 8821 8.97 4110 8598 8.86 3955 8664 8.86 3985 8858 8.99 4136 8798 8.86 4047 8864 8.86 4077 9058 9.31 4379 8853 8.86 4072 8912 8.86 4100 9095 9.36 4424 9053 8.85 4164 9112 8.86 4192 9295 10.38 5014 9101 8.86 4187 9165 8.85 4216 9329 10.55 5115 9301 10.52 5083 9365 9.53 4637 9529 11.18 5534 9336 10.81 5241 9409 9.68 4730 9558 11.27 5595 9536 11.73 5809 9609 11.63 5806 9758 11.13 5640 9562 11.84 5880 9639 11.92 5968 9786 11.11 5647 9762 11.55 5856 9839 12.37 6323 9986 9.25 4796 9785 11.51 5853 9859 12.42 6359 10029 8.85 4614 9985 9.28 4816 10059 10.76 5623 10229 8.85 4706 10025 8.86 4611 10088 10.53 5519 10299 8.85 4737 10225 8.86 4703 10288 9.22 4927 10499 8.85 4829 10294 8.85 4735 10344 8.85 4758 10594 8.86 4873 10494 8.85 4827 10544 8.85 4850 10794 8.86 4965 10594 8.85 4873 10634 8.86 4892 10909 8.86 5018 10794 8.85 4965 10834 8.86 4984 10917 8.86 5022 10945 8.85 5035 Table 1: Listing of estimated pressures and mudweights at the proposed drill locations. I\L--~./I--.I V L_~./ DEC 20OO Alaska Oil & Gas Cons. Commission Anchorage Pressure Prediction at Proposed Trailblazer Drill Locations in the NPR-A Winter 2001 Greg Brewton- AEX Sr Geophysicist Jim Seccombe - AEX Petrophysicist Phil Hep£ard- BP UTG Pressure Analyst NPR-A Exploration Team December, 2000 RECEIVED DEC 2 2 2000 Alaska Oil & Gas Cons. Commission Anchorage NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton O bp Table of Contents: I. Introduction 3 II. Conclusions 3 III. Methodology 3 IV. Calibration, Pressure Estimates and Shallow Gas Presence in Control Wells 6 IVa. East Teshekpuk Well Sonic Log Pressure Calibration- East Teshekpuk IVb. North Inigok Well Sonic Log Pressure Calibration - North Inigok Seismic Velocity to Sonic Log Calibration - North Inigok Seismic Velocity Pressure Estimation - North Inigok Shallow Gas Evaluation - North Inigok 8 8 9 10 11 IVc. West Fish Creek Well Sonic Log Pressure Calibration - West Fish Creek Seismic Velocity to Sonic Log Calibration- West Fish Creek Seismic Velocity Pressure Estimation - West Fish Creek Shallow Gas Evaluation - West Fish Creek 12 12 13 14 15 V. Pressure Estimates and Shallow Gas Presence at Trailblazer Pad Locations 16 Va. Trailblazer Pad A 18 Seismic Veloci~. Comparison to Control Well Seismic - Trailblazer Pad A 19 Seismic Velocity Pressure Estimation - Trailblazer Pad A 20 Shallow Gas Evaluation - Trailblazer Pad A 21 Vb. Trailblazer Pad G 22 Seismic Veloci~_ Comparison to Control Well Seismic - Trailblazer Pad G 22 Seismic Velocity Pressure Estimation - Trailblazer Pad G 23 Shallow Gas Evaluation- Trailblazer Pad G 24 Vc. Trailblazer Pad H 26 Seismic Veloci~_ Comparison to Control Well Seismic - Trailblazer Pad H 26 Seismic Velocity Pressure Estimation - Trailblazer Pad H 27 Shallow Gas Evaluation- Trailblazer Pad H 28 VI. References 29 RECEIVED 12/19/2000 DEC 2 2 ZOO0 Alaska Oil & Gas Cons. Commission Anchorage NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton O bp I. Introduction BP Exploration Alaska is proposing to drill three National Petroleum Reserve - Alaska pad locations during the winter 2001 drilling season: Trailblazer Pads A, G, and H. In accordance with state A.O.G.C.C. permit regulations, this report provides an assessment of potential shallow subsurface drilling hazards at each of the three Trailblazer Pad locations. Shallow drilling hazards may result from abnormally high pressures or the presence of gas. II. Conclusion Each of the three Trailblazer Pad locations exhibit similar pressure and mudweight profiles to three wells previously drilled in the vicinity of the pad locations, North Inigok, West Fish Creek and East Teshekpuk. Mudweights in the shallow subsurface should not exceed 10.5 ppg. Based on anomalous seismic amplitude and polarity, possible shallow gas is indicated at the following pad locations: Pad Depth Trailblazer Pad A 2900-3100 ft Trailblazer Pad G 2900-3100 ft The surface casing program has been designed to anticipate shallow gas at the depths listed above. By setting the surface casing at about 2400 feet subsea, the anomalous seismic event seen at Pads A and G will not be drilled on diverters, and will be drilled with blow-out preventers on. III. Methodology Pore pressure was predicted at each Trailblazer Pad location using seismic stacking velocity data calibrated to available sonic log and pressure data at three well locations in the vicinity of the pads. Shallow gas presence was determined by observation of anomalously high or low seismic amplitude, polarity reversals along a reflecting horizon and the presence of gas-related time sags. The stacking velocity data was carefully determined from detailed moveout analysis of 3D seismic data around each pad location. The data were then smoothed spatially, on a quarter mile radius, and temporally, over a forty-millisecond window. The smoothed stacking velocities were then converted to interval velocity using the Dix equation, and then calibrated to sonic log data (at well ties) using a single percentage scaling factor derived as a composite of the data. RECEIVED 12/19/2000 3 Alaska Oil & Gas Cons. Commission Anchorage NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton ObP Transformation of sonic log and stacking velocity data into pressure estimates requires establishing a normal compaction trend, relating velocity to that normal compaction trend and estimating the degree of overpressure by decreases in velocity from the normal compaction trend. The BP method employed in this report involves a proprietary algorithm that was built upon earlier published reports. The key equations in this method are: overburden (integrated densi~_ log): shale compaction curve: pressure models: Eaton- Eberhart-Phillips, Han and Zoback- ~-- ~0e-S/c Vt, = 5.77 - 6.94~ - 1.73(vet )~ + 0.446(P~ - e-16'7~' ) fracture gradient: nomenclature F =k(S- p)+ p _ % )~ k = 0.39(D - ag --~-_ g gravitational acceleration p bulk density z,D depth {b porosity {bo surface porosity S overburden pressure p pore pressure P, effective pressure Vo observed velocity Vn normally pressures velocity Vct clay volume ag air gap we water depth C compaction rate Vp compressional velocity 12/19/2000 RECEIVED DEC Alaska Oil & Gas Cons. Commission Anchorage NPR-A Winter 2001 Drilling Season - Pressure Prediction Greg Brewton C - 4132 C - 5000 C - 3000 Figure i: Variables thai affect shale In general, four parameters control the calibration procedure: shale compaction rate (C), surPace porosity (%), clay content (vc~) and upIift. As illustrated in Figure 1. compaction rate afikcts the overall curvature of the compaction curve and a lower compaction rates indicate more rapid compaction. Surface porosity represents the original porosity at the earth's surface (or very near surface) and is generally held to be near to critical porosity (38.6 %). Clay content is a lithoIogic term that encompasses the gross composition of shales (such as, amounts of illite or smectite and total organic content), and alTects the shape of the compaction curve by shil:ting it laterally. Uplift affects the compaction curve by vertical bulk shift, mimicking the geologic process of burial and uplift (and erosion). For this projecL surface porosity was held constaxlt at 40%, uplift ranges sip to 2000 fket (after consultation with BPXA structural geologists and basin modelers) and clay content and compaction rates were varied to achieve ties in welis with available mndweight data. Mudweights are usually not very good indicators of true formation pressure because ,,,/ells are ohen drilled over-balanced or under-balanced in relation to true formation pressure, or are used to handle non-pressure related drilling problems, such as sloughing shales or lost circulation. In this report, rnudweights in the control wells are considered to be over-balanced in relation to true formation pressure. In addition, fnrmation pressure estimates are given at the pad locations in both pounds per square inch (psi) and equivalent mudweight in pounds per gallon (ppg), which is meant to be that mudweight to exactly counter l'onT~ation pressure. NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton IV. Calibration, Pressure Estimates and Shallow Gas Presence in Control Wells Pressure translk)rm variables and sonic-to-seismic calibrations were established in three wells in the vicinity of the proposed pad locations. Figure 2 shows the location of the control wells (East Teshekpuk, North In/gok and West Fish Creek) in relation to the proposed Trailblazer Pad locations, the outline of available 3D seismic data and proposed ice roads, Figure 2: Basemap showing the outline of 3D seismic coverage, the control wells, the proposed Trailblazer Pads and ice road locations NPR-A - Winter 2(~)1 Drilling Season - Pressure Prediction Greg Brewton IVa. East Teshekpuk WeLl Sorbic _L_.o~. Pre.t.s'ure Calibratio~ East Teshekp~k Pressure translbrm variables were determined through an iterative process that was constrained by available mudweight data. Using the mudweight constraints, a compaction £actor of 4132, uplill of 1000 feet and two layers of clay content were used to estimate pressure fi'om the sonic log in the East Teshekpuk well. These parameters give an excellent tie of estimated pressure to actual mudweight, as seen in figure 3. Figure 3: East Teshekpuk sonic log to pressure calibration. The left track mudweight, middle track is pressure and right track is sonic transit time. NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton IVb. North Inigok Well Sonic Log Pressure Calibration North lnifjok Again, using mudweight to constrain the determination of transform parameters, pressure was estimated in ~he North lnigok well. Reasonable ties to mudweight data were achieved using parameters similar to the East Teshekpuk well. A compaction factor of 4132 and two layers of clay content were used and the uplift was determined to be 1700 feet. As shown in figure 4, the pressure estimate matches quite well to mudweight data, except the deepest layers, which are high in total organic content. Fiaure 4: North tnigok sonic log to pressure calibration. The tefl track is mudweight, middle track is pressure and right track is sonic transit time. NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton ObP Seismic Vetncirv to Sonic Lo;~ Calibratio;~ - North Inigok The results of seismic velocity analyses can be used to estimate pressure and mudweigbt at each of the Trailblazer Pad locations. Seismic velocity data is affected by wavelet attenuation and by non-hyperbolic move-out character as a result of anisotropic properties of subsurface rocks and unusual ray bending due to structural complexity. Therefore. seismic velocity data must be calibrated to well velocity data. The seismic velocity data were smoothed using a haft-mile radial window and a forty millisecond temporal window, prior to application of a single scaling function. The seismic velocity matches very well to the overall low frequency trend of the bulk of the sonic tog velocity as seen in figure 5. Minor discrepancies between the two can be seen in the deepest part of the data, just above l 0,000 feet and just above the LCU marker. The shallowest part of the seismic velocity data, from the surface down to about 1200 feet, was derived by estimating permafrost velocity at the surface and then tapering down to the first valid stacking velocity point, based on semblance data. Seismic velocities are unreliable in the shallowest depths due to lack F_jg_ure 5: North lnigok calibrated seismic velocity to sonic tog veloci~3 of multiplicity (lk~Id) in this part of the data. The sonic log data over this shallow interval may also be circumspect due, at Ieast in part, to partial melting of the permafrost during drilling. Never the less, the seismic velocity matches sonic Iog velocity very well fi'om 1200 l~et to depths 1500 feet below the LCU, and if the shallow sonic log data is reliable. it lies on a normally pressured gradient and the seismic velocities anomalous pressures. NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton ObP Seismic Velocity Pressure £stimation - North lni~ok Given that the seismic velocities match sonic velocities well, the pressnre transform variables derived from the sonic log data were applied to the seismic velocities for pressure estimates alt North Inigok, The pressure predicted by seismic data fits the bounds defined by mudweights used dining drilling of the well. Since the well did not enconnter any anomalous ~ressures during drilling, the slight increase in pressure predicted by seismic around I800 feet indicates a possible error of ~/2 pound per gallon, in relation to nmdweights used in the well. The pressm'e seen in the seismic velocities at deeper depths (eg. 8600 - 11000 ft) indicates opposite organic rich shales. Figure 6: North tnlgok selsmi¢ velocity to pressure transform. The left track is mudweight, middle track is pressure and right track is SOlfiC transit time. NPR-A Winter 200I Drilling Season - Pressure Prediction Greg Brewton S&diow Ga.s Eval, alio - North b i,,c~Lk Gas bearing formations in the shallow snbsurface are often too thin to have eft'cci on seismic vetociry analysis. In order to estimate shallow gas presence, attributes, such as anomalous amplitudes, polarity reversals and time sags are analyzed from stacked surface seismic data around the Trailblazer Pad locations. Figure 7 shows two lines, extracted from ~he 3D seismic dataset and the colTesponding velocity data that cross nver the North Inigok well location, Drilling reports indicated no shallow gas presence in the sohsmTace at North laigok, and the seismic data exhibit neither anomalous amplitudes nor polarity reversals. North Ialgok- Seismic and Velocity Data Xline 271 Velocity - lnline 799 Fiaure 7: Stacked seismic data and velocities f>ver the Nortt~ inigok well location. Color bar for the velocities is listed at tl~e top of the figure. The ~op ,Jurassic reflector is highlighted in red on the seismic data and black on the velocity data. The vdocity ased in the pressure prediction was taken at the well location (highlighted). ~, NPR-A - Winter 200i Drilling Season - Pressure Prediction Greg Brewton iVc. West Fish Creek Well Sonic Log Pressure Calibration - West Fish Creek Similar transik~rm variables to the other two wells were used to estimate pressures and mudweights from tile sonic log in the West Fish Creek well. Figure 8 shows that pressures match J'2irly well to mudweights for the well. within a V~ pound per gallon error. It is apparent that the sonic log data is unreliable lbr pressure estimates above about 1200 feet, possibly due at least in pm1 to partial melting of permafrost during drilling. The presence of an organically rich layer at 9000 feet (within the Kingak shales) causes low velocity. ?igure 8: West Fish Creek sonic to pressure calibration. The left track ts mudwei~ht, middle track is vressure and right track is static transit time. NPR-A - WinteF 2001 Drilling Season - Pressure Prediction Grog Brewton Seismic Velocity ~o Sonic Lo~t, Calibration - FVkst Fish Creek The seismic velocity matches very well to the overall Iow fi'equency trend of the bulk of the sonic log velocity as seen in figure 9. Discrepancies between the two can be seen in the deepest part of the data, from about 900 feet to total depth, where the seismic data is af~'ccted by the structural complexity of the Fish Creek Slide (see also figure 11). The shallowest part of the seismic velocity data, fFom the surface down to about 1200 feet, was derived by estimating permafrost velocity at the surface and then tapering down to the first valid stacking velocity point, based on semblance data. Again, the seismic velocity is unreliable in th shallow permalkost zone due to lack of multiplicity in the data. West Fish Creek - Vp Log and Vstack Comparison F~re 9: West Fish Creek calibrated seismic velocity to sonic log velocity NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Bre'4 ton Seismic Velocity Presxure Extimation - Wext Fixh Creek ObP '['he pressure ~ransl'orm variables used previously were applied lo the seismic velocities for pressure and mudweight estimates at West Fish Creek. The pressure predicted by seismic data fits the bounds defined by mudweights used during drilling of the well. Since the x~el[ did nor encounter any anomalously high pressures during drilling~ the slight increase in pressure predicted by seismic around 1500 to 3000 rket indicates a possible error of V2 pound per g~dlon. Figure It): West Fish Creek seismic velocity to pressure trans]~k3rm. The lef~ track is mudweight, middle track is pressure and right track is sonic transit time. NPR-A -- Winter 2001 Drilling Season - Pressure Prediction Greg gl-ewtoit Sh~llow Gr~s £vrtlix~tior~ - West Fi.~t~ Creek Figure ! 1 shows two lines, extracted from the 3D seismic dataset and the corresponding velocity data that cross over the West Fish Creek well location. The relatively high negative amplitude events seen on these sections at 700 (-2400 ft), 900 (-3500 1:9, t000 (-4100 fi) and 1200 (-4600 1~) milliseconds correspond to either gas or oil shows as recorded on mudtog reports or a hard-to-soft formation boundary. 'i'heref~.)re these amplitudes represent criteria by which to judge seismic attributes at pad locations. Also shown in the figure is the structural complexity associated with tile Fish Creek Slide. lntine 561 Xline 1061 Velocity - h~line 561 Fiaure l 1: S~acked seismic data and velocities over the West Fish Creek well location. Color bar for the velocities is listed at the top of the flg~re. The top Jurassic reflector is highlighted i~ red on the seismic data and black on the velocity data. The velocity used in the pressure prediction was taken at the well location (highlighted). Also highlighted are events on the seismic data that correspond to either oil or gas shows reported on nmd logs. NPR-A - Winter 200i Drilling Season - Pressure Prediction Greg Brewton Pressure Estimates and Shallow' (;as Presence at Trailblazer Pad l,ocatiuns Figure 12 shows the location of the proposed Trailblazer Pad locations in relation to the coutrot wells and ice roads. Using the pressure transform variables determined at the control wells, pressure is estimated at the proposed Trailblazer Pad locations. The overburden pressure used at North hfigok is representative of the overburden f¢>r the three Figure 1~3: Basemap sho~ring control well Trailblazer Pad and ice road locations. Fieure 12: Comparison of overburden pressures from the three control wells. {" { NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton ObP control wells, as shown in figure 13, and is used as overburden at the pad locations. Since the pressures estimated at each pad location use the transform variables established at the control wells, then pressures become relative to those known at the control wells. Based on the pressure estimates at the control wells, a ¥2 pound per gallon tolerance can be applied to the Trailblazer Pad location pressure estimates. Also, the Trailblazer Pad locations are outside the Fish Creek Slide and seismic velocities are not affected by structural complexity. 12/19/2000 17 NPR-A - Winter 200i Drilling Season - Pressure Prediction ~ bp Greg Brewton Va. Trailblazer Pad A Seixmic Veloci~;' CompaFison to Control We. II Sehmic- TrctilhbfzeF PaolA Figure 14 shows that stacking velocity at Trailblazer Pad A lies between the seismic velocities at control well locations fur shallow depths. This is a first indication that pressure at Trailblazer Pad A should be similar to that fUund in North lnigok and West Fish Creek. 32000 28OOO 24OOO 2OOOO 1200O 8000 4000 0 q 500 1000 !500 2000 2500 30o0 3500 4000 Time (2 way, ms) Figure 14: Comparison of stacking velocity at Trailblazer Pad A with stacking veloclty at North Inigok and West Fbb Creek. Vint Comparison for Pad A and N [nigok & W Fish Creek NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton Seismic Velocity Pre.~xure £sfimation - Trailblazer Pad A Trailblazer Pad A is proposed to drill to a depth of about 8500 feet and is predicted to have a nonnaI pressure gradient for the entire hole. Figure I5 shows that the estimated pressure is less than the mudweights in the control wells. Figure 15: Trailblazer Pad A location seismic velocity to pressure transt~,rm. The left track is mudweight, middle track is pressure and right track is sonic transit time. NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton Figure 16 shows two lines, extracted ffonl the 3D seismic dataset and the corresponding velocity data that cross over the Trailblazer Pad A location. The relatively high negative amplitude event seen on these sections at 800 milliseconds con'esponds to possible a gas prone interval occurring between 2900 and 3100 feet, subsea, A deeper a~iomaious ampiitude at nearly 1100 n~s (4300-4500 feet, subsea), indicates possible cemented interval and is not likely gas because the reflector has a leading positive amplitude. Fimn-e 16: Stacked seismic data and veloclties over the Trailbla×er Pad A loeatlon. Color bar for the velocities is listed at the top of the figure. The top Jurassic reflectm- is highlighted in red on the seismic data and black on the velocity data. The veloclty used in the pressure prediction was taken at the well location (hi,blighted). Figure 17 shows detail of the seismic attributes of the possible gas prone interval at 800 milliseconds. The possible shallow gas interval covers the Trailblazer Pad A location, is at the fl'inges of the Trailblazer Pad G location and is not present at the Trailblazer Pad H location. NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton Figure 17: Detail of stacked seismic data over Trailblazer Pad A showing possible gas anomaly NPR-A - Winter 2001 Drilling Season - Pressure Prediction O bp Greg Brewton Vb. Trailblazer Pad G Seismic Velocity Comparistm to Cot~trol Well Seismic - Trailblazer Pad G Figure 18 shows that stacking velocity at Trailblazer Pad G lies between the seismic velocities at control welt locations fbr shallow depths indicating that pressure at Trailblazer Pad G should be similm- to that found in No~h Inigok and West Fish Creek. Vint Comparison for Pad G and N Inigok & W Fish Creek Fitmre 18: Comparison of stacking velocit,,~ at Trailblazer Pad G with stacking velocity at North NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton Seixmic VelociiT, Pressure Estimatiot~ - Trailblazer Pad G Trailblazer Pad G is proposed to drill to a depth of about 7500 f'eet and is predicted to have a nonaml pressure gradient for the entire hole. Figure 19 shows tlnat within a possible error of 1/2 pound per gallon, the estimated pressure is similar to the mudweights in the control wells. Figure 19: Trailblazer Pad G locatkm seismic velocity to pressure transform. The left track is mudweight, middle track is pressure and right track is sonic transit time. NPR-A .- Winter 2001 Drilling Season - Pressure Prediction Greg Brewton Figure 20 shows two lines, extracted from the 3D seismic dataset and the corresponding velocity data that cross over the Trailblazer Pad G location. The relatively high negative amplitude event seen on these sections at 800 milliseconds correspunds to the outer reaches of the possible gas prone interval seen at the Trailblazer Pad A location. At Trailblazer Pad G, this zone also occurs between 2900 and 3100 feet, subsea. The pos~iblc cemented interval seen at Trailblazer Pad A is also seen at Trailblazer Pad G at nearly 1100 ms (4300-4500 17eel: subsea) and is not likely gas because the reflector has a leading positive amplitude. Trailblazer Pad G t,ocation - Seismic and Veh)dt¥ Data hfline 560 Xline 580 Velocity - tnllne 560 Velocity - Xllne 580 F[m~re 20: Stacked seismic data and velocities over the Trailblazer Pad G location. Color bar for the velocities is ~isted at the top of the flgure~ The top Jurassic reflector is hlghlighted tn red on the seismic data and black on the velodty data. The velocity used in the pressure predictkm was taken at the well location (h[gtfllghted). Figure 2I shows detail of the seismic attributes of the possible gas prone interval at 800 milliseconds. The fl'inges of the possible shallow gas interval and cemented streak reach thc Trailblazer Pad G location. NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton lnIine 559 Crrkssline 579 Fiaure 21: Detail of stacked seismic data over Trailblazer Pad G showlng possible gas anomaly. %~¢ %i~ O bp NPR-A - Winter 2001 Drilling Season - Pressure Predicdo~ Grog Brewton Vc. Trailblazer Pad H Seismic Velocity Comparison to Conzrol Well Seismic - Trailblazer Pad H Figure 22 shows that stacking velocity at Trailblazer Pad H lies between the seismic xelocifies at control well locations for shallow depths indicating that pressure at Trailblazer Pad H should be similar to that fnund in North Inigok and West ~isb Creek, Vint Comparison for Pad H and N tnigok & W Fish Creek 0 50o i 000 1500 2ooo 25oo 3000 3500 4000 Time (2 way, ms) Fi-ute 22: Comparison of stacking velocit) at Trailblazer Pad G with stacking ',elocity at North lnigok and West Fish (reek. NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton Seismic Velocii~ Pressure E~timatio~z - Trailblazer Pad H Trailblazer Pad H is proposed to drill to a depth of about 7500 feet and is predicted to have a normal pressure gradient for the entire hole. Figure 23 shows that within a possible error of V2 pound per gallon, the estimated pressure is similm' to the umdweights in the control wells. Figure 23: Trailblazer Pad H seismic velocity to pressure trans~brm. The left track is mudweight, middle track is pressnre and right track is s(mic transit time. NPR-A - Winter 2001 Drilling Season - Pressure Prediction ~ b9 Greg Brewton Sh~dlow Gas' E~'aluafion Trailblazer Par/H Figt~re 24 shows two lines, extracted from the 3D seismic daraset arxi the corresponding velocity data that cross over the Trailblazer Pad H location, There are no apparent amplitude anomalies indicated on these lines in the shallow subsurface and so shallow gas is l~ot expected to be ~ound ar Trailblazer Pad H. hdine 25t) Xline 300 Veloclt3 - Xline 3(~0 _Figure 24: Stacked seismic data and velocities over the Trailblazer Pad Fl location. Color Bar for the velocities is listed at the top of the f~gttre. The top Jurassic reilector is highlighted in red on ti~e seismic data and black on the velocity data. The velocity used in the pressure prediction was taken a~ the x~ ell location (hightighted), , NPR-A - Winter 2001 Drilling Season - Pressure Prediction Greg Brewton O bp VI. References Eaton, Ben E., 1969, Fracture gradient prediction and its application in oilfield operations: Journal of Petroleum Technology, October, 1969, p. 1353-1360. Eaton, Ben E., 1975, The Equation for Geopressure Prediction from Well Logs, SPE 5544, abstract of paper presented at the 50th Annual Fall Meeting of the SPE in Dallas, Texas, Sept-Oct 1975. Eberhart-Phillips, D., D-H Han, and M. D. Zoback, 1989, Empirical relationships among seismic velocity, effective pressure, porosity and clay content in sandstone: Geophysics, v. 54, no. 1, p. 82-89. PRESGRAF user notes, BP internal pressure prediction software. Scott, D. R. and L. A. Thomsen, 1993, A Global Algorithm for Pore Pressure Prediction, SPE 25674, paper presented at the SPE Middle East Technical Conference in Bahrain, April 1993. Traugott, M. O., 1982, Rock mechanics, petrophysics, and stratigraphy of the Tuscaloosa trend: Journal of Petroleum Technology, February, 1982, p. 428-432. RECEIVED DEC Ataska Oil & Gas Cons, commission Anchorage 12/19/2000 29 VEN~R ALASKASTAT 10 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 13OOO C½ 1 13OOOF 1OO. OD 1 OO. OD PYMT C:OMMENT$- PeT'ali't 'to dT'i11 tee HANDL]N~ INST' S/H - Te~-~-ie X4(~8 q"mil CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ 1 OO. OO 1 OO. OO ATTACHED · ..:BP EXPLORATION (ALASKA),JNC., ~.O:':~0X: 196612 ',;i~.'." :';.i::;'.'.,.'.:, ' ':;:'~/~''''':~': :':.,'AN.~HORAGE; ALASKA;: 99519-6612 ?!?' ?'' :::?.": :'i:!i!~ · :.... : ;;,.'. · ..... .,,.; :, :i;:. ':":': ~: ,:::. .,;,;,': FiRST:~TIQ~L. BANK' bF ASHLAND '.?' 2. !'": :~:':~EII;IATE,{3~ :;!.;iii::', ' :ii : .' ::':'i :,,:" NAT'ONA~:CITY.BANK :':: '::: ,'.': :.,":' ,::, ' ':~EVE[~,~JD (~HiO ,':" '. ";:::'5~'389 ::,:': ...... ~AY ONE ..! · ::;:::.. :STA:~E OF ^L^SK~:':. ...... :,':.,-,.::.. :~o~c~::..' ':,:. ,i;:::::: · .:::. :. ::333 ~ST 7TH '::!~E~UE:::;::'' SUITE 100 ANCHORAGE AK 99501 12/01/00 DATE :::,",',':':.. ::::::"::AMOUNT $100. O0 I · :.:':": NOT::VALID AFTER 120 DAYS ::.,' '~?:1 EXEMPTION FROM H2S REQUIREMENTS The Commission grants BP exemption from the H2S requirements found in 20 AAC 25.065 (c) for the Trailblazer G-1 well upon the condition that: 1. H2S monitoring complies with 20 AAC 25.066, 2. H2S gas levels are monitored continuously and recorded hourly during drilling and casing operations, and 3. recorded levels of H2S gas are submitted to the Commission in report form within 30 days after completion, suspension, or abandonment of the well. SHALLOW GAS MONITORING REQUIREMENTS Because of the.possibility of encountering gas in the shallow portion of the Trailblazer'A-1 Wellbore, the Commission requires mudlogging services, including"'standard gas monitoring equipment, be operational at all times from surface to the total depth of the well. Gas measurements must be monitored and recorded continuously, and these measurements will be submitted to the Commission in report form within 30 days after completion, suspension, or abandonment of the well. LITHOLOGIC SAMPLES All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught (when drill rate permits) and 10' sample intervals through target zones and/or any hydrocarbon shows. The AOGCC would like to commend the BP NPRA Ex~olo~on team members for the high quality information package included as a supplement to~J~Trailblazer Pad G Well 1 permit to drill application. The supplemental information w%~a~ccurate, comprehensive and contained a level of detail that allowed the AOGCC staff to easil/y/evaluate BP's permit. The attention to detail contained in the supplemental info/~package is appreciated. The AOGCC would like to thank the BP NPRA Exploration team for the high quality information package filed as a supplement to the Trailblazer Pad A Well 1 permit to drill application. The supplemental information was comprehensive and contained a level of detail that facilitated commission review and evaluation. wELL PERMIT CHECKLIST coMpANy /~' .... WELL NAME '~.'- / 'PROGRAM: exp /dev redrl, serv wellbore sag FIELD & POOL ,,'V",~ INIT CLASS ~'x'P~_ C~,~ t~_,,./7- -~,~/~ ~ GEOL AREA ~'~';'~.) UNIT# ,"~,5~ ADMINISTRATION APPR DATE 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 .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available, in drilling unit ............. N 8. If deviated, is wellbore plat included ............... ,44, . 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 ...... (~_~ N 13. Can permit be approved before 15-day wait ........... N Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to' tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. ann. disposal para req ON/OFF SHORE ENGINEERING 14. 19. 21. If a re-drill, has a 10~03 for abandonment been approved. 22. Adequate weilbore separation proposed ............. 23. If dive~r required, does it meet regulations .......... 24. Drilling .fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ....... ~: ....... ~~~ ~. 26. BOPE press rating appropriate; test to ~~ Dsig. 27. Choke manifold ~mplies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presen~ of H2S gas probable ................. GEOLOGY . 30. Pe~it ~n be issued wlo hydrogen sulfide measures ..... 31. Data presented on potential ove~res[~[~ones~ ...... 32. Seismic analysis of shallow gas zone~' . ......... ANNU~R DISPOSAl35. With proper cementing records, this plan (A) will contain waste in ~ ~u~u~= ~=~=~v,~ ~u.=; .... iAPPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E). will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: UIC/A.nnular I-IJ Y N f ~ , , COMMISSION: Comments/Instructions: · c:~nsoffice\wordian\diana\checklist (rev. 11/01//00) 0 Z 0
