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201-193
David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250602 (IGB 25-001) Well API #PTD #Log Date Log Company Log Type Format AOGCC E-Set# KTU 43-6XRD2 50133203280200 205117 07/14/2014 POLLARD CBL PDF MPU C-15A 50029213580100 216070 07/06/2016 HALLIBURTON RCBL PDF LAS PPTX PBU L-103 50029231010000 202139 08/06/2002 SCHLUMBERGER USIT/TEMP/GR PDF PBU L-108 50029230900000 202109 06/30/2002 SCHLUMBERGER USIT/TEMP/GR PDF PBU L-111 50029230690000 202030 03/02/2002 SCHLUMBERGER USIT/TEMP/GR PDF TIF PBU S-104 50029229880000 200196 02/02/2001 SCHLUMBERGER USIT PDF PBU V-212 50029232790000 205150 12/14/2005 SCHLUMBERGER USIT PCU 04 50283201000000 201193 11/04/2001 SCHLUMBERGER USIT/CBL PDF TIF Please include current contact information if different from above. T40515 T40516 T40517 T40518 T40519 T40520 T40521 T40522PDFPCU 04 50283201000000 201193 11/04/2001 SCHLUMBERGER USIT/CBL TIF Please include Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.03 08:26:36 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 11, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 4 PRETTY CK UNIT 4 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/11/2024 4 50-283-20100-00-00 201-193-0 G SPT 3196 2011930 1500 597 597 595 596 0 0 0 0 4YRTST P Guy Cook 3/2/2024 Testing completed with a trailered triplex pump and calibrated gauges. There was a gauges for the conductor as well that stayed at zero psi during the testing process. The well was producing gas during the test. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRETTY CK UNIT 4 Inspection Date: Tubing OA Packer Depth 14 1706 1685 1675IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC240227183047 BBL Pumped:0.2 BBL Returned:0.2 Thursday, April 11, 2024 Page 1 of 1 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/06/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231006 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 11-17x 50133205850000 209016 9/23/2023 HALLIBURTON RMT3D MPU C-23 50029226430000 196016 9/15/2023 HALLIBURTON RBT MPU F-89A 50029232680100 223026 9/12/2023 HALLIBURTON COILFLAG MPU F-89A 50029232680100 223026 9/12/2023 HALLIBURTON RBT PCU-04 50283201000000 201193 9/14/2023 HALLIBURTON EPX PCU-04 50283201000000 201193 9/14/2023 HALLIBURTON MFC24 Please include current contact information if different from above. T38041 T38042 T38043 T38043 T38044 T38044 10/6/2023 PCU-04 50283201000000 201193 9/14/2023 HALLIBURTON EPX PCU-04 50283201000000 201193 9/14/2023 HALLIBURTON MFC24 Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.06 15:41:18 -08'00' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to. iim.reaaitbalaska.aov: AOGCC.InsDectors0.alaska.00v: Dhoebe.brooks(cDalaska.aov OPERATOR: Hilcorp Alaska LLC FIELD/ UNIT / PAD: Pretty Creek Field / Pretty Creek Unit / Pad 2 DATE: 03/09/20 OPERATOR REP: Scott Anthony AOGCC REP: 1616 1597 Well PCU #4 Pressures: Pretest PTD 2011930 Type Inj N Tubing 980 Packer TVD 3196 r BBL Pump 0.0 IA 0 Test psi 1500 BBL Return 0.0 OA 0 Notes: AOGCC witness waived. Gas Storage Well I/ Well Pressures: Pretest PTD Type Inj Tubing Packer TVD BBL Pump IA Test psi BBL Return OA Notes: Well Pressures: Pretest PTD Type Inj Tubing Packer TVD BBI -Pump IA Test psi BBL Return OA Notes: Well Pressures: Pretest PTD Type Inj Tubing Packer TVD BBL Pump IA Test psi BBL Return OA Notes: Well Pressures: Pretest PTD Type Inj Tubing Packer TVD BBI -Pump IA Test psi BBL Return OA Notes: Well Pressures: Pretest PTD Type Inj Tubing Packer TVD BBL Pump IA Test psi BBL Return OA Notes: Well PTD Type Inj Packer TVD BBLPump Test psi BBL Return Notes: Well Pressures: Pretest PTD Type Inj Tubing Packer TVD BBLPump IA Test psi BBL Return OA Notes: chns.wallace(dalaska. aov to('W2,0 Initial 15 Min. 30 Min. 45 Min. 60 Min. 980 980 980• Type Test P 1620 1616 1597 Interval 4 0 0 0 Result P Initial 15 Min. 30 Min. 45 Min. 60 Min. Initial 15 Min. 30 Min. 45 Min. 60 Min. ype Test Interval Result Type Test Interval Result Initial 15 Min. 30 Min, 45 Min, 60 Min. Type Test Interval Result Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Test Interval Result Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Test Interval Result Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Tubing Type Test IA Interval OA Result TYPE INJ Codes W = Water G = Gas S = Slurry I = Industrial Wastewater N = Not Injecting Initial 15 Min. 30 Min. 45 Min. 60 Min, Type Test T Interval I Result TYPE TEST Codes INTERVAL Codes Result Codes P = Pressure Test I =Initial Test P = Pass O = Other (describe in Notes) 4 = Four Year Cycle F = Fail V = Required by Variance I = Inconclusive O = Other (describe in notes) Form 10-426 (Revised 01/2017) MIT Pretty Creek 03-09-20 • 41) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,April 12,2016 Jim Regg 2CT 77 ` 1�I1 P.I.Supervisor SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 4 FROM: Matt Herrera PRETTY CK UNIT 4 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry I--& _- NON-CONFIDENTIAL Comm Well Name PRETTY CK UNIT 4API Well Number 50-283-20100-00-00 Inspector Name: Matt Herrera Permit Number: 201-193-0 Inspection Date: 3/23/2016 Insp Num: mitMFH160329122854 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill 4 Type Inj N TVD I 3196 - Tubing 1350 1350 - , 1350 . 1350 • PTD 1 I 2011930 [Type Test SPT Test psi 1500 . IA 9 1800 - a 1780 - 1775 - L Interval4YRTST P/F P ,' OA o 0 0 0 Notes: SCANNED SEP 2 7 2016 Tuesday,April 12,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday, March 29, 2012 gel ((( v P.I. Supervisor l SUBJECT: Mechanical Integrity Tests HILCORP ALASKA, LLC 4 FROM: Lou Grimaldi PRETTY CK UNIT 4 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name PRETTY CK UNIT 4 API Well Number 50 283 - 20100 - 00 - 00 Inspector Name: Lou Grimaldi Permit Number: 201 - 193 - Inspection Date: 3/28/2012 Insp Num: mitLG120329021736 Rel Insp Num: • Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 4 Type Inj N ' TVD 3196 IA 0 1625 - 1610 1605 - PTD 1 2011930 ' Type Test SPT Test psi 1500 ' OA 0 0 0 0 Interval 4YRTST P/F P , Tubing 1310 1310 1310 1310 - Notes: 1/4 Bbl methanol pumped and returned. Good test. , Thursday, March 29, 2012 Page 1 of 1 • Maunder, Thomas E (DOA) Page 1 of 2 From: Ross, David A. [Petro Technical Resources of AK] [rossda@chevron.com] Sent: Tuesday, October 21, 2008 3:05 PM To: Maunder, Thomas E (DOA) Cc: Kanyer, Christopher V; Tyier, Steve L Subject: RE: Pretty Creek #4 (201-193) Hi Tom, ('ve reviewed the 404 submitted for the Pretty Creek #4 well and have the following responses to your message below; The only sleeve manipulated during this workover was the CMD sleeve @ 5173' (5183' SLM), on 9/3-9/4 the sleeve was closed in order to perform a pickling treatment which took place on 9/13. On 9/13-9114, there were several attempts to re-open the sleeve @ 5183' SLM which was finally confirmed to be open. The depth of this sleeve was omitted on the operations summary as per your observation. On 9/17-9/18 there was another slickline run made to confirm that the sleeve @ 5183' SLM was still open and this was confirmed. Again the depth of the sleeve was omitted from the operations summary. Although from the form it appears that the well was classified as a water injector (WINJ}, it is misleading due to the fact the check boxes for the selections are to the right of each respective selection. In reality the box that is checked is actually indicating a gas injector (GINJ) although the box is much closer to the WINJ selection. This is an issue with the spacing of the boxes on the form itself. I'm am not sure what the issue is pertaining to your comment about the 2G-GS designation in block 16. To my knowledge this well is permitted as a gas storage well. Please confirm if these explanations are sufficient or if we need to re-submit the 404 with the appropriate modifications. Regards, David Ross Alaska Wellbore Maintenance Team Chevron North America Exploration & Production (MCA) Office: {907) 263-7696 Cell: (281) 660-2493 Fax: (866) 244-1439 Email: rossda@chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, October 21, 2008 1:13 PM To: Ross, David A, [Petro Technical Resources of AK] 10/22/2008 • Subject: Pretty Creek #4 (201-193) Page 2 of 2 David, I am reviewing the 404 for the work recently performed on this well. There is detail given for the sliding sleeve work accomplished 9/3 - 9/4, however there is no depth given for any other sleeve work. Also, according to the drawing, the sleeve at 5173 ss that was closed by the work 9/3 - 9/4 is open. But there it is not possible to tell that from the work summary. You have indicated that the well is a water injector, but this is not correct. The well is "2G-GS" which is not a selection that is available in block 16. What are the future plans for well work? Thanks in advance. Tom Maunder, PE AOGCC 10/22/2008 STATE OF ALASKA • A~ OIL AND GAS CONSERVATION COMMISSION.,... REPORT OF SUNDRY WELL OPERATIONS ' 1. Operations Abandon Repair Well Plug Perforations Stimulate ~ Otht?r' Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver ^ • Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory^ 201-193 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ^~ 6. API Number: 50-283-20100-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 100' above MSL ~ Pretty CK Unit 4 (PCU #4) 8. Property Designation: 10. Field/Pool(s): ADL0063048 [Pretty Creek Unit] Pretty Creek /Undefined Gas /Beluga Gas Storage 11. Present Well Condition Summary: Total Depth measured 9,580' ~ feet Plugs (measured) 5,584' true vertical 7,566' feet Junk (measured) N/A Effective Depth measured 5,584' feet true vertical 3,981' feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 120' 13-3/8" 120' 120' 3450 psi 1950 psi Intermediate 2,385' 9-5/8" 2,385' 1,970' 6870 psi 4760 psi Production 6,942' 7" 6,942' 5,105' 8160 psi 7020 psi Liner 1,212' 4"gravel pack screen 4,372' &; ~ 3 96' N/A N/A ~~1~ Perforation depth: Measured depth: See Attached Schematic True Vertical depth: See Attached Schematic Tubing: (size, grade, and measured depth) 6.4# L-80 4,372' Packers and SSSV (type and measured depth) (3) SC-1 Packers / N/A 4,372', 4,526', 5,181' / N/A 12. Stimulation or cement squeeze summary: Acidize /stimulate open Beluga interval. (See operations summary) Intervals treated (measured): 5,152'-5,172'MD Treatment descriptions including volumes used and final pressure: Xylene /acid treatment 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 15 1500 psi Subsequent to operation: 0 10,000 (prod rate) 0 15 1468 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^ Service Daily Report of Well Operations X 16. Well Status after work: ~ ~ ~ ~ ~~~ Oil ^ Gas ^ WAG ^ GINJ J ^ 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: 308-304 Contact David Ross 263-7696 Printed Name Timothy C. Brandenburg Title Drilling Manager ~.•~;~ ~ ..._. ' ~ Signature ~•-' ~ -~ Phone 263-7600 Date 10/6/2008 Form 10-404 Revised 04/2006 ~~ ~ ~. ~ # ~ ~ ~ ~ ~ - ~ Submit Original Only 10~a.,~ UNOCAL ~retty Creek Well No. 4 CASING AND TUBING DETAIL SI%H; WT GRADE CONN IU TOP B"I'M. 13-3/8" Surface 120' 9-5/8" 47 L-80 Butt Surface 2,385' 7" 29 L-80 Butt Surface 6,942' Tubing 2-7/8" 6.4 L-80 Butt SC 4,372' JEWF,LRY DETAIL Production Tubing Inner String Jewelry I 4521 2.313 3.170 Baker CMD sliding sleeve II 4560 2.313 3.24 Baker "X" nipple III 5173 2.313 3.17 Baker CMD sliding sleeve IV 5212 2.313 3.24 Baker "X" nipple V 5319 2.313 3.117 Baker "X"nipple VI 5576 2.313 3.17 Baker CMD sliding sleeve 5584 Bull plug -end of tubing Packers, Screens, Misc. 1 - - Dual Tubing Hanger, 2-7/8" x 2-3/8", 11" SM 2 4,372' SC-1 Gravel Pack Packer 3 4,501' Baker Weld Wire Wrapped Screen 4 4,526' SC-1 Gravel Pack Packer 5 5,147' Baker Weld Wire Wrapped Screen 6 5,181' SC-1 Gravel Pack Packer 7 5,554' Baker Weld Wire Wrapped Screen 8 5,584' K-1 Retainer 9 6,862' K-1 Retainer with 12 bbls cement below and 5 bbls above. A 2,517' Heater String 2-3/8", L-80, Butt SC PERFORATION HISTO RY Interval Accum Date 'Lone 'I'o Btm Amt s f (;omtnents 11/24/2001 Sterli 4 0T 4 14' T 12 11/17/2001 Beluga 5,152' 5,172' 20' 12 11/14/2001 Bel a 5 S 77' 11' 12 SLIDING SLEEVE H[STORY SS Depth 5/40002 9/21/2002 4/20103 3122/06 9/13/2008 4521 cosed open closed cosed closed 5173 open open open open open 5576 cored closed open? cored cored TD = 9,580'MD/7,600' TVD Max Hole Angle = 51 deg DRAWN BY: crw/tcb/jws Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) PCU-04 PRETTY CK UNIT 4 ADL063048 5028320100 HE3462 Jobs Primary Job Type Job Category Objective ' Actual Start Date ' Actual End Date Workover Workover CTCO and xylene/acid stimulation for gas storage well 9/2/2008 Primary WellboreAffected Wellbore UWI Well Permit Number PCU-04 5028320100-00 2011930 - _ - -- ~Daily Operations - , _ _ _ 9/212008 00:00 - 9/3/2008 00:00 _ _ _ _ __ Operations Summary Site visit with Schlumberger Coil Tubing Supervisor, No luck with Pollard unit, due to road problems. 913/2008 00:00 - 9!4/2008 00:00 _ _ _ _ Operations Summary RU wireline. Pressure test 250psi low/ 3500psi high. Close Slidin Sleeve at 5183' SLM. _ _ 9/4/2008 00:00 - 9/5/2008 00:00 _ - Operations Summary Work on tomorrows load out and move equipment to PCU #4 9/5/2008 00:00 - 9161200$ 00:00 _ Operations Summary Recieve Barge w/ Coil Tubing unit and support equipment. Mobilize to well site. Begin set-up. - - - __ 9/6/200800:00 - 9/7/2008 00:00 Operations Summary Mobilize Coil Equipment from barge landing to PCU #4 site, Spot and rig up equipment. 917/2008 00:00 - 9/812008 00:00 _ _ _ Operations Summary Last trailers to PCU #4 Spot last equipment in containment and shore up w/Timbers. _ 9/81200$ 00:00 - 919/2008 00:00 _ _ _ Operations Summary Set up DSM Trailer and work camp issues. Operations suspended until Xylene can be delivered. -- 9/11/2008 00.:00 - 9/12/200& 00:00 Operations Summary Travel to PCU #4 Unload barge and stab BOP's on well and make up flow lines. Contacted AOGCC of upcoming BOP test. 9/1;212008 00:00 - 9/13/2008 00:00 _ Operations Summary Test Coil Bop's and flow lines, 250psi low/40000psi high. Jim Regg of AOGCC waived witness of test. Pickle tubing w/ 5bbl xylene w/ 10% U-67, & 10bb1 gas zone acid. Displaced with 5bbl water & 20bb1 soda ash solution. - - _ _- - - 9/13/2008 00`00 - 9/141 008 00:00 Operations Summary Made many attempts to open CDM sliding sleeve and confirm same _ _ 9/14/2008 00:00 - 9/15/2008 00:00 _ -- ___ Operations Summary Inject 38.5 bbls of Xylene @ 1.2bpm & 2300 psi, Soak and flow back through test seperator. Total 28bb1 recovered. :9/15/2008 Q0:00 - 9/16/2008,00:00 . ____ ___.__ _ _ _ _ _ _ _ _ _ Operations Summary Flow well, pumped 34.6 Bbls nitrofied gas zone acid [10% HCL, 5.5%Mutual Solvent, 26.5% Methanol, Non-ionic Surfactant, Corrosion Inhibitor, & Iron Reducing Agent] @ 2bpm & 2650psi displace with 12000scfm N2, flow back get total of 20 Bbls acid, attemping to get well to flow to recover acid. -- - ---- 9/16/2008 00:00 - 9/17/2008 00:00.. _ _ _ Operations Summary Attempt to flow remaining 15 BBLs acid from well, Rig Down and Demob. - - - - -- -- 911€ 120!)8 00:00 = 8/18/2008 00:00 Operations Summary R/U slickline and confirmed sleeve position open, fluid level @ 5,251' WLM/5,267' KB, sand level @ 5,581' WLM/5,597' KB, and catch fluid sample. Rig up test seperator -- 1b%212008 00:00 -10/3!2008 00:00 - -- _ _ -- Operations Summary Finish DeMobe of equipment out of all fields 10!3/2008 00:00.1014/2008 00:00 Operations Summary Consolidate loads at Cotton Wood Yard. Unload Timbers for dry storage, work CVX share of 2 barge. 10/4/2008 00:00 -10/5/2008 00:00 _ Operations Summary Work morning & evening barges. Work trailers & mud products at Cotton Wood. - --- ---- 10/5/2008 00:00 -10/6/2008 00:00 Operations Summary Last Report for Coit operations on Westside 2008 ~ ~~ ~~ ~ ~ i`s ~ .~ ~ ~ ~_ ..~.. ~.,a ~ ~ ~... a ~~1- ~_~ . ~~~t.s ~ ~J .i~~ ALA5SA OIL A1~TD GAS CO1~T5ERQATI011T C01-IIrII55IOH Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Anchorage AK 99519 ~ D J ~ ~ 3 Re: Pretty Creek Field, Beluga Undefined Gas Storage Pool, PCU #4 Sundry Number: 308-304 Dear Mr. Brandenburg: ~~~:'~~~~ S~' ~ ~;~ 200$ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED thi~day of August, 2008 Encl. STATE OF ALASKA ~~~~~ g~ cc~ ~~ ` A~ OIL AND GAS CONSERVATION COM~SION , BUG 2 ~ [OOb ~ '~' APPLICATION FOR SUNDRY APPROVALS ~ss~~r-~ 20 AAC 25.280 r 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate f~~{/y~~~~V Other^ ~ ` ~1 7Ld 4i1 P Alter casing^ Repair well ^ Plug Perforations ^ Stimulate Q ~ Time Extension Change approved program^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ~ Exploratory ^ 201-193 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-283-20100-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Pret CK Unit 4 PCU #4 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL0063048 Pret Creek Unit 16.6' Pre Creek /Undefined Gas / Belu a Gas Stora e 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9,580' 7,566' ~ 5,584' - 3,981' 5,584' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 120' 13-3/8" 120' 120' 3450 psi 1950 psi Intermediate 2,385' 9-5/8" 2,385' 1,970' 6870 psi 4760 psi Production 6,942' 7" 6,942' 5,105' 8160 psi 7020 psi Liner 1,212' 4" gravel pack screen 4,372' 3,196' N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 6.4# L-80 4,372' Packers and SSSV Type: Packers and SSSV MD (ft): (3) SC-1 Packer(s) / N/A 4,372', 4,526', 5,181' / N/A 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 9/8/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ^' WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Ross 263-7696 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature 6-7600 Date 8/25/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~©~ . i) SZ ~`~ e~~ w~~ ~ CS ©~ `~S'~' SSV~ t~.T'S~ ~~~C ~ ~~ ~~ Cr t~\L ~ c , t ~ 0 i~SS V ~~ Cam` ~ ~~ ~ Q ( Subsequent Form Required: '~®~( ` __, _t ~~ ~~~~~ ~~~ O h M®('~~`n~ 1© '1~~ , APPROVED BY ~ /~~ NER THE COMMISSION D t A d b I a e: pprove y: COMMISS O Form 10-403 Revised 6/ QB6 ~ 1 -, I ~ (~ ~ ~ ~ ~~~= ~~ t~ ~ ~: 1Q0B Submit in Duplicate UNOCAL CASING AND TUBING DETAIL SI"l,H; W"1' GRADE CONN ID TOP BTM. 13-3/8" Surface 120' 9-5/8" 47 L-80 Butt Surface 2,385' 7" 29 L-80 Butt Surface 6,942' Tubing 2-7/8" 6.4 L-80 Butt SC 4,372' Tight spot in tubing at 1150' WLM (4/ 17/03 ) JEWELRY DETAIL ~retty Creek Well No. 4 Production Tubing Inner String Jewelry I 4521 2.313 3.170 Baker CMD sliding sleeve II 4560 2.313 3.24 Baker "X" nipple III S 173 2.313 3.17 Baker CMD sliding sleeve 'g- IV 5212 2.313 3.24 Baker "X" nipple V 5319 2.313 3.117 Baker "X" nipple VI 5576 2.313 3.17 Baker CMD sliding sleeve 5584 Bull plug -end of tubing Packers, Screens, Misc. 1 - - Dual Tubing Hanger, 2-7/8" x 2-3/8", 11" SM 2 4,372' SC-1 Gravel Pack Packer 3 4,501' Baker Weld Wire Wrapped Screen 4 4,526' SC-1 Gravel Pack Packer 5 5,147' Baker Weld Wire Wrapped Screen 6 5,181' SC-1 Gravel Pack Packer 7 5,554' Baker Weld Wire Wrapped Screen 8 5,584' K-1 Retainer 9 6,862' K-1 Retainer with 12 bbls cement below and 5 bbls above. A 2,517' Heater String 2-3/8", L-80, Butt SC PERFORATION HISTO RY nterva Accum. Date Zone Top Btm Amt s f Comments 11/24/2001 Sterlin 4,507 4,514' T 12 11/17/2001 Beluga 5,152' S 172' 20' 12 11/14/2001 Belu a 5,566' S,57T 11' 12 SLIDING SLEEVE HISTORY SS Depth 5/4/2002 9/21/2002 4/20/03 3/22/06 4521 closed open closed closed 5173 open open open open 5576 closed closed open? closed TD = 9,580'MD/7,600' TVD Max Hole Angle = 51 deg PCU 4 Actua105-30-06.doc DRAWN BY: crw/tcb/jws Ch\evr~on T PROCEDURE SUMMARY: Pretty Creek Unit Well #PCU #4 8/25/08 PCU 4 is a current Gas Storage well on Cook Inlet's Westside. The well has recently declined in injection and production rates due to the build up of "gunk". The following procedure and contingencies are to clean the tubing and stimulate the matrix, and return the well to its previous rates. Operation: 1. MIRU Slickline. RI close sldg slue @ 5173'. 2. Pressure wellbore to 2000 psi w/ gas. Monitor f/ 3 hrs. Bleed pressure off. 3. MIRU/Spot CTU. Turnkey RU. RU flow back equipment & tank(s). 4. PT BOPE. PUMU CTC & jet nozzle. Accept CTU. 5. RIH to 5580' while circulating at minimum rate. CBU. Pressure test wellbore to 1500 psi f/ 30 min. 6. Displace Pickle-Chem to nozzle. POOH @ 30 fpm while jet washing tbg w/ Pickle-Chem. 7. RIH to 5580'. Open circ valve. POOH while blowing tbg dry w/ N2. Trap pressure on tbg. Stand-back CTU injector head. 8. MIRU Slickline. RI open sldg slue @ 5173'. POOH. RD 9. Produce well through flow-back equipment to atmosphere for 2 hours. 10. RU CTU. RIH to 5580'. Spot stimulation chemical across upper Beluga interval. Perform matriz stimulation as directed. Blow tbg dry w/N2. POOH. Trap pressure on tbg. 11. Release CTU to turn- key Demobe. 12. Turn well over to production. PCU #4 REVISED BY: CVK 8-25-08 PC4_injectivity~roblem_OSO~.doc . Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 27, 2008 2:38 PM To: 'Ross, David A. [Petro Technical Resources of AKj' Subject: RE: PC4_injectivity_problem_050206.doc Thanks David. That is what I sort of thought the source of the problem was. Any mechanical fix possible? Tom From: Ross, David A. [Petro Technical Resources of AK] [mailto:rossda@chevron.com] Sent: Wednesday, August 27, 2008 2:37 PM To: Maunder, Thomas E (DOA) Subject: PC4_injectivity_problem_050206.doc «PC4_in jectivity_problem_050206. doc» Tom, I found this document that was created prior to the previous stimulation on this well in 2006. The belief is that the hydrocarbon portion of the gunk is primarily made up of gas compressor tube oil. The treatment that was pumped in 2006 was very successful and is virtually identical to the proposed treatment with the exception that I plan to pump a xylene:acid dispersion for the pickle treatment as well as the acid stage. Let me know if you need any additional info. Regards, David Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 27, 2008 2:04 PM To: Ross, David A. [Petro Technical Resources of AK] Subjec`: Pretty Creek #4 (201-193) t ~- David, I am reviewing the sundry to stimulate this well. Do you have an analysis of the "gunk"? Thanks in advance, Tom Maunder, PE AOGCC • PCU #4 Inj ectivity Problem S/2/06 C We are having infectivity problems with our new gas storage well in the Pretty Creek Unit. Gas storage is being conducted in a depleted Beluga gas zone that has 20 feet of net sand. Pressure buildup tests during the production of the well indicated perm of 132 and and skin of 17. The well is completed with gravel pack as follows: 7" production casing, 4.S" Baker screens, 30-SO Econoprop sand. The well has two other gravel packed zones which are not currently being using for injection. An inner 2-7/8" tubing string with sliding sleeves isolates the different intervals. A 2-7/8" tubing string runs from surface down to the gravel pack assemblies. Storage injection was commenced on 11/1S/OS. Gas was free-flowed into the well at an average rate of 3.S mmcfd and 800 psi tubing pressure for just over one month. On 12/21/OS, the storage injection compressor was commissioned. Injection continued until the end of the month at a final rate of 9.2 mmcfd at 1300 psi. Storage injection ceased on 1 / 1 /06 due to market conditions. The well was left shut in until 3/1 S/06 when injection was reinitiated. Reduced infectivity was apparent at this time, with average rates of 6 mmcfd at 1200 psi. Note that reservoir pressure has increased from 47S psis on 9/30/OS, to 726 on 2/9/06, and 882 psia on 3/24/06. On 3/21106, 2 gallons of methanol were pumped into the well to clear any potential hydrates. The tubing pressure initially climbed SO psi after this injection and then dropped back to previous levels. Then 12-14 gallons of diesel were pumped into the well. This was done to try to dissolve probable Tube oil buildup seen in our other gas storage wells. The diesel was pumped in while the well was on injection at 6 mmcfd. After 4 to S minutes, the flowing tubing pressure rose from 1440 psi to 1 SSO psi and then to 1950 psi. The compressor shut down at this point due to either pressure or temperature set points. The tubing pressure slowly dropped to 1000 psi (over 10 to 1 S minutes). According to the operators, it normally drops off in 2 to 3 minutes. On 3/22/06, a tag run was made with a bailer prior to running pressure bombs to get a static pressure measurement. The bailer was run to 5613' with some weight loss as high up as 1700' (also coincident with the highest angle in the hole). Well goes to SO degrees at 1800'. A full load of material was recovered in the bailer. The sample was analyzed by Baker Petrolite's lab and found to be 62% acid soluble, 14% acid insoluble and 24% organics. Of the acid insoluble portion, 37% was iron sulfide. Other components were CaSO4, CaMg(C03)2, CaC03 and NaCI. We assume that the organics are primarily Tube oil and residue from the compressor. The insolubles appeared to be clay and quartz. Infectivity has continued to decline. On S!1/06, the injection rate was 2.7 mmcfd at 1925 psi injection pressure. We are running a pressure falloff survey today. Need recommendations on a treatment plan. PCU-4 10000 9000 8000 7000 v 8000 U E m 5000 a m ~ 4000 3000 2000 1000 0 Sep-05 PCU-4 10000 9000 8000 7000 .0 6000 v E W 5000 K a A ~ 4000 3000 2000 1000 0 Mar-06 Gas Rate and Tbg Press vs Time Gas Rate and Tbg Press vs Time • 2000 1900 1800 1700 1600 1500 1400 1300 1200 a 1100 ~ a 1000 ~ 900 a c S00 H 700 B00 500 400 300 200 100 0 2000 1900 1800 1700 1600 1500 1400 1300 w 1200 a 1100 ~ 1000 900 a a c 800 700 600 500 400 300 200 100 0 Dec-O5 Mar-OB Apr-O6 May-06 .. STATE OF ALASKA . ALAS~IL AND GAS CONSERVATION COMM N REPORT OF SUNDRY WELL OPERATIONS RECE'\/Fn .. ,·..·"'."'A ",,,d' OCT J 6 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate ~ . Alas~~ff~¡~ G.' "',' , " . Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension . IB LUd", <'''Jmrms:$1fJr Change Approved Program D Ope rat. Shutdown D Perforate D Re-enter Suspended Well [JAflchoraga 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development D Exploratory D 201-193 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic D Service 0 6. API Number: 50-28-320100 fØ~Z$?1-Z6l00-00~H 7. KB Elevation (ft): 9. Well Name and Number: 16.6' KB above Wellhead Height PCU #4 8. Property Designation: 10. Field/Pool(s): Pretty Creek Unit and Preek Creek Storage Lease (ADL No. 390776) Pretty Creek / Beluga - Sterling 11. Present Well Condition Summary: Total Depth measured 9580' . feet Plugs (measured) 3979' true vertical 7566' . feet Junk (measured) Effective Depth measured 5584' . feet true vertical 3979' . feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 120' 13-3/8" 120' 120' 3,450 psi 1,950 psi Intermediate 2386' 9-5/8" 2386' 1,970' 6,870 psi 4,750 psi Production 6942' 7" 6942' 5,150' 8,160 psi 7,020 psi Liner 1212' 4" Gravel Pack Screen 4372' 3,196' NA NA Perforation depth: Measured depth: 4507' - 5577' ," ~Ir...:ti'·, ,,;;.fi': ",,~., True Vertical depth: 3275' - 3976' Tubing: (size, grade, and measured depth) 2-7/8" 6.4#, L-80 4372' Packers and SSSV (type and measured depth) SC-1 Packer(s) 4372',4526',5181' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft (] CT 3 1 2006 Beluga 5152' - 5172' Treatment descriptions including volumes used and final pressure: 20 bbls Xylene+20 bbls 10% HCI wi Acetic Pickle. 68 bbls Xylene wi 10% EGMBE Bullhead. Bullhead 24 bbls Acetic w13% HC/.Final pressure 1075psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2700 (Inj. Rate) 0 0 1925 Subsequent to operation: 0 10190 (Inj. Rate)'¡ 0 0 1480 . 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory D Development D Service 0 Daily Report of Well Operations Operation Summary 16. Well Status after work: Gas Storage / OilD Gas D WAG D GINJ D WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I ~Undry Number or N/A if C.O. Exempt: 306-201 Contact Steve Tyler Printed Name Tim Brandenburg ,# -'"I Title Drilling Manager Signature'G b ~ Phone 907263-7657 Date 10/10/2006 -- Form 10-404 Revised 04/200~ ~ 10'23""," ubmit Ori inal Only ORIGINAL ht, g ~ "- ~ IP/,b¡&~ PCU-04 Primary Job Type Other Stimulation Jobs Primary Job Type Other Stimulation Daily Operations 8/15/2006 00:00 .8/16/2006 00:00 Operations Summary MobelSpot Coil Unit and Accessory equipment. 8/16/200600:00·8/17/200600:00 Operations Summary MobelSpot Chevron Equipment. 8/17/200600:00·8/18/200600:00 Operations Summary Coil "Turnkeyed" Mobe 8/18/2006 00:00 - 8/19/2006 00:00 Operations Summary Turnkeyed Mobe 8/19/2006 00:00 - 8/20/2006 00:00 Operations Summary PUMU nozzle BHA. RIH to 5578'. CBU. Circulate 20 bbls of Xylene + 20 bbls of 10% HCI wi 5% Acetic + 10 bbls of Soda Ash + 5 bbls of 9% KCI. Circulate well dry w/1100 gals of N2. recovered 35 bbls in junk tank. POOH. Stand-back lubricator. RU slickline. RIH open middle sliding sleeve @ 5173'. POOH. RD. 8/20/2006 00:00 - 8/21/2006 00:00 Operations Summary PJSM. RIH wi CT wi wash nozzle BHA to 5165', 1st Stage - Bullhead 31 bbls of Xytene wi 10% EGMBE down CT x Tbg annulus. Pressure limitation limitated achieving displacment. Circulate fluids from well bore wi N2. Recovered 14 bbls of Xylene cocktail. Flowed well to T-Pack. 2nd Stage - Bullhead 37 bbls of Xylene w/1 0% EGMBE down CT x Tbg annulus. displace with N2. Dry well wi N-2. Recovered 6.5 bbls of cocktail. Flowed well to T -Pack. 8/21/2006 00:00 - 8/22/2006 00:00 Operations Summary Continue to attempt to flow well out of CT x Tbg annulus. POOH wI CT. Continue to flow well. wait on N2. 8/22/2006 00:00 - 8/23/2006 00:00 . Operations Summary . PJSM. RIH wi CT to 5165'. Bullhead 24 bbls 10% Acetic wI 3% HCI wi 5% NH4CL. Displace wI 9% KCI @ .3 bpm wI 1075 psi. Total pump down CT x Tbg annulus 42 bbls. Dry tbg wi N2. Flow well to T-pak. POOH wi CT. SDFN. 8/23/200600:00·8/24/200600:00 , Operations Summary PJSM. RIH wi CT. Unload well wI N2. Flow well to T-Pak on N2 Assist. POOH. Release CT on "Turnkeyed Demobe. · .etty Creek ell No.4 CASING AND TUBING DETAIL SIZE WT GRADE CONN IV TOP BTM. 1 13-3/8" Surface 120' 9-5/8" 47 L-80 Butt Surface 2,385' 7" 29 L-80 Butt Surface 6,942' Tubing 2-7/8" 6.4 L-80 Butt SC 4,372' Tight JEWELRY DETAIL spot in NO. Depth IV OD Item tubing at A Production Tubing Inner String Jewelry -1150' I 4521 2.3 13 3.170 Baker CMD sliding sleeve WLM II 4560 2.3 13 3.24 Baker "X" nipple (4/17/03) III 5173 2.313 3.17 Baker CMD sliding sleeve IV 5212 2.313 3.24 Baker "X" nipple V 5319 2.313 3.117 Baker "X" nipple VI 5576 2.313 3.17 Baker CMD sliding sleeve 5584 Bull plug - end of tubing Packers, Screens, Misc. 2 I Dual Tubing Hanger, 2-7/8" x 2-3/8", II" 5M 2 4,372' SC-I Gravel Pack Packer 3 3 4,501' Baker Weld Wire Wrapped Screen I 4 4,526' SC-I Gravel Pack Packer 4 5 5,147' Baker Weld Wire Wrapped Screen 6 5,181 ' SC-I Gravel Pack Packer II 7 5,554' Baker Weld Wire Wrapped Screen 8 5,584' K-I Retainer 9 6,862' K- I Retainer with 12 bbls cement below and 5 bbls above. Heater String A 2,517' 2·3/8", L-80, Butt SC 5 III 6 IV V 7 VI 8 9 PCU 4 Actual 05-30-06.doc PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 11/24/2001 Sterlin~ 4,507' 4,514' 7' 12 11/17/2001 Belue:3 5,152' 5,172' 20' 12 11/14/2001 Belue:3 5,566' 5,577' 11' 12 SLIDING SLEEVE mSTORY SS Depth 5/4/2002 9/21/2002 4/20/03 3/22/06 4521 closed open closed closed 5173 open open open open 5576 closed closed open? closed TD = 9,580'MDI7,600' TVD Max Hole Angle = 51 deg DRAWN BY: crw/tcb/jws AI.lASHA OIL AlWD GAS CONSERVATION COJDIISSION e / FRANK H. MURKOWS/(/, GOVERNOR / J 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 e ~iL%iŒ (ID~ L%~~~æL% TrrnothyBrandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 \~ '\ q3 ~O Re: Pretty Creek Field, Beluga Gas Storage Pool, PCU # 4 Sundry Number: 306-201 Dear Mr. Brandenburg: '"Jf;, \~, ""¡"'\ '1 1: \,,;,)V ." .. í\\.'.à.,..cn Jl)\ - J,.' ,- ~ÇA~~!''e~'-- Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may fIle with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisßday of June, 2006 Encl. ~ t{ " . Ð '11 lò\l~ Af¿ G),J-/õ6 CfÎ r;/t'iJ(f(. ~ (,/I¿/~o(, STATE OF ALASKA it;y 0 AL. OIL AND GAS CONSERVATION COM~ION RECEIVE APPLICATION FOR SUNDRY APPROVALS JUN 082006 20 MC 25.280 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Suspend Repair well 0 Pull Tubing 0 taska njl ~î3"ås Stimulate./ Time Extenxi~n Re-enter Suspended WJff . Other ns. Convnlsslon 1. Type of Request: Abandon Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: Development Stratigraphic o o Exploratory 0 Service / 0 PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 16.6' KB above Wellhead Height 8. Property Designation: Pretty Creek Unit and Preek Creek Storage Lease (ADL No. 390776) 9. Well Name and Number: PCU #4 / 10. Field/Pools(s): Pretty Creek / Beluga - Sterling 11. Total Depth MD (ft): 9580' Total Depth TVD (ft): 7566' Length PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 5584' 3979' 3979' Size MD / TVD Burst Junk (measured): none Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 4507' - 5577' / Collapse 120' 2386' 6942' 13-318" 9-5/8" 120' 2386' 6942' 120 1970 5150 3450 6870 8160 1950 4750 7020 7" Perforation Depth TVD (ft): 3275' - 3976' Tubing Size: Tubing Grade: 2-7/8" 6.4#, L-80 Packers and SSSV MD (ft): 4372',4526',5181' Tubing MD (ft): / 4372 Packers and SSSV Type: SC-1 Packers / 12. Attachments: Description Summary of Proposal Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: ./ 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: 6/5/2006 Oil 0 Gas 0 / Plugged 0 WAG 0 GINJ 0 WINJ 0 Service 0 Abandoned o o 16. Verbal Approval: Commission Representative: Date: WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 907-276-7600 Date COMMISSION USE ONLY Gas Storage Well Contact Steve Tyler 263-7627 b - F-a:- Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3o{,_ Bo Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: T~t- ISo PE fo 2.000 ýI v:. RBDMS 8Fl JUN 1 3 2006 Subsequent Form Required: ~O - 4- 0 ~ Date: t 13" ~£ Approved by: Form 10-403 Revised 07/2005 AFE XXXXXX Submit in Duplicate e e Pretty Creek #4 Workover Summary: PCU 4 is a current Gas Storage well on Cook Inlet's Westside. The well has recently declined in injection and production rates due to the build up of "gunk". The following procedure and contingencies are to clean the tubing and stimulate the matrix, and return the well to its previous rates. Operation: 1, Flow well to atmosphere (12 hrs). 2. Dump 3 drums of xylene, Soak for 24 hours (or overnight), 3. Flow well to atmosphere for 12 hours, 4. Inject gas. Contingency # 1 : Repeat above procedure with variations on the volume; soak time and production and injection sequences, Contingency #2 (Coil tubing operation): 1. MIRU Slickline. RI close sldg slve @ 5173'. 2. Pressure wellbore to 2000 psi wi gas. Monitor fl 3 hrs. Bleed pressure off. 3. MIRU/Spot CTU. Turnkey RU. RU flow-back equipment & tank(s). 4. PT BOPE. PUMU CTC & jet nozzle. Accept cru. 5. RIH to 5580' while circulating at minimum rate. CBU. Pressure test wellbore to 1500 psi fl 30 / mm. 6. Displace Pickle-Chern to nozzle. POOH @ 30 fpm while jet washing tbg wi Pickle-Chern. 7. RIH to 5580'. Open circ valve. POOH while blowing tbg dry wi N2. Trap pressure on tbg. Stand-back CTV injector head. 8. MIRV Slickline. RI open sldg slve @ 5173'. POOH. RD 9. Produce well through flow-back equipment to atmosphere for 2 hours. 10. RV CTU. RIH to 5580'. Spot stimulation chemical across upper Beluga interval. Perform matriz stimulation as directed. Blow tbg dry w/N2. POOH. Trap pressure on tbg. 11. Release CTV to turn- key Demobe. 12. Turn well over to production. / e a>retty Creek ~ell No.4 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1 13-3/8" Surface 120' 9-5/8" 47 L-80 Butt Surface 2,385' 7" 29 L-80 Butt Surface 6,942' Tubing 2-7/8" 6.4 L-80 Butt SC 4,372' ./ Tight spot in NO. Depth tubing at A ~1150' I 4521 WLM II 4560 (4/17/03) III 5173 IV 5212 V 5319 VI 5576 5584 2 I 2 4,372' / 3 3 4,501' I 4 4,526' 4 5 5,147' 6 5,181' II 7 5,554' 8 5,584' 9 6,862' 5 III 6 IV V 7 VI 8 9 PCV 4 Actual 05-30-06 ID JEWELRY DETAIL OD Item Production Tubing Inner String Jewelry Baker CMD sliding sleeve Baker "X" nipple Baker CMD sliding sleeve Baker "X" nipple Baker "X" nipple Baker CMD sliding sleeve Bull plug - end of tubing 2.313 2.313 2.313 2.313 2.313 2.313 3.170 3.24 3.17 3.24 3.117 3.17 Packers, Screens, Misc. Dual Tubing Hanger, 2-7/8" x 2-3/8",11" 5M SC-I Gravel Pack Packer Baker Weld Wire Wrapped Screen SC-I Gravel Pack Packer Baker Weld Wire Wrapped Screen SC-I Gravel Pack Packer Baker Weld Wire Wrapped Screen K -I Retainer K-I Retainer with 12 bbls cement below and 5 bbls above. A Heater String 2-3/8", L-80, Butt SC 2,517' PERFORATION HISTORY Interval I Accum. -Date Zone Top Btm Amt spf Comments 11/24/2001 Sterlin~ 4,507' 4,514' I 7' 12 11/17/2001 Belu~a 5,152' 5,172' í 20' 12 11/14/2001 í Belu~a 5,566' 5,577' i 11' 12 I i ._"."...~ , SLIDING SLEEVE mSTORY I I SS Depth 5/4/2002 9/21/2002 4/20/03 3/22/06 T 4521 closed open closed closed I 5173 open open open open 5576 closed closed open? closed I L I ~~.- L TD = 9,580'MD/7,600'TVD Max Hole Angle = 51 deg DRAWN BY: crw/tcb/jws . rage 1 01 1 . Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp@chevron.com] Sent: Thursday, June 08, 2006 8: 18 AM To: Thomas Maunder Subject: RE: 2006 May's PCU #4 Storage Well Monitoring Report ~ ~ ~(j \ - \<\ ~ Only injection so far... not enough pressure built up in the well to produce back into the Enstar system yet From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, June OS, 2006 8:04 AM To: Greenstein, Larry P Cc: Jim Regg SUbject: Re: 2006 May's PCU #4 Storage Well Monitoring Report "-, +O~stc 0.. 0+~t'\""ú:'J ~"l s \ a ~ Thanks Larry, Has there been any production out ofPCU #4 or just injection? Tom Greenstein, Larry P wrote, On 6/612006 4:34 PM: ~¡CANNED SEP 1 12007 Hi Tom & Jim, Here is May'smoothly report for the wells requiring pressure monitoring in the PCU #4 Storage reservoir. The PCU # 2 welf has been shut-in for some time and is being used to monitor injection zone isolation: The gas injection into PCU #4 has been stopped for a while due to low ínjectivity. We are looking into ways to improve the injectivityinto tile well. The pressure monitoring doesn't show any indication of annulus communication. Bottom line, I don't see any indication that the storage gas is not being contained in the approved storage area. Larry «Master Well List Wavered Well Report May 2006.xls» . -~ '" ,-\' - ·o~ ~. _<C . ~ç''''- 8/1/2007 MEMORANDUM e e State of Alaska Alaska Oil and Gas Conservation Commission TO: ~~ S~:;~isor !<c4¡t[ ir/ t tj Ð~ DATE: Thursday, April 06, 2006 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 4 PRETTY CK UNIT 4 Src: Inspector ').ù \ ~ \ C\-:? Reviewed By: P.I. Suprv :Jþe-- Comm FROM: Lou Grimaldi Petroleum Inspector Well Name: PRETTY CK UNIT 4 API Well Number 50-283-20100-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG060324 I 05712 Permit Number: 201-193-0 Inspection Date: 3/24/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 4 ¡Type Inj. G I TVD I 3272 I IA I 0 I 1730 ¡ 1700 I 1680 I 1670 I I P.T. I 2011930 ITypeTest SPT I Test psi I 818 ! OA ! 0 0 ¡ 0 ¡ 0 I 0 I I I I Interval INITAL P/F P Tubing I 1100 ! 1100 I 1100 I 1100 I 1100 I i Notes Initial MIT on gas storage well. NON-CONFIDENTIAL I ~\ ~ Thursday, April 06, 2006 Page I of I e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicl1e\CvrPgs _lnserts\Microfilm _ Marker.doc ) ) Chevron .. Jeff w. Smetanka Reservoir Engineer Union Oil Company of California P.O, Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7622 Fax 907 263 7847 Email smetankaj@chevron.com ~Ol- Iq3 February 10, 2006 RECEIVED \t"ì' f1r'lC\1 1 4 i.GOB stANNE\LJ I Lt). " Mr. Tom Maunder FE8 I ~1 íOO' Alaska Oil and Gas Conservation Commission" b 333 W. ih Avenue, Suite 1 ~aska m¡ & Gas Cons. rl-'r71mission Anchorage, AK 99501-3539 Anchorage PCU #4, PRETTY CREEK FIELD REPORT ON CONVERSION TO STORAGE SERVICE Dear Mr. Maunder: Attached is a Form 10-404 Report on Sundry Well Operations for converting well PCU #4 to gas storage service, as authorized by the Commission and related to Storage Injection Order No.4. Union Oil Company of California, as Operator, commenced storage operations into the well on November 15, 2005. The well is currently idle due to the winter gas supply/demand balance. Note that this was a change of service authorization only and that no mechanical changes to the wellbore were made. If you have any questions, please contact me at 263-7622. Jeff W. Smetanka cc: Dave Whitacre Larry Greenstein Union Oil Company of California / A Chevron Company http://www.chevron.com t( r:: \J 1::.1 V ......., STATE OF ALASKA , ALP ')\ OIL AND GAS CONSERVATION COM I ):>ION FEB 1 3 2006 REPORT OF SUNDRY WELL OPERA TIONSAlaska on & Gas Cons. commission .. 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other l{ ' 'Conve-rt to Storage Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension D Eft. Date 11/15/05 Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: Union Oil Company of California Development D Exploratory D 201-193 3. Address: Stratigraphic D Service [2] 6. API Number: PO Box 196247, Anchorage, AK 99519 50-283-20100-00 7. KB Elevation (ft): 9. Well Name and Number: 100' KB above MSL PCU #4 8, Property Designation: 10. Field/Pool(s): Pretty Creek Unit and Pretty Creek Storage Lease (ADL No. 390776) Pretty Creek I Beluga-Sterling 11. Present Well Condition Summary: Total Depth measured 9580 feet Plugs (measured) 5584 true vertical 7566 feet Junk (measured) none Effective Depth measured 5584 feet true vertical 3979 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 120 13 3/8" 120 120 3450 1950 I ntermed iate 2386 95/8" 2386 1970 6870 4750 Production 6942 7" 6942 5105 8160 7020 Liner Perforation depth: Measured depth: 5152' True Vertical depth: 3679 Tubing: (size, grade, and measured depth) 2 7/8" 6.4# L-80 4372' Packers and SSSV (type and measured depth) SC-1 Packers 4372',4526',5181' 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: RBDMS BFl FEe .1 4: 2006 NIA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 250 Subsequent to operation: 0 9190 0 0 1320 14, Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development D Service [2] Daily Report of Well Operations 16. Well Status after proposed work: Gas Storage OilD Gas D WAG D GINJ [2] WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¡SUndry Number or NIA if C.O. Exempt: 305-301 Contact Jeff Smetanka 263-7622 Printed Name Jeff Smetanka /') Title Reservoir Engineer ~ n ~ ' ,1Á. J Phone 263-7622 Date z./\a lob Signature ~ .. ~ " " .. - Form 1 O-~Revis~ 04/2004 Submit Original Only OR\G\NAL TO P.l ---..". OCT-06-2005 13:27 FROM: """,ì iII;n, I¡"..,':_!;"....."."." ..,.-,.,~,';, ~~' \Ìr.~"I,~'W.:!I. ,'f(I'.~: .1.:' :, ~,""'~ ''I' \..01,. ~"\:"I"b.,,, ~ ~. '\^ \ ~1IfIr( \~}. (PI:" '\ 1\ "',' I,"~).~' . ^ ,'" : ~I.:\(..:~"'" :~"~,, .p..'t.....,', t,. ).: ': I, . ~,,,,\ " '" ".- .\. . lit"" "': '. .. ~""''''''' ' .. -, .., .... ....~ \¡:,,~-4.~,,~.;.. '. I .~.,.. -: ....".~."'t " ~ ry 20,0.5 : : , . ;Wd\¡9" ":'; .. y;")n '\, ""'··~I··.I\\" '~'\" .,.~;.X>. ~. ~\\ '.. " :., II . ~ \'1' -, ~ -'.'~' . .... 'I! ,II ~, 1\, ~, I, '" ... ., ,. '4"" A:~." O~I&, G'ti6, c:;.X~:¡ :::~:aQ~'\-';;.~:.:\;....~, Ai,,:(~~ ')r~.~' e e (~o I· / q 3 Subject: Re: Planning for SRF and NNA 2006 MITs . From: James Regg <jimJegg@admin,state.ak.us> '"""Î /).11' ZV""-;II U'O«) \~k:t:'(1 Date: Wed, 08 Feh 2006 14:07:29 -0900. .. . .. . 1':o:"tGreenstein, Larry}>" <greèi1steinlp@unocátcQm>.' .'. "':.,,:.:. Co.: Winton GAubert'<:winton.:.:.atlbert@admin.state.<ak.us>, Tom Maunder <tom~.}1J.å\.1nder@a<hWI'l.state';åk:';t1s>' . This email documents our conversation 2/2/2006 and provides guidance regarding the required mechanical integrity determinations for the wells listed below. NNA #1 In accordance with DIO 28A (Rule 5), we would like to see another temperature survey with wellbore conditions replicating to the extent feasible those of the post-injection start temp survey done 12-31-04. Also, the MIT due this year (December 2006) should be performed with the 1A pressure dropped to 500 psi below the tubing pressure and monitored for 30 minutes, This test coupled with the imposed pressure for back-up purposes (no apparent communication from no pressure plots I reviewed) will confirm tubing integrity. SRF 213-10 CO 474 orders Unocal to demonstrate mechanical integrity annually, This does not specifically require the demonstration to be a conventional pressure test (MIT). One way this requirement can be satisfied is the monitored and reported annuli pressures as required in the Order ("Each annuli pressure must be monitored daily and reported to the Commission quarterly."). In addition, before restarting production in Well 213 -l 0, U nocal will be required to perform a pressure test to demonstrate wellbore integrity. Long Term Shut In Injectors Based on our conversation, there are 6-8 injectors that fall into this category. You have suggested doing a low pressure MIT as a way to confirm integrity while the well is shut in. Commission's current thought is that no MIT is necesssary for a well that would be categorized "long term shut in" (no intent to inject in the well in foreseeable future). In lieu of an MIT, periodically sending a T10 plot would provide information to determine any developing problems with the well. Regulations at 20 AAC 25.115 require you to address these S1 wells annually (due 3/31); the injection orders include provisions for monitoring and notification if leakage or pressure communication is identified. Before restarting injection in any ofthese wells, Unocal will be required to demonstrate mechanical integrity (could include temp survey, MIT, other type of demonstration). pev #4 Strategy outlined in your message regarding PCU #4 is appropriate. You have satisfied the requirements of our regulations by performing the pre-injection MIT 1 0/25/2005. A Commission inspector should witness the M1T after restarting storage injection and the well's performance has stabilized; you can coordinate scheduling such a test with me. MIT Due Dates We did not talk about this subject but clarification is appropriate based on recent discussions with other operators and within the Commission regarding scheduling MITs. Mechanical integrity determinations are due on or before the anniversary date. The Commission must approve an extension to go beyond the due date. 10f2 2/8/20062:07 PM Ke: 1'1annmg tor ~Kt and NNA LUUó MIl S . e e For Admininstrative Approvals (well integrity, alternate demonstration of mechanical integrity), we are using the admin approval date to establish when the next mechanical integrity demonstration is due. Jim Regg AOGCC Greenstein, Larry P wrote: Tom/Jim, When you get a chance, could you call me (263-7661) to talk about a couple of MITs that will be coming up this year. They may be a little out of the ordinary depending how you define the MIT. NNA #1 (PTD #201-215)- calls for an MIT this year (every two years). We are constantly doing an MIT based on the backpressure held in the annulus (see previous letters in file). The backpressure could be altered for an inspector to verify integrity, if so desired. With the 'high set packer' in this well, we need to come to some agreement as to how to perform this MIT. Temp logs with test injection periods were used for the initial MIT on this well. SRF 213-10 (PTD #202-118) - called for an MIT last year (every year). This 31/2" monobore gas production well is not in use. We were originally considering converting this well into a gas storage well (with modifications to create a monitorable annulus), but decided against this. The well has remained shut-in and water appears to have entered the well bore (based on a wellhead pressure increase). Nothing is planned for this well in 2006 also. If we were to do something (recomplete uphole??) we would be able to do a pressure test MIT at that time. There is nothing in the budget, so I don't know if leaving this shut-in gas well idled until such time as we decide what to do next is adequate to meet the annual MIT requirements for an 'active gas well'. There is an uphole profile that would allow at least a fairly deep pressure test to be performed while it is in its idled condition. As usual, I would still like some time to discuss low pressure MITs with you as we still have a backlog of 6-8 wells pending your decision. On a shut-in well, I believe the normal 'operating condition' (ie shut-in) would allow a low pressure MIT to have validity. Let's discuss whenever you can. Also, I would like to inform you that we were unable to obtain the follow-up MIT on PCU #4 (PTD #201-193) gas storage well. Just about the time we had achieved a consistent stabilized gas injection (Xmas time after the injection compressor started up), the weather started getting real cold and all injection was stopped in this well. Prior to this time, the well was injecting using only the varying line pressure off the Enstar 20" line and the injection rates were all over the place. The best guess is that we will not start injection back up in PCU #4 until March at the earliest. We do have the successful pre-injection MIT and will plan on doing the follow-up MIT after injection stabilizes upon restarting injection this spring. Hope this is meets with your approval. Thanks for you time. Larry 2of2 2/8/20062:07 PM e e FRANK H. MURKOWSKI, GOVERNOR AI.ASHA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 JeffW. Smetanka Reservoir Engineer Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 , ~lJ1. ,;~ .,~"""T- '1. ' Re: Pretty Creek Unit #4 Sundry Number: 305-301 , r '\t 'ìr.pï:- SCI\NNElJ NOV t) c)J ,-V,,;j Dear Mr. Smetanka: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED fuiSi day of October, 2005 Encl. e Unocal Alaska - Union Oil Company of CaliforrP 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7622; Fax (907) 263-7847 UNOCALe September 30, 2005 Ii>~c~ At..... S£p lV~D ~Q;- 3 0 ,~ 2005 ~ ~Ca VJ]/lJ" Jeff w. Smetanka Consulting Reservoir Engineer Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. ih Avenue, Suite 100 Anchorage, AK 99501-3539 PCU #4, PRETTY CREEK FIELD SUNDRY FOR CONVERSION TO STORAGE SERVICE Dear Mr. Maunder: Attached is a Form 10-403 Application for Sundry Approval to convert well PCU #4 to gas storage service, pursuant to the initiation of gas storage operations, as authorized by the Commission in Storage Injection Order No.4. Union Oil Company of California, as Operator, intends to commence storage operations into the well as early as October 5, 2005, provided that all requirements noted in the order have been met. Note that this is a change of service authorization only and that no mechanical changes to the wellbore will be made. Also attached for your reference is a schematic showing the current configuration of the well and a process flow diagram that shows both Unocal's and Enstar's new metering points. If you have any questions, please contact me at 263-7622. JWS:dma Attachment cc: Dave Whitacre Larry Greenstein L 1. Type of Request: STATE OF ALASKA _ AL. OIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Suspend Repair well 0 Pull Tubing 0 Development Stratigraphic PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 100' KB above MSL 8. Property Designation: Pretty Creek Unit and Pretty Creek Storage Lease (ADL No. 390776) 11. Abandon Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: Total Depth MD (ft): 9580' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 5152' Packers and SSSV Type: SC-1 Packers Time Extension o o Exploratory 0 o Service 9. Well Name and Number: Pretty Creek Unit #4 10. Field/Pools(s): Pretty Creek o Mechanical Integrity Test ~ Total Depth TVD (ft): 7566' Length Size Plugs (measured): 5584' Junk (measured): NA Collapse 120' 2386' 6942' 13-3/8" 68# J55 9-5/8" 47# L80 7" 29# L80 Burst 3450 6870 8160 1950 4750 7020 Perforation Depth TVD (ft): 3679 Tubing Grade: 6.4# L80 Tubing MD (ft): 4372' Packers and SSSV MD (ft): 4372',4526',5181' COMMISSIONER Form 10-403 Revised 11/2004 AFE XXXXXX 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/5/2005 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: ~ e ~7YV\. \C { 17. I hereby certify that the foregoing is true a cor. ect to the best of my knowledge. Contact Printed Name tanka Title Reservoir Engineer Phone 907-276-7622 Date COMMISSION USE ONLY 9/28/2005 Sundry Number: Conditions of approval: Plug Integrity Other: Location Clearance 0 RECEIVED Sfp 3 Nasta . 0 2005 Oil & Gas Co ~"_L 08. Corn . APPROVED BY ·..,Iti11Drage mISsion THE COMMISSION Date: rì \ . f~ L l-\ Submit in Duplicate OCT-03-2005 MON 08:35 AM _uo____..__.__ '. . e FAX NO, e Unocal Alaska union Oil Company of California 909 West 9to Avenue, P.O. Box 196247 AnChorage, Alaska 99519-6247 Telephone (907) 263-7622; Fax (907) 263-7847 UNOCALe JeffW. Smetanka Consulting Re~¡;Noir Englne¡;r October 3, 2005 p, 02 o \1,"'* & GiG Gì..;'!I8,))_~_tì Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501-3539 I , PCU #4, PRETTY CREEK FIELD ~ SUNDRY FOR CONVERSION TO STORAGE SERVICE ~ ~ Dear Mr. Maunder: Attached is a replacement Form 10-403 Application for Sundry Approval to conve to gas storage service, Sundry Number 305-301, The application submitted on ovember was on Form 10-403 Revision 11/2004, The form for this submittal is Revision 07 005. ease replace the originally submitted Form with this one. Please contact me at 263-7622 if you have any questions on thiS. JWS:dma Attachment cc: Dave Whitacre Larry Greenstein ._OCT-_º3~200~..MON 08:35 AM e FAX NO, ~)~-4)~ f'{E~(; STATE OF ALASKA ()/S lö \;3 ( r" ALASKA OIL AND GAS CONSERVATION COMMISSION \'2:> APPLICATION FOR SUNDRY APPROVALS I··'"¡~.·.·;;~~ I·~-J'. ~.f r~ , ,,} ~~~.,^ , \0\7 1. Type of Request: Suspend U Repair well D Pull Tubing D 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4, Current Well Class: Development [2] Stratigraphic 0 ...~ ().f,1 , Giß (:.;:4ìi. Perforate TI Waiver LJ4,;~:::~')t~'r Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number; Other L:j Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. AddreS$: PO Sox 196247. Anchorage, AK 99519 7. KB Elevation (ft): 9. Wen Name and Number: 100' K6 above MSL. Pretty Creek Unit #4 8. Property Designation: 10. Field/Pools(s); Pretty Creek Unit and Pretty Creek Storage Lease (ADL No. 390776) Pretty Creek 11, PRESENT WELL CONDITION SUMMARY Total Depth MO (It): ITotal Depth NO (ft): ¡Effective Depth MD (ft); Effective Depth TVD (ft): rPIUgS (measured): 9580' 7566' I 5584' 3979' 5584' Casing L$ogth Size MC TVD Struotur<ll Exploratory 0 Service 0 201-193 6. API Number: 50-283-20100 ¡Junk (measured): I NA Collapse Burst Condl,¡ctor SI.IrfaG8 120' 13-3/8" 68# J55 120' 120' 3450 1950 Intermediate 2386' 9·5/8" 47# L80 2386' 1970' 6870 4750 Prodl.lction 6942' 7" 29# L80 6942' 5105' 8160 7020 Liner Perforation Depth MD (ft): 5152' Packers and SSSV Type: SC-1 Packers rTUbing Size: rTI.IÞing Grade; 2-7/8" 6.4# L80 Packers and SSSV MD (ft): 4372'.4526',5181' 13. Wen Class after proposed wor (: Exploratory D Development 0 15. Well Status after proposed work: 10/5/2005 Oil 0 Gas 0 Plugged 0 Abandoned WAG 0 GINJ 0 WINJ 0 WOSPL ~~~~·~~~£W 17. I hereby cartify that the foregoing is true and correct to the best of my knowledge. Contõlct ~ t"30 -O'So Printed Name .. Jeff W. Smßtanka (J Title Re5ervolr Engineer Signature I')U ......6. .À Phone 907-263-76.22 Date \ \ , ...., COMMISSION USE ONLY I Perforation Depth TVD (ft); I 3679 ¡-Tubing MD (ft): 4372' 12. Attachment$: Desoription Summary of Proposal U Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Service 0 Commencing Operations; 16. Verbal Approval: Commission Representative; Date: D o 1013/2005 CQnditions of approval; Notify Commission so that II representative may witness SUndry Number: 305-301 Mechanical Integrity Test ~ Location Clearance D Other: O~~\~~O\,,~-..)~\-'''' \\~s..J'o~\~ ~~.~~ \>t\a\-\G \~r~\t.1.~~~ \"\~~~"'" ~~c;.~SJ \J\\.\~~~a.~~~ (;L.\-<J. \~~\ÐQte. Su""'''''''/7;:' , RBDMS BFL OCT 05101J5 l / _~ APPROvED BY Approved bYI / COMMISSIONER THE COMMISSION Pll,¡g Integrity 0 BOP Test 0 ~~ '- =--- -, --.., -, _o,,~ ~~£ Form 10-403 Revised 07/200~ ORIGINAL Submit in Dl,¡plicate e _retty Creek Well No.4 Actual 05/05/04 Tight spot in NO. Depth tubing at A ~1150' I 4521 WLM II 4560 (4/17/03) III 5173 IV 5212 V 5319 VI 5576 5581 2 1 2 4,372' 3 3 4,501 ' I 4 4,526' 4 5 5,147' 6 5,181 ' II 7 5,554' 8 5,584' 9 6,862' 1 5 6 IV V 7 VI 8 9 PCU 4 Actual 05-05-04 III SIZE WT 13-3/8" 9-5/8" 47 7" 29 Tubing 2-7/8" 6.4 2-3/8" 4.6 CASING AND TUBING DETAIL GRADE CONN ill BTM. 75' 2,398' 6,941' TOP Surface Surface Surface L-80 Butt L-80 Butt L-80 Butt SC L-80 Butt SC 4,372' 2,517' JEWELRY DETAIL ill OD Item Production Tubing Inner String Jewelry 2.313 3.170 Baker CMD sliding sleeve 2.313 3.24 Baker "X" nipple 2.313 3.17 Baker CMD sliding sleeve 2.313 3.24 Baker ")C' nipple 2.313 3.117 Baker "X" nipple 2.313 3.17 Baker CMD sliding sleeve Bull plug - end of tubing Packers, Screens, Misc. Dual Tubing Hanger, 2-7/8" x 2-3/8", 11" 5M SC-1 Gravel Pack Packer Baker Weld Wire Wrapped Screen SC-1 Gravel Pack Packer Baker Weld Wire Wrapped Screen SC-1 Gravel Pack Packer Baker Weld Wire Wrapped Screen K-1 Retainer K-1 Retainer with 12 bb1s cement below and 5 bbls above. A Heater String 2-3/8", L-80, Butt SC 2,517' PERFORATION HISTORY Interval Accurn. Date Zone Top Btm Amt spf Comments 11/14/2001 Sterlin2 4,507' 4,514' 7' 12 11/17/2001 Belu2a 5,152' 5,172' 20' 12 11/24/2001 Belu2a 5,566' 5,577' 11' 12 SLIDING SLEEVE HISTORY SS Depth 5/4/2002 9/21/2002 4/30/03 4/9/04 4521 closed open open open 5173 open open open? closed 5576 closed closed open closed TD = 9,502'MD/7,600' TVD Max Hole Angle = 51 deg DRAWN BY: tcb/jws ------¡ ------ I I , -I ~ I I I I I FNSTAR AI DIRECTIONAL I MFTFRrClJSTO,DY TRANSFER) ¡-if I I ~ METER I I I I ~ Illir I ENSTAR M~ER MODULE I I Mm. I LD~YD~ UNOCA' MFTFR MODU' E _ _ _ ---.J I I I I PRODUCTION COMPRESSOR .MQQlli GL yeOI RFAOIl ER I /'--"\ [;1 vcm PUMP I I I I I I I " n L.J LJ ~ ílll I I I I I I I PCU-2 ëÃSWlli 5000 GALLON ~ COMPRFSSOR .MQQlli I -.J = ÐiMf' = HßIEB I L ~ "" WEU. 00 PRODUCED WATFR STORAGF TANK PRETTY CREEK COOK INLET ALASKA PROCESS FLOW DIAGRAM ;~~2õå1 ISHÓÖ~ CHEVRON NU_DO ",." DIFSFl . EXPANSION ~ R~V 1:;;1 :;:~E~PAOV~ 1IQJES¡ OWG. NUMBER ISHTI REFERENCE DRAWINGS 3 ) J).LL- DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 J-¡wJ.. I ~ ~~ API No. 50-283-20100-00-00 UNION OIL CO OF CALIFORNIA Operator Well Name/No. PRETTY CK UNIT 4 2011930 Permit to Dri N UIC 1-GAS Current Status 1-GAS Completion Status / 11/30/2001 Completion Date ./ 7566 ND ..----- 9580 MD REQUIRED INFORMATION N&- \of ~( Master Well Data Maint Directional Survey (data taken from Logs Portion of No Samples No Mud Log DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: '~-1 OH CH Interval Start Stop Run No Log Media Log Scale Electr Dataset Number Digital Med/Frmt Log/ Data Type Comments Received Name Comments Sample Set Number 1062 Received Sent Interval Stop 9580 Start 200 Well Cores/Samples Information: Name Cuttings ©/N ~/N ADDITIONAL INFORMATION Well Cored? Y ® Daily History Received? Formation Tops C" Y/N - ....::u..w-- Chips Received? -. I~ )(\ ~ {~ a-- ß t¿ v j.J..~,r~~ t-w l~ - G rZ..J ~ /fJc.v-(IJ.U'\> ~""-- c... 1"3 ìll..4..J I ì ft........___ Analysis Received? Comments: ~~~j , q}~ 't ~ 't ! ''I ~ç-g\J C J'" ~ ~ ~>C~ - ~Jù~ - g })'""b ~ .... g )'O\:) - r-.. Date: \., \) ¡~~.~ ~ M \) 11 L- Vh·I^,-~~) Ì1I D ß ~ \j: )~~ ~tv\~ ¡VIr) a-t \J{~~~..... l)~'t"Ij ¡-VI) q) l,.. \J(>~.a",- ~~~ rJI)) DL.. \}l ~ ~t'.. ~~ tv J> F.) ~ , \ ~;t-r- / r It n..~. I~ Compliance Reviewed By: Né 'f-~ VZ f) D M-J, ~ ~~~ î,^-¿v'~l ù -- /IJJ~~( fà.»r...ç; I ~.~. ((IE xj r> l ? Fit e ~ V"'~IoL\." "- ~ )..v'J 11ft. v ~~ , ;jl-. i- I=...l~ C. b __r,~"t.j ~ - ~ 1 ì 1J\" ^h \. ~ ,--.$ h'-[ ~ ßl- ß,L (' !( Date: OS/29/02 To: File From: Sam A. Darkwah Subject: Buildup Analysis for Sands within PCU #4 Gas Well and Deliverability Forecast Purpose: The purposes of conducting the surveys are to update reserves with new reservoir pressure and determine the deliverability potential of the well and/or individual sands with and without compression. Survey Date(s): The surveys were conducted from the last week of April to middle of May 2002. Survey Procedure: The procedures used to conduct the surveys are attached to this report. Sliding sleeves were shifted to allow the individual sands to be tested separately. ,Beluga Sand 5566 - 5577 This was the first zone to be tested. The sleeve at 5579' was opened while the other two at 5176' and 4524' were closed to allow production from the lower Beluga sand. After lowering tubing pressure to 800 psig and the zone did not produce any gas, we proceeded to test the next zone. Sterling Sand 4507 - 4514 This was the next zone to be tested after the lower Beluga sand. As shown in the attached four point and pressure buildup analyses, the zone produced dry gas @ approximately 3.22 mmcfd for 4 days (May 26 - 29, 2002) and was shut in subsequently for 72-hour pressure buildup. The buildup was followed by a 24- hour four-point test which has been analyzed and attached to this 'report. Beluga Sand 5152 - 5172 This zone was tested last. It produced dry gas @ an average rate of 3.75 mmcfd for 4 days (May 4 - 7, 2002) and was shut in for 72-hour pressure buildup which PCU #4_PBU_May 2002.doc ( ( was followed by the attached, analyzed, 24-hour four-point test for sand 5152 - 5172. Survey Results: The Table below summarizes the results from the surveys. Additional details can be found in the attached WEM and PANSYSTEM files. Zone Dates Gauge K, KH, C, n AOF, p* @ COMMENTS Depth md rod-it mmcf/psi ^2 mmcf Midperf, pSla 4507 - 4/26/02 - Surface 118 826 2. llE-6 1 9 1271 Homogeneous 4514 5/3/02 Reservoir 5152- 5/4/02 - Surface 82 1638 1.0E-5 0.98 14 1300 Multi-layer 5172 510/02 Reservoir Discussion The four point and buildup survey results from the individual sands in PCU #4 were used to forecast future deliverability using a multi-layer reservoir model in WEM. Results from the WEM runs shows that the well may produce briefly (approximately one month) at rates as high as 7 mmcfd after which compression will be necessary in order to keep the well producing at 7 mmcfd or slightly less(see attached deliverability prediction sheet for more details). Assuming a compressor intake pressure of 200 psi, approximately 1 bef of gas can be produced (or a total cumulative gas production of 1.9 bcf) before abandonment at approximately 300 psi reservoir pressure. PCD #4_PBU_May 2002.doc UNOCAL@) -...."'-A 1 , , , ' ,. I A , , 'I , i . ; ",! 2 3 4 " " j' j \ ;j : ;¡ , ;¡ , 'I , r : ~ 5 6 7 8 : ~ 9 PCU 4 Actualll-29-01.doc (' ... Pretty Creek ( 'ell No.4 Áctualll/29/01 --- CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" Surface 75' 9-5/8" 47 L-80 Butt Surface 2,398' 7" 29 L-80 Butt Surface 6,941' Tubing 2-7/8" 6.4 L-80 Butt SC 4,372' 2-3/8" 4.6 L-80 Butt SC 2,51 7' NO. Dcpth ID I 2 4,372' 3 4,501' 4 4,526' 5 5,147' 6 5,181' 7 5,554' 8 5,584' 9 6 862' , , , JEWELRY DETAIL 00 Item Dual Tubing Hanger, 2-7/8" x 2-3/8", 11" 5M SC-I Gravel Pack Packer Baker Weld Wire Wrapped Screen SC-l Gravel Pack Packer Baker Weld Wire Wrapped Screen SC-l Gravel Pack Packer Baker Weld Wire Wrapped Screen K-l Retainer K-l Retainer with 12 bbls cement below and 5 bbls above. A 2,517' Heater String 2-3/8", L-80, Butt SC PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 11/14/01 Sterlin2 4,507' 4,514' 7' 12 11/17/01 Belu2a 5,152' 5,172' 20' 12 11/24/01 Belu2a 5,566' 5,577' 11' 12 Sliding Sleeves 4524 5176 5579 -.... --- TD = 9,502'MD/7,600'TVD Max Hole Angle = 51 deg DRAWN BY: tcb PCU #4 paz 2400 1 2200 ~-----------------------------~------------------------------------------------------------------------- 2000 +-~-----------------------]5~io2[~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ 1800 ~-------~------------------ 1600 uuuu__u_----~u_--u_u--u_~uuu--u_u-----uuu_uuuu_u_u__uu--_u_--u__u 1400 ------------------- ---------------------------------------------------------------------------------- " ----- - --- ~ ---------- !!:. 1200 -+- - - - - - - - N 0 a.. I Abandonment without compression I --------------------------------------------------------------- 1000 --------------------------------------------------------------------- 800 -+---------------------------------a---- ---------------------------------------------------------------- 600 ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - I - - - - - - - - - -'-- - - - - - - - - - - - - - - - - L J Abandonment with compression I ---------------------- 400-+--------------------------------- 200 ~--------------------------------.-------------------~-------------------------------------------------- 0 0 1 2 2.5 BCF 3 3.5 4 4.5 1.5 0.5 -- --~ 5 ~. ( Report Name Tbg String Time Period Date Created Gas Well Status PCU -4 Last Year 5/15/02 Rate Casing Tubing Outer Casing Date Meter Num Status Hours (mscf/d) Press Press Press 5/15/02 2 24 0 1170 5/14/02 2 24 0 1170 5/13/02 2 24 0 1170 5/12/02 2 20 820 918 5/11/02 2 18 3060 918 5/10/02 2 0 0 1155 5/9/02 2 24 0 1155 5/8/02 2 24 1320 1155 5/7/02 2 24 3970 995 5/6/02 2 24 4020 997 5/5/02 2 24 405.0. 970 5/4/02 2 22 3690 984 5/3/02 2 18 2510 835 5/2/02 2 0 0 1072 5/1/02 2 0 0 1072 4/30/02 2 12 1600 1130 4/29/02 2 24 3190 908 4/28/02 2 24 3220 912 4/27/02 2 24 3220 912 4/26/02 2 20 3010 905 4/25/02 2 6 1730 870 4/24/02 2 24 6920 870 4/23/02 2 24 7030 870 4/22/02 2 24 6700 880 4/21/02 2 24 6920 890 4/20/02 2 24 6810 920 4/19/02 2 24 6780 920 4/18/02 2 . 24 6780 920 ,. ... 4/'17/02 2 24 6810 9'" .ill 4/16/02 2 24 6540 960 4/15/02 2 0 0 1160 4/14/02 2 24 6810 900 4/13/02 2 24 6970 900 4/12/02 2 24 6970 900 4/11/02 2 24 6920 940 4/10/02 2 24 6890 940 4/9/02 2 24 6650 940 4/8/02 2 24 6810 925 4/7/02 2 24 6730 925 4/6/02 2 24 6810 930 4/5/02 2 24 6870 930 4/4/02 2 24 6690 930 4/3/02 2 24 6920 930 . 4/2/02 2 24 6950 930 f 'le ~\ 4/1/02 2 24 6950 930 3/31/02 2 24 7030 930 3/30/02 2 24 6870 930 3/29/02 2 24 6920 945 3/28/02 2 24 6920 945 3/27/02 2 24 6920 945 3/26/02 2 24 6920 950 3/25/02 2 24 6970 965 3/24/02 2 24 6940 965 3/23/02 2 24 7170 965 3/22/02 2 ' 24 7060 965 3/21/02 2 24 7080 965 3/20/02 2 24 6860 965 3/19/02 2 24 7080 975 3/18/02 2 24 7190 975 3/17/02. 2 24 7140 985 3/16/02 2 24 7250 985 3/15/02 2 24 7140 985 3/14/02. 2 . 24 7300 970 3/13/02 2 24 7080 970 3/12/02 2 24 7250 970 3/11/02 2 24 7410 940 3/10/02 2 24 7620 940 3/9/02 2 24 7300 950 3/8/02 2 24 7470 950 3/7/02 2 24 7550 950 3/6/02 2 24 7680 950 3/5/02 2 24 7470 950 3/4/02 2 24 7500 950 3/3/02 2 24 7580 950 3/2/02 2 24 7450 950 3/1/02 2 24 7740 950. 2/28/02 2 24 7500 960 2/27/02 2 24 7500 2250 2/26/02 2 . .'."'. . .7660 . 960 ¿,"-J 2/25/02 2 24 7720 960 2/24/02 2 24 7620 950 2/23/02 2 24 7240 990 2/22/02 2 24 7920 1000 2/21 /02 2 24 7560 965 2/20/02 2 24 7580 970 2/19/02 2 24 7740 975 2/18/02 2 24 7820 975 2/17/02 2 24 7730 . 975 2/16/02 2 24 7740 975 2/15/02 2 24 7740 975 2/14/02 2 24 7680 960 2/13/02 2 24 7700 960 2/12/02 2 24 7250 970 2/11 /02 2 24 7100 975 (' ( 2/10/02 2 24 6890 980 2/9/02 2 24 7170 970 2/8/02 2 24 7250 980 2/7 /02 2 24 7170 980 2/6/02 2 24 7230 975 2/5/02 2 24 6640 1030 2/4/02 2 10 , 2770 1030 2/3/02 2 0 0 1224 2/2/02 2 8 2240 1224 2/1/02 2 24 6540 1030 1 /31 /02 2 24 6220 1080 1/30/02 2 24 6170 1080 1/29/02 2 24 5850 1150 1/28/02 2 24 5960 1145 1/27/02 2 24 5960 1140 1/26/02 2 24 6041 1135 1/25/02 2 24 6010 1135 1/24/02 2 24 6140 1135 1/23/02 2 24 6190 1130 1/22/02 2 24 6370 1120 1/21/02 2 24 6480 1135 1/20/02 2 24 6220 1135 1/19/02 2 24- 6040 1135 1/18/02 2 24 6040 1135 1/17/02 2 24 5990 1150 1/16/02 2 24 6040 1140 1/15/02 2 24 6090 1160 1/14/02 2 24 6040 1085 1/13/02 2 24 6050 1085 1/12/02 2 24 6160 1110 1/11 /02 2 24 6180 1120 1/1 0/02 2 24 6240 1105 1/9/02 2 24 6170 1095 1/8/02 2 24 6190 1095 1/7/02 . 2".'" ."..,. 24 '6270 1120 1/6/02 2 24 5990 1120 1/5/02 2 24 5990 1110 1/4/02 2 24 6150 1098 1/3/02 2 24 5470 1068 1/2/02 2 24 5350 1100 1 / 1/02 2 24 5440 1110 12/31/01 2 24 5070 1140 12/30/01 2 24 5070 1160 12/29/01 2 24 4080 1260 12/28/01 2 20 4690 1200 12/27/01 2 24 5450 1150 12/26/01 2 24 5360 1250 12/25/01 2 24 5360 1220 12/24/01 2 24 5060 1170 12/23/01 2 24 4810 1170 12/22/01 2 ( 24 J 4330 I ( I 1260 I -' . . , . . . . ~" ."",' ,"'i. PCU 4 Production graph Pretty Creek 4 Rate (mscf/d) - - -- - - Pipeline Pressure . Tubing Press 10000 m_______,T Tn__-__------------ ----------------- ------------------~~ T---------------- c c.. u.. (.) :ž :æ 100 ~~~~~~~~"~~~~~,~~~~~~,~~~~##~ $~#~~~~~~ø~~~~ßßßß~~~~~#~~~~ "'"v ",(I '"'v ~ " ~ ~ ~ ~ '(1 '(1 '(1 '(1 '(1 ~ ~ ~ ~ ~ ." Page 1 1400 1200 ~" 1000 - tT) 7ñ a. - 800 CD '- :J ø w Q) '- a.. 600 U) c .- .c ::s I- 400 ~, 200 0 Unocal (' ( Declination:: 21.214° >. .:&~ J*:~ ' Schlumberger Pretty Creek Unit "'~:",)."o"'\'\""""""'M"i9:^'~~ Total Field strength:: 55584.1 nT !,;:~....t::,~,..~:.':'.::~¡.~.,...;,:,,~.t~..~,~.\::.= Well #4 ""'f'!""'1')y"," "', Dip:: 73.955° H&R#9 ~ "",'\.~~.& L~' Proposed Direction :: 191.65° RB - MSL:: 87.7 Survey Meas'd True Sub Sea Vertical Coordinates Closure D.L.S.! # Depth Jnc Azimuth TVD TVD Section N(+)/S(-) E(+)/W(-) Dlst. Dil 100 BUR 1 0.00 0.00 0.00 0.00 -87.70 0.00 0.00 2 205.7 4 0.55 246.51 205.74 778.04 0.57 -0.39 -0.91 0.99 246.5 0.27 0.27 3 296.11 0.97 235.92 296.10 208.40 1.37 -1.00 -1.94 2.18 242.8 0.49 0.46 4 387.54 2.70 207.23 387.48 299.78 3.99 -3.34 -3.56 4.89 226.8 2.09 1.89 5 479.03 4.37 194.38 478.79 397.09 9.55 -8.64 -5.42 70.19 272.1 2.01 1.83 6 572.54 6.30 199.74 571.89 484. 19 18.19 -16.92 -8.03 18.73 205.4 2.13 2.06 7 663.78 10.01 183.30 662.21 574.57 31.00 -29.55 -10.18 31.26 199.0 4.76 4.07 8 756.14 13.81 185.17 752.56 664.86 49.90 -48.55 -11.64 49.93 193.5 4.13 4.11 9 848.61 18.09 190.43 841.46 753.76 75.23 -73.68 -15.23 75.23 191.7 4.88 4.63 10 940.35 20.88 191.97 927.94 840.24 105.83 -103.68 -21.20 105.83 191.6 3.09 3.04 11 1035.24 25.67 193.89 1.015.08 927.38 143.30 -140.20 -29.65 143.30 191.9 5.11 5.05 12 1128.66 29.65 192.75 1.097.81 1010.11 186.64 -182.40 -39.61 186.65 192.3 4.30 4.26 13 1221.73 33.24 192.95 1, 177.20 1089.50 235.17 -229.72 -50.41 235. 19 192.4 3.86 3.86 14 1314.17 36.97 192.80 1,252.81 1165. 11 288.31 -281 .54 -62.25 288.34 192.5 4.04 4.04 15 1408.05 41.10 192.41 1.325.71 7238.07 347.41 -339.23 -75.14 347.45 192.5 4.41 4.40 16 1501.90 43.80 190.99 1,394.96 7307.26 410.75 -401.25 -87.97 470.78 192.4 3.05 2.88 17 1593.81 44.49 189.55 1,460.91 7373.21 474.74 -464.24 -99.37 474.75 192.7 1.32 0.75 18 1687.29 46.54 188.41 1,526.41 7438.77 541 .35 -530.11 -109.77 541.35 191.7 2.36 2.19 19 1779.57 50.09 188.17 1,587.77 7500.07 610:14 -598.29 -119.70 610. 15 191.3 3.85 3.85 20 1872.73 51.33 186.63 1,646.77 1559.07 682.03 -669.79 -128.98 682.09 190.9 1.85 1.33 21 1967.07. 51.26 185.78 1,705.76 7618.06 755.32 -742.98 -136.94 755.49 190.4 0.71 -0.07 22 2062.59 50.84 186.50 1,765.81 7678.11 829.26 -816.83 -144.88 829.58 190.1 0.73 -0.44 23 2155.08 50.22 187.16 1,824.60 7736.90 900.41 -887.72 -153.37 900.88 189.8 0.87 -0.67 24 2247.99 51.07 188.63 1,883.52 7795.82 972.09 -958.88 -163.24 972.68 189.7 1.53 0.91 25 2339.51 51.29 189.08 1,940.89 7853.19 1043.31 -1029.33 -174.22 7,043.97 189.6 0.45 0.24 26 2445.46 50.43 189.10 2.007.77 1920.07 1125.40 -1110.48 -187.20 7, 126.15 189.6 0.81 -0.81 27 2538.37 50.91 190.22 2,066.65 7978.95 1197,22 -1181.32 -199.26 1,798.07 189.6 1.07 0.52 28 2633.07 51.77 192.09 2, 125.82 2038.12 1271.16 -1253.87 -213.57 7,271.92 189.7 1.79 0.91 29 2724.68 51.83 191.30 2,182.47 2094.77 1343.15 -1324.36 -228.17 1,343.87 189.8 0.68 0.07 30 2818.82 51.43 191.32 2.240.90 2753.20 1416.96 -1396.74 -242.64 7,477.66 189.9 0.43 -0.42 31 2912.02 51.24 191.04 2.299.13 2211.43 1489.73 -1468.13 -256.75 7,490.47 189.9 0.31 -0.20 32 3004.39 51.04 191.28 2-357.09 2269.39 1561.65 - 1538.69 -270.67 7,562.32 190.0 0.30 -0.22 33 3097.88 51.39 190.96 2,415.65 2327.95 1634.53 -1610..20 -284.73 7,635.78 190.0 0.46 0.37 34 3191.17 51.10 191 .32 2-474.05 2386.35 1707.27 -1681.58 -298.78 7,707.92 790.7 0.43 -0.31 35 3284.83 51.31 191.23 2,532.73 2445.03 1780.27 -1753.17 -313.06 7,780.90 190.7 0.24 0.22 36 3378.;;") 51.06 190.87 2,591.33 2503.63 1853.11 -1824.66 -327.02 7,853.71 ,190.2, Q¿'{, ,0,27 37 3471.0;¿ 51.1 0 190.61 2,649.57 2567.87 1925.22 -1895.52 -340.46 7,925.85 190.2 0.22 0.04 , 38 3563.78 51.27 191.39 2,707.71 2620.07 1997.49 -1966.47 -354.25 7,998.72 190.2 0.68 0.18 39 3657.94 51.50 190.31 2,766.48 2678.78 2071.06 -2038.73 -368.10 2,077.69 190.2 0.93 0.24 40 3752.81 50.35 191.69 2-826.28 2738.58 2144.70 -2111.02 -382.14 2, 745.33 190.3 1.66 -1.21 41 3843.84 51.95 190.42 2.883.38 2795.68 2215.58 -2180.59 -395.73 2,276.27 790.3 2.07 1.76 42 3937.96 53.28 189.50 2,940.52 2852.82 2290.33 -2254.25 -408.66 2,290.99 790.3 1.61 1.41 43 4030.06 53.70 189.52 2,995.32 2907.62 2364.31 -2327.26 -420.89 2,365.07 190.3 0.46 0.46 44 4123.46 54.37 187.51 3,050.18 2962.48 2439.78 -2402.01 -432.07 2,440.57 190.2 1.88 0.72 45 4215.75 54.19 186.96 3, 104.06 3076.36 2514.49 -2476.35 -441.51 2,575.40 190.7 0.52 -0.20 46 4309.79 54.11 186.80 3,159.13 3071.43 2590.45 -2552.02 -450.64 2,591.50 190.0 0.16 -0.09 47 4400.89 53.97 187.14 3,212.63 3724.93 2663.94 -2625.21 -459.59 2,665.14 189.9 0.34 -0.15 48 4493.75 53.82 187.58 3,267.35 3779.65 2738.75 -2699.62 -469.20 2,740.09 189.9 0.42 -0.16 49 4586.57 53.65 187.64 3,322.25 3234.55 2813.41 -2773.80 -479.11 2,874.88 189.8 0.19 -0.18 50 4680.84 52.63 188.00 3,378.80 3291. 70 2888.66 -2848.53 -489.37 2,890.26 189.7 1.12 -1.08 51 4773.98 51.57 187.46 3.436.02 3348.32 2961. 99 -2921.35 -499.26 2,963.77 189.7 1.23 -1.14 52 4867.96 51.03 188.05 3,494.78 3407.08 3035.16 -2994.02 -509.15 3,037.07 189.7 0.76 -0.57 53 4961.05 50.46 187.37 3,553.68 3465.98 3107.07 -3065.45 -518.83 3, 109.05 789.6 0.83 -0,61 54 5052.58 49.13 186.82 3,612.77 3525.07 3176.75 -3134.82 -527.46 3, 178.89 189.6 1.52 -1.45 55 5145.85 48.07 187.41 3,674.45 3586.75 3246,50 -3204.24 -536.13 3,248.79 189.5 1.23 -1.14 56 5239.09 47.19 186.82 3,737.28 3649.58 3315.17 -3272.60 -544,66 3,317.67 189.4 1.05 -0.94 57 5330.74 45.92 186.94 3,800.30 3712.60 3381.48 -3338.66 -552.63 3,384.09 189.4 1.39 -1.39 58 5423.03 45.14 187.79 3,864.96 3777.26 3447,15 -3403,97 -561 .07 3,449.97 189.4 1.07 -0.85 59 5515.04 43,62 187.27 3.930.72 3843.02 3511 .33 -3467,77 -569.51 3.574.22 189,3 1.70 -1.65 Unocal ( { Declination = 21.214° ~ Schiijmberger Pretty Creek Unit ., "".' ",','..' ". Total Field Strength = 55584.1 nT Well #4 UNOCAll~ Dip = 73.955° H &R#9 >~;~,. Proposed Direction = 191.65° RB - MSL = 87.7 Survey Meas'd True Sub Sea Vertical Coordinates Closure D.L.S./ # Depth Inc Azimuth TVD TVD Section N(+)/S(-) E(+)/W(-) Dls'. Dlt 100 BUR 60 5611.40 42.31 187.72 4,001.23 3973.53 3576.83 -3532.88 -578.07 3,579.86 789.3 1.39 -1.36 61 5704.31 41.43 188.24 4,070.41 3982.77 3638.72 -3594.30 -586.68 3,647.86 789.3 1.02 -0.95 62 5797.65 39.65 189.69 4,141.34 4053.64 3699.32 -3654.22 -596.12 3; 702.52 789.3 2.16 -1.91 63 5890.78 38.31 190.20 4,213.74 4726.04 3757.87 -3711.92 -606.23 3,767.70 789.3 1.48 -1.44 64 5982.66 36.90 189.61 4,286.53 4798.83 3813.91 -3767.15 -615.88 3,877.76 789.3 1.58 -1.53 65 6075.16 35.84 190.04 4,361.01 4273.37 3868.73 -3821.20 -625.24 3,872.07 789.3 1.18 -1.15 66 6169.11 34.79 189.72 4,437.67 4349.97 3923.02 -3874.70 -634.56 3,926.32 789.3 1.13 -1.12 67 6260.63 33.61 189.64 4,513.36 4425.66 3974.43 -3925.41 -643.21 3,977.76 789.3 1.29 -1.29 68 6354.94 32.34 189.51 4,592.48 4504.78 4025.72 -3976.02 -651.74 4, 029.08 789.3 1.35 -1.35 69 6449.01 30.58 189.74 4,672.72 4585.02 4074.78 -4024.42 -659.95 4,078.78 789.3 1.88 -1.87 70 6540.95 29.20 191.00 4,752.43 4664.73 4120.59 -4069.49 -668.19 4, 723.98 789.3 1.65 -1.50 71 6633.39 28.52 190.38 4,833.39 4745.69 4165.20 -4113.33 -676.47 4, 768.59 789.3 0.80 -0.74 72 6726.84 28.39 190.60 4,915.55 4827.85 4209.71 -4157.12 -684.57 4,273.77 789.4 0.18 -0.14 73 6820.97 28.39 190.32 4,998.36 4970,66 4254.46 -4201.13 -692.70 4,257.85 789.4 0.14 0.00 74 6852.06 28.22 189.95 5,025.73 4938.03 4269.20 -4215.64 -695.29 4,272.59 789.4 0.79 -0.55 75 6882.88 28.21 190.50 5,052.89 4965.79 4283.76 -4229.98 -697.88 4,287.76 789.4 0.84 -0.03 76 7016.41 28.95 190.90 5,170.14 5082.44 4347.63 -4292.75 -709.74 4,357.02 789.4 0.57 0.55 77 7107.56 28.17 191.14 5,250.20 5762.50 4391.21 . -4335.52 -718.07 4,394.58 789.4 0,86 -0.86 78 7199.54 26.95 192.25 5,331.74 5244.04 4433.76 -4377.19 -726.69 4,437.70 789,4 1.44 -1.33 79 7294.37 26.37 190.98 5.416.49 5328,79 4476.31 -4418.87 -735.26 4.479.62 789.4 0.86 -0.61 80 7387.60 25.86 190.47 5,500.20 5472.50 4517.34 -4459.19 -742.90 4,520.65 789.5 0.60 -0.55 81 7481.08 25.35 189.02 5,584.51 5496.87 4557.71 -4499.00 -749.74 4,567.04 789.5 0.86 -0.55 82 . 7575.44 24.74 189.32 5,669.99 5582.29 4597.62 -4538.43 -756.10 4, 600. 99 789.5 0.66 -0.65 83 7668.35 24.11 189.21 5,754.59 5666.89 4636.01 -4576.35 -762.29 4,639.40 789.5 0.68 -0.68 84 7759.99 23.25 188.54 5,838.51 5750.87 4672.77 -4612.71 -767.97 4,676.27 789.5 0.98 -0.94 85 7852.17 22.86 188.30 5,923.33 5835.63 4708.81 -4648.42 -773.26 4, 772.30 789.4 0.44 -0.42 86 7947.24 22.72 188.48 6,010.98 5923.28 4745.58 -4684.86 -778.63 4,749.72 789.4 0.16 -0.15 87 8039.89 22.32 187.71 6,096.56 6008.86 4780.99 -4719.99 -783.63 4, 784.60 789.4 0.54 -0,43 88 8133.45 21.51 187.50 6,183.36 6095.66 4815.82 -4754.60 -788.25 4,879.50 789.4 0.87 -0.87 89 8225.43 21.30 187.00 6,269.00 6787.30 4849.29 -4787.90 -792.49 4,853.04 789.4 0.30 -0,23 90 8319.40 20.29 187.23 6,356.84 6269. 74 4882.55 -4821.00 -796.62 4,886.38 789.4 1.08 -1.07 91 8409.54 19.87 185.79 6,441.50 6353.80 4913.37 -4851.75 -800.13 4, 97 7.28 789.4 0.72 -0.47 92 8503.71 19.82 185.50 6,530.08 6442.38 4945. 17 -4883.56 -803.28 4, 949.79 789.3 0.12 -0.05 93 8597.97 19.61 184.12 6,618.82 6537.72 4976.74 -4915.25 -805.94 4, 980.88 789.3 0,54 -0.22 94 8690.90 18.50 184.65 6,706.65 6678.95 5006.83 -4945.50 -808.26 5,077.77 789.3 1.21 -1.19 95 8782.70 17.02 181.30 6,794.08 6706.38 5034.50 -4973.45 , -809.75 5,038.93 789.2 1.96 -1.61 ", 96 8877.63 15.62 178.98 6,885.18 6797.48 5060.64 -5000. 12 -809.83 5,065.27 789.2 1.63 -1.47 97 8970.02 14.83 175.55 6,974.33 6886.63 5084.14 -5024.34 -808.69 5,089.07 789.7 1.30 -0.86 98 9063.29 14.34 174.52 7,064.59 6976.89 5106.64 -5047.74 -806.67 5, 777.79 789.7 0.59 -0.53 99 9156.37 14.29 175.77 7,154.78 7067.08 5128.71 -5070.67 . -804.72 5, 734.73 789.0 0.34 -0.05 100 9247.60 14.18 175.48 7,243.21 7755.57 5150.27 -5093.04 -803.Dl 5,755.95 789.0 0.14 -0.12 101 9340.81 14.16 176.14 7,333.59 7245.89 5172.22 -5115.79 -801.34 5,778.77 788.9 0.17 -0.02 102 9436.23 14.27 176.80 7,426.09 7338.39 5194.84 -5139.18 -799.90 5,207.06 788.8 0.21 0.12 103 9528.91 12.00 172.85 7,516.34 7428.64 5215.00 -5160.15 -798.06 5,227.50 788.8 2.63 -2.45 Projection 9580.00 12.00 172.85 7,566.31 7478.67 5225.06 -5170.69 -796.74 5,237.77 788.8 0.00 0.00 '~ i Edinburgh Petroleum Services Ltd. Report File: PCU4Sand5152_51402_PBU.pan I ~ 51 panSystem Version 2.6a Analysis Date: 5/15/2002 I t]1:jJj Well Test Analysis Report I I Analyst name Sam A. Darkwah Company Unocal Corporation Well PCU 4 (Sand 5152 - 5172) Field Pretty Creek Date 5/11/02 Rig Name/Number Test Depth Reference - MSL Gauge Type Gauge Number Gauge Depth - Measured Gauge Depth - Vertical Producing Formation Top Producing Formation Bottom Perforated interval Top Perforated interval Bottom Remarks: PBU & 4 Point SPIDR Surface Gauge Surface Surface 5152 5172 5152 5172 I I I I I I 0._" I PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 1 of 11 I Edinburgh Petroleum Services Ltd. Report File: I PCU4Sand5152_51402_PBU.pan I I 5/15/2002 PanSystem Version 2.6a Analysis Dàte: Well Test Analysis Report Reservoir Description Fluid type: Gas Well orientation: Vertical Number of wells: 1 Number of layers: 1 Layer Parameters Data .-.."..' Layer 1 Formation thickness 20.00 ft Average formation porosity 0.20 Water saturation 0.35 Gas saturation 0.65 Formation compressibility 3.6468e-6 psi-1 Total system compressibility 5.658ge-4 psi-1 Layer pressure 1297.8899 psia Temperature 88.0000 deg F Well Parameters Data .'c- Well 1 Well radius 0.35 ft Distance from observation to active well 0.0000 ft Wellbore storage coefficient 0.0452 bbllpsi Storage Amplitude 0.0000 psi Storage Time Constant 0.0000 hr Second Well bore Storage 0.0000 bbl/psi Time Change for Second Storage 0.0000 hr Well offset - x direction 0.00 ft Well offset - y direction 0.00 ft Fluid Parameters Data Layer 1 Gas gravity 0.5600 sp grav Water-Gas ratio 1.0000e-3 STB/MMscf Water salinity 3000.0000 ppm Check Pressure 1300.0000 psia panSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 2 or 11 I Edinburgh Petroleum Services Ltd. Report File: PCU4Sand5152 51402 PBU.pan. 5/15/2002 - - I ~ S panSystem Version 2.6a Analysis Délte: L11::1I:I Well Test Analysis Report -- Fluid Parameters Data (cont) --- Layer 1 Check Temperature 88.0000 deg F Gas density 4.18488Ib/ft3 Initial gas viscosity 0.0134907 cp Gas formation volume factor 0.01022 ft3/scf Water density 62.3986 Ib/ft3 Water viscosity 0.78419 cp Water formation volume factor 1.00154 RB/STB Initial Z-factor 0.85853 Initial Gas compressibility 8.6334e-4 psi-1 Water compressibility 3.055ge-6 psi-1 Layer 1 Correlations Ug Correlation: Carr et al Layer Boundaries Data Layer 1 Boundary Type: Infinitely acting Layer 1 L1 0.0000 ft L2 0.0000 ft L3 0.0000 ft L4 0.0000 ft Drainage area 0.0000 acres Dietz shape factor 0.0000 ;"'~. Layer 1 Model Data Layer 1 Model Type: Radial homogeneous Layer 1 Permeability 75.3027 md Skin factor (Well 1) 6.7198 Rate dependent skin coefficient (0) 0.00 1/(Mscf/day) PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 3 of 11 Edinburgh Petroleum Services Ltd. Report File: PCU4Sand5152_51402_PBU.pan E~S PanSystem Version 2.6a Analysis Date: 5/15/2002 Well Test Analysis Report Rate Change Data '-' Time Pressure Rate Hours psla MMscf/day -3038.00000 1145.0000 3.8000 95.84310 1139.5570 3.7500 . 163.69400 1276.1560 0.0000 167.76390 1179.6851 2.5000 171.85510 1166.6541 3.0000 175.35350 1139.0050 3.5000 187.61400 1082.9091 4.5000 '0.- PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 4 of 11 I 1282.41 1241.72 "-~ 1201.03 ......... co (/) 0.. - Q) L- ::J (j) rn Q) L- a... 1160.33 '-~ 1119.64 8 Q~ 107 0.0133 Edinburgh Petroleum Services Ltd. Report File: PCU4Sand5152- 51402_PBU. pan PanSystem Version 2.6a Analysis Date: 5/15/2002 A.59 I I 3.672 ~ 2 7~4 4::: ..... () rn ~ ~ 31 01 1 .836 LL I (/) co CD 0.918 0 191.ù66 Well Test Analysis Report PCU4 Sand5152-5172 Drawdown. PBU & 4Pt 38.2838 76.5544 114.825 153.095 PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 5 of 11 Edinburgh Petroleum Services Ltd. Report File: PCU4Sand5152_51402_PBU.pan IS ~ S PanSystem Version 2.6a Analysis Date: 5/15/2002 ~ Well Test Analysis Report I PCU 4 - Semi loa Plot for 5152 - 5172 PBU 146.467 129.59 -- ,'- III' -.......::: ~ IIIIoo.c ~ ~ - -~ III" , "" " "" ~ , 11os-- c~ "0 ~ 0 [ :--.. ....... " """ """'" 0 0 Ì'---..... 0 " -""""' ..... " " " 0 " 0 I " 0 0 G " " 0 .. ~ I ! Model Results OJ Radial homogeneous ~ Infinitely acting " K = 81.8998 md kh = 1637.9963 md.ft 0 Rinv = 1749.483 ft I " FE = 0.544 " dpS = 74.3391 psi " S = 8.5981 P* = 1297.8899 psia " 10 100 1000 Homer Time Function - Tp=3133.843 10000 100000 142.247 --- ......... .- ~ 138.028 I ill ~ .¡c -- a. .Q N en Co -- .- -3:133.809 E -- 125.3711 panSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. i Page 6 of 11 I Edinburgh Petroleum Services Ltd. Report File: PCU4Sand5152 51402 PBU.pan, . - - I 5/15/2002 i panSystem Version 2.6a Analysis D::)1e: , Well Test Analysis Report PCU 4 - Semilog Plot for 5152 - 5172 PBU Model Results Radial homogeneous - Infinitely acting Classic Wellbore Storage "'-'" Value Permeability 81.8998 md Permeability-thickness 1637.9963 md.ft Radius of investigation 1749.4830 ft Flow efficiency 0.5440 dP skin (constant rate) 74.3391 psi Skin factor 8.5981 Extrapolated pressure 1297.8899 psia PCU 4 - Semilog Plot for 5152 - 5172 PBU Line Details Line type: Radial flow Slope: -2.05196 Intercept: 150.343 Coefficient of Determination: 0.997882 Radial flow Extrapolated m(p) 150.3430 psi2/cp (*1 E-06) Extrapolated pressure 1297.8899 psia m(p) at dt = 1 hr 143.1689 psi2/cp (*1 E-06) Pressure at dt = 1 hour 1265.4044 psia ',~ Number of Intersections = 0 PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 7 of 11 I ~ ..- ..- CD a I W rO.1 --- 0.. () - N en a.. --- ..- a.. E'°.01 JY (]) 0 "'-,~ Edinburgh Petroleum Services Ltd. Report File: PCU4Sand5152_51402_PBU .pan PanSystem Version 2.6a Analysis Date: 5/15/2002 Well Test Analysis Report PCU 4 - Sand 5152 - 5172 PBU 50902 10 ~ 3"0 f caccca DOOCDD .00 a ~.. ~ :JDD a c c 0 0 C D ~ ","" ,J-' ~ ~ 'òc f:q,oo OJ 00 00 0 00 0 0 0 0 0 0 000000 0" 0000 0 - c"'- ~ ~. -:-:". - - .- . - ~ \ I ¡¡o ~ I I ¡ '" 0 ~ ' "" I ~ «0 I ! (t¡ Oq, I I Model Results Radial homogeneous I Infinitely acting Cs = 0.077 bbl/psi Cd = 162.6754 V = 89.202 bbl 0 K = 80.0273 md kh = 1600.5455 md.ft a S = 8.2682 0 - . 1 0.001 0.0001 0.01 0.1 10 Equivalent Time PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 8 of 11 I Edinburgh Petroleum Services Ltd. Report File: PCU4Sand5152_51402_PBU.pan I I 5/15/2002 PanSystem Version 2.6a Analysis Date: Well Test Analysis Report PCU 4 - Sand 5152 - 5172 - PBU_50902 Model Results Radial homogeneous - Infinitely acting Classic Well bore Storage "-' Value Well bore storage coefficient 0.077 bbl/psi Dimensionless wellbore storage 162.6754 Apparent wellbore volume 89.2020 bbl Permeability 80.0273 md Permeability-thickness 1600.5455 md.ft Skin factor 8.2682 PCU 4 - Sand 5152 - 5172 - PBU_50902 Line Details Line type: Wellbore storage Slope: 1 Intercept: 883.123 Coefficient of Determination: Not Used Line type: Radial flow Slope: 0 Intercept: 0.912009 Coefficient of Determination: Not Used Number of Intersections = 0 ~- panSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 9 of 11 --- -- -- <0 0 I ill ~ CO.1 0- C,) - N '00 0- ........ 0:0.01 ........ E .rn Q) 0 0.001 .~--- PCU4Sand5152 51402 PBU.pan I - - I 5/15/2002 Edinburgh Petroleum Services Ltd. Report File: PanSystem Version 2.6a Analysis Date: Well Test Analysis Report PCU 4- TC Match for PBU on 5152-5172 Sand 100 I , ~' DO OJ' . ~ n ~ n n~ 'n~ -- ~ - - "'i-" ~ ~ ...- I ,"'" ~ I -.;¡ ~ ~ ~ ¡:.... ........ ,, 1 ~ 0 i'.;-... ....... - I / 0 V I o ""r-, ~ ¡.."" 0 ~ - "" ' ~ ~ I @ C!: I " ~ I I 'I I Match Results Radial homogeneous Infinitely acting 0 K = 75.3027 md 0 Cs = 0.0452 bbl/psi 0 Cd = 145.6228 .v = 52.3399 bbl I ) s = 6.7198 , L = 579.4003 ft I 0 =0 1/(Mscf/day - - - . - - . - . . - . - - 10 1 0.0001 1 e-005 0.001 0.01 0.1 1 EQuivalent Time 100 1000 I Page 10 of 11 I PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Edinburgh Petroleum Services Ltd. Report File: PCU4Sand5152_51402_PBU.pan i ~ 51 panSystem Version 2.6a Analysis Date: 5/15/2002 I t]UJ:j Well Test Analysis Report PCU 4-TC Match for PBU on 5152-5172 Sand Model Results Radial homogeneous - Infinitely acting Classic Wellbore Storage ""-' Value Permeability 75.3027 md Wellbore storage coefficient 0.0452 bbl/psi Dimensionless well bore storage 145.6228 Apparent wellbore volume 52.3399 bbl Skin factor 6.7198 Distance to boundary 579.4003 ft Type Curve Details . Stage 1 File Name: C:\Program Files\EPS\PanSystem 2.6a\typecurv\radhomog.tch Axis Type: Td/Cd-- Stage 2 File Name: C:\Program Files\EPS\PanSystem 2.6a\typecurv\faults.tcb Axis Type: Td/Ld2 Stage 1 Stage 2 Match point - X -2.8626 1.4118 Match point - Y -0.2875 -0.2875 Curve Number 9.0000 4.0000 Curve Value 1 . 0000e8 3.0000 -.-- PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 1 î of 11 I I Edinburgh Petroleum Services Ltd. Report File: PCU4_Sand4507PBU_O42902.pan I ~ ~ 51 PanSystem Version 2.6a Analysis Date: 5/15/2002 I L:Il:j[] Well Test Analysis Report I Analyst name Sam A. Darkwah ' Company Unocal Corporation Well PCU 4 Field Pretty Creek Survey Date 4/29/02 Rig Name/Number Test Depth Reference - MSL Gauge Type Gauge Number Gauge Depth - Measured Gauge Depth - Vertical Producing Formation Top Producing Formation Bottom Perforated interval Top Perforated interval Bottom Surfz-:e PBU "-, Surface SPIDR 4507 4514 Remarks: -~-- panSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 1 of 11 .'- -,- I Edinburgh Petroleum Services Ltd. Report File: PCU4_Sand4507PBU_042902.pan E~S panSystem Version 2.6a Analysis Date: 5/15/2002 I LIJ:j[j Well Test An~lysis Report I Reservoir Description Fluid type: Gas Well orientation: Vertical Number of wells: 1 Number of layers: 1 Layer Parameters Data L-ayer1 Formation thickness 7.00 ft Average formation porosity 0.20 Water saturation 0.30 Gas saturation 0.70 Formation compressibility 3.6468e-6 psi-1 Total system compressibility 6.2085e-4 psi-1 Layer pressure 1305.1830 psia T em peratu re 84.0000 deg F Well Parameters Data We/!1 Well radius 0.35 ft Distance from observation to active well 0.0000 ft Wellbore storage coefficient 0.0253 bbl/psi Storage Amplitude 0.0000 psi Storage Time Constant 0.0000 hr Second Wellbore Storage 0.0.000 bbl/psi Time Change for Second Storage 0.0000 hr Well offset - x direction 0.00 ft Well offset - y direction 0.00 ft Fluid Parameters Data Layer 1 Gas gravity 0.5600 sp grav Water-Gas ratio 1. 0000e-5 STB/MMscf Water salinity 3000.0000 ppm Check Pressure 1280.0000 psia PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 2 of 11 I I Edinburgh Petroleum Services Ltd. Report File~ ! PCU4- Sand4507PBU _042902. pan I ~ 51 PanSystem Version 2.6a Analysis Date: 5/15/2002 LI1::1J: Well Test Analysis Report I Fluid Parameters Data (cant) ~~ Layer 1 Check Temperature 84.0000 deg F Gas density 4.16272 Ib/ft3 Initial gas viscosity 0.0134021 cp Gas formation volume factor 0.01027 ft3/scf Water density 62.4487 Ib/ft3 Water viscosity 0.82199 cp Water formation volume factor 1.00074 RB/STB Initial Z-factor 0.85608 Initial Gas compressibility 8.8041e-4 psi-1 Water compressibility: 3.0705e-6 psi-1 Layer 1 Correlations Ug Correlation: Carr et al Layer Boundaries Data Layer 1 Boundary Type: Infinitely acting Layer 1 L1 0.0000 ft L2 0.0000 ft L3 0.0000 ft L4 0.0000 ft Drainage area 0.0000 acres Dietz shape factor 0.0000 -',~ Layer 1 Model Data Layer 1 Model Type: Radial homogeneous Layer 1 Permeability 123.1173 md Skin factor (Well 1) 8.8333 Rate dependent skin coefficient (0) 4.0000e-4 1/(Mscf/day) PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 3 of 11 D ~ S panSystem Version 2.6a Analysis Date: []1:j[j Well Test Analysis Report " Rate Change Data Edinburgh Petroleum Services Ltd. Report File: PCU4- Sand4507PBU _042902. pan 5/15/2002 Time Pressure Rate Hours psla - MMscf/day -2918.00000 1065.0000 3.7500 69.56050 1035.0170 3.2200 101.94740 1275.8510 0.0000 »~ ~ PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 4 of i 1 I Edinburgh Petroleum Services Ltd. Report File: i PCU4- Sand4507PBU - 042902.pan ! panSystem Version 2.6a Analysis Date: 5/15/2002 , Well Test Analysis Report Test Overview -- PCU 4 Sand4507 PBU 5/02 1283.5 3.2844 ~ IIIK=D=<D> L1: 1 I 2.62752 I 1232.12 '~ I -J 1180.73 (Ij u 1.97064 '5 CI) ~ ~ .......... ro "00 0.. .......... Q) L- :J CI) CI) Q) L- 0.. 1129.35 2 ro a: s. 1"31376~1 CI) {Ij CD ~~_. 1077.96 0.65688 I 1026.5eo 24.3334 48.6668 73.0002 97.3336 0 121.067 panSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 5 of 11 I Edinburgh Petroleum Services Ltd. Report File: PCU4- Sand4507PBU _042902. pan Ie ~ S PanSystem Version 2;6a Analysis Date: 5/15/2002 I Mfj Well Test Analysis Report I Semi-Lo.Q Plot for PCU 4 Sand 4507 PBU 147.365 r-f... " 137.352 '"tJ ?r, û £~ 'J 0 9. I" ~ I I rt-t+tL ! I ~ ~"":....-" ..--.. ...- 8127.34 I w '6 '6 c c 0 0 0 c 0 c 0 0 0 0 0 " d ~ '" -- c.. u - N (/) c.. -- ..--.. ð117.327 E ~ - Þ .2 0 0 0 " 0 c . ~,~ Model Results Radial homogeneous 107 .3141lnfinitely acting K = 117.5721 md kh = 823.0049 md.ft Rinv = 1383.6371 ft FE = 0.5631 dpS = 124.9053 psi S = 8.0466 97.301e{* = 1305.183 PSi~O " 0 0 c Þ [J c 0 < [J - 0 [J 0 [J ill 100 1000 10000 Horner Time Function - Tp=2987.5605 100000 1e+006 PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 6 of 11 Edinburgh Petroleum Services Ltd. Report File. ] PCU4- Sand4507PBU _042902. pan I PanSystem Version 2.6a Analysis Date: 5/15/2002 Well Test Analysis Report Semi-Log Plot for PCU 4 Sand 4507 PBU Model Results Radial homogeneous - Infinitely acting Classic Wellbore Storage '~ Value Permeability 117.5721 md Permea bility-th ickness 823.0049 md.ft Radius of investigation 1383.6371 ft Flow efficiency 0.5631 dP skin (constant rate) 124.9053 psi Skin factor 8.0466 Extrapolated pressure 1305.1830 psia . Semi-Log Plot for PCU 4 Sand 4507 PBU Line Details Line type: Radial flow Slope: -3.48114 Intercept: 152.966 Coefficient of Determination: 0.999965 Radial flow Extrapolated m(p) 152.9658 psi2/cp (*1 E-06) Extrapolated pressure 1305.1830 psia m(p) at dt = 1 hr 140.8672 psi2/cp (*1 E-06) Pressure at dt = 1 hour 1250.9480 psia ~~ Number of Intersections = 0 Page 7 of 11 I I PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Edinburgh Petroleum Services Ltd. Report File:. PCU4_Sand4507PBU_042902.pan . ~ 51 PanSystem Version 2.6a Analysis Date: 5/15/2002 I r:tr::l[] Well Test Analysis Report H+mfFFFflI I I "-~ ....- <0 0 I ~10 ~ a. .Q C\I .ëi) 5 â E 19 Q5 0 ._' - - - - - -.- - - - - - - -- - - -- - - - - - - - - / I Q :J !J Q 0 a!) oc- 0:::0= =.<' I c 8 I I~ -,-CO .C' ! ..<I' ~ ~.p' ./ J ~ I ;oooc,oo ! I V G I 0 " / 0 ..=P m" /0 Q ooor:P"" 'G ~ < 0 000 <>0 Model Results Ç o Radial homogeneous l< 0 CO 00 " 0 Infinitely acting 0 0 Cs = 0.0308 bbl/psi i 0 0 Þ 0 0 Cd = 182.2115 þ 0 c ~ = 34.9701 bbl 0 l{ " K = 118.2448 md 0 kh = 827.7136 md.ft 0 S = 8.1237 V " I " 0 0 0 I 0 0 I I 0 0 ...d ... "'" -~ 00 - - - --"..,..- / I 'j 0.001 0.01 1 10 - Tc=2987.5605 PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 8 of 11 I Edinburgh Petroleum Services Ltd. Report File: PCU4 Sand4507PBU 042902.oan - -. I I panSystem Version 2.6a Analysis Date: 5/15/2002 Well Test Analysis Report PCU 4 - Top Zone Sand 4507 PBU 5/2002 Model Results Radial homogeneous - Infinitely acting Classic Wellbore Storage ~ Value Wellbore storage coefficient 0.0308 bbl/psi Dimensionless wellbore storage 182.2115 Apparent well bore volume 34.9701 bbl Permeability 118.2448 md Permeability-thickness 827.7136 md.ft Skin factor 8.1237 PCU 4 - Top Zone Sand 4507 PBU 5/2002 Line Details Line type: Wellbore storage Slope: 1 Intercept: 1895.39 Coefficient of Determination: Not Used Line type: Radial flow Slope: 0 Intercept: 1.50324 Coefficient of Determination: Not Used Number of Intersections = 0 .~. PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 9 of 11 I Edinburgh Petroleum Services Ltd. Report File: PCU4- Sand4507PBU _042902. pan E~S panSystem Version 2.6a Analysis Date: 5/15/2002 '""--':-;'~ ....- <0 0 J ill ~ ~ 0.10 .Q C\I 'ëi) 5 â E 19 Q5 0 ~ Well Test Analysis Report TCurve Match for PCU 4 - Sand 4507 PBU 100 Match Results I I I Radial homogeneous Infinitely acting I K = 123.1173 md I I- Cs = 0.0253 bbl/psi Cd = 212.5699 V = 28.769 bbl ~ S = 8.8333 L = 781.1068 ft 0 = 4.000e-004 1/(Mscf/day) ~.;;¡: -- / II ~ p / ",'" I /' ,/ ! ..,'~ """'- V ~ 2_V "'" Æ' / ~ 1:,;9Í \ ~ h ~~ 'I (,I 1,~\ ,/ 0 / I .. / 0 \ V / 0 r-- 000 - I I I I I ¡ 0.1 0.0001 0.01 1000 0.001 0.1 Eauivalent Time 10 100 PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 10 of 11 Edinburgh Petroleum Services Ltd. -~!i panSystem Version 2.6a Well Test Analysis Report TCurve Match for PCU 4 - Sand 4507 _PBU Model Results Radial homogeneow~ - Infinitely acting Classic Wellbore Storage "~~- Value Permeability 123.1173 md Wellbore storage coefficient 0.0253 bbl/psi Dimensionless wellbore storage 212.5699 Apparent wellbore volume 28.7690 bbl Skin factor 8.8333 Distance to boundary 781.1068 ft Type Curve Details Stage 1 File Name: C:\Program Files\EPS\PanSystem 2.6a\typecurv\radhomog.tch Axis Type: T d/Cd Stage 2 File Name: C:\Program Files\EPS\PanSystem 2.6a\typecurv\faults. tcb Axis Type: Td/Ld2 Stage 1 Stage 2 Match point - X -2.8745 1.4952 Match point - Y -0.4605 -0.4605 Curve Number 10.0000 4.0000 Curve Value 1.0000e10 3.0000 """-~~ Report File:. PCU4 - Sand4507PBU _042902. pan 5/15/2002 Analysis Date: PanSystem - Copyright (C) 2000 Edinburgh Petroleum Services Ltd. Page 11 of 11 '. PCU 4_Sand 5152_Fourpoint ~ Well PCU-4 Field PrettY Creek !Yee Test MI" - 4-Doint Test Date 5/11/02 Table 1 PwI(~ PwI(actual) Pr2 - Pwf^2 log (Pws! - Pwf) % Error of Pwf cafc a SITP PIbg psia Zfactor Viscosity, cp psia psia psia2 log Q mmcfd psia2 from F....1 actual % Well Data 1 E-11 1175 1175 0.8689556 0.013866658 1276.276541 1300 - - - ~ 82% 2.5 1070 0.8731788 0.013341299 1177.102579 1181 295,239 0.3979 5.4702 0.;33% Gas Gravitv 0.56 3 1050 0.8749138 0.013292554 1161.443712 1164 335,104 0.4771 5.5252 0.22% Surface Temp "F 68 3.5 1014 0.8779083 0.01321078 1129.955818 1137 397,231 0.5441 5.5990 0.62% Shale Teme "F 88 4.5 937 0.8846871 0.013035803 1 066.692662 1075 534,375 0.6532 5.7278 0.77% Averaae Teme "F 78 1 E-11 1175 1175 0.8689556 0.013866658 1276.276541 1300 - - - 1.82% EDsilon 0.0001 " Modified Isochronal MidDerf DeDth MD ft 5162 Midperf Depth TVD ft 3688 p- 14.7 1 6.074385649 Tbg ID inches 2.441 10 15.29681944 . n- 0.975881226 c= 0.00001 mmcfdlpsia^2 AOF- 13.84 mmcfd --- O:\Gas Cft\Openmind\Westside\Pretty Creek\PCU 4\Surveys\Pressures\PCU 4-5152- 4poinC511 02.xls 10,000,000 -~ 1,000,000 M < .s fI. CI.c N < ~ ~ ~ I M < r-. ~ 100,000 L~ 10,000 PCU 4 -- Middle Pack Sand 5152 - 5172 -- Four Point Test (5/11/02) Analysis n = 0.88 c = 4.0993E-5 mmlpsia^2 AOF = 13 mmcfd Reservoir Pressure = 1300 psia - - - - - - - - - - - -. -- - ------------------------------------------------ --------______L_______J-_____L___J___~___L__L_l- = = = == = = = = = = = = =~ = = = ==== f = = = =~ = = = =:= = = ~= = =~ = =;= = n= = = == = = = = == == = ~~==r = = ~ = = = ~= = ~ = =~= =~ = I --------------~-------4------~---4---~---~--~-~- --------------~-------~------~---~---~---~--~-1- - - - -.. - - ï - - - - - - - - ï - - - - - ï - - - - ï - - - ï - - ï - - ï - -,-- -------------_J_-------~-----~--__~___L__~__~__L- --------------'--------T-----'----T---T--,--,--r- -----------------------------------------------~-------------------------------------------------1 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~E~i~j~~~~~~~~~~~~~~~~~~~~~~~i~~~~~~~~~~i~~~i~~~~~i~~~~ --------------~-------~------~---~---~---~--~-~-~--------------~--------~-----~----~---~--~--~--~- --------------~-------~------~---~---~--~~--~-f-~--------------~--------+-----~----+---+--~--4--~- I I I I I J I , ------------------------------------------------ I I I I I I I J ------------------------------------------------- --------______L______-~______L___~___~___L__L_~_~__------------J--------~-----~--__~___L__J__~__L- I. 10 100 Gas Rate, mmcfd PCU 4_Sand 4507 _FourPoint May 3, 2002 --- Well PCU4 Upper Sand 4507 - 4514 Field/Location Pretty Creek Westside IY Je Test MI" - 4-point Test Date 3/2102 P wf (caJculai<J P wi (actual) pf - Pwf^2 log (Pws2 - Pwf) Sandface a SITP PIbg psia Zfactor Viscosity, cp psia psia psia2 log a mmcfd psia2 Dr~down, % Well Data 1 E-11 1156 1156 0.86585797 0.013847563 1279.846063 1280 - - 2.5 967 0.88576466 0.01307469 1078.98169 1056 523,264 0.3979 5.7187 17.50% Gas Gravitv 0.56 3 919 0.89014066 0.012967401 1030.43873 1015 608,175 0.4771 5.7840 25.09% Surface Temp of 75 3.5 862 0.89556656 0.012841226 973.4594448 964 709,104 0.5441 5.8507 31.13% Shole Temp "F 85 3.6 852 0.8964827 0.012820624 963.7924175 956 724,464 0.5563 5.8600 33.61 % AveraQe Temp "F 80 1E-11 1156 1156 0.86585797 0.013847563 1279.846063 1280 - - EPsilon 0.0001 " Modified Isochronal Midperf Depth MD ft 3284 Midperf Depth TVD ft 4511 Palm 14.7 1 6.260381527 Tbg ID inches 2.441 10 14.38678081 n= 1 c= 4.97E-Q6 mmcfd/psia^2 AOF= 8.14 mmG~ . ~- O:\Gas CIt\OpenminÓ\Westside\Pretty Creek\PCU 4\Surveys\Pressures\PCU 4507 _FourPtcalcs_30202.xls Pretty Creek Unit # 4 Well -- Deliverab'ïlity Prediction of the Existing Sterling and Beluga Reservoirs OS/23/02 4507 5152 Sand Sand Max. Reservoir Reservoir Sandface Unloading Date Gas Rate Pressure Pressure Z Factor P¡bg PwI Cum Gas P/Z Drawdown Rate mmcfd psiQ psiQ psiQ psiQ bcf psiQ % mmcfd 10/01/02 7.1 1265 1285 0.8786 870 1093 0.85 1451 15% 1.72 11/01/02 7.1 1150 1170 0.8872 730 962 1.07 1308 18% 1.57 12/01/02 7.1 1022 1042 0.8975 550 810 1.28 1150 22% 1.35 01/01/03 7.1 897 917 0.9082 550 648 1.50 999 29% 1.34 02!OÜ03 5.9:, ':' 763 ,':, ',-,"'"783-:.' 0.9204' ',' ,200 - ,,:' 514':-' .. :'1.68::, ,": 840 :~.' ,:-":<~4% ':,' >~::~;~. 03/01/03 ,4.3 ",,628,:': ,'. '648 ' 0.9333" '" 200 ..' ':'.'A06 :-. ':1'.8:1 ",: ':'",,684,-,,'.': ,,'/ ,37°(0 "", 04/01/03 ',,2:5'- ' .46,5:," ::: ,485 ' ' , : 0.9495 200 ' ,295' "'1'.88, "500:' .': " . 39:,/0'<' ',": "~ .,79;;,;:" 05/01/03 0.7 '." ',300' 300 0.9677 200 226,, " 1.90" : "'310' , "25°¡lg': ',,- ':':'0.78 '. 'l<trThis Spreadsheet assumes that minimum compressor intake pressure is 200 psig** **Shaded area is when compressor's minimum limit is reached** '-"', ~, ( (' Date: May 8, 2002 Well: Pretty Creek # 4 Survey: Beluga 5152 - 5172 Step Rate Test 1. Bring well on at a rate of 2.5 mmcfd for 2 hours. 2. Increase rate to 3.0 mmcfd and flow well for 2 hours. 3. Raise rate to 3.5 and flow well for 2 hours. 4. Raise rate to 4.5 mmcfd and flow for 18 hours. 5. Emai! Test Data to Sam and Gary in the Anchorage office. . '-. ., '-', .' ( ( Date: April 29, 2002 Well: Pretty Creek # 4 Survey: Beluga 4507 - 4514 Step Rate Test 1. Bring well on at a rate of 2.5 mmcfd for 2 hours. 2. Increase rate to 3.0 mmcfd and flow well for 2 hours. 3. Raise rate to 3.5 and flow well for 2 hours. 4. Raise rate to 4.25 mmcfd and flow for 18 hours. f ( Darkwah, Samuel A ~uw, d. ---- ŒVlbIw'~ 1"'1 ~-~ ~I .t:: DM From: Sent: To: Cc: Subject: StJohn, Bob Wednesday, April 24, 2002 9:23 PM Samuel A Oarkwah (E-mail) Glynn B Brown (E-mail); Ken J Lucas (E-mail) westside #2 Just got in from pc 4. We are still at a total build up of 10 psi and 4 hours. 785 psi tubing. Talking with Donny Pollard after dinner, He thinks there is fluid below the midle perf. Because he could reset his oil jars while free falling.So for lack of direction ,I am having him run a full or close to full bore tool and look for a fluid level .we should have that for you Sam ,About the time you read this. 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'($ g < '. ß ~ ...' ..... ~ ~X' 'L.l)/(~ ' _r " >. ." ~ ,.. ~ -....ry"" .' \...... ...~ \ ~" (,,, ~ " ."' ( ( Date: April 23, 2002 Well: Pretty Creek # 4 Survey: Deliverability and PBU (Surface) on Individual Sands Step 1 - Testing Beluga Sand (5566 - 5577) 1. Run 2.25" GR and tag fill. Last tag was on 2/3/02. Tag depth was 5575' WLM. 1. Rill and close CMD sleeves at 4524' and 5176'. ' 2. Rill and ensure that sleeve @ 5579' is open. 3. Bring well on and flow for four days. 4. Hook-up Data Logger and shut-in well 72-hour surface build-up. 5. Conduct Step Rate Test. (Rates will be determined based on how interval flowed in step 2). Step 2 - Testing Sterling Sand (4507 - 4514) 1. Rlli and close CMD sleeves at 5176' and 5579'. 2. Rlli and ensure that sleeve @ 4524' is open. 3. Bring well on and flow for four days. 4. Hook-up Data Logger and shut-in well for 72-hour surface build-up 5. Conduct Step Rate Test (Gas Rate in Step 2 will help to determine step rates) Step 3 - Testing Beluga Sand (5152 - 5172) 1. Rill and close CMD sleeves at 5579' and 4524'. 2. Rlli and ensure that sleev'e @ 5176' is open. 3. Bring well on and flow for four days. 4. Hook-up Data Logger and shut-in well for 72-hour surface build-up. . 5. Conduct Step RaLe Test (Gas Ratt;. in Step 2 will help to determine step rates). After .surveys are completed Gary and Sam will determine which sleeve to leave open. ,../JI"è t STATE OF ALASKA I~ ALASKA ÒIL AND GAS CONSERVATION dLJlvlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ 1. Status of Well Classification of Service Well OIL: GAS: X SUSPENDED: ABANDONED: SERVICE: 2. Name ~f Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 201-193 3. Address 8. API Number P. O. Box 196247, Anchorage, Ak 99519 50- 283-20100 4. Location of well at surface .. "''''''''..c" ¡tOCA 'I1OI<IS 9. Unit or Lease Name 3681' FSL, 2117' FEL, Sec. 33, T14N, R9W, SM ." :';'rii_E~'~':{,;';~' I&~. Pretty Creek Unit At Top Producing Interval ,~ ,Bi, T~~' 10. Well Number 971' FSL, 2592' FEL, Sec. 33, T14N, R9W, SM ! .-iL3.~~yí Pretty Creek Unit NO.4 At Total Depth ] VCnf¡-::!:~,' : -. ,,::~~t' 11. Field and Pool ' -Æ "." ¡.'. '" .,1 .. ., ~.... ,jI;I .\_"'f'....,.,,~~roy':'~'I,...."::¡"',.;',' 3790' FSL, 2922' FEL, Sec. 4, T13N, R9W, SM ,L ~:::__., -~~=:"" c;' 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Pretty Creek 100' KB above MSL ADL-18772 12. Date Spudded 13. Date T.D. Reached 114. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 10/12/01 11/3/01 11/30/01 completed NA 3 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 9,580' MD/7,566' TVD 5584' MD/3979' TVD Yes: X No: NA feet MD NA 22. Type Electric or Other Logs Run Anadri ILWD GR/Res/Neutron/Density E-Line CBT/USIT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE wr. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 68# J-55 0 120' N/A Driven N/A 9-5/8" 47# L-80 0 2,386' 12-1/4" 756 sx N/A 7" 29# L-80 0 6,942' 8-1/2" 1363 sx N/A 24. Perforations open to Production (MD+ TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 4,372' 4,372' Sterling 4507'-4514' MD / 3,274'-3,280' TVD, 4-5/8", 12SPF 2-3/8" 2,517' N/A (Heater String) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Beluga 5152'-5172' MD / 3,679'-3,692' TVD, 4-5/8", 12SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4,507-4,514' 405 Ibs 30/50 Gravel Pack Sand Beluga 5,566'-5,577' MD / 3,968'-3,975' TVD, 4-5/8", 12SPF 5,152'-5,172' 4,733 Ibs 30/50 Gravel Pack Sand 5,566-5,577' 3,200 Ibs 50/50 Gravel Pack Sand 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 12/14/2001 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 1/23/02 24 TEST PERIOD => 6,190 .4 N/A Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) Press. 1130 0 24-HOUR RATE => 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED JAN 3 1 Z002 Alaska Oil & Gas Cone. CommiSSiOn And1or8ge Form 10-407 Rev. 7-1-80 CONTO, UEpON ~EVERSE SIDE k i G t r~ f\ l~BDMS 8Fl Submit in duplicate ÆB ? 2002 ~f . 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Beluga Fm. Top Tyonek Fm. 5108 9068 3648 7070 RECEIVED JAN 3 1 2002 Alaska Oil & Gas Cons. commisSiOn Anchorage 31. LIST OF ATTACHMENTS Wellbore schematic, Daily Summary of Rig Operations, Directional Survey Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge )/ll[ Title Drillina Manaaer- Date /-2 L) -0:2- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ORIGINAL UNOCALe ( Pretty Creek Unit No.4 Summary 10/9/01 - 12/15/01 DAY 1 10/9/01 MIRU KHR NO.9 DAY 2 10/10/01 CO NT. RU. DAY 3 10/11/01 NIPPLE UP 13-5/8" DIVERTER. FUNCTION TEST DIVERTER. DAY 4 10/12/01 MU CLEAN OUT ASSY. SPUD WELL AT 3:30 AM. DRILL 12-1/4" HOLE TO 187'. POOH. LD BHA. MU 12-1/4" BIT, 9-5/8" MOTOR/DIRECTIONAL BHA NO.2. DIRECTIONALLY DRILL FROM 187' TO 1289' BUILDING 4/100'. DAYS 10/13/01 CONT. DIRECTIONALLY DRILL. TD HOLE SECTION AT 2398' MD/1976'TVD. CIRC. AND CONDITION. BACK REAM OUT OF HOLE. MODERATE AMOUNTS OF GRAVEL OVER SHAKERS. POOH TO 200'. TIH TO 1780'. WASH AND REAM TO BOTTOM. CIRCULATE AND CLEAN HOLE. DAY 6 10/14/01 CIRC. HIGH VIS SWEEP. RECOVER SMALL AMOUNT OF GRAVEL. ROTATE AND PUMP OUT OF HOLE TO 801'. POOH. LD BHA. RU TO RUN 9-5/8" SURFACE CASING. RU AND RUN 9-5/8", 47#, L-80, BUTRESS TO 2395'. CIRC AND CONDITION MUD. CEMENT WITH 210 BBLS/627 SX (50 % EXCESS) 13 PPG, G LEAD AND 27 BBLS/129 SX (50% EXCESS) 15.8 PPG G. BUMP PLUG WITH 1500 PSI. FLOATS HOLDING. FULL RETURNS THROUGHOUT JOB. CEMENT TO SURFACE. RD CEMENT EQUIPMENT. INSTALL 9-5/8" PACK OFF. ND DIVERTER. DAY 7 10/15/01 CONT. ND DIVERTER. NU CAMERON 11 " MULTI-BOWL WELLHEAD SYSTEM. TEST SEALS AND PACK OFF TO 3,000 PSI. NU 11", 5k BOPE. TEST BOPE TO 250/3000 PSI. PULL TEST PLUG AND INSTALL WEAR BUSHING. DAY 8 10/16/01 PU DIRECTIONAL DRILLING BHA NO.3. 8-1/2" PDC, 6-3/4" MOTOR AT .78 DEG AKO. RIH. TAG CEMENT AT 2284'. TEST CACING TO 1,500 PSI. GOOD TEST. CLEAN OUT CEMENT AND FLOAT COLLAR. BUILD NEW MUD SYSTEM. CHANGE OVER WELL TO 9.3 PPG MI peD 4 Summary.doc Page 1 of 10 1/24/02/3:57 PM UNOCALO ( Pretty Creek Unit No.4 Summary 10/9/01 - 12/15/01 FLOW PRO MUD SYSTEM. DRILL 20' OF NEW HOLE TO 2418'. PERFORM LOT TO 18.4 EMW (.959 PSI/FT). DRILL TO 2542. DAY 9 10/17/01 CONT DRILLING FROM 2542'-3918'. DAY 10 10/18/01 CONT DRILLING FROM 3918' TO 4801'. DAY 11 10/19/01 CONT DRILLING FROM 4901 '-5544'. DAY 12 10/20/01 CONT DRILLING 5544-6157'. DAY 13 10/21/01 CONT DRILLING FROM 6157'-6841'. RAISE MUD WEIGHT TO 10 PPG DUE TO CONNECTION GAS. DAY 14 10/22/01 DRILL TO SECTION TO OF 6954' PUMP HIGH WTNIS SWEEP, LARGE AMOUNT OF CUTTINGS TO SURFACE. POOH. START BACK REAMING AT 6583'. HOLE PACKING OFF AT TIMES. CONT REAM OUT OF HOLE AND CIRCULATING TO CLEAN HOLE. DAY 15 10/23/01 CONT. BACK REAMING TO SHOE. POOH. LAY DOWN LWD. RIH WITH 8-1/2" BIT ON MOTOR FOR WIPER TRIP. RIH TO 4312', CBU. WASH FROM 4312' TO 4510'. WORK THROUGH TIGHT SPOT AT 4510'. WASH AND REAM 4510'-4867'. CBU. CAOL BACK AT SURFACE. RIH TO 5242'. WASH FROM 5242' TO 5615'. RIH TO 6359'. DAY 16 10/24/01 CONT. RIH TO 6575' WAS AND REAM TO BOTTOM AT 6954'. NO FILL ON BOTTOM. CIRCULATE AND CONDITION MUD. POOH. GOOD TRIP OUT. LD BHA. CHANGE RAMS TO 7". DRIFT 7" CASING HANGER THROUGH BOPE. SHELL TEST BOPS 250/3000 PSI. RU TO RUN 7" CASING. RIH WITH 7", 29#, L-80, KC BUTTRESS CASING TO 1535'. DAY 17 10/25/01 pev 4 Summary.doc Page 2 of 10 1/24/02/3:57 PM UNOCALG) ( Pretty Creek Unit No.4 Summary 10/9/01 - 12/15/01 CONT. RIH WITH 7" CASING. WORK PAST TIGHT SPOT 4510'-4565'. UNABLE TO GET PAST 4565'. BREAK CIRC. HOLE PACKING OFF WITH SHOE AT 4559'. ROTATE 7" CASING. PACKING OFF. DAY 18 10/26/01 CONT WORKING CASING AT 4559'. WORK CASING TO 4637'. RIH TO 4783'. WORK THROGH TIGHT HOLE 4783'-4808'. RIH TO 6941'. DAY 19 10/27/01 RU DOWELL. CEMENT 7" WITH 106 BBLS I 250 SX, 12 PPG LlTECRETE CEMENT. BUMP PLUG WITH 2200 PSI. NO LOSSES DURING JOB. RD CEMENT EQUIPMENT. RUN 7" CASING PACK OFF. CANGE TOP RAMS TO 4". TEST BOPE 250/3000 PSI. PICK UP DIRECTIONAL DRILLING BHA NO.4 = 6" PDC BIT, 4-3/4" MOTOR WI .78 DEG AKO, MWD. DAY 20 10/28/01 RIH. PU ADDITIONAL 4" DRILL PIPE. TEST CASING TO 3000 PSI. GOOD TEST. DRILL FLOAT EQUIPMENT AND 20' OF NEW 6" HOLE. PERFORM LEAK OFF TEST TO 15.7 PPG EMW (.81 PSIIFT FRAC GRAD) DIRECTIONALL Y DRILL TO 7107'. DAY 21 10/29/01 DRILL 6" HOLE FROM 7108' TO 7585' DAY 22 10/30/01 DRILL FROM 7585' TO 7907'. SHORT TRIP TO 7" SHOE AT 6941'. HOLE IN GOOD CONDITION. RIH AND WASH LAST STAND TO BOTTOM. DRILL TO 8000' DAY 23 10/31/01 DRILL FROM 8000' TO 8343' DAY 24 11/1/01 DRILL FROM 8343' TO 8783'. DAY 25 11/2/01 DRILL FROM 8783' TO 9268' DAY 26 11/3/01 DRILL FROM 9268' TO 9580'. CIRC. FOR SHORT TRIP. SHORT TRIP TO 8189' RIH TO TD AND CIRC FOR LOGS. SOME TIGHT HOLE AT BOTTOM. POOH FOR WIRE LINE LOGS. peu 4 Summary.doc Page 3 of 10 1/24/02/3:57 PM UNOCALe ( Pretty Creek Unit No.4 Summary 10/9/01 - 12/15/01 DAY 27 11/4/01 LD BHA. RU SCHLUMBERGER E-LlNE "PLATFORM EXPRESS" TRIPLE COMBO TOOLS. RIH. UNABLE TO GET BELOW 8645'. LOG OUT OF HOLE. TEST BOPE 250/3000 PSI. MAKE UP SCHLUMBERGER USIT/CBL. RIH. LOG 7" CASING FROM 6920' TO 2192'. RIG DOWN E-LlNE. PU ANADRIL LWD/AND TOOL. DAY 28 11/5/01 COMPLETE PU BHA. RIH TO 8471'. LOG 6' HOLE FROM 8500' TO 9580'. TIGHT HOLE 8523'-8547'. PACKING OFF. CBU. POOH. LD LWD/ADN TOOLS. DAY 29 11/6/01 CO NT. LD BHA. RIH. POOH LD DRILL PIPE WHILE ANALlZING TYONEK LOG DATA. RECEIVE APPROVAL FROM AOGCC TO ABANDON TYONEK OPEN HOLE SECTION. RIH WITH 7" RETAINER ON DRILL PIPE. SET RETAINER AT 6862' ( 79' FROM SHOE). TEST RETAINER WITH 1000 PSI AND 30K DOWNWEIGHT. EST INJECTION RATE Y2 BPM @ 2750 PSI, 1 BPM @ 3100 PSI AND 3 BPM @ 3300 PSI. UNSTING FROM RETAINER. MIX AND PUMP 17 BBLS (82 SX) OF CLASS G, 15.8 PPG SLURRY TO WITHIN 5 BBLS OF STINGER. STAB INTO RETAINER AND SQUEEZE CEMENT AWAY AT 2 BPM W/2000 PSI AND FINISHING W/1 BPM @ 2750 PSI PLACING 12 BBLS OF CEMENT BELOW RETAINER (266' OF CEMENT IN GAGE 6" HOLE). UNSTING AND SPOT 5 BBLS (134') OF CEMENT ONTOP OF RETAINER. PULL TO 6396' AND REVERSE PIPE CLEAN. PRESSURE TEST PLUG TO 1500 PSI FOR 15 MIN WITH NO BLEED OFF. POOH. DAY 30 11/7/01 CONT. POOH. LD RUNNING TOOL/STINGER. MU CLEAN OUT BHA = 6" MILL TOOTH BIT AND 7" CASING SCRAPER. RIH TO 6710'. PUMP 50 BBL HIGH VIS SWEEP AND DISPLACE WELL TO WATER. FLUSH SURFACE EQUIPMENT. CLEAN PITS. DAY 31 11/8/01 CLEAN PITS. FILL PITS WITH FRESH WATER. MIX 9.7 PPG KCL/NACI COMPLETION BRINE. DAY 32 11/9/01 CONT MIX 9.7 PPG KCL/NACI COMPLETION BRINE. FILTER FLUID TO 20 NTU'S. AFTER LENGTHY REVIEW OF USIT/CBL LOG DECISION MADE TO PERFORATE 7" AND EVALUATE CEMENT. MIX COMPLETION FLUID TO 10.2 PPG AND VIS SYSTEM. DAY 33 11/10/01 CONT. BUILDING SYSTEM. POOH WITH BIT AND CASING SCRAPER. LD BHA. RU E-LlNE UNIT. RIH AND PERFORATE 5594'-5596' WITH 4-1/2" HS CARRIER, 4 SPF GUN. POOH. ALL SHOTS FIRED. CLOSE BLINDS AND AND PUMPED DOWN 7". ESTABLISHED pev 4 Summary.doc Page 4 of 10 1/24/02/3:57 PM UNOCAL8 (I Pretty Creek Unit No.4 Summary 10/9/01 - 12/15/01 RETURNS UP 7" ANNULUS. CIRCULATE UNTIL GOOD MUD TO SURFACE. MU BAKER 7" RETAINER ON E-LlNE. RIH AND SET RETAINER AT 5584' TYING INTO LWD/CDR LOG DATED 10/18/01-10/22/01. POOH. RIH WITH STINGER ON DRILL PIPE. STAB INTO RETAINER. BREAK CIRCULATION WITH FULL RETURNS AT SURFACE. 11/11/01 DAY 34 MIX AND PUMP 230 BBLS /1113 SX OF 15.6 PPG, G CEMENT. DISPLACE WITH WATER. 12 BBLS OF CEMENT RETURNS TO SURFACE. CUT DISPLACMENT SHORT BY 5 BBLS. UNSTING FROM RETAINER AND REVERSE OUT DRILL PIPE. FULL RETURNS THROUGHOUT JOB. POOH WITH RETAINER RUNNING TOOL/STRINGER. LD BHA. MU 6" MILL TOOTH BIT AND 7" CASING SCRAPER. RIH TO RETAINER AT 5584' ELM. DISPLACE HOLE TO FRESH WATER. ROUND TRIP BIT AND SCRAPER TO CLEAN HOLE. CLEAN PITS. 11/12/01 DAY 35 CLEAN PITS AND CIRC. HOLE CLEAN. POOH. TEST BOPE 250/3000 PSI. TEST WHITNESSED BY AOGCC INSPECTOR CHUCK SCHEVE. CONT. BUILDING 9.7PPG KCI/NACI COMPLETION FLUID. 11/13/01 DAY 36 BUILD 9.7 PPG KCL/NACI COMPLETION BRINE AND FILTER SAME TO 18 NTU'S. MU HALLIBURTON TCP ASSEMBLY. RIH TO 4065' CONTINUE BUILDING VOLUME IN PITS. 11/14/01 DAY 37 CONT BUILDING VOLUME IN PITS. TAG RETAINER FOR CORRELATION. MU HALLIBURTON LINES AT SURFACE. TEST LINES TO 3000 PSI. PU AND PUT GUNS ON DEPTH. PRESSURE UP DRILL PIPE TO 1800 PSI TO DETONATE GUNS. PERFORATE BELUGA FROM 5556'-5577'ELM (11') WITH HALLIBURTON 4-5/8" ALTERNATING SHOT, 6SPF, RDX OMNI, 25 GRAM BIG HOLE AND 6SPF RDX, OMNI, 22.7 GRAM, DEEP PENETRATOR (12SPF TOTAL). GOOD INITIAL BLOW. DIED QUICKLY. WITH 500 PSI ON BACKSIDE, PU BYPASS AND REVERSE OUT. SOME GAS iN RETURNS. MONITOR WELL. STATIC LOSSES = 1.5 BPH. POOH WITH GUNS. LD TCP ASSY. ALL SHOTS FIRED. MU CLEAN OUT BHA. 6" BIT, 7" SCRAPER AND 2 EA. BOOT BASKETS. RIH TO 5510'. WASH DOWN TO RETAINER AT 5584' ELM. RUN SCRAPER THROUGH PERFS AND CBU. FILTER ACTIVE SYSTEM. 11/15/01 DAY 38 FILTER ACTIVE SYSTEM. POOH WITH CLEAN OUT BHA. LD BHA. RECOVERED APPRX. 2 QRTS OF PERF DEBRIS FROM JUNK BASKETS. RU TO PU GRAVEL PACK ASSEMBLY NO.1. PU 4" BULL NOSE, 49.56' OF 4" BAKERWELD WIRE WRAP .12 GA SCREEN AND 4" BLANK. PU 2-7/8" INNER ISOLATION STRING WITH 2-7/8" SLIDING SLEEVE AND X- NIPPLE AND RUN INSIDE OF 4" SCREEN. PU GRAVEL PACK ASSEMBLY = SHEAR OUT pev 4 Summary.doc Page 5 of 10 1/24/02/3:57 PM UNOCALe ( Pretty Creek Unit No.4 Summary 10/9/01 - 12/15/01 SAFETY JT. , SEAL BORE, GRAVEL PACK SLIDING SLEEVE, EXTENSION AND SC-1 GRAVEL PACK PACKER. RIH TO RETAINER AT 5584' ELM. 11/16/01 DAY 39 RU SURFACE LINES AND TEST TO 3500 PSI. DROP PACKER SETTING BALL AND PUMP TO SEAT. PRESSURE UP IN STAGES TO 3100 PSI AND SET PACKER AT 5181' ELM.. PULL TEST 25K OVER. REVERSE OUT BALL. PUMP 5 BBL POLYMER PILL. THAW FROZEN DOWELL LINE. PRESSURE TEST LINES TO 6500 PSI. PUMP 5.5 BBLS OF DRILL PIPE PICKLE AND PUMP TO CROSSOVER TOOL. REVERSE OUT AND RECOVER PILL AT SURFACE. WITH 1000 PSI ON ANNULUS, PERFORM STEP RATE INJECTION TEST. 1 BPM = 1497 PSI, 2 BPM = 1780 PSI, 4 BPM = 2115 PSI, 6 BPM = 2380 PSI, 8 BPM = 2730 PSI, 10 BPM = 3130 PSI. SHUT DOWN. ANALlZE RESULTS. COMMENCE PUMPING 1 BPM = 1181 PSI, 2 BPM = 1780 PSI, 4.5 BPM = 1914 PSI, 7.3 BPM = 2381 PSI, 10.2 BPM = 2999 PSI. START INFUSING 30/50 SAND AT 1 PPA RAMPING UP TO 2 PPA. PUMP 3600 LBS OF SAND AT 10 BPM W/2641 PSI. AFTER TOTAL DISPLACMENT OF 38 BBLS CUT RATE TO 6 BPM. = 1671 PSI. AFTER TOTAL DISPLACMENT OF 44 BBLS CUT RATE TO 4 BPM = 1364 PSI. AFTER DISPLACING 46 BBLS CUT RATE TO 2 BPM =1000 PSI. SCREEN OUT WITH 3000 PSI. BLEED ANNULUS PRESSURE FROM 1000 PSI TO 500 PSI. PULL CROSSOVER TOOL TO REVERSE POSITION AND REVERSE DRILL PIPE CLEAN WITH RIG PUMPS. RECOVER APPROX. 400 LBS OF SAND AT SURFACE. RESTRESS PACK 2500 PSI AT 1 BPM. INDIACTES 46.8' OF BLANK COVERED. PULL CROSSOVER TOOL OUT OF GRAVEL PACK. ATEMPT TO TEST ISOLATION ASSEMBLY TO 1500 PSI WITHOUT SUCCESS. LOWER CROSOVER TOOL INTO GRAVEL PACK AND TEST PACKER AND 2-7/8" ISOLATION ASSEMBLY TO 1500 PSI. TEST INDICATES THAT GRAVEL PACK SLlIDING SLEEVE DID NOT CLOSE. PULL OUT OF GP ASSY WITH CROSSOVER TOOL. HOLE TAKING 3.3 BPH INDICATING THAT SLEEVE STILL IN OPEN POSITION. 11/17/01 DAY 40 POOH. LD GRAVEL PACK CROSSOVER TOOL. PU HALLIBURTON 4-5/8" TCP ASSY. RIH. DROP OF PACKER PLUG IN SC-1 PACKER AT 5181'. RU E-LlNE. RIH WITH GAMMA RAY TOOL. TIE IN GUNS WITH ANADRIL CDR RESISTIVITY LOG DATED 10/16-10/22/01. PLACE GUNS ON DEPTH AND SET CHAMP PACKER. RU SURFACE LINES AND TEST TO 3000PSI. PERFORATE BELUGA 5152'- 5162' ELM WITH HALLIBURTON 4-5/8", 12SPF, RDX OMNI, 25 GRAM BIG HOLE PERFORATORS. VERY STRONG BLOW AT SURFACE. PU BYPASS ON CHAMP PACKER AND REVERSE OUT DRILL PIPE. GAS IN RETURNS. UNSTEAT PACKER. LOSSES AT .5 BPH. CIRC. LONG WAY. RD SURFACE LINES. POOH TO 1500'. CBU, DIRTY FLUID TO SURFACE. POOH. ,---. 11/18/01 DAY 41 POOH. CBU AT 1400'. SMALL AMOUNT OF GAS TO SURFACE. CONT POOH. LD BHA. ONE SHOT NOT FIRED. PU PLUG RETRIEVING TOOL AND 7" CASING SCRAPER AND 2 EA. BOOT BASKETS. RIH TO 5162'. WORK SCRAPER THROUGH PERFS. CIRCULATE DOWN TO PLUG. LATCH AND PULL PLUG W/10K OVER. MONITOR WELL, STATIC LOSS pev 4 Summary.doc Page 6 of 10 1/24/02/3:57 PM UNOCALe ( Pretty Creek Unit No.4 Summary 10/9/01 - 12/15/01 = 1 BPH. POOH. LD BHA. RECOVER 2 QUARTS FROM BOOT BASKETS. SERVICE RIG. RU TO RUN GRAVEL PACK NO.2. PU SNAP LATCH, 43.43' OF 4" BAKERWELD WIRE WRAP .12 GA SCREEN AND 4" BLANK. PU 2-7/8" INNER ISOLATION STRING WITH 2-7/8" SLIDING SLEEVE AND X-NIPPLE AND RUN INSIDE OF 4" SCREEN. PU GRAVEL PACK ASSEMBLY = SHEAR OUT SAFETY JT. , SEAL BORE, GRAVEL PACK SLIDING SLEEVE, SEAL BORE, EXTENSION AND SC-1 GRAVEL PACK PACKER. 11/19/01 DAY 42 PU 2-7/8" INNER ISOLATION STRING WITH 2-7/8" SLIDING SLEEVE AND X-NIPPLE AND RUN INSIDE OF 4" SCREEN. PU GRAVEL PACK ASSEMBLY = SHEAR OUT SAFETY JT., SEAL BORE, GRAVEL PACK SLIDING SLEEVE, EXTENSION AND SC-1 GRAVEL PACK PACKER. RIH. LATCH INTO PACKER AT 5181'. RU SURFACE LINES AND TEST TO 3500 PSI. DROP PACKER SETTING BALL AND PUMP TO SEAT. PRESSURE UP IN STAGES TO 3100 PSI AND SET PACKER AT 4526' ELM. PULL TEST 15K. ATTEMPT TO PRESSURE TEST ANNULUST TO 1000 PSI. NO TEST. COMMUNICATING TO DRILL PIPE. REPEAT WITH NO TEST. REVERSE OUT BALL. PU CROSSOVER TOOL 2' TO ISOLATE IN PACKER BORE. RETEST ANNULUS TO 1000 PSI. GOOD TEST. INDICATES THAT CROSSOVER TOOL AND PACKER HAVE INTEGRITY. PULL CROSSOVER TOOL OUT OF PACKER. GOOD INDICATION OF COLLETS SHIFTING GRAVEL PACK SLIDING SLEEVE SHUT. ATTEMPT TO PRESSURE TEST 7" CASING AND ALL ISOLATION ASSEMBLIES. NO TEST. RD GRAVEL PACK LINES. POOH WI CROSSOVER TOOL. LD SAME. NO INDICATIONS OF DAMAGE. PRESSURE TEST BOPE 250/3000 PSI. 11/20/01 DAY 43 CONT. TEST BOPE. MU TEST SEAL ASSEMBLY. RIH. TAG SC-1 PACKER AT 4526' STAB IN. TEST BACKSIDE TO 1500 PSI. OK. PRESSURE TEST DOWN DRILL PIPE. NO TEST. RU POLLARD SLlCKLlNE. TEST LUBRICATOR TO 2000 PSI. PRESSUR EDOWN DRILL PIPE THREE TIMES TO DETERMINE LOSS RATE. PRESSURE DROP FROM 1600 TO 500 PSI IN APPROX 2 MIN. RIH WITH IB' SHIFTING TOOL. ATTEMPT TO DETERMINE IF SLIDING SLEEVE AT 5172' IS CLOSED. NO INDICATION THAT SLEEVE IS OPEN. POOH. MU NYLON ROPE FLAG ON GAGE RING. RIH. MAKE PASES FROM 5260'-5150' WHILE MAINTAINING 800 PSI ON DRILL PIPE. NO INDICATION OFF LEAK. POOH. MU POSITIVE SHIFTING TOOL. RIH. UNABLE TO LOCATE. POOH. RD POLLARD. UNSTING FROM SC- 1 WITH TEST SEALS. POOH WITH ASSEMBLY. PU SC-1 RETRIVING TOOL. RIH. 11/21/01 DAY 44 RIH TO 4500'. WASH DOWN TO PACKER. LATCH INTO SC-1 PACKER. PULL 22K OVER AND RELEASE PACKER. PULL 25 K AND SNAP OUT OF LOWER PACKER WITH SEALS. CIRCULATE UNTIL RETURNS = 19 NTU. POOH. LD GRAVEL PACK ASSEMBLY. LOWER SEALS DAMAGED BADLY. MU 2-7/8" CLEAN OUT STINGER AND S-22 SEAL ASSEMBLY. RIH. STAB INTO PACKER AT 5181'. WASH THROUGH BORE. LAND SEALS. TEST ISOLATION STRING TO 1500 PSI. GOOD TEST. PU ABOVE GRAVEL PACK PORT AND RETEST. RE-TEST. NO TEST. BLEED FROM 1400 TO 900 PSI IN 4 MIN. CIRCULATE. REPEAT TEST WITH SAME RESULTS. CIRCULATE AND FILTER BRINE. PCU 4 Summary.doc Page 7 of 10 1/24/02/3:57 PM UNOCALe ( Pretty Creek Unit No.4 Summary 10/9/01 - 12/15/01 11/22/01 DAY 45 CONT. CIRC AND FILTER BRINE. MONITOR WELL. POOH. LD BHA. SEALS IN GOOD SHAPE. PU SNAP LATCH ASSY WI 2.313" X-NIPPLE WI RHC PLUG AND PRONG INSTALLED. PU 43.43' OF 4" BAKERWELD WIRE WRAP .12 GA SCREEN AND 4" BLANK. PU 2-7/8" INNER ISOLATION STRING WITH 2-7/8" SLIDING SLEEVE AND X-NIPPLE AND RUN INSIDE OF 4" SCREEN. SPACE OUT. PRESSURE TEST INNER STRING AN SEALS TO 1500 PSI. RU SLlCKLlNE. 11/23/01 DAY 46 RETRIEVE PRONG AND PLUG BODY. RD SLlCKLlNE. PU REMAINDER OF GRAVEL PACK ASSEMBLY = SHEAR OUT SAFETY JT. , SEAL BORE, GRAVEL PACK SLIDING SLEEVE, SEAL BORE, EXTENSION AND SC-1 GRAVEL PACK PACKER. RIH AND LATCH INTO SC-1 PACKER AT 5181'. UN-SNAP FROM PACKER TWO TIMES WITH 10K OVER. RU LINES AND TEST LINES TO 3500 PSI. DROP PACKER SETTING BALL AND PUMP TO SEAT. PRESSURE UP IN STAGES TO 3100 PSI TO SET PACKER. PULL TEST PACKER WITH 20K OVER. PRESSURE TEST ANNULUS TO 2000 PSI. RELEASE FROM PACKER. REVERSE OUT BALL. RU DOWELL LINES AND PRESSURE TEST TO 6500 PSI. PLACE CROSSOVER TOOL IN SQUEEZE POSTION. PRESSURE ANNULUS TO 1000 PSI AND PERFORM STEP RATE INJECTION TEST. 1 BPM = 1140 PSI, 2 BPM = 1754 PSI, 3.8 BPM = 2175 PSI, 6 BPM = 2573 PSI, 8 BPM = 2930 PSI, 10 BPM = 3390 PSI. START INFUSING SAND AT 1 PPA RAMP UP TO 2 PPA. PUMP A TOTAL OF 5393 LBS OF 30/50 SAND AT 10 BPM WI 3475 PSI. AFTER PUMPING 27 BBLS CUT RATE TO 6 BPM WI 2349 PSI. AFTER 33 BBL DISPLACMENT CUT RATE TO 4 BPM W 1900 PSI. AFTER40 BBLS CUT RATE TO 2 BPM WI 1612 PSI. SCREEN OUT WITH 43 AWAY. PRESSURE INCREASED FROM 1600 TO 3100 PSI. SHUT DOWN PUMPS. WITH 458 PSI ON ANNULUS. PU TO REVERSE POSITION AND REVERSE OUT DRILL PIPE WITH RIG PUMPS. RECOVER APPROX 660 LBS OF SAND AT SURFACE. CONT. REVERSE UNTIL CLEAN. SET DOWN IN SQUEEZE POSITIONA AND RESTRESS PACK TO 2700 PSI AT 1 BPM. RESTRESS INDICATES 173LBS/FT OF SAND BEHAIND PIPE AND 84.4' OF BLANK COVERAGE. PULL OUT OF GRAVEL PACK WITH CROSSOVER TOOL. PRESSURE TEST BOTH ISOLATION ASSEMBLIES AND THE 7" TO SURFACE WITH 1660 PSI. POOH. LD BHA. 11/24/01 DAY 47 CONT CLEAR FLOOR OF TOOLS. PU HALLIBURTON 4-5/8" TCP ASSY. RIH. DROP OF PACKER LUG IN SC-1 PACKER AT 4526'. RU E-LlNE. RIH WITH GAMMA RAY TOOL. TIE IN GUNS WITH ANADRIL COR RESISTIVITY LOG DATED 10/16-10/22/01. PLACE GUNS ON DEPTH AND SET CHAMP PACKER. RU SURFACE LINES AND TEST TO 3000PSI. PERFORATE STERLING 4507'- 4514' ELM WITH HALLIBURTON 4-5/8" ALTERNATING SHOT, 6SPF, RDX OMNI, 25 GRAM BIG HOLE AND 6SPF RDX, OMNI, 22.7 GRAM, DEEP PENETRATOR (12SPF TOTAL). STRONG BLOW AT SURFACE. PU BYPASS ON CHAMP PACKER AND REVERSE OUT DRILL PIPE. GAS IN RETURNS. UNSTEAT PACKER. LOSSES AT .5 BPH. CIRC. LONG WAY. RD SURFACE LINES. POOH TO 1500'. CBU, SOME GAS TO SURFACE. POOH TO 819'. ADDITIONAL GAS TO SURFACE FROM GUNS. - PCU 4 Summary.doc Page 8 of 10 1/24/02/3:57 PM UNOCAL8 ( Pretty Creek Unit No.4 Summary 10/9/01 - 12/15/01 11/25/01 DAY 48 CBU. WELL STABLE. POOH AND LAY DOWN BHA. MU PLUG RETRIEVING TOOL, 7" 29# SCRAPER AND 2 EA. BOOT BASKETS. RIH. WASH DOWN TO PACKER PLUG AT 4536' DPM. LATCH PLUG AND PULL FREE WITH 12K OVER. CBU. POOH. LD BHA. PU DUMMY SEAL ASSY WITH 2-7/8" TAIL PIPE. RIH TO 4539' STAB INTO SC-1 PACKER AT 4526'. WASH THROUGH PACKER BORE. STAB SEALS INTO PACKER BORE AND UNSTING. CBU. GAS TO SURFACE. SHUT WELL IN. 60 OSI ON ANNULUS. CIRCULATE GAS OUT ON CHOKE. OPPEN ANNULAR. SOME GAS NOTED. CBU TWO TIMES. WELL STABLE. 11/26/01 DAY 49 POOH AND LD BHA. RU TO RUN GRAVEL PACK. PU GRAVEL PACK ASSY. NO.3. PU SNAP LATCH ASSY W/ 2.313" X-NIPPLE W/ RHC PLUG AND PRONG INSTALLED. PU 28.33' OF 4" BAKERWELD WIRE WRAP .12 GA SCREEN AND 4" BLANK. PU 2-7/8" INNER ISOLATION STRING WITH 2-7/8" SLIDING SLEEVE AND X-NIPPLE AND RUN INSIDE OF 4" SCREEN. SPACE OUT. RU POLLARD SLlCKLlNE. RIH WITH RHC PLUG AND SET IN 2.313" X NIPPLE. POOH. RUN RHC PRONG IN PLUG BODY. POOH. PRESSURE TEST INNER STRING AN SEALS TO 1500 PSI. 11/23/01 DAY 46 RETRIEVE PRONG AND PLUG BODY. RD SLlCKLlNE. PU 1.9" CS HYDRILL INNER STRING. PU GRAVEL PACK ASSY. PU REMAINDER OF GRAVEL PACK ASSEMBLY = SHEAR OUT SAFETY JT. , SEAL BORE, GRAVEL PACK SLIDING SLEEVE, SEAL BORE, EXTENSION AND SC-1 GRAVEL PACK PACKER. RIH WITH GRAVEL PACK NO.3 11/27/01 DAY 50 CONT RIH. CBU AT 4500'. SOME GAS TO SURFACE. SNAP INTO PACKER AT 4526' DPM. UNLATCH AND SNAP BACK IN. RU SURFACE LINES AND ATTEMPT TO PRESSURE TEST. TROUBLE SHOOT LEAK IN SURFACE LINES. TEST LINES TO 3500 PSI. DROP BALL AND PUMP TO SEAT. PRESSURE UP IN STAGES AND SET PACKER AT 4372'. PULL TEST PACKER 25K OVER. RELEASE FROM PACKER. REVERSE OUT BALL. SET DOWN IN CIRC POSITION. EST CIRC. PRESS. AT 1 BPM = 80 PSI, 2 BPM = 250 PSI. PERFORM STEP RATE INJECTION TEST AT 1 BPM = 439 PSI, 2 BPM = 1168 PSI, 4.25 BPM = 1758 PSI, 6 BPM = 2074 PSI, 8 BPM = 2390 PSI. OPEN CHOKE TO ESTABLISH 2 BPM RETURNS. INFUSE SAND AT 1 PPA AND RAMP TO 2 PPA. PUMP 2942 LBS OF 30/50 SAND AT 8 BPM AT 2285 PSI. SCREEN OUT WITH 4667 PSI. WITH 500 PSI ON ANNULUS PU CROSSOVER TOOL TO REVERSE POSITION. REVERSE OUT DRILL PIPE WITH RIG PUMPS. RECOVERED APPROX 2537 LBS OF SAND. RESTRESS PACK WITH 1500 PSI AT 1 BPM. INDICATES 11' OF BLANK COVERED. PULL CROSSOVER TOOL OUT OF GRAVEL PACK. ATTEMPT TO PRESSURE TEST ALL ISOLATION ASSEBLlES WITH OUT SUCCESS. DETERMINE NO.3 GRAVEL PACK SLIDING SLEEVE TO BE LEAKING. WILL SCAB WITH PRODUCTION SEALS. POOH LD DP. peD 4 Summary.doc Page 9 of 10 1/24/02/3:57 PM UNOCALe (' Pretty Creek Unit No.4 Summary 10/9/01 - 12/15/01 11/28/01 DAY 51 CONT. POOH LD DRILL PIPE AND COLLARS. CHANGE TOP RAMS TO 2-7/8" AND TEST 250/3000 PSI. RD TOP DRIVE. RU TO RUN COMPLETION. 11/29/01 DAY 52 RIG UP GBR TO RUN 2-7/8" COMPLETION. MU S-22 SEAL ASSEMBLY AND RIH WITH 2- 7/8",6.4#, L-80, BUTTRESS TUBING. SNAP INTO PACKER AT 4372' AND UNSNAP FOR SPACE OUT. MU HANGER. LAND HANGER. PRESSURE TEST 2-7/8" X 7" TO 1500 PSI. GOOD TEST. PRESSURE TEST DOWN 2-7/8" TO 1500 PSI TO TEST ISOLATION ASSEMBLIES. GOOD TEST. SET BPV IN LONG STRING. RU TO RUN HEATER STRING. RUN 2-3/8",4.6#, L-80, BUTTRESS HEATER STRING TO 2499' MU HANGER AND LAND SAME. NO BOPE. 11/30/01 DAY 53 NIPPLE UP CAMERON DUAL 5M TREE AND TEST TO 5000 PSI. DISPLACE HEATERSTRING AND ANNULUS TO HEATER FLUID. RELEASE RIG. RU PRODUCTION FACILITIES. peo 4 Summary.doc Page 10 of 10 1/24/02/3:57 PM ( UNOCALG ( ")retty Creek ,veIl No.4 Actual 11/29/01 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1 13-3/8" Surface 75' 9-518" 47 L-80 Butt Surface 2,398' 7" 29 L-80 Butt Surface 6,941' Tubing 2- 7 18" 6.4 L-80 Butt SC 4,372' 2-3/8" 4.6 L-80 Butt SC 2,517' A 2 3 NO. ] 2 3 4 5 6 7 8 9 JEWELRY DETAIL OD Item Dua] Tubing Hanger, 2-7/8" x 2-3/8", ]]" 5M SC-] Grave] Pack Packer Baker Weld Wire Wrapped Screen SC-] Grave] Pack Packer Baker Weld Wire Wrapped Screen SC-] Grave] Pack Packer Baker Weld Wire Wrapped Screen K-l Retainer K-l Retainer with 12 bbls cement below and 5 bbls above. Depth ID 4,372' 4,501 ' 4,526' 5,147' 5,181 ' 5,554' 5,584' 6,862' A Heater String 2-3/8", L-80, Butt SC 4 2,517' PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spr Comments 11/14/01 Sterling 4,507' 4,514' 7' 12 11/17/01 Beluga 5,152' 5,172' 20' 12 11/24/01 Beluga 5,566' 5,577' 11' 12 -, 5 6 7 8 9 PCU 4 Actual 11-29-01.doc TD = 9,502'MDI7,600'TVD Max Hole Angle = 51 deg DRAWN BY: tcb 4 .. - .. . - .- UNOCAL8 PCU #4" Actual Surveys Survey Report - Geodetic Report Date: Client: Field: Structure I Slot: Well: Borehole: UWUAPI.: Survey Name I Date: Tort I AHD I DDlI ERD ratio: Grid Coordinate System: Location Latllong: Location Grid NIE YIX: Grid Convergence Angle: Grid Scale Factor: Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: 19-Dec-2001 Unocal Pretty Creek Unn Pretty Creek Unn 4/ PCU #4 PCU #4 PCU #4 502832010000 PCU #4/ December 3, 2001 123.774° /5241.15 ft /5.915/ 0.693 NAD27 Alaska State Planes, Zone 4, US Feet N 611548.841, W 1505339.796 N 2654875.030 ftUS. E 342560.591 ftUS -0.78425026° 0.99992820 Schlumberuer Minimum Curvature / Lubinski 188.760° N 0.000 ft, E 0.000 ft KB 87.700 ft relative to MSL 0.000 ft relative to MSL +21.195° 55584.311 nT 73.956° December 03, 2001 BGGM 2000 True North +21.1950 Well Head ~ Station ID Grid Coordinates Northing I Easting 'flUS) (flUS) 2654875.03 342560.59 0.27 2654874.65 342559.68 0.49 2654874.06 342558.64 2.09 2654871.74 342556.98 2.01 2654866.47 342555.06 0.0 246.5 235.9 207.2 194.4 572.54 6.30 199.7 571.89 17.94 -16.92 -8.03 663.78 10.01 183.3 662.21 30.76 -29.55 -10.18 756.14 . 13.81 185.2 752.56 49.76 -48.55 -11.64 848.61 18.09 190.4 841.46 75.14 -73.68 -15.23 940.35 20.88 192.0 927.94 105.70 -103.68 -21.20 1035.24 25.67 193.9 1015.08 143.08 -140.20 -29.65 1128.66 29.65 192.8 1097.81 186.30 -182.40 -39.61 1221.73 33.24 192.9 1177.20 234.72 -229.72 -50.41 1314.17 36.97 192.8 1252.81 287.73 -281.54 -62.25 1408.05 41.10 192.4 1325.71 346.71 -339.23 -75.14 1501.90 43.80 191.0 1394.96 409.97 -401.25 -87.97 1593.81 44.49 189.6 1460.91 473.95 -464.24 -99.37 1687.29 46.54 188.4 1526.41 540.64 -530.11 -109.77 PCU #4 Actual Surveys.xls Page 1 of 4 2.13 2654858.23 4.76 2654845.62 4.13 2654826.65 4.88 2654801.58 3.09 2654771.66 5.11 2654735.26 4.30 2654693.21 3.86 2654646.04 4.04 2654594.39 4.41 2654536.89 342552.33 342550.01 342548.29 342544.35 342537.97 342529.03 342518.49 342507.04 342494.50 342480.82 N 61 1548.841 W 1505339.796 N 61 1548.837 W 1505339.814 N 61 15 48.831 W 150 53 39.835 N 61 1548.808 W 1505339.869 N 61 1548.756 W 1505339.906 f j I N 61 1548.675 W 1505339.960 f N 61 1548.550 W 1505340.004 ' N 61 15 48.363 W 150 53 40.034 N611548.116 W1505340.107 N 611547.820 W 1505340.229 N 611547.461 W 150 53 40.40~: N 61 1547.045 W 15053 40.6( N 61 1546.579 W 1505340.82/ N 61 1546.069 W 1505341.069 N 611545.501 W 1505341.332 3.05 2654475.05 342467.15 N 611544.890 W 1505341.594 1.32 2654412.23 342454.88 N 61 15 44.270 W 150 53 41.828 2.36 2654346.52 342443.58 N 61 15 43.621 W 150 53 42.040 ~- 12/19/2001-9:08 AM t. I StationiD I . ..... . . . . . . ".., . ,.... . ,.-. . ,~-, . . N 6115 42.950 W 1505342.243 N 61 1542.246 W 1505342.433 1967.07 51.26 185.8 1705.76 755.16 -742.98 -136.94 0.71 2654134.05 342413.51 N 611541.525 W 1505342.596 2062.59 50.84 186.5 1765.81 829.37 -816.83 -144.88 0.73 2654060.32 342404.56 N 61 1540.798 W 1505342.758 2155.08 50.22 187.2 1824.60 900.73 -887.72 -153.37 0.87 2653989.55 342395.10 N 611540.100 W 1505342.932 2247.99 51.07 188.6 1883.52 972.56 -958.88 -163.24 1.53 2653918.54 342384.25 N 611539.399 W 1505343.133 2339.51 51.29 189.1 1940.89 1043.86 -1029.33 -174.22 0.45 2653848.25 342372.31 N 61 1538.706 W 1505343.358 2445.46 50.43 189.1 2007.77 1126.03 -1110.48 -187.20 0.81 2653767.30 342358.22 N 611537.907 W 1505343.623 2538.37 50.91 190.2 2066.65 1197.89 -1181.32 -199.26 1.07 2653696.63 342345.19 N 61 1537.209 W 1505343.870 2633.07 51.77 192.1 2125.82 1271.77 -1253.87 -213.57 1.79 2653624.30 342329.89 N 6115 36.495 W 1505344.163 2724.68 51.83 191.3 2182.47 1343.66 -1324.36 -228.17 0.68 2653554.01 342314.34 N 61 1535.801 W 1505344.461 2818.82 51.43 191.3 2240.90 1417.40 -1396.74 -242.64 0.43 2653481.85 342298.87 N 61 15 35.088 W 150 53 44. 75~, 2912.02 51.24 191.0 2299.13 1490.10 -1468.13 -256.75 0.31 2653410.66 342283.79 N 61 15 34.385 W 150 53 45.04... 3004.39 51.04 191.3 2357.09 1561.97 -1538.69 -270.67 0.30 2653340.30 34~268.90 N 61 15 33.690 W 150 53 45.330 3097.88 51.39 191.0 2415.65 1634.78 -1610.20 -284.73 0.46 2653269.00 342253.87 N 61 1532.986 W 1505345.617 3191.17 51.10 191.3 2474.05 1707.47 -1681.58 -298.78 0.43 2653197.82 342238.84 N 61 15 32.283 W 150 53 45.904 3284.83 51.31 191.2 2532.73 1780.40 -1753.17 -313.06 0.24 2653126.44 342223.59 N 6115 31.578 W 1505346.196 3378.32 51.06 190.9 2591.33 1853.18 -1824.66 -327.02 0.40 2653055.15 342208.66 N 61 1530.874 W 1505346.482 3471.02 51.10 190.6 2649.57 1925.26 -1895.52 -340.46 0.22 2652984.48 342194.25 N 61 1530.176 W 1505346.756 3563.78 51.27 191.4 2707.71 1997.48 -1966.47 -354.25 0.68 2652913.74 342179.49 N 61 15 29.478 W 150 53 47.038 3657.94 51.50 190.3 2766.48 2071.00 -2038.73 -368.10 0.93 2652841.68 342164.65 N 61 1528.766 W 1505347.321 3752.81 50.35 191.7 2826.28 2144.59 -2111.02 -382.14 1.66 2652769.59 342149.62 N 61 1528.055 W 1505347.609 3843.84 51.95 190.4 2883.38 2215.42 -2180.59 -395.73 2.07 2652700.22 342135,09 N 61 1527.369 W 1505347.886 3937.96 53.28 189.5 2940.52 2290.19 -2254.25 -408.66 1.61 2652626.75 342121.15 N 6115 26.644 W 1505348.150 4030.06 53.70 189.5 2995.32 2364.21 -2327.26 -420.89 0.46 2652553.92 342107.92 N 61 1525.925 W 1505348.400 4123.46 54.37 187.5 3050.18 2439.80 -2402.01 -432.07 1.88 2652479.33 342095.72 N 6115 25.189 W 1505348.629 4215.75 54.19 187.0 3104.06 2514.70 -2476.35 -441.51 0.52 2652405.14 342085.26 N 6115 24.457 W 1505348.822 --. 4309.79 54.11 186.8 3159.13 2590.88 -2552.02 -450.64 0.16 2652329.60 342075,10 N 61 1523.712 W 1505349.0 4400.89 53.97 187.1 3212.63 2664.58 -2625.21 -459.59 0.34 2652256.55 342065.15 N 6115 22.991 W 1505349.191 4493.75 53.82 187.6 3267.35 2739.59 -2699.62 -469.20 0.42 2652182.28 342054.52 N 611522.259 W 1505349.388 4586.57 53.65 187.6 3322.25 2814.41 -2773.80 -479.11 0.19 2652108.25 342043.60 N 61 1521.528 W 1505349.590 4680.84 52.63 188.0 3378.80 2889.83 -2848.53 -489.37 ,1.12 2652033.68 342032.32 N 61 1520.792 W 1505349.800 4773.98 51.57 187.5 3436.02 2963.31 -2921.35 -499.26 1.23 2651961.00 342021.43 N 61 1520.075 W 1505350.002 4867.96 51.03 188.1 3494.78 3036.64 -2994.02 -509.15 0.76 2651888.48 342010.55 N 61 1519.360 W 1505350.204 4961.05 50.46 187.4 3553.68 3108.71 -3065.45 -518.83 0.83 2651817.19 341999.90 N 61 1518.656 W 1505350.402 PCU #4 Actual Surveys.xls Page 2 of 4 12/19/2001-9:08 AM Station ID I Ift\ I 1°\ I (O) I (ft) I (ft) I (ft) I (ft) I (°11000) I (ftUS) I (ftUS) I I N 61 1517.973 W 1505350.579 N 61 1517.290 W 1505350.756 5239.09 47.19 186.8 3737.28 3317.37 -3272.60 -544.66 1.05 2651610.43 341971.23 N 61 15 16.617 W 1505350.930 5330.74 45.92 186.9 3800.30 3383.88 -3338.66 -552.63 1.39 2651544.49 341962.36 N 61 1515.966 W 1505351.093 5423.03 45.14 187.8 3864.96 3449.72 -3403.97 -561.07 1.07 2651479.30 341953.03 N 61 1515.323 W 1505351.265 5515.04 43.62 187.3 3930.72 3514.05 -3467.77 -569.51 1.70 2651415.64 341943.72 N 611514.695 W 1505351.438 5611.40 42.31 187.7 4001.23 3579.71 -3532.88 -578.07 1.40 2651350.65 341934.27 N 611514.054 W 1505351.613 5704.31 41.43 188.2 4070.41 3641.71 -3594.29 -586.68 1.02 2651289.37 341924.82 N 61 1513.449 W 1505351.789 5797.65 39.65 189.7 4141.35 3702.38 -3654.22 -596.12 2.16 2651229.58 341914.56 N 61 1512.859 W 1505351.982 5890.78 38.31 190.2 4213.74 3760.95 -3711.92 -606.23 1.48 2651172.03 341903.66 N 61 1512.291 W 1505352.188 5982.66 36.90 189.6 4286.53 3817.00 -3767.15 -615.88 1.58 2651116.94 341893.26 N 61 1511.747 W 1505352.385 6075.16 35.84 190.0 4361.01 3871.84 -3821.19 -625.23 1.18 2651063.03 341883.16 N 611511.215 W 1505352.577 ~, 6169.11 34.79 189.7 4437.67 3926.14 -3874.70 -634.56 1.13 2651009.67 341873.11 N 61 1510.688 W 15053 52.7L 6260.63 ~- 33.61 189.6 4513.36 3977.57 -3925.41 -643.21 1.29 2650959.08 341863.77 N 6115 10.189 W 1505352.944 6354.94 32.34 189.5 4592.48 4028.90 -3976.02 -651.74 1.35 2650908.60 341854.54 N 61 159.690 W 1505353.118 6449.01 30.58 189.7 4672.72 4077 .99 -4024.42 -659.95 1.88 2650860.31 341845,67 N 61 159.214 W 1505353.286 6540.95 29.20 191.0 4752.43 4123.78 -4069.49 -668.19 1.65 2650815.37 341836.82 N 61 158.770 W 1505353.454 6633.39 28.52 190.4 4833.39 4168.37 -4113.33 -676.47 0.80 2650771.64 341827.94 N 61 158.338 W 1505353.624 6726.84 28.39 190.6 4915.55 4212.88 -4157.11 -684.57 0.18 2650727.98 341819.24 N 61 15 7.907 W 150 53 53.789 6820.97 t 28.39 190.3 4998.36 4257.61 -4201.13 -692.70 0.14 2650684.09 341810.51 N 61157.474 W 1505353.955 6852.06 28.22 189.9 5025.73 4272.35 -4215.64 -695.29 0.79 2650669.61 341807.72 N 61 157.331 W 1505354.008 6882.88 28.21 190.5 5052.89 4286.92 -4229.98 -697.88 0.84 2650655.31 341804.94 N 6115 7.190 W 1505354.061 7016.41 28.95 190.9 5170.15 4350.76 -4292.74 -709.74 0.57 2650592.72 341792.22 N 61 15 6.571 W 150 53 54.303 7107.56' ~ 28.17 191.1 5250.20 4394.30 -4335.52 -718.07 0.86 2650550.07 341783.30 N 61 156.150 W 1505354.474 7199.54 ~ 26.95 192.3 5331.75 4436.80 -4377.19 -726.69 1.44 2650508.52 341774.12 N 61 155.740 W 1505354.650 7294.37 26.37 191.0 5416.49 4479.30 -4418.87 -735.26 0.86 2650466.97 341764.98 N 61 1 ~ 5.330 W 150 53 54.825 7387.60 25.8ß 190.5 5500.21 4520.31 -4459.19 -742.90 0.60 2650426.76 341756.79 N 6115 4.933 W 1505354.981 ,-... 7481.08 25.35 189.0 5584.51 4560.70 -4499.00 -749.74 0.86 2650387.05 341749.40 N 61 154.541 W 1505355.1 7575.44 24.74 189.3 5669.99 4600.64 -4538.43 -756.10 0.66 2650347.71 341742.50 N 61 154.152 W 1505355.25'1 7668.35 24.11 189.2 5754.59 4639.06 -4576.35 -762.29 0.68 2650309.88 341735.80 N 61153.779 W 1505355.377 7759.99 23.25 188.5 5838.51 4675.86 -4612.71 -767.97 0.98 2650273.60 341729.62 N 61 153.421 W 1505355.493 7852.17 22.86 188.3 5923.33 4711.96 -4648.42 -773.26 0.44 2650237.97 341723.84 N 6115 3.069 W 1505355.601 7947.24 22.72 188.5 6010.98 4748.79 -4684.85 -778.63 0.16 2650201.62 341717.97 N 61152.710 W 1505355.711 8039.89 22.32 187.7 6096.56 4784.27 -4719.98 -783.63 0.54 2650166.56 341712.49 N 61 152.365 W 1505355.813 8133.45 21.51 187.5 6183.36 4819.18 -4754.60 -788.25 0.87 2650132.02 341707.40 N 61 15 2.024 W 150 53 55.908 PCU #4 Actual Surveys.xls Page 3 of 4 12/19/2001-9:08 AM Station ID I (ft) I CO) I (°) I (ft) I (ft) I (ft) I (ft) ~ (ON 00ft) I (ftUS) I ,(ftUS) I I , . N 61151.696 W 1505355.994 J N 61151.370 W 1505356.079 8409.54 19.87 185.8 6441.51 4917.01 -4851.75 -800.13 0.72 2650035.05 341694.19 N 61151.067 W 1505356.150 8503.71 19.82 185.5 6530.08 4948.93 -4883.56 -803.28 0.12 2650003.28 341690.61 N 61 150.754 W 1505356.215 8597.97 19.61 184.1 6618.82 4980.65 -4915.24 -805.94 0.54 2649971.64 341687.51 N 61 150.442 W 1505356.269 8690.90 18.50 184.6 6706.66 5010.90 -4945.49 -808.26 1.21 2649941.43 341684.78 N 61 150.144 W 1505356.316 8782.70 17.02 181.3 6794.08 5038.75 -4973.44 -809.75 1.96 2649913.50 341682.91 N 61 1459.869 W 1505356.347 8877.63 15.62 179.0 6885.18 5065.12 -5000.11 -809.83 1:63 2649886.84 341682.46 N 61 1459.606 W 1505356.348 8970.02 14.83 175.6 6974.33 5088.89 -5024.34 -808.69 1.30 2649862.60 341683.27 N 61 1459.368 W 1505356,325 9063.29 14.34 174.5 7064.60 5111.71 -5047.74 -806.67 0.59 2649839.18 341684.98 N 61 1459.137 W 1505356.284 9156.37 14.29 175.8 7154.79 5134.07 -5070.67 -804.72 0.34 2649816.23 341686.61 N 61 14 58.911 W 150 53 56.244 9247.60 14.18 175.5 7243.22 5155.92 -5093.03 -803.01 0.14 2649793.84 341688.01 N 61 14 58.691 W 150 53 56.2~ 9340.81 14.16 176.1 7333.59 5178.16 -5115.79 -801.34 0.17 2649771.06 341689.37 N 61 1458.467 W 1505356.175 9436.23 14.27 176.8 7426.09 5201.05 -5139.18 -799.90 0.21 2649747.66 341690.49 N 611458.237 W 1505356.145 9528.91 12.00 172.9 7516.34 5221.49 -5160.15 -798.06 2.63 2649726.67 341692.04 N 61 14 58.030 W 150 53 56.108 9580.00 12.00 172.9 7566.31 5231.71 -5170.69 -796.74, 0.00 2649716.12 341693.22 N 61 1457.927 W 1505356.081 Survey Error Model: (No Error Model Selected) ,-..., PCU #4 Actual SUlveys.xls Page 4 of 4 12/19/2001-9:08 AM ( Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@unocal.com ( UNOCAL Beverly Harrison Business Ventures Assistant January 17, 2002 DATA TRANSMITTAL To: From: Lisa Weepie Beverly Harrison 333 W 7th Ave, #100 909 W. 9th Avenue Anchoraqe, AK 99501-3539 Anchorage, AK 99501 Alaska Oil & Gas Unocal Alaska Transmitting the following: I ' LOG TYPE ,'I SCALE I LOG DATE I INTERVAL ~ ' Well t Medium I 9 D 1.. !. q 3 :",9c,,,,OO,,,,,RR,,,,RR,,,,,EE,,,,,,LL,,,,AA,,JT"",JI"OO,,,,J~Nw'^'~L,,oO,,,,,,GGw,,,,,,,,,,,,,,,,,""""""""'''''''''''''''''''''''''''''''''''''''''''''''I,i, ,55",JI,NN,,,,,,CC,,,,,HH^"'"''''',,!,11,J1'''¡/,J1'}7"//",22"".90,,,,,oO,,,J1""''''¡,'44",,,55,,,,,99,,,,66,",,,:55,,,00,,,,,66,,,00'"""':,:",,,,,J1w",:,Pp,,,,,Jree,Jt,tt"Y',Cc"",fr"ee"kk,,,,JJu,,J'n,,,J ;tt,,:,44w"""''''IfB'''~'Lm,;'n,w''''e'''w""",! ~ '''"'''''''''''''''''''"''''''''''''''''"''''''''''''''''"''''''''''''",,','0'.'''",,'.'."""""",,,,,.,,,"'",,,,,,.,.,..,.,,,,,.,.,,,",,,',',"",'0''''''',','''',',','''',,,,,','.w,w.' ,"',"I,,",',..-..,','W',. ...;..."',."".".,..."'...-..","'"'""...","'"""",.","-';¡".,',',W,wo'.y,',',',,,,,.',,-,',',','.'.,',','.,",,,','.',,,,,.'..".""....w...",.,...,.,.,..:.w.....,..,.,.....,w"."...,.,.,."....",..,.""".,.""""",."",.".",.",.,:,., ,.",' ,".',',', ",."",.""""",.,.,,,,,.,,,,,,.y"",,,..,,,,.,.,,,,,,w.,....,,,,n.,.....,".'.'.'.'.'.',w.",',',',',',',,,,,w.,,,,,.,.,,,,,',',,,",.,.,.,.,J,."".,,,,,,,,,,,,,.,,,..,..,.,,.w,,,,.,,..,...,, ,.' """.~.} , dO/- rì(P ¡PERF RECORD 15 INCH 111/18/2001 :0-96 ¡ 1 M-12 IFilm J. I: PEËiÞ.''ÃEQQF{'Ö"":""""..':"'" """"I'5'f~fcH""r1"'1"'/1ijj2Öõ'1""""'lÖ:96""'" ,', """'1", M-1"2"""'" " ",' ,"',",',i,"B'~'['i'ne """" l-loÎ5~~~ ~ 0 J.. Î Ip PDC~QG, ,,' ",§"J~ÇH..,J..1 V1?I?QQ1,I,Q~~.9 '" :,,J [NkJ? "",' i!m, , ""',"'" ",..,: 1 I ~~g~~~ N-2 BRïbGEPLUG.I~~g-~-1 H;~~~~~l:~i~î:i 061"5i. .11~~1~.. .... ~&~Q~ ... ... ~ iêA~>K:g:R:N;?:ê:R:fpGg:::p:~QG:::,:'I$:TNçH ,::j:t¡?:~/?Q:Q:i: ::J:$}$õ;}þ$}$':,::::jJM; i?::: ::':: :ß:;:~¡Ò~:":" RECEIVED I t.\ ~\ 1,~ t)nnl) and returning one copy of this transmittal or FAX"¥d oy~éf§~8. Alaska Oil & Gas Cons Comm. . Date: . ( ( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 16, 2001 RE: MWD Formation Evaluation Logs 2N - 314 (') dCD--J-Ô AK-MM-00318 1 LDWG formatted Disc with verification listing. API#: 50-103-20355-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Signd~~ Date: RECEI'\/ED NOV 2 9 2001 Alaska Oil & Gas Cons. C(munissioi'ì Ancoorage ( ( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska November 15,2001 RE: MWD FOffi1ation Evaluation Logs 1A-04A, AK-MM-00317 d. (X)-/qtj 1 LDWG fOffi1atted Disc with verification listing. API#: 50-029-20621-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: ~perry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Signedd~~~ Date: RECEIVED NOV 2 9 2001 Alaska Oil & Gas Cons, Commission Anc~orage ( Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@unocal.com ( UNOCAL Beverly Harrison Business Ventures Assistant November 16, 2001 DATA TRANSMITTAL To: From: Lisa Weepie Beverly Harrison 333 W 7th Ave, #100 909 W. 9th Avenue AnchoraÇJe, AK 99501-3539 AnchoraÇJe, AK 99501 Alaska Oil & Gas Unocal Alaska Transmitting the following: :;ël 11/4/20 i 6934-8643 1 PCU 4 ',','" ,J,Jl~!?Qw;§~~1:~§4~w",w,J",Eg,~"4,w,,, ,'J,Q(J ?/g, , )1.~Q~,~Þ§?, ' ..,..1JPG.W....4" , 1 0/12/2 i 180-9582 11 PCU 4 11/4/20 ,6934-8643 1 PCU 4 :::(jj¡4.¡g:Q:"$~~4~'ë$4?::: ::,::: 1:ç:U:A: JJJ/§(gQ,..~qQQ:~§?9 ",' """ J G.W..4 "'" ""'" lQl1 §(?" ,. ..g~QQ,:9~94.. 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R~P.9RT RECEIVED NOV 1 9 2001 Please acknowledge receipt by signing and returnin Received b . ANADRILL SCRLUMBERGER Survey report 3-Nov-2001 18:25:06 Client. . . . . . . . . . . . . . . . . . .: Unocal Field..... ....... ........: Pretty Creek Unit We 11 . . . . . . . . . . . . . . . . . . . . .: PCU - 4 API number...............: 50-283-20100 Engineer........ ....... ..: Goode Spud date. . . . . . . . . . . . . . . . : Last survey date..... ....: Total accepted surveys...: MD of first survey... ....: MD of last survey........: RIG. . . . . . . . . . . . . . . . . . . . . .: R&R - 9 ALASKA... ..... ... ... .....: ALASKA Page 1 of 5 12-0ct-01 03-Nov-01 104 0.00 ft 9580.00 ft ~. ----- Geomagnetic data ------- Magnetic model...........: BGGM version 2000 Magnetic date........ ....: 12-0ct-2001 Magnetic field strength..: 1111.70 RCNT Magnetic dec (+E/W-). ....: 21.22 degrees Magnetic dip... ..........: 73.96 degrees ----- Survey calculation methods------------- Method for positions... ..: Minimum curvature Method for DLS...... .....: Mason & Taylor ----- Depth reference ---------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: Drillers Depth GL above permanent.. .....: 72.10 ft KB above permanent.. .....: N/A ft DF above permanent..... ..: 88.10 ft Tally ----- MWD survey Reference Reference G...... ...... ..: Reference R.... ...... ....: Reference Dip............: Tolerance of G....... ....: Tolerance of R........ ...: Tolerance of Dip..... ....: ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft Criteria -- 1002.06 mGal 1111.70 RCNT 73.96 degrees (+1-) 2.50 mGal (+1-) 6.00 RCNT (+1-) 0.45 degrees --, ----- Corrections Magnetic dec (+E/W-).....: Grid convergence (+E/W-).: Total az corr (+E/W-) ....: (Total az corr = magnetic dec Sag applied (Y/N) ........: No ' ----- Platform reference point-- Latitude (+N/S-)... ......: -999.25 ft Departure (+E/W-)...... ..: -999.25 ft Azimuth from rotary table to target: 191.65 degrees [(c)2001 Anadrill IDEAL ID6_1C_10] ------ 21.21 degrees 0.00 degrees 21.21 degrees - grid conv) degree: 0.00 Q.J 0 -- -- '-Û ÚV ANADRILL SCHLUMBERGER Survey Report 3-Nov-2001 18:25:06 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 205.74 0.55 246.51 205.74 205.74 0.57 -0.39 -0.91 0.99 246.51 0.27 MWD 6-axis 3 296.11 0.97 235.92 90.37 296.10 1.37 -1.00 -1.94 2.18 242.81 0.49 MWD 6-axis 4 387.54 2.70 207.23 91.43 387.48 3.99 -3.34 -3.56 4.89 226.82 2.09 MWD 6-axis 5 479.03 4.37 194.38 91.49 478.79 9.55 -8.64 -5.42 10.19 212.09 2.01 MWD 6-axis 6 572.54 6.30 199.74 93.51 571.90 18.19 -16.92 -8.03 18.73 205.40 2.13 MWD 6-axis (' 7 663.78 10.01 183.30 91.24 662.21 31.00 -29.55 -10.18 31.26 199.01 4.76 MWD 6-axis 8 756.14 13.81 185.17 92.36 752.56 49.90 -48.55 -11.64 49.93 193.48 4.13 MWD 6-axis 9 848.61 18.09 190.43 92.47 841.46 75.23 -73.68 -15.23 75.23 191.68 4.88 MWD 6-axis 10 940.35 20.88 191.97 91.74 927.94 105.83 -103.68 -21.20 105.83 191.56 3.09 MWD 5-axis 11 1035.24 25.67 193.89 94.89 1015.08 143.30 -140.20 -29.65 143.30 191.94 5.11 MWD 6-axis 12 1128.66 29.65 192.75 93.42 1097.81 186.64 -182.40 -39.61 186.65 192.25 4.30 MWD 5-axis 13 1221.73 33.24 192.95 93.07 1177.20 235.17 -229.72 -50.41 235.19 192.38 3.86 MWD 5-axis 14 1314.17 36.97 192.80 92.44 1252.81 288.31 -281.54 -62.25 288.34 192.47 4.04 MWD 5-axis 15 1408.05 41.10 192.41 93.88 1325.71 347.41 -339.23 -75.14 347.45 192.49 4.41 MWD 6-axis 16 1501.90 43.80 190.99 93.85 1394.96 410.75 -401.25 -87.97 410.78 192.37 3.05 MWD 6-axis 17 1593.81 44.49 189.55 91.91 1460.91 474.74 -464.24 -99.37 474.75 192.08 1.32 MWD 5-axis 18 1687.29 46.54 188.41 93.48 1526.41 541.35 -530.11 -109.77 541.35 191.70 2.36 MWD 6-axis 19 1779.57 50.09 188.17 92.28 1587.77 610.14 -598.29 -119.70 610.15 191.31 3.85 MWD 5-axis 20 1872.73 51.33 186.63 93.16 1646.77 682.03 -669.79 -128.98 682.09 190.90 1.85 MWD 6-axis 21 1967.07 51.26 185.78 94.34 1705.76 755.32 -742.98 -136.94 755.49 190.44 0.71 MWD 6-axis ( 22 2062.59 50.84 186.50 95.52 1765.81 829.26 -816.83 -144.88 829.58 190.06 0.73 MWD 6-axis 23 2155.08 50.22 187.16 92.49 1824.60 900.41 -887.72 -153.37 900.88 189.80 0.87 MWD 6-axis 24 2247.99 51.07 188.63 92.91 1883.52 972.09 -958.88 -163.24 972.68 189.66 1.53 MWD 6-axis 25 2339.51 51.29 189.08 91.52 1940.89 1043.31 -1029.33 -174.22 1043.97 189.61 0.45 MWD 6-axis 26 2445.46 50.43 189.10 105.95 2007.77 1125.40 -1110.48 -187.20 1126.15 189.57 0.81 MWD 5-axis 27 2538.37 50.91 190.22 92.91 2066.65 1197.22 -1181.32 -199.26 1198.01 189.57 1.07 MWD 6-axis 28 2633.07 51.77 192.09 94.70 2125.82 1271.16 -1253.87 -213.57 1271.92 189.67 1.79 MWD 6-axis 29 2724.68 51.83 191.30 91.61 2182.47 1343.15 -1324.36 -228.17 1343.87 189.78 0.68 MWD 6-axis 30 2818.82 51.43 191.32 94.14 2240.90 1416.96 -1396.74 -242.64 1417.66 189.86 0.43 MWD 6-axis [(c)2001 Anadrill IDEAL ID6_1C_10J ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 31 32 33 34 35 -------- -------- 2912.02 3004.39 3097.88 3191.17 3284.83 36 37 38 39 40 3378.32 3471.02 3563.78 3657.94 3752.81 ------ ------ Incl angle (deg) ------ ------ 51.24 51.04 51.39 51.10 51.31 51.06 51.10 51.27 51.50 50.35 51.95 53.28 53.70 54.37 54.19 54.11 53.97 53.82 53.65 52.63 51.57 51.03 50.46 49.13 48.07 47.19 45.92 45.14 43.62 42.31 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 191.04 191.28 190.96 191.32 191.23 190.87 190.61 191.39 190.31 191.69 190.42 189.50 189.52 187.51 186.96 186.80 187.14 187.58 187.64 188.00 187.46 188.05 187.37 186.82 187.41 186.82 186.94 187.79 187.27 187.72 ------ ------ 93.20 92.37 93.49 93.29 93.66 93.49 92.70 92.76 94.16 94.87 91.03 94.12 92.10 93.40 92.29 94.04 91.10 92.86 92.82 94.27 93.14 93.98 93.09 91.53 93.27 93.24 91.65 92.29 92.01 96.36 [(c)2001 Anadrill IDEAL ID6_1C_10] 41 42 43 44 45 3843.84 3937.96 4030.06 4123.46 4215.75 46 47 48 49 50 4309.79 4400.89 4493.75 4586.57 4680.84 51 52 53 54 55 4773.98 4867.96 4961.05 5052.58 5145.85 56 57 58 59 60 5239.09 5330.74 5423.03 5515.04 5611.40 -------- -------- TVD depth (ft) -------- -------- 2299.13 2357.09 2415.65 2474.05 2532.73 2591.33 2649.57 2707.71 2766.48 2826.28 2883.38 2940.52 2995.32 3050.18 3104.06 3159.13 3212.63 3267.35 3322.25 3378.80 3436.02 3494.78 3553.68 3612.77 3674.45 3737.28 3800.30 3864.96 3930.72 4001.23 3-Nov-2001 18:25:06 -------- -------- Vertical section (ft) -------- -------- 1489.73 1561.65 1634.53 1707.27 1780.27 1853.11 1925.22 1997.49 2071.06 2144.70 2215.58 2290.33 2364.31 2439.78 2514.49 2590.45 2663.94 2738.75 2813.41 2888.66 2961.99 3035.16 3107.07 3176.76 3246.50 3315.17 3381.48 3447.15 3511.33 3576.83 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- -1468.13 -1538.69 -1610.20 -1681.58 -1753.17 -1824.66 -1895.52 -1966.47 -2038.73 -2111.02 -2180.59 -2254.25 -2327.26 -2402.01 -2476.35 -2552.02 -2625.22 -2699.62 -2773.80 -2848.53 -2921.35 -2994.02 -3065.45 -3134.82 -3204.24 -3272.60 -3338.66 -3403.97 -3467.77 -3532.88 -256.75 -270.67 -284.73 -298.78 -313.06 -327.02 -340.46 -354.25 -368.10 -382.14 -395.73 -408.66 -420.89 -432.07 -441.51 -450.64 -459.59 -469.20 -479.11 -489.37 -499.26 -509.15 -518.83 -527.46 -536.13 -544.66 -552.63 -561.07 -569.51 -578.07 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 1490.41 1562.32 1635.18 1707.92 1780.90 1853.74 1925.86 1998.12 2071.69 2145.33 2216.21 2290.99 2365.01 2440.57 2515.40 2591.50 2665.14 2740.09 2814.88 2890.26 2963.71 3037.01 3109.05 3178.89 3248.79 3317.61 3384.09 3449.91 3514.22 3579.86 189.92 189.98 190.03 190.08 190.12 190.16 190.18 190.21 190.23 190.26 190.29 190.28 190.25 190.20 190.11 190.01 189.93 189.86 189.80 189.75 189.70 189.65 189.61 189.55 189.50 189.45 189.40 189.36 189.33 189.29 3 of 5 DLS (deg/ 100f) 0.31 0.30 0.46 0.43 0.24 0.40 0.22 0.68 0.93 1.66 2.07 1.61 0.46 1.88 0.52 0.16 0.34 0.42 0.19 1.12 1.23 0.76 0.83 1.52 1.23 1.05 1.39 1.07 1.70 1.40 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Tool qual type ------ ------ 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 5-axis -.", 5-axis 5-axis 5-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ...-.~ 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 3-Nov-2001 18:25:06 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5704.31 41.43 188.24 92.91 4070.41 3638.72 -3594.29 -586.68 3641.86 189.27 1.02 MWD 6-axis 62 5797.65 39.65 189.69 93.34 4141.35 3699.31 -3654.22 -596.12 3702.52 189.27 2.16 MWD 6-axis 63 5890.78 38.31 190.20 93.13 4213.74 3757.87 -3711.92 -606.23 3761.10 189.28 1.48 MWD 6-axis 64 5982.66 36.90 189.61 91.88 4286.53 3813.91 -3767.15 -615.88 3817.16 189.28 1.58 MWD 6-axis 65 6075.16 35.84 190.04 92.50 4361.01 3868.73 -3821.19 -625.23 3872.01 189.29 1.18 MWD 6-axis 66 6169.11 34.79 189.72 93.95 4437.67 3923.01 -3874.70 -634.56 3926.31 189.30 1.13 MWD 6-axis ( 67 6260.63 33.61 189.64 91.52 4513.36 3974.42 -3925.41 -643.21 3977.75 189.31 1.29 MWD 6-axis 68 6354.94 32.34 189.51 94.31 4592.48 4025.72 -3976.02 -651.74 4029.08 189.31 1.35 MWD 6-axis 69 6449.01 30.58 189.74 94.07 4672.72 4074.78 -4024.42 -659.95 4078.17 189.31 1.88 MWD 6-axis 70 6540.95 29.20 191.00 91.94 4752.43 4120.58 -4069.49 -668.19 4123.98 189.32 1.65 MWD 6-axis 71 6633.39 28.52 190.38 92.44 4833.39 4165.20 -4113.33 -676.47 4168.59 189.34 0.80 MWD 6-axis 72 6726.84 28.39 190.60 93.45 4915.55 4209.71 -4157.11 -684.57 4213.10 189.35 0.18 MWD 6-axis 73 6820.97 28.39 190.32 94.13 4998.36 4254.46 -4201.13 -692.70 4257.85 189.36 0.14 MWD 6-axis 74 6852.06 28.22 189.95 31.09 5025.73 4269.20 -4215.64 -695.29 4272.59 189.37 0.79 MWD 6-axis 75 6882.88 28.21 190.50 30.82 5052.89 4283.76 -4229.98 -697.88 4287.16 189.37 0.84 MWD 6-axis 76 7016.41 28.95 190.90 133.53 5170.15 4347.63 -4292.74 -709.74 4351.02 189.39 0.57 SP 6-axis 77 7107.56 28.17 191.43 91.15 5250.20 4391.21 -4335.50 -718.18 4394.58 189.41 0.90 SP 6-axis 78 7199.54 26.95 192.25 91.98 5331.75 4433.76 -4377.15 -726.90 4437.09 189.43 1.39 SP 6-axis 79 7294.37 26.37 190.98 94.83 5416.49 4476.31 -4418.82 -735.47 4479.61 189.45 0.86 SP 6-axis 80 7387.60 25.86 190.47 93.23 5500.21 4517.34 -4459.14 -743.11 4520.64 189.46 0.60 SP 6-axis 81 7481.08 25.35 189.02 93.48 5584.51 4557.71 -4498.95 -749.95 4561.03 189.46 0.86 SP 6-axis ( 82 7575.44 24.74 189.32 94.36 5669.99 4597.62 -4538.39 -756.32 4600.98 189.46 0.66 SP 6-axis 83 7668.35 24.11 189.21 92.91 5754.59 4636.01 -4576.31 -762.50 4639.40 189.46 0.68 SP 6-axis 84 7759.99 23.25 188.54 91.64 5838.51 4672.77 -4612.67 -768.19 4676.20 189.46 0.98 SP 6-axis 85 7852.17 22.86 188.30 92.18 5923.33 4708.81 -4648.38 -773.47 4712.29 189.45 0.44 SP 6-axis 86 7947.24 22.72 188.48 95.07 6010.98 4745.58 -4684.81 -778.84 4749.11 189.44 0.16 SP 6-axis 87 8039.89 22.32 187.71 92.65 6096.56 4780.99 -4719.94 -783.84 4784.59 189.43 0.54 SP 6-axis 88 8133.45 21.51 187.50 93.56 6183.36 4815.82 -4754.55 -788.47 4819.49 189.42 0.87 SP 6-axis 89 8225.43 21.30 187.00 91.98 6269.00 4849.29 -4787.85 -792.70 4853.03 189.40 0.30 SP 6-axis 90 8319.40 20.29 187.23 93.97 6356.84 4882.55 -4820.96 -796.83 4886.37 189.39 1.08 SP 6-axis [(c)2001 Anadrill IDEAL ID6_1C_10] ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 91 92 93 94 95 96 97 98 99 100 101 102 103 104 -------- -------- 8409.54 8503.71 8597.97 8690.90 8782.70 8877.63 8970.02 9063.29 9156.37 9247.60 9340.81 9436.23 9528.91 9580.00 ------ ------ Incl angle (deg) ------ ------ 19.87 19.82 19.61 18.50 17.02 15.62 14.83 14.34 14.29 14.18 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 185.79 185.50 184.12 184.65 181.30 178.98 175.55 174.52 175.77 175.48 14.16 176.14 14.27 176.80 12.00 172.85 12.00 172.85 ------ ------ 90.14 94.17 94.26 92.93 91.80 94.92 92.40 93.27 93.08 91.23 93.21 95.42 92.68 51.09 [(c)2001 Anadrill IDEAL ID6_1C_l0] -------- -------- TVD depth (ft) -------- -------- 6441.50 6530.08 6618.82 6706.65 6794.08 6885.17 6974.33 7064.60 7154.79 7243.21 7333.59 7426.09 7516.34 7566.31 3-Nov-2001 18:25:06 -------- -------- Vertical section (ft) -------- -------- 4913.37 4945.17 4976.73 5006.83 5034.50 5060.64 5084.14 5106.64 5128.71 5150.27 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- -4851.70 -4883.52 -4915.20 -4945.45 -4973.40 -5000.07 -5024.30 -5047.69 -5070.62 -5092.99 -800.35 -803.49 -806.16 -808.47 -809.96 -810.05 -808.91 -806.88 -804.93 -803.22 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 4917.27 4949.18 4980.87 5011.10 5038.92 5065.26 5089.00 5111.78 5134.12 5155.94 189.37 189.34 189.31 189.28 189.25 189.20 189.15 189.08 189.02 188.96 5172.22 -5115.75 -801.55 5178.16 188.90 5194.83 -5139.13 -800.11 5201.05 188.85 5215.00 -5160.10 -798.27 5221.48 188.79 5225.05 -5170.64 -796.95 5231.70 188.76 5 of 5 DLS (deg/ 100f) 0.72 0.12 0.54 1.21 1.96 1.63 1.30 0.59 0.34 0.14 0.17 0.21 2.63 0.00 ------ ------ Srvy tool type Tool qual type ------ ------ SP SP SP SP SP 6-axis 6-axis 6-axis 6-axis 6-axis SP SP SP SP SP 6-axis 6-axis 6-axis 6-axis 6-axis .~~ SP 6-axis SP 6-axis SP 6-axis Projected to TD .-, ~I ( ~1r!A\1rŒ (ll~ !A\~!A\~[ß!A\ / AlASKA OIL AND GAS / CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Williamson Drilling Manager . U nocal PO Box 196247 Anchorage AK 99519 Re: Pretty Creek Unit No.4 Unocal Permit No: 201-193 Sur Loc: 3695 FSL, 2132' FEL, Sec. 33, T14N, R9W, SM Btmhole Loc. 4125, FSL, 3140' FEL, Sec. 4, TI3N, R9W, SM Dear Mr. Williamson: 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. Annular disposal has not been requested as part of the Permit to Drill application for Pretty Creek Unit No.4. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, & ~lvt..~ C~ChSli Tayl09 . Chair BY ORDER OF THE COMMISSION DATED this 5th day of October, 2001 jj c/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . ~ \, If ' Hole 12-1/4" 8-1 12" 7" 6" 4-1 12" Weight 54.5 47 29 12.6 STATE OF ALASKA ( J+I r;6Î1f/úl AND GAS CONSERVATION CuMMISSION PERMIT TO DRILL 20 AAC 25.005 A -!:J (Old- /o~ /~/6 r-. ALASKA d, Red rill: Deepen: 1b. Type of well Service: 1 a. Type of work Drill: X Re-Entry: 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska, 99519-6247 4. Location of well at surface 3,695 FSL, 2,132' FEL, Section 33, T14N, R9W, SM At top of productive interval 969 FSL, 2,574' FEL, Section 33, T14N, R9W, SM At total depth 4,125' FSL, 3,140' FEL, Section 4, T13N, R9W, SM 12. Distance to nearest 13. Distance to nearest well property line 221' feet 25.5' at surface 16. To be completed for deviated wells Kickoff depth: 300' feet Maximum hole angle: 54.3' 18. Casing program size Casing 13-3/8" 9-518" feet Specifications Grade Coupling K-55 Welded L-80 Buttress L-80 Buttress L-80 Buttress 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical true vertical 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Drilling fluid program: X Time vs. depth plot: Refraction analysis: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: Sign@~ j ~a~ Dan Williamson Title: f) li!t~ Alt.tlr. "" "" Commission Use Only ,/ / Permit Number API number , I Approval date r 1 /1 See cover letter 20) - J 'J.:::j 50- :z r:3 - :z. O/CJo \ Û, ~\Q \ for other requirements Conditions of approval Samples required: [] Yes 'Þ<I No Mud log required: [~Ye~ D<J No Hydrogen sulfide measures [] Yes t><I No Directional survey required W Yes [] No Required working pressure for BOPE [] 2M; '~M; [] 5M; [] 10M; [] 15M Other: Origina' Signed BV Approved by Cammy Oechs\i Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Form 10-401 Rev. 12-1-85 'I \ \ feet feet measured true vertical feet feet Length Size measured Exploratory: Stratigraphic Test: Developement Gas: X Single Zone: 5. Datum Elevation (OF or KB) 10. Field and Pool 98' feet Pretty Creek 6. Property Designation ADL 63048/ADL 58813 7. Unit or property Name Pretty Creek Unit 8. Well number NO.4 9. Approximate spud date 1 0/7/2001 14. Number of acres in property Development Oil: Multiple Zone: X 11. Type Bond (see 20 AAC 25.025) Number U 62-9269 Amount $200,000 15. Proposed depth (MD and TVD) 1,280/1,095 9,502' MOl 7,600' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2» Length 120' 2,440' 6,900' 2,750' Maximum surface 1437 psig At total depth (TVD) 3754 psig Setting Depth Top Bottom Quantity of cement MD TVD MD TVD (include stage data) 0' 0' 120' 120' 0' 0' 2,440' 2,002' 675 sx 0' 0' 6,900' 5,120' 747 sx 6,750' 4,994' 9,500' 7598' 249 sx r:) ~~"'W ('~ F'" ~~~,~:: ~1~~~ ¡~= [) Plugs (measured) SEP 2 J, 2001 Junk (measured) Cemented Alaslr"a Oil & Gas Cons. Commission Anchorage True vertical depth Measured depth Diverter Sketch: X Seabed report: Drilling program: X 20 AAC 25.050 requirements: X Date9/1!/a; . Commissioner by order of the Commission ,d~ 0 \ Date: , ORIGINAL Submit in triplicate . ~ r- r-J i i r-J r-J i i i L______-------j l ~W-4 /. / . ,./ +244-4 ~ -.t~"...1 r- .... a . J .r~ - - + - - - - - - - - - - - - - - - - - 1- - r - - + ;,¡ .. " <\ ....~~~ \ ~ T12N R10W r---, T12N R9W r.--~ i ~.J ! r-J ; .J NO~TH COOK INLET UNIT i r 1 r:'- . r-.J .J¡J~ 0 ,&IIt...-,,=- r-J . .JI",... " / II + . ~ - l . '~~'-7~';:.or~ . . 11 - - - - - - - - - - - - - - - - ~ C.1.S. 1715~1 "1 ..",/ >./: '~..... 10 '~OOQ. -. H~IY" ~1uw.!'AN AM . I P.p.s.s... II. Ow CJ.s. '874' " I 0 C./.$. '8t40 " .... 10 8.011' . . 10 8,'82, °...J I r- . . 1".1'.9.8. L .J + 1874YI -., r- TO 8, L.__- '---_J :0 ct) . .,...; ~m: - . + + Figure 1 ------.- L:\DtllfUng\WnI.Id.\PRCP!RTI£S.DI UNDCAL8 BD.1JCA RIVER - PRETIY CAŒK - IVAN RIVER - SlUIIP IJ WEST SIDE PROPERTIE~ COOK ImET, ALASK¡ SCIU: '"00.4000' 0fITE: l1-e-et DRAWN 1M £. TAN' P. KIm .' ( . . ZAMERALLO) ET 19 --- UNOCAL-10 % I I 30 ~- J 2532 AC I ITR-l01 3-31-00 r ~~ AC ADL-381234 IADL~~~047 UNOCA -10 % 31 32 ITR-12 UNOCA --10(1% I : I : I 127~ AC I H U I ADL- 8814 5 TR - 5 ARCO-100% DANCO 100% ~-R9W- I I I 22 4480 AC 3-31-00 ADL -381232 UNOCAL-100% UNOCAL-100% 2oCR$EK21 UMIT PCU2~24-28 !ITR-lll 27 TR-2 ---- --- - PCU 2 UNOCAL--,1 00% PCU 4 1080 AC I HBU ADL--58813 ARCO-60% PHILLIrS-4O% 8 9 I 10 ONE MILE I ::r: ~ p:: 0 z --- - _. + --- 364 AC HBP ADL-58820 3364,518 AC 3-31(:00 ADL -3 1221 211-13 AC BBU ADL 32930 0> ~ "'ö :j U a.. ./ 1/1 +> d õ: D- o L a.. 0> c :¡:; L r=1 ./ .::J . ~ ( Pad Limits Existing Production Facilities 250' Plan View (Not to Scale) ( / North PCU 2 PCU4 335' UNOCAL~ Proposed PCU 4 Layout Drilling Well Site Layout Mat Su Borough State of Alaska Date: Julv '01 (' Pretty Creek Field PCU No.4 , \ UNOCAL(; Procedure: Prep 1) Improve Pad and Install Cellar. 2) Drive 13-3/8" conductor to refusal. 3) MIRU. Surface Hole 12-1/4" 4) NU 13-5/8" Diverter. Function test diverter valve. 5) Spud 12-1/4" Hole and drill to 2,441' MD/ 2,002' TVD (KO at 500' @ 3deg/1 00') to 51 deg. 6) Run and set 9-5/8" Casing at 2,440'. 7) Cement 9-5/8" with 675 sx of cement. 8) Nipple down diverter. 9) Nipple up A and B Sections on Wellhead. 10) Nipple up 11" BOPE and test to 3,000 psi. Intermediate Production Hole 8-1/2" 11) Drill float equipment and 10' of new formation. Conduct LOT. 12) Drill 8-1/2" Hole to 6,904' -start drop at 1 deg/100' from 4,600' to TO. 13) Log open hole (LWO). 14) Run and Set 7" Casing at 6,900'. 15) Cement 7" casing with 747 sx Lower Production 6" 16) Drill float equipment an 10' of new hole. Conduct LOT. 17) Drill 6" Hole to 9,504' cont. dropping at 1 deg/100' to TO. Final Inclination = 6.95 deg. 18) Log open hole. 19) Run 4-1/2" Liner from TO to 6,750' MD. 20) Cement Liner with 249 sx. 21) Clean out Liner. Complete/Gravel Pack 22) Clean out 7" casing, filter brine to 20 NTU's. 23) TCP Perforate 5,372'-5,452' (80'). 24) Gravel Pack interval. 25) TCP Perforate 5,088'-8,180' (92'). 26} Gravel Pack interval. 27) Run 2-7/8" Completion. 28) RU to run dual (heater string). 29) Run 2-3/8" Heater String to 2,450' and land completion. 30) NO BOPE, NU Tree and test to 5,000 psi. 31) Release rig. Drill Prog.DOC Page 1 9/19/01/4:50 PM (" l ")retty Creek Well No.4 Proposed 1 A 2 3 6 8 9 PCU 4 Proposed ILdoc CASING AND TUBING DETAIL GRADE CONN ID BTM. 75' 2,440' 6,900' 9,500' SIZE WT 13-3/8" 9-5/8" 47 7" 29 4-1/2" 12.6 Tubing 2-7/8" 6.4 2-3/8" 4.6 TOP Surface Surface Surface 6,200' L-80 Butt L-80 Butt L-80 Butt SC L-80 Butt SC L-80 Butt SC 8,871 ' 2,000' NO. 1 2 3 4 5 6 7 8 9 Depth JEWELRY DETAIL OD Item Dual Tubing Hanger, 2-7/8" x 2-3/8" DCB II" 5M Sliding Sleeve, 2-7/8" Butt Packer SC-I Gravel Pack Packer Baker Weld Wire Wrapped Screen SC-I Gravel Pack Packer Baker Weld Wire Wrapped Screen SC-I Gravel Pack Packer HMC/ZXP Liner Top Packer ID 2,250' 5,100' 5,284' 5,546' 6,750' A Heater String 2-3/8", L-80, Butt SC 2,000' PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments Proposed Beluga 5,183' 5,274' 91' 12 Proposed Beluga 5,466' 5,546' 80' 12 TD = 9,502'MDI7,600'TVD Max Hole Angle = 51 deg DRAWN BY: tcb ( ~ ( . . Pretty Creek No.4 Hazard Analysis for APD 20AAC 25.005 (c) 4 (A) Maximum pore pressure anticipated is 3,754 psi at 7,600' TVD or 9.5 ppg EMW. Offset wells were drilled with mud weights ranging from 8.5 to 10.3 ppg (Pretty Creek 2 experienced Mud Weights of up to 10.6ppg but this was likely a result of insufficient mud cleaning equipment as the mud was repeatedly watered back to a 10.3). (B) While losses were not recorded in the drilling of the original well in these intervals, lost circulation is a possibility if the Beluga intervals have been depleted by the adjacent PCU No 2. Adequate supplies of lost circulation material and water will be kept on location before drilling commences. Crews will be briefed on the strategy for dealing with losses should they occur. (C) H2S production has not been identified in any of the West Side Fields operated by Unocal. (D) Cuttings and Mud will be injected at the Ivan River 14-31 Class II disposal well. , . ( I' ' Pretty Creek Well #PCU 4 Bottomhole Pressure Information The following presents data used for calculation of anticipated surface presures (ASP) during drilling of the PCU 4. The pore pressure gradient was estimated from the following information: Well BHP ~ Depth TVD EMW, ppg 8.8 Comment PCU 1 DST PCU 2 1,500 1,575 1,705 1,911 3,396' 3,500' 3,700' 3,900' 8.5 8.7 8.8 9.4 DST Re-completion Re-completion Re-completion The fracture gradient for the surface and intermediate casing points was conservatively estimated at .8 psi/ft or 15.4 ppg. Casing Pore Casing Setting Fracture Pressure Mud Pore ASP Size Depth Gradient Gradient Weight Pressure Drilling i!.ŒJ (TVD ft) (Ibs/gal) (Ibs/gal) (Ib/gal) ~ ~ 9-5/8" 2,002' 15.1 8.5 9 884 7" 5,120' 15.4 9.5 10 2,529 562 4-1/2" 7,600' NA 9.5 10 3,754 1437 Procedure for Calculating Anticipated Surface Pressure While Drilling ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat (with gas bubble just below shoe and mud gradient above shoe) or 2) formation pore pressure at the next casing point less 1/4 gas gradient and 3/4 mud gradient to the surface as follows: 8-1/2" Intermediate Production Hole Section from 2,002' TVD to 5,120' TVD 1) ASP = (FGx.052xD) - (MWx.052xD) = (15.4x.052x2002) - (10x.052x2002) = 562 psi OR (' 2) ASP 1(1 = FPP - (0.1gas gradient xDx.25) - (MWx.052xDx.75) = 2,529 - (.1 x 5120x.25) - (1 OX.052x5120x. 75) = 2,529 - 128 - 1996 = 405 psi 6" Production Hole Section from 5,120' TVD to 7,600' TVD 1) ASP 2) ASP 2 = (FGx.052xD) - (MWx.052xD) = (15.4x.052x5120) - (10x.052x5120) = 1437 psi OR = FPP - (0.1 gas gradientxD) = 3,754 - (.1x 7600) = 3,754 - 760 = 2,994 psi 09/19/01 PCU No.4 . . ( t Kick Tolerance for PCU NO.4 8-1/2" Intermediate Production Hole Section from 2,002' TVD to 5,120' TVD With 10 ppg mud in the hole and a gas bubble in the well and an estimated shoe frac gradient of 15.4 ppg, the shoe will fail at 562 psi of surface pressure ((15.4- 10)x.052x2002'). At the most vulnerable point for shoe failure when the gas bubble is just below the 9-5/8" casing shoe, the hydrostatic pressure situation will be as follows: + 562 psi max surface pressure without fracturing the shoe + 2002' x .052 x 10 ppg mud in the surface casing = 1041 psi + Gas height (Ht) x 0.1 psi/ft gas bubble just below surface casing + (5120'-2002'-Ht) x .052 x 10 mud below the gas bubble = 9.5 x .052 x 5120' TVD = 2529 psi estimated formation pressure Solving the above equation for Ht: 562 + 1041 + 0.1Ht + (5120'-2002'-Ht).52 = 2529 562+1041 +0.1 Ht+ 1621-.52 Ht=2529 695 = .42 Ht Ht = 1655' (TVD height of gas bubble just below shoe which will cause shoe fracture failure) The gas volume is 1655' x (.054 bbl/ft for a 4" Drill pipe x 8-1/2" annulus) = 89 bbl If the gas volume at the shoe is 89 bbl, then the original gas kick volume when it first entered the well bore at 5120' TVD would be: P1 xV1 = P2XV2 P1 = 10 x 5120' x .052 = 2662 psi hydrostatic pressure at TD V1 = X, unknown gas volume at TD P2 = (562 psi surf pressure w/o fracturing shoe) + (10 ppg x .052 x 2002') = 1603 psi pressure at shoe V 2 = 89 bbl gas bubble just below 9-5/8" shoe V 1 =89 bbl x 1603 psi/2662 psi = 53 bbls kick tolerance at 5120' TVD. 6" Production Hole Section from 5,120' TVD to 7,600' TVD 3 09/19/01 PCUNo.4 ,( ( With 10 ppg mud in the hole and a gas bubble in the well and an estimated shoe frac gradient of 15.4 ppg, the shoe will fail at 1437 psi of surface pressure ((15.4- 10)x.052x2002'). At the most vulnerable point for shoe failure when the gas bubble is just below the 9-5/8" casing shoe, the hydrostatic pressure situation will be as follows: + 1437 psi max surface pressure without fracturing the shoe + 5120' x .052 x 10 ppg mud in the intermediate casing = 2662 psi + Gas height (Ht) x 0.1 psi/ft gas bubble just below intermediate casing + (7600'-5120'-Ht) x .052 x 10 mud below the gas bubble = 9.5 x .052 x 7600' TVD = 3754 psi estimated formation pressure Solving the above equation for Ht: 1437 + 2662 + 0.1Ht + (7600'-5120'-Ht).52 = 3754 1437 + 2662 + 0.1 Ht + 1289 -.52 Ht = 3754 1634 = .42 Ht Ht = 3890' (TVD height of gas bubble just below shoe which will cause shoe fracture failure) \, The gas volume is 3890' x (.019 bbl/ft for a 4" Drill pipe x 6" annulus) = 73bbl '",,".J>" If the gas volume at the "hoéls73 bbl, then the original gas kick volume when it first entered the wellbore at 7600' TVD would be: P1 X V1 = P2 X V2 P 1 = 10 x 7600' x .052 = 3952 psi hydrostatic pressure at TO V1 = X, unknown gas volume at TO P2 = (1437 psi surf pressure wlo fracturing shoe) + (10 ppg x .052 x 5120') = 4099 psi pressure at shoe V 2 = 73 bbl gas bubble just below 7" shoe V1 =73 bbl x 4099 psi/3952 psi = 75 bbls kick tolerance at 7600' TVD. 4 09/19/01 PCUNo.4 , . (, ( , , UNOCALe Pretty Creek Unit Well No.4 Diverter and BOPE Diverter The diverter will consist of a 13-5/8", 5,000psi Annular Preventer and a 12" 0.0. non bifurcated vent line. The vent line will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The Vent Line will be a minimum of 100' away from any source of ignition. Blow Out Preventers The blowout preventor will consist of a 11", 5000psi Annular, a 11", 5,000 psi double ram preventor with pipe rams on top and blind rams on bottom, a 11", 5000 psi mud cross wI 3-1/8", 5000 psi flanged outlets, and a 11", 5000 psi single ram preventor with pipe rams. Choke Manifold The choke manifold will be a 3-1/8",5000 psi manifold. It will include 1 ea. remote controlled hydraulically actuated choke and one hand adjustable choke. Casing Test MASP Test BOPS LowlHigh Casing String Size (in) (psi) (psi) Size and Rating (psi) Conductor 13-3/8" N/A N/A 13-5/8" 5M Annular Function Surface 9-518" 11", 5M Annular 250/3000 11", 5M Pipe Ram 250/3000 11", 5M Blind Ram 250/3000 Intermediate 7" 11", 5M Annular 250/3000 11", 5M Pipe Ram 250/5000 11", 5M Pipe Ram 250/5000 11", 5M Blind Ram 250/5000 Production 4-1/2" 11", 5M Annular 250/3000 Liner 11", 5M Pipe Ram 250/5000 11", 5M Pipe Ram 250/5000 11", 5M Blind Ram 250/5000 Wellhead Manufacturer Cameron Model MB Split Multibowl System, 11" 5M Starting Head SOW, 13-3/8" x 13-5/8", 3M wI XXX Outlets preped for Mandrel Hanger Casing Head 13-5/8", 3M x 11", 5M, wI 9-5/8" Csg Mandrel Hanger and Pack Off Tubing Spool 11",5Mx11"5M Tubing Hanger 11", 5M wI 4-1/2" EUE 8rd Lift x 4-1/2" Imp Mod Butt Suspension wI Type H BPV Prep UNOCALe ( Pretty Creek Unit Well No.4 Cementing Program Surface Casing Size: 9-5/8" Lead Slurry: Top of Cement: Specifications: Tail Slurry: Top of Cement: Specifications: Total Volume: Intermediate Casing Size: 7" Tail Slurry: Top of Cement: Specifications: Total Volume: Setting Depth: Annular Vol to 2,440' MDI 2002 TVD 2,440' with 12.25 gauge hole: 764 ft3 Density: 13 ppg, Yield: ~ Sx: 547 CF: 1028 ft3 0 MD 0 TVD Class G with Additives Mixed with Fresh Water Density: 15.8 ppg, Yield:.J.:.!Z. Sx: 128 CF: 149 ft3 2,190' MD 1,834' TVD Class G with Additives Mixed with Fresh Water 1177 ft3, % open hole excess 50 Setting Depth: Annular Vol to 6,900' MDI 5120' TVD 6,900' with 8-1/2" gauge hole: 2~..ft3 Density: 15.8 ppg, Yield: ~ 2,440' MD 2,002' TVD Class G with Additives Mixed with Fresh Water Sx: 747 CF: 867 ft3 867 ft3, 50 % open hole excess Note: Top hydrocarbon bearing interval at 4,553' MD/3,322' TVD Production Liner Size: 4-1/2" Tail Slurry: Top of Cement: Specifications: Total Volume: Setting Depth: 9,500' MDI 7,600' TVD Annular Vol to 6,900' with 6" gauge hole: 223 ft3 Density: 15.8 ppg, Yield: ~ Sx: 249 6,900' MD 5120' TVD Class G with Additives Mixed with Fresh Water CF: 289 ft3 289 ft3, 30 % open hole excess, Note: Top Hydrocarbon bearing interval at 8,871 'MD/6,977' TVD UNOCALe { Pretty Creek Unit Well No.4 Casing Program ~ . Surface Casing: 9-5/S", 47 #, L-SO, Buttress Worst case for burst would be in the event of a gas kick while drilling at intermediate hole section TO. If the Maximum Anticipated Surface pressure were encountered, the SI pressure against the 9-5/8" production casing would be 562 psi. Burst = 562 psi. 9-5/8",47#, L-80 @ 6,870 psi for burst Safety Factor = 12.22 OK Worst case for collapse is if returns are lost while drilling below the 9-5/8" Surface Shoe Collapse = (8.5 x.052x 2,002')-(2,002'-.1) 47#, L-80 rated @ 4,760 psi collapse = 685 psi for full evacuation Safety Factor = 6.95 OK Tension = 2440' X 47# = 115K Rated = 1122K for body yield Safety Factor = 9.75 OK Intermediate Production Casing: 7", 29#, L-SO, Buttress Worst case for burst would be in the event of a gas kick while drilling at TO. If the Maximum Anticipated Surface pressure were encountered, the SI pressure against the 7" production casing would be 1,437 psi. Burst = 1 ,437 psi. 7", 29#, L-80 @ 7,240 psi for burst Safety Factor = 5 OK Worst case for collapse is if lost returns occur while drilling below the 7" casing. Collapse = (9.5 x.052x5, 120')-(5120'-.1) 29#, L-80 rated @ 7,020 psi collapse = 2,017 psi for full evacuation Safety Factor = 3.48 OK Tension = 6,900' X 29# = 200K Rated = 718K for body yield Safety Factor = 3.59 OK 4-1/2", 12.6#, L-80 Buttress Liner from 2,500' MDITVD to 6409' TVD6350'MD Burst: There are no significant burst requirements for a production liner Worst case for collapse is when the well is unloaded of fluid and has 0 psi Tubing Pressure, Collapse (1 Ox.052x7600')-(7600'x.1) = 3,192 psi for full evacuation 12.6#, L-80 rated @ 7,500 psi collapse Safety Factor = 2.34 OK Tension = (9,500'-6,750') X 12.6# = 35K Rated = 288K for body yield Safety Factor = 8.2 OK APD Casing Design.DOC Page 1 9/20/01/2:26 PM Pretty Creek Unit #4 Proposed Well Profile - Geodetic Report August 30,2001 Unocal Pretty Creek Unit Pretty Creek Unit 4/ PCU #4 stu :~~: Feasibility pcu #4 (P10) / August 30,2001 94.484 ° /4974.26 ft /5.769/ 0.65e NAD27 Alaska State Planes, Zone 4, US Feel N 61.26360574, W 150.8944751C N 2654889.400 ftUS, E 342545.400 ftUE -0.784327190 0.99992821 ~ UNOCAL8 Report Date: Client: Field: Structure I Slot: Well: Borehole: UWUAPI#: SUlVey Name I Date: Tort I AHD 10011 ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid HIE Y/X: Grid Convergence Angle: Grid Scale Factor: Station 10 KBE KOP Bid 1.5/100 Bid 4/100 Schlumberuer SUlVey I DLS Computation Method: Vertical Section Azimuth: I Vertical Section Origin: On Y TVD Reference Datum: TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: Minimum Curvature / Lubinski 192.220° N 0.000 ft, E 0.000 ft KB 98.0 ft relative to MSL 82.000 ft relative to MSL 21.220° 55605.773 nT 73.95r September 15, 2001 BGGM 2001 True North +21.220° Well Head ~ 700.00 11.00 189.13 698.26 29.55 -29.21 -4.70 800.00 15.00 189.13 795.67 52.00 -51.42 -8.26 900.00 19.00 189.13 891.28 81.19 -80.28 -12.90 1000.00 23.00 189.13 984.62 116.97 -115.66 -18.59 1100.00 27.00 189.13 1075.24 159.16 -157.37 -25.30 1200.00 31.00 189.13 1162.68 207.56 -205.23 -32.99 1300.00 35.00 189.13 1246.53 261.94 -258.99 -41.63 1400.00 39.00 189.13 1326.38 322.02 -318.40 -51.18 1500.00 43.00 189.13 1401.83 387.52 -383.16 -61.59 1600.00 47.00 189.13 1472.53 458.11 -452.96 -72.81 1700.00 51.00 189.13 1538.12 533.46 -527.46 -84.78 End Bid 1707.50 51.30 189.13 1542.83 539.29 -533.23 -85.71 9-5/8" Csg pt 2441.89 51.30 189.13 2002.00 1111.60 -1099.11 -176.67 PCU#4 (P10) Report.xls Page 1 of 3 Ic Coordinates Longitude N 61.26360574 W 150.89447510 N 61.26360574 W 150.89447510 N 61.26360221 W 150.89447629 N 61.26359160 W 150.89447981 N 61.26356808 W 150.89448765 4.00 2654860.26 342540.30 N 61.26352584 W 150.89450179 4.00 2654838.10 342536.44 N 61.26346510 W 150.89452201 4.00 2654809.31 342531.40 N 61.26338616 W 150.89454837 ~~-..,~ 4.00 2654774.01 342525.23 N 61.26328939 W 150.89458069 4.00 2654732.40 342517.95 N 61.26317530 W 150.89461880 4.00 2654684.66 342509.61 N 61.26304439 W 150.89466248 4.00 2654631.02 342500.23 N 61.26289735 W 150.89471156 4.00 2654571.75 342489.87 N 61.26273485 W 150.89476580 4.00 2654507.15 342478.58 N 61.26255772 W 150.89482493 4.00 2654437.51 342466.40 N 61.26236680 W 150.89488865 4.00 2654363.19 342453.41 N 61.26216303 W 150.89495664 4.00 2654357.43 342452.41 N 61.26214725 W 150.89496192 0.00 2653792.89 342353.72 N 61.26059945 W 150.89547851 8/30/2001-11 :27 AM Station ID I (ft) I (°) ~ (°) I (ft) I (ft) I (ft) I (ft) I (0/100ft) I (ftUS) I (ftUS) I I PCU#4 Tgt 4553.07 51.30 189.13 3322.00 2756.84 -2725.85 -438.16 0.00 2652170.00 342070.00 N 61.25614996 W 150.89696333 4600.00 50.83 189.20 3351.49 2793.29 -2761.89 -443.98 1.00 2652134.05 342063.69 N 61.25605138 W 150.89699637 4700.00 49.84 189.34 3415.32 2870.16 -2837.87 -456.38 1.00 2652058.25 342050.25 N 61.25584356 W 150.89706677 4800.00 48.85 189.49 3480.47 2945.94 -2912.70 -468.79 1.00 2651983.60 342036.82 N 61.25563888 W 150.89713722 4900.00 47.85 189.64 3546.93 3020.58 -2986.39 -481.21 1.00 2651910.10 342023.39 N 61.25543733 W 150.89720774 5000.00 46.86 189.80 3614.67 3094.06 -3058.89 -493.63 1.00 2651837.78 342009.98 N 61.25523902 W 150.89727825 5100.00 45.87 189.97 3683.68 3166.37 -3130.18 -506.05 1.00 2651766.67 341996.59 N 61.25504403 W 150.89734876 GP Top 5183.14 45.04 190.11 3742.00 3225.59 -3188.53 -516.38 1.00 2651708.47 341985.46 N 61.25488443 W 150.89740741 - -- 5200.00 44.87 190.14 3753.93 3237.49 -3200.26 -518.47 1.00 2651696.77 341983.21 N 61.25485234 W 150.89741927 GP Bottom 5274.42 44.14 190.27 3807.00 3289.62 -3251.59 -527.71 1.00 2651645.58 341973.27 N 61.25471194 W 150.89747173 5300.00 43.88 190.31 3825.40 3307.38 -3269.08 -530.89 1.00 2651628.13 341969.85 N 61.25466410 W 150.89748978 5400.00 42.89 190.49 3898.08 3376.04 -3336.64 -543.29 1.00 2651560.76 341956.53 N 61.25447931 W 150.89756018 GP Top 5466.42 42.23 190.62 3947.00 3420.94 -3380.81 -551.51 1.00 2651516.71 341947.71 N 61.25435850 W 150.89760684 5500.00 41.90 190.68 3971.93 3443.43 -3402.92 -555.67 1.00 2651494.66 341943.25 N 61.25429802 W 150.89763046 GP Bottom 5546.95 41.43 190.77 4007.00 3474.63 -3433.58 -561.48 1.00 2651464.08 341937.02 N 61.25421416 W 150.89766344 5600.00 40.91 190.88 4046.94 3509.54 -3467.88 -568.04 1.00 2651429.88 341929.99 N 61.25412034 W 150.89770068 5700.00 39.91 191.08 4123.08 3574.35 -3531.52 -580.38 1.00 2651366.42 341916.78 N 61.25394627 W 150.89777074 5800.00 38.92 191.29 4200.33 3637.84 -3593.81 -592.70 1.00 2651304.30 341903.61 N 61.25377589 W 150.89784068 5900.00 37.93 191.51 4278.67 3699.99 -3654.74 -604.98 1.00 2651243.55 341890.50 N 61.25360923 W 150.89791039 6000.00 36.94 191.75 4358.07 3760.77 -3714.28 -617.24 1.00 2651184.19 341877.42 N 61.25344638 W 150.89797999 6100.00 35.95 191.99 4438.51 3820.18 -3772.42 -629.45 1.00 2651126.23 341864.42 N 61.25328735 W 150.89804930 6200.00 34.96 192.24 4519.96 3878.19 -3829.14 -641.63 1.00 2651069.68 341851.47 N 61.25313221 W 150.89811845 6300.00 33.98 192.51 4602.40 3934.79 -3884.42 -653.76 1.00 2651014.58 341838.58 N 61.25298101 W 150.89818731 6400.00 32.99 192.79 4685.80 3989.95 -3938.25 -665.84 1.00 2650960.92 341825.77 N 61.25283377 W 150.89825588 ~~, 6500.00 32.00 193.09 4770.15 4043.67 -3990.61 -677.86 1.00 2650908.74 341813.03 N 61.25269055 W 150.89832412 6600.00 31.01 193.40 4855.40 4095.92 -4041.48 -689.84 1.00 2650858.04 341800.36 N 61.25255141 W 150.89839213 6654.22 30.48 193.58 4902.00 4123.63 -4068.43 -696.30 1.00 2650831.18 341793.53 N 61.25247769 W 150.89842880 6700.00 30.03 193.73 4941.55 4146.69 -4090.85 -701.75 1.00 2650808.84 341787.77 N 61.25241637 W 150.89845974 6800.00 29.04 194.09 5028.55 4195.97 -4138.70 -713.60 1.00 2650761.16 341775.27 N 61.25228549 W 150.89852700 6900.00 28.06 194.46 5116.39 4243.73 -4185.02 -725.38 1.00 2650715.01 341762.86 N 61.25215879 W 150.89859388 7" Csg Pt 6904.22 28.02 194.48 5120.11 4245.72 -4186.94 -725.87 1.00 2650713.10 341762.34 N 61.25215354 W 150.89859666 7000.00 27.08 194.86 5205.03 4289.97 -4229.79 -737.09 1.00 2650670.41 341750.54 N 61.25203633 W 150.89866035 7100.00 26.10 195.29 5294.46 4334.67 -4273.01 -748.72 1.00 2650627.35 341738.32 N 61.25191812 W 150.89872637 7200.00 25.12 195.75 5384.63 4377.82 -4314.65 -760.28 1.00 2650585.88 341726.19 N 61.25180422 W 150.89879199 7300.00 24.14 196.24 5475.54 4419.39 -4354.71 -771.76 1.00 2650545.98 341714.16 N 61.25169465 W 150.89885716 PCU#4 (P10) Report.xls Page 2 of 3 8/30/2001-11 :27 AM Station ID I (ft) I (°) I (°) I (ft) I (ft) I (ft) ~ (ft) I (0/100ft) I (ftUS) I (ftUS) I I N 61.25158945 W 150.89892182 N 61.25148865 W 150.89898602 7600.00 21.21 197.98 5752.32 4534.61 -4465.25 -805.67 1.00 2650435.93 341678.75 N 61.25139229 W 150.89904966 7700.00 20.24 198.66 5845.85 4569.80 -4498.85 -816.79 1.00 2650402.48 341667.17 N 61.25130038 W 150.89911279 7800.00 19.27 199.41 5939.96 4603.37 -4530.80 -827.81 1.00 2650370.69 341655.71 N 61.25121299 W 150.89917534 7900.00 18.31 200.23 6034.63 4635.30 -4561.11 -838.73 1.00 2650340.53 341644.38 N 61.25113009 W 150.89923733 8000.00 17.35 201.15 6129.83 4665.58 -4589.76 -849.54 1.00 2650312.04 341633.18 N 61.25105172 W 150.89929870 - -, 8100.00 16.39 202.17 6225.52 4694.21 -4616.73 -860.24 1.00 2650285.22 341622.11 N 61.25097795 W 150.89935944 8200.00 15.45 203.30 6321.68 4721.18 -4642.03 -870.84 1.00 2650260.07 341611.17 N 61.25090875 W 150.89941962 8300.00 14.50 204.59 6418.29 4746.48 -4665.65 -881.31 1.00 2650236.59 341600.38 N 61.25084414 W 150.89947905 8400.00 13.57 206.05 6515.30 4770.10 -4687.57 -891.67 1.00 2650214.82 341589.72 N 61.25078418 W 150.89953787 8500.00 12.64 207.71 6612.70 4792.03 -4707.80 -901.91 1.00 2650194.73 341579.20 N 61.25072885 W 150.89959600 8600.00 11.73 209.64 6710.44 4812.27 -4726.32 -912.03 1.00 2650176.36 341568.83 N 61.25067819 W 150.89965345 8700.00 10.83 211.88 6808.51 4830.81 -4743.12 -922.01 1.00 2650159.69 341558.62 N 61.25063223 W 150.89971011 8800.00 9.95 214.52 6906.87 4847.65 -4758.22 -931.87 1.00 2650144.73 341548.56 N 61.25059093 W 150.89976608 End Orp 8871.44 9.33 216.70 6977.31 4858.63 -4767.95 -938.83 1.00 2650135.10 341541.47 N 61.25056431 W 150.89980560 TO /4-1/2" Lnr Pt 9502.49 9.33 216.70 7600.00 4951.77 -4850.00 -1000.00 0.00 2650053.90 341479.18 N 61.25033988 W 150.90015287 Leaal DescriDtion: Surface: 3695 FSL 2132 FEL S33 T14N R9W SM PCU#4 Tgt: 969 FSL 2574 FEL S33 T14N R9W SM TO /4-1/2" Lnr Pt / BHL: 4125 FSL 3140 FEL S4 T13N R9W SM Northina M fftUSl Eastina IX} fftUSl 2654889.40 342545.40 2652170.00 342070.00 2650053.90 341479.18 ---~, PCU#4 (P10) Report.xls Page 3 of 3 8/30/2001-11 :27 AM UNOCAL8 - - Q)- .æ~ g~ 0 Q) C'\I > II ..8 c CO :;:4= ..........0 ..c~ -ex:> 0.0) Q).......... om -~ r3~ .- Q) to::: Q) > > Q)~ ::JW L.. I- -2000 10000 0 2000 4000 6000 8000 / ~,. t \ VERTICAL Client: Well: Field: Structure: Section At: SECTION VIEW Unocal Date: PCU #4 (Pl0) Pretty Creek Unit Pretty Creek Unit 4 192.22 deg August 30, 2001 Schlumberger KOP Bid 1. 100300 MD 300 TVD 0.00' 189. 3' az 0 departure Bid 4/10 500 MD 500 TVD '3.00' 18 .13' az 5departure GP Top 5183 MD 3742 TVD 45,04' 190.11' az 3226 depa ure GP Bottom 5274 MD 3807 D ,/ 44.14' 190,27' az 3290 da rture . ./' ~:'2~~P ;:~~~~z 3;:; :~arture GP Bottom 5547 M 4007 TVD '41:43"'"19{f77"äz- '475'aë¡¡ä¡'¡üië 7UC. PI 8904 D 5120 TVD 28.02 194.48" az 4246 aparture End Drp 8871 MD 6977 TVD 9.33' 216.70' az 4859 departure -2000 2000 4000 6000 Vertical Section Departure at 192.22 deg from (0.0, 0.0). (1 in = 2000 feet) 0 :('" ( ...... UNOCAL8 PLAN VJ:EW Client: Unocal Well: Field: Structure: Scale: Date: PCU #4 (PiO) Pretty Creek Unit Pretty Creek Unit 4 1 in = 1000 ft 30-Aug-2001 Schlumberger -3000 -2000 -1 000 0 1000 2000 1000 True North 1000 Mag Dec ( E 21.22° ) 0 -1000 ^ ^ ^ :J: ~ a:: 0 z t, - Cj)' CO - 5 ;:, €, ~ ~ £ -2000 GP Top 5183 MD 3742 TVD 45.04' 190.11' az 3189 S 518 W " -3000 :J: ~ :::> 0 en V V V GP Bottom 5274 MD 3807 TVD-- 44.14' 190.27' az 3252 S 528 W -4000 -5000 End Drp 8871 MD 697 TVD 9.33' 216.70' az 4768 S 939 -6000 -3000 -2000 -1000 «< WEST 0 -1 000 -2000 PCUt14 Tgt 4553 MD 3322 TVD 51.30' 189.13' az . '2726S"4:¡ä'W""" , -3000 GP Top 5466 MD 394 7 TVD 42,23' 190,62' az 3381 S 552 W '-." GP Bottom 554 7 MD 4007 TVD 41.43' 190.77' az 3434'Š"S¡¡:¡ïjij' .., -4000 7"C8g PI 6904 MD 5120 TVD 28.02' 194.48' az 4187 S 726 W -5000 -6000 0 1000 EAST »> 2000 . \ . . / ( (' Interval Summary UNOCAL Pretty Creek #4 0-2450' MD 9, 5/8" :Casi'ng 12 1/4" Hole Drilling Fluid System Gel - Gelex Key'Products M-I Gel / M-I Bar / Soda Ash / Caustic Soda / Gelex / DD / Sapp / Drill XT Sol ids Control Flow Line Cleaners / Centrifuge / Desander / Desilter Pötel1tial>Prôl:Jlènis Hole Cleaning / Gravel/Gas Kick / Lost Circulation / Bit Balling ,.." Interval Drilling Fluid Properties Depth Mud Plastic Yield Gel API Total Interval V\lE!ight Visç()sity Point Strength Fluid Loss Drilled- .", ..,., """ ", ,."" ',< ",'. "", Sdliâs ,..' ,..., .' ",.i '... ',., ,,'. (ft) (ppg) (cp.) (lb./100ft2) (lb./100ft2) (ml/30min) (%) 200 8.7 5-10 20 - 30 N/C < 20 3 or less 1500 9.2 7-12 15 - 25 12 12-15 5 or less 2450 9.2-10.0 1 0-15 10 - 20 10-12 <10 5 or less . Build spud system with pre-hydrated bentonite and Gelex in fresh water. . Utilize all solids control equipment. . Raise viscosity if gravel sections are encountered. . Pump sweeps if required. . Add DD (drilling detergent) and/or Sapp for possible bit balling. . Potential Problems: Running gravel, bit balling, shallow gas, and swelling clay . Lower fluid loss to below 10 cc's API by end of interval with Polypac additions. . Estimated volume usage - 700 barrels. Note: Mud Weights of 10.0 ppg may be required because of potential shallow gas. M-I. L.L.e. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax (' -( Interval Summary UNOCAL Pretty Creek #4 2450' -6800' MD 7" Casing, 8 1/2" Hole Drilling Fluid System 6% KCl Flo Pro Key Products M-I Bar I Flo Vis I Soda Ash I Polypac ULI Soltex I Desco CF I Bicarb I Caustic Soda! KCL I KIa-guard I Drill XT IDual Flo Solids Control Flow Line Cleaners I Desander I Desilter I Centrifuge " Potehtial<Problems Hole Cleaning I Tight Hole I Bit Balling I Hole Enlargement I ...'".'"",',...".,.".,, ... ",.,',.. ,,'.,',.,., ,..',',',.,.."." ......'... "'. Gas Kicks I Coal Sloughing Depth (*) Mud Plastic Yield Gel API Total Interval Weight Viscosity Point Strength Fluid Loss DrilledSolids (ft) (ppg) (cp.) (lb./100ft2) (lb.l100ft2) (mI/30min) (%) 2500 9.0 -10.0 8 - 14 10 - 20 ~10 6-10 5 or less 5000 9.0 -10.0 8 - 14 10 - 20 8 - 10 <5 5 or less 6800 9.0 -10.0 8 - 14 10 - 20 8 or less <5 5 or less . Use surface mud to drill float collar, cement, and shoe. Treat this fluid for cement contamina- tion. . Build new Flo Pro mud system with 6% KCL. Run all solids control. Add KIa-guard for addi- tional inhibition. . Maintain adequate YP and 3 RPM reading for hole cleaning Lower fluid loss with Polypac UL and Dual Flo. Add 2 - 4 PPB of Soltex if running coal becomes a problem. . Potential problems: Gas kicks, Bit balling, sloughing coal. Lost Circulation possible due to de- pletion ofreservior to 6.5 ppg EMW @ 3700'.4000' TVD. . Run 7" casing. . Estimated volume usage - 1100 barrels. Note: Mud Weights as high as 10.0 ppg maybe required. Gas may be encountered just below the 9 5/8" casing. M-I. L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax . < . . l' ( ( Interval Summary UNOCAL Pretty Creek #4 680'0'-940'0' 'MO' '4 1/2" Liner 6" Hole Drilling Fluid System 6°/ó KCl Flo Pro KeyProducts M-I Bar / Flo Vis / Soda Ash / Polypac UL/ Soltex / Desco CF / Bicarb / Caustic Soda! KCL / KIa-guard / Drill XT /Dual Flo Solids Control" Flow Line Cleaners / Desander / Desilter / Centrifuge PotentialProblerns Hole Cleaning / Tight Hole / Bit Balling / Hole Enlargement / '." Gas Kicks / Coal Sloughing ,."..',"".' Interval Drilling Fluid Properties Depth (*) Mud Plastic Yield Gel API Total Interval Weight Viscosity Point Strength Fluid Loss DrilledSolids (ft) (ppg) (cp.) (lb./100ft2) (lb./100ft2) (ml/30min) (%) 6800 9.0 -10.0 8 - 14 1 0 - 20 8 or less <5 5 or less 9400 9.0 -10.0 8 - 14 10 - 20 8 or less <5 5 or less . Use 8 1/2" mud to drill float collar, cement, and shoe. Treat this fluid for cement contamination. . Maintain adequate YP and 3 RPM reading for hole cleaning Lower fluid loss with Polypac UL and Dual Flo. Add 2 - 4 PPB of So It ex if running coal becomes a problem. . Run 4 1/2" liner. . Estimated volume usage - 350 barrels. M-I. L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax . , ..' ( . . Well Summary ,~. \, UNOCAL Pretty Creek #4 Casing Hole Casing Depth TVD Mud Size Size Program System 9 5:'8" 12 1,'4" 2450' 2 000' Gel:Gclcx T' 8 I. 2'~ 6_. )" l1lil81li- .Keylssue .No. .1 Well ('1ontrol .Key .Issue No.2 Sloughing (~oal Hole Stability .Key Issue No.3 Drill Solids Build-~p Mud Weight Sum Days Cumulative Mud Cost 8.8-] 0.0 522,375 7 I 6800' 5] 00' FLOOR 6(~~) KCL 9.0 --. 10.0 14 5101,125 9400' 7600' FLOOR 6%) KC L 9.0. 10.0 7 S 116562 . Shallow gas sands may be encountered near the bottom of the surface casing. Mud weights as high as 10.0 ppg may be needed to control pressures. . Numerous stringers of coal (lignite) may be encountered throughout the well. Treatments of 2 - 4 ppb, Soltex can help in stabilizing sloughing coal. Maintain 4 - 6 ppb KlaGard concentration through the entire interval. Maintain KCL concentration. . Run as fine a mesh screens on shakers and centrifuge if avail- able to reduce the build up of drill solids in the mud. Dilu- tion and/or chemical additions may be needed to reduce pro- gressive gel strengths. M-I. L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax . , . . ( Load Out ( UNOCAL Pretty Creek #4 PRODUCT MI BAR MI GEL GELEX SODA ASH CAUSTIC SODA SODIUM BICARB BORAX POLYPACUL DESCO CF FLOVIS SOLTEX RESINEX DD KLAGAURD BUBBLE BUSTER SAPP DRILL XT NUT PLUG FINE NUT PLUG MEDIUM NUT PLUG COARSE MI SEAL FINE MI SEAL MEDIUM MI SEAL COARSE RECOMMENDED LOAD OUT ESTIMATED TOTAL SPUD LOAD 100 PALLETS 20 PALLETS 4 BOXES 1 PALLET 1 PALLET 2 PALLETS 2 PALLET 3 PALLETS 2 PALLETS 1 PALLET 4 PALLETS 2 PALLETS 2 PALLETS 4 PALLETS 1 PALLET 1 PALLET 2 PALLETS 1 PALLET 1 PALLET 1 PALLET 1 PALLET 1 PALLET 1 PALLET 50 PALLETS 10 PALLETS 4 BOXES 1 PALLET 1 PALLET 1 PALLET 1 PALLET 1 PALLET 2 PALLETS 1 PALLET 1 PALLET 1 PALLET 1 PALLET 1 PALLET 1 PALLET NOTE: SHOULD KEEP MINIMUM 2000 SX OF BAR ON LOCATION. KCL GREENCIDE SAFE SCA V 0 25 PALLETS 1 PALLET 1 PALLET M-I. L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax (' ( Project Team UNOCAL Pretty Creek #4 GusWìk WarehöuseMgr; ,', t ~ ....E~i~~~~>~~~t;Y ~ , , . MI Proj ect Engineer and Engineering Manager will coordinate between the Anadarko office, rig, warehouse, and the M-I field engineers. . Well progress will be monitored to look for any changes which will improve the effi- ciency of the operation or avert trouble.. Proj ect Team Title Work Cellular Craig Bieber District Manager 907274-5051 907229-1196 Deen Bryan Tech Service 907-274-5003 Lee Dewees Project Engineer 907-274-5533 907-230-6653 Gus Wik Warehouse Manager 907 776-8680 907 252-4218 M-I. LLC. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax E 12" 12" 6.x48 4" 48 X 68 WELL RETURNS MUD MIX HOPPER 6"x4" 4" "'8 4'" AS;; 8" ..--""".E:",- 6" MUD MIX HOPPER -lir- 6" 6" DESILTER 6" ~ 10" x 3- 3" a a a B G TRIP TANK 8" 6"x3" 3" LEG~ND -0- CONCENTRIC REDUCER ~ BOTTOM MUD GUN LOW PRESSURE lYPE - GATE VALVE -@- BUTTERFLY VALVE C/W FLANGES )t AGITATOR --g- SUCTION VALVE. TEE lYPE ~~K EQUALIZER ~ SUCTION VALVE. ELL TYPE OR SKIMMER 8" FLOW UNE TO MUD PUMPS 36" MUD GAS SEPARATOR TO F1..ARE Total Active System = 1,135 bbls (Not including Trip Tank) w 1-.1 om MUD SYSTEM SCHEMATIC NOT SHOWN ARE TANK CLEAN-DUTS SUMP SUCTION OR STEAM TRACE UNES H & R DRILLING INC. RIG 8 @-Et MUD TANK SCHEMATIC I.- ( Fill Line 13-5/8",5K, Shaffer Annular 13-5/8", 5M x 13-5/8, 5M Diverter Spool 58.75" 41.75" i 17" 13-5/8", 5M x 13-5/8, 3M Crossover Spool Welded 13-3/8" ( Flow Line 12", Hydraulic Operated Knife ., Valve 12", Diverter Line 13-5/8" 3M Starting Head 8.5' .. UNOCALej Diverter Hookup Well PCU No.4 West Side Cook Inlet, Alaska Drawn by: TeB Date: 7-24-01 11 ", 5M, Shaffer Annular 11", 5M, Shaffer Double Gate 11", 5M, Mud Cross 11", 5M, Shaffer Single Gate ( ~ ~ 15.75" ,----, , I I 58.75" + 26" i 17" 7" ( ~ ~ ~ 11" 5M x 11" 5M Cameron MB Tubing Spool 11" 5M x 13-5/8" 3M Cameron MB Spool 13-5/8" 3M Starting Head 8.5' Welded 13-3/8" 9-5/8" i 41-1/2 " ,r .... 33" l t 24" t 19-1/2" ~ . _~NOCALeJ BOP Hookup Well PCU No.4 West Side Cook Inlet, A.laska Drawn by: TCB Date: 7-24-01 .. ' . . \ . "I" I( ( TO FLARE TO FlARE TO DEGASSER A PLAL'T VIEW CHOKE LINE FROM B.O.P. SECTION' AA ' ~ ~~ .. DRILLING INC. Rig 9 Choke Manifold 3" x 5 000# , Unocal Corporation ( P.O. Box 196247 Anchorage, Alaska 99519 907-263-7671 UNOCAL8 Dan Williamson Drilling Manager Thursday September 20, 2001 Ms. Cammy Taylor, Commissioner AOGCC 333 West th Ave., Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill Pretty Creek Field Well NO.4 West Side, Cook Inlet Dear Chairperson Taylor, Enclosed is an Application for Permit to Drill (Form 10-401) for Pretty Creek Unit Well NO.4. PCU No.4 is proposed as a development gas well targeting the Beluga and Tyonek sands in the Pretty Creek Unit. The well will be directionally drilled from the existing PCU NO.2 Pad so no additional surface pad construction is necessary. The Beluga sands being targeted fall inside ADL 63048. The well bore will penetrate the prospective Beluga sands within approximately 221' of the ADL 58813 Lease Line. The well path will then cross the lease line onto ADL 58813 as it heads south until it penetrates the prospective Tyonek sands. Unocal is the lease holder of each lease and the well does not encroach on other property owners. Unocal proposes to utilize a 12" diverter line for the drilling of the 12-1/4" Survface hole. Of the three nearest offset wellsm, no problems were encouuntered while drilling surface hole. PCU NO.4 proposed surface casing depth is at the same TVD as PCU 2 and is 1,100' away. The anticipated start date for this well work is October 7, 2001. If you have any question please do not hesitate to call Tim Brandenburg at 263-7657. r-1' r'~'" ("''''~ ,,,at! ~r","m ,,~_. "",JJ (' .-' P 2 1 Z ,)t. ~,! J .001 0 R I G I N A IAlaska Oil & Gas con, s. Cormniss¡on L ,l\nchorage DATE INVOICE/CREDIT MEMO NO. VOUCHERNO. ~Ê$i~RN(). l QATE I CHECK NO. I , I I i 1031548 27-AUG-Oi 2004704 I DISCOUNT I NET ¡ FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WERE SUBMITTED 27-AUG-01 ~RILL PERMIT PCN~4 8013001064 100.00 100.00 L-'~"~~ (:~~ ~ \~L.. SEP 2 -; }~jnS;<:¿; --"1- FORM 4-28181 (REV. 11-95) PRINTED IN U.S.A. DETACH STUB BEFORE DEPOSITING CHECK 100.00 I I 100.00 ! - -- - -- - - - . .-----,- CITIBANK DELAWARE A Subsidiary of Citicorp ONE PENN'S WAY NEW CASTLE, DE 19720 62.20 311 UníonOilCorhpanyof California Accounts Payable Field Disbursing 2004704 UNOC-A-L.8 Pay One Hundred Dollars And 00 CentsJ~****,**~~**,***1r*********************** '< ,.e òrãér of STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE ANCHORAGE, AK 99501 United States CheCkA~o~~**100. 00 Void after six months from above date. III, 200.... 70 ~III 1:03 *10020HI: 19...J.J.a .¡'.3?lí' ,. r' l0\- \S > Unocal Corporation Agricultural Products 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7685 Facsimile 263-7901 ( UNOCAL8 RECEIVED Faye W. Sullivan Advising Environmental Scientist JUl 0 5 ¡nn1 July 2, 2001 Alaska OH & Gas Cons. Commjss;on Anchorage Mr. Jack Hewitt Project Manager Department of the Army U.S. Army Engineer District, Alaska P. O. Box 898 Anchorage, AK 99506-0898 Dear Mr. Hewitt: Pretty Creek Unit Gas Development Program This is to advise that Unocal has completed analysis of recent seismic data at Pretty Creek. We have determined that the downhole target for the proposed Pretty Creek #4 well can be drilled from the existing Pretty Creek #2 pad. Unocal hereby requests to withdraw its Department of the Army 404 permit application for the location designated as Pretty Creek #4, PC-U. We previously withdrew the application designated as Pretty Creek #4, PC-F, therefore, there are no pending permit applications for the Pretty Creek Unit Gas Development program. Please contact me if you have questions. Thank you for your help. _5;:; -fA}. ~ Faye W. Sullivan Enclosure cc: Judd Peterson, ADEC, Solid Waste Program Tim Rumfelt, ADEC 401 Cert. Program Gary Prokosch, ADNR, DMLW, Water Section Jim Haynes, ADNR, DO&G Mark Fink, ADF&G, Habitat Gary Wheeler, FWS Kaye Laughlin, DGC SPCO Phil North, EPA, Kenai River Center Ted Rockwell, EPA Judith Bittner, ADNR, SHPO Dan Seamount, AOGCC Ken Hudson, Mat-Su Borough Jeanne Hanson, NOAAlNMFS Unocal Corporation Agricultural Products 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7685 Facsimile 263-7901 ( UNOCAL8 Faye W. Sullivan Advising Environmental Scientist May 17,2001 (' ~O)-IC¡ 3 RECE\VED ¡.\ "\ 2001 \\i' ,t\ '{ 1;,' ' ' " mm\~cCi{'¡ "" 0, f:,,~,',"',,-,S L~)n.g:, ~lç¡,. l~t.~'~~, )tl . \" ß}(a 0\\ t'¡l.. ¡":I~'<,' Þ\,j1. ' , ' " .' ÄfW~~omgß - Mr. Jack Hewitt Project Manager Department of the Army U.S. Army Engineer District, Alaska P. O. Box 898 Anchorage, AK 99506-0898 Dear Mr. Hewitt: Pretty Creek Unit Gas Dev~lopment Program This is to advise that Unocal's analysis of recent seismic data at Pretty Creek have been completed. The surface location for this new well has been selected. Unocal hereby requests to withdraw its application for the location designated as Pretty Creek #4, PC-F. This is the location that was proposed !lout on the flats." Please continue to process our 404 Permit application for construction of the drilling pad designated Pretty Creek #4, PC-U. As we discussed, also enclosed are the first two pages of the application signed in the correct spot. Please contact me if you have questions or need additional information. Thank you for your help. Sincerely, J~ Faye W. Sullivan Enclosure cc: Judd Peterson, ADEC, Solid Waste Program Tim Rumfelt, ADEC 401 Cert. Program Gary Prokosch, ADNR, DMLW, Water Section Jim Haynes, ADNR, DO&G Dennis Gnath, ADF&G, Habitat Gary Wheeler, FWS Kaye Laughlin, DGC SPCO 'tv . ~St,J¿Wt't-,'-' Phil North, EPA, Kenai River Center Ted Rockwell, EPA Judith Bittner, ADNR, SHPO Dan Seamount, AOGCC Ken Hudson, Mat-Su Borough Jeanne Hanson, NOAAlNMFS ( ( APPLICATION fOR DEPARTMENT OF 11iE ARMY PERMIT OMI APPROVAL NO. 0710.0003 (33 CFR 3251' Expire. JUne 30. 2000 The Public burden for this collection of info~1Jon I. sestlmated to averagl 10 hour. per response. altho~gh the maJorhy of applications should re uil1 5 hours or less. Thl. Include. the time for reViewing InsvuC1ion., se8fchlng ex.l~ng data sources. gathering and maintaining thl data needed d q completing and reviewing the collection of information. Send comments regarding this burden ,estimate or any other aspect of thI. collection ~:n infoR11aûon. including suggestion. for reducing thi. burden, to Depanment of Defense. Washington Headquamrs Service Dlrectonlt8 of Inform tl Operation. and Reports. 1215 Jefferson Davis, Highway. Suite 1204. ArUngton, VA 22202-4302: and to the Office of Management and Bud :t an Paperwon Reduction Project 10710..(003), Washington. DC 20603. Respondent. should be aware that notwlth8tandlng any o1h.r proviliongoi'l no per80n she,D be subject to any penalty for failing 10 comply with a collection of information If It doe. not ~1'Play a currently valid OMI controlaw. number. Pllase DO NOT RETURN your form to lither of tholl addre8l8L Completed appUca1Jon,1 muSt'b. IUbmlttad to the DlatriCt Engine., having Jurisdiction over the location of the proposed activity. . PRIVACY ACT STATEMENT Authorities: Rivers and Harbors Act, Section 10,33 USC 403: Clean ~.lIr Act. Sec1ion 404, 33 use 1344: Marine ProteCtIon. Re..arch and SanctUaries Act. 33 use 1413. Section 103. PrIncipal Purpoee: Infarmadon provided on this fo"" will be ulld In Ivaluatlng 1111 appnu'don for I permit. RoUtIne U...: This Informa1Jon may be shared with the Cepanment of Justice and other fed.,al, 81818. Ind local government agencl,. Submission of requeSted Information Is voluntary, however, If Information II not provided the permh appllcltion cennot b8 evaluated nor can I ;'rmlt be I.....d. One lit of original drawings or good reproducible cople. which show thllocatlon and charlcter of the propo88d aC1lvhy muSt be attached to 1111. application C.. sample drawing. and Instructionl) and be atbmltted to the, District Engineer having Jurisdiction over 1M location of the propo. activity. An application thlt II not completed In full wUl be retUmed. ' 1. APPUCATION NO. '"EMS 1 THRU 4 TO BE FILLED BY THE CORI'~ 2. FIELD OFFICE CODE 3. DATE RECEIVED 4. DATE APPUCATION COMPLETI s. ÄPPUCANT'S NAME Unocal Alaska ~esources 'ITEMS BELOW TO 8E FILLED 8 API'LlC 8. AUTHORIZED AGENT'S NAME ANp TITLE Ian.,.,., II nor,..,...., Faye Sullivan, Advising Environme~tal Sci, 9. AGENT'S ADDRESS e. APPLICANT'S ADDRES~ 196247 909 W. 9th Avenue, P.O. Box Anchorage, AX 99519-6247 . O. AGENT'S PHONE NOS W REA CO .. R..idence 196'247 " b. Buline.. 907-263-7600 b. Bu~e8L 907-263-7685 " . S1 A YEMENT OF AUTHORIZ TION I hereby authorize, to act In my behalf a. my agent In thl procel8ing of thl. application and 1 furnish, upon request, supplemental In10rmation In support of this permit application. ~PPLICANT"S. SIG~A TURE DATE NAME. LOCATION AND DESCRIPT10N OF PROJECT OR ACTIVITY 12. PROJECT NAME'OR TITLE C..inIIrucIIoneJ Pretty Creek D4, PC-U 13. NAME OF WATERBODY, IF KNOWN 1iI.,...J Beluga River. Cook Inlet. TheodC?re River reek Unnamed Wetland 1 5. LOCATION OF PROJECT 14. PROJECT STREET ADDRES~ 1/1 ""'8bWJ Not Appl.ica~le Ms:! t s:lT1" ~K::!-~t1~i t'1UI 'RoTough , COUNTY A1s:1'::¡KA STATE 1'3., OTHER lOCATION DESCRIPTIONS, IF KNOWN, ø./tøfIuI:fItJMJ ~~ PC-U Latitude 61°15'26.731" Longitude 150°54'14.640" 17. DIRECTIONS TO THE SITE , From Beluga, head north on the existing Short~ÿ\after. crossing Grassy Creek the roåç (Figure 2). . unnamed road till you go over Grassy Creek. proposed.lI-oad would be on the east side of j ENG FORM 4345, Jul97 E,DITION OF FEB 94 IS OBSOLETE. CProponent: CECW ( ( 1 B. Nature of Activity (Ducn;ørion of project. include., f'.ftI1I.J Unocal is proposing to construct one oil and gas well pad, PC-U, and access road for exploration north of Beluga, Alaska. The pad will be 262 feet by 312 feet with a temporary waste storage pit on the north end of the pad that has a foot print of' 182 fe by 96 feet. The access road will be approximately 675 feet long and 34 feet wide (Figure 3). ' 19: Project Purpose (DacriJ» the fllØtHI or PU1110.. of tlNprojlCr.... iMtnJt:tioMJ - ..... See Supplemental Page USE BLOCKS 20-22 IF DREDGED AND/OR FILL MATERIAL IS TO BE DISCHARGED 20. Reason(s) for Discharge Fill material and structural gravel will be placed in wetlands to construct an oil and gas well pad and access road (Figures 3 and 4). 2;. Type(s) of Material Being Discharged and the Amount of Each Type in Cubic Yards Gravel fill will be used to construct the oil and gas well pad and access road. PC-U will require 7,637 cubic yards of fill and the access road will require 2,096'yards. 22. Surface Area in Acres of Wedand-. or Other Waters Filled IsH ltøtructiøntll A maximum of 1.1 acres will be affected for the pad Road construction would A maximum of 0.5 acres for the access road require clearing a 50 foot 23. Is Any Portion of the Work Already Complete? Yes - No, -X- IF YES, DESCRIBE THE COMPLETED WORK. 24. Addresses of Adjoining Property Owners, Lessees, Etc., Whole Property Adjoins the Waterb<tdy (If more than can be entered here, , please attach a supplemental list). -, ...:...' . - - Subsürfac~ Surface Alaska Department of Natural Resources ADF&G 550 West 7th Avenue 333 Raspberry Road Anchorage, Alaska 99501 . Anchorage, Alaska 99518-1599 Ant's 58810,58813, 58814, 63047, 63048, 63,049 25. List of Other Ce~ificatio!1s or Approvals/Denials Received fro~ ~ther Federal, State or Local Agencies for Work Described in This Application. AGENCY TYPE APPROVAL' ICENTIFICA TION' NUMBER DATE APPUED DATE APPROVED DATE DENIED See Supplemental Page . Would include but is not restricted to zoning, building and flood plain permits 26. Application is hereby made for a permit or permits to authorize the work described In this application. I certify that the Information In this application is complete and accurate. I further certify that I possess the authority to undertake the work described herein or am acting as the dUlY" "., thorlzed agent of th~ .~ppllcant." , / =-<,"j~ iJ ~J1Ul!rl--' .5 17/ D I . SI' ATURE OF APPLICANT DATE" SIGN~TURE OF AGENT DATE 11'.; bppllcatlon must be signed by the person who desires to undertake the proposed activity (applicant) or It may be signed by a duly authorized agent if the statement in block 11 has been filled out and signed. 18 U.S.C. Section 1001 provides that: Whoever, in any manner within the jurisdiction of any department or agency of the United States knowingly and willfully falsifies, conceals, or covers up any trick, scheme, or disguises a material fact or makes any false, fictitious or fraudulent statements or representations or makes or uses any false writing or document knowing same to contain any false, fictitious or fraudulent statements or entry, shall be, fined not more than ,$10,000 or imprisoned not more than five years or both. CHECK 1 STANDARD LETTER DEVELOPMENT v DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL . ( ~i' ~ RANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /~ 0J Û.uJ'I .lJë!j I CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) " ANNULA~ D~C, OSAL ~NO ANNULAR DISPOSAL <-> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new well bore segment of existing well --:I Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The, permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (ComDanv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY rJAk-->c--=- / FIELD & POOL S1fðS'("~ t? INIT CLASS ADMINISTRATION 1, Permit fee attached. . . , . . . , . . . . . , . . . . . , . . , ;: ~~~;~en~~~~~:~~~ri~~~b~r.'. '. '. '. " " '. '. '. " '. " " '. '. '. " if:y N ~ ~~ Cr~ ~ç~; ~~&~ ~~ ~: ~::: :~~~:~ ~r~p~~~:t~~~~~;"; drilli~g ~n¡t b~u~da~~ '. '. '. Y NbAo// /~, c~<:If-/;/t1 c.U;~. 9ß db4 Þ,,; - ~ 6. Well located proper distance from other wells.. . . , . . . . . Y N , . " . 7. Sufficient acreage available' in drilling unit.. . . . . . . , N. 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . , . . . . , . . . . . N 10. Operator has appropriate bond in force. , . . , , . , , N 11. Permit can be issued without conservation order. . . . . N wR -:-DJ\111. 12, Permit can.be issued without administrative approval.. , . . , N L.- ~~ 13. Can permit be approved before 15-day wait.. . . , . . N 14. Conductor string provided. . . , , . . . ., . , . . . , . . . 'i. N 15. Surface casing protects all known USDWs. . . . . . , N 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg. . . , . . . , N 18. CMT will cover all known productive horizons. . . , . . N 19. Casing designs adequate for C, T, 8 & permafrost. . . . . . . ' N l 20. Adequate tankage or reserve pit.. . . . . . . . . . , . . . , . N Q..~""'~\I'o;: ~ '- . ~O ~~~ ~~ 21. If a re-drill, has a 10-403 for abandonment been approved, . . ~~..::> \' \. ("... ~ 22. Adequate wellbore separation proposed.. . . . . . . . . . . , N -, \ ,'\ c..\ K c.: ~.~. '. <è~ '\~~) 23. If diverter required, does it meet regulations. . . . . . . . . . Y N lè1-'l,-\" ~~ \~ ,,\ \\~ "\c;. ~~ \v 24. Drilling .fluid program schematic & equip list adequate. , . . . N ' ~~: ~g~~spr~~~~:iï~e:~¿~;~~~~i~;nt~sit~ . . , . "~~sig: ~'-"~~~ ~~~~~,~~').~~~~( 27. Choke manifold complies w/API RP-53 (May 84). . . . . . , . N ~~: ~~~:~~~rH~h;~~ ~~:~:~?; ~~u~d~~n: : : : : : : : : : : Y ~ 30, Permit can be issued w/o hydrogen sulfide measures. . . .' Y N / ~~: ~:::~~e:~~:;~i~~tsO~:~:1 ;::~~~::~r~ ~~n~~ ". : '. '. : : : ~ /1//4, AP- R ~{ ~: ~~~~:~ ~~~~~~o~~~i Z~~;~~~~~~s~ ~ep~rt~ [e~p/~r~t~~ o¿~ ~ - , ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate frèshwater; or cause drilling waste. " to surface; . (C) will not impair mechanical integrity .of the well used for disposal; Y N (D) will not damage producing f.ormation or impair recovery fr.om a Y N po.ol; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~þ~ WM~ . Ú "" ENGINEERING 9ð15 GEOLOGY APPR DATE PROGRAM: exp - dev .x redrll- serv - wellbore seg _ann. disposal para req - GEOL AREA ?:.L<=, UNIT# //,< :? Q ON/OFF SHORE ~ N c 0 Z ( 0 -t ~ ::0 -I m - z -t :I: en » ( ::0 m » Y N Y N --- ~~ ..\ò c-\a,~s 'n: ~,,\ Comments/Instructions: II)i.flo ì c:\msoffice\wordian\diana\checklist (rev. 11/01/100)
