The URL can be used to link to this page

Home My WebLink About202-168 i From: Saltmarsh, Arthur C (DOA) Sent: Monday, March 09, 2009 11:08 AM To: Maunder, Thomas E (DOA); Seamount, Dan T (DOA); Davies, Stephen F (DOA); Roby, David S (DOA); McMains, Stephen E (DOA); Williamson, Mary J (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); Colombie, Jody J (DOA); Gary Carlson; Norman, John K (DOA); Foerster, Catherine P (DOA); Laasch, Linda K (DOA); IongmereCa~verizon.net Subject: FW: Pacific Energy files chapter-11, it's official!!! Fl(l. PACIFIC ENERGY RESOURCES LTD. r ~ - , k T. y 111 West Ocean Blvd., Suite 1240 Long Beach, California 90802 Telephone: (562) 628-1526; Fax: (562) 628-1536 Files for Chapter 11 to Facilitate a Restructuring aoa-peg LONG BEACH, CALIFORNIA, Monday, March 9, 2009 - -Pacific Energy Resources Ltd. (the "Company")(TSX:PFE) announces today that it and its wholly owned subsidiaries have filed voluntary petitions for reorganization under Chapter 11 of the U.S. Bankruptcy Code in the U.S. Bankruptcy Court for the District of Delaware. The filing was precipitated by the dramatic decrease in the market price of oil over the past five months. Combined with the Company's pre-existing level of debt related to past acquisitions and poor capital market conditions, the Company's liquidity and cash flow is insufficient to operate its business and invest in its oil producing assets to increase production. Faced with these constraints, the Company and its subsidiaries filed petitions for reorganization under chapter 11 to facilitate access to an immediate source of liquidity as it works to restructure its debt. In connection with the filing, the Company is seeking customary authority from the Bankruptcy Court that will enable it to continue operating its business in the ordinary course of business. The requested approvals include requests for the authority to make wage and salary payments and continue various benefits for employees. In addition, the Company has negotiated a commitment for $40 million in debtor-in-possession ("DIP") financing. The DIP facility wraps and replaces two of the Company's three asset-based credit facilities and is being provided by the lenders of the two credit facilities that are being replaced. Upon Court approval, the DIP financing combined with the Company's operating revenue will provide sufficient liquidity to fund working capital, meet ongoing obligations and ensure that normal operations continue without interruption during its restructuring. About Pacific Energy Resources Pacific Energy Resources Ltd. is an oil and gas exploration and production company based in Long Beach, California, U.S.A. Additional information relating to the Company may be found on SEDAR at www.sedar.com. The Company's web site is www.PacEnergy.com. ON BEHALF OF THE BOARD OF DIRECTORS • • PACIFIC ENERGY RESOURCES LTD. Pacific Energy Resources Ltd. 310 K. Street, Suite 700 Anchorage, AK 99507 Office: 907-258-8600 Fax: 907-258-8601 David Hall Alaska Operations Manager Main: 907-868-2133 Cell: 907-317-8239 dmhall(a?pacenera~m w~v~v.pacenera~m • Maunder, Thomas E (DOA) From: David Hall [DMHeII@pacenergy.com] Sent: Wednesday, July 30, 2008 8:12 AM To: Maunder, Thomas E (DOA) Cc: Joe Kitchrist Subject: RE: RU 5A (202-168) Attachments: Scan_10 404_RU#5A_Jul 30_2008.pdf Page 1 of 1 Tom, Please see the attachment showing the dates on the operation summary in regards to the 404 form for RU5A. Thank you, David Pacific Energy Resources Ltd. 310 K. Street, Suite 700 Anchorage, AK 99507 Office: 907-258-8600 Fax: 907-258-8601 David Hall Alaska Operations Manager Main: 907-868-2133 Cell: 907-317-8239 .cam dmhall a,pacenergy.com From: Maunder, Thomas E (DOA) [maitto:tom.maunder@aiaska.gov] Sent: Tuesday, July 22, 2008 11:54 AM To: David Hall Subject: RU 5A (202-168) David, We have received the revised 404 for the work recently done on RU 5A. The information does not include any dates as to when the work was done. Can you add the operating dates to the operations summary? Sending the updated summary is acceptable via email. Call or message with any questions. Tom Maunder, PE AOGCC ~~1~~ ,IUL ~ ~ 200$ 7/30/200$ • PACIFIC ENERGY RESOURCES, LTD. 310KStreet, Suite 700 Anchorage, AK 99501 S Phone: (907) 258-8600 • Fax: (907) 258-8601 ~ M•` -v ~. July 15, 2008 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 W. 7~` Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Forest Oil Redoubt Unit #SA Jet Pump Conversion (Sundry No. 307-169) Dear Mr. Seamount, Attached please find additional information per Tom Maunder's email request on July 9, 2008 in reference to Form 10-404 Report of Sundry Well Operations for the conversion of Redoubt Unit Well #SA from electric submersible pump operation to jet pump that was submitted and dated July 2, 2008 by Pacific Energy Resources Ltd. If you have any questions, please contact me at 868-2133. Sincerely, /~ ~`~ David Hall Alaska Operations Manager Attachments: Form 404 Report of Sundry Well Operations Operations Summary Log Operations Summary Details Updated Wellbore Schematic Email Request Pacific Energy Resources Ltd, 111 West ocean Blvd. ,Suite 1240, Long Beach, CA 90802 Ph: 562-628-1526 Fax: 562-628-1536 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION e ~~/ A,~~~~~ ail ~~ ~ ~ ~ ~~~$ REPORT OF SUNDRY WELL OPERATIONS ~{~' a ~ ?.7h;~ ~!^r~r. ~ w'i'ry 1. Operations Abandon ^ Suspend ^ Operation Shutdown ^ Perforate^ Waiver^ '~- Other' `~S Performed: Alter Casing ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Convert to jet pump Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: Pacific Energy Resources, Ltd. Development ^~ Exploratory^ 202-168 3. Address: 310 K Street, Suite 700, Anchorage, Alaska Stratigraphic^ Service^ 6. API Number: 99501 50-733-20513-01 - 7. KB Elevation (ft): 9. Well Name and Number: 90' AMSL Redoubt Unit #5A 8. Property Designation: 10. Field/ P ol(s): o ~ `` `` ~ ADL 374002 __ Undefined Oil Pool `'S~f3c7`~'t S~~i 11. Present Well Condition Summary: ~~~, `~ i Total Depth measured 17,000 ~ feet Plugs (measured) Pkr & LLC @ 14,988' true vertical 12,830 feet Junk (measured) N/A Effective Depth measured 16,575 feet true vertical 12,639 feet Casing Length Size MD TVD Burst Collapse. Structural 200' 30" 200' 200' N/A N/A Conductor Surface 3,190' 13-3/8" 3,190' 2,940' 5,020 2,260 Intermediate 11,500' 9-5/8" 11,500' 10,065' 6,870 4,750 Drilling Liner 4,033' 7-5/8" 15,323' 11,980' 6,890 4,790 Liner 1,882' 5-1/2" 17,000' 12,830 7,740 6,290 Perforation depth: Measured depth: 15,350'-16,525' True Vertical depth: 11,995" -12,616' Tubing: (size, grade, and measured depth) 3-1/2", P-110 & L-80, from surface to 14,946" Packers and SSSV (type and measured depth) LLCM valve in Baker FA pkr set @ 14,988'MD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 65 16 691 238 1544 Subsequent to operation: 51 ~ 12 99 272 4536 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run NIA Exploratory^ Development Q Service ^ Daily Report of Well Operations Oprns Summary 16. Well Status after proposed work: Oi10 Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-169 Contact David Hall 868-2133 h ~ `(~ Printed Name David Hall Title Production Manager 1 t '- ~ Signature ~ ~~'K 2133 Date ~~ o?- p ~ -T Phone 868 .. - r~ !"1 ~ ro ~ ~.,,~ a~1 ~ ~ S ~~. ,1UI ,~ 0 2008 ~~~/`~'f~ :7 Redoubt Unit #SA -Jet Pump Installation Operations Summary Details The Electric Submersible Pump (ESP) in the Redoubt Unit #SA well failed on January 6, 2007. The ability to produce from either ESP or jet pump was originally planned and designed for. RUSA completion includes a packer and two sliding sleeves which will accommodate the down hole jet pump. Pacific Energy is utilizing produced water as power fluid to drive the jet pump. This is a "standard" jet pump configuration, whereas the power fluid goes down the tubing and production returns up the annulus. Projected power fluid pressure at the wellhead is less than 4800 PSIG and power fluid flow rate to ~ 3800 BPD. Projected annulus return pressure at the wellhead is 200-500 PSIG and production flow rate anticipated to that of ESP (600 - 1200 BPD). The operation of the SSV is set to close upon the following conditions: PSHH @ 2200 PSIG on the casing annulus. PSLL @ 125 PSIG on the casing annulus. Wellhead MAOP of 5000 PSIG will be protected from pressure relief valves on the produced water injection pumps onshore. • Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, July 09, 2008 2:41 PM To: David Hall Subject: RU 5A (202-168) and RU 7 (203-150) David, I am reviewing the latest 404s submitted regarding the jet pump activities. RU 5A - Do you have any greater detail regarding the work pertormed? Although pressures and depths are .~' included, the operations report is very similar to the procedure. RU 7 -The coil tubing string installed in the well is not listed on the 404 sheet. Could you send in a new 404 sheet with the CT string detailed on a line under the current 7" liner line? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 7/21/2008 ~~ July 2, 2008 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 W. 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 AjaSk~ !~1~ ~ Cap ~oRS, ~'o~.~ii~Sr~r~ °~~2~~'i~3i'c~~~' Re: Forest Oil Redoubt Unit #SA Jet Pump Conversion (Sundry No. 307-169) Dear Mr. Seamount, Attached please find a Form 10-404 Report of Sundry Well Operations for the conversion of Redoubt Unit Well #SA from electric submersible pump operation to jet pump. Additional attachments include a summary work description and an updated wellbore schematic. If you have any questions, please contact me at 868-2133. Sincerely, or/c/ 6 o%N~' David Hall Production Manager attachments • PACIFIC ENERGY RESOURCES, LTD. 310 KStreet, Suite 700 Anchorage, AK 99501 Phone: (907) 258-8600 • Fax.• (907) 258-8601 Pacific Energy Resources Ltd, 111 West Ocean Blvd ,Suite 1240, Long Beach, CA 90802 Ph: 56228-1526 Fax: 562-628-1536 g STATE OF ALASKA ~ F= f'`~ ~"" `" ALA OIL AND GAS CONSERVATION COMMON , ~ ~,~~, REPORT OF SUNDRY WELL OPERATIONS ~ 2 y..., ~, Al~u~ : ~~r,~. 1. Operations Abandon Suspend Operation Shutdown Perforate Waiver Other ~ ^ ^ ^ f~~,.:.: Performed: Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Time Exterision ^ Convert to jet ` pump Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspen ed Well ^ 2. Operator 4. Current Well Class: 5. Per to Drill Number: Name: Pacific Energy Resources, Ltd. Development^ ~ Exploratory ^ 202-168 3. Address: 310 K Street, Suite 700, Anchorage, Alaska Stratigraphic ^ Service ^ 6. PI Number: 99501 50-733-20513-01 • 7. KB Elevation (ft): 9. Well Name and N ber: 90' AMSL Redoubt Unit #5A S. Property Designation: 10. Field/Pool(s ADL 374002 • ~~K,~ ~~ Undefined Oil Pool ~•j•~-~ 11. Present Well Condition Summary: Total Depth measured 17,000 feet P gs (measured) pkr 8~ LLC @ 14,988' true vertical 12,830 ~ feet Junk (measured) N/A Effective Depth measured 16,575 feet true vertical 12,639 feet Casing Length Size MD TVD Burst Collapse Structural 200' 30" 200' 200' N/A N/A Conductor Surface 3,190' 13-3/8" 3 0' 2,940' 5,020 2,260 Intermediate 11,500' 9-5/8" ,500' 10,065' 6,870 4,750 Drilling Liner 4,033' 7-5/8" 15,323' 11,980' 6,890 4,790 Liner 1,882' 5-1 /2" 17,000' 1 ,830 7,740 6,290 2 f ~ Perforation depth: Measured depth: 15,350'-16,525' ~1"`~I~~'~^ ~" ~, ? True Vertical depth: 11,995" -12,6 ~ ~ ~°~ Tubing: (size, grade, and measured depth) 3-1/2", P-110 8 L-80, from surface to 14,946" Packers and SSSV (type and measured depth) LLC-3 valve in Baker FA pkr set @ 14,988'MD 12. Stimulation or cement squeeze summ Intervals treated (measured): N/A Treatment descriptions including v mes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior t ell operation: 65 16 691 238 1544 Subse ent to operation: 51 ~ 12 99 272 4536 14. Attachments: 15. Well Class after proposed work: Copies of Logs a Surveys Run N/A Exploratory^ Development ~ ~ Service ^ Daily Report of ell Operations Oprns Summary 16. Well Status after proposed work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereb certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-169 Contact David Hall 868-2133 Printed Name avid Hall Title Production Manager /D Q ~ Signature a/ ~ ~~•"~ Phone 868-2133 Date ~- o?y O . l~~~G~/l~ T. B.os r ~ Redoubt Unit #5A -Jet Pump Installation Operations Summary Beginning 12-29-07 1. N/U and test lubricator to 3,000 psi -okay. 2. R/U WL, RIH w/ 2.So" gauge ring to 13,300'. POH. 3. RIH w/ shifting tool, shift open RIV sleeves at 13, 150' and 12,259'. POH. 4. RIH with 3" standing valve, set at 13,259 in lower RIV sleeve. POH. 5. RIH with RIV sleeve open/close confirmation tool. Set down on standing valve at 13,259'. POOH and inspect tool -tool did not shear. 6. RIH with 3" National Oil Well jet pump and set in standing valve at 13,259'. POH and rig down wireline. 7. Fill tubing and annulus with produced water. Pressure test annulus and tubing to 2,000 psi for 30 minutes -okay. Bleed off. 8. M/iJ flow connections and bring well on in 500 psi increments, bringing power fluid pressure up to 4,800 psi. Ending 01-01-08 ~~~~ ~~ .~ ~~ 1 ~-~~ ~~ ~ 4 `~ J C] • Redoubt Unit #SA -Jet Pump Installation Operations Summary ~ 1. N/LT and test lubricator to 3,000 psi -okay. 2. R/U WL, RIH w/ 2.50" gauge ring to 13,300'. POH. 3. RIH w/ shifting tool, shift open RIV sleeves at 13,150' a 13,259'. POH. 4. RIH with 3" standing valve, set at 13,259 in lower RIV leeve. POH. 5. RIH with RIV sleeve open close confirmation tool. et down on standing valve at 13,259'. POOH and inspect tool -tool did not sh 6. RIH with 3" National Oil Well jet pump and set 'n standing valve at 13,259'. POH and rig down wireline. 7. Fill tubing and annulus with produced Ovate .Pressure test annulus and tubing to 2,000 psi for 30 minutes -okay. Bleed 8. M/iJ flow connections and bring well in 500 psi increments, bringing power fluid pressure up to 4,800 psi. ~~ ~ , \~.~~, ~, ~~~~~~ ~- J``,~~ ~ v v~ 1 ~~-vim Redoubt Uni~A Completion -December, 2007 TOL @ 11290 MD 30" 150 # 13 3/8" 68 # A-36 200 TVD Welded 200 MD L-80 2940 TVD BTC 3190 MD Tubing 3-1/2", 12.95#, P-110, TSHD 9 5/8" 47 # L-80 10065 TVD BTC 11500 MD RIV Sleeve 13,150' MD (open) Weatherford Hyd 11 Pkr @ 13,204' MD RIV Sleeve 13,259' MD (open) with standing valve and jet pump installed. TOL@15118 MD Perforations: 15,350' - 15,385' 15,410' - 15,460' 15,560' - 15,600' 15,615' - 15,635' 15,765' - 15,915' 15,950' - 15,960' 16,020' - 16,030' 16,170' - 16,525' 3/8" 6 SPF :entrilift ESP Assembly stake @ 13,377' MD nd @ 13,433' MD <er Model FA Packer 4988 MD 7 5/8" L-80 11980 TVD 29.7 # Hydril 521 15323 MD 'erforations .Z Drill @ 16575 MD 5 1/2" L-80 12830 ND 17 # Hydril 521 17000 MD • ~~ [ ~ J j ~ SARAH PAIIN, GOVERNOR ALASSA OII, A1~TD GA5 333 W. 7th AVENUE, SUITE 100 C011f5ER~'ATIO)•T COMl-II551Or1T ANCHOF2P,GE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Hall Production Manager Forest Oil Company 310 K Street, Suite 700 ~~~ ~~~ ~ ~ ZOD7 Anchorage, AK 99501 Re: Redoubt Shoal Field, Undefined Oil Pool, Redoubt Unit #SA Sundry Number: 307-169 Dear Mr. Hall: 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 this~~day of December, 2007 Encl. ~~-<jv~ • • • ~ Forest Oil Corporation 310 K Street, • ~ • Suite 700 Anchorage, Alaska 99501 (907) 868-2133 or 776-7108 Fax: (907) 258-8601 or 776-7119 May 22, 2007 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7~' Avenue. Suite 100 Anchorage, AK 99501-3539 Re : RU #5A Jet pump Completion: Dear Mr. Maunder: Enclosed per your request, please find the updated Sundry Notice for RU #5A Jet Pump Completion. If you have any further questions, please contact me at 868-2133. Sincerely, ~~ David Hall ~ " Production Manager Forest Oil Corporation DH:rv Enclosure STATE OF ALASKA ALASKA OlL AND GAS CONSERVATION COMMISSION MaY ~ ~ 2007 APPLICATION FOR SUNDRY APPROVALS ~~/r~ ~n ear o~ man Alaska flit R, t;nc f nee t+......r.~ .. Other ^ 1. Type of Request: Abandon Suspend ^ Operational shutdown ^ Perforate ^ B ~ A ~ ` ~ W~ ji Attar casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Exton Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ .d r~'"`r°' 2.Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ~..y3. Forest Oil Corporation Development ^ Exploratory ^ 202-168 3. Address: Stratigraphic ^ Service ^ 6. API Number. 310 K Street, Suit 700, Anchorage, Alaska 99501 50-733-20513-01 ~ 7. If pertorating, closest approach in pool(s) opened by this operation to nearest e. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Requfred7 Yes ^ No ^ Redoubt Unit #5A ' 8. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Redoubt Unit ~>D~ 3?~oc>Z~ ,~~.~~ 90' MSL Redoubt Shoal Oil Field, Redoubt Shoal .C'U.' 12. PRESENT WELL CONDITION SUMMARY ~,~ Total Gepth iLiv ~iij: T otai Gep[n TVG (ftj: Eriective Gepih iviD (ft): Effective Gepin Tvu (ftj: 'rings (measuredj: - Junk (rreasuredj: 17,000' 12,830' 16,575' 12,639' LLC & Packer @.14,988' Casing Length Size MD TVD Burst Collapse Structural 200' 30" zao' 200' N/A N/A Ganductor Surface 3,190' 13-3/B" 3,190' 2,940' Intermediate 11,500' 9-518" 11,500' 10,065' Production 1,882' 5-1i2" 17,000' 12,830' Liner 4,033' 7-5l8" 15,323' 11,980' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 15350'-16525' 11995'-12685' 3-112" 48 jts P-110, 424 jts L-80 14,946' Packers and SSSV Type: Baker FA packer wILlC-3 valve Packers and SSSV MD (ft): 14,888' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development 0 Service ^ 15. Estimated Date for 28-May-07 16. Well Status after proposed work: Gommencing 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 J •.~ II }l4M ^Ygri1~' YG~ri~i ~~ii Tftl~i ~I Q~~i~i~r~i~i Mariay-sr Signature Phone 907-258-8600 Date 5122/2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ~O?,,, ~ t'o Plug Integr ity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ g ~-~ Other: ~~~ ~ ( ~®~ ~~5~ ~S ~ ~ ~~~~~ ~r- p '~/ -~ ,(t p~ -~~-C.. ~~(;~ I ,~j' ~~ 1°` ~P r r~ n ~ ^ - ^~r ! ~ Y~- t 1~ 1 ~'c ~lJr,w 1'~ ~~C,~ 1 ! ~C f E ~ ~ i~ 1E~.'d"zvv l~ , t Subsequent Form Required: t.-.~ roved b A : APPROVED BY /~ ~~ , 10~ C SSIONER THE COMMISSION Date: ~' pp y 7 .0'7 Form 10-403 Revised 06/2006 . , ~~ ~l.. ~ ~~pt ubmit' plica e L .. ~~~ "~ ORIGIN • • Forest Oil Corporation ~ 31 D K Street, Suite 700 Anchorage, Alaska 99501 (907) 868-2133 or 776-7108 Fax.• (907) 258-8601 or 776-7119 May 24, 2007 RU5A Operation Procedure for Conversion to Jet Pump: RU5A Current Well Status: • Shut in as a result of a failed ESP, failed on January 6, 2006. • 3-1/2" 12.95#, P-110 tubing. • RIV top sleeve @ 13,150' MD. • RIV bottom sleeve @ 13,259' MD. • Weatherford Hyd 11 packer @ 13,204' MD. • ESP intake @ 13,37T MD, ESP end @ 13,433' MD. • Baker Model FA packer @ 14,988' MD. • Starting perforations @ 15,350' MD, ending perforations @ 16,525' MD • KB @ 90' MSL feet. Pre RU5A ESP failure conditions (last day of flowing conditions, 1-6-06) • Flow rate: 650 - 700 BPD. • Water cut: 93°l0. • Fluid surface temp: 127 degrees. • Flowing tubing pressure: 1545 PSIG. • Annulus pressure: 280 PSIG. RU5A Conversion Procedure: 1. Test lubricator to 3,000 PSIG. 2. RIH with 2.50" gauge ring, POOH 3. RIH with 2.562" shifting tool and shift RIV Sleeve @ 13,259' MD then shift upper RIV Sleeve @ 13,150' MD, POOH. 4. RIH with 3" standing valve and set @ 13,250' MD in lower RIV Sleeve, POOH. 5. RIH with RIV sleeve opeNdose confirmation tool and set down on standing valve, POOH and confirm pins in confirmation tool did not sheer. 6. RIH with 3" National Oil Well jet pump and set in standing valve @ 13,250' MD, POOH, rig down. 7. Conduct Bundle test, (casing, tubing annulus integrity verification test) a. Fill tubing and annulus with produced water relieving and air while filling. b. Pressure up tubing and annulus to 2,000 PSTG. c. Allow enough time. for pressure to stabilize, then monitor and record tubing and Annulus pressure for 30 minutes. d. Bleed off tubing and annulus pressure when test is completed. 8. Fundionai checkout all assodated alarms, shutdown, meters and surface safety valve. 9. Line up flow connections and bring well online, slowly work power fluid up in 500 PSIG increments until reaching 4800 PSIG while verifying returns. 10. Annulus pressure not to exceed 2200 PSIG and surface tubing pressure not to exceed 5000 PSIG. David Hall Production Manager Office 907-776-7108 -868-2133 Cell 907-317-8239 Fax 907-776-7119 ~GCG~ V ~~ MAY 2 4 2007 Alaska Ojl & Gas Cons. Col'rtm~s#ion Anchorage ® • A ~ ,; Forest Oil Corporation ~~. 310 K Street, Suite 700 Anchorage, Alaska 99501 - (907) 868-2133 or 776-7108 Fax: (907) 258-8601 or 776-7119 April 18, 2007 Mr. Tom Maunder, Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re : RU #5A Jet pump Completion: Dear Mr. Maunder, Forest Oil Corp is proposing to produce Redoubt Unit #5A (RU #5A) by means of a jet pump. The Electric Submersible Pump (ESP) in the RU #5A well failed on January 6, 2007.`The ability to produce from either ESP or jet pump was originally planned and designed for as is reflected on the completion diagram (see attachment). The RU #5A completion includes a packer and two sliding sleeves which will accommodate the downhole jet pump. Forest planes to utilize produced water as the power fluid to drive the jet pump. Forest proposes a "standard" jet pump configuration, whereby the power fluid will go down the tubing and production returns up the annulus. The projected power fluid pressure at the wellhead is near 4,800 PSIG, with a power fluid flow rate of approximate 3,800 BPD. Projected annulus return pressure at the wellhead is 200-500 PSIG with an anticipated production flow rate of 600 - 1200 BPD (in excess of the power fluid}. The proposed well allocation would involve subtracting power water fluid from return fluid. Forest proposes to leave the SSV on the tubing side (power fluid side). The proposed operation of the SSV would be set to close upon the following conditions: • PSHH @ 2,200 PSIG on the annulus. • PSLL @ 50 PSIG on the annulus. • ESD, OSD, GSD. Wellhead MAOP of 5,000 PSIG will be protected from pressure relief valves on the produced water injection pumps onshore. If you have any questions, please contact me at 868-2133. Sincerely, David Hall Production Manager Forest Oil Corporation Attachments: Sundry notice Wellhead completion P&ID Wellbore Schematic - RU #5A • Redoubt Unit #5A Completion -February, 2005 30" A-36 200 ND 150 # Welded 200 MD 13 3l8" L-80 2940 ND 68 # BTC 3190 MD TOL @ 11290 MD Tubing 3-1/2", 12.95#, P-110, TSHD 9 Sl8" 47 # L-80 10065 ND BTC 11500 MD RIV Sleeve 13,150' MD Weathertord Hyd 11 Pkr ~ 13,204' MD RIV Sleeve 13,259' MD TOL@15118 MD Perforations: 15,350' - 15,385' 15,410' - 15,460' 15,560' - 15,600' 15,615' - 15,635' 15,765' - 15,915' 15,950' - 15,960' 16,020' - 16,030' 16,170' - 16, 525' 3/8" 6 SPF :entrilift ESP Assembly ntake ~ 13,377' MD :nd ~ 13,433' MD ker Model FA Packer 14988 MD 7 5/8" L-80 11980 N D 29.7 # Hydril 521 15323 MD perforations EZ Drill ~ 16575 MD 5 1 l2" L-80 12830 N D 17 # Hydril 521 17000 MO ~/UTr $ . /. Jule. P a_[.a.,;.,.L :~..r ,~ r-a9 ~ ,' ~ro /s.ca~ c~*ar Bled AJ Powar ~'w~ ~- TGf P .w~ S sas[d~+• / CnaFs fr.r.a f.'o ~ pa[..er F! rd dnW.. T b:~9 /'efvr.L Fa„-d Lp Annulus. g Y SS t/ o~ T~a.>,9 ! PAW .. Fr : ~ s, d ~ 33 s' 'SS~ SGf 'i<O CIoJ[ O/L 7tkC Fultnrr.i.f ~ ee /i • ESA d. C-sO (.'- 050 p, psNN @ ,~070o psrfr E• P3«' ~ so p.st~ 5 2 t a 8 i/r ss.meiKC, ppy .scf ~ ~/9~ -r, ~LUiER •KN!!W$ Of NEIL L~~~~Ytt lTclt F001.1 J RgLL pn c sCr ~L~ ~ \\ n tD~.m -w¢LL _ _ ~ baRp LTl L~ Q~ 1 In Onoal L L yIIL 70 1 Y~ ~~S 1K-103 I I '- I g§t a i _ ~ L •I~ ~ 1 ~ ' I s tl r__r_____i______.__r______i__ /\ NW i >' ~ I I ! i ~ I ~ I I KEA O.OOw `Il/oy1 ~~L~l-L I l I Qj -11 /~ i0 lEL 0.pW? 6-ICWro^~n/ln/ I ' t~l`- ~ I ~~~'~ VYLL ~/ (` '. 1 ~ I` ~ L ` ~' IL (o-.IO1.~ I 1 1 L~ se ` i i ~ uvo Isa ~ ~' S0 ,c ' ~ ~~l Is~el ~~ \w~ I 0Y~/L12V1 ~ I~r,~~D ^ ~l L[ ~ u r ~ 0 . rt 7 s rn• 4 , __ now FRN sni~SW prlJs.ccd wMC[ ~.~ 9 Pq1 SafN loo /;~_ ri-,Ira Fran Pfed,,.Wn NJR. MtD-oGp-SOn; 2oF5 Pbws~ FI~IsL ~~ P-IIXTY Iwau q a.~a wa a[cr [~~m[In ~R „ 1[_L .~, xo u-s m-s nu-r x-~ v~-m~ nms :-r rtyn Y-] - ~_~ MObJ A-3 w.ID-GW UW - - - srws ~n r~,w1~R Da.K K .se.® ,,.,..,n ns-sm .u,r.n~„irn.a.m , . s.a .mnwrtn ' r 'muu m en.v CC iAC WDiI% NU7E5 u¢us s s O m~+.smrum96nl.~~ws.ros.wc mmn n C 61 p g 9 ~ .nrmn~~ o®uu[ su R N , sx-swl-r. a-wi i K [ [rwr nu wvm sNS a mnw.o ~.s .sum. rm n.smc ~R[-YN-r. rt-/p 'S Cu0[ 4K Ku IoOU din a 46 [mmCrm ern " sa - l+-s aL uw .a ~. ,-svmcws say ocn sasv nn s1 sx m. ssvac K su r[ =m-r. a-fn a sn'..ussN sHS. pass .s ,ss„n I. [[ . w a ~c.sws w um .ass russus murc.o wu s me swml suns,.[ m rwrp+ n no.. - i u. n¢a ~..us - a.asw wrsae. n m. s n mwa.n wn oxs swonR n¢ +,.e.sas Iurn ser uRSra. ~~ro K ' u~ELLLL nppp~p~,~~ 2 C . t'hLL RO{!1 i KLK] . KO ALDLI J Oui9DE (K VOt] •~ • • • AOGCC Memorandum Date: May 31, 2007 To: Redoubt Unit SA Well File PTD 202-168 From: Jim Regg, Petroleum Engineer ~'~~%%~j ~ Subject: Sundry Application to Convert RU SA to Jet Pump Forest Oil Corporation ("Forest") requested approval by sundry application dated May 16, 2007 to convert Redoubt Unit SA ("RU SA") to jet pump ("JP") artificial lift. Contact for Forest is Mr. David Hall (Production Manager; 907-776-7108; 907-868-2133). RU SA experienced a failure of the electrical submersible pump ("ESP") on January 6, 2007. Additional information was requested by the Commission and provided by Forest by email as follows: 1) Procedure for converting well from ESP to JP; 2) Process and Instrumentation Diagram for the platform; 3) Well completion diagram; 4) JP power fluid metering locations (allocation and leak detection). The JP configuration for RU SA will be to pump power fluid (produced water) down the tubing and produce the well up the tubing-casing annulus ("inner annulus" or "IA"). An email response from Mr. Hall dated May 29, 2007 responded to questions I posed regarding measurement of power fluid, pressure rating for power fluid delivery line, integrity tests to be performed on tubing and IA, performance monitoring of the JP, and confusing production records (Commission records show the well on continuous production through April 2007; Forest indicates JP failure occurred 1//6/07}. I spoke with Mr. Hall this date and confirmed the need for pressure integrity tests on both the tubing and IA. He agreed to test as follows: Tubing - 5000 psi IA - 2000 psi A Commission Inspector will witness the tests on 6/1/2007. Attached are copies of emails exchanged between the Commission and Mr. David Hall. Attachments Re RUSA sundry notice to produce on jet pu~ • Subject: Re: RUSA sundry notice to produce on jet pump From: James Regg <jim regg@admin.state.ak.us> Date: Thu, 31 May 2007 12:38:37 -0800 Ta David Hall <DMHaII@forestoil.com> CC: Tom Maunder <tom_maunder~@adminatate.ak.us> David - Thank you for the responses to my questions and the Osprey platform well room schematic showing the metering locations. I am working on the sundry approval for the jet pump conversion. As we discussed this morning, the tubing must be tested to at least 5000 psi and the IA (tubing-casing annulus) must be tested to at least 2000 psi. Given that the PSHH for the IA is set at 2200 psi, perhaps a 2500 psi test would be more appropriate for the IA. AOGCC Inspector Bob Noble is scheduled to witness the pressure testing. Thank you for the quick responses to our questions and accomodating our witness of the pressure tests. Jim Regg AOGCC David Hall wrote, On 5/29/2007 6:10 PM: Jim, In response to your questions, More questions: 1) Where is power fluid metered before entering tubing (you reference well allocation would involve subtracting power fluid from return fluid)? Power fluid meter is located prior to the tubing of RUSA. Proposed plan is to subtract the power fluid. meter reading from the return fluid meter reading that is connected to the annulus thus proving calculated well production for RUSA. 2) What is the pressure rating for the line delivering power fluid? 8" produced water pipeline is rated for 5500 maximum operating pressure. Is this a dedicated line or the line used to supply produced water to RU-6 for pilot water flood? The 8" produced water pipeline will be used for produced power water fluid for RUSA as well as pilot water flood for RU6 anal RUD1. Is there an impact on the pilot water flood approved by Enhanced Recovery Order 2? Forest is not aware of any impact due to Enhanced Recovery Order 2. 3) What is driving the 2000 psi integrity test for tubing and IA? The proposed integrity test was intended to satisfy Tom Maunders original comment about the possibility of needing one. Essentially, the integrity was proven by means of being monitored on a daily basis while the well was on ESP production. Pre ESP failure showed the tubing at 1545 PSIG and the annulus at 280 PSIG. Proposed well head surface return pressure is 300 PSIG far under the proposed 2000 PSI integrity test. Forest does not foresee operating the jet pump return pressure higher than 500 PSIG due to the ineffectiveness of the jet pump. The highest conceivable not to exceed return pressure would be 2200 PSIG due to surface piping and equipment pressure limitations. Even your maximum allowable pressures for IA and tubing exceed the planned 2000 psi test. The test pressure probably needs to be rethought, or you will need to do separate tests for IA and tubing. Power fluid at the wellhead (down 1 of 4 5/31/2007 1:14 PM Re: RUSA sundry notice to produce on jet p#' • tubing) will be 4800 psi (not to exceed 5000 psi)? That pressure is nearly 100% of the pressure rating for the wellhead and the valves; 70 percent of the production casing MIYP. 4) Some confusing dates in your supporting information; ESP failure was 1!612006 or 1/612007? I checked our production database and it shows RU-SA on continuous production through end of April 2007 (no data available for May). Our records show January 6, 2007 RUSA ESP failure. Sorry for the error on the "Operations Procedure" showing the wrong failure date. Curious if you have thought through the performance monitoring for the well while on jet pump and what would trigger taking it out of service - I see a few of the things with pressure sets. Really what were trying to accomplish is to test out jet pump operation on the Redoubt unit. With RUSA currently down and outfitted for jet pump, it is a good candidate to prove out the entire system, pumps, separators, compressors, meters, and etc. If successful, then Forest will evaluate not using ESP's in the future due to high replacement cost. Jet pumps require significant horsepower but are quick to repair and maintain. Per my experience, usually when a well gets into the 98% water cut then it typically becomes uneconomical to produce depending on the price per barrel of oil. Also, I attached a sketch showing the overall system in general. Let me know if you have anymore questions, Thank you, David Hall David Hall Production Manager Office 907-776-7108 -868-2133 Ce11 907-3 1 7-8239 Fax 907-776-7119 -----Original Message----- From: lames Regg ~mailto:iim reaa@admin.state.ak.us] Sent: Friday, May 25, 2007 5:13 PM To: David Hall Subject: Re: RUSA sundry notice to produce on jet pump More questions: 1) Where is power fluid metered before entering tubing (you reference well allocation would involve subtracting power fluid from return fluid)? 2) What is the pressure rating for the line delivering power fluid? Is this a dedicated line or the line used to supply produced water to RU-6 for pilot water flood? Is there an impact on the pilot water flood approved by Enhanced Recovery Order 2? 3) What is driving the 2000 psi. integrity test for tubing and IA? Even your maximum allowable pressures for IA and tubing exceed the planned 2000 psi test. The test presure probably needs to be rethought, or you will need to do separate tests for IA and tubing. Power fluid at the wellhead (down tubing) will be 4800 psi (not to exceed 5000 psi)? That pressure is nearly 100% of the pressure rating for the wellhead and the valves; 70 percent of the production casing MIYP. 2 of4 5/31/2007 1:14 PM Re RUSA sundry notice to produce on jet pt~ • 4) Some confusing dates in your supporting information; ESP failure was 1/6/2006 or 116/2007? I checked our production database and it shows RU-SA on continuous production through end of April 2007 (no data available for May). Curious if you have throught through the performance monitoring for the well while on jet pump and what would trigger taking it out of service - I see a few of the things with pressure sets. I will be in the office Tuesday. Jim Regg AOGCC David Hall wrote: All, Let me know if you need anymore information, Thanks, David Hall David Hall Production Manager Office 907-776-7108 -868-2133 Ce11907-317-8239 Fax 907-776-7119 -----Original Message----- From: Thomas Maunder fmailtoaom maunder~admin.state.ak.us] Sent: Wednesday, May 23, 2007 2:33 PM To: David Hall Cc: Jim Regg; Dave Roby; Steve Davies Subject: Re: RUSA sundry notice to produce on jet pump David, We have received the sundry and are reviewing. In the future, please submit 2 complete hard copies of your request package. I have printed the attachments you did send and attached them this time. Do you have a procedure for the operations necessary to convert the well? It would be appreciated if you would provide one. Also, demonstrating the integrity of the casing x tubing annulus should be included in the planned operations. This demonstration will possibly be witnessed by an Inspector. When you reply, please copy all of us. Thanks, Tom Maunder, PE AOGCC David Hall wrote, On 5/16/2007 2:41 PM: 3 of 4 5/31/2007 1:14 PM Rg; RUSA sundry notice to produce on jet p~ Tom, Please let me know if you have any questions. Thanks, David Hall David Hall «AOGCC proposal letter.doc» «RU #5A Completion Diagram 02-05.x1s» «Wellhead P-I D. pdf» Production Manager Office 907-776-7108 -868-2133 Ce11907-317-8239 Fax 907-776-7119 «Sundry Notice.pdf» Jim Regg <jim regg cr,admin.state.ak.us> Petroleum Engineer AOGCC 4 of 4 SJ31J2007 1:14 PM T ,a~ .~. 1 o,aoo 6aL capacrry To Seperator i tdo;mal production To Seperator t3orm~I Prcducflan P-145 A P-14'1 P-145 B ssao rrRnf' Exisling Maflonal OlwGll k4arJlold Modified b" PC Proet~nq Ter- p~,~p ~~ ~,.e,~; o ,, M ,~ ~~ ~. ,, P;pQu„5 ES'~ ~roc~4~fto ~ ~ I _. 61 ~~~~~ ~` ~- ;-, Hia IN.f HZO WATER FLGOD M C.` ,91/oC~ ~,on ~~ e ~F CsL S ,~ i 1~ ~V'J __ wM~ WELL ROOPh3 ~y ~~~~~~ i..i1~ ~~~~ ~1 A E "~k^ COOK INLET A~.ASKA ~~ H GIN E E A f „~ PORESTOIL >=~~ JET PUMPPFO - ~~~ _ D325~ ~~~ ~~d~ ~ ~~+~~+~~~~ RY~~ • Subject: RE: RUSA sundry notice to produce on jet pump From: David Hall <DMHaII@forestoil.com> Date: Thu, 24 May 200'7 09:44:25 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, Jim Regg <jim_regg@admin.state.ak.us>, Dave Roby <dave_roby@admin.state.ak.us>, Steve Davies <Steve davies@adminstate.ak.us> CC: David Hall <DMHaII@forestoil.com> All, Let me know if you need anymore information, Thanks, David Nall David Hall Production Manager Office 907-776-7108 -868-2133 Ce11 907-3 1 7-8239 Fax 907-776-7119 R~~~ Y _, Al~sk~ tlil~ Gl~ ~~~1~~. ~~rr~tOn, QhGilraf~l~s -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, May 23, 2007 2:33 PM To: David Hatl Cc: Jim Regg; Dave Roby; Steve Davies Subject: Re: RUSA sundry notice to produce on jet pump David, We have received the sundry and are reviewing. In the. future, please submit 2 complete hard copies of your request package. I have printed the attachments you did send and attached them this time. Do you have a procedure for the operations necessary to convert the well? It would be appreciated if you would provide one. Also, demonstrating the integrity of the casing x tubing annulus should be included in the planned operations. This demonstration will possibly be witnessed by an Inspector. When you reply, please copy all of us. Thanks, Tom Maunder, PE AOGCC David Hall wrote, On 5/16/2007 2:41 PM: Tom, Please let me know if you have any questions. Thanks, David Hall David Hall «AOGCC proposal letter.doc» «RU #5A Completion Diagram 02-05.x1s» «Wellhead P-I D. pdf» Production Manager Office 907-776-7108 -868-2133 Cell 907-317-8239 Fax 907-776-7119 «Sundry Notice.pdf» Content-Description• Operations Procedure for RUSA on Jet Pump-2 .doc Operations Procedure for RUSA on Jet Pump-2 .doc Content-Type: application/msword Content-Encoding: base64 6~~~~~ V A7ssk~ (il ~a ~uc~s, Gt~r~rnissinn Qnch~orap~ • • Forest Oil Carparatian ~~~ 310 K Street, Suite 700 ~ Anchorage, Alaska 99501 (907) 868-2133 or 776-7108 Fax: (907) 258-8601 or 776-7119 May 24, 2007 RU5A Operation Procedure for Conversion to Jet Pump: RUSA Current Wet Status: • Shut in as a result of a ia~ed ESP, fit on .lanuary 6, 2006. • 3-1/2" 12.95#, P-110 tubing. • RIV top sleeve @ 13,150' MD. • RIV bottom sleeve @ 13,258 MD. • Weatherford Hyd 11 packer @ 13,204' MD. • ESP intake ~ 13,37T MD, ESP end @ 13,433' MD. • Bate Model FA packer Q 14,988' MD. • Starter ~ 15,350` ~, endbg ~ @ 16,525' MD • KB ~ 9tY MSt_ feet. Pre RU5A ESP faibre corid~iores (last day of towing , 1-6-06) • Flow rate: 650 - 700 BPD. • Water alt: 93%. • Fkrid suriaee terr4m:127 degmes. • Fbwir~ tut~g presscue:1545 PSTG. • Annulus pressure: 280 PSTG. RU5A Conversion Pmoedt,xe: 1. Test lubricata~ to 3,000 PStG. 2. RIH with 2.50" gauge rte, POOH 3. R1H with 2.562" sttiftkmg tool aEid shift RN Sleeve ~ 13,259` MD ttrerr st~tt upper R1V Sleeve @ 13,150' MD, POOH. 4. RIH witty 3° sta<tding valve aril set ~ 13,25tY MD in bwer RN Sleeve, POOH. 5. RIH witty RtV sleeve open/ebse confirmation tool and set down on starmcfr~ valve, POOH and cxirmfirm pins in confirmation toot did not suer. 6. RIH with 3° National O~ Well jet pump and set in 9 valve ~ 13,250' Ate, POOH, rig down. 7. Conduct Bundte test, (casing, tubir~ annulus irmteg<ittr verificxtiorm test) a. F~ tubumg amxf anrxmbs witty proct~ed water retieabg and as whtiee tom. b. Pressure up and ~ 2,000 PS1G. c. A~nr ermough tgne iii pressure b stab~ze, then mores and reo~ ~ and Annulus presstx>r tior ~ rrmuuites. d. Bleed otf tub'smg arxi arm pressue wtmen test ~ . 8. Fundionat d'tedccxmt ~ assoctiated alarms, shuhdowrr, ureters arxt surface safety valve. 9. Lirme up lbw ~ armd bring rnrefi orrYrme, sbaAy worts power up tit 500 PS1G ~ until 4800 PS1G wt~e vamif}rtimg returns. 10. pressere not ~ e>«:eed 2200 PStG arxt scxfaoe tubkmg r td 5000 PStG. David Hall Produt~ion Manager Office 907-Tf6-71E~ -fi6$-2133 Cell 9(t7-317-8239 Fax907-776-7119 Re: RUSA sundry notice to produce on jet p~ • Subject: Re: RUSA sundry notice to produceon jet pump From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date; Wed, 23 May 2007 14.:32:59 -0800 'I`o: Davis{ Mall ~~'D1~~1Ha11(ifo~-est~~il.co~1~== CC: _fim lZe~~~ ~ jimre~~~~~cr:admirl.state.ah.us~_ Dave R~~b}~ <da~e roh~'ci adlnin.staic.ak.u~-=,Steve Davies <stcve c3avit~iu:acimii~.state.ak.us> - ~ - David, We have received the sundry and are reviewing. In the future, please submit 2 complete hard copies of your request package. I have printed the attachments you did send and attached them this time. Do you have a procedure for the operations necessary to convert the well? It would be appreciated if you would provide one. Also, demonstrating the integrity of the casing x tubing annulus should be included in the planned operations. This demonstration will possibly be witnessed by an Inspector. When you reply, please copy all of us. Thanks, Tom Maunder, PE AOGCC David Hall wrote, On 5/16/2007 2:41 PM: Tom, Please let me know if you have any questions. Thanks, David Hall David Hall «AOGCC proposal letter.doc» «RU #5A Completion Diagram 02-05.x1s» «Wellhead P-ID.pdf» Production Manager Office 907-776-7108 -868-2133 Ce11907-317-8239 Fax 907-776-7119 «Sundry Notice.pdf» 1 of 1 5/23/2007 2:33 PM [Fwd: RUSA sundry notice to produce on je~p) • Subject: jFwd: RUSA sundry notice to produce on jet pump] From: Thomas Maunder <tom_maunder c~admin.st~te.ak.us> Date: Wed, 23 May 2007 13:24:39 -0800. To: Dave [Zob~ ~=~la~~c r~>hv,ccadmin.stat~.al:.u5='. ~1lVe Davies ~stc~~e davie~~u?admin.state.ak.us> CC: dim Re~~g`lu» rc~~~~u aclmm.state.ak.us> Here is what David sent. Tom -----Original Message----- *From:* Thomas Maunder [;r:.a9_~_to:tcm rnaur:::fie-rc~-a~.mi_rz.stat_e.a.l=.us *Sent:* Wednesday, May 16, 2007 3:32 PM *To:* David Hall *Subject:* Re: RU5A sundry notice to produce on jet pump Thanks David, while I can look at electronic copies we don't accept them for processing. Tom David Hall wrote, On 5/16/2007 3:19 PM: Yes, I will send out a hard copy tomorrow. Thanks, David David Hall Production Manager Office 907-776-7108 -868-2133 Cell 907-317-8239 Fax 907-776-7119 -----Original Message----- *From:* Thomas Maunder [zzailto:tcm me.ur~de.rp:a.dm.i.rt.sta.te.ak.us) *Sent:* Wednesday, May 16, 2007 2:59 PM *To:* David Hall *Subject:* Re: RU5A sundry notice to produce on jet pump David, I presume the sundry etc is being sent hard copy? Tom -------- Original Message -------- Subject: RUSA sundry notice to produce on jet pump Date: Wed, 16 May 2007 14:41:37 -0800 From: David Hall <DMi-Ial'~c~forestoil . com> To : Thomas Maunder <tom maurzder~.~adzn i:r .state . ak . us> CC: David Hall <DMHaII<zfcrestoi-.com> Tom, Please let me know if you have any questions. 1 of 2 5/23/2007 2:26 PM [Fwd: RUSA sundry notice to produce on jet~np] Thanks, David Hall David Hall «AOGCC proposal letter.doc » «RU #SA Completion Diagram 02-05.x1s » «Wellhead P-ID.pdf» Production Manager Office 907-776-7108 -868-2133 Cell 907-317-8239 Fax 907-776-7119 « Sundry Notice.pdf» 'Content-Type: application/msword AOGCC proposal letter.doc Content-Encoding: base64 Content-Type: application/vnd.ms-excel RU #5A Completion Diagram 02-OS.xls Content-Encoding: base64 Content-Type: application/octet-stream 'Wellhead P-ID.pdf Content-Encoding: base64 Content-Type: application/octet-stream Sundry Notice.pdf Content-Encoding: base64 2 of 2 5123/2007 2:26 PM ~ ~ ~~~c:~d ~'~~~Iidps 2004-0802_CPA_jet_pump_policy.txt subject: Re: Emailing: MITP KRU 3S-24A 7-16-04.x1s From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 02 Aug 2004 16:11:56 -0800 TO: NSK Problem well supv <n1617@conocophillips.com> CC: Jim Regg <jim_regg@admin.state.ak.us> MJ, Please keep sending in the MIT paperwork. I think it is a diagnostic/verification that should be sent in with the 404. Tom NSK Problem well supv wrote: >Hi Tom, >our internal Jet Pump Guidelines are still in draft form (Jerry will finish them when I come back to Pws full time next month), however, there is/ or will be a clause for periodic (every 2 years) MIT's. I believe this is the first one we have submitted to the AOGCC. Jerry gave me the impression the data was required with the 10-404 (GL to JP conversion). However, if this is not the case and you would prefer to not get the data let me know. >Below is a cut and paste copy of the draft JP operating guidelines. >MJ Loveland >COnocoPhillips >Problem well supervisor >659-7224 >JET PUMP-LIFTED PRODUCERS >In order to continue producing a jet pump-lifted well without a waiver, the following tubing / casing integrity criteria must be met. Diagnostics to identify the type and severity of the problem are required if a well does not meet these criteria. >1. operational requirements: >a. A jet pump equipped well must be operated in jet pump service; flowing the well without power fluid in operation is not allowed (T x IA communication will be present); >b. To flow a jet pump equipped well without jet pump assist requires removal of the pump and isolation of the tubing and casing; >c. A rapid reduction of power fluid supply pressure or significant increase in flow rate must be investigated to ensure there are no losses downhole that may be the result from a hole in the tubing, casing or packer. >2. The maximum operating pressure limits are: >a. 2500 psi on the production casing (IA) annulus during jet pump operation; >b. 2000 psi on the production casing (IA) annulus with the well shut-in; and >c. 1000 psi on the surface casing (oA) annulus. >3. The production casing annulus (IA) must not exhibit the following characteristics: >a. A rapid reduction in the power fluid injection pressure that may indicate a downhole leak; >b. Evidence of communication with any formation other than the producing formation, including loss of power supply fluid volume downhole; >c. Evidence of communication with the atmosphere. >4. The surface casing annulus (oA) must not exhibit the following characteristics: Page 1 • • 2004-0802_CPA_jet_pump_policy.txt >a. A production casing leak that requires the surfacing casing annulus (oA) pressure to be bled more than twice per week to maintain the pressure below the established operating pressure limit; >b. A production casing leak that is large enough to allow the surface casing annulus (oA) pressure to rapidly track the production casing annulus (IA) pressure even if the annulus maximum limit is not exceeded. >c. Evidence of surface casing leaks to the formation, other than the casing shoe; >d. Evidence of communication to the atmosphere. >5. Mechanical Integrity: >a. Each producing well equipped with a jet pump using power fluid will have a mechanical integrity test (MIT) every two years; >b. The MIT pressure will be to at least 1.2 times the expected maximum allowable operating pressure (MAOP) of the annulus (in most cases the header pressure); >c. A failing MIT will require removal from jet pump service., diagnostics, repair and/or waiver of the failure mechanism before returning to jet pump service; >d. The Problem well supervisor (Pws) will schedule testing, maintain records, and submit reports to the AoGCC as required. >-----original Message----- >From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] >Sent: Monday, August 02, 2004 1:53 PM >To: NSK Problem well Supv >Cc: Jim Regg >Subject: Re: Emailing: MITP KRU 3S-24A 7-16-04.x1s >MJ, >Thanks. I don't think I had seen one of these MITS before. I presume >this is a test that is conducted whenever such a switch is done. >A while back Jerry and I had discussed "ongoing" tests similar to the >injection well MITS. Is there an internal CPAI procedure/policy >for doing subsequent MTIS on jet pump wells?? >Tom Maunder, PE >AOGCC >NSK Problem well Supv wrote: »TOm , »Attached is Producer MIT for 3S-24A (PTD 204-061), pre conversion from GL to Jet Pump. »A 10-404 is following today in the mail. » Please let me know if you »MJ Loveland »ConocoPhillips » Problem well Supervisor » 659-7224 have any questions »«MITP KRU 3S-24A 7-16-04.x1s» Page 2 • • ConocoPhillips Alaska, Inc. Kuparuk River Unit Tarn Jet Pump Installation Summary As per request by the AOGCC, the following is a summary of the surface powered jet-pump artificial lift control system currently in place in the Tarn field at Kuparuk. Future installations in the Kuparuk area may vary somewhat in design, but will retain the monitoring features described below. Of note is the existence of sub-surface powered jet pumps, which are powered by sub- surface production (typically C sand gas) and are not included in the following discussion. The jet pump artificial lift system includes a power fluid that is injected into the production casing by tubing annulus (IA), which enters the tubing via a sliding sleeve or other similar tubing port. The jet pump is a wireline retrievable unit that locks into a profile in the sliding sleeve assembly. The jet pump contains an orifice that directs the flow up the tubing, creating alow- pressure zone below the pump. The low-pressure zone induces the well to produce at a lower bottom-hole pressure than otherwise would be available in a non-lifted system. Each jet pumped well has an individual orifice meter for measuring the power fluid rate (water) injected into the IA. The meters have a scheduled calibration program. Each well also has a pressure sensor located on the casing valve, which provides real-time surface casing injection pressure data. The fluid injection rate and pressure is continuously monitored real-time on every surface powered water jet pump in the field. Each well is equipped with high and low-pressure alarms to signal when any pre-set alarm point is reached. The monitoring software program has the capability to retain data for at least asix-month period. Removing the jet pumps from the well for servicing is currently an ad-hoc process. The reliability of jet pumps has shown that regularly scheduled maintenance is not necessary. There are no moving parts in the pump and well testing provides feedback as to the functionality of the pump and the wells' performance on the pumping system. The jet pump is only pulled when the nozzle orifice should be resized due to well production rate changes, or if wear is suspected on the nozzle orifice resulting in less than optimal performance. The drill site is monitored 24 hours a day with telemetry and have on-site operators for operations and maintenance duties. Below is a basic piping diagram of the Power Fluid (water) line as it comes off of the main water supply header to each individual well. Schematic of TARN Jet Pump Power Fluid Piping to Wellhead ~ Pressure Transducer Water Line From Header T ~~ ~~~~ Casing Valve Orifice Meter Production Casing NSK Problem Well Supervisor ~ March 3, 2003 a tour-Week is The data s ew d ~s t the application d play. via ump data trend is being v ical jet p when the display Tho frame below sh°ws lvy Pdated real time pF sc ^ March 3, 2003 tiSK Problam W ell SupeC~ i,or 2 ^ • • The panel shown below is a typical well test for the same well that is shown in the trend panel above. "the tests are used to judge if the pumping system is performing normally and if reservoir performance is stable over time. NSK Problem Well Supervisor 3 March 3. 2003 Osprey RUSA Jet pump conv~ion amendment ARaunder, Thomas E (DOA) From: David Half [DMHaff@forestoif.com} Sent: Wednesday, November 28, 2447 4:33 PM To: Maunder, Thomas E (DOA} Cc: Regg, James B (DOA} Suf~ject: Osprey RUSA Jet pump conversion amendment Attachments: 11-27-47 AOGCC tetter.pdf Tam, Please let me know if you have any questions. Thank you, David Hatl David Hall Production Manager Ofllce 907-776-71(38 -868-2133 Ce11907-317-8239 Fax 907-776-7119 «11-27-07 AOGCC fetter.pdf» Page 1 of 1 t2i12i2oo~ • - Forest opt Corporation ~~ 310 K Street, Suite 700 ,,`~ = , ~Inchorage, Alaska 99501 " (907) 868-2133 or 776-71118 Fax: (907) 258-8601 or 776-7119 November 27, 2007 Mr. Tom Maunder, Alaska Oii and Gas Conservation Commission 333 W. 7th Avenue, Suite 104 Anchorage, Alaska 99501-3539 RU #5A Jet Dump Completion: Dear Mr. Maunder, On June 3, 2007 an MIT was attempted on RU5A though not successful many diagnostics were made to determine the source of communication. As a result of a spinner survey, the inner annulus showed direct communication with the tubing through the top sliding sleeve but grossly leaking through the packer. In light of original Osprey ESP completions {RU7 which is cun°ently on(ir~}, mosf did not include packers, l=crest Oil proposes running RU5A je# pump without retaining a MIT based on the follawing condusiorrs. a. The well can be safely placed back on production (with the lack of art available rig, ill! otherwise have to remain shut in} b. The diagnostics have proven that the tubing has pressure integrity above the existing packer and proposed jet pump c, The well wilt not flow unassisted, thus the leak at the packer doesn't compromise well integrity d. End result is an artificially lifted, packer-less completion which is common in the oi{ patch.. The communication from the tubing to the inner annulus is not believed to impact the operation of the ~t pump because the jet pump will seat in the top sliding sleeve above the packer, high pressure power fluid will be pumped down the tubing and wi11 then the jet pump taking low pressure returns {production} back. up the inner annulus. Tubing integrity was established by setting a plug in top sliding sleeve and pressuring up to 5000 PSI. If you have any questions, please contact me at 868 2133. Sincerely, David Hall ~ '~~ Production Manager ~~ h Cd r~~`c~S~ C~-) ~~~~ Sex Forest Oil Corporation P ~ ~ ~~ ~ `~ `~~~~ ~ ~ ~ ~1:,.-~-Q ~ k~C t ~~`z S ~~C t..~~ P~~svC~E. Attachments: S ~~~ 1. Wellbore Somatic - RU #5A "~ ~ Lt~yt~~-~C~~ C"~ [~T'~ ~}O, \ r 2. Spinner survey /~`~ I~~ ~~1 Database: ForestRU-Sa2.sdb Date Creation: 6/26/2007 9:59:35 AM Project: Forest Oil RU-5a Depth Unit: ft Well: RU-5a Vertical Scale: 1:240 Log Pass: Down Pass 4 SI a Presentation: MPLT Default Presentation -100 Casing 5500 Downhole Pressure 7000 Depth (ft) 186 ~3Gator (mv-200 tap S~ Downhole Lrylt~ L~aK ~ f~ Su~~n9 .L e c Vt_ , Grass L.eati ~n Pa~Ke'e 00 Casing Depth (ft) 186 Downhole 194 50 194 50 5500 Downhole Pressure (psi) 7000 • Redoubt Unit #5A Completion -February, 2005 J TOL @ 11290 MD RIV Sleeve 13,150' MD Weatherford Hyd 11 Pkr @ 13,204' MD RIV Sleeve 13,259' MD 30" 150 # 13 3/8" 68 # • A-36 200 TVD Welded 200 MD L-80 2940 ND BTC 3190 MD Tubing 3-1/2", 12.95#, P-110, TSHD 9 5/8" L-80 10065 TVD 47 # BTC 1150D MD :enirilift ESP Assembly stake @ 13,377' MD nd Q 13,433' MD er Model FA Packer 4988 MD TOL @ 15118 MD Perforations: 15,350' - 15,385' 15,410' - 15,460' 15,560' - 15,600' 15,615' - 15,635' 15,765' - 15,915' 15,950' - 15,960' 16,020' - 16,030' 16,170' - 16,525' 3 3/8" 6 SPF 7 5/8" L-80 11980 TVD 29.7 # Hydril 521 15323 MD ;rforations ~ Dritl @ 16575 MD 5 12' L-80 12830 TVD 17 # Hydril 521 17000 MD ._tt1 ~~T ~~ May 24, 2007 Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 868-2133 or 776-7108 Fax: (907) 258-8601 or 776-7119 RU5A Operation Procedure for Conversion to Jet Pump: RU5A Current Well Status: '` • Shut in as a result of a failed ESP, failed on J uary 6, 2~ • 3-1/2" 12.95#, P-110 tubing. ~ ~ ct~ • RIV top sleeve @ 13,150' MD. • RIV bottom sleeve @ 13,259' MD. rf • Weatherford Hyd 11 packer @ 13,204' MD. • ESP intake @ 13,377' MD, ESP end @ 13,433' MD. ~ ~ • Baker Model FA packer @ 14,988' MD. ~~ c~E` • Starting perforations @ 15,350' MD, ending perforations @ 16,525' MD ~S ~~w ~' ~s~ ~~ • KB @ 90' MSL feet. ~ CC's`' ,~ ~ ..,---~7 ~ec~ ~ ra,`~1 Pre RU5A ESP failure conditions (last day of flowing conditions, 1-6-06) ~~ • Flow rate: 650 - 700 BPD. ~_ ~ - ~~~'"^-r1 • Water cut: 93%. ~~,~ Pw u~ 12€?~u~s' • Fluid surface temp: 127 degrees. b,;z„k,- • Flowing tubing pressure: 1545 PSIG. ~ Gaf • Annulus pressure: 280 PSTG. ~~'~ Zct77 133 3Z7 {~~`~~ RU5A Conversion Procedure: ~~~ ~"C 1. Test lubricator to 3,000 PSIG. 2. RIH with 2.50" gauge ring, POOH 3. RIH with 2.562" shifting tool and shift RIV Sleeve @ 13,259' MD then shift upper RIV Sleeve @ 13,150' MD, POOH. 4. RIH with 3" standing valve and set @ 13,250' MD in lower RIV Sleeve, POOH. 5. RIH with RIV sleeve open/close confirmation tool and set down on standing valve, POOH and confirm pins in confirmation tool did not sheer. 6. RIH with 3" National Oil Well jet pump and set in standing valve @ 13,250' MD, POOH, rig down. 7. Conduct Bundle test, (casing, tubing annulus integrity verification test) a. Fill tubing and annulus with produced water relieving and air while filling. ~~ ~ b. Pressure up tubing and annulus to 2,000 PSIG. c. Allow enough time for pressure to stabilize, then monitor and record tubing and Annulus pressure for 30 minutes. d. Bleed off tubing and annulus pressure when test is completed. (,t1 ~~SS ~ 8. Functions{ checkout all associated a{arms, shutdown, meters and surface safety valve. 9. Line up flow connections and bring well online, slowly work power fluid up in 500 PSIG increments until reaching 4800 PSIG while verifying returns. 10. Annulus pressure not to exceed 2200 PSIG and surface tubing pressure not to exceed 5000 PSIG. ~-- II ••'' -- tti David Hall ~r C C%i`.~T~7` (~~ Z'(~- Production Manager Office 907-776-7108 -868-2133 Ce11907-317-8239 ~~ Fax 907-776-7119 'T _ ~ Z~ Redoubt Unit #5A Completion -February, 2005 Free ~~~ ~ LESU° ''~ L4~`~ - - ~~ ~e ~1~~ P3~AAif+ r 30.. 150 # .. i eft .~ 3c~o~s, ~ ~ ~~ ~`~~ zae v ~ P~ - asr~ ~o ~e~ v~ -IeS~ -E-b~ ~ ~n;,~ ~ TOL ~ 11290 MD RIV Sleeve 13,150' MD Weatherford Hyd 11 Pkr 13,204' MD RIV Sleeve 13,259' MD TOL@15118 MD Perforations: 15,350' - 15,385' 15,410' - 15,460' 15,560' - 15,600' 15,615' - 15,635' 15,765' - 15,915' 15,950' - 15,960' 16,020' - 16,030' 16,170' - 16, 525' 3 318" 6 SPF 13 3l8" 68 # ~Ow~- ~~ ~ ~j'v~~Le~.Q wry-) 44uvo.~~i A-36 200 ND Welded 200 MD L-80 2940 ND BTC 3190 MD ~Ozl7 p,; 1/t~y,° Tubing 3-1/2". 12.95#, P-110, TSHD ~ at~a~i% ~ S !~~(~ = Z~,63D~s~ ~~ z3_~ `'~ 'mil] ,~ co~(gtsP - ZI,~PS: 9 5/8" 47 # L-80 10065 ND BTC 11500 MD Grv7a~,: an.ufP /~-~,oa~,~ I~ -Z dF bar s~- CentriliR ESP Assembly Intake @ 13,377' MD End @ 13,433' MD Baker Model FA Packer 14988 MD 7 5/8" L-80 11980 N D 29.7 # Hydril 521 15323 MD Perforations EZ Drill @ 16575 MD 5 1 /2" L-80 12630 N D 17 # Hydril 521 17000 MD [Fwd: RUSA sundry notice to produce on jet~p] • Subject: [Fwd: RUSA sundrynotice to produce onjetpump] From: Thomas Maunder <tom_ maunder(cr~adir~in.state.ak.us> Date: Wed, 23 May 2007 13:?~: ~9 -O~0O To: Dave Roby~~:lave_r~ohyiaa~rliir~.stale.ak.u~=~. Stwe Davics <steti~cdavic~!uadi»i~l.statc.ak.us~=- CC: _jim Re~`~ -,jim re`~'~;("~laclmin.statc.ak.us> Here is what David sent. Tom -----Original Message----- *From:* Thomas Maunder [r:.a.i.=.to:tom rrzau.nde-~~~-acrnin.state.ak.u:>] *Sent:* Wednesday, May 16, 2007 3:32 PM *To:* David Hall *Subject:* Re: RU5A sundry notice to produce on jet pump Thanks David, while I can look at electronic copies we don't accept them for processing. Tom David Hall wrote, On 5/16/2007 3:19 PM: Yes, I will send out a hard copy tomorrow. Thanks, David David Hall Production Manager Office 907-776-7108 -868-2133 Cell 907-317-8239 Fax 907-776-7119 -----Original Message----- *From: * Thomas Maunder [rr:ai.lto: tcm zna.undera:a.dm.irl .state . ak . u.s] *Sent:* Wednesday, May 16, 2007 2:59 PM *To:* David Hall *Subject:* Re: RU5A sundry notice to produce on jet pump David, I presume the sundry etc is being sent hard copy? Tom -------- Original Message -------- Subject: RUSA sundry notice to produce on jet pump Date: Wed, 16 May 2007 14:41:37 -0800 From: David Hall <D~Hallc?forestoil.com> To: Thomas Maunder<tor:.~ Taurider.~~%adz~.~.state.a.k.u.s> CC: David Hall <DMHal1;^forestoil.com> Tom, Please let me know if you have any questions. 1 of 2 5/24/2007 12:04 PM [Fwd: RUSA sundry notice to produce on jetp] Thanks, David Hall David Hall «AOGCC proposal letter.doc » « RU #5A Completion Diagram 02-05.x1s» «Wellhead P-ID.pdf» Production Manager Office 907-776-7108 -868-2133 Cell 907-317-8239 Fax 907-776-7119 « Sundry Notice.pdf» Content-Type: application/msword AOGCC proposal letter.doc!' Content-Encoding: base64 Content-Type: applicationlvnd.ms-excel RU #SA Completion Diagram 02-OS.xls' Content-Encoding: base64 Content-Type: application octet-stream ''Wellhead P-ID.pdf Content-Encoding: base64 Content-Type: application/octet-stream Sundry Notice.pdf Content-Encoding: base64 2 of 2 5/24/2007 12:04 PM Mr. Hall: Sorry I can't accept this 10-403. We have updated 10-403's on our website (www.agocc.alaska.gov), under "forrns" is where you can download our latest 10-403. We do ask that you send in the original with signature and a duplicate of the application. , /~ 3 p~ Thank you ~,~~ ~~ - ~ Chasity Smith /h . V~ f" _ ~~,~" C k~~ ~~~~ • ° ~ Forest Oil~~~orporation 310 K Street, Suite 700 .~. Anchorage, Alaska 99501 ° (907) 868-2133 or 776-7108 Fax: (907) 258-8601 or 776-7119 May 16, 2007 Mr. Tom Maunder, Alaska Oil and Gas Conservation Commission 333 W. 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re : RU #5A Jet pump Completion: Dear Mr. Maunder, ~~~~~® ~lAY 2 Y 2007 ~iaska Oil & Gas Cons. Commission Anchorage Forest Oil Corp is proposing to produce Redoubt Unit #5A (RU #5A) by means of a jet pump. The Electric Submersible Pump (ESP) in the RU #5A well failed on January 6, 2007. The ability to produce from either ESP or jet pump was originally planned and designed for as is reflected on the completion diagram (see attachment). The RU #5A completion includes a packer and two sliding sleeves which will accommodate the downhole jet pump. Forest planes to utilize produced water as the power fluid to drive the jet pump. Forest proposes a "standard" jet pump configuration, whereby the power fluid will go down the tubing and production returns up the annulus. The projected power fluid pressure at the wellhead is near 4,800 PSIG, with a power fluid flow rate of approximate 3,800 BPD. Projected annulus return pressure at the wellhead is 200-500 PSIG with an anticipated production flow rate of 600 -1200 BPD (in excess of the power fluid). The proposed well allocation would involve subtracting power water fluid from return fluid. Forest proposes to leave the SSV on the tubing side (power fluid side). The proposed operation of the SSV would be set to close upon the following conditions: • PSHH @ 2,200 PSIG on the annulus. • PSLL @ 50 PSIG on the annulus. • ESD, OSD, GSD. Wellhead MAOP of 5,000 PSIG will be protected from pressure relief valves on the produced water injection pumps onshore. If you have any questions, please contact me at 868-2133. Sincerely, 6"r ~~~ David Hall ~''~~ Production Manager Forest Oil Corporation Attachments: Sundry notice Wellhead completion P&ID Wellbore Schematic - RU #5A n u F m E ii • N~r~.s . /. Jr rPl. M~ cawvs•S ~ [l.l r'+u/l' ~V s-[~/ °~. QRAd6•c~l ~f~r v5ed AJ ~ower f7v/cl 3. ~Cf /Jv~e .ffNndpr I CunF+;so~.ai~v ~ PoW.c,r FG•rd dvl.•~ Tab;ng l'c+v~a. FI[.rd L•P AnKvlvs. Y SS/ 0~ T~b/k9i Pnw~~ Fl6.1-C S~dr. s• SSIr Sef to Clo3t O/t ?rkc Fc,rltal.-.ky ~ A ~ Eso !3. ~ s0 ~, pso o• ~s~~~ ~a~aPsl~ E, ~scc. ~ So ~pslG • pAN s~~+ ~. yqc~ / IlQLESr2 ~, IS51~_~TC--ITI i urort I) I (m onmisl L L L I I I ~^~ I 2BL [ I l i I'> ( '~ r--r-----~------i°-r -Ii----I-- I I L I I I I I \~ I I I I I I L I 1 1 I I I 1 I [ I l L I L I I I I I ~ [ ~I I ~ ~ a-wpov(a \ L-L-L [--[ L ~~1P~/ I I I IT o-spoo Ps N X07- °r [ i i i I I ~ °° ~-- i i i ( L I( L i I L I L i I 1 I hl I W I D-SOOp PAL I I I sFi a I sn o PI ~~ ~ vs»13ssgr~c c~~ 5D~ 8 ssv )sc tso CC 1511 W 1~ ~ Ic 1 1 I Imo- ~ IrwQp' ~ q ~ nr 7• r o7 a7 nort ~ Y Q Q -D4 5 FI9If 5[I ~ SU) ~eF~~ ~ rlr plat. s[~ ~ IDo cLY v3 ~J >-- 7p••I,• Lea-r-om p /-xr l l rn• ~1 1 _ - / ~\ lxl ' Vr ss.iuewD, ~T OUTER ANNULUS OF WELL wEU RoDLI 3 wau 15 -rru Q Ic 5 r'aL BALI (NTH-103 63 VALrS ,J ILL 3- d: r r 1YcLl ~~ IsTli pl Q I, ~E~R0017 2 Fiu~d. Ilrort n• na1P n FA SOpDI as uugpg P-%XKX plm[ [) sutx QI uc[x 17Q Ipl 1xC fro. NoE s) 1'R-JpOD-rx CC-POI rx-7aN-rA a-P07 /vc-7DO7-rx u-Pa] +T[-]76l-rA Co-PDi +'FC-7ow-rx a-Pm +TC-~05-FA CC-Fop 55 nRNG ~ nelgwaa ru Inp+[4ns aloNl xm xsstvm rD IuK Pkp raaetD lauom rl to INUSq AS couple: ttt-aall-m . usl pelnwuu IOWWI usq: u . SPxla u1511NUEltl InNptpAS: 11 colNAxo NI sn. ] lam 1. 55Y 4N10p1:1 DT lpC7L n1gxWC [QlinpL z SSY Iu5 rvsmt PU16. ] nl[ swrowD ulsnw+all rnx~omm Paaawn[ wu R uaD fq Iwm7caw stns Ett[PI text n¢ ctrl INNpIn rill ~ nnluocp u A s,rlU. tq [wIRL roc-Nar-S•m /. St! 15a fA0 uxnll] fq V5p IMa4A6. I{~S IWC r rq M-S 4 +'-PC-`Ap1-Fl. WB r rq Dp-7 ni 1'-PC-7pp7-t4 a Pum ua's r,r7to[ nu In7 npou uo. t tilt cwounml 110. tiu-r Ivrtu now Iro; r-cnwcfq no.l r. aea vuta cm so eso gxaula Plrtsswrc [ 1/]', 7165[ 5105, p p65' rt lp0llD 9. Sa a IAG ue1Pa Iq a ININtAi la nca run D[lpn ululuo rlm ss vs6 tAxaJIG wamun[ al NrylA it IIDYx - 1 our [rra Vxtlt - g6aUW PM-i~nre a n[ll 115 D[a+Nll NIO p1Ei IronUK nE NnNLa15 IXEfn Gf xs~r ]Ip N Sln[C7, SNIIC 70p iJ4/IpnADr, AlA4tA OSPREY OFFSHORE PLA' Yell flBOTI TAGGING ~AiW% • • LEGEND IC o nQll RODU t 2C = wElt ROC51 2 3C ~ 14TH RDpA 3 4C . l'/cll R00ld 4 YrORJ = K'0 RCDI7 3 DDT90E DF r,R3 Redoubt Unif~5A Completion -February, 2005 ~ 4 J ~''~ ~• I `50 # ~,J 13 3/8" 68 # TOL @ 11290 MD RIV Sleeve 13,150' MD Weatherford Hyd 11 Pkr @ 13,204' MD RIV Sleeve 13,259' MD TOL @ 15118 MD Perforations: 15,350' - 15,385' 15,410' - 15,460' 15,560' - 15,600' 15,615' - 15,635' 15,765' - 15,915' 15,950' - 15,960' 16,020' - 16,030' 16,170' - 16,525' 3/8" 6 SPF • A-36 200 ND Welded 200 MD L-80 2940 ND BTC 3190 MD Tubing 3-1/2", 12.95#, P-110, TSHD 9 5/8" 47 # ;entrilift ESP Assembly ntake @ 13,377' MD fid @ 13,433' MD Aker Model FA Packer 14988 MD L-80 10065 TVD BTC 11500 MD 7 5l8" L-80 11980 TVD 29.7 # Hydril 521 15323 MD Perforations EZ Drill @ 16575 MD 5 1/2" L-80 12830 TVD 17 # Hydril 521 17000 MD J • • Forest Oil Corporation S 310 K Street, Suite 700 Anchorage, Alaska 99501 . : ,,. (907) 868-2133 or 776-7108 Fax: (907) 258-8601 or 776-7119 April 18, 2007 Mr. Tom Maunder, Alaska Oil and Gas Conservation Commission 333 W. 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re : RU #5A Jet pump Completion: Dear Mr. Maunder, Forest Oil Corp is proposing to produce Redoubt Unit #5A (RU #5A) by means of a jet pump. The Electric Submersible Pump (ESP) in the RU #5A well failed on January 6, 2007. The ability to produce from either ESP orjet pump was originally planned and designed for as is reflected on the completion diagram (see attachment). The RU #5A completion includes a packer and two sliding sleeves which will accommodate the downhole jet pump. Forest planes to utilize produced water as the power fluid to drive the jet pump. Forest proposes a "standard" jet pump configuration, whereby the power fluid will go down the tubing and production returns up the annulus. The projected power fluid pressure at the wellhead is near 4,800 PSIG, with a power fluid flow rate of approximate 3,800 BPD. Projected annulus return pressure at the wellhead is 200-500 PSIG with an anticipated production flow rate of 600 - 1200 BPD (in excess of the power fluid). The proposed well allocation would involve subtracting power water fluid from return fluid. _ ~ ~~; ~ ~ Forest proposes to leave the SSV on the tubing side (power fluid side). The proposed operation of the SSV would be set to close upon the following conditions: • PSHH @ 2,200 PSIG on the annulus. • PSLL @ 50 PSIG on the annulus. • ESD, OSD, GSD. Wellhead MAOP of 5,000 PSIG will be protected from pressure relief valves on the produced water injection pumps onshore. If you have any questions, please contact me at 868-2133. Sincerely, David Hall Production Manager Forest Oil Corporation Attachments: Sundry notice Wellhead completion P&ID Wellbore Schematic - RU #5A f • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLI~ATI~N TOR SUNDRY APPRQVALS 1. Type of Request: Abandons Suspend: Operation shutdown: Re-enter suspended well: _ Alter casing: Repair welC Plugging: Time extension: Stimulala: _ Change approved program: Pull Tubing: Variance: Periarata: Other: Produce on Jet pump 2. Name of Operator 5. Typa of well: 6. Dab.im elevation f DF or KB) Forest Oil Corporation. Development: X 90' MSL feet 3. Address Exploratory: 7. Unit cr Properly Warne 310 K Street, Suite 7DD SlrBiigraphic: Redoubt Unit Anchorage, Alaska 99501 Service: 4. Location of well al ,urface 8. Well number ~ 1909' F5L;.318' FEL, SEC. 14, TD7N, R34W, 5(yl ~ Redcubt Unit #5A ~ At tap of productive interval S. Permit nismber ~ 105$' PSL, 288' i'EltlL, SeC- 19,~'pfl7N, R13W, SM 202-158 At effective dep'.h 10. API number „ 4D' FSL, 1361' F1NL, Sec. 19, TD7N, R13W, SM 50-733-2D5'I3-D'I At btal cisnti 11. Field/Paul Redoubt Shoat O:I Field ~, 40' FSL, 1361' FWL, Sec. 19, Tfl7N, R33W, SM ~ Redou;,t Shoal i7_. Pre entU~ell con~fition um4napy %~ T3ta~ ~'u~th: measured 17,000 ft ~ Plugs (measured] ~LC & P~ erat 14,988' true vertical 12,830 ft a Effectivadepii;: measurer 1x,575 ft Jung {measurad) N!A trio vertical 12,639'it Casing Length Stye Cemented Pleasured depth True vertical depth Structural 20D' 30" Driven 20D' ZOO' Conductor Suraca 3,190' 13.~.,'S" Surface 3,190' 2,9Q4' Intermediate 11,500' 9 518" 1,286 Cu ft 11,5D0' iQ065' Drilling Liner 4,033' ? 7-5(8" 252 cu ft .'15,323' 11,90' Production Liner 1,882' `5-1 (2" 311 eu Ft 17,000' 12,83D' Perfor_tion depth: ^Aeasured Depth: 1535D'-15385', 15410`-15A60', 15560'-15600', 15615`-15635', 15765'-15915', 15950'-15960', 16020'-1603D', '16170'-16525', 3-318" TCP, 6 SPF ND: 11995'-12013', 1Z027'-12063', 12D99'-12125', 12134'-12145', 12220'-12308', 12327'-12333', 12366'-12371', 12443'-12616', 12657- 12685', '3-318" TCP, fi SPF Tubing {size, grade, and measured depth) 3 112" #ubtng set at 14,946' NiD (d8 jts P-110, 424 jts L-$Dj ~' i''ackers and SSSV type and measured depth) Baker F1xgaCker W/ LLC-3 valve set ~ 14,988' MD / 13. Att3chements Description Summary of prepr~sal: X Deialled operations program: X SOP sketch: On File 14. E;tima,ed dais for commancing operation 1b. Status of wall classification as: 5125!2007 16. If proposal ~.vall veroal[y 2pproved: Ofl: X Gas: Suspended: Name of approver Date approved Sa!vice: 17. l hereby certify chat the forogoina ig truE and correct to the best of my l:novAedge_ '= ~~ ~ ~ Titla: Production Engineer, Forest Oii Date: -, ~ ~ is f Signad: ~~ .'=~-- t -~ ~, .,-~- { --.__- FOR COMN'dSSION USE ONLY Cfmditions cf approval: Notif}+ Commission so 2prasentative may:~r~itness Approval No. Flug integrity BOP Test__ _ __ LvC2tiorl clearance--- P9eohanical integrity Test Subsgq~~ienfform required 10-__ Approved. by order of the Commissioner Commissioner Date Form 1Q-403 Rev OG11~lES SUgNiIT IN TRIPLiC.ATE MEJ\;10RANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission fO: -, JIm R~(W i¿,(." 1/) . <::",,,, ! \[/CI (/ 'Vi P.I. Supervisor C ¿ r..-; '7 0.\ TE: Tuesday June 12,2007 SCBJECT: \kchanlcal Integflly Iesl' FOREST OiL CORP 5-\ r'\ --l (pi{, a, 0 d-' FROM: RCN Petroleum Inspector REDOUBT UNIT 5A Src: [nspector Reviewed By: P.I. Supr\~ Comm NON-CONFIDENTIAL Well Name: REDOUBT 1JNIT SA Insp Num: mitRCN0706090717I 7 ReI Insp Num: API Well Number: 50-733-20513-01-00 Permit Number: 202-168-0 Inspector Name: RCN Inspection Date: 6!li2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 l'1in. ~"---'-I-----::-----I-------------T-- , -----y---~!~----¡--~-:-~--------;---~-______¡_-------~---~----¡-----" Well ¡ )A ¡Type Inj.! : TVD' , fA I 2000 ' 2040 I 1800 I 1650! ! ---'r--~-----¡---------~ ------¡-------~------------'+_ ------- p.T.Dr 2021680 ,TypeTest i SPT: Test psi I OA' 30 . 30 30 I 30' ! ___._---1.-.__._...___--'---_..__._..______...l-__.__~.__~.____.__ ___. ,__.____.___ ---'-..._______________ _"_ Interval OTHER PfF ç Tubing I 4500 : 5000 : 4950 : 4930 : _______._._~_~___.o....-_____~__.______._.._~_~..___..._.._~_____.._._----'----.______._~____~_~_____------.-l.___.__.__ Notes: Bob, this is not really a MIT. We were pressure testing the tubing and the IA The tubing passed and the IA failed sCANNED JUN, 2, 1 2007 Tuesday, June 12, 2007 Page I of I . . MEMORANDUM State of Alaska TO: Alaska Oil and Gas Conservation Commission ,/'j . I Jim Regg . l<é1(1 ~IŠOl P. I. SupervIsor I. \ DATE: June 5, 2007 FROM: Bob Noble Petroleum Inspector SUBJECT: Pressure Test Tubing & IA RU #5A Forest Oil PTO 202-168 June 1-2, 2007: I traveled to the Forest Oil-operated Osprey Platform in the Redoubt Unit to witness well pressure tests. Redoubt 5A is planned to be converted to jet pump due to a failed ESP. Upon arrival on the Osprey platform to do a pressure test on the tubing and the IA of Redoubt Unit Well 5A, the operator had the tubing pressured up to 5000 psi and was pressuring up the IA to 2000 psi. We attempted a MIT. The tubing passed, losing 70 psi in 30 min. The IA failed, losing 390 psi in 30 min. We pressured up the IA several more times and it kept bleeding off. They went in with wire line and removed the tubing tail plug and attempted to shift a sleeve. I told the operator to put 1000 psi or less on the tubing and 2200 psi on the IA. While doing this, the tubing was tracking with the IA. At this point I left the platform. I explained what the State wanted for a test and told him to do it when they got the well fixed and to do a chart of it. I requested them to call the AOGCC office for inspection when they get a passing test on the IA. I also checked well pressures on those wells in operation: RU-1 T/IIO=1500/125/10 RU-7 T/IIO=1512/135/10 Summary: Pressure test on the tubing passed and the pressure test on the IA failed. But I told operator that they would both need to be redone when well was fixed. Attachments: none Confidential SCANNED JUN 252007 ,. ., .. .,..'~ 2007-0601 Redoubt RU-5A MITP bn.doc - - - - FW: Redoubt Unit Production . . Jim, Thanks for pointing out the reporting error, we will make the corrections and resubmit them. David Hall ~O~- I ~ <if ¡(ù,5A David Hall Production Manager Office 907-776-7108 -868-2133 Cell 907-317-8239 Fax 907-776-7119 -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Wednesday, May 30, 2007 10:25 AM To: David Hall Cc: Steve McMains Subject: Redoubt Unit Production Attached are the Monthly Production Reports we received from Forest for 2007; these report RU-5A on continuous production. The reports will need to be corrected if the well has been shut in due to failed ESP since January 6, 2007. Please research this. Thank you. Jim Regg AOGCC Jim Regg <iim regg(â;admin.state.ak.us> Petroleum Engineer AOGCC ~>CANNED JUN 0 1 Z007 .. 2007 monthly prod rpts Content-DescnptIOn: Redo~bt.pdf prod rpts Redoubt.pdf . . Content- Type: apphcatIon/pdf Content-Encoding: base64 1 of 1 5/31/2007 10: 18 AM . . Production History - Redoubt Unit SA PTD: 202-168 7 72 7 154 111 -07 720100 302 8207 I 28 87. '" L ,,~ 720100 20 502 788 31 79.4% 11_ f)",,_O¡:; 720100 1999 490 21417 31 91.5% " "T- A, 720100 1832 449 22031 30 92.3% OI_nd_O¡; 720100 1829 448 24994 31 93.2% A1 C'. AL. 720100 2 2 93iJ A' A, 7201 25770 31 92.90 o I-Ju1-06 720100 19 472 22715 31 92.20 o I-Jun-06 720100 145 356 22405 30 93. fl1 'L Ar 720100 1223 300 24775 31 95.3% A' A, 720100 1333 27 27461 30 95.4% 01-Mar-06 720100 1417 47 27522 11 Q5.1% fl1 v~t.. flL. 720100 1099 269 243 ~J:).7% 01- Tan-Oli 720100 1005 246 23608 31 ! 95.9% ~il~t=roo 1674 410 28R1d~~¡~lji . -Nov-05 720100 230 56 30562 .3% . 01 20100 831 204 2630 31 A' CL M 720100 1002 245 30005 30 96.8% A' A~ 720100 865 212 31672 31 97.3% A' T. A,. 720100 596 147 32577 31 98.2% o I-Jun-05 720100 508 =~F~:~~:=H~4 32287 30 98.5% A' 'L A~ 720100 512 5 49005 31 99,~~~···=1 0' A~ 720100 892 219 49005 30 98. A' K. A,. 720100 1737 426 55428 31 97.0% fl1 lC"~t.. A,. 720100 26 6 59793 28 100.0% 01-Jan-05 720100 3 1 17794 17 100.0% o L f)p,,_OJ. 720100 0 0 0 0 01-Nov-04 720100 0 0 0 0 01_nd_OLt 720100 0 0 0 0 fl1 C'. flA 720100 0 0 0 0 A' A 720100 0 0 0 0 o I-Ju1-04 720100 0 0 0 0 A1 T. AA 720100 11234 2752 31664 19 73.8% A' 'L A' 720100 21923 5371 55275 31 71.6% A' A' 720100 17971 4403 48904 30 73.1% A' 'K. A. 720100 19365 4744 50686 31 72.4% 01-Feb-04 720100 17436 4272 48993 29 4=!f '=N__n~~N 01-Jan-04 720100 4560 53382 31 .1% . ¡01-Dee-03 72010 05 I 52746 31 72. 9% 01-Nov-03 720100 18470 4525 49772 30 72.9% ·n~'~_.^"m'mw^~'_··.·^w>m^~~' ' 3812 50611 31 ! 76.5% 01-0et-03 720100 15561 _m'^WNNuuN~~~'~ 52151 720100 14567 3569 ::Et=J~I~-=] u 7201 16 47436 76.3% 72010 14990 3 47436 30 76.0% 72010 15680 2 46689 30 74.9% 2010 .. ';~~~~'-'~I31tI=J 51933 31 73.9% Ql-Ap~~~. 72010 59385 30 77.3% '~^'c'cow·_,W·',.wcmuu_n 01-Mar-03 72010 7896 1935 20826 18 72.5% 01-Feb-03 ~--~~Õ~·:·:J::··=ii~=·. 3901 36906 28 69.9% .vm~'__N_~~U~~ 01-Jan-03 713 15068 10 83.8% ?~+ ~~ .) <::ox:. r <::- II b I zø 7 Esp -Iá I 'We- c:: ~ e e MICROFilMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc STATE OF ALASKA ) ALA 1. OIL AND GAS CONSERVATION COMI,,"~SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED 1. Operations Abandon U Performed: Alter Casing D Change Approved Program D 2. Operator Forest Oil Corporation Name: 3. Address: Repair Well U Pull Tubing 0 Ope rat. Shutdown D Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D Stimulate U Other ~ YRipJirllfWe Waiver D Time Extension D Re-enter Susp~~QH:::a Gøs Cons. Commissicn 5. Permit to Drill Numgftnchorage Exploratory D 202-168 Service D 6. API Number: 50-733-20513-01 9. Well Name and Number: Redoubt Unit #5A 10. Field/Pool(s): Redoubt Shoal Field 310 K St, Ste 700, Anchorage, AK 99501 7. KB Elevation (ft): 90 8. Property Designation: ADL 381203, ADL 374002 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structu ral Conductor Surface Intermediate Drilling Liner Production Liner Perforation depth: measured 17,000 feet true vertical 12,830 feet measured 16,575 feet true vertical 12,639 feet Length Size MD 200' 30" 200' 3190' 13 3/8" 3190' 11500' 95/8" 11500' 4033' 7 5/8" 15232' 1882' 5 1/2" 17000 Plugs (measured) Junk (measured) TVD 200' Burst Collapse 2940SCANNED MAY 2 6 2005 10065' 11980' 12830' Measured depth: 15350'-15385',15410'-15460', 15560'-15600', 15615'-15635', 15765'-15915', 15950'-15960', 16020'-16030', 16170'-16525',3-3/8" TCP, 6 S True Vertical depth: 11995'-12013',12027'-12063', 12099'-12125', 12134'-12145', 12220'-12308', 12327'-12333', 12366'-12371', 12443'-12616', 12657'-12685', 3-3/8" TCP, 6 SPF Tubing: (size, grade, and measured depth) 3.5" 12.95 # P-11 0 Packers and SSSV (type and measured depth) 14988'BakerFA 13,204 Weatherford Hyd. 11 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: nla 13. RBDMS 8FL MAY 2 3 2UU5 Prior to well operation: 591 Subsequent to operation: 0 14. Attachments: Copies of Logs and Surveys Run no Daily Report of Well Operations 145 1667 o 1047 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: Oil0 Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Paula :nman .. / Signature ~~J~¿~- Contact Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1626 1585 Service D yes GINJ D WINJ D WDSPL D Sundry Number or NIA if C.O. Exempt: 305-011 Title Production Engineer Phone 868-2135 Date 5/19/2005 OklGINAL Form 10-404 Revised 04/2004 Submit Original Only Redoubt Unit )A Completion - February, 2005 ) I .. . TOL @ 11290 MD RIV Sleeve 13,150' MD Weatherford Hyd 11 Pkr @ 13,204' MD I II",',.'., I . 11,..1,'., I~.',¡.·,,·. ~ . II.".. .:\ ;.:"..'...,,1,.'.:, " I.:... ( . 'f:':· I I, ::', I I,~, ~:".;.,: ¡..J.., ~...,.:..'...":......:...;,,..,' . ...1.;, L . r) i I I ~ I '. ~ ~,.,.., =f b ~,i...1.,." - U ~f~ 'j RIV Sleeve 13,259' MD TOL @ 15118 MD Perforations: 15,350' - 15,385' 15,410' - 15,460' 15,560' - 15,600' 15,615' - 15,635' 15,765' - 15,915' 15,950' -15,960' 16,020' - 16,030' 16,170'-16,525' 3 3/8" 6 SPF ~30" 150 # 13 3/8" 68 # A-36 200 TVD Welded 200 MD L-80 2940 TVD BTC 3190 MD Tubing 3-1/2",12.95#, P-110, TSHD 95/8" 47# Centrilift ESP Assembly Intake @ 13,377' MD End @ 13,433' MD Baker Model FA Packer @ 14988 MD L-80 10065 TVD BTC 11500 MD 7 5/8" L-80 11980 TVD 29.7 # Hydril521 15323 MD Perforations EZ Drill @ 16575 MD 51/2" L-80 12830 TVD 17 # Hydril521 17000 MD · ý PEftC WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 12/29/2004 ) OPERATIONS SUMMARY REPORT ) Today's Date: 5/19/2005 REDOUBT UNIT #5A KUUKPIK #5 REDOUBT SHOAL 3 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 045541 507332051300 50-733-20513-00 PULL AND REPLACE ESP FOR RU DSS: DEPTH: o MUD WT: CUM COST TO DATE: 5,700.00 HOURS PH OP ACT 6.00 C MO 6.00 C MO 6.00 C MO 6.00 C DATE: 12/30/2004 HOURS PH 18.00 C 4.00 C 2.00 C DATE: 12/31/2004 HOURS PH 24.00 C DATE: 1/1/2005 MO ACTIVITY DESCRIPTION R/U STEAM LINE AIR FOR SUPPORT BUILDINGS TO RIG. R/U HIGH PRESSURE MUD LINE. SET CUTTINGS TANK UNDER SHAKERS. START RIG CLEAN UP - SHOVEL SNOW OUT OF BUILDINGS R/U ELECTRIC LINES. WORK ON HAND RAILS & CUTTINGS CHUTES. READY RID. SKID OVER RU #5. SET PIPE RACKS & CATWALK. INSTALLED CUTTINGS CHUTES, STAIRS & LANDINGS AFTER SKIDDING RIG. PUT WHITE SUITCASES OVER HYD LINES. PIU SAFETY MATS. PLACE STEAM HEATERS. SECURE PIPE RACKS & CATWALK. RE-ORGANIZE DECK. INSULATED BUILDINGS. RIU GAS BUSTER. PREPARED BOILER HOUSE FOR FUEL AND WATER. PUT BLOCK RUNNING GUIDE TOGETHER. TAKE ON FUEL. START FABRICATING FLOW-LINE. NOTE: INFORMED LOU GRIMALDI WITH THE AOGCC OF INTENT TO WORK ON THE RU#5A WELL RATHER THAN THE #6 AS ORIGANAL Y PLANNED. NOTE: WORK BOAT COULD NOT RUN DUE TO HIGH WINDS THROUGHOUT THE DAY AND EVENING, SHOULD BE DIEING DOWN TODAY. DSS: o DEPTH: MUD WT: CUM COST TO DATE: 11,700.00 OP ACT ACTIVITY DESCRIPTION MO R/U ELECTRIC START BOILER. WORK ON ACC DRIVE FROM ALLlMENT. WORKED ON ELECTRIC MOTOR CONTROLLER. WELDER INSTALLED FLOW LINE. OFFLOADED BOAT. STARTED STEAM THROUGH RIG. R/U HYD HOSES TO MAKE UP BREAK OUT RAMS. MOVED BEAVER SLIDE & CATWALK. INSTALLED SKID RAILS. WELDED ON KELLY HOSE FITTING. WORKED ON FLOWLINE BRACKET. CLEANED UP AUX HYD PUMP ROOM. PUT BLOCK GUIDE PARTS TOGETHER. CLEANED UP DECK. MO R/U PORTABLE HPU. INSTALLED BLOCK GUIDE RAIL. MADE LOADS FOR BOAT. PULLED OFF AUX HYD PUMP. MO PULLED DRILL LINE ONTO RIG FLOOR FOR STRING UP OF SAME. WORKED ON STEAM LEAKS. NOTE: AT +1-14:00 HRS STARTED UP RIG AT 1800 RPMS. ATTEMPTED TO UP RPMS TO 2100. RIG POWER FAILED. TROUBLE SHOT ELECTRICAL PROBLEM. SHOULD RECEIVE WORD SOMETIME TODAY FROM CANADA ON ELECTRICAL PROBLEMS. NOTE: NEXT WORK BOAT LOAD-OUT AT 04:15 AM FRIDAY 12-31-04, ALL SERVICE COMPANIES ARE ON WILL CALL AND READY TO GO. DSS: DEPTH: o MUD WT: CUM COST TO DATE: 17,700.00 OP MO ACT ACTIVITY DESCRIPTION TROUBLESHOOT ELECTRIC DRIVE PROBLEM. MECHANIC WORKING ON BOILER. SET ELECTRIC DRIVE RPMs. COMPLETED FLOW LINE BRACKETS. BUILT POP-OFF LINE TO TANK. CUT OUT SHIM FROM TOP DRIVE DOLLY. WORKED ON BOOM LINE GAURD. PUT SHIM IN TOP DRIVE GAURD. ORGANIZED PUMP ROOM. CLEANED OUT OFFICES TO BE SENT TO BEACH. STRAIGHTEN OUT TOOL HOUSE. PULLED LINE ON DRUM. PIU TOP DRIVE. PREPARING TO SCOPE DERRICK. NOTE: AT APPROXIMATELY 16:30 PM RESOLVED ELECTRICAL PROBLEM. DSS: o DEPTH: MUD WT: CUM COST TO DATE: 229,900.00 Page 1 of 7 Copyright © 1993-2004 by Epoch Well Services Inc. All rights reserved. · 'ý PEtC WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 1/1/2005 HOURS PH 18.00 C 1.00 C 5.00 C DATE: 1/2/2005 HOURS PH OP 9.00 C BP 2.50 C BP 9.50 C PT 3.00 C RS DATE: 1/3/2005 HOURS PH OP 3.00 C RS 6.00 C RS 3.00 CT RR 6.00 CT RR 6.00 CT RR DATE: 1/4/2005 ) OPERATIONS SUMMARY REPORT ) Today's Date: 5/19/2005 REDOUBT UNIT #5A KUUKPIK #5 REDOUBT SHOAL 3 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 045541 507332051300 50-733-20513-00 PULL AND REPLACE ESP FOR RU DSS: DEPTH: o MUD WT: CUM COST TO DATE: 229,900.00 OP MO ACT ACTIVITY DESCRIPTION WORKED ON HPU. INSTALLED AUX PUMP. FINISHED GUARD ON BOOM WINCH. MAKE BACK STOP ON DECK. PUT HOSES ON EXTENDER ARMS. FILL SWIVEL AND TOP DRIVE WITH OIL. CHANGED COMPENSATORS. SERVICED TOP DRIVE. REMOVED GUIDES ON ODS DERRICK. CENTER TORQUE TUBE OVER RT TABLE. INSTALLED WINCH & SPOOL. HOOKED UP STAND PIPE SENSORS & CORDS. MIU RISER SPOOLS. MIU SINGLE GATE ON MUD CROSS. WORKED ON #1 PUMP, CHANGED TO 5-1/2" LINERS & SWABS. PREPARING TO REMOVE TREE. NOTE: RIG WENT ON DAY RATE AT 00:01 ON 1/01/2005 NIU BOPS NOTE: NOTIFIED CHUCK SCHEVE WITH THE AOGCC AT 08:3012/31/04 ABOUT PLANS TO TEST BOPS. WE WERE INSTRUCTED TO CALL BACK THIS A.M. MO BP DSS: DEPTH: o MUD WT: CUM COST TO DATE: 262,200.00 ACT ACTIVITY DESCRIPTION FINISHED NIU BOPs. WENT TO SET MOUSE HOLE, WOULD NOT GO. HAD TO MODIFY WELL BAY CEILING TO FIT SAME. MIU TEST JTS & FLOOR VALVES. FUNCTIONED SAME. FILLED STACK AND TESTED BOPS, TOP RAMS, INSIDE & OUTSIDE KILL LINES, FLOOR VALVES & CHOKE MANIFOLD TO 250 PSI LOW & 5000 PSI HIGH. TESTED HYDRIL TO 3500 PSI. INSTALLING BELL NIPPLE. NOTE: RIG BLEW UP HYD PUMP FOR TOP DRIVE AT 17:30 PM. REPAIRING SAME. NOTE: SPOKE WITH CHUCK SHEVE ABOUT WITNESSING BOP TEST. AT 07:50 AM 1-1-05 HE WAIVERED HAVING A WITNESS ON BOARD. DSS: DEPTH: o MUD WT: CUM COST TO DATE: 305,500.00 ACT ACTIVITY DESCRIPTION LOWERED TOP DRIVE. TESTED UPPER & LOWER KELLY VALVES TO 250 PSI LOW & 5000 PSI HIGH. CLEANED UP RIG. OFFLOADED 451 JTS. OF 3-1/2" TBG AND CENTRALlFT REELS FROM MN CHAMPION. RR: MAIN HYD POWERPACK UNIT DOWN. INSTALLED FLOWLINE METER & HOOKED UP PIT MONITOR. RE-PLUMBED STEAM/H20 TRAP IN SHAKER ROOM. PLUMBED IN FLOWLINE CIRC PUMP. RR: BUILT BOX FOR HYD MOTORS. TROUBLESHOT PLC WITH TECH SUPPORT. CLEANED DDS DOGHOUSE. INSTALLED H2S & GAS ALARMS. RE-ORGANIZED DECK SPACE. RR: TROUBLESHOOTING MAIN HPU DSS: DEPTH: o MUD WT: CUM COST TO DATE: 350,300.00 Page 2 of 7 Copyright © 1993-2004 by Epoch Well Services Inc. All rights reserved. · . t( PEIC WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 1/4/2005 HOURS PH OP 14.00 CT RR 0.50 C RS 0.50 C RS 0.50 C RS 8.50 C CC DATE: 1/5/2005 HOURS PH OP 0.50 C CC 5.50 C CC 0.50 C CC 1.00 C RS 1.00 C RS 0.50 C RS 15.00 C TB DATE: 1/6/2005 HOURS PH OP 12.00 C TB 5.50 C TB 1.00 C RS 1.00 C TR 0.50 C RS 0.50 C RS 3.50 C TR DATE: 117/2005 HOURS PH OP 10.50 C TR 1.00 C 12.50 C ') OPERATIONS SUMMARY REPORT Today's Date: 5/19/2005 ) REDOUBT UNIT #5A KUUKPIK #5 REDOUBT SHOAL 3 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 045541 507332051300 50-733-20513-00 PULL AND REPLACE ESP FOR RU DSS: DEPTH: o MUD WT: CUM COST TO DATE: 350,300.00 ACT ACTIVITY DESCRIPTION RR: TROUBLESHOOTING HPU WITH ALASKA HYDRAULIC & RIG MECHANIC. WELDED HAND RAILS ON SUB. WELDED CUTTINGS TANK. SILICONE TOP OF BUILDING. CLEAN UP DECK. RIG OFF OF DOWN TIME AT 20:00 HRS. RIU LONG BAILS,CIRC HEAD & 2" HP HOSE. RIU LANDING JT. PULLED TWO-WAY CHECK - NO PRESSURE. BACKED OUT L.D.S. MIU LANDING JT & HP HOSE. PULL 190K WT UP FOR 20' AND UNSEATED HGR. PUMPED 23 BBLS TO FILL TBG (1200 PSI AT 2 BPM). RETURNS AT SHAKER AT 120 BBLS WITH 2000 PSI. CIRC BIU AT 2 BPM. AFTER BIU, GAS WENT TO 1500 UNITS. FLUID ROLLING IN BELL NIPPLE. CIRC ANOTHER 12000 STROKES. GAS STILL 1300+ AND ROLLING IN BELL NIPPLE. AT 05:30 SHUT OFF PUMP. OBSERVING WELL TO LET GAS WORK OUT OF WELL. DSS: DEPTH: o MUD WT: CUM COST TO DATE: 385,900.00 ACT ACTIVITY DESCRIPTION MONITORING HOLE AT BELL NIPPLE. GAS BREAKING OUT AND FLUID ROLLING IN SAME. CLOSED HYDRIL. CIRC B/U AT 2-1/2 BPM WITH 2400 PSI HOLDING 300 PSI BACKPRESSURE ON BACKSIDE. STOPPED PUMP. CLOSED CHOKE. BULLHEADED 15 BBLS AT 1-1/2 BPM WITH 2400 PSI. OPENED CHOKE. OPENED HYDRIL. OBSERVED WELL. WELL TAKING 6 BPH. HELD PRE-JOB SAFETY MEETING. RID CIRC HEAD. CENTERED STACK TO PULL HGR TO FLOOR. PULLED HGR TO FLOOR WITH 160K. TRIED TO PUMP DOWN CHEMICAL INJECTION LINES. PUMPED 11 GAL BEFORE REACHING 5000 PSI. CUT CONTROL LINE & DETACHED POWER CABLE. UD LANDING JT & HGR. POOH RACKING BACK 3-1/2" TBG IN DERRICK, SPOOLING UP CENTRILlFT LINE ON SPOOLS. ONE PHOENIX CLAMP ON EVERY OTHER JT - NO CLAMPS MISSING. NOTE: HOLE STILL TAKING APPROX 6 BBLS OF FLUID PER HR. AT 8570' HAD 20K OVERPULL & AT 8450' HAD 5K OVERPULL. DSS: DEPTH: o MUD WT: CUM COST TO DATE: 460,700.00 ACT ACTIVITY DESCRIPTION FINISHED POOH WITH 3-1/2" PRODUCTION TBG & CENTRILlFT CABLE. CHANGED SPOOL AT 4030', FOUND 1 BAD SPOT ON CENTRILlFT CABLE AT 4000'. FINISHED POOH. RECOVERED 236 CABLE CLAMPS. LAID DOWN ESP PUMP. INSTALLED WEAR BUSHING. PIU BAKER BHA (PKR RETRIEVING ASSY). REMOVED BAIL EXTENDERS PERFORMED RIG SERVICE. TIH WITH PKR RETRIEVING ASSY CIRC EVERY 3000' & CHECKING TORQUE EVERY 5000'. DSS: DEPTH: o MUD WT: CUM COST TO DATE: 510,600.00 RS TR ACT ACTIVITY DESCRIPTION CONTINUED TIH BREAKING CIRC EVERY 3000' & CHECKING TORQUE EVERY 5000'. AT 11992' TORQUE WAS 3600 FT LBS AND COULD NOT ROTATE WITHOUT RECIPROCATING PIPE. DECISION WAS MADE THAT WE WOULD NOT BE ABLE TO TURN PIPE ON BOTTOM. WITHOUT POSSIBILITY OF TWISTING OFF. REMOVED ESP SHEAVE FROM DERRICK. POOH LAYING DOWN 3-1/2" 8RD TBG AT 3277'. Page 3 of 7 Copyright © 1993-2004 by Epoch Well Services Inc. All rights reserved. · ... ' ý PelC WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 1/8/2005 HOURS PH OP 4.00 C TR 3.00 C TR 1.00 C TR 0.50 C RS 0.50 C TR 15.00 C TR DATE: 1/9/2005 HOURS PH OP 1.00 C RS 9.00 C TR 0.50 C TR 1.50 C CC 12.00 C TR DATE: 1/10/2005 HOURS PH OP 5.00 C TR 1.00 C TR 0.50 C RS 8.50 C PT 0.50 C RS 0.50 C SL 6.00 C SL 0.50 C SL 1.50 C SL DATE: 1/11/2005 ) OPERATIONS SUMMARY REPORT ) Today's Date: 5/19/2005 REDOUBT UNIT #5A KUUKPIK #5 REDOUBT SHOAL 3 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 045541 507332051300 50-733-20513-00 PULL AND REPLACE ESP FOR RU DSS: o DEPTH: MUD WT: CUM COST TO DATE: 560,000.00 ACT ACTIVITY DESCRIPTION CONTINUED POOH UD 3-1/2" 8RD TBG. UD 1600¿ OF 3-1/2¿ 8RD TBG OUT OF DERRICK. LOADED PIPE RACK WITH 3-1/2" 12.95# P-110 TSHD TBG & STRAPPED SAME. PERFORMED RIG SERVICE - LUBRICATED RIG. MIU LLC RETRIEVING TOOL BHA. P/U & TIH WITH LLC BHA AND 3-1/2" TSHD TBG. TORQUE AT 6000' 1700#. CONTINUE TIH. DEPTH AT 06:00 HRS 9194'. DSS: DEPTH: o MUD WT: CUM COST TO DATE: 627,800.00 ACT ACTIVITY DESCRIPTION SLIP & CUT DRILL LINE. CONTINUED TIH WITH LLC RETRIEVING BHA ON 3-1/2" 12.95# P-110 TSHD TBG FROM 9194' TO 14988'. TAGGED LLC PLUG AT 14988'. PIU AND HAD 20K OVERPULL. RELEASED K-ANCHOR WITH 15 RIGHT HAND TURNS (TORQUE 5000 PSI). P/U AND FREED. HOLE STARTED TAKING 42 BPH. CIRCULATE & CONDITION FLUID. POOH FROM 14988' TO 7800' (FLUID LOSSES AT 16 BPH) DSS: DEPTH: o MUD WT: CUM COST TO DATE: 673,700.00 ACT ACTIVITY DESCRIPTION FINISHED POOH WITH 3-1/2" TSHD TBG & BHA WITH LLC PLUG. UD LLC & BROKE APART BHA. PULLED WEAR RING. TESTED BOP TOP & BTM RAMS, CHOKE & KILL LINE VALVES & HCR, FLOOR & TOP DRIVE VALVES AND BLIND RAMS TO 250 PSI LOW & 3500 PSI HIGH. PERFORMED KOOMEY TEST TO 250 PSI LOW & 3500 PSI HIGH. TESTED HYDRIL TO 250 PSI LOW & 3500 PSI HIGH. ALL TESTED TO FOREST OIL & AOGCC SPECS. UD TEST JT. HELD PRE-JOB SAFETY MEETING. RIU POLLARD SLlCKLlNE. TIH WITH 6.5" GAUGE RING & JUNK BASKET. COULD NOT GET PAST 13600'. POOH. ADDED 5' SINKER BAR. TIH TO 300', HAD BAD NOISE IN CHAIN CASE. POOH TO CHECK OUT UNIT. CHAIN HITTING GAURD, REMOVED GAURD. TIH WITH GAUGE RING & JUNK BASKET AT 10000'. NOTE: JOHN CRISP WITH THE AOGCC CAME OUT TO WITNESS BOP TEST. DSS: o 718,900.00 DEPTH: MUD WT: CUM COST TO DATE: Page 4 of7 Copyright © 1993-2004 by Epoch Well Services Inc. All rights reserved. · I ý PERC WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 1/11/2005 HOURS PH OP 2.00 C SL 1.00 C SL 3.00 C TR 5.00 C TR 4.00 C TR 9.00 C TR DATE: 1/1 2/2005 HOURS PH OP 1.00 C TR 23.00 C TB DATE: 1/13/2005 HOURS PH 3.50 C 4.50 C 3.00 C 3.00 C 1.00 C 6.00 C 3.00 C DATE: 1/14/2005 ) OPERATIONS SUMMARY REPORT ) Today's Date: 5/19/2005 REDOUBT UNIT #5A KUUKPIK#5 REDOUBT SHOAL 3 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 045541 507332051300 50-733-20513-00 PULL AND REPLACE ESP FOR RU DSS: o CUM COST TO DATE: 718,900.00 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION CONTINUED TIH WI 6.5" GAUGE RING & JUNK BASKET TO 13375'. COULD NOT WORK ANY DEEPER DUE TO ANGLE OF HOLE. NO JUNK POOH. RID SLlCKLlNE UNIT. HELD PRE-JOB SAFETY MEETING WITH ALL CREWS. RIU CENTRILlFT. PIU CENTRILlFT ELECTRIC MOTOR & PUMP. FOUND BAD SPOT IN ELECTRIC CABLE FLAT. CHANGED OUT ELECTRIC CABLE. CHECKED NEW CABLE LEAD. PIU PUMPS, PRESSURE HEAD, TBG & WEATHERFORD PKR. RIU SLIDING SLEEVE W/2.562 PROFILE. CHECKED ELECTRIC LEAD MOTOR. INSTALLED CLAMPS AS PER CENTRILlFT. DAILY DOWNHOLE LOSSES: 384 BBLS CUM. DOWNHOLE LOSSES: 1032 BBLS DSS: o MUD WT: DEPTH: CUM COST TO DATE: 791,000.00 ACT ACTIVITY DESCRIPTION FINISHED PIU PUMPS & PKR AND MADE FINAL SPLICE AT PACKER. TIH WITH ESP PUMPS & WEATHERFORD PKR ON 3-1/2" 12.95# P-110 TSHD TBG. NOTE: CHECKED CONNECTIVITY AT 2000' - O.K. CONTINUED TIH. MADE SPLICE AT 4000'. BROKE CIRC (NOT TO EXCEED 500 PSI). CONTINUED TIH. TESTED CONNECTIVITY AT 6000' - O.K. CONTINUED TIH. MADE SPLICE AT 8200'. BROKE CIRC (NOT TO EXCEED 500 PSI). CONTINUED TIH. DEPTH AT 06:00 HRS 9385' NOTE: DAILY DOWNHOLE LOSSES=384 BBLS CUM. DOWNHOLE LOSSES=1416 BBLS DSS: o MUD WT: CUM COST TO DATE: 839,000.00 DEPTH: OP TB ACT ACTIVITY DESCRIPTION CONTINUED TIH WITH ESP PUMPS & PKR TO 12080'. BROKE CIRC AS PER WELL PROG. STOPPED FILLING HOLE FOR 1 HR. FILLED ANNULUS WITH 17 BBLS (769'). PUMPED 10 BBLS IN ANNULUS EVERY HR UNTIL 17:00 HRS. MADE SPLICE IN CABLE. PUMPED THROUGH TBG AT 400 PSI AT 8 SPM. CONTIUED TIH F/12080' TO 13809'. HIT BRIDGE. WORKED FREE W/35K OVERPULL. ATTEMPTED TO WORK BACK THROUGH BRIDGE AT 13809' WI PUMP ASSIST AT 8 SPM AT 469 PSI. COULDN'T WORK THROUGH BRIDGE. PULLED 20K OVER TO PULL FREE OF BRIDGE. POOH TO 13400'. INSTALLED HGR, LANDING JT AND CENTRILlFT CABLE & MADE SPLICE ON SAME. STARTED SHOOTING FLUID LEVEL IN ANNULUS AT 02:00 HRS. PROGRAM FOR READING RESULTS NOT WORKING. DOWNLOADED NEW PROGRAM AND INSTALLED SAME IN POLLARD COMPUTER TO READ ECHO READINGS. NOTE: PUMPED 10 BPH EACH HR UNTIL 17:00 HRS TO REDUCE CHANCES OF SETTING PACKER WHEN BREAKING CIRC. ANY COMBINATION OF HYDROSTATIC HEAD OR PUMP PRESSURE OF 1000 PSI WOULD SET OFF PACKER. NOTE: DAILY DOWNHOLE LOSSES= 260 BBLS CUM LOSSES= 1676 BBLS TB TB TB TB TB TB DSS: o 1,489,900.00 MUD WT: CUM COST TO DATE: DEPTH: Page 5 of 7 Copyright © 1993-2004 by Epoch Well Services Inc. All rights reserved. · ~ ý PEtC WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 1/14/2005 HOURS PH OP 10.00 C CC 2.00 C TB 2.00 C SL 2.50 C SL 2.50 C SL 1.00 C PT 2.50 C SL 0.50 C SL 1.00 C TB DATE: 1/15/2005 HOURS PH OP 0.50 C WH 5.00 C WH 0.50 C WH 4.50 C WH 3.50 C MO DATE: 2/1 5/2005 HOURS PH OP 1.50 C MO 2.00 C PT 3.00 C SL 1.00 15.00 IS-C WO C SL DATE: 2/16/2005 ') OPERATIONS SUMMARY REPORT ) Today's Date: 5/19/2005 REDOUBT UNIT #5A KUUKPIK #5 REDOUBT SHOAL 3 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 045541 507332051300 50-733-20513-00 PULL AND REPLACE ESP FOR RU DSS: o DEPTH: MUD WT: CUM COST TO DATE: 1,489,900.00 ACT ACTIVITY DESCRIPTION SHOOTING FLUID LEVELS WITH 8.5# FLUID. FLUID DEPTHS: 0:600 4,438¿, 07:304,527 ¿, 08:00 4,748¿, 08:30 4,759¿, 10:00 5,138¿, 11:30 5,368¿, 13:30 5,632¿, 15:30 5,719¿. ORIENT AND LAND HANGER. PIU 4¿ & SET SLIPS. PUMPED AT 13,433¿. RIU POLLARD SLlCKLlNE. TIH AND SET PLUG BODY AT 13263¿. POOH. TIH WITH PLUG. PRESSURED UP TO 2700 PSI BLEW OUT SEALS IN HYD PUMP). SET PACKER AT 13203.63¿; END OF MOTOR AT 13433'; SLIDING SLEEVE AT 13150'; SLIDING SLEEVE AT 13258'. FILLED ANNULUS WITH 146 BBLS. ADDED 2 BBLS OF CONQOR 404. NOTE: RAN 211 JTS OF 3-1/2" 12.95# P-110 TSHD TBG RIU AND TESTED PACKER THROUGH ANNULUS TO 500 PSI. FOR 10 MIN. POOH WI PLUG & PLUG BODY. RID LUBRICATOR & SLlCKLlNE. LANDED HGR. RUN IN LOCKDOWN SCREWS. BREAK OUT LANDING JT & UD SAME. INSTALLED TWO-WAY CHECK. DSS: DEPTH: o MUD WT: CUM COST TO DATE: 1,650,200.00 ACT ACTIVITY DESCRIPTION INSTALL TWO WAY CHECK AND CLEAN RIG FLOOR. NID BOP'S, PULL ROT TABLE. NID BELL NIPPLE, FLOW LINE, CHOKE LINE, KILL LINE, BOP'S, RISER, AND UD RISER. NIU TREE. TEST TREE TO 3000 PSI = OK. TEST PACK OFF TO 5000 PSI = OK. HOOK UP WING VALVE TO PRODUCTION LINE, PULL TWO WAY CHECK VALVE. SKID RIG FI RU 5 WELL TO RU 2 WELL. DSS: o DEPTH: MUD WT: CUM COST TO DATE: 1,694,500.00 ACT ACTIVITY DESCRIPTION SKID RIG TO WELL RU #5A & CENTER OVER WELL. HOOK-UP SERVICE LINES. (NOTE: PROD BLED BOTH 3/8" CAPILLARY LINES PRIOR TO RIG MOVE). SCREW 3-1/2" RISER JT IN TOP OF TREE TO RIG FLOOR. INSTALL SAFETY VLV & RU BLEED LINE TO RIG CHOKE MANIFOLD. SITP- 75 psi. BLEED DRY GAS THRU RIG GAS BUSTER FROM 75 psi TO ZERO. RU POLLARD SIL UNIT & LUBR. MU 2.50" GR, SPANG JARS, ROLLER STEM & OIL JARS. RIH & TAG 'RIV' SLEEVE @ 13,154' WLM. POH, OIL JARS HAD BACKED OUT OF SUB; PIN HAD SHEARED. NO FISHING NECK, 7/8" ROD SHOULD BE DOWN IN JAR BODY. (FISH LEFT IN HOLE: 2.50" GR, SPANG JARS, ROLLER STEM & OIL JARS-12' L). TOF @ 13,142' WLM. FOUND FL @ APPROX 3300' WLM. WAIT ON 1-3/4" OVERSHOT TO CATCH BODY OF JARS. MU OVERSHOT wI 1-3/4" GRAPPLES. RIH & LATCH FISH @ 13,140' WLM. POH, REC ALL OF FISH. LD FISH, MU 2.56" 'PR' PLUG BODY & RIH. SET PLUG IN 'R' NIPPLE @ 13,154' WLM. POH; MU 'PRR' PRONG & RIH; SET PRONG IN PLUG @ 13,154' WLM. POH & LD SIL LUBR. RU RIG PUMP & LOAD TBG wI 23 B FSW. ATTEMPT TO TEST PLUG w/1 000 psi; WOULD NOT TEST. BLEEDS DOWN TO ZERO IN 5 min; TBG ON VACUUM; PLUG APPEARS TO BE LEAKING. PU SIL LUBR & RIH wI PULLING TOOL TO PULL 'PRR' PRONG. LATCH & PULL PRONG & 13,154' WLM. POH, PRONG LOOKED OK. RE-DRESS PRONG & RIH. SET PRONG IN PLUG @ 13,154' WLM. POH. ATTEMPT TO TEST PLUG wI 1000 psi, STILL LEAKED; TBG ON VACUUM. RIH & PULL PRONG. DSS: o 1,716,200.00 DEPTH: MUD WT: CUM COST TO DATE: Page 6 of 7 Copyright © 1993-2004 by Epoch Well Services Inc. All rights reserved. · , "I' Ý PEtC WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: HOURS PH 5.00 C ) OPERATIONS SUMMARY REPORT ) REDOUBT UNIT #5A KUUKPIK #5 REDOUBT SHOAL 3 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: OP SL Today's Date: 5/19/2005 045541 507332051300 50-733-20513-00 PULL AND REPLACE ESP FOR RU ACT ACTIVITY DESCRIPTION RIH & PULL 'PRR' PRONG @ 13,154' WLM; POH. RIH wI 'JDC' PULLING TOOL & PULL PLUG BODY @ 13,154' WLM. BOTH PLUG & PRONG IN EXCELLENT CONDITION; PKG & 'O-RINGS' ALL LOOK GOOD. CHECK PRONG POSITION IN PLUG, SEALED OK. RD SIL UNIT & SECURE WELL. TURN WELL OVER TO PRODUCTION. Page 7 of 7 Copyright © 1993-2004 by Epoch Well Services Inc. All rights reserved. ) , . ,-rlr 0lUJn~~2, 11;þ I¡,IU~ u lb L AItASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSK', GOVERNOR 333 w. -¡m AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ctl"",',""C, ",',',"', .",',~""",',', ",~", """'" -, " /i _,.,01,"", "'"'",,, ,"',."., ",', d(U~' ,.~ Ted E. Kramer Production Manager Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 Re: Redoubt Unite #5A Sundry Number: 305-011 Dear Mr. Kramer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd d ollowing the date of this letter, or the next working day if the 23rd day falls on oliday or weekend. A person may not appeal a Commission decision t Sup~io Court .less rehearing has been requested. ' DATED ilii~Y of January, 2005 Encl. fAü,f";'" SCANNEr¿ FEB 0 4 LU~ ) @ FOREST 0 I L CORPORATION /110 cfl{(;f-/i;;r+>Æ¿-. &£{:te 700 CJS2tn~ff6' cPÚaðka .9.9501 (907) 258-8600 . (907) 258-8601 (~,;¡;) January 18, 2005 'Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RECEIVED JAN 2 0 Z005 1Re: Forest Oil Redoubt Unit #5A ESP Repair Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Norman, ,During the recent electrical submersible pump (ESP) replacement in the Redoubt Unit #5A two check valves were inadvertently placed below the tubing. hanger in this well. These check valves are unnecessary due to the installation of Nova flow check valves already installed in the capillary lines below the packer. Forest Oil plans to use Kuukpik Drilling Co. 'Rig #5 to remove the well head, pick up the tubing, and remove the check valves as detailed in the attached procedure. Attached please find a completed Form 10-403 for the work, a detailed work procedure and a current tubing hanger schematic. If you have any questions, please contact me at 868-2137. Sincerely, ~( '7~ Ted E. Kr~er Production Manáger Forest Oil Corporation Attachments ORIGiNAL ) STATE OF ALASKA) R k ALASKA Oil AND GAS CONSERVATION COMMISSIO])tN 20 2r:¡;t¡ '61 APPLICATION FOR SUNDRY APPROVAL~\o. com'~r¡ MD~\{2lji 0. Abandon: - Suspend: - Operation shutdown: - Re-enter suspended well: -Anchorage Alter casing: Repair well: X Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: Remove check valves. 5. Type of well: 6. Datum elevation (DF or KB) Development: ~ Exploratory: Stratigraphic: Service: 1. Type of Request: 2. Name of Operator Forest Oil Corporation. 3. Address 310 K Street, Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 1909' FSL, 318' FEL, Sec. 14, T07N, R14W, SM At top of productive interval 1058' FSL,288'FWL,Sec.19, T07N,R13W,SM At effective depth 40' FSL, 1361' FWL, Sec. 19, T07N, R13W, SM At total depth 40' FSL, 1361' FWL, Sec. 19, T07N, R13W, SM 12. Present well condition summary Total depth: measured true vertical Plugs (measured) 17,000 ft 12,830 ft 90' MSL feet 7. Unit or Property name Redoubt Unit 8. Well number Redoubt Unit #5A 9. Permit number 202-168 10. API number 50-733-20513-01 11. Field/Pool Redoubt Shoal Oil Field Redoubt Shoal Effective depth: measured true vertical 16,575 ft 12,639 ft Junk (measured) N'A Casing Structural Conductor Surface 3,190' 13 3/8" Surface 3,190' 2,940' Intermediate 11,500' 9 5'8" 1,286 cu ft 11,500' 10,065' Drilling Liner 4,033' 7-5'8" 252 cu ft 15,323' 11,980' Production Liner 1,882' 5-1/2" 314 cu ft 17,000' 12,830' Perforation depth: Measured Depth: 15350'-15385', 15410'-15460', 15560'-15600', 15615'-15635', 15765'-15915', 15950'-15960', 16020'-16030', 16170'-16525',3-3/8" TCP, 6 SPF TVD: 11995'-12013',12027'-12063', 12099'-12125', 12134'-12145', 12220'-12308', 12327'-12333', 12366'-12371', 12443'-12616', 12657'- 12685', 3-3'8" TCP, 6 SPF Tubing (size, grade, and measured depth) Length 200' Size 30" Cemented Driven Measured depth 200' True vertical depth 200' Packers and SSSV (type and measured depth) ESP on 3 1'2" 12.95# tbg. set at 13,440' MD (425 jts P-110 PH6) 13. Attachements Description summary of proposal: X Weatherford Hydro II, 3-1'2" X 7-5/8" Pkr. @ 13203.76' MD BOP sketch: On File Detailed operations program: X 14. Estimated date for commencing operation 2/5/2005 16. If proposal well verbally approved: Oil: X 15. Status of well classification as: Gas: Suspended: - Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed/~ ~ ~~ Date: II ß/p~ Title: Production Manager, Forest Oil FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity- BOP Test~ L '1 clearance- Mechanical Integrity Test- Subsequent fa required 10- '-'.0,,",\ Form 10-4 Approval No. 3oS-0/ I RBDMS BFL JAN') 'ií(¡1 RBDMS 8Fl JAN 2 4 2005 Commissioner ff/or SUBMIT IN TRIPLICATE Date ') ) Procedure for Removing Redundant Check Valves Forest Oil Corp summits the following proposal to the AOGCC for approval. The work involved is on the Redoubt Unit #5A wen. Proposed Work Remove two inline check valves from chemical injection and vent lines under tubing hanger. These check valves are redundant to two Nova flow check valves installed below the packer and were installed by mistake while repairing the ESP pump. The check valves were installed 18" under the tubing hanger. 'TheWeatherfordpacker@ 13,203' was set in compression \vith 30,OOOlbsofwton it. This was then tested to 500 psi with the annulus full of 8.5 ppg fiçld produced water. The proposed work will be performed after a successful no flow test is preformed which will be witnessed by AOGCC. Please see the attached tubing hanger diagram for location of check valves in well. Steps to be taken: 1.) Forest Oil Corp proposes to kill the well with 8.5 ppg field produced water and set a plug in the Weatherford R/V sliding sleeve @ 13,149' . 2.) Set a BPV in the tubing hanger before removing the tree. 3.) The tubing hanger would then be lifted up approximately 18" in order to gain access to the check valves. 4.) Remove the two check valves in the capillary strings. 5.) Lower and reset the tubing hanger. 6.) Nipple up tree and test same to 250 psi low to 3500 psi hi. . 7.) Remove Plugs, place well back on production. ~" ~\,)\....\. {f 01"1"''''\,) '> <..\ ".,.\~~~ o~"'~~ ...;\ \ \ '0(: ~v\' ~ ~~~ ~~~. ,""\-:. \>~~t<ë ~\-.a~\'ð "Ð'\-~>\) \\-ìt\ \)",...~.t{~ ~k ~~~ 1: t"CCCO,,^~Q.PPtt)-.tO. C Á£ "W7 \I"ó>\-ð~ ) J:.tJl. (tV ~ Ch6v.k.. (j.4]v$<j 7'D 13 r$f< 6 vmövtfd. ,\ ¡ ~. y 'vi ) " I . I I I i ! i ¡ t I i 13.4id" ,", ",' , ,,¡ :] ¡ -:f}.J/)IJl!: Cbec~ '. r)¿4luçe" "To t3¿RlfTY'O~l.,,<:' ~ ~ ?) DATA SUBMITTAL COMPLIANCE REPORT 10/29/2004 u Permit to Drill 2021680 Well Name/No. REDOUBT UNIT 5A Operator FOREST OIL CORP API No. 50-733-20513-01-00 MD 17000 .,,/ Completion Date 10/22/2002 Completion Status 1-01L Current Status 1-01L UIC N TVD 12830 ..r ,/' REQUIRED INFORMATION Mud Log No Samples No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: 8-1/2" Hole - Azimuthal Density, Res, GR 63/4" Hole - ND, Res, Gr, C Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr ~ Data Digital Dataset Log Log Run Interval OH/ ~e Med/Frmt ~ber Name Scale Media No Start Stop CH Received Comments 'ÉD 2242 Report: Final Well R 0 0 4/23/2003 ~ 12242 Report: Finsl Well R 0 4/23/2003 4 C Tf t>f2242 Directional Survey 0 17000 4/23/2003 ~D C Tf c6242 LIS Verification 11501 17000 Case 4/23/2003 Cased Hole Wireline data - 2 files on disk \R5'( ~ssure 0 0 Case 4/23/2003 Pressure Gauge Report ~. See Notes 0 0 Case 4/23/2003 R..~sults of Laboratory ---Analysis of Oil ~pt See Notes 0 0 Case 4/23/2003 DST#1 (Lower Hemlock) Water Analysis Rpt See Notes 0 0 Case 4/23/2003 Testing Summary & Analysis - Upper & Lower ~( Hemlock Sands See Notes 0 0 çi.i/t^4/23/2003/Textural and compositional characteristices of core ~' samples - 1J¿6g Mud log 2 ~ 145 17000 C~' 4/23/2003 Composite Formation Log ~.. Mud Log 2 cBtt( 11473 17000 ~4/23/2003 Formation Log , Log See Notes 2 Blu 11473 17000 ~ 4/23/2003 DML-MWD Combo Log t..:/ Log See Notes 2 Blu 145 17000 C e 4/23/2003 Composite DML-MWD ~; Combo Log v Log See Notes 2 Blu 11473 17000 C e 4/23/2003 Drilling Dynamics log (.,/ Log See Notes 2 Blu 145 17000 Ca e 4/23/2003 Composite Drilling ~2242 Dynamics Log ED D Pds Cement Evaluation 5 14400 16850 Case 4/23/2003 Cenent Bond Tool- VDl -,.1::69' ¿../6ement Evaluation 5 ~r#/ 14400 16850 Case 4/23/2003 Cenent Bond Tool - VDL DATA SUBMITTAL COMPLIANCE REPORT 10/29/2004 Permit to Drill 2021680 Well Name/No. REDOUBT UNIT 5A Operator FOREST OIL CORP API No. 50-733-20513-01-00 MD 17000 TVD 12830 Completion Date 1 0/22/2002 Completion Status 1-01L Current Status 1-01L UIC N ~ D Pds l1'2242 Magnetic Resonance 5 15367 16716 Case 4/23/2003 Combinable Magnetic ¿ ø Resonance Tool ~gnetic Resonance 5 BM 15367 16716 Case 4/23/2003 Combinable Magnetic Resonance Tool ~D D Pds C1'2242 See Notes 5 14400 16850 Case 4/23/2003 Correlation Log GRlCCL Log See Notes 5 Sep 14400 16850 Case 4/23/2003 Correlation Log GRlCCL #1' D Pds /12242 Casing collar locator 5 1 14400 16850 Case 4/23/2003 Correlation Log GRlCCL ~g '" /Casing collar locator. ~ ~ 5 B' 1 14400 16850 Case 4/23/2003 Correlation Log GRlCCL " -~ C Pds .)2242 Magnetic Resonance 5 1 15342 16697 Case 4/23/2003 Elemental Capture /. Spectroscopy Tool r...Jd>g c.Jf1'agnetic. Resonance 5 BM./' 1 15342 16697 Case 4/23/2003 ~mental Capture ~2242 pectroscopy Tool 40 C Pds Perforation 5 15753 15755 Case 4/23/2003 Squeeze Perforation Record 2 7/8" 2906 HMX 6 L spf -log \/12242 Perforation 5 B~ 15753 15755 Case 4/23/2003 Squeeze Perforation Record 2 7/8" 2906 HMX 6 spf /Ep C Pds J12242 Cement Evaluation 5 14400 16850 Case 4/23/2003 Ultrasonic Imaging Tool - Cement Mode - Cement ¿g /" Bond Tool ' / BrvI' V Cement Evaluation 5 1 14400 16850 Case 4/23/2003 Ultrasonic Imaging Tool - Cement Mode - Cement ¿g ';jG ).G .,' í- Bond Tool Casing collar locator .;Lû (1,. ~ 5 BIlV' 1 14600 14950 Case 4/23/2003 er6P Correlation GRlCCL ~\:A~~ BI~/ 1 .~ '-Ic6Q Casing collar locator J ( 5 14650 14925 Case 4/23/2003 TCP Correlation GRlCCL / ~2243 ß[)./ See Notes 4/23/2003 Core Photo's Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments 1114 £/'. ." Cuttings 11500 17000 Permit to Drill 2021680 MD 17000 TVD 12830 ADDITIONAL INFORMATION Well Cored? llYJl N Chips Received? Y I~ Y/@ Analysis Received? Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/29/2004 Well Name/No. REDOUBT UNIT SA Operator FOREST OIL CORP Completion Date 1 0/22/2002 Completion Status 1-01L Current Status 1-01L Daily History Received? ð'lN Q/N Formation Tops }d-v Date: API No. 50-733-20513-01-00 UIC N ~' .3 J g,^- ~ r' '"-,,r 'þ~ , ) r10z - Ii? 'If ~J&\lrŒ J} !k\~ffi~~AU~ AI,ASIiA OIL AND GAS CONSERVATION COMMISSION / / I j / I' FRANK H. MURKOWSKI, GOVERNOR ¡' ,i 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paula Inman Production Engineer Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 Re: Redoubt Unit #5A Sundry Number: 304-461 Dear Ms. Inman: 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 fonn. 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. ~ Daniel T. Seamount, Jr. Commissioner DATED thi0 day of December, 2004 Enc!. RU #5A ESPJETPUMP Procedure Rev 2 AOGCC.doc ) Subject: RU #5A ESPJETPUMP Procedure Rev 2 AOGCC.doc From: Paula Inman <PRInman@forestoi1.com> Date: Thu, 02 Dec 2004 17:25:27 -0700 To: Thomas E Maunder <tom_maunder@admin.state.ak.us> Here is the revised procedure for RU #5A. Thanks for you help, Paula «RU #5A ESPJETPUMP Procedure Rev 2 AOGCC.doc» #5A ESPJETPUMP Procedure Rev 2 Content-Type: application/msword Content-Encoding: base64 1 of 1 12/2/20044:21 PM Re: RU #2 ESPJETPUMP Procedure rev2AOGCC.doc Subject: Re: RU #2 ESPJETPUMP Procedure rev2AOGCC.doc From: Thomas Maunder <tom_maunder@admin.state.alcus> Date: Thu, 02 Dec 2004 13:51:41 -0900 To: Paula Inman <PRInman@forestoi1.com> Paula, I have the new 403 covers for your proposed work. Thanks to you and Bill. I was putting the new procedure you sent over in the packages and I noted that there is only one for RU#2. I presume the procedure has changed for RU#5A, but there is no "paperwork" for the change. Can you send me the RU#5A revised procedure or confirm the the procedure is that same as RU#2, but the with appropriate depths changed. Thanks, Tom Maunder, PE AOGCC Paula Inman wrote: Tom, See attached procedure for RU#2. This procedure would be the same for RU#5a also. Thanks for you help. Paula Inman 868-2135 «RU #2 ESPJETPUMP Procedure rev2AOGCC.doc» 1 of 1 12/2/20044:10 PM 1. Type of Request: ) STATE OF ALASKA \ ALASIV\~OIL AND GAS CONSERVATION COMMI~jON APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Suspend U Repair well D Pull Tubing 0 Development Stratigraphic 310 K St., Suite 700, Anchorage, AK 99501 7. KB Elevation (ft): Abandon U Alter casing D Change approved program D 2. Operator Name: Forest Oil Corporation 3. Address: 8. Property Designation: 11. Total Depth MD (ft): 17,000' Casing Structural Conductor Surface Intermediate Drilling Liner Production Liner Perforation Depth MD (ft): 15,350' - 16,525' Packers and SSSV Type: F::: [:¡~~ b~0 2004 'd- 1~ ~- : r"': ~I Perforate U \Í\/aiv~J U I"~ r Stimulate D Time Extensio~O~ Re-enter Suspended Well D 5. Permit to Drill Number: 0 D Exploratory D D Service 90' MSL 9. Well Name and Number: Redoubt Unit #5A 10. Field/Pools(s): ADL-381203 . }\~rular Dispos. U . ,. Other 0 Repair ESP 202-168 6. API Number: 50-733-20513-01 Redoubt Shoal Oil Field PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Total Depth TVD (ft): 12,830' Length 16,575' Size 30" MD 200' 200' 3,190' 13-3/8" 11 ,500' 9-5/8" 4,033' 7 -5/8" 1,882' 5-1/2" Perforation Depth TVD (ft): 3,190' 11,500' 15,323' 17,000' Tubing Size: 11,995' - 12,685' Baker FA pkr w/ LLC-3 valve 12,639' Plugs (measured): Pkr/LLC @14,988' Burst Junk (measured): None Collapse TVD 200' 2,940' 10,065' 11,980' 12,830' Tubing Grade: 3-1/2" Packers and SSSV MD (ft): P-110 14,988' 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D 12/15/2004 Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Paula Inman Title Signature -. /7. . /2 If..... ¿ a.nA. Pbone i+~i"'.i 'ò...:-:.-'í/-z..-¡rl/( 'Y - N/A N/A 5,020 2,260 6,330 4,750 6,890 4,790 7,740 6,280 Tubing MD (ft): 14,946' 0 Service D Plugged WINJ D D Abandoned WDSPL D D Contact Paula Inman Production Engineer, Forest Oil 868-2135 Date "It JO 'I COMMISSION USE ONLY /. Conditions of approval: Notify Commission so that a representative may witness BOP Test ~ Sundry Number: 3ocj-ll~1 Mechanical Integrity Test D Location Clearance D Other: ?,~\;.>~, Ñ\.'f'.-~''"'-~~ ~~~ ~\--, ~\>~"'=>*-\~~~\ f... ~~'i ~ RBDMS BFL DEC 9 6 2004 Plug Integrity D Subsequent Form Required: APprOVedby.Øi7 ~ 0 R>~GU~A L ~::;~~:~:ION INSTRUCTIONS ON REVERSE Form 10-403 Revised 12/2003 Oate: f z/~ ( 4- Submit in Duplicate Latest RU #3 and SA Sundries .' \ /,. .~ . /~. Subject: Latest RU~nd sA. Sundries From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Sat, 27 Nov 2004 14:02:41 -0900 To: Paula Inman <prinman@forestoil.com>, Bill Penrose <bill@fairweather.com> ) Paula and Bill, I am working on the recently submitted sundries for the workovers. As I started to look at the "forms", I noticed that they are not the most current as available on our website. I have to ask that the information be resubmitted using the most recent 403. Sorry about that, but the Commissioners issued a letter a while back that said after September I, 2004 prior editions of the forms would not be accepted. I look forward to the receiving the revised forms. All that is needed is the form, I can transfer the attachments. Please let me know when they are available. Tom Maunder, PE AOGCC 1 of 1 11/27/20042:02 PM ~ FOREST OIL ) CORPORATION .J 1 0 QYC Q%tpÆ](. ÇJ51~u;te 700 QW/}U'k~1fØ ~ c;S4taakÆZ, .9.9501 (907) 2.58-86'00 . (907) 2.58-86'01 (dhxx) ~ovember19,2004 Mr. John ~onnan, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Forest Oil Redoubt Unit#5A ESP Repair Dear Mr. ~onnan, The Electric Submersible Pump (ESP) in the Redoubt Unit #5A well has failed. Forest Oil plans to use Kuukpik Drilling Co. Rig #5 to pull the ESP assembly and run a new assembly as detailed in the attached repair procedure. Attached please find a completed Form 10-403 for the work, a detailed work procedure and a current wellbore schematic. If you have any questions, please contact me at 868-2135 or Bill Penrose at Fairweather at 258-3446. Sincerely, /ÜJ~~- ..- Paula Inman Production Engineer Forest Oil Corporation Attachments ORIGINAL \ STATE OF ALASKA \ ALASKA Oil ÁND GAS CONSERVATION l.JMMISSION APPLICATION FOR SUNDRY APPROVALS ,f:!¡? 1. Type of Request: Abandon: Suspend: - Operation shutdown: Alter casing: Repair well: Plugging: - Change approved program: Pull tubing: X Variance: 5. Type of well: Development: ~ Exploratory: Stratigraphic: Service: Re-enter suspendeöwell: - Time extension: Stimulate: Perforate: Other: epair ESP 6. Datum elevation (DF B) 2. Name of Operator Forest Oil Corporation. 3. Address 310 K Street, Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 1909' FSL, 318' FEL, Sec. 14, T07N, R14W, SM At top of productive interval 1058' FSL, 288' FWL, Sec. 19, T07N, R13W, SM At effective depth 40' FSL, 1361' FWL, Sec. 19, T07N, R13W, SM At total depth 40' FSL, 1361' FWL, Sec. 19, T07N, R13W, SM 12. Present well condition summary Total depth: measured true vertical 90' MSL feet Casing Structural Conductor Surface 3,190' 13 3/8" Suñace 3,190' 2,940' Intermediate 11,500' 9 5/8" 1,286 cu ft 11,500' 10,065' Drilling Liner 4,033' 7 -5/8" 252 cu ft 15,323' 11,980' Production Liner 1,882' 5-1/2" 314 cu ft 17,000' 12,830' Perforation depth: Measured Depth: 15350'-15385',1 10'-15460',15560'-15600',15615'-15635', 15765'-15915', 15950'-15960', 16020'-16030', 16170'-16525',3-3/8" TCP, 6 SPF TVD: 11995'-12013', 12027'-12063', 2099'-12125',12134'-12145', 12220'-12308', 12327'-12333', 12366'-12371', 12443'-12616', 12657'- 12685',3-3/8" TCP, 6 SPF Tubing (size, grade, and measured depth) Length 200' Size 30" 8. Well mber ~ doubt Unit #5A 9 ermit number 202-168 V 10. API number V 50-733-20513-01 . 11. Field/Pool Redoubt Shoal Oil Field Redoubt Shoal 17 ,000 ft 12,830 ft LLC & Packer at 14,988' Effective depth: measured true vertical 16,575 ft 12,639 ft Junk easured) ~ " ~" ';;?7'~" ' ~V'-~~. >, Measured depth 200' True vertical depth 200' Packers and SSSV (type and measured dept 1/2" tubing set at 14,946' MD (48 jts P-110, 424 jts L-80) Baker FA packer w/ LLC-3 valve set @ 14,988' MD 13. Attachements X Detailed operations program: X BOP sketch: On File 14. Estimated date for commencing opera on 12/5/2004 16. If proposal well verbally approved: 15. Status of well classification as: Oil: X Gas: Suspended: - Name of approver Date approved Service: 17. I hereby certify t~he fore oing is true and correct to the best of my knowledge. Signed: ~, a .. ........,L t:'" , - Title: Production Engineer, Forest Oil FOR COMMISSION USE ONLY Conditions of approval: otify Commission so representative may witness Plug inte ity- BOP Test- Location clearance- Mecha callntegrity Test- Subsequent form required 10- Date: II's}" 3¿::>L/~'-Ib / Approval No. Approved by order of the Commissioner \ r ì. ¡~ ~,~ ~, 1 D\ \ [i.. ~... Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE . Weatherford Forest Oil Cor ) Redoubt Unit ¡, ',. , Prepared For: ~lI.' fed Kramer & Mr. Chuck Wilson Prepared By: Lyle Savage & Mike Gray Date Prepared: 10-7-04 ) Completion & Production Systems " I~ 3-111" 12.9 ppf 81'S-6 Tubing P-I10 ESP Cable Wilh Chemical Injection Line & Gas Vent Tube Pup Joint 6' Length 3-1/2" 1:!.9 ppfBTS-6 P-IIO ---- Weatherlord RIV Sliding Sleeve, Size 3-1/2" With 2.562" WR Proßle 3-112" 12.9 ppf Bl'S-6 Box x Pin Pup Joint tit Length 3-1/1" 12.9 ppfBT8-6 P.IIO One JoiI113-112" 12.9 ppf BTS..6 Tubing P-I10 Chemical Injection Une I ESP Cable I Gas Vent Tube Protector Clamps "r'I~ Packer Top Sub 8' Length:J..I/21t 12.9ppfDTs..6 Dox Up P.110 Gas Vent Line 318" OD x .049" Wall 316 Stainless Steel 3.112" Producdon String ~ -------- Chemical Injection Line 318'1 OD:II: .049" Wan 316 Suinless Steel 3/8" Gal Vent Tube . , ' ~ Cable Connector 100 Amp SKV With 3/C #21\ we Cahle 0 t j ESP Feedthrough :.. . , II Weatherford 'Hydrow II-AP' Dual String Hydraulic Set Retrievable Casing Packer With 3-1/2" 12.9 ppf 318" Cbemicallnjection Line ~A' Bl'S-ó Box J Pin Production String, 100 Amp SKV Integral ESP Power Feedthrough, i=..., Two Eacb 111" NPT Bo.. Pin Gas Vent /Cbemical Injedion Tubes With 40,000 Ib Straight Pull Shur Release 1111 6.672" OD x $.67' LengtbTo Fit 7.518" Z4-Z9.7 ppfCasing Vent I Chemical Injection Tubes With 1/2'" NPl' Pin Down 3-112" Production String Nova Eltg. Velocity Valve ~ 'Nova Engineering 1" OD J. 7.75" Length x 112" :s, PT Velocity Check L iii' j Valves Installed On Chemical Injection And Ga1i Vent Strings . : 0 \- Cabl. Conn...or 100 Amp 5KV Wltb J/C #2A WG Cable ESP Fecdthrough ; .. - . VI;" 'IH' Packer Bottom Sub 6' Length 3-J/2" J2.9 ppf81S-ó Pin Down P-I10 Nova Eng. Velocity Valve -- I :¡ Pump, II Z StageS.IJ" 00 . 23.45' Lengtb ~ Pump JntAke 5.13" 00 %6.21 Length ~,' ',. SeaI5.IJ" 00.6.9' Lengtb ~ Seal5.B" OD x 6.9' Length FOi '~:'. : I i i I rr 1.-- ~. ~- - . 'i :z 0 § u.. ë2 w > Q ...J W u: c::: 0 u.. ~ a.. r.... 0 " tV") q.: ..".. 0 0 N M- 2 One Joint 3-112" 12.9 ppfBl'S,,", l'ubillg P-II0 Pup Joint 6' Length J..1/2" 12.9 ppfBT,5..6 P.l10 - Weatberford RlV Sliding Sleeve. Size 3-112" With 2.562" WR Profile J-In" 12,9 ppfBTs-6 Bo.. Pin Pup Joint 6' Length 3-1/2" 12.9 ppfBTSw6 p-t 10 Minimum One Joint 3-112" 12.9 ppfBTs-ti Tubing P-IIO Cr05S0n:r Sub 3-112" 12.9 ppfBT5-6 Box x ~I/Z" EU 8rd Pin Pres¡.re Head S.!ilt OD x I' Length With 1/4" OD Sensor Line Disdulrgc lJead 5.13" on x 0.5' Length Pumll, 112 Sblge 5.13" on x 23A5' Length Pump, 112 Slage 5.13" 00 x 23AS' Leagth Molor 5.62" OD x 33.85' Lmgtb 418 HP x 98 Amp J: 2.61 KV Sensor 4.5" OD J. 4.2' Lenglh With 114" OD Sensor Line Cenlralizer 6" 00 x 2' LengÛl Wrapped Anode~" 00 J.]' Lenglb Redoubt Unit. \ Completion - November 2002 ~ TOl @ 11290 MD TOl @ 15118 MD Perforations: 15,350' - 15,385' 15,410' - 15,460' 15,560' - 15,600' 15,615' - 15,635' 15,765' - 15,915' 15,950' - 15,960' 16,020' - 16,030' 16,170' - 16,525' 3/8" 6 SPF I ø I I i~ '~ ~ ~ ~ . ; ',~ ï~ Ii" ~ ~ ~ J 'W J ~ ~ ì~ I., ; . ! !! I .' I ~~ ~~ if! ~ ~ :"." ~ t~ry-~~: ; f ", hi" ~ ~" {,J,~:f '4 ~, ....,~.. n ) ~ i II 'I " \j 3 ¡¡. ~ =1 ~ I,' -J; :I :::::t W n ~ ä ~~ ~ 11 'till !t E i= r- ~ !.= ~30" 150 # 13 3/8" 68# \ l A-36 Welded 200 TVD 200 MD l-80 2940 TVD BTC 3190 MD 3 1/2" P-110 Pup 48 jts 31/2" P-110 Tubing 424 jts 3 1/2" l-80 Tubing 95/8" 47# Centrilift ESP Assembly @ 14946 MD llC-3 Valve set in Baker Model FA Packer @ 14988 MD l -80 10065 TVD BTC 11500 MD 7 5/8" l -80 11980 TVD 29.7 # Hydril521 15323 MD Perforations EZ Drill @ 16575 MD 51/2" 17# l-80 12830 TVD Hydril521 17000 MD J FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #5A AFE # 045541 Revision #2 DATE: 11/24/04 ) I. ESP/JET PUMP Install Completion General Information: Existing Casing: 95/8" 47# @ 11,500' MD 75/8" 29.7# @ 15,323' MD, Top of Liner@ 11,29~MD 5 %" 17# @ 17,000' MD, Top of Liner@ 15,118' MD Bottom of ESP Motor: 14,946' MD* Existing Pump Type: LLC-3 Valve set in Baker Model "FA" Packer@ 14,988' MD . 71/GC4100 w/266/KMHU Motor&.:~/KMHL Motor .: Existing LLC Valve: Existing Press. Gauges: Phoenix MS1 Existing Perforations: 48 Joints 3 %" 9.3# P-11 O:árd - 1,498' . 424 Joints 3 %" 9.3# L-80 8r~t~,'.3,2~.7.~\:;;..: . 15,350-15,38~D/11,995-12,01'3'.rvo: . 15,410-15,480' ftI([)/12,027-12,063' T\(D,. 15,550-15,600' MDI12t099-12,125' TVD.'-:' 15,615-15,635' MD/12~'¡~12,145' TVD ':. 15,765-15,915' MD/12,220-12,308'. TVD 15,950-15,960' MI)I1.2,327 -12;333' TVt? 16,020-16,030' MD/1:2~66.-12;,371' TvD.-. 16,170-16,525 MD/12,443712,616' TVD 16,610-1~,~!O' MD/12,~-12,685' TVD " Existing Tubing: Proposed Tubing: 3 %" 12.95# P-11 0 TSN ""1, :":1, . ,'. ~ - ! ~ .) . . , Pho~ix:MSfí ,~..' _: ;~ r.'" . . Proposed Press. Gauges: ProPO/~of~;, ... 14,941;' MD' pro~, Pump Type: . ":'::~.'." ;J-112 ~~.g,e GC2900 with 418 HP KMH Motor *AII MD~;~.ba.sed on the Nab~~ 429 drilliripg with a KB of 90 ft from Mean Low Water(MLW). . . The Kuukpik Ríg#5 has a rig floor hèight of 29 ft. The upper deck height of Osprey Platform above MLW is 60 ft. These measurements nî'aY;?~~d to be ~~,~ed slightly to allow for deck configuration but should be close. Prior to rig up of KUUkPi~:,~.;~.:~U #6 wellbore will be bled down and circulated with produced water. The well has to be on prod*on to perform the no-flow-test. The No-flow test will occur after the well has been placed on production. Rig up Kuukpik Rig #5 1. Notify AOGCC for BOP Test. 2. Set BPV's and nipple down tree. Page 1 of6 12/02/04 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #SA AFE # 045541 Revision #2 DATE: 11/24/04 ) @ 3. Move in and rig up Kuukpik Rig #5 with 13 5/8" BOP stack and test BOP's & rig to 5,000 PSI. Prior to Pulling ESP: Â~ Verify rig is centered over hole. ESP power cable will be damaged if rig is off center òf .hole. A pre job safety/planning meeting will be held prior to pulling the pump and at any crew change to ensure goocfcommunication between all parties on location. A Centrilift representative will be on the rig floor at all times during the pulling of the ESP and will be responsible for ensuring that cable is kept free when setting the slips...,'." " . " , , ~ . ~., ~ NOTE: Install records show that there are 236 ea. Cannon clamps, ~R' 1.25" SS Ban~;.' 7 ea. Unique Protectors, 15 ea. motor flat guards installed in this well. Please keep an accurate counfof the amount pú~tècHrom the well. Pull equipment until a splice is reached and install a new cable ieéJ. Continue pulling equipment while visually im:;pecting the cable and cut at splices. Clean threads, visually inspect and install thread protectors. "';~;'>: " Current install shows 424 joints of 3 %" L-80 -13,237' and 48 joìntsof 3 %':.P~110 -1,498' Equipment installed in the well a.) b.) c.) d.) e.) t.) g.) , h~) . i.) .. ,j.) ,k.) I.). m.) 1. 2. 3. 4. 12102/04 Length(tt) 0.8' 0.5' ~h .' ,.~'. . , OD(in) 'IO(íri)" . . .' ..., ~. : ~ . '. .' ~. i . . PhoefJbc Dis~harge h~ad Disc~~GPI?IS 3.5" S'Rd ,:~nterTandem Pump GC41 00 71 STAGE 'CenterTandem Pump GC4100 71 STAGE Center Tandem Pump GC410071 STAGE ,':.enterTandem Pump GC4100 71 STAGE - Seal'Section GSB3DBUTILH6PFS HSN CL5 Seal Section GSB3DBL TH6 ABHSN CL5 Motor 266 HP 1660/98 KMHU Motor 304 HP 1900/98 KMHL Phoenix MS1 Sensor (4.50" OD at Motor Flange) Centralizer . :.'.:... 3.5"x5.5" --. . 17.65' .;' 5.13". ~.13" 3.5'" . 17~44' .17.44' 17.44,' , 6.88' " -6.89' 22.88' 5.13". ~ 5.13" ,.' . 5.13~ ;, '. '5.13" _. . . .- ' , -, '., 5.13" 5.62" . 25.30' , .,' 5.62'" V' 4.22' 3.75" 2.00' -:'5.85" . . 2.88' , . . '. J" 3.00" Anode Pull out of Hole, Racking back the 3 %" tubing, and laying down ESP Pump/ Motor and reeling up the ESP electrical cable. Make note of any indication of electrical failure on the cable. Pick-up the LLC -3 Auto On / LH Off Retrieving Tool and bumper sub on 3 %" and trip in hole. Latch up in LLC but do not pull it (the retrieving tool will latch up automatically). Shoot fluid level in annulus prior to pulling the LLC valve. Record fluid level. After latch up - utilize bumper sub run above the retrieving tool to locate neutral point. To pull anchor with LLC, pull 2-5K LBS over string weight and rotate 15 turns to the right. Do not exceed the torque value of the tubing. Page 2 of 6 FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #5A AFE # 045541 Revision #2 DATE: 11/24/04 5. Contingency - To release LLC Auto On / LH Off retrieving tool turn to the left while slowly picking up the tubing or work string. 6. Once well has stabilized pull out of hole laying down 3 %" tubing and LLC valve. RIG OPERATIONS NOTES 1. Strap and record the dimensions of each piece of equipment prior to RIH. 2. The Baker Centrilift Representative will be responsible fors,ubinitting to Forest Oil's Company Representative a Complete Tubing Detail to include the following' infonnation: . Number and length of each joint AÆ . . . Any other downhole equipment installed in the tubing' string . Number & location of each clamp . Number of electrical splices and location. ':. . ' . 3. A Centrilift representative must be on location when the. ESP is ambled and when hange;wþenetrations are made. 4. Place cable on the spooler, in an area, o_.':~ direct view of t~ rig operator; make the motor flat splice prior to job commencement.,): '. "'. . " . 5. Confirm that the sheave is 54" in diameter 'and the 'safety cable is attached to sheave. Normal running height shall not exceed 40' above floor. . . :::" . .." ....' ~' 6. NOTE: The flat cable shouldbe hand fed to the floor anci'. the round cable tied off at the floor until the flat round splice is secured to the tûbing,tomìnimize stress on the flaUround splite. . , ... . 7. Do not handle the cabte'spool with sJings in direct contact with the cable. , . 8. Use pre-formed ~Perbands sparinQty to secure the flat ~ble alongside the equipment. 9. Do not allow the tubinQ.to. turnWh~:makin9'''ConnectiOt1S~ or while TIH with the ESP. Back up all connections while TI~;.:"',,' ".," . ", ., -. 1 0. ~~r~'exi~ême Ca~tion t~' ~id ~arring or bending equipment when moving to rig floor. 1 t~:~'hole shall be covered at all tim~:~~en cable bands or clamps are being installed. 12. ~It:f.with ESP no faster thäri:1 iUmin (-1800 ftlhr). Exercise extreme caution when TIH to avoid sudden starts and stÓ~..~hiCh may damage ~~ (especially when setting slips/spider). NOTE: A Hot work permit is requir~.for testing the ESP and cables. 13. Conductivitÿ)ests shall be~'performed on the cable every 2,000 feet while RIH. Note: Conductivity tests have been corrupted,~.oth~r.çook Inlet Platforms due to the Platform cathodic protection system. This system may need to be disablß<j temporarily. Operations shall be immediately shut down and the cable visually inspected and a conductivity t~,tperformed any time a severe pull is noted. 14. While electrical checks are being made, break Circulation through the pump to assure pump is' clear of foreign material. Rate should not exceed 1.5 bpm at 1500 psi. 15. Exercise caution to insure slips will not be set on either the ESP or cable. Damage to the cable will require that the installation is stopped and the cable repaired. Assign one man on the rig floor to be responsible for watching the cable when lowering into well. 16. DO NOT allow the cable to drag across rough edges while TIH. Page 3 of 6 12/02/04 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #SA AFE # 045541 Revision #2 DATE: 11/24/04 ') 17. A Forest representative shall witness free rotation of completely assembled ESP unit on Rig floor. Prior to Running ESP: Verify rig is centered over hole. ESP power cable will be damaged if rig is off c f hole. Layout and strap all equipment. A pre job safety/planning meeting will be held prior to running the pump and at any crew change to ensure good communication between all parties on location. A Centrilift representative, wi.lLbe on the rig floor at all times during the 'running of the ESP and will be responsible for ensuring that cable is k~~:~ ~.',~,;setting the slips. NOTE: It is absolutely essential that all clamps and bands used to install the ESP cabte be counted with a documented location and reported accurately so that there can be no confusion cohœrning the numberof:bands in the well if the completion needs to be pulled in the future. Schematics of all clamps will be included with 'the Checklists and count. ". . ~,' 1. Exercise caution when handling the seal, motor and pumps sections to minimize bending:'.> Use at least two lift points when moving horizontally. Equipment shall be moVed in boxes at aJHimes until on the cat'vyalk. 2. ALL ESP AND CABLE movement shall be witnessed and approved by Céntrilift Service rep. 3. Motor, seal and pump boxes shall be supported by three eQUá1ly spaced rests or on a flat surface whenever in storage or shipment. . " 4. Move the pump, motor and seal sections up.to rig in'd~~u:aIlY. ;~ l . . , "t..- ~ t '" :'".' . 'J" ': . ~. '''-. , " ..' . ,.' . , '. " ... .. " . -. ~~~ ~.~~', ~ .~ ..":i . /~ . .' , "." <. w, . .., " '. . . . ," -... f_' .~. l .. -", ',': .' ," ,,- Page 4 of 6 12/02/04 ') FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #5A AFE # 045541 Revision #2 DATE: 11/24/04 ) ESP RUNNING PROCEDURE Bottom Hole Assembly consists of the following: Length(ft) a.) b.) c.) d.) e.) f.) g.) h.) i.) j.) k.) I.) m.) n.) 0.) p.) q.) r.). ...~'m... : S~) t.) '> ". u.) v.) w.) . x.) 3.00' 2.00' 4.20' 33.85' 6.9' 6.9' 23.45' 23.45' 23.45' 0.50' 1.00' 1.00' OD(in) ID(in) 3.00" 6.00" 4.50" 5.62" 5.13" 5.13" 5.13" Anode Centralizer Phoenix MS1 se,nsor :(4~.50" DD at Motor Flange) Motor 418 HP 2610198 KMH .. ,'~. . . . . Seal Section GSB3DB EHLH6ABHUKPFSAMNLL T Seal Section"GSB3DB EHLH6ABHUKPFSAMNLUT Lower Tandem Pump GC2900 112 STAGE wI Inconel Shaft'i-" '. .: . ~ '. .'. , 5.13" Cent~:Ta.ndem"p'.~~p'GC2900 112 STAGE wI Monel Shaft 5.13" UpperTa~~m Pump GC2900 112 STAGE wI Monel Shaft 5.5"X3.5A>A1&&- Discharge 'G~~IS 3.5" 8 Rd 5.5" . - ::.' ':: Pressure Head ';;'. '. 3.5" .. . . - I,' -:." -- '. Cross over Sub 3.5",12.9 # B1S-6 box to 8rd Pin . . . . ' 30.00' dAZøw~.5" 2.75'" 1- J~~.~.~ of Tubi~g. 12.9 #' BTS-6 10.00'. '3.5" , 2.75" , Pup Joint 3.5" 12.9 # BTS-6 3.20' 5" 2.562" Weatherford RIV(Sliding Sleeve) wI 2.562 R profile :6.00' 3.5".' 2.75" Pup Joint 3-1/2" 12.9# BTS-6 30.00' ,,~.~5~..' - .. : ~!~".., 1- Joi:ptofTubing 12.9 # BTS-6 12.00.'>' ., '.3..5" 2.75".' Plip Joint 3-1/2" 12.9# B1S-6 . . . 8.27' <" 7 5I8"X 3-1/2" X 1.9" Weatherford Hydrow 11- Dual $tring Packer 12.~~' .: 3.571 2.75" Pup Joint 3-1/2" 12.9# BTS-6 30.00".' 3.5" '. 2.75" 1- Joint of Tubing 12.9 # BTS-6 10.00' ',' 3.5" 2.75" Pup Joint 3-1/2" 12.9# BTS-6 3.2' . '3.5" 2.13" Weatherford RIV(Sliding Sleeve) wI 2.13 X profile .:, ,,6.0~:::.. ."..': :' ':: 3.5" 2.75" Pup Joint 3-1/2" 12.9# BTS-6 , "'." ~ . ..: Note: 7 5/8"" Liner top¥¡ 11,290' MD 1. Pick up the 418 Hp ESP motor (33.85') and attach the Phoenix MS1 (4.20') to the bottom with the Unique Stand-off attached to the bolts at 180 deg opposite the motor pothead terminal. Screw a centralizer (2.0') into the bottom of the Phoenix MS1. Attach anode to centralizer (3.0'). This assembly will be 43.05' in length. 12/02/04 Page 50f6 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE -Redoubt Unit #5A AFE # 045541 Revision #2 DATE: 11/24/04 ) 2. Slowly lower the motor assembly into the well and lower lifting clamp onto the wellhead slips. Assemble the seal (13.8') and lower assembly onto the motor. Line up assembly alignment marks at the seal. 3. Service the seal and the motor as per standard servicing procedures as outlined in the Baker Centrilift Technical. Service Manual. 4, 4. Attach the motor flat as per standard procedure and attach the proper Unique protection clamp at the lower flange of the Seal section. ' . . . ,: '" 5. Continue installing into the well with the lower pump, center pump and the. upper pump and Phoenix discharge pressure head attaching Unique clamps & guards to secure the ~uipment. '.' .< >. ." 6. Do not allow the tubing to turn while making connections or while TIH with the ESP; Back up all connections while TIH. '.. , 7. Install cross over form 8rd to BTS-6 on top of Phoe.nix discharge pressure head. 8. Run in hole with one joint of 3 %" 12.95# P-110 BTS-6tubing. ; . . . ~, , . , 9. Recommended torque values for 3-1/2" 12.95#/ft P-110 BT~ ~:.'. "M~,nimum = 7,OO~.ft-lb. ~xìmum = 8,800' ft-lb. 10. Pick -up Weatherford RIV sliding sleeve with 2.562'R Profile with a 10" pup below and a 6' pup above and run inhale. ..' . .' . . . ' 11. Run in hole with one joint of 3~".12.95# P-110'BTS-6 tubing. 12. Pick-up Weatherford Hydrow 11- dual string packe cable will be pig taHed and ready foradditional coni connections with Box by Pin conneCtion. Make con injection lines belowt!1e..~ack7-~r~~:)" '...< . Jh 12'pups above and below. A BIW feed through power . n above and below the packer. There are two %" NPT n of the NOVA Double Check valves to the chemical 13. Ru~ öne jq~t'~ ~.,~" 12..95tf;:. p- ~ '1 0 BTS-6 ab~~~~ttWn-win Seal Packer. . . '8',:.), : ,,,,,,..... 14. .Pick -up Weatherford R-IV sliding sleeve with 2.562" R Profile with a 10' pup below and a 6' pup above and run :. ::.'.,.fn hole. ..' :' .~. . "",.;, . .;, 15."~Run in hole with 3-1/2" ~'2:.95# P-110:iJfs-6 Production Tubing as required for ESP setting depth. The bottom of ESP motor at plus or miryuS 14,946' MD. Conductivity tests shall be performed on the cable every 2,000 feet while Rlti.. .'.'. ~ ~-~- ': ...:.... H" 16. Run in hole .~ plug .orfwireline to set in bottom sliding sleeve, pressure up on it and the packer will set it. 17. Place 20,000 Ibs ~ (in compression) on the packer. This weight is needed for the future operations of the Jet Pump. 18. Place one drum of Baker packer fluid on the backside of well. 19. Tubing hanger with 3-1/2" 12.95# P-110 BTS-6 pup joint, ESP power cable Penatrator, CAP Tube penetrator. Page 6 of 6 12/02/04 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #5A AFE # 045541 Revision #1 DATE: 10/28/04 ) ESP/JET PUMP Install Completion I. General Information: 95/8" 47# @ 11,500' MD 75/8" 29.7# @ 15,323' MD, Top of Liner@ 11,290' MD 5 %" 17# @ 17,000' MD, Top of Liner@ 15,118' MD Existing Casing: Bottom of ESP Motor: 14,946' M D* LLC-3 Valve set in Baker Model "FA" Packer@ 14,988' D Existing LLC Valve: I 'II 71/GC4100 wI 266/KMHU Motor & 304/KMHL Motor Existing Pump Type: Phoenix MS1 Existing Press. Gauges: 48 Joints 3 %" 9.3# P-11 0 8rd - 1,498' 424 Joints 3 %" 9.3# L-80 8rd - 13,237' Existing Tubing: .... '\\, \'1~;). '7--5~~~ ~ 15,350-15,385' M D/11 ,995-12,013' TVD 15,410-15,480' MD/12,027-12,063' TV 15,550-15,600' MD/12,099-12,125' 15,615-15,635' MD/12, 134-12, 145' D 15,765-15,915' MD/12,220-12,30 TVD 15,950-15,960' MD/12,327-12,3 ' TVD 16,020-16,030' MD/12,366-12 71' TVD 16,170-16,525 MD/12,443-1 ,616' TVD 16,610-16,670' MD/12,657.'-12,685' TVD Existing Perforations: Proposed Tubing: Phoenix MS1 Proposed Press. Gauges: Proposed Bottom of ESP: 14,946' M D* GC2900 with 418 HP KMH Motor Proposed Pump Type: Ive set in Baker Model "FA" Packer @ 14,988' MD Proposed LLC Valve: *AlI MD are based on the Nabors 4 drilling rig with a KB of 90 ft from Mean Low Water(MLW). The Kuukpik Rig #5 has a rig floor eight of 29 ft. The upper deck height of Osprey Platform above MLW is 60 ft. These measurements may need to be é:!justed slightly to allow for deck configuration but should be close. Prior to rig up of Kuukpik Ri #5, the RU #5A wellbore will be bled down and circulated with produced water. Rig up Kuukpik Rig 1. Notify AOGC for BOP test. 2. MIRU Kuuk . Rig #5. 3. Set BPV a nipple down tree. N/U 13-5/8", 5K BOP stack and test. Page 1 of6 11/18/04 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #5A AFE # 045541 Revision #1 DATE: 10/28/04 ) Prior to Pulling ESP: Verify rig is centered over hole. ESP power cable will be damaged if rig is off center hole. A pre job safety/planning meeting will be held prior to pulling the pump and at any crew change to ensure goo communication between all parties on location, A Centrilift representative will be on the rig floor at all times dur' 9 the pulling of the ESP and will be responsible for ensuring that cable is kept free when setting the slips. NOTE: Install records show that there are 236 ea. Cannon clamps, 46e 1.25" SS Bands, 7 ea. Unique Protectors, 15 ea. motor flat guards installed in this well. Please keep an accurate cou of the amount pulled from the well. Pull equipment until a splice is reached and install a new cable reel. ontinue pulling equipment while visually inspecting the cable and cut at splices. Clean threads, visually inspect and in all thread protectors. Current install shows 424 joints of 3 Yo" L -80 - 13,237' and 48' ints of 3 y." P-1 ~-~8' Equipment installed in the well <::þJfE: \C.ecßd Length(ft) OD(in) ID(in \J-()- a.) 0.8' 3.5"x5.5" --- Phoenix Discharge head b.) 0.5' 5.13" Discharge GPDIS 3.5" 8 Rd c.) 17.65' 5.13" Center Tandem Pump GC41 00 71 STAGE d.) 17.44' Center Tandem Pump GC4100 71 STAGE e.) 17.44' Center Tandem Pump GC41 00 71 STAGE f.) 17.44' Center Tandem Pump GC41 00 71 STAGE g.) 6.88' Seal Section GSB3DBUTILH6PFS HSN CL5 h.) 6.89' Seal Section GSB3DBL TH6 ABHSN CL5 i.) 5.62" Motor 266 HP 1660/98 KMHU j.) 5.62" Motor 304 HP 1900/98 KMHL k.) 3.75" Phoenix MS1 Sensor (4.50" OD at Motor Flange) I.) 5.85" Centralizer m.) 3.00" Anode 1. , racking back the 3 %" tubing, and laying down ESP pump/motor and reeling up the ESP electrical note of any indication of electrical failure on the cable. RIG OPERATIONS NOTES 1. Str and record the dimensions of each piece of equipment prior to RIH. 2. Th ""Saker Centrilift Representative will be responsible for submitting to Forest Oil's Company Representative a Complete Tubina Detail to include the following information: Page 2 of 6 11/18/04 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #5A AFE # 045541 Revision #1 DATE: 10/28/04 . Number and length of each joint . Any other downhole equipment installed in the tubing string . Number & location of each clamp . Number of electrical splices and location. 3. A Centrilift representative must be on location when the ESP is assembled and made. 4. Place cable on the spooler, in an area that is in direct view of the rig oper r; make the motor flat splice prior to job commencement. 5. Confirm that the sheave is 54" in diameter and the safety cable is ached to sheave. Normal running height shall not exceed 40' above floor. 6. NOTE: The flat cable should be hand fed to the floor and the ound cable tied, off at, the t\ ut,r, ,u~, ',',', il the flat""round splice is secured to the tubing to minimize stress on the flat/r nd splice. ~c..cJ r;)-. 7. Do not handle the cable spool with slings in direct contac ith the cable. SJf)êJ1JtJ. 1>- 8. Use pre-formed Superbands sparingly to secure the fI cable alongside the equipment. 9. Do not allow the tubing to turn while making co ections or while TIH with the ESP. Back up all connections while TIH. 10. Exercise extreme caution to avoid jarring or ending equipment when moving to rig floor. 11. The hole shall be covered at all times wh cable bands or clamps are being installed. 12. TIH with ESP no faster than 1 itJmin ( 00 ftJhr). Exercise extreme caution when TIH to avoid sudden starts and stops which may damage cable (es cially when setting slips/spider). 13. Conductivity tests shall be perfo ed on the cable every 2,000 feet while RIH. Note: Conductivity tests have been corrupted on other Cook let Platforms due to the Platform cathodic protection system. This system may need to be disabled tempo~ Ily. Operations shall be immediately shut down and the cable visually inspected and a conductivity test peri med any time a severe pull is noted. 14. While electrical checks e being made, break Circulation through the pump to assure pump is clear of foreign material. Rate should ot exceed 1.5 bpm at 1500 psi. 15. Exercise caution to nsure slips will not be set on either the ESP or cable. Damage to the cable will require that the installation is topped and the cable repaired. Assign one man on the rig floor to be responsible for watching the cable whe owering into well. the cable to drag across rough edges while TIH. 17. A Forest presentative shall witness free rotation of completely assembled ESP unit on Rig floor. Verify ig is centered over hole. ESP power cable will be damaged if rig is off center of hole. Layout and strap all equi ment. A pre job safety/planning meeting will be held prior to running the pump and at any crew change to ensure go d communication between all parties on location. A Centrilift representative will be on the rig floor at all times during t running of the ESP and will be responsible for ensuring that cable is kept free when setting the slips. Page 3 of 6 11/18/04 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #5A /~'/" g . AFE # 045541 Revision #1 /" DATE: 10/28/04 NOTE: It is absolutely essential that all clamps and bands used to install the ESP cab be counted with a documented location and reported accurately so that there can be no confusion concerning the n mber of bands in the well if the completion needs to be pulled in the future. Schematics of all clamps will be inclu ed with the checklists and count. 1. Exercise caution when handling the seal, motor and pumps sections t minimize bending. Use at least two lift points when moving horizontally. Equipment shall be moved in boxes all times until on the catwalk. 2. ALL ESP AND CABLE movement shall be witnessed and approved y Centrilift Service rep. 3. Motor, seal and pump boxes shall be supported by three equal spaced rests or on a flat surface whenever in storage or shipment. 4. Move the pump, motor and seal sections up to rig individually ESP RUNNING PROCEDURE (\ C\ I.?>- ~ St~c<:è) f:>- I Bottom Hole Assembly consists of the followin : a.) b.) c.) d.) e.) f.) g.) h.) i.) j.) k.) I.) m.) n.) 0.) p.) q.) r.) .) .) u.) 11/18/04 Length(ft) OD(in) 3.00' 3.00" 2.00' 6.00" 4.20' 4.50" 33.85' 5.62" 6.9' 6.9' 23.45' 23.45' 23.45' 5.5"X3.5" --- 5.5" 3.5" 3.20' 6.00' 30.00' 12.00' 8.27' 12.00' 30.00' Centralizer Phoenix MS1 Sensor (4.50" OD at Motor Flange) Motor 418 HP 2610/98 KMH Seal Section GSB3DB EHLH6ABHUKPFSAMNLL T Seal Section GSB3DB EHLH6ABHUKPFSAMNLUT Lower Tandem Pump GC2900 112 STAGE wI Inconel Shaft Center Tandem Pump GC2900 112 STAGE wI Monel Shaft Upper Tandem Pump GC2900 112 STAGE wI Monel Shaft Discharge GPDIS 3.5" 8 Rd Pressure Head Cross over Sub 3.5" 12.9 # BTS-6 box to 8rd Pin 3.5" 2.75" 1- Joint of Tubing 12.9 # BTS-6 3.5" 2.75" Pup Joint 3.5" 12.9 # BTS-6 5" 2.562" Weatherford RIV(Sliding Sleeve) wI 2.562 R profile 3.5" 2.75" Pup Joint 3-1/2" 12.9# BTS-6 3.5" 2.75" 1- Joint of Tubing 12.9 # BTS-6 3.5" 2.75" Pup Joint 3-1/2" 12.9# BTS-6 7 5/8"X 3-1/2" X 1.9" Weatherford Hydrow 11- Dual String Packer 3.5" 2.75" Pup Joint 3-1/2" 12.9# BTS-6 3.5" 2.75" 1- Joint of Tubing 12.9 # BTS-6 Page 4 of 6 ') FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #5A AFE # 045541 Revision #1 DATE: 10/28/04 ') v.) 10.00' 3.5" w.) 3.2' 3.5" x.) 6.00' 3.5" 2.75" Pup Joint 3-1/2" 12.9# BT5-6 2.13" Weatherford RIV(5liding 51 ve) wI 2.13 X profile 2.75" Pup Joint 3-1/2" 12.9# B 5-6 Note: 75/8"" Liner top at 11,290' MD (\ C\ þ . ~¥\«:~ /> 1. Pick up the 418 Hp ESP motor (33.85') and attach the Phoeni S1 (4.20') to the bottom with the Unique Stand-off attached to the bolts at 180 deg opposite the moto othead terminal. Screw a centralizer (2.0') into the bottom of the Phoenix MS1. Attach anode to centraliz (3.0'). This assembly will be 43.05' in length. 2. Slowly lower the motor assembly into the well and low lifting clamp onto the wellhead slips. Assemble the seal (13.8') and lower assembly onto the motor. Line up sembly alignment marks at the seal. 3. Service the seal and the motor as per standard rvicing procedures as outlined in the Baker Centrilift Technical Service Manual. 4. Attach the motor flat as per standard proce re and attach the proper Unique protection clamp at the lower flange of the Seal section. 5. Continue installing into the well with th ower pump, center pump and the upper pump and Phoenix discharge pressure head attaching Unique clam s & guards to secure the equipment. 6. Do not allow the tubing to turn who e making connections or while TIH with the ESP. Back up all connections while TIH. 7. Install cross over form 8rd to B -6 on top of Phoenix discharge pressure head. 8. Run in hole with one joint of Y2' 12.95# P-110 BTS-6 tubing. 9. Recommended torque val es for 3-1/2" 12.95#/ft P-110 BTS-6 are: Minimum = 7,000 ft-Ib. Maximum = 8,800 ft-Ib. 10. Pick -up Weatherfor RIV sliding sleeve with 2.562 R Profile with a 10' pup below and a 6' pup above and run in hole. 11. Run in hole with ne joint of 3 Y2' 12.95# P-110 BTS-6 tubing. 12. Pick-up Wea erford Hydrow 11- dual string packer with 12'pups above and below. A BIW feed through power cable will b pig tailed and ready for additional connection above and below the packer. There are two Y2' NPT connectio with Box by Pin connection. Make connection of the NOVA Double Check valves to the chemical injection' es below the packer. 13. Run 0 joint of 3 Y2' 12.95# P-110 BTS-6 above the Twin Seal Packer. 14. Pick up Weatherford RIV sliding sleeve with 2.562" R Profile with a 10' pup below and a 6' pup above and run in Ie. Page 5 of 6 11/18/04 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #,SA AFE # 045541 Revision #1 / DATE: 10/28/04 ) 15. Run in hole with 3-1/2" 12.95# P-110 BTS-6 Production Tubing as r uired for ESP setting depth. The bottom of ESP motor at plus or minus 14,946' MD. Conductivity tests sh be performed on the cable every 2,000 feet while RIH 16. Run in hole with plug on wireline to set in bottom sliding sle e, pressure up on it and the packer will set it. 17. Place 20,000 Ibs weight (in compression) on the packe . This weight is needed for the future operations of the Jet Pump. 18. Place one drum of Baker packer fluid on the bac Ide of well. 19. Tubing hanger with 3-1/2" 12.95# P-110 BTS- pup joint, ESP power cable Penatrator, CAP Tube penetrator. 20. Set BPV, N/D BOPE, N/U and test tree. elease rig. (\ <\ { :;>. ~~cJ (; Page 60f6 11/18/04 ) ) ~ FOREST OIL CORPORATION June 21, 2004 /i 1 0 dYC dll}((?Æt. cJ;llu;te 700 Q.Qt;~cho}r.allÆ -' Q.9(¿a~ka .9<9/;01 (907) 258-8600 . (.907) 258-8601 (Œøaæ) ~~~ I (q~ EIVE JUN 2 1 2004 & Mr. John Nonnan, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: RU #5A ESP Repair Dear Mr. Norman, The Electric Submersible Pump (ESP) in the Redoubt Unit #5A well has failed. Forest Oil plans to use a Cudd Hydraulic Unit to pull the ESP assembly and run a new assembly as outlined in the attached summary repair procedure. Attached please find a completed Form 10-403 for the work, a request for waiver of a specification in 20 AAC 25.035(e)(4)(H), a current wellbore schematic and a BOP configuration diagram for the hydraulic unit to be used. If you have any questions, please contact me at 868-2135 or Bill Penrose at Fairweather at 258-3446. Sin¡zerel , ~/ '. ! ~ Paula Inman Production Engineer Forest Oil Corporation Attachments: 10-403 Application for Sundry Approvals Outline Procedure Wellbore Schematic - RU #5A 13-5/8" 5M BOP Schematic Snubbing Circulation Schematic Snubbing Equipment Layout OR1G1NAL Pcb {, (¿rt-{ t:L Ý- ) STATE OF ALASKA) .' ~ /ð-,\ ALASKA OILAND GAS CONSERVATION COMMISSI<RE APPLICATION FOR SUNDRY APPROVALS JUN'2 7004 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: - Repair well: - Plugging: - - Time extension: - A\~,W!~1EE\ - ", '. Change approved program: Pull tubing: X Variance: Perforate: Other: B~p~if;E$P 5. Type of well: 6. Datum elevation (DF or KB) Development: ..2S.. Exploratory: Stratigraphic: Service: 2. Name of Operator Forest Oil Corporation. 3. Address 310 K Street, Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 1909' FSL, 318' FEL, Sec. 14, T07N, R14W, SM At top of productive interval 1058' FSL, 288' FWL, Sec. 19, T07N, R13W, SM At effective depth 40' FSL, 1361'FWL, Sec. 19, T07N, R13W, SM At total depth 40' FSL, 1361' FWL, Sec. 19, T07N, R13W, SM 12. Present well condition summary Total depth: measured true vertical 90' MSL feet 7. Unit or Property name Redoubt Unit 8. Well number Redoubt Unit #5A 9. Permit number/ 202-168 ,/ 10. API number/ 50-733-20513-01 11. Field/Pool Redoubt Shoal Oil Field Redoubt Shoal 17,000 ft 12,830 ft Plugs (measured) LLC & Packer at 14,988' Effective depth: measured true vertical 16,575 ft 12,639 ft Junk (measured) N/A Casing Structural Cond uctor Surface 3,190' 13 3/8" Surface 3,190' 2,940' Intermediate 11,500' 95/8" 1,286 cu ft 11,500' 10,065' Drilling Liner 4,033' 7-5/8" 252 cu ft 15,323' 11,980' Production Liner 1,882' 5-1/2" 314 cu ft 17,000' 12,830' Perforation depth: Measured Depth: 15350'-15385', 15410'-15460', 15560'-15600', 15615'-15635', 15765'-15915', 15950'-15960', 16020'-16030', 16170'-16525',3-3/8" TCP, 6 SPF TVD: 11995'-12013', 12027'-12052', 12104'-12125', 12134'-12145', 12220'-12308', 12327'-12333', 12366'-12371', 12443'-12616', 3-3/8" TCP, 6 SPF Tubing (size, grade, and measured depth) Length 200' Size 30" Cemented Driven Measured depth 200' True vertical depth 200' 31/2" tubing set at 14,946' MD (48 jts P-110, 424 jts L-80) Packers and SSSV (type and measured depth) Baker FA packer w/ LLC-3 valve set @ 14,988' MD 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 7/1/2004 16. If proposal well verbally approved: 15. Status of well classification as: Oil: X Gas: Suspended: - Name of approver Date approved Service: 17. I hereby ce"at t~~ fore9jing is true and correct to the best of my knowledge. Signed: n~~-=P~ Title: Production Engineer, Forest Oil FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so repre~9Jitive may witness Plug integrity- BOP TestA- Location clearance- Mechanical Integrity Test- Subsequent form required 10- Y 0 L~ Date: ~/~'1' I Approval No. J 3o'i-'~3{P ~~,,,~ \ ~"Ç,)~~ ~~~\ì\.~ ..., (;"P\ , ~ J ,"-'''-' r ~. M.ê:ì '-v Approved by order of the Commissioner - d(j~~~d-~ «)'Sç~~\\.\) Ç;> .\ês. ''\ BFL JUN 2 9 2004 JIJN ~at~ ~tJI'f SUBMIT IN TRIPLICATE fIbts 8Ft Commissioner Form 10-403 Rev 06/15/88 nQIG\NAL ) ) Redoubt Unit #5A - ESP Repair Outline Summary 1. Bleed off gas head in tubing and annulus. 2. Fill tubing and annulus with produced water. 3. Nipple Down 3-118" production tree. 4. Nipple up 13-5/8" 5M riser and 13-5/8" 5M BOP stack. Test BOPs to 3,000 psi. 5. Rig up Snubbing Unit on RU #5A. 6. Pull 3" BPV. 7. Pull tubing hanger and 3 'l'í" ESP Completion. 8. Run new 3-'l'í" ESP Completion. 9. Set 3" BPV in tubing hanger. 10. Nipple down 13 5/8" BOPE and riser. 11. Nipple up and test 3-118" production tree. 12. Pull BPV. 13. Turn over well to production crew. ) ') REQUEST FOR WAIVER RU #5A ESP Repair Forest Oil plans to use a Cudd 340K Hydraulic Pulling Unit to pull the failed ESP assembly in Well RU #5A and run a new assembly. While the BOP system associated with this hydraulic unit mainly conforms to the specifications set out in the Commissions regulations, the choke and kill part of the system differs slightly and a waiver is requested to enable the system's use as is. At variance with 20 AAC 25.035(e)(4)(H) is that the unit does not have a remotely controlled hydraulic choke. Choke operation on this unit is via two redundant, manually operated chokes located at the choke manifold. It is Forest Oil's position that the unit's choke and kill system as currently configured is sufficient for work on RU #5A and similar wells on Osprey Platform due to the under- pressured character of the reservoir. RU #5A is currently dead with only crude oil and produced water in the wellbore. Before commencing the planned ESP replacement work, the well will be displaced with produced water and Forest Oil will ensure the LLC valve functions and the well remains full. The chance of any pressure being observed at the surface is extremely remote and, even if it did occur, it would be of such low pressure and volume that the existing BOP system could handle it safely. Forest Oil therefore requests a variance from the specification of 20 AAC 25.035(e) (4 ) (H) to utilize the choke and kill system configured as described above and on the attached BOP system configuration diagram for the hydraulic unit to be used. \.) 'S <L a \- CJ~ \"l kG," '--'Q" J,,-'G \'¿f5 \:>..)G-'S Q ~ ? '\t)'.J ~ .\-0 \+-\'CL' Q\..J~~, ~~D~~~\ ~~'" dfJ~~C~S:, () ~ ç ( \,) ~ \) ~ (p l }~ Redoubt Unit ~,.)A Completion - November 2002 .. TOL @ 11290 MD TOL @ 15118 MD Perforations: 15,350' - 15,385' 15,410' - 15,460' 15,560' - 15,600' 15,615' - 15,635' 15,765' -15,915' 15,950' - 15,960' 16,020' - 16,030' 16,170' - 16,525' 3/8" 6 SPF ~ ,~: ~. ;..~ ~ ~ . . lilt " ¥ p . , t. 1;. ~ ~¡ t""':.M"'-..'".'f:,,.',"":, í' '- ", ",. ~~ .~.. ... J; ~K ~ ~ i' J~ I> (~ ~"' ~: ) ).; ;'\~ ~ ~~ ": II' .;y ~30" 150 # 133/8" 68# ) A-36 Welded 200 TVD 200 MD L -80 2940 TVD BTC 3190 MD 3 1/2" P-110 Pup 48 jts 3 1/2" P-110 Tubing 424 jts 3 1/2" L-80 Tubing 95/8" 47# Centrilift ESP Assembly @ 14946 MD LLC-3 Valve set in Baker Model FA Packer @ 14988 MD L-80 10065 TVD BTC 11500 MD 75/8" L-80 11980 TVD 29.7 # Hydril521 15323 MD ~ ~ =¡ .,- Perforations -. ~~ ; ---!" ~...- -, ~e: - - 3 =; ~- :=!~" .', F ~ ":,:'" "- ; "',' : l~. EZ Drill @ 16575 MD 51/2" 17 # L-80 12830 TVD Hydril521 17000 MD ) IIcuiiP _~~E»rmLJf ~ ToKdJey FI ..." f "':',,:~~ ,',,' , 1 i r.,',',',; '¡JfI,':],ril ".~ ,".~. "..1. í I " "',- ';: :,;,tdp;.. Þt"d¡""~1I +,:'1, " '" .I"','~,'-' \\... ,/ 11 ... ¡ ". . . l " . . , , , . 3-1,z' H1-6 TtbÌJg ,i, 2'l:D2Wa:o ~ Ii 1 OPO~g mIX i I rwr II Ir'tr1nl O,--ll J ,- ''<\" ~~r<;'f.&;, I Il i J II ~l . I -.- .~~~~ ~,' '.' ".....~(õ-:{,~ ./'/' .........." .,.~/ Pump Manifold BleedŒLille 2-1/16" 3m:, ~~~~ ~\ I KmU.c. "~ :~ ~. MDWUJ1Chok ..f:h~' ~ LbW; : ~ ..At~~ I,~ - '¡¡-II' L- 211D~1I1e H.1:e . [ ~~JlIL"",. ' I'L (fJiJ8. í4 'I I, ..- - 1'" 2' "°211"" ". t '"-fI I.. . \ 0'1 ~ 8,ooOps mIX I \ J 1 '.L¡;i Po , , , 2'II1"IDIIM~~, I '~ ~ t,:, 2-1/16'IDIO~1 .,/ ..,.~ooges 1O,OOOR;¡ ~ , ILb- - § I _.n!¡OOJ"''''''./ "'" J \ ~~ ~ J" ,." '. Manual Choke Choke LJ~ :ti:: I / I.' . " Manifold 2-1/16" 3m f'DL t--..> 2' GJcuhte HJæ j ,,-- _i~~~___L_, ,',. ') FoIeSt QI Alaska Cudd Presslre Corfrol, Inc. Propœed Ri~ pllluSratio n Wth Rcnge; & arc. Hoæs 8 ,Jure 04 rev1,noscale M.tdflls / SffJ(Talor . . 'I!II' cm~J 340k Jack Unit Lift Cap:340,000 Snub C~: 170,000 Rotary Cap: 9,700 ftJ]bs 11" Bore II ') ~ 1m ~r'l œ ¡ ,~lUL ,> J, >;~~j;tki~j~.....~~mU!f ".' ¡ II r.~mÞl!,"I-' "" II m " /'1"--, ... -'78- J,m ... ~jJ 1 I '~I ~]D~ '~- 'Bl( ~ ~ ::::~ ;",>:.. /. <.~ "11t.'"";':::"':¡,:- ::::::: J ~ II I . - ,II IlL-' "":~F;; . '.,.:.~?< ,.. > ~" I~O+ W~co Fill Line 288" Snuh Llnll ...'\: Work Ba.s.;el ----' ---.-- Ele\'Jnon 888 55"17~ O~') , 1.10.8" Work Window Elö:Hlon 696.55" ¡'58 O..r) 29" 30.75" .." Flow Lme 10 1I.1ud Pll~ \\Jth G:J<; Delò':lor & Flow r,.~IP.J, 55.0" Ele\ allon 6(155"(576~') ---- 550" 60" " I¡- ..8" ^ 72" Elevation 192" (I 6') 120" I . y v ........._.~,-,----"._, 3c''' Bc¡¡m T Pp De.'k Tn" r\.>...1,. ......,..-......." Bottom Deck ') Forest Oil Alaska . Cudd Pressure Control, Inc. Proposed Rigup Illustration Without Rig on Location 8, June 04 rev 1, no scale 340k Jack Unit 13-5/8" 5M BOP Stack S\\ ¡vel Spool 1)..5/8" 5M Drilling Spool \3-5:8" 51\.1 Annular BOP, 13..5 8" 51\1 3-1/2"Plpe Ram. 13-S:8" 51\1 Bhnd'Shear Ram, 1)-5:'8" 51\1 5' Spool, 13-5/8" 51\1 ~'Spool. 13-5;8" 51\1 I __I 6' Spool, 13-5/8" 5M 10' Spool, 13-5/8" 5M Bottom Deck WelI Head ~~, u ) Forest Oil Corporation Alaska Division 310 K Street, Suite 700 Anchorage, Alaska 99501 Phone: (907) 258-8600 Fax: (907) 258-8601 DATA TRANSMITTAL To: Lisa Weepie/Howard Oakland AOGCC 333 W. 7th Ave, Suite 1 00 Anchorage, AK 99501 (907) 279-1433 From: Linda M. Starr C)Cß -Œi3 )f)o/9- J(b~ , RECEIVED APR 2 32003 Alaska oa & Gas Cons~ Commission Anchorage Date: April 23, 2003 Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Phone: (907) 868 - 2162 FAX: (907) 258 - 8601 Phone: TRANSMITTAL DESCRIPTION: Well data for Redoubt Unit #5 and# 5A wells, API#50-733-20513-00 and #50-733-20513-01 Qty Description Bottom Top Depth Log Date Run# Scale depth (feet) (feet) ~ Redoubt Unit #5, API #50-733-20513-00, Schlumberger logs: Array Induction Dipole Shear Sonic, Platform Express 08/09/02 2" &5" 15,452' 13,760' ~Q -" Array InductionlDensity/Neutron/GR, Caliper, PEX 08/09/02 2" &5" 15,452' 13,760' ~ BeslOT" Final Result (PEXlDSI/NGT, CMRlECS, UBI) 08/11/02 5" 15,489' 13,564' lo.s..~ Break-Out Run 1 08/16/02 5" 15,394' 13,844' ~9.... Caliper Log (i i ~ s:.._~ 08/09/02 5" 15,452' 13,760' ~. Casing Packer Setting Tool 08/14/02 5" 15,459' 13,760' ~ CMR, DMRP + BINS 08/10/02 5" 15,367' 13,711' ~ Combinable Magnetic Resonance Tool 08/09/02 5" 15,459' 13,760' ~iPole Shear Sonic Tool, Image Log 08/09/02 5" 15,452' 13,760' log - ECS Spectrolith, TCOM + CMR Display 08/10/02 5" 15,367' 13,760' Z'. ELAN Composite 08/10/02 5" 15,360' 13,760' ~. ELAN w/ ECS-CMR 08/1 0/02 5" 15,350' 13,763' . 110g- Elemental Capture Spectroscopy Sonde c\ 08/09/02 5" 15,459' 13,760' ~. Natural Gamma Ray Tool (I J-!..\cC ç:, '. 08/09/02 5" 15,452' 13,760' ~ Repeat Formation Tester 08/09/02 15,190' 14,485' , log " UBI Dip Analysis (1 :240) 08/09/02 5" 15,396' 13,844' I~ UBI Dip Analysis (1 :48) 08/09/02 25" 14,620' 13,844' ~ UBI Dip Analysis (1 :48) 08/09/02 25" 15,396' 14,619' . 10a......-11ltra Sonic Borehole Imager 08/09/02 5" 15,400' 13,800' v1Íog Ultra Sonic Imaging Tool 08/11/02 5" 13,746' 10,261' vffiím Array Induction Dipole Shear Sonic, Platform Express 08/09/02 1 2" &5" 15,452' 13,760' v1'fiÍrt:l Array InductionlDensity/Neutron/GR, Caliper, PEX 08/09/02 1 2" &5" 15,452' 13,760' Z-caliPerLOg 0~ 08/09/02 1 5" 15,452' 13,760' filIIV' Casing Packer Setting Tool 08/14/02 1 5" 15,459' 13,760' ~m Combinable Magnetic Resonance Tool 08/09/02 1 5" 15,459' 13,760' ~m Dipole Shear Sonic Tool, Image Log 08/09/02 1 5" 15,452' 13,760' RU5 Well data.xls/AOGCC 4-23-03 Date Modified:04/22/2003 Date Prepared: 12/6/00, bk Forest Oil Corporation Redoubt Unit #5 and 5A ) ) To AOGCC, Lisa Weepie 4-23-03 ì \, Qty Description Scale Bottom Top Depth Log Date Run# depth (feet) (feet) Well data for Redoubt Unit #5 and# 5A wells, API#50-733-20513-00 and #50-733-20513-01 (Continued) Redoubt Unit #5, API #50-733-20513-00, Schlumbergerlogs (Continued): Elemental Capture Spectroscopy Sonde - r 08/09/02 1 Natural Gamma Ray Tool Q j,Jl Q k G ~" 08/09/02 1 Repeat Formation Tester 08/09/02 1 Ultra Sonic Borehole Imager 08/09/02 1 Ultra Sonic Imaging Tool 08/11/02 1 Ä" , .vffim ~.. ~ 0film 5" 5" 15,459' 15,452' 15,190' 15,400' 13,746' 13,760' 13,760' 14,485' 13,800' 10,261 ' 5" 5" /",," Epoch Well Logging, Redoubt Unit 5 and 5A V'f report Final Well Report, containing the following logs: tZ Redoubt Unit 5 Formation Log (MD) 08/08/2002 2" 15,438' 145' ~ Redoubt Unit 5 Formation Log (TVD) 08/08/2002 2" 15,438' 145' , 1 10ç Redoubt Unit 5 Drilling Dynamics Log (MD) 08/08/2002 2" 15,438' 145' v-1íog Redoubt Unit 5A Formation Log (MD) 09/28/2002 2" 17,000' 11,473' Z Redoubt Un~5A Formation Log (TVD) 09/28/2002 2" 17,000' 11,473' Z'"" Redoubt Unit 5A DML-MWDCombo Log (MD) 09/28/2002 2" 17,000' 11,473' log Redoubt Unit 5A Drilling Dynamics Log (MD) 09/28/2002 2" 17,000' 11,473' .~g-' Redoubt Unit 5A composite Formation Log (MD) 09/28/2002 2" 17,000' 145' ~ Redoubt Unit 5A composite Formation Log (TVD) 09/28/2002 2" 17,000' 145' Z-" Redoubt Un~ 5A composite DML-MWD Combo Log (MD) 09/28/2002 2" 17,000' 145' 1 log Redoubt Unit 5A composite Drilling Dynamics Log (MD) 09/28/2002 2" 17,000' 145' Redoubt Unit #5A, API #50-733-20513-01, Schlumberger logs: t,,/JJ?g Cement Bond Tool- VDL 10/14/2002 5" 16,850' 14,400' ~. Combinable Magnetic Resonance Tool 10/0212002 5" 16,716' 15,367' ~~ Correlation Log 10/14/2002 5" 16,850' 14,400' ~ Elemental Capture Spectroscopy Tool 10/0212002 5" 16,697' 15,342' 110.£L Natural Gamma Ray Tool Q }J(.\.. ( c ~\ 1 0/0212002 5" 16,685' 15,342' ¡/"ÍÍog Squeeze Perforating Record - 2-7/8" 2906 PJ, HMX 6 spf 10/15/2002 5" 15,755' 15,753' ~~,-.TCP Correlation GR/CCL 1 0/20/2002 5" 14,950' 14,600' (~ TCP Correlation GRlCCL 10/31/2002 5" 14,925' 14,650' t, 1 log ..lJltrasonic Imaging Tool- Cement Mode, Cement Bond Tool 1 0/14/2002 5" 16,850' 14,400' 4 Cement Bond Tool - VDL 10/14/2002 5" 16,850' 14,400' ~~ Combinable Magnetic Resonance Tool 10/0212002 5" 16,716' 15,367' t.,"""" 1)itfñ Correlation Log 10/14/2002 5" 16,850' 14,400' ,,/1 film Elemental Capture Spectroscopy Tool ~ 10/0212002 5" 16,697' 15,342' .v11 m' Natural Gamma Ray Tool C' Sl.Q CLi. ç , 10/0212002 5" 16,685' 15,342' ~queeze Perforating Record - 2-7/8" 2906. J, HMX 6 spl 10/15/2002 5" 15,755' 15,753' \.1' 1 film Ultrasonic Imaging Tool- Cement Mode, Cement Bond Tool 10/14/2002 5" 16,850' 14,400' RECetVED Please sign below to acknowledge receipt. ~eived By:"\ C"-. =Btlú N',\ ~,Q CVL')~/V\. APR ?32003 I Date: AI., Oit" Gu Coni. Comm_n AndI«age RU5 Well data.xls/AOGCC 4-23-03 Date Modified:04/22/2003 Date Prepared: 12/6/00, bk ~T«~ 119 ,.. ~ V Forest Oil Corporation Alaska Division 310 K Street, Suite 700 Anchorage, Alaska 99501 Phone: (907) 258-8600 Fax: (907) 258-8601 DATA TRANSMITTAL Ð-O(} -0 ~ 8-0 C).. '- / to--¿; RECEIVED APR 2 3 2003 Alaska Oil & Gas Cons. Commission Anchorage Date: April 23, 2003 To: Lisa Weepie/Howard Oakland AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 (907) 279-1433 From: Linda M. Starr Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Phone: (907)868 - 2162 FAX: (907) 258 - 8601 Phone: TRANSMITTAL DESCRIPTION: Well data for Redoubt Unit #5 and# 5A wells, API#50-733-20513-00 and #50-733-20513-01 Qty Description Bottom Top Depth Log Date Run# Scale depth (feet) (feet) Di9i~'~ta: V ~ CoreLab Redoubt 5A Reservoir Information Browser version 1.5, 02106/03 (Core Photos) / !} (). Lf:3 ~ Redoubt Unit 5 and 5A well data: las log curves, ascii surveys, pds log curves, Epoch Final Report (htm, doc, las) 4f: J g¿ d t.-(, ~ 1~()LfA Redoubt Unit SA Test Reports (There were no tests for Redoubt Unit 5): V3 pages Redoubt Unit 5A: Testing Summary and Analysis (DST 1, 2 and 3) /3 pages Redoubt Unit 5A: Water Analysis (DST 1, 2 and 3) Vl'report Redoubt Unit 5A: Production Testing Services reports (DST 1, 2 and 3) /f report Redoubt Unit 5A: Halliburton Pressure Gauge Report (DST 1, 2 and 3) ~ report Redoubt Unit 5A: ITS Fluid Analysis of DST#3 Cor~ata V""1page Redoubt Unit 5: Textural and compositional characteristics of core samples E~h Well Logging, Redoubt Unit 5 and SA v"'1 ~um .' Redoubt Unit 5 Formation Log (MD) 0' v~ Redoubt Unit 5A Formation Log (MD) vellum Redoubt Unit 5A composite Formation Log (MD) 08/08/2002 09/28/2002 09/28/2002 Please sign below to acknowledge receipt. Receive~ \ , ~ ~\ 9-Q -Pv'- "- ') ~O <J"'<J ~ ~ -'\ ~ RU5 Well data,xls/AOGCC 4-23-03 (2) 2" 2" 15,438' 17,000' 17,000' 145' 11,473' 145' 2" Date: Date Modified:04/23/2003 Date Prepared: 12/6/00, bk ðOð-JLog' Redoubt Unit #SA Testing Summary & Analysis . DST #f Lower Hemlock Sands '12,130 -12,595 ft SSTVD' . ~ , - Perforations: 15,765 -15,915' MD (12,130 -12,218' SSTVD) 15,950 - 15,960' MD (12,237 - 12,243' SSTVD) 16,020 - 16,030' MD (12,276 - 12,281' SSTVD) 16,170 -16,525' MD (12,353 -12,526' SSTVD) 16,610 - 16,670' MD (12,567 - 12,595' SSTVD) - Test Dates 10/21/02 - 10/24/02 Flowed Oil to the surface - Final average flowrate = 41 bfpd - Total fluid produced to the tank = 56.1 Bbls (28.8 BO & 27.4 BW) - Total fluid reversed from test string = -218 Bbls (25 BO & 193 BW) - Total fluid entry from perforations = 274 Bbls (54 BO & 220 BW) ".~ ;¡,p:" ii?~',,;. ~'t" ~~'"'~ " ~ "'1....., \J j';Ja1!.a Oi¡ ~---~ ... - C-', Redoubt Unit #SA Testing Summary & Analysis . DST #2' Lower Hemlock Sands' 12, 130 - 12,526 ft SSTVO' . . I - Perforations: 15,765 -15,915' MD (12,130 -12,218' SSTVD) 15,950 - 15,960' MD (12,237 - 12,243' SSTVD) 16,020 -16,030' MD (12,276 -12,281' SSTVD) 16,170 -16,525' MD (12,353 -12,526' SSTVD) ~ - Test Dates 10/26/02 - 10/27/02 - Flowed Oil to the surface - Final average flowrate = 15 bfpd - Total fluid produced to the tank = 31.1 Bbls (28.3 BO & 2.8 BW) - Total fluid reversed from test string = -220 Bbls (10.6 BO & 209.5 BW) - Total fluid entry from perforations = 251 Bbls (39 BO & 212 BW) .~. Redoubt Unit #SA Testing Summary & Analysis . DST #3: Upper Hemlock Sands :11,905 - 12,055 ft SSTVD: - Perforations: 15,350 - 15,385' MD (11 ,905 - 11,923' SSTVD) 15,410-15,460' MD (11,937 -11,962' SSTVD) 15,560 - 15,600' MD (12,014 - 12,035' SSTVD) 15,615 - 15,635' MD (12,044 -12,055' SSTVD) '-" - Test Dates 1 0/30/02 - 11/2/02 - Flowed Oil to the surface - Final average flowrate = 79 bfpd - Total fluid produced to the tank = 83.0 Bbls (77.2 BO & 5.7 BW) - Total fluid reversed from test string = -220 Bbls (21.5 BO & 198.5 BW) - Total fluid entry from perforations = 303 Bbls (99 BO & 204 BW) '(j,ur:y.. -/ UJ¿? RU #SA . DST #1 (Lower Hemlock) Water Analysis Redoubt Unit #5A DST #1 Perfs: 15,765 -16,670 ft MD (12,130 - 12,595 ft SSTVD) Water Samples while Reversing Out CT&E Environmental Services, Inc. ~. Sample Fluid Wt Chlorides Reversed TDS Chlorides Na Ca Mg K # Date Time (ppg) (ppm) Out - bbls Comments: (mg/L) (mg/L) (mg/L) (mg/L) (mg/L) (mg/L) 1 10/24/02 10:27 AM Initial Sample 2 10:50 AM 8.6 25.0 3 10:55 AM 8.6 31.7 4 11:00 AM 8.6 39.5 X 39,300 19,000 2,510 2,040 45.2 13,400 5 11:05AM 8.6 47.2 6 11 : 1 0 AM 8.6 54.0 X 33,200 1 5,400 3,250 2,860 49.7 9,670 7 11 :20 AM 8.6 65.0 8 11 :30 AM 8.6 80.0 X 23,100 9,780 3,340 2,300 28.4 4,110 9 11 :40 AM 8.6 109.5 10 11:50AM 8.4 138.1 X 21 ,1 00 10,500 3,210 1,620 15.8 3,990 11 12:00 PM 8.3 167.4 X 16,400 8,420 3,540 1,690 13.3 929 12 12:10 PM 8.3 193.7 X 16,600 8,470 3,460 1,690 12.9 870 13 12:20 PM 8.6 224.3 X 47,000 28,700 2,820 122 * 24,800 14 12:25 PM 8.6 239.6 Finished Reversing Out X 45,500 30,700 271 98.2 * 25,100 r-"'" 15 Water Sample from Drain Valve 16 Oil Sample from Drain Valve Note: Drill pipe/Testing string displacement volume = 218 bbls X Sample Analyzed * Analyzed for, but not detected RECEI.VED APR 23 2003 '~~~\~ ~ Ala8kaon & Gas Cons. Comm~ Anehomge RU #5A . CST #2 (Lower Hemlock) Water Analysis Redoubt Unit #5A DST #2 Perfs: 15,765 - 16,525 ft MD (12,130 - 12,526 ft SSTVD) '-" Water Samples while Reversing Out CT&E Environmental Services, Inc. Sample Wtr Chlorides Reversed TDS Chlorides Na Ca Mg K Specific # Date Time Cut (ppm) Out - bbls Comments: (mg/L) (mg/L) (mg/L) (mg/L) (mg/L) (mg/L) Gravity 10/28/02 8:20 AM Start Reversing Out 1 8:30 AM 90% 27,000 20.2 Initial Sample X 56,500 25,300 733 544 10.7 30,100 1 .0416 2 8:40 AM 97% 22,000 37.0 3 8:50 AM 99% 18,000 60.5 X 16,600 36,500 2,590 1,560 12.1 13,200 1.0284 4 9:00 AM Trace Oil 15,000 80.7 5 9:10 AM 16,000 97.5 X 28,900 12,800 2,810 1,310 13.1 8,440 1.0232 6 9:20 AM 10,000 129.4 # 19,300 8,200 3,620 1,700 7.83 1,320 1.0183 7 9:30 AM 10,000 163.0 # 18,300 7,840 3,510 1,720 7.28 885 1.0173 8 9:40 AM 29,000 201.5 9 9:50 AM 28,000 220.0 Finish Reversing Out X 58,500 27,100 462 87.7 23.8 31,200 1.0422 ~ Note: Drill pipelTesting string displacement volume = 218 bbls X Sample Analyzed # Full Water Analysis RU #5A. DST #3 (Upper Hemlock) Water Analysis Redoubt Unit #5A DST #3 Perfs: 15,350 - 15,635 ft MD (11,905 - 12,055 ft SSTVD) Water Samples while Reversing Out CT&E Environmental Services, Inc. Sample Wtr Chlorides Reversed TDS Chlorides Na Ca Mg K Specific # Date Time Cut (ppm) Out - bbls Comments: (mg/L) (mg/L) (mg/L) (mg/L) (mg/L) (mg/L) Gravity '-'" 1 11/2/02 6:45 PM 0.0 Open Well- Begin revercing-Out 2 6:50 PM 4.6 3 6:55 PM 9.2 4 7:00 PM 12.1 5 7:05 PM 0.1% 15.1 6 7: 1 0 PM 18.1 7 7:15 PM 21.0 8 7:20 PM 98% 23.9 Water to Surface 9 7:25 PM 98% 29,000 26.9 10 7:30 PM 28,500 30.2 11 7:35 PM 98% 28,000 33.6 12 7:40 PM 29,000 36.9 13 7:45 PM 98% 27,000 40.3 14 7:50 PM 23,500 49.1 15 7:55 PM 99% 17,000 57.9 16 8:00 PM 13,500 72.6 X 26,400 12,500 3,270 1,890 6,060 1.0220 17 8:05 PM 100% 12,000 87.3 18 8:10 PM 11,500 101.5 # 23,400 10,200 3,000 1,610 6.63 4,100 1.0220 19 8:15 PM 100% 11,000 115.9 # 22,500 9,850 3,110 1,630 7.46 3,950 1.0196 ~ 20 8:20 PM 12,000 131.8 X 24,600 10,900 2,960 1,580 * 4,940 1.0195 21 8:25 PM 100% 13,000 147.8 22 8:30 PM 13,000 164.8 X 24,700 11,500 2,940 1,510 5,810 1.0200 23 8:35 PM 100% 13,500 180.5 24 8:40 PM 18,000 195.2 25 8:45 PM 100% 28,000 210.0 26 8:50 PM 30,000 222.6 X 61,600 29,400 394 * 30,200 1.0430 27 8:55 PM 100% 30,000 235.2 28 9:00 PM 31,000 X Sample Analyzed Note: Drill pipelTesting string displacement volume = 218 bbls # Full Water Analysis * Analyzed for, but not detected ITS Intertek ~esting Services Caleb Brt....{ WinAssay '95 Version 1.00 Final Reports "~~\\i\~ -"REDOU/.3T" ÛNlT SA Client Name: Forest Oil Sample ID: DST # 3 Laboratory ID: )f)CfJ-I&6 2002-009808-DRPK Date: 11/20/02 Operator: S.T. / B.F. RECEIVED APR 23 2003 AtW Ot~ & Gas Cons. Comm~ Anchorege Copyright 1995 Envantage, Ine ITS- Caleb Brett Distillation Group ASTM D2892/D5236 CHARGE INFORMATION Lab ID: 2002-009808-DRPK Client Name: Forest Oil Sample ID: DST # 3 Date: 11/20/02 Charge Mass D2892(g): Charge S.G D2892 (60/60F): Charge Mass D5236(g): Charge S.G. D5236 (60/60F): .~ OperatorJS.T./ S.F. 12075.0 0.8959 Water Weight Removed (g): Initial Vapor Temp: Whole Crude Sulfur Wt%: 4007.0 0.9987 217.8 60 ~ 02-9808 DST #3 TBP(Export File).xls ) WinAssay'95 ASTM TBP And Potstill Distillation Sample ID: LabID: Client: DST # 3 2002-009808-DRPK Forest Oil Material Balance Parameters: ASTM D2892 Distillation ) Quality Control Report Date: 11/20/02 D2892 Material Balancef 100.001 ASTM D5236 Distillation Passes Material Balance Per D2892 D5236 Material Balancet 100.001 API Balance Parameters: D2892 Measured API: D2892 Calc API: API Delta (Meas-Calc): I D5236 Measured API: D5236 Calc API: API Delta (Meas-Calc): f Passes Material Balance Per D5236 26.4 0 26.7 0 -0.31 0 Passes API Test 10.2 0 10.2 0 0.°1 Passes API Test Note: Review the API vs Mid-Vol% Plot For Outliers along the curve. Points lying ofT the curvature should be reviewed for accuracy in density determination. 02-9808 DST #3 TBP(Export File) ( JI.. ::J - "' JI.. ( c. E ~ 600 ( .5 -¡: 0 c. "' > ) WinAssay'95 ) True Boiling Point Curve vs Cumulative Vol% Yield Sample ill DST # 3 1200 r... .n_m.....- mm. nnm..'._~ nnnmn_n '.nm. moon 'mn~__n- .m... nmnmm' ..00"__' ) ¡ ) 1000 ¡ 800 400 200 j ì > ~ 0\ 0 20 40 60 Cumulative Vol% Yield 80 '___.m.n ..-.....---¡ I ¡ I 100 f ¡ ~ ¡ f ¡ ~ ¡ I ! ¡ $ ~ i $ $ $ f ¡ ¡ í I í I f , 120 TBP CURVE Chart 1 ) WinAssay'95 True Boiling Point Curve Vaporline Temperature v. Cumulative Wt% Yield Sample ID DST # 3 1200 _.nn n-_'. 'm_~n... --.m .~__~m.-_-n--' 'nm'm'.n.m... mmmnm'._.___nmn'n m-..'nm.-_nn ..-....-,--.- -._-~~~~~~ I ¡ ¡ ~ 1000 . 800 600 , 400 200 0 0 40 60 20 80 \ I ¡ ¡ ! I I ¡ ¡ ! I I ¡ i ¡ I I 100 120 Wt Curve Chart 1 140 : ~ . 120 ; 100 ¡ ) ( ~ 'S; ns ~ C) õ: c:t ) ) 80! - 60 40 20 wh.lssay '95 Quality Control Applicatk ) Cum. Mid Vol% v. API Gravity DST # 3 '-_..vv_~~-...~----_.............. \\ ~-. '~I 0 :. 0 ---~ ~. -.- -- ..--j 20 30 40 50 60 70 80 90 10 Cumulative Mid Vol% API CURVE Chart 1 WinAssay '95 Final TBP Distillation Yield Report Prepared For: Forest Oil Sample ID: DST # 3 Date: 11/20/02 I .~< I Cut Temp 1ge9rees F I DUMP I specifiC' 'LIQ 'CUM. LIQ WT% I CUM' API I MID' WT(g) Gravity MLS VOL% VOL% WT% GRAVITY LIQ VOL% ASTM D2892 Distillation Yields IBP 68 76.50 0.5580 137.10 1.04 1.04 0.65 0.65 122.08 0.52 68 170 349.10 0.6747 517.42 3.91 4.95 2.94 3.59 78.22 2.99 170 270 746.70 0.7462 1000.67 7.56 12.51 6.30 9.89 58.13 8.73 270 350 599.60 0.7780 770.69 5.82 18.33 5.06 14.94 50.38 15.42 350 400 365.00 0.8029 454.60 3.43 21.76 3.08 18.02 44.74 20.05 400 500 1014.90 0.8345 1216.18 9.19 30.95 8.56 26.58 38.06 26.36 500 550 550.20 0.8524 645.47 4.88 35.83 4.64 31.22 34.50 33.39 550 600 644.10 0.8561 752.37 5.68 41.51 5.43 36.65 33.78 38.67 600 650 686.10 0.8820 777.89 5.88 47.39 5.79 42.44 28.93 44.45 650 700 703.90 0.8903 790.63 5.97 53.37 5.94 48.38 27.44 50.38 700 750 647.40 0.9005 718.93 5.43 58.80 5.46 53.84 25.63 56.08 750+ 5473.70 0.9987 5480.83 41.41 100.21 46.16 100.00 10.18 ASTM D5236 Distillation Yields 750 900 957.90 0.9245 1036.13 10.69 69.49 11.04 64.87 21.56 64.15 900 950 372.40 0.9432 394.83 4.08 73.57 4.29 69,16 18.52 71.53 950 1032 600.00 0.9608 624.48 6.45 80.01 6.91 76.07 15.77 76.79 ~ 1032+ 2076.70 1 .0550 1968.44 20.32 100.33 23.93 100.00 2.62 02-9808 DST #3 TSP(Export File).xls Simdist-2000 ) Injej{fl ~~k:: ITS Caleb Brett - Houston SAMPLE: Forest Oil Report Date: 11/16/02 16:35 FILE: C:\CPWIN\CARLA\FOIL.07R PROCEDURE: C:\CPWIN\CARLA\1106-HTSD.PRC EXCEL FILE: C:\CPW IN\Carla\FOIL- 07R.xls Boiling Point Distribution Report High Temp Simdis By External Standard %Off BpOF BpOC %Off BP OF BpoC %Off BP of BpoC IBP 25.0 -3.9 40% 629.3 331.9 80% 1010.3 543.5 1% 81.0 27.2 41% 638.1 336.7 81% 1021.6 549.8 2% 143.5 62.0 42% 646.8 341.6 82% 1034.1 556.7 3% 165.3 74.1 43% 655.2 346.2 . 83% 1043.9 562.2 4% 185.0 85.0 44% 665.6 352.0 84% 1053.7 567.6 5% 205.8 96.5 45% 675.6 357.5 85% 1063.1 572.8 6% 220.2 104.6 46% 685.0 362.8 86% 1072.7 578.2 7% 236.1 113.4 47% 695.9 368.8 87% 1082.6 583.7 8% 252.8 122.7 .48% 703.7 373.1 88% 1092.3 589.1 9% 271.2 132.9 49% 712.7 378.2 89% 1102.0 594.5 10% 286.5 141.4 50% 721.2 382.9 90% 1111.8 599.9 11% 299.1 148.4 51% 730.5 388.1 91% 1122.1 605.6 12% 315.9 157.7 52% 740.1 393.4 92% 1132.4 611.3 13% 330.7 165.9 53% 752.1 400.1 93% 1142.7 617.0 14% 343.0 172.8 54% 763.5 406.4 94% 1153.6 623.1 '15% 360.0 182.2 55% 774.7 412.6 95% 1164.8 629.3 16% 371.8 188.8 56~ 783.2 417.3 96% 1175.4 635.2 17% 389.3 198.5 57% 791.1 421.7 97% 1186.8 641.6 .18% 402.4 205.8 58% 799.3 426.3 98% 1198.7 648.1 19% 413.4 211.9 59% 807.5 430.8 99% 1210.6 654.8 20% 426.9 219.4 60% 818.5 43~).9 100% 1224.2 662.4 21% 438.9 226.1 61% 829.9 4/43.~ 22% 450.3 232.4 62% 841.2 449.5 23% 462.5 239.1 63% 850.1 454.5 24% 473.5 245,3 64% 859.2 459.5 25% 484.5 251.4 65% 868.1 464,5 26% 495.0 257.2 66% 879.0 470.6 .27% 505.4 263.0 67% 890.4 476.9 28% 517.2 269.5 .68% 900.9 482.7 29% 528.6 275.9 69% 909.2 487.3 30% 539.0 281.7 70% 917.5 491.9 31% 548.9 287.2 71% 925.9 496.6 32% 556.4 291.4 72% 936.4 502.5 33% 565.7 296.5 73% 947.1 508.4 34% 575.7 302.1 .74% 955.8 513.2 35% 583.0 306.1 75% 964.2 517.9 36% 593.2 311.8 76% 972.9 522.7 37% 602.6 317.0 77% 984.0 528.9 38% 610.9 321.6 78% 994.5 534.7 39% 620.3 326.8 79% 1002.3 539.0 Start Elution Time (mlns): 0.047 Sample Wt: 0.32695 g End Elution Time (mlns): 41.487 Solvent Wt: 7.4222 g Material Balance: 100.9 ww. Blank File: C:\CPWIN\CARLA\DLK-S.02R Calib File: C:\CPWIN\CARLA\RTMX 114.03R Resp Factor: 1.882E-09 Envantage, Inc. Version 1.0706 Simdist-2000 Copyright 2001 Detailed Hydrocarbl ) Analysis (DHAX) Neil G. Johansen, Inc. Raw File: FORDST3.03R Sample: FOREST OIL DST#3 BOMB 1 Method: !DHA.MET Processed 37 peaks Comments: Summary Report Group Type: Paraffins: I-paraffins: Olefins: Naphthenes: Aromatics: . Total C14+: Total Unknowns: Total(mass%): 67.987 31.276 0.148 0.495 0.025 0.000 0.069 Oxygenates: Total: T ota1 Oxygen Content: 0.000 (mass%) 0.000 (masso/a) 0.000 (m~s%) Multisubstituted Aromatics: Average Molecular Weight: 55.339 Relative Density: (~ 11 }fIZÐ/~ Analyzed: Nov 08, 2002 04:30 AM Reported: Nav 08, 2002 08:32 PM DHA DBase File: DHA1-BAK.CSV Normalized to 100.00% J Total(vol%): 68.799 30.600 0.144 0.368 0.016 0.000 0.073 0.000 (volo/c) 0.000 (vol%) Vapor Pressure, calc. RVP (EPA method): 81.88 (psi @ 100°F) Octane Number (Calculated)(~ Boiling Point (est.): IBP: T10: T50: T90: FBP: -127.48°F -43.67°F 31.10°F 82.11°F 155.71°F Percent Carbon: 82.521 Percent Hydrogen: 17.479 Bromine Number (calc.): 0.475 DHA_WIN e 1993 uNJu FORDST3.03D Page 1 Detailed Hydrocarb\ ) Analysis (DHAX) Neil G. Johansen, Inc. Raw File: FORDST3.03R Sample: FOREST OIL DST#3 BOMB 1 Oxygenates Compound Mass% ') Analyzed: Nov 08, 2002 04:30 AM Reported: Nov 08. 2002 08:32 PM Mass% Oxygen Molecular Weight and Relative Density Data Group: C1: C2: C3: C4: C5: C6: C7: C8: C9: C10: C11: C12: C13: Total Sample: Ave. Molwt.: 16.043 30.070 44.091 58.118 72.104 85.582 97.674 112.216 128.259 0.000 0.000 0.000 0.000 55.339 V 010/0 Ave. ReI. Density: 0.260 0.340 0.501 0.571 0.624 0.683 0.739 0.780 0.709 0.000 0.000 0.000 0.000 0.558 ø Research Octane Number 113.97 (Calculated from Individual Compon es Contribution to Total by: Paraffins: Isoparaffins: Olefins: Naphthenes: Aromatics: Oxygenates: OHA_WIN <C> 1993 UNJ" FORDST3.03D 76.81 36.44 0.18 0.43 0.03 0.00 Page 2 . Detailed Hydrocarb ) Analysis (DHAX) Neil G. Johansen, Inc. ) Raw File: FORDST3.03R Analyzed: Nov 08, 2002 04:30 AM Sample: FOREST Oil 08T#3 BOMB 1 Reported: Nov 08,2002 08:32 PM Totals by Group Type & Carbon Number (in Mass Percent) Paraffins: I-paraffins: Olefins: Naphthenes: Aromatics: Total: C1: 0.005 0.000 0.000 0.000 0.000 0.005 C2: 0.572 0.000 0.000 0.000 0.000 0.572 C3: 20.890 0.000 0.056 0.000 0.000 20.946 C4: 42.860 24.419 0.091 0.000 0.000 67.371 C5: 3.478 6.390 0.000 0.227 0.000 10.095 C6: 0.174 0.431 0.000 0.223 0.004 0.833 C7: 0.008 0.032 0.000 0.040 0.020 0.100 C8: 0.000 0.000 0.000 0.006 0.000 0.006 C9: 0.000 0.003 0.000 0.000 0.000 0.003 C10: 0.000 0.000 0.000 0.000 0.000 0.000 C11: 0.000 0.000 0.000 0.000 0.000 0.000 C12: 0.000 0.000 0.000 0.000 0.000 0.000 C13: 0.000 0.000 0.000 0.000 0.000 0.000 Total: 67.987 31.276 0.148 0.495 0.025 99.931 Oxygenates: 0.000 Total C14+: 0.000 Unknowns: 0.069 Grand Total: 100.000 Totals by Group Type & Carbon Number (in Volume Percent) Paraffins: I-paraffins: Olefins: Naphthenes: Aromatics: Total: C1: 0.010 0.000 0.000 0.000 0.000 0.010 C2: . 0.939 0.000 0.000 0.000 0.000 0.939 C3: 23.285 0.000 0.062 0.000 0.000 23.348 C4: 41.312 24.450 0.082 0.000 0.000 65.844 C5: 3.098 5.756 0.000 0.170 0.000 9.024 C6: 0.147 0.366 0.000 0.164 0.003 0.681 C7: 0.007 0.026 0.000 0.030 0.013 0.076 C8: 0.000 0.000 0.000 0.004 0.000 0..004 C9: 0.000 0.002 0.000 0.000 0.000 0.002 C10: 0.000 0.000 0.000 0.000 0.000 0.000 C11: 0.000 0.000 0.000 0.000 0.000 0.000 C12: 0.000 0.000 0.000 0.000 0.000 0.000 C13: 0.000 0.000 0.000 0.000 0.000 0.000 Total: 68.799 30.600 0.144 0.368 0.016 99.927 Oxygenates: 0.000 Total C14+: 0.000 Unknowns: 0.073 Grand Total: 100.000 OHA_WIN (þ 1993 uNJ" FORDST3.03D Page 3 . Detailed Hydrocarr)n Analysis (DHAX) Neil G. Johansen, Inc. ) Raw File: FORDST3.03R Sample: FOREST OIL DST#3 80MB 1 Method: !DHA.MET Processed 37 peaks Analyzed: Nov 08, 2002 04:30 AM Reported: Nov 08,2002 08:30 PM DHA DBase File: DHA1-BAK.CSV Normalized to 100.0000% Comments: Components Listed in Chromatographic Order RT, min. Index Component: Mass% VolO/o Mol% 5.885 100.0 methane 0.005 0.010 0.016 6.050 200.0 ethane 0.572 0.939 1.054 6.493 294.0 propylene 0.056 0.062 0.074 6.543 300.0 propane 20.890 23.285 26.233 7.382 362.4 ? 0.056 0.063 0.070 7.454 366.0 i-butane 24.419 24.450 23.265 8.227 396.8 1,3-butadiene 0.091 0.082 0.093 8.326 400.0 n-butane 42.860 41.312 40.835 8.758 414.5 2,2-dimethylpropane 0.039 0.037 0.030 11.691 477.1 i-pentane 6.351 5.718 4.874 13.382 500.0 n-pentane 3.478 3.098 2.669 15.847 541.0 2,2 -d i me thyl butane 0.007 0.006 0.005 17.861 567.6 cyclopentane 0.227 0.170 0.179 18.072 570.1 2,3-dimethy1butane 0.036 0.030 0.023 18.442 574.4 2-methylpentane 0.263 0.225 0.169 19.4 77 585.8 3-methylpentane 0.125 0.105 0.080 20.875 600.0 n-hexane 0.174 0.147 0.112 22.865 624.4 2,2-dimethylpentane 0.001 0.001 0.000 22.994 625.9 methylcyclopentane 0.154 0.114 0.101 23.423 630.7 2,4-dimethylpentane 0.007 0.006 0.004 25.283 650.4 benzene 0.004 0.003 0.003 26.038 657.9 cyclohexane 0.069 0.050 0.046 27.076 667.7 2-methylhexane 0.009 0.008 0.005 27.207 668.9 2,3-dimethylpentane 0.006 0.005 0.003 27.465 671.3 1,1-dimethylcyclopentane 0.004 0.003 0.003 27.995 676.0 3-methylhexane 0.009 0.007 0.005 28.652 681.8 1 c,3-dimethylcyclopentane 0.008 0.006 0.004 28.966 684.5 1 t,3-dimethylcyclopentane 0.007 0.005 0.004 29.282 687.1 1 t,2-dimethylcyclopentane 0.009 0.007 0.005 30.872 700.0 n-heptane 0.008 0.007 0.005 33.468 718.0 1 c¡2-dimethylcyclopentane 0.011 0.009 0.006 39.168 752.1 toluene 0.020 0.013 0.012 61.238 843.8 2,6-dimethylheptane 0.003 0.002 0.001 61.535 844.8 ? 0.007 0.005 0.003 61.778 845.5 ? 0.006 0.005 0.003 62.598 848.2 N7 0.004 0.003 0.002 63.023 849.5 N8 0.003 0.002 0.001 DHA_WIN (Ç) 1993 uNJu FORDST3.03D Page 4 Detailed Hydrocarb') Analysis (DHAX) Neil G. Johansen, Inc. _l Raw File: 980B--3.06R Sample: 9808-3 Method: !DHA.MET Processed 46 peaks Comments: 68-170F Summary Report Group Type: Paraffins: I-paraffins: Olefins: Naphthenes: Aromatics: Total C14+: Total Unknowns: T otal(mass%): 36.026 33.394 0.001 28.537 2.026 0.000 0.016 Oxygenates: Total: Total Oxygen Content: 0.000 (mass%) 0.000 (masso/a) 0.001 (ma~s%) Multisubstituted Aromatics: Average Molecular Weight: 78.746 Relative Density: 0.671 Vapor Pressure, calc. RVP (EPA method): Octane Number (calculated): 74.63 ) Analyzed: Dee 10, 2002 11:10 AM Reported: Dec 10, 2002 11 :39 AM DHA DBase File: DHA1-BAK.CSV Normalized to 100.000/0 T otal(vol%): 38.180 34.915 0.001 25.344 1.546 0.000 0.014 0.000 (vol%) 0.001 (vola/a) 9.96 (psi @ 100°F) Boiling Point (est.): IBP: T10: T50: T90: FBP: 10.90°F 82.11°F 140.47°F 177.30°F 211.15°F Percent Carbon: 84.286 Percent Hydrogen: 15.714 Bromine Number (calc.): 0.002 DHA_WIN e 1993 uNJu 9808-3.060 Page 1 Detailed Hydrocart)l Analysis (DHAX) Neil G. Johansen, Inc. Raw File: 9808-3.06R Sample: 9808-3 Oxygenates Compound Mass% Analyzed: Dee 1 0, 2002 11: 10 AM Reported: Dec 10, 2002 11 :39 AM Mass% Oxygen Vol% Molecular Weight and Relative Density Data Group: C1: C2: C3: C4: C5: C6: C7: C8: C9: C10: C11: C12: C13: Total Sample: Ave. Molwt.: 0.000 30.070 44.097 58.124 71.871 85.065 99.313 113.274 126.942 0.000 0.000 0.000 0.000 78.746 Ave. ReI. Density: 0.000 0.340 0.501 0.576 0.637 0.701 0.709 0.732 0.750 0.000 0.000 0.000 0.000 0.671 Research Octane Number = 74.63 (Calculated from Individual Component Values) Contribution to Total by: Paraffins: Isoparaffins: Olefins: Naphthenes: Aromatics: Oxygenates: DHA_WIN It) 1993 UNJ" 9808-3.06D 18.20 29.67 0.00 24.76 1.99 0.00 Page 2 Detailed Hydrocarb '~Analysis (DHAX) Neil G. Johansen, Inc. ') Raw File: 9808-3.06R Analyzed: Dee 10, 2002 11 :10 AM Sample: 9808-3 Reported: Dec 1 A, 2002 11 :39 AM Totals by Group Type & Carbon Number (in Mass Percent) Paraffins: I-paraffins: Olefins: Naphthenes: Aromatics: Total: C1: 0.000 0.000 0.000 0.000 0.000 0.000 C2: 0.001 0.000 0.000 0.000 0.000 0.001 C3: 0.045 0.000 0.000 0.000 0.000 0.045 C4: 4.401 0.744 0.000 0.000 0.000 5.144 C5: 16.843 12.685 0.000 4.627 0.000 34.155 C6: 14.361 17.775 0.001 21.886 2.025 56.047 C7: 0.319 2.146 0.000 1.916 0.000 4.381 C8: 0.047 0.030 0.000 0.068 0.000 0.144 C9: 0.011 0.015 0.000 0.040 0.001 0.067 C10: 0.000 0.000 0.000 0.000 0.000 0.000 C11: 0.000 0.000 0.000 0.000 0.000 0.000 C12: 0.000 0.000 0.000 0.000 0.000 0.000 C13: 0.000 0.000 0.000 0.000 0.000 0.000 Total: 36.026 33.394 0.001 28.537 2.026 99.984 Oxygenates: 0.000 Total C14+: 0.000 Unknowns: 0.016 Grand Total: 100.000 Totals by Group Type & Carbon Number (in Volume Percent) Paraffins: I-paraffins: Olefins: Naphthenes: Aromatics: Total: C1: 0.000 0.000 0.000 0.000 0.000 0.000 C2: 0.003 0.000 0.000 0.000 0.000 0.003 C3: 0.060 0.000 0.000 0.000 0.000 0.060 C4: 5.100 0.895 0.000 0.000 0.000 5.995 C5: 18.042 13.734 0.000 4.164 0.090 35.939 C6: 14.608 18. 134 0.001 19.364 1.545 53.653 C7: 0.313 2.109 0.000 1.723 0.000 4.144 C8: 0.045 0.029 0.000 0.059 0.000 0.132 C9: 0.010 0.014 0.000 0.035 0.001 0.060 C10: 0.000 0.000 0.000 0.000 0.000 0.000 C11: 0.000 0.000 0.000 0.000 0.000 0.000 C12: 0.000 0.000 0.000 0.000 0.000 0.000 C13: 0.000 0.000 0.000 0.000 0.000 0.000 Total: 38.180 34.915 0.001 25.344 1.546 99.986 Oxygenates: 0.000 Total C14+: 0.000 Unknowns: 0.014 Grand Total: 100.000 DHA_WIN @ 1993 uNJ" 9808-3.060 Page 3 Detailed Hydrocart'11 Analysis (DHAX) Neil G. Johansen, Inc. ) Raw File: 9808-3.06R Sample: 9808-3 Method: !DHA.MET Processed 46 peaks Analyzed: Dec 10, 2002 11: 10 AM Reported: Dec 10, 2002 11 :39 AM DHA DBase File: DHA1-BAK.CSV Normalized to 100.0000% Comments: 68-170F Components Listed in Chromatographic Order RT, min. Index Component: Mass% Vol% Mol% 6.060 200.0 ethane 0.001 0.003 0.003 6.558 300.0 propane 0.045 0.060 0.080 7.472 366.0 i-butane 0.744 0.895 1.008 8.336 400.0 n-butane 4.401 5.100 5.963 8.777 414.7 2,2-dimethylpropane 0.019 0.022 0.021 11.710 477.1 i-pentane 12.666 13.712 13.826 13.409 500.0 n-pentane 16.843 18.042 18.385 15.870 540.9 2,2-dimethylbutane 0.104 0.108 0.095 17.879 567.4 cyclopentane 4.627 4.164 5.196 18.088 569.9 2,3-dimethylbutane 1.089 1.104 0.995 18.469 574.3 2-methylpentane 10.352 10.633 9.461 19.497 585.7 3-methylperítane 6.229 6.289 5.692 20.635 597.3 1 c/t,4-hexadiene 0.001 0.001 0.001 20.911 600.0 n-hexane 14.361 14.608 13.124 22.877 624.1 2,2-dimethylpentane 0.070 0.069 0.055 23.028 625.9 methylcyclopentane 14.713 13.183 13.768 23.448 630.6 2,4-dimethylpentane 0.505 0.504 0.397 23.840 634.9 2,2,3-trimethylbutane 0.025 0.024 0.020 25.265 649.9 benzene 2.025 1.545 2.041 25.730 654.6 3,3-dimethylpentane 0.033 0.032 0.026 26.061 657.8 cyclohexane 7.173 6.180 6.712 27.092 667.6 2-methylhexane 0.578 0.571 0.454 27.225 668.8 2,3-dimethylpentane 0.320 0.308 0.251 27.486 671.2 1,1-dimethylcyclopentane 0.193 0.171 0.154 28.011 676.0 3-methylhexane 0.556 0.543 0.437 28.673 681.7 1 c,3-dimethylcyclopentane 0.405 0.365 0.325 28.989 684.4 1 t.3-dimethylcyclopentane 0.324 0.291 0.260 29.158 685.9 3-ethylpentane 0.059 0.057 0.047 29.302 687.1 1 t,2-dimethylcyclopentane 0.590 0.526 0.473 30.894 700.0 n-heptane 0.319 0.313 0.250 33.485 717.9 1 c,2-dimethylcyclopentane 0.385 0.352 0.308 33.923 720.7 2,2-dimethylhexane 0.016 0.015 0.011 35.245 729.1 ethylcyclopentane 0.020 0.017 0.016 36.594 737.2 1 c,2t,4-trimethylcyclopentane 0.007 0.006 0.005 37.796 744.2 1 t,2c,3-trimethylcyclopentane 0.010 0.009 0.007 . 39.302 752.5 ? 0.014 0.012 0.010 41.528 764.2 2-methylheptane 0.014 0.013 0.010 43.299 773.0 1 c,2t,3-trimethylcyclopentane 0.020 0.018 0.014 DHA_WIN @ 1993 uNJu 9808-3.060 Page 4 RT, min. Index c"xonent: Mas~q!) Vol% Mololo 46.498 787.9 L. .; hylmethylcyclopentane O.t, 0.010 0.008 47.628 792.9 1 t,2-dimethylcyclohexane 0.020 0.017 0.014 49.300 800.0 n-octane 0.047 0.045 0.032 57.482 831.0 1.1,4-trimethylcyclohexane 0.040 0.035 0.025 59.165 836.8 4,4-dimethylheptane 0.015 0.014 0.009 76.063 886.2 ? 0.002 0.002 0.001 81.663 900.0 n-nonane 0.011 0.010 0.007 92.873 957.0 1,4-methylethylbenzene 0.001 0.001 0.001 DHA_WIN @ 1993 **NJ** 9808-3.060 Page 5 .Detailed Hydrocart '}1 Analysis (DHAX) Neil G. Johansen, Inc. Raw File: 9808-4.03R Sample: 9808-4 Method: !DHA.MET Processed 67 peaks Comments: Summary Report Group Type: Paraffins: I-paraffins: Olefins: Naphthenes: Aromatics: Total C14+: Total Unknowns: Total(mass%): 16.829 24.861 0.000 55.837 2.473 0.000 0.000 Oxygenates: Total: Total Oxygen Content: 0.000 (mass%) 0.000 (mass%) 1.151 (ma~s%) Multisubstituted Aromatics: Average Molecular Weight: 103.124 Relative Density: 0.731 Vapor Pressure, calc. RVP (EPA method): Octane Number (calculated): 65.06 ) Analyzed: Nov 23,2002 12:47 AM Reported: Dec 10, 2002 03:47 PM DHA DBase File: DHA1-BAK.CSV Normalized to 100.000/0 T otal(vol%): 17.863 25.948 0.000 54.109 2.080 0.000 0.000 0.000 (vol%) 0.969 (vol%) 0.41 (psi @ 100°F) Boiling Point (est.): IBP: T10: T50: T90: FBP: 140.47°F 177.30°F 211.15°F 268.43°F 291.97°F Percent Carbon: 85.160 Percent Hydrogen: 14.840 Bromine Number (calc.): 0.000 DHA_WIN (01993 uNJ" 9808-4.030 Page 1 Detailed Hydrocarl:t )1 Analysis (DHAX) Neil G. Johansen, Inc. Raw File: 9808-4.03R Sample: 9808-4 Oxygenates Compound Mass% ) Analyzed: Nov 23,2002 12:47 AM Reported: Dec 10, 2002 03:47 PM Mass% Oxygen Vol% Molecular Weight and Relative Density Data Group: C1: C2: C3: C4: C5: C6: C7: C8: C9: C10: C11: C12: C13: Total Sample: Ave. Molwt.: 0.000 0.000 0.000 0.000 71.330 84.297 98.904 112.913 127.355 0.000 0.000 0.000 0.000 103.124 Ave. ReI. Density: 0.000 0.000 0.000 0.000 0.667 0.748 0.719 0.739 0.743 0.000 0.000 0.000 0.000 0.731 Research Octane Number = 65.06 (Calculated from Individual Component Values) Contribution to Total by: Paraffins: tsoparaffins: Olefins: Naphthenes: Aromatics: Oxygenates: DHA_WIN <01993 uNJu 9808-4.030 -0.72 18.41 0.00 44.25 3.12 0.00 Page 2 ,Detailed Hydrocarl;~p Analysis (DHAX) Neil G. Johansen, Inc. ') Raw File: 9808-4.03R Analyzed: Nov 23,2002 12:47 AM Sample: 9808-4 Reported: Dee 10, 2002 03:47 PM Totals by Group Type & Carbon Number (in Mass Percent) Paraffins: I-paraffins: Olefins: Naphthenes: Aromatics: Total: C1: 0.000 0.000 0.000 0.000 0.000 0.000 C2: 0.000 0.000 0.000 0.000 0.000 0.000 C3: 0.000 0.000 0.000 0.000 0.000 0.000 C4: 0.000 0.000 0.000 0.000 0.000 0.000 C5: 0.155 0.088 0.000 0.162 0.000 0.405 C6: 1 .488 0.831 0.000 9.670 0.444 12.433 C7: 7.835 7.307 0.000 27.021 0.000 42.163 C8: 7.125 12.272 0.000 15.314 2.029 36.740 C9: 0.226 4.363 0.000 3.670 0.000 8.258 C10: 0.000 0.000 0.000 0.000 0.000 0.000 C11: 0.000 0.000 0.000 0.000 0.000 0.000 C12: 0.000 0.000 0.000 0.000 0.000 0.000 C13: 0.000 0.000 0.000 0.000 0.000 0.000 Total: 16.829 24.861 0.000 55.837 2.4 73 100.000 Oxygenates: 0.000 Total C14+: 0.000 Unknowns: 0.000 Grand Total: 100.000 Totals by Group Type & Carbon Number (in Volume Percent) Paraffins: I-paraffins: Olefins: Naphthenes: Aromatics: Total: C1: 0.000 0.000 0.000 0.000 0.000 0.000 C2: 0.000 0.000 0:000 0.000 0.000 0.000 C3: 0.000 0.000 0.000 0.000 0.000 0.000 C4: 0.000 0.000 0.000 0.000 0.000 0.000 C5: 0.181 0.104 0.000 0.159 0.000 0.443 C6: 1.651 0.923 0.000 9.208 0.370 12.152 C7: 8.383 7.795 0.000 26.726 0.000 42.903 C8: 7.419 12.692 0.000 14.547 1.710 36.368 C9: 0.230 4.434 0.000 3.469 0.000 8.133 C10: 0.000 0.000 0.000 0.000 0.000 0.000 C11: 0.000 0.000 0.000 0.000 0.000 0.000 C12: 0.000 0.000 0.000 0.000 0.000 0.000 C13: 0.000 0.000 0.000 0.000 0.000 0.000 Total: 17.863 25.948 0.000 54.109 2.080 100.000 Oxygenates: 0.000 Total C14+: 0.000 Unknowns: 0.000 Grand Total: 100.000 DHA_WIN @ 1993 uNJU 9808-4.030 . Page 3 I;)etailed Hydrocarb", Analysis (DHAX) Neil G. Johansen, Inc. ') Raw File: 9808-4.03R Sample: 9808-4 Method: !DHA.MET Processed 67 peaks Analyzed: Nov 23, 2002 12:47 AM Reported: Dec 10, 2002 03:47 PM DHA DBase File: DHA 1-BAK.CSV Normalized to 100.0000% Comments: Components Listed in Chromatographic Order RT, min. Index Component: Masso/o Vol °/0 Molo/o 11.723 477.2 i-pentane 0.088 0.104 0.126 13.416 500.0 n-pentane 0.155 0.181 0.221 17.892 567.6 cyclopentane 0.162 0.159 0.238 18.4 70 574.4 2-methylpentane 0.446 0.499 0.533 19.503 585.8 3-methylpentane 0.385 0.424 0.461 20.899 600.0 n-hexane 1.488 1.651 1.781 23.019 625.8 methylcyclopentane 3.262 3.188 3.997 23.451 630.7 2A-dimethylpentane 0.330 0.359 0.340 25.283 650.1 benzene 0.444 0.370 0.587 26.068 657.8 cyclohexane 6.407 6.020 7.851 27.101 667.6 2-methylhexane 2.257 2.433 2.323 27.234 668.8 2,3-dimethylp'entane 1.143 1.203 1.176 27.493 671.2 1,1-dimeth~lcyclopentane 0.580 0.562 0.609 28.021 675.9 3-methylhexane 3.103 3.304 3.194 28.680 681.7 1 c,3-dimethylcyclopentane 2.121 2.083 2.227 28.996 684.3 1 t,3-dimethylcyclopentane 2.066 2.018 2.170 29.166 685.8 3-ethylpentane 0.474 0.497 0.488 29.314 687.0 1 t,2-dimethylcyclopentane 3.893 3.790 4.088 30.920 700.0 n-heptane 7.835 8.383 8.063 33.542 718.1 1 c,2-dimethylcyclopentane 16.766 16.750 1 7.609 33.943 720.7 2,2-dimethylhexane 1.393 1.465 1.257 35.235 728.8 ethylcyclopentane 1.596 1.523 1.676 35.415 730.0 2,5-dimethylhexane 0.459 0.484 0.414 35.709 731.7 2A-dimethylhexane 0.564 0.590 0.510 36.594 737.0 1 c,2tA-trimethylcyclopentane 1.273 1.220 1.170 37.814 744.1 1 t,2c,3-trimethylcyclopentane 1.880 1.785 1.727 38.282 746.8 2,3 A-trimethylpentane 0.275 0.280 0.248 39.159 751.6 2,3,3-trimethylpentane 2.971 2.993 2.682 40.388 758.2 2,3-d imethylhexane 1.166 1.197 1.052 41.527 764.1 2-methylheptane 3.393 3.557 3.063 41.813 765.5 4-methylheptane 0.667 0.692 0.602 42.605 769.5 1 c,2cA-trimethylcyclopentane 0.206 0.198 0.189 43.054 771.7 3-methylheptane 1.385 1.435 1.250 43.320 773.0 1 c,2t,3-trimethylcyclopentane 3.817 3.624 3.508 43.714 774.9 1 tA-dimethylcyclohexane 1.369 1.313 1.258 44.890 780.4 1,1-dimethylcyclohexane 0.375 0.351 0.345 45.730 784.3 3c-ethylmethylcyclopentane 0.662 0.632 0.609 46.222 786.5 3 t -e thyl methylcyclopentane 0.609 0.581 0.560 DHA- WIN @ 1993 UNJU 9808-4.030 Page 4 RT, min. Index cr'~onent: Mas$o/o Vol% Molo/o 46.517 787.8 ~. hylmethylcyclopentane 1.f ") 1.863 1.800 46.987 789.9 1,1-methylethylcyclopentane 0.11 I 0.160 0.157 47.643 792.8 1 t,2-dimethylcyclohexane 2.393 2.256 2.199 49.330 800.0 n-octane 7.125 7.419 6.432 51.293 807.9 i-propylcyclopentane 0.212 0.200 0.195 52.947 814.4 N1 0.095 0.089 0.087 53.675 817.1 2,3,4-trimethylhexane 0.068 0.068 0.055 54.152 818.9 N2 0.216 0.203 0.199 55.860 825.2 2,3,5-trimethylhexane 0.807 0.818 0.649 57.503 831.0 1,1 ,4-trimethylcyclohexane 2.977 2.820 2.432 58.110 833.1 2,2,3-trimethylhexane 0.610 0.623 0.490 59.187 836.8 4,4-dimethylheptane 0.638 0.653 0.513 59.948 839.3 n-propylcyclopentane 0.078 0.074 0.072 60.277 840.4 2,5-dimethylheptane 0.236 0.241 0.190 60.986 842.7 3,5-dimethylheptane 0.158 0.160 0.127 61.413 844.1 2,6-dimethylheptane 0.260 0.269 0.209 61.980 846.0 1 ,1 ,3-trimethylcyclohexane 0.114 0.106 0.093 63.399 850.5 N10 0.123 0.116 0.101 63.921 852.1 ethyl benzene 0.878 0.740 0.852 64.452 853.7 1 c,2t,4t-trimethylcyclohexane 0.318 0.299 0.260 67.185 861.9 1 ,3-dimethylbenzene 0.819 0.693 0.795 67.869 863.9 2,3-dimethylheptane 0.665 0.670 0.535 68.699 866.3 3,4-dimethylheptane 0.293 0.293 0.235 70.895 872.5 4-methytoctane 0.175 0.178 0.141 71.278 873.5 2-methyloctane 0.290 0.298 0.233 73.441 879.4 3-methyloctane 0.161 0.163 0.129 74.741 882.8 1,2-dimethylbenzene 0.333 0.276 0.323 76.593 887.6 N18 . 0.138 0.129 0.113 81.640 900.0 n-nonane 0.226 0.230 0.181 DHA_WIN @ 1993 uNJ" 9808-4.030 Page 5 ') /~e. ÒO(A.f3T llJ'JìT Sit ~~)T :#:3 Haverlv Systems GC Component List for iCDM (DHA Import Automated b' 1. Enter Start and End Temp for each cut 2. Do not enter SG, Cut Yield or % of GC Consolidation Yiled data. 3. Press Import over desired cut column, select DHA result file and Vol% on Cut is Auto-Entered 4. Do not override sum formulas for iC6, iC7, C7 Naphthenes and C8 Aromatics Totals 5. Formula references to other spreadsheets are OK for Component data. 2002-009808 Forest Oil GC File DHA Import File Start Temp End Temp SG Cut Yield % of GC Consolidation Yield C# Totals 2 Ethane C2 ~::::~~:p.r.9.p.~~~::::~::::::::::::::::::::::::::::::::::::::::::::::::::::::::~S?~:::::::::::::::::::::::::::::::::: 4 Normal Butane NC4 ''''''4~ïšõ''Šü¡äïïe'''''''''''''''''''''''''''''''''' """""""""""-ïC.4'''''''''''''''''''''''''''''''' """g"Ñ'õ¡'ïñãi"pëñtä.ñã.'."'"''''''''''''''''''''''''''"""."-.ÑC5"'"''''''''..''''''''''''''' """g'ïšõ"pëñtãñã""""""'"''''''''''''''''''''''''''''''......... ïcg"""""""""""""""" ::::::§'~:9:Ÿ.~!2P.~~!~~:~:::::::::::::::::::::::::::::::::::::::::::::::::~S?~::::::::::::::::::::::::::::::::: 6, Normal Hexane NC6 ...............................-................................................................. .......................................... C:\CPWIN\Eu C:\CPWIN\Eu C:\CPWIN\Eugene\9808-4.03D IBP 68.0 170.0 68F 170F 270F Eafl- 0.9392 0.0026 0.0000 23.2852 0.0597 0.0000 41.3120 5.1001 0.0000 24.4499 0.8953 0.0000 3.0984 18.0415 0.1806 5.7556 13.7340 0.1039 0.1697 4.1637 0.1589 0.1474 14.6084 1.6512 ::::::~~:~~:M~!~y.~p.~~!~~~::::::::::::::::::::::::::::::::::::::::::~~~M:~:::::::::::::::::::::::::::: ......~,.~.~~!~Y.!P.~!J!~~~....¡...................................... ~:ME~............................ ......~,.?'!?':Q!~.~~bY.~Þ.~!~D,~...................................._?...?.:.9..~ê.................... ......~~.?'!~:Q!~.~.~bY.~Þ.~~.~D.~...................................._?...~:.9..~ê.................... ......~~.!~!?..~~~~~~,.Cf.2~~!..9.~..!.~2!!!~r.~L......_.I.Ç.~.......,.......,................ ::::::~::M~!~:ÿ'~~y.~i~f?~~!~~~::::::::::~:::::::::::::::::::::::~M:ç:~::::::::::::::::::::::::::::: ......~..g.y.~!2b~~~~~..................................................._ftt................................ 6 Benzene BZ ::::::?::~~f.~~!:E~e.~~~~:::::::::::::::::::::::::::::::::::::::::::~E~t::::::::::::::::::::::::::::: ::::::t.~:~~M~!hŸ.~b~~~~~::::::::::::::::::::::::::::::::::::::::::::~~~ME:::::::::::::::::::::~:::: ......?...~:.~~~.~Y.!.~~~~~~............................................_~:M.~............................ ......?"..?'!?':Q!~.~~bY.!J?~~~.~D.~................................._?...?:.9..~p..................... ......?"..?'!~:Q!~.~.~by.~J?~~!~.'].~................................._?...~:.9.,~.p..................... ......?"..?'!~:Q!~.~.~by.~J?~~~.~.'].~.................................. ?...~.9.,~p..................... ......?",.~!~:Q!~.~.~bY..~J?~~~.~.'].~................................._~.,.~:.9..~p..................... ......?,.?.~.~.:.~.:~f..~!.~~!.~Y.~p.~!~!".'.~............................._?...?.!~:!M.ê................ ,.....?.}:.~!~.y.~.p..~.']!~~~.........................................,..... ~:~.!P........................... ......?..!~!?'..~.~p'~~~~..(!P'!~!',Ç~.?...~.~2~.~E~)........_.I.g.!.................................. ::::::t.j:;:EQ!~:~j~y.~~ÿ.~!2p.~:6!~~~::::::::::::::::::::~:!~:EÞ.:Mç:~:::::::::::::::: ......!....~.!ç~.~:?:!?~~.~!~y'.I.~Y.~~!?J?.~~~.~D.~.........._.~.Ç?':QM9~.............. ,.....!...J.!ç~.~:~_-:!?~~.~~~y'.I.~Y.~~!?J?.~~~.~D.~.........._.~.ç~:QM9~.............. ......?.~.!I~~.§.:?.:!?..!~.~!~y'~~y.~!~P.~~!~Ð.~. .tT.~.:QM.9.~.............. ,.....!....~.!I~~.~:~:Q!~.~!~y"~~y.~!~P.~~!~Ð.~_.!I~::.9.M.9..~.............. ......!....§!~y..~~Y.~~!?P.~~~~.'].~......................................._.~It!:Ç,~..................... ......!..,.g.?..~Y.~~.~.P..~.!".'.~~~~~.ITp.!~!L..................._f?,:ÇYf?.................. 0.2248 10.6327 0.1049 6.2895 0.0064 0.1079 0.0303 1.1044 0.3664 18.1344 0.1144 13.1834 0.0497 6.1803 0.0028 1.5453 0.0068 0.3126 0.0076 0.0072 0.0007 0.0046 0.0059 0.0000 0.0000 0.0000 0.0260 0.0033 0.0086 0.0058 0.0069 0.0051 0.0000 0.0297 ::::::?~~M~!~ÿ'I~y.~~~~~~~~~::::::::::::~::::::::~::::~:::::::~M:çE::::::::::::::::::::=::::: 0.0000 .._..?...M~!~.y.~.~.~.~.~~~~..{!.~.~~~~~L..................._I~.~~~!".'.~...................... 0.0131 0.5709 0.5426 0.0695 0.3084 0.5040 0.0322 0.0244 0.0569 2.1089 0.4990 0.4241 0.0000 0.0000 0.9231 0.0000 0.0000 3.1878 6.0205 0.3698 8.3826 2.4329 3.3036 0.0000 1.2026 0.3591 0.0000 0.0000 0.4968 7.7949 0.0000 0.0000 0.1712 0.5624 0.3523 16.7499 0.3650 2.0827 0.5263 3.7896 0.2907 2.0179 0.0173 1.5232 1.7228 26,7257 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 ) ) Haverlv Systems GC Component List for iCDM (DHA Import Automated b, 1. Enter Start and End Temp for each cut 2. Do not enter SG, Cut Yield or % of GC Consolidation Yiled data. . 3. Press Import over desired cut column, select DHA result file and Vol% on Cut is Auto-Entered 4. Do not override sum formulas for iC6, iC7, C7 Naphthenes and C8 Aromatics Totals 5. Formula references to other spreadsheets are OK for Component data. 2002-009808 Forest Oil GC File DHA Import File 8 Normal Octane NC8 """ä"ïsõ"õëtãñë"''''''''''''''''''''''''''''''''''''''''''''''''''''''-ï(58".'"'''''''''''''''''''''''''' ::::::~r:M~!~ÿ'E~t:~y'!~y'çI~i?~:6!~~~:::::::::::::::::::::~f~~ÇŸf~:::::::::::::::::: ......~...Q~~~!~Y..~~Y.2!~~~~~D.~................................_ç~:Qyç~.................. ::::::~::I;~~Q!~~!~y'~þ'~~~~~~:{~:~~ÿ'I~~~j:::::~~~~y'~~~~::::::::::::::::::: ......~..J!~:Q!!P..~~~Y.!Þ.~!:!~~D.~.~~:~.y.!~.~~L.}~.:?SY..~~!!~....'''''''''''''' ......~..1.!~:Q!!P..~.!~Y.!Þ.~!:!~~D.~.~Q:?5y.!~~~L._9:~y.!.~~.~................... ......~...~~~Y..~þ..~~.~.~~~.................................................._.~!.~:~.~......................... ......~...9.~..ðf.~!!!~!.i.~.~..IT~J~~)................................._ç~.~r.~!P.~.~!~~........ ......................................................................................................-............................................. 9 Normal Nonane NC9 ""'g.ïsõ"Ñõrlãñã'"''''''''''''''''''''''''''''''''''''''''''''''''''''''ïëg'''''''''''''''''''''''''''''''' ::::::~::~~2þ.~!ÿ'!p.y.~(9.i?~6:~~~~:::::::S::::::::::::::::::~f~~ÇŸf~:::::::::::::::::: ......~..!~~p.f.~I?y'.ISY.2!~~~~~D.~.................................ç~:9.Y.9.~.................. ......~...9.~.ðf.~D}~!~£~..IT~!~~>'.................................-ç~.~!~!p'.~!!~......... 10 Normal Decane NC10 "'1.õ'ïsõ"õãCãñë'''''''.'''''''''''''''''''' '"''''''''''''''''''''''''-ïc'1'õ''''''''''''''''''''''''''''' ~:IQ::~~~y.(i?f.~:p.ÿ'!p.y.~I9.i?~~~~~~::::::::::::::::::::::::~fI9.~ÇŸf~::::::::::::::: ...~.Q...!~~þ'~!y'~~y'~.I.~~.~~~~~.................................._ç.~.9.::Qy'ç~............... ...~.Q..9.~.Q..ðf.~.~~!~~.~..IT~.!~~L..........................._ç.~.9...~!~~.~.~!~~..... 11 Normal Undecane NC11 "'1Tïsõ",[fñdãCãñë""'''''''''''''''''''''''''''''''''''''''''''''-ïë1T'''''''''''................. :::n:::ç1IQy'çI~:i?~:6:~~~~~::ëf.9.!~~[:::::::::::::::~f:n:~ÇY.f~::::::::::::::: ...~.~...g.~.~..çy'~~g.~.~.~~~~~..Œ?!~!L................._ç.t~.:Qyç~............... ...~.~...9.~.Lðf.~.~~!~~.~..IT~.~~~>..............................._ç.~..1...~r.~~.~.~~..... 12 Normal Dodecane NC12 .......................................................................................................-........................................... 12 Iso Dodecane IC12 ::I?,:~Ç1IQy.~I9.i?~6:t~~~~:f.f.9.!~!)'::::::::::::::::::~fI?~çY.f~::::::::::::::: ...~.?g.~.?.gy'g~g.~.~.~~!:!~~..Œ?.!~!L.................._ç.~.~:çy'ç~............... 12 C 12 Aromatics (Total) C 12 Aromatics Total Cut Yield (should = 100%) C:\CPWIN\Eu C:\CPWIN\Eu C:\CPWIN\Eugene\9808-4.03D 0.0000 0.0447 7.4189 0.0000 0.0285 12.6925 0.0022 0.0421 10.5463 0.0022 0.0170 4.0006 0.0000 0.0000 0.0000 0.0000 0.0000 0.6931 0.0000 0.0000 0.2764 0.0000 0.0000 0.7404 0.0000 0.0000 1.7098 0.0000 0.0000 0.0000 0.0104 0.2301 0.0022 0.0141 4.4335 0.0000 0.0000 0.1775 0.0000 0.0349 3.2918 0.0000 0.0006 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 '0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 99.7730 99.98531100.0000 I 0.0000 1 0.0000 1 Interim Laboratory Report No.: 2002-009808-DRPK ITS Caleb Brett 1114 Seaco Avenue DeerPmk, TX77536 Ph: (713) 844 -3200 Fax: (713) 844-3330 SAMPLE DETAILS: SUBMITTED BY: NUMBER OF CONTAINERS: TYPE OF CONTAINERS: - ¡.{e''bðu5'T [1 Nil SA bST '#-3 Page Sample(s) received on Forest Oil Corporation Wednesday, November 06,2002 CUSTOMER PRODUCT DESCRIPTION: SAMPLE ID Crude As Received DST No.3 Crude Oil IBP-68F Gas Fraction DST No.3 Crude Oil 68-170F DST No.3 Crude Oil 170-270F DST No.3 Crude Oil 270-350F DST No.3 Crude Oil 350-400F DST No.3 Crude Oil 400-500F DST No.3 Crude Oil 500-550F DST No.3 Crude Oil 550-600F DST No.3 Crude Oil 600-650F DST No.3 Crude Oil 650-700F DST No.3 Crude Oil 700-750F DST No.3 Crude Oil 750+F DST No.3 Crude Oil 750-900F DST No.3 Crude Oil 900-950F DST No.3 Crude Oil 950-1032F DST No.3 Crude Oil 950+F DST No.3 Crude Oil 1032+F DST No.3 Crude Oil 2002-009808-DRPK -00 I 2002-009808-DRPK -002 2002-009808-DRPK-003 2002-009808-DRPK-004 2002-009808-DRPK-005 2002-009808-DRPK-006 2002-009808-DRPK-007 2002-009808-DRPK-008 2002-009808-DRPK-009 2002-009808-DRPK -0 I 0 2002-009808-DRPK-Ol1 2002-009808-DRPK -012 2002-009808-DRPK-013 2002-009808-DRPK-014 2002-009808-DRPK -015 2002-009808-DRPK-016 2002-009808-DRPK-0 17 2002-009808-DRPK-0 18 RESULTS: Sample ID: 2002-009808-DRPK-00I Customer Product Description: Crude As Received DST No.3 Crude Oil Method ASTM D323 I ASTM D3230 I ASTM D4294 I ASTM D445 (IP 71S1) I ASTM D445 (IP 71S1) I ASTM D445 (IP 71S1) I I Reid Vapor Pressure I Salt Content I Sulfur I Kinematic Viscosity at 15.6°C, 60°F I Kinematic Viscosity at 26.7°C, 80°F I Kinematic Viscosity at 37.8°C, 100°F Test Result Units psi lb /1000 bbls I Wt% I I I I 2.20 124 I 0.335 I 46.04 I 28.55 I 18.11 I cSt cSt cSt ITS Caleb Brett, 1114 Seaco Avenue, Deer Park, TX 77536 Ph: (713) 844 3200, Fax: (713) 844-3330 Sample ID: 2002-009808-DRPK-OOl Customer Product Description: Crude As Received DST No.3 Crude Oil Method ASTM D5002 I ASTM D664 (IP 177) ASTM D97 (IP 15) I UOP 163 Test Density 15.6°C, 60°F API Gravity 15.6°C, 60°F I Average Acid Number Pour Point Pour Point I Average H2S Sample ID: 2002-009808-DRPK-002 Customer Product Description: IBP-68F Gas Fraction DST No.3 Crude Oil Method ISM ASTM DHA Test Detailed Hydrocarbon Analysis Details Research Octane Number, Calculated Calculated Relative Density Sample ID: 2002-009808-DRPK-003 Customer Product Description: 68-170F DST No.3 Crude Oil Method ASTM D2622 I ASTM D4052 (IP 365) I ASTM D4052 (IP 365) ISM ASTM DHA Test Quality Control Sample Sulfur I API Gravity 15.6°C, 60°F I Relative Density 15.6°C, 60°F Detailed Hydrocarbon Analysis Details Research Octane Number, Calculated Sample ID: 2002-009808-DRPK-004 Customer Product Description: 170-270F DST No.3 Crude Oil Method ASTM D2622 I ASTM D4052 (IP 365) I ASTM D4052 (IP 365) ISM ASTM DHA Test Quality Control Sample Sulfur I API Gravity 15.6°C, 60°F I Relative Density 15.6°C, 60°F Detailed Hydrocarbon Analysis Details Research Octane Number, Calculated ') Interim Report Page 2 Result Units 0.8959 g/mL 26.4 °API 0.05 I mgKOH/g I -24 °C -11.2 of <I I ppm (Wt) Result See Attached Report 113.97 0.558 Result 100 <0.0003 78.2 I 0.6747 I See Attached Report 74.63 Result 100 0.0008 58.1 I 0.7462 I See Attached Report 65.06 ITS Caleb Brett, 1114 Seaco Avenue, Deer Park, TX 77536 Ph: (713) 844 3200, Fax: (713) 844-3330 Units Units ppm (Wt) Wt% °API Units ppm (Wt) Wt% °API ') ) Interim Report Page 3 Sample ID: 2002-009808-DRPK-005 Customer Product Description: 270-3S0F DST No.3 Crude Oil Method Test Result Units ASTM 01319 (IP 156) Aromatics 7.8 Vol % Olefins 1.8 Vol % Saturates 90.4 Vol % I ASTM 01322 (IP 57) I Smoke Point 24.5 I mm I ASTMDI840 I Naphthalenes 0.08 I Vol % ASTM 02386 Freezing Point <-72.0 °C Freezing Point <-97.5 of ASTM D2622 Quality Control Sample 100 ppm (Wt) Sulfur 0.0003 Wt% ASTM 04052 (IP 365) I API Gravity 15.6°C, 60°F 50.4 I °API I ASTM D4052 (IP 365) I Relative Oensity 15.6°C, 60°F 0.7780 I I ASTM 0664 (IP 177) I Average Acid Number <0.05 I mgKOHI g I UOP 163 I Average Mercaptan Sulfur 0.5 I ppm (Wt) I Sample ID: 2002-009808-DRPK-006 Customer Product Description: 350-400F DST No.3 Crude Oil Method I Test Result Units ASTM D1322 (IP 57) I Smoke Point 23.5 mm I ASTM D1840 ¡ Naphthalenes 0.68 I Vol % ASTM D2386 Freezing Point -64.0 °C Freezing Point -83.0 OF I ASTM D2622 I Sulfur 0.0024 I Wt% I I ASTM D4052 (IP 365) I API Gravity 15.6°C, 60°F 44.7 I °API I I ASTM D4052 (IP 365) I Relative Density 15.6°C, 60°F 0.8029 I I I ASTM D664 (IP 177) I Average Acid Number <0.05 I mg KOH I g I I UOP 163 I Average Mercaptan Sulfur 1.0 I ppm (Wt) I Sample ID: 2002-009808-DRPK-007 Customer Product Description: 400-S00F DST No.3 Crude Oil Method I Test Result Units ASTM D 1322 (IP 57) I Smoke Point 21.5 mm I ASTM Dl840 I Naphthalenes 3.72 I Vol % Sample ID: 2002-009808-DRPK-007 Customer Product Description: 400-500F DST No.3 Crude Oil Method ASTM D2386 I ASTM D2622 I ASTM D4052 (IP 365) I ASTM D4052 (IP 365) I ASTM D664 (IP 177) I UOP 163 Test Freezing Point Freezing Point I Sulfur I API Gravity 15.6°C, 60°F I Relative Density 15.6°C. 60°F I Average Acid Number I Average Mercaptan Sulfur Sample ID: 2002-009808-DRPK-008 Customer Product Description: 500-550F DST No.3 Crude Oil Method ASTM D 1322 (IP 57) I ASTM Dl840 ASTM D2386 I ASTM D4052 (IP 365) I ASTM D4052 (IP 365) I ASTM D4294 I I I ASTM D445 (IP 71S1) ASTM D445 (IP 71S1) ASTM D664 (IP 177) I I Smoke Point I Naphthalenes Freezing Point Freezing Point I API Gravity 15.6°C, 60°F I Relative Density 15.6°C, 60°F 1 Sulfur I Kinematic Viscosity at 26.7°C, 80°F I Kinematic Viscosity at 37.8°C, lOO°F I Average Acid Number Test ) Interim Report Page 4 Result Units -42.0 °C -43.5 of 0.0140 I Wt% I 38.1 I °API I 0.8345 I I <0.05 I mgKOH/ g I <0.1 I ppm (Wt) I Result Units 18.5 mm >5 I Vol % -20.5 °C -5.0 OF 34.5 I °API 0.8524 I 0.0462 I Wt% 4.049 I cSt I 3.219 I cSt I <0.05 I mgKOH/ g I ) Interim Report Page 5 Sample ID: 2002-009808-DRPK -008 Customer Product Description: 500-550F DST No.3 Crude Oil Method Test Result Units ASTM D86 Initial Boiling Point 500.8 of 5% Recovery 503.6 of 10% Recovery 504.5 of 20% Recovery 505.4 of 30% Recovery 506.7 of 40% Recovery 508.1 of 50% Recovery 509.3 of 60% Recovery 510.9 of 70% Recovery 513.1 of 80% Recovery 515.9 of 90% Recovery 520.6 of 95% Recovery 525.1 of Final Boiling Point 533.3 OF % Recovered 98.3 Vol % % Residue 1.4 Vol % % Loss 0.3 Vol % ASTM D97 (IP 15) Pour Point -21 °C Pour Point -5.8 of I ASTM D976 (IP 364) I Calculated Cetane Index 46.1 I I UOP 163 I Average Mercaptan Sulfur <0.1 I ppm (Wt) Sample ID: 2002-009808-DRPK-009 Customer Product Description: 550-600F DST No.3 Crude Oil Method I Test Result Units ASTM D4052 (IP 365) I API Gravity 15.6°C, 60°F 33.8 °API I ASTM D4052 (IP 365) I Relative Density 15.6°C, 60°F 0.8561 I I ASTM D4294 I Sulfur 0.0887 I Wt% I 1 ASTM D445 (IP 71S1) I Kinematic Viscosity at 26.7°C, 80°F 6.426 I cSt I I ASTM D445 (IP 71S1) I Kinematic Viscosity at 37.8°C, 100°F 4.796 I cSt I I ASTM D664 (IP 177) I Average Acid Number 0.05 I mgKOH/g I ITS Caleb Brett, 1114 Seaco Avenue, Deer Park, TX 77536 Ph: (713) 844 3200, Fax: (713) 844-3330 ') ') Interim Report Page 6 Sample ID: 2002-009808-DRPK-009 Customer Product Description: 550-600F DST No.3 Crude Oil Method Test Result Units ASTM D86 Initial Boiling Point 533.5 of 5% Recovery 552.2 of 10% Recovery 552.5 of 20% Recovery 554.1 of 30% Recovery 555.2 of 40% Recovery 556.4 of 50% Recovery 557.5 of 60% Recovery 559.0 of 70% Recovery 561.0 of 80% Recovery 563.6 OF 90% Recovery 568.1 OF . 95% Recovery 571.9 of Final Boiling Point 579.8 OF % Recovered 98.6 Vol % % Residue 1.3 Vol % % Loss 0.1 Vol % ASTM D97 (IP 15) Pour Point -12 °C Pour Point 10.4 OF I ASTM D976 (IP 364) I Calculated Cetane Index 49.8 I Sample ID: 2002-009808-DRPK-O 1 0 Customer Product Description: 600-650F DST No.3 Crude Oil Method I Test Result Units ASTM D4052 (IP 365) I API Gravity 15.6°C, 60°F 28.9 °API I ASTM D4052 (IP 365) I Relative Density 15.6°C, 60°F 0.8820 I I I ASTM D4294 I Sulfur 0.244 I Wt% 1 I ASTM D445 (IP 71S1) I Kinematic Viscosity at 26.7°C, 80°F 11.23 I cSt I I ASTM D445 (IP 71S1) I Kinematic Viscosity at 37 .8°C, 100°F 7.875 I cSt I I ASTM D664 (IP 177) I Average Acid Number 0.05 I mgKOHI g I ITS Caleb Brett, 1114 Seaco Avenue, Deer Park, TX 77536 Ph: (713) 844 3200, Fax: (713) 844-3330 ) ) Interim Report Page 7 Sample ID: 2002-009808-DRPK -010 Customer Product Description: 600-650F DST No.3 Crude Oil Method Test Result Units ASTM D86 Initial Boiling Point 587.6 of 5% Recovery 599.7 OF 10% Recovery 601.4 of 20% Recovery 601.8 OF 30% Recovery 602.8 of 40% Recovery 604.3 of 50% Recovery 605.0 of 60% Recovery 606.9 OF 70% Recovery 608.9 OF 80% Recovery 611.1 OF 90% Recovery 615.7 of 95% Recovery 619.4 of Final Boiling Point 623.3 of % Recovered 98.4 Vol % % Residue 1.3 Vol % % Loss 0.3 Vol % ASTM D97 (IP 15) Pour Point -3 °C Pour Point 26.6 of I ASTM D976 (IP 364) Calculated Cetane Index 45.3 I Sample ID: 2002-009808-DRPK-OII Customer Product Description: 650-700F DST No.3 Crude Oil Method I Test Result Units ASTM DI747 I Refractive Index at 20°C 1.4870 I ASTM D4052 (IP 365) I API Gravity 15.6°C, 60°F 27.4 I °API I I ASTM D4052 (IP 365) I Relative Density 15.6°C, 60°F 0.8903 I I I ASTM D4294 I Sulfur 0.347 I Wt% I I ASTM D4530 I Average Micro Carbon Residue <0.10 I Wt% I I ASTM D5762 I Nitrogen 321 I ppm (Jig I g) I I ASTM D664 (IP 177) I Average Acid Number 0.25 I mg KOH I g I ITS Caleb Brett, 1114 Seaco Avenue, Deer Park, TX 77536 Ph: (713) 844 3200, Fax: (713) 844-3330 ) ') Interim Report Page 8 Sample ID: 2002-009808-DRPK-Oll Customer Product Description: 650-700F DST No.3 Crude Oil Method Test Result Units ASTM D86 Initial Boiling Point 640.0 of 5% Recovery 642.0 of 10% Recovery 646.0 OF 20% Recovery 648.0 OF 30% Recovery 649.0 OF 40% Recovery 650.0 OF 50% Recovery 651.0 OF 60% Recovery 652.0 OF 70% Recovery 654.0 of 80% Recovery 656.0 OF 90% Recovery 658.0 OF 95% Recovery 659.0 of Final Boiling Point 674.0 OF % Recovered 98.0 Vol % % Residue 1.5 Vol % % Loss 0.5 Vol % I ASTM D976 (IP 364) I Calculated Cetane Index 44.4 I I UOP 269 I Basic Nitrogen 106 I ppm (Wt) Sample ID: 2002-009808-DRPK -012 Customer Product Description: 700-750F DST No.3 Crude Oil Method I Test Result Units ASTM DI747 I Refractive Index at 20°C 1.4914 I ASTM D4052 (IP 365) I API Gravity 15.6°C, 60°F 25.6 I °API I I ASTM D4052 (IP 365) I Relative Density 15.6°C, 60°F 0.9005 I I I ASTM D4294 I Sulfur 0.288 I Wt% I I ASTM D445 (IP 71SI) I Kinematic Viscosity at 60°C, 140°F 9.893 I cSt I I ASTM D445 (IP 71SI) I Kinematic Viscosity at 98.9°C, 210°F 3.981 I cSt I I ASTM D4530 I Average Micro Carbon Residue <0.10 I Wt% I I ASTM D5762 I Nitrogen 550 I ppm (~gl g) I I ASTM D664 (IP 177) I Average Acid Number 0.2 I mgKOHI g I ) ) Interim Report Page 9 Sample ID: 2002-009808-DRPK-0 12 Customer Product Description: 700-750F DST No.3 Crude Oil Method Test Result Units ASTM D86 Initial Boiling Point 674.0 of 5% Recovery 686.0 OF 10% Recovery 690.0 of 20% Recovery 694.0 of 30% Recovery 696.0 of 40% Recovery 697.0 of 50% Recovery 698.0 of 60% Recovery 701.0 of 70% Recovery 702.0 OF 80% Recovery 703.0 of 90% Recovery 711.0 OF 95% Recovery 718.0 OF Final Boiling Point 720.0 of % Recovered 97.0 Vol % % Residue 1.0 Vol % % Loss 2.0 Vol % I ASTM D976 (IP 364) I Calculated Cetane Index 41.8 I I UOP 269 I Basic Nitrogen 186 I ppm (Wt) Sample ID: 2002-009808-DRPK -013 Customer Product Description: 750+F DSTNo.3 Crude Oil Method I Test Result Units ASTM 04052 (IP 365) I API Gravity 15.6°C, 60°F 10.2 °API I ASTM 04052 (IP 365) I Relative Density 15.6°C, 60°F 0.9987 I Sample ID: 2002-009808-DRPK -014 Customer Product Description: 750-900F DST No.3 Crude Oil Method 1 Test Result Units ASTM D1747 I Refractive Index at 20°C 1.5040 I ASTM D4052 (IP 365) I API Gravity 15.6°C, 60°F 21.6 I °API I ASTM D4052 (IP 365) I Relative Density 15.6°C, 60°F 0.9245 I I ASTM D4294 I Sulfur 0.266 I Wt% I ASTM D445 (IP 71S1) I Kinematic Viscosity at 60°C, 140°F 31.17 I cSt I ASTM D445 (IP 71S1) I Kinematic Viscosity at 98.9°C, 210°F 8.763 I cSt ITS Caleb Brett, 1114 Seaco Avenue, Deer Park, TX 77536 Ph: (713) 844 3200, Fax: (713) 844-3330 ) ') Interim Report Page 10 Sample ID: 2002-009808-DRPK-014 Customer Product Description: 750-900F DST No.3 Crude Oil Method I Test Result Units ASTM D4530 I Average Micro Carbon Residue <0.10 Wt% I ASTM D5762 I Nitrogen 1202 I ppm (~g / g) I 1 ASTM D664 (IP 177) I Average Acid Number <0.05 I mgKOH/g I I UOP 269 I Basic Nitrogen 346 I ppm (Wt) I Sample ID: 2002-009808-DRPK -015 Customer Product Description: 900-950F DST No.3 Crude Oil Method Test Result Units ASTM D1747 Refractive Index at 20°C 1.5157 I ASTM D4052 (IP 365) API Gravity 15.6°C, 60°F 18.5 °API I ASTM D4052 (IP 365) Relative Density 15.6°C, 60°F 0.9432 I ASTM D4294 Sulfur 0.319 Wt% I ASTM D445 (IP 71SI) Kinematic Viscosity at 60°C, 140°F 84.41 cSt I ASTM D445 (IP 71S1) Kinematic Viscosity at 98.9°C, 210°F 17.02 cSt I ASTM D4530 Average Micro Carbon Residue 0.3 Wt% I ASTM D5762 Nitrogen 2059 ppm (~g / g) I ASTM D664 (IP 177) Average Acid Number <0.05 I mgKOH/ g I UOP 269 Basic Nitrogen 535 I ppm (Wt) Sample ID: 2002-009808-DRPK-0 16 Customer Product Description: 950-1032F DST No.3 Crude Oil Method I Test Result Units ASTM Dl747 I Refractive Index at 20°C 1.5277 I ASTM D4052 (IP 365) I API Gravity 15.6°C, 60°F 15.8 I °API I ASTM D4052 (IP 365) I Relative Density 15.6°C, 60°F 0.9608 I I ASTM D4294 I Sulfur 0.393 I Wt% I ASTM D445 (IP 71S1) I Kinematic Viscosity at 60°C, 140°F 269.3 I cSt I ASTM D445 (IP 71SI) I Kinematic Viscosity at 98.9°C, 210°F 37.55 I cSt I ASTM D4530 I Average Micro Carbon Residue 2.0 I Wt% I UOP 269 I Basic Nitrogen 928 I ppm (Wt) ITS Caleb Brett, 1114 Seaco Avenue, Deer Park, TX 77536 Ph: (713) 844 3200, Fax: (713) 844-3330 ) Interim Report Page II Sample ID: 2002-009808-DRPK-OI7 Customer Product Description: 950+F DST No.3 Crude Oil Method ASTM D3279 I ASTM D4294 I ASTM D445 (IP 71S1) I ASTM D445 (IP 71S1) ASTM D70 I Test I Average n-Pentane Insolubles I Sulfur I Kinematic Viscosity at 135°C, 275°F I Kinematic Viscosity at 98.9°C, 210°F Temperature Relative Density (Specific Gravity) API Gravity Result Units Wt% Wt% 25.6 0.545 I 675.9 I 9077 I 15.56°C,60°F 1.0324 5.6 cSt cSt °API Sample ID: 2002-009808-DRPK-018 Customer Product Description: 1032+F DST No.3 Crude Oil Method ASTM D2171 (IP 222) I ASTM D3279 I ASTM 04052 (IP 365) I ASTM D4052 (IP 365) I ASTM D4294 1 ASTM D445 (IP 71S1) I ASTM D445 (IP 71S1) I ASTM 0445 (IP 71S1) I ASTM D4530 ASTM D5708 I CTM Tesoro I UOP 269 I Test Result Units I Viscosity 1906400.0 poise T est Temperature 60°C, 140°F Vacuum 300 mmHg I Average n-Pentane Insolubles 30.5 I Wt% I I API Gravity 15.6°C, 60°F 2.6 I °API I I Relative Density 15.6°C, 60°F 1.055 I I I Sulfur 0.605 I Wt% I I Kinematic Viscosity at 135°C, 275°F 5796 I cSt I I Kinematic Viscosity at 148.9°C, 300°F 2197 I cSt I I Kinematic Viscosity @ 350 deg F 450.2 I cSt I I Average Micro Carbon Residue 29.0 I Wt% I Iron 55.3 ppm (mg I kg) Nickel 13.0 ppm (mg I kg) Vanadium 3.30 ppm (mg I kg) Sodium 45.6 ppm (mg I kg) Copper 2.20 ppm (mg I kg) I Toluene Equivalence 45 I Vol % I Basic Nitrogen 2537 I ppm (Wt) ITS Caleb Brett, 1114 Seaco Avenue, Deer Park, TX 77536 Ph: (713) 844 3200, Fax: (713) 844-3330 ') ) Interim Report . Page 12 This report has been reviewed for accuracy, completeness, and comparison against specifications where available. These results are subject to confinnation on completion of the final report. Laboratory Review Reported By Date: Date: ITS Caleb Brett, 1114 Seaco Avenue, Deer Park, TX 77536 Ph: (713) 844 3200, Fax: (713) 844-3330 ) ) fJOÐ-/Ú2 HALLIBURTDNI 7<e1:>()~ST UN I. sA Pressure Gauge Report Forest Oil . RII#5 DST (1, 2, 3) 1l.u 5A Dates 19-0ct-2002 to 03-Nov-2002 Field Cook Inlet Well Number: RU#5 DST (1, 2, 3) Well Type 01-0il RECEiVED APR 232 . PJi8ka O&~ & Gu 11\,cf¡Offt~j(.; ~~\Y'\~ CLIENT: Forest Oil FIELD: Cook Inlet WELL: RU#5 DST-l AREA: Alaska DATE 19-0ct-02 20-0ct-02 21-0ct-02 TIME 3:00:00 9:40:00 12:00:00 19:30:00 22:15:00 1 :30:00 10:00:00 10:30:00 13:00:00 14:00:00 22:00:00 1 :00:00 1:45:00 2:15:00 3:00:00 3:15:00 5:00:00 5:45:00 6:15:00 9:47:00 10:04:00 10:07:00 10: 10:00 10:23:00 10:27:00 10:38:00 11: 17 :00 ) HALLIBURTON SEQUENCE of ()PERATIONS OPERATIONS Pre-job Safety Meeting Start Memory Gauges Tools Started in Hole On depth with ToolslTCP Guns Pollard Slickline parted wire - Attempt to fish tools ') SALES ORDER: 2086030 GAUGE DEPTH: 14,962 ft. COMPANY REP. : Paul Winslow CONTACT PHONE: Pollard unable to recover tools - Begin Trip OOH to recover fish OOH - Debris, and loggin tool pieces on top ofLPR-N Attempt to clean out OMNI wlo success - change to backup tools Begin Picking up new LPR-N & OMNI Being Trip in hole with tools On bottom OOH wi Wireline cOITelation log Pull 57 feet to put guns on depth. Rig up Test Head Set Packer wi 25,000 down weight Start rigging up surface well test equipment PT Surface Equipment Pre Job Safety Meeting Start Pumping N2 for under balance Finished pumping N2 - 3000 psi surface pressure Start pressuring annulus to open LPR-N & Fire Guns 3100 psi on annulus Bleed annulus to 2850 & hold @ 10:07 pressure change noted at wellhead - only indicator guns fired. PTI opens well through adjustable choke to bleed N2 and flow well Monitor Annulus Bleed annulus to 0 psi to close LPR-N for first shut-in Monitor Annulus and maintain pressure Pressure up annulus to open LPR-N and start main flow period. CLIENT: Forest Oil FIELD: Cook Inlet WELL: RU#5 AREA: Alaska DATE 21-0ct-02 22-0ct-02 23 -Oct -02 24-0ct-02 25-0ct-02 TIME 21:00:00 22:03:00 0:00:00 10:24:00 10:30:00 14:00:00 22:30:00 0:00:00 2: 12:00 ') ') HALLIBURTDN SEQIJEN'CE,.of OPERATIONs SALES ORDER: 2086030 GAUGE DEPTH: 14,962 ft. COMPANY REP. : Paul Winslow CONTACT PHONE: OPERATIONS Fluid to surface - continue to flow well Wellhead shut-in after seeing pressure drop (10 psi to 0 psi) at surface Bleed annulus to 0 to close LPR-N and start final close in Monitor annulus for flow for 1 hour then close in choke Well shut-in for day Pressure annulus to 3500 psi - RD safety circ valve opens Start reversing out drill pipe (Reversed out 25 bbl oil then started getting water) Rig down PTS Surface Test Equipment @ Tools Tools Laid down - End Sales order Read and Report Gauge Data (Gauges stopped @ 2:12am 10/25) CLIENT: Forest Oil FIELD: Cook Inlet WELL: RU#5 DST-2 AREA: Alaska DATE 25-0ct-02 26-0ct-02 27-0ct-02 28-0ct-02 29-0ct-02 TIME 2:30:00 7: 12:00 10:00:00 16:15:00 16:45:00 16:50:00 17:00:00 17:00:00 22:30:00 22:56:00 23:04:00 10:30:00 8:05:00 8: 10:00 8:20:00 9:50:00 10: 15:00 13:45:00 23:00:00 7 :20:00 ') ) HALLIBURTON . SEQUENCE ofOPE:RATIONS SALES ORDER: 2108292 GAUGE DEPTH: 14,956 ft. COMPANY REP. : Paul Winslow CONTACT PHONE: OPERATIONS Pre-Job Safety Meeting Start Gauges Tools Started in Hole Tools on Depth - space out Make up control head Set packer @14981 Rig starts riggin up & PT PTS surface equipment Start pumping N2 for under balance Finish pumping N2 @ 2088 psi surface pressure - Rig down N2 lins Change to Alaska Standard Time from 23:30 Pressure annulus to open LRP-N (1700 psi) LPR-N open - Increase on drill pipe pressure (2088 - 3040 psi) Open well to flow - monitor annulus pressure while flowing well Fluid to surface - WHP @ 10 psi Bleed pressure off annulus Safety meeting Rig pressure up to 3200 psi and shear RD on RD Circ Valve and Reverse Out Stop Reversing Rig pick up on Drill Pipe and open bypass on packer and circulate Laydown testhead Lay down tools Download gauges CLIENT: Forest Oil FIELD: Cook Inlet WELL: RU#5 DST-3 AREA: Alaska DATE TIME 30-0ct-02 11:45:00 13:24:00 14:15:00 16: 15:00 31-0ct-02 3 :00:00 3:15:00 4:15:00 4:30:00 5:00:00 7:10:00 10:00:00 10:20:00 10:28:00 10:29:00 10:31 :00 10:35:00 10:58:00 11 :23:00 13:00:00 13:30:00 17:30:00 19:30:00 I-Nov-02 10:00:00 2-Nov-02 18:00:00 18:45:00 18:52:00 21 :00:00 21:45:00 ) ) HALLIBURTON SEQUENCE of OPERATIONS SALES ORDER: 2116661 GAUGE DEPTH: 14,946 f1. COMPANY REP. : Paul Winslow CONTACT PHONE: OPERATIONS Safety Meeting Started Gauges Pick up Test Tools Rig Started in hole wi BHA Set 75/8" Champ Packer @ 14971 PTS began Rigging up Surface Test Equipment Safety Meeting PT Surface Equipment to 4000 psi BJ down working on unit for N2 BJ Started pumping N2 BJ stopped pumping N2 @ 3000 psi on drill pipe Safety Meeting Rig started pressure up on annulus to 3000 psi LPR-N open Rig bled pressure on annulus to 2000 psi Guns fired Rig bled pressure off annulus Rig pressure up to 1700 psi on annulus PTS started bleeding N2 off drill pipe Rig had to keep putting pressure on annulus to keep it at 1700 psi N2 bled to 10 psi on drill pipe Fluid to surface with 20 psi Closed well in for 36 hrs Safety Meeting Pressured up to shear RD Circ Valve RD sheared @ 3670 psi and rig began reverse out Stopped reversing out Unset Packer CLIENT: Forest Oil FIELD: Cook Inlet WELL: RU#5 DST-3 AREA: Alaska DATE 2-Nov-02 3-Nov-02 TIME 23:00:00 7:00:00 7:15:00 7:30:00 8:00:00 15:00:00 17:00:00 ) ) HALLIBURTON SEQUENCE of OPERATIONS SALES ORDER: 2111661 GAUGE DEPTH: 14,946 ft. COMPANY REP. : Paul Winslow CONTACT PHONE: OPERATIONS Continued OaR wi BRA Tools to surface Safety Meeting Drain two drain valves Lay down tools Download gauges Depart location ) ') HALLIBURT'DN ~ottom Hole Pressure Survey, Results CLIENT: Forest Oil SALES ORDER: 2086030 FIELD: Cook Inlet COMPANY REP. : Paul Winslow WELL: RU#5 DST-1 CONTACT PHONE: AFC I PC : 025756/ GAUGE SPECIALIST: Tim Fletcher Upper Gauge Lower Gauge Wire Line Date Time MD SS 70318/70318 75338/75338 Tubing Spartek Spartek Pressure Press. (psia) Temp. Press. (psia) Temp. (psig) 19-0ct-02 19:48:30 14,962' MD 11,773' SS 5255.54 193.05° F 5250.59 190.68° F 20-0ct-02 01 :36:23 14,962' MD 11,773' SS 5255.44 192.88° F 5251.08 190.53° F 20-0ct-02 07:13:50 14,962' MD 11,773' SS 2858.36 122.67° F 2855.48 123.64° F 20-0ct-02 23:03:03 14,962' MD 11,773' SS 5258.81 194.02° F 5252.07 191.56° F 21-0ct-02 10:08:06 14,962' MD 11,773' SS 5216.40 193.40° F 5212.38 191.02° F 21-0ct-02 10:16:23 14,962' MD 11,773' SS 4207.70 194.05° F 3872.46 191.26° F 21-0ct-02 10:31 :19 14,962' MD 11,773' SS 4570.87 194.20° F 4565.35 191.72° F 21-0ct-02 10:43:11 14,962' MD 11,773' SS 4216.89 194.33° F 4210.72 191.81° F 21-0ct-02 11:17:10 14,962' MD 11,773' SS 5167.99 193.59° F 4523.76 190.83° F 21-0ct-02 20:37:34 14,962' MD 11,773' SS 5085.45 197.75° F 5082.27 194.96° F 22-0ct-02 22:02:35 14,962' MD 11,773' SS 5146.89 195.33° F 5144.66 192.73°F 24-0ct-02 10:20:02 14,962' MD 11,773' SS 5123.90 194.67° F 5216.51 192.19° F 24-0ct-02 14:57:07 14,962' MD 11,773' SS 5207.45 191.60° F 5203.89 189.27° F 24-0ct-02 15: 14:02 14,962' MD 11,773' SS 5319.86 191.05°F 5316.97 189.47°F Comments: Unusual Events: ) ') HALLIBURTON Bottom Hole Pressure Survey Results CLIENT: Forest Oil FIELD: Cook Inlet WELL: RU#5 DST-2 AFC I PC : 025756/ SALES ORDER: 2108292 COMPANY REP.: Paul Winslow CONTACT PHONE: GAUGE SPECIALIST: Dave Newton Upper Gauge Lower Gauge Date Time MD SS 70318/70318 75338 I 75338 Spartek Spartek Press. (psia) Temp. Press. (psi a) Temp. 26-0ct-02 16:49:47 14,956' MD 5309.77 193.01°F 5303.94 190.62° F 26-0ct-02 23:56:11 14,956' MD 5209.88 193.56° F 5205.82 191.13°F 27-0ct-02 00:03 :50 14,956' MD 4455.47 194.54° F 4451.02 191.98° F 27-0ct-02 02:28:03 14,956' MD 3787.53 197.34° F 3782.25 194.64° F 27-0ct-02 11: 13:03 14,956' MD 5080.61 197.23° F 5076.80 194.49° F 28-0ct-02 11 :06: 15 14,956' MD 5190.85 194.55° F 5185.76 192.08° F 28-0ct-02 14:29:10 14,956' MD 5388.41 174.65° F 5385.47 173.86° F 28-0ct-02 17:44: 10 14,956' MD 4364.83 159.47° F 4361.76 159.82° F Comments: Unusual Events: Wire Line Tubing Pressure (psig) ) ) HALLIBURTDN BottolD Hole Pressure Survey Results CLIENT: Forest Oil FIELD: Cook Inlet WELL: RU#5 DST-3 AFC I PC : 025756/ SALES ORDER: 2116661 COMPANY REP.: Paul Winslow CONTACT PHONE: GAUGE SPECIALIST: Dave Newton Upper Gauge Lower Gauge Date Time MD SS 70318/70318 75338 I 75338 Spartek Spartek Press. (psia) Temp. Press. (psia) Temp. 30-0ct-02 23:52:02 14,946' MD 5302.72 190.67° F 5300.61 188.50° F 31-0ct-02 03:01 :32 14,946' MD 5295.54 190.94° F 5292.01 188.71 ° F 31-0ct -02 09:24:00 14,946' MD 5299.54 191.74°F 5295.93 189.46° F 31-0ct-02 10:28:21 14,946' MD 5433.15 191.13°F 5425.21 189.66° F 31-0ct-02 10:34:28 14,946' MD 4262.92 192.44° F 4258.94 189.89° F 31-0ct-02 10:53:05 14,946' MD 4196.66 192.67° F 4193.17 190.28° F 31-0ct-02 11 :23:52 14,946' MD 5174.69 192.24° F 5171.38 189.88° F 31-0ct-02 14:24:00 14,946' MD 3919.60 197.58°F 3916.33 194.75° F 31-0ct-02 19:27:25 14,946' MD 4880.93 198.07° F 4877.66 195.18° F I-Nov-02 10:09: 16 14,946' MD 5105.27 197.87°F 5101.80 194.95° F 2-Nov-02 18:45:45 14,946' MD 5205.71 194.73°F 5203.44 192.17° F 2-Nov-02 21:37:12 14,946' MD 5218.92 194.31°F 5215.93 191.72° F 2-Nov-02 22:41 :48 14,946' MD 5304.46 192.85° F 5300.18 190.52° F 2-Nov-02 23:43:57 14,946' MD 5111.00 187.68° F 5108.00 185.75°F Comments: Unusual Events: Wire Line Tubing Pressure (psig) CLIENT: Forest Oil FIELD: Cook Inlet WELL: RU#5 DST-l AFC I PC : 025756/ 5000 5200 9XIO 4750 ct4500 ff 42SO 4000 3750 3500 I' I I I 30 Date 19-0ct-02 20-0ct-02 20-0ct-02 20-0ct-02 21-0ct-02 21-0ct-02 21-0ct-02 21-0ct-02 21-0ct-02 21-0ct-02 22-0ct-02 24-0ct-02 24-0ct-02 24-0ct-02 '--ALLIBURTON ) BOttOl11 HolePressureSurvev"'Rèsûlts SALES ORDER: 2086030 COMPANY REP. : Paul Winslow CONTACT PHONE: GAUGE SPECIALIST: Tim Fletcher 70318_RUII5_DST_#I P -""-- ß}rest Oil RU#5DST - Test ere (Gluge70318) '-, I I I I 40 Time 19:48:30 01 :36:23 07:13:50 23:03:03 10:08:06 10:16:23 10:31 :19 10:43: 11 11:17:10 20:37:34 22:02:35 10:20:02 14:57:07 15: 14:02 \ I I I I I I I I 50 60 ~Hrs 10.14 15.94 21.56 37.38 48.47 48.61 48.86 49.05 49.62 58.96 84.38 120.67 125.29 125.57 I I I I 70 æ 90 Della Tme (H) MD 14962 14962 14962 14962 14962 14962 14962 14962 14962 14962 14962 14962 14962 14962 I I I I I I I I TVD 11773 11773 11773 11773 11773 11773 11773 11773 11773 11773 11773 11773 11773 11773 70318_RUII5_DST_#I T I I I I I I I I 100 110 Pressure 5255.54 psia 5255.44 psia 2858.36 psia 5258.81 psia 5216.40 psia 4207.70 psi a 4570.87 psia 4216.89 psia 5167.99 psia 5085.45 psia 5146.89 psia 5123.90 psia 5207.45 psia 5319.86 psia 120 . 205.0 ~ j~ 200.0 - j j 197.5 ~ Ii? 195.0 ~ 1 !II 192.5 --' -" IIDi 190.0 - ~ 187.5 I I I II: l,i-185.0 130 Temp 193.05° F 192.88° F 122.67° F 194.02° F 193.40° F 194.05° F 194.20° F 194.33° F 193.59° F 197.75° F 195.33° F 194.67° F 191.60° F 191.05° F CLIENT: Forest Oil FIELD: Cook Inlet WELL: RU#5 DST-l AFC / PC : 025756/ ~ALLIBURTON ) Bottom Hole PressureSurvevResults SALES ORDER: 2086030 COMPANY REP. : Paul Winslow CONTACT PHONE: GAUGE SPECIALIST: Tim Fletcher 5500 75338_RUII5_DST_#1 P 75338_RUII5_DST_#1 T . 205.0 :furest Oil RU#5ŒT - Test em (G:luge75338) 5200 ~ I 202.5 42SO ~ ~ t: 3 i =~ 195.0 ~ !DK) 4700 c( 4500 if -' \ ~ 192.5 '-, '" ~ 1, 190.0 4000 \ ~ ¡., 187.5 3700 -< 3500 1 1 I 1 1 1 1 1 1 I 1 1 1 1 1 1 I I 1 I 1 1 1 I I 1 1 1 1 I 1 1 1 I 1 1 1 I lEI I. IlL 185.0 30 40 00 m 70 80 90 100 110 120 130 DellaTme(H) Date Time ~Hrs MD TVD Pressure Temp 19-0ct-02 19:48:30 10.14 14962 11773 5250.59 psia 190.68° F 20-0ct-02 01 :36:23 15.94 14962 11773 5251.08 psia 190.53° F 20-0ct-02 07:13:50 21.56 14962 11773 2855.48 psia 123.64° F 20-0ct-02 23:03:03 37.38 14962 11773 5252.07 psia 191.56° F 21-0ct-02 10:08:06 48.47 14962 11773 5212.38 psia 191.02° F 21-0ct-02 10:16:23 48.61 14962 11773 3872.46 psia 191.26° F 21-0ct-02 10:31:19 48.86 14962 11773 4565.35 psia 191.72° F 21-0ct-02 10:43: 11 49.05 14962 11773 4210.72 psia 191.81° F 21-0ct-02 11:17:10 49.62 14962 11773 4523.76 psia 190.83° F 21-0ct-02 20:37:34 58.96 14962 11773 5082.27 psia 194.96° F 22-0ct-02 22:02:35 84.38 14962 11773 5144.66 psia 192.73°F 24-0ct-02 10:20:02 120.67 14962 11773 5216.51 psia 192.19° F 24-0ct-02 14:57:07 125.29 14962 11773 5203.89 psia 189.27° F 24-0ct-02 15: 14:02 125.57 14962 11773 5316.97 psia 189.47° F CLIENT: Forest Oil FIELD: Cook Inlet WELL: RU#5 DST-2 AFC / PC : 025756/ ~ALLIBURTDN ) Bottom Hole Ptessure. SurvevResults SALES ORDER: 2108292 COMPANY REP. : Paul Winslow CONTACT PHONE: GAUGE SPECIALIST: Dave Newton 5200 '-- ,n . tmo - ~ 202.5 furest Oil RU#5ŒT - TestT\\O(Gluge70318) 5500 RUI#5A DST#2 70318) P RU#I5A DST#2(7031S: T 4250 ,--- í" 200.0 j 5000 «4500 if ~ f 1~5 ~ '. 195.0 ~ 4700 "l 4000 III 192.5 :I -! r } 190.0 ~ 3700 !II 187.5 -, - 3500 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I !"-185.0 I 5 10 15 æ 25 30 35 40 45 00 55 60 Della Tme (H) Date Time ~Hrs MD TVD Pressure Temp 26-0ct-02 16:49:47 9.63 14956 5309.77 psia 193.01°F 26-0ct-02 23:56:11 16.74 14956 5209.88 psia 193.56° F 27 -Oct-02 00:03:50 16.86 14956 4455.47 psia 194.54° F 27-0ct-02 02:28:03 19.27 14956 3787.53 psia 197.34° F 27 -Oct-02 11 :13:03 28.02 14956 5080.61 psia 197.23°F 28-0ct-02 11:06:15 51.90 14956 5190.85 psia 194.55° F 28-0ct-02 14:29:10 55.29 14956 5388.41 psia 174.65° F 28-0ct-02 17:44:10 58.54 14956 4364.83 psia 159.47°F ~ALLIBURTDN ) Bottom Hole Pressure, Survey Results SALES ORDER: 2108292 COMPANY REP. : Paul Winslow CONTACT PHONE: GAUGE SPECIALIST: Dave Newton CLIENT: Forest Oil FIELD: Cook Inlet WELL: RU#5 DST-2 AFC I PC : 025756/ furest Oil RU#5 - Test T~(Gmge75338) 5500 RUt#5A DSTtt:z(75338) P RUt#5A DSTtr.Z(75338 T 1. 525) ~ 0000 4750 4(4500 ~ 42S) 4000 ,--. 3750 205.0 ,0. 202.5 -' 200.0 ~ ~ 197.5 ~ 19&0 ! ~ -q -; . 192.5 j .. 190.0 187.5 - 3!Ð) I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 185.0 I 5 10 15 2D 25 30 35 40 45 50 55 60 Delta Trne (H) Date Time ßHrs MD TVD Pressure Temp 26-0ct-02 16:49:47 9.63 14956 5303.94 psia 190.620 F 26-0ct-02 23:56:11 16.74 14956 5205.82 psia 191.13°F 27 -Oct-02 00:03 :50 16.86 14956 4451.02 psia 191.980 F 27 -Oct-02 02:28:03 19.27 14956 3782.25 psia 194.640 F 27-0ct-02 11:13:03 28.02 14956 5076.80 psia 194.490 F 28-0ct-02 11:06:15 51.90 14956 5185.76 psia 192.080 F 28-0ct-02 14:29:10 55.29 14956 5385.47 psia 173.860 F 28-0ct-02 17:44:10 58.54 14956 4361.76 psia 159.820 F CLIENT: Forest Oil FIELD: Cook Inlet WELL: RU#5 DST-3 AFC I PC : 025756/ 5500 5250 0000 4750 c( 4500 ~ 4250 4000 3750 3500 i I Date 30-0ct-02 31-0ct-02 31-0ct-02 31-0ct-02 31-0ct-02 31-0ct -02 31-0ct-02 31-0ct-02 31-0ct-02 1-Nov-02 2-Nov-02 2-Nov-02 2-Nov-02 2-Nov-02 ~, ~ I I I I 10 Time 23:52:02 03:01 :32 09:24:00 10:28:21 10:34:28 10:53:05 11 :23:52 14:24:00 19:27:25 10:09:16 18:45:45 21:37:12 22:41 :48 23:43:57 ~ALLIBURTDN ) . Bottom HolePress1Ìre SutvevResuIts . . SALES ORDER: 2116661 COMPANY REP. : Paul Winslow CONTACT PHONE: GAUGE SPECIALIST: Dave Newton RUI#5 DST~18) P furest Oil RU#5- DST Three (GIuge 7Œ 18) RU##5 DST#3(10318) T 20 " I I I I 3) ~Hrs 10.47 13.63 20.00 21.07 21.17 21.48 22.00 25.00 30.06 44.75 77.36 80.22 81.30 82.33 '~.~ I I I I I I I I I I I I I I I I 40 50 Della Tme (H) 60 70 MD 14946 14946 14946 14946 14946 14946 14946 14946 14946 14946 14946 14946 14946 14946 TVD Pressure 5302.72 psia 5295.54 psia 5299.54 psia 5433.15 psia 4262.92 psia 4196.66 psia 5174.69 psia 3919.60 psia 4880.93 psia 5105.27 psia 5205.71 psia 5218.92 psia 5304.46 psia 5111.00 psia I I I I Lr 1 \ . ~: 200.0 - r 197.5 ~ 5? ~ 195.0 ~ 1.. 192.5 J 190.0 I I 11~~ , t 1850 90 80 Temp 190.67° F 190.94° F 191.74°F 191.13° F 192.44° F 192.67° F 192.24° F 197.58°F 198.07° F 197.87°F 194.73°F 194.31° F 192.85° F 187.68°F CLIENT: Forest Oil FIELD: Cook Inlet WELL: RU#5 DST-3 AFC I PC : 025756/ 5000 5250 5000 4700 ~4000 ~ 4250 4000 3700 3500 i 1 Date 30-0ct-02 31-0ct-02 31-0ct-02 31-0ct-02 31-0ct -02 31-0ct-02 31-0ct-02 31-0ct-02 31-0ct-02 I-Nov-02 2-Nov-02 2-Nov-02 2-Nov-02 2-Nov-02 ¡"ALLIBURTDN ') Bottom Hole PresslIre SurvevResults SALES ORDER: 2116661 COMPANY REP. : Paul Winslow CONTACT PHONE: GAUGE SPECIALIST: Dave Newton furest Oil RU#5- asT 3 (Gluge75338) RU#6 DST#ß(7æ38) P r---;¡ ~ I 1 1 1 10 Time 23:52:02 03:01 :32 09:24:00 10:28:21 10:34:28 10:53:05 11 :23:52 14:24:00 19:27:25 10:09:16 18:45:45 21:37:12 22:41 :48 23:43:57 20 RU#6~æ38)T / 1 1 I 1 1 1 1 1 I I 1 1 1 1 I 1 1 1 1 I 30 40 70 00 DellaTme(H) 60 LlHrs 10.47 13.63 20.00 21.07 21.17 21.48 22.00 25.00 30.06 44.75 77.36 80.22 81.30 82.33 MD 14946 14946 14946 14946 14946 14946 14946 14946 14946 14946 14946 14946 14946 14946 TVD Pressure 5300.61 psia 5292.01 psia 5295.93 psia 5425.21 psia 4258.94 psia 4193.17 psia 5171.38 psia 3916.33 psia 4877.66 psia 5101.80 psia 5203.44 psia 5215.93 psia 5300.18 psia 5108.00 psia 1 I I 1 . 205.0 Lr 2025 200.0 197.5 i - -r 195.0 ~ 'ì fm5 .JA 190.0 -; .J, 80 =í 187.5 11 1 lit 185.0 90 Temp 188.50° F 188.71 ° F 189.46° F 189.66° F 189.89° F 190.28° F 189.88° F 194.75° F 195.18° F 194.95° F 192.17° F 191.72° F 190.52° F 185.75° F ) HALLIBURTON ) Equipment Specifications Customer: Forest Oil Field: Cook Inlet Well: RU#5 DST-l Sales Order: 2086030 Customer Rep: Paul Winslow Customer Phone: Spartek Gauge Specifications Gauge Serial Number Calibration Date Pressure Rating Temperature Rating Data Points Available 70318 01-Feb-2002 6,000 psi 300 ° F 260,000 Data Sets Sensor Type Pressure Accuracy Resolution Temperature Accuracy Pressure Drift Housing Material O.D. Length Sapphire Crystal 0.024% Full Scale 0.0003% Full Scale 0.20° F < 2 psi ¡ Year Inconel 718 1.25 in 25. in Spartek Gauge Specifications Gauge Serial Number Calibration Date Pressure Rating Temperature Rating Data Points Available 75338 28-Apr-2002 6,000 psi 300.00° F 260,000 Data Sets Sensor Type Pressure Accuracy Resolution Temperature Accuracy Pressure Drift Housing Material O.D. Length Sapphire Crystal 0.02% Full Scale 0.0003% Full Scale 0.20° F < 2 psi ¡Year Inconel 718 1.25 25 fJð'ð -} t.D~ -Production T estingServices ( wELL' RU#5A DST#1 DATE 10/21102 TO 10/22/02 Clock Cum Choke Tubing Tubing Static Diff. Meter Date time Time Comments Size Pres. IJA O/A Temp Pres. Pres Temp mmlddlyy hhlmm hr. in. psi(g) of psi(g) in. of H2O F 10/21/02 10:30:00 0.00 Open well up to Tank A via sep. by :>ass thru adjustable choke 10:30:00 0.00 9.000 3136 10:33:00 0.05 13.000 3065 10:35:00 0.08 15.000 3061 10:36:00 0.10 15.000 3008 10:37:00 0.12 16.000 2978 10:39:00 0.15 16.000 2902 10:40:00 0.17 16.000 2866 10:42:00 0.20 16.000 2817 10:44:00 0.23 Shut In 0.000 2744 11 :20:00 0.83 open well up to tank A via sep. 11 :20:00 0.83 Flow N2 14.000 2805 11:30:00 1.00 Flow N2 14.000 2598 12:00:00 1.50 Flow N2 14.000 2078 12:30:00 2.00 Flow N2 14.000 1656 13:00:00 2.50 Flow N2 14.000 1304 13:30:00 3.00 Flow N2 14.000 1006 1527 14:00:00 3.50 Flow N2 14.000 722 1598 14:30:00 4.00 Flow N2 14.000 495 1594 15:00:00 4.50 Flow N2 14.000 311 1536 15:30:00 5.00 Flow N2 14.000 149 1611 16:00:00 5.50 slightly ga~ 14.000 52 1561 16:30:00 6.00 slight blow 14.000 1 1606 17:00:00 6.50 slight blow 14.000 0 1510 17:30:00 7.00 slight blow 14.000 1 1530 18:00:00 7.50 slight blow 14.000 1 1520 18:30:00 8.00 slight blow 14.000 1 1552 19:00:00 8.50 slight blow 14.000 1 1589 19:30:00 9.00 slight blow 14.000 1 1570 20:00:00 9.50 slight blow 14.000 1 1539 20:30:00 10.00 slight blow 14.000 1 1542 21:00:00 10.50 slight blow 14.000 1 1540 21 :00:00 10.50 mud to surface intermittent blow 21:12:00 10.70 I 50.000\ 10 21 :30:00 11.00 slight blow\ 50.000 11 1536 21 :35:00 11.08 bypass & shut down heater 21 :48:00 11.30 mud to sep. 22:00:00 11.50 slow mud 50.000 22:30:00 12.00 slow mud 50.000 23:00:00 12.50 bypass 23:30:00 13.00 ( 58 57 58 58 56 56 56 55 54 52 53 53 52 53 52 52 52 53 53 52 53 44 1587 13 1620 7 1540 8 1563 53 53 55 55 Gas Cum Fluid Fluid. Fluid Cum. Oil Oil Cum H2O CUM H2O Orifice Rate Gas Meter BSW Gain Rate Fluid Gain Rate Oil Gain H2O Rate GOR in. MMCFID MMCF BBL % BBL BBlJD BBL BBL BBlJD BBL BBL BBL BBlJD MMCFIBBL 0.000 0.000 0.000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.000 0 0 0 100 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ~ë(;EIVED APR 23 2003 Aia~ œ & G~ Coos. CommiMoo An :tfOfefge 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 16.000 17.720 100 1.720 24.282 1.720 0.000 0.000 0.000 1.720 1.720 24.282 Prepared by pts 04/22/2003 Page 1 "'roduction T estingServices WELL. RU#5A DST#I j)å.TE', 10/21/02 TO 10/22/02 Clock Cum Choke Tubing Tubing Static Diff. Meter Gas Cum Fluid Fluid Fluid Cum. Oil Oil Cum H2O CUM H2O Date time Time Comments Size Pres. IIA O/A Temp Pres~ Pres Temp Orifice Rate Gas Meter BSW Gain Rate Fluid Gain Rate Oil Gain H2O Rate GOR mmldd/yy hh/mm hr. in. psi(g) of psi(g) in. of H2O F in. MMCF/D MMCF BBL % BBL BBL/D BBL BBL BBLID BBL BBL BBL BBLID MMCFIBBL 10/22/02 0:00:00 13.50 2 1560 55 19.420 100 1.700 81.600 3.420 0.000 0.000 0.000 1.700 3.420 81.600 0:30:00 14.00 5 1563 56 21.120 100 1.700 81.600 5.120 0.000 0.000 0.000 1.700 5.120 81.600 1 :00:00 14.50 8 1618 55 24.420 100 3.300 158.400 8.420 0.000 0.000 0.000 3.300 8.420 158.400 1 :30:00 15.00 5 1550 53 26.120 100 1.700 81.600 10.120 0.000 0.000 0.000 1.700 10.120 81.600 1 :55:00 15.42 oil to sep 0 2:00:00 15.50 4 1585 54 29.520 90 3.400 163.200 13.520 0.340 16.320 0.340 3.060 13.180 146.880 2:15:00 15.75 25.000 31.220 90 1.700 163.200 15.220 0.170 16.320 0.510 1.530 14.710 146.880 ( 2:30:00 16.00 4 1517 52 31.640 90 0.420 40.320 15.640 0.042 4.032 0.552 0.378 15.088 36.288 2:31 :00 16.02 50.000 90 3:00:00 16.50 positive 50.000 7 1543 54 34.520 70 2.880 138.240 18.520 0.864 41.472 1.416 2.016 17.104 96.768 3:15:00 16.75 50.000 34.520 70 0.000 0.000 18.520 0.000 0.000 1.416 0.000 17.104 0.000 3:30:00 17.00 50.000 4 1576 54 34.520 70 0.000 0.000 18.520 0.000 0.000 1.416 0.000 17.104 0.000 3:45:00 17,25 50.000 34.520 70 0.000 0.000 18.520 0.000 0.000 1.416 0,000 17.104 0.000 4:00:00 17.50 50.000 8 1519 55 36.220 70 1.700 163.200 20.220 0.510 48.960 1.926 1.190 18.294 114.240 4:15:00 17.75 50.000 37.920 70 1.700 163.200 21.920 0.510 48.960 2.436 1.190 19.484 114.240 4:30:00 18.00 50.000 4 1570 53 39.620 70 1.700 163.200 23.620 0.510 48.960 2.946 1.190 20.674 114.240 4:45:00 18.25 50.000 39.620 70 0.000 0.000 23.620 0.000 0.000 2.946 0.000 20.674 0.000 5:00:00 18.50 50.000 8 1506 55 40.420 70 0.800 76.800 24.420 0.240 23.040 3.186 0.560 21.234 53.760 5:15:00 18.75 50.000 41.220 70 0.800 76.800 25.220 0.240 23.040 3.426 0.560 21.794 53.760 5:30:00 19.00 50.000 4 1567 54 41.220 45 0.000 0.000 25.220 0.000 0.000 3.426 0.000 21.794 0.000 5:45:00 19.25 50.000 42.070 45 0.850 81.600 26.070 0.468 44.880 3.894 0.383 22.176 36.720 6:00:00 19.50 50.000 7 1600 54 42.070 45 0.000 0.000 26.070 0.000 0.000 3.894 0.000 22.176 0.000 6:15:00 19.75 50.000 42.070 45 0.000 0.000 26.070 0.000 0.000 3.894 0.000 22.176 0.000 6:30:00 20.00 50.000 8 1538 54 43.770 35 1.700 163.200 27.770 1.105 106.080 4.999 0.595 22.771 57.120 6:45:00 20.25 50.000 44.570 35 0.800 76.800 28.570 0.520 49.920 5.519 0.280 23.051 26.880 7:00:00 20.50 50.000 4 1571 54 44.570 35 0.000 0.000 28.570 0.000 0.000 5.519 0.000 23.051 0.000 7:15:00 20.75 50.000 44.570 35 0.000 0.000 28.570 0.000 0.000 5.519 0.000 23.051 0.000 ( 7:30:00 21.00 50.000 4 1506 54 44.570 35 0.000 0.000 28.570 0.000 0.000 5.519 0.000 23.051 0.000 7:45:00 21.25 50.000 44.570 35 0.000 0.000 28.570 0.000 0.000 5.519 0.000 23.051 0.000 8:00:00 21.50 50.000 4 1556 53 45.470 35 0.900 86.400 29.470 0.585 56.160 6.103 0.315 23.366 30.240 8:15:00 21.75 50.000 45.470 35 0.000 0.000 29.470 0.000 0.000 6.103 0.000 23.366 0.000 8:30:00 22.00 50.000 7 1611 53 46.320 25 0.850 81.600 30.320 0.638 61.200 6.741 0.213 23.579 20.400 8:45:00 22.25 50.000 48.020 25 1.700 163.200 32.020 1.275 122.400 8.016 0.425 24.004 40.800 9:00:00 22.50 50.000 6 1554 52 49.620 25 1.600 153.600 33.620 1.200 115.200 9.216 0.400 24.404 38.400 9:15:00 22.75 50.000 50.470 25 0.850 81.600 34.470 0.638 61.200 9.853 0.213 24.616 20.400 9:30:00 23.00 22.3 API Gravity @ 60 F 9:30:00 23.00 50.000 7 1448 52 50.470 30 0.000 0.000 34.470 0.000 0.000 9.853 0.000 24.616 0.000 9:45:00 23.25 50.000 50.470 25 0.000 0.000 34.470 0.000 0.000 9.853 0.000 24.616 0.000 10:00:00 23.50 50.000 8 1554 51 52.170 25 1.700 163.200 36.170 1.275 122.400 11.129 0.425 25.041 40.800 10:15:00 23.75 50.000 52.170 25 0.000 0.000 36.170 0.000 0.000 11 .129 0.000 25.041 0.000 10:30:00 24.00 50.000 7 1438 51 52.170 20 0.000 0.000 36.170 0.000 0.000 11.129 0.000 25.041 0.000 Prepared by pts 04/22/2003 Page 2 ,. 'lie ""roduction T estingServices WELL RU#5A DST#1 DATE 10/21/02 TO 10/22/02 Clock Cum Choke Tubing Tubing Static DitT. Meter Gas Cum Fluid Fluid Fluid Cum. Oil Oil Cum H2O CUM H2O Date time Time Comments Size Pres. IIA O/A Temp Pres. Pres Temp Orifice Rate Gas Meter BSW Gain Rate Fluid Gain Rate Oil Gain H2O Rate GOR mmldd/yy hh/mm hr. in. psi(g) of psi(g) in. of H2O F in. MMCFID MMCF BBL % BBL BBLID BBL BBL BBLID BBL BBL BBL BBLID MMCFIBBL 10:45:00 24.25 50.000 52.170 25 0.000 0.000 36.170 0.000 0.000 11.129 0.000 25.041 0.000 11 :00:00 24.50 50.000 7 1590 51 53.140 25 0.970 93.120 37.140 0.727 69.840 11.856 0.242 25.284 23.280 11 :30:00 25.00 50.000 7 1564 51 53.870 15 0.730 35.040 37.870 0.620 29.784 12.476 0.109 25.393 5.256 12:00:00 25.50 50.000 8 1550 50 54.720 15 0.850 40.800 38.720 0.723 34.680 13.199 0.128 25.521 6.120 12:30:00 26.00 50.000 7 1529 50 55.570 15 0.850 40.800 39.570 0.723 34.680 13.922 0.128 25.648 6.120 13:00:00 26.50 50.000 5 1560 51 56.420 12 0.850 40.800 40.420 0.748 35.904 14.670 0.102 25.750 4.896 13:30:00 27.00 50.000 8 1614 51 57.220 8 0.800 38.400 41.220 0.736 35.328 15.406 0.064 25.814 3.072 ( 14:00:00 27.50 50.000 6 1547 51 58.020 12 0.800 38.400 42.020 0.704 33.792 16.110 0.096 25.910 4.608 14:30:00 28.00 50.000 7 1525 51 59.460 15 1.440 69.120 43.460 1.224 58.752 17.334 0.216 26.126 10,368 15:00:00 28.50 50.000 6 1539 51 61.160 15 1.700 81.600 45.160 1.445 69.360 18.778 0.255 26.381 12.240 15:30:00 29.00 50.000 5 1599 51 62.270 12 1.110 53.280 46.270 0.977 46.886 19.755 0.133 26.515 6.394 16:00:00 29.50 50.000 7 1527 51 63.120 12 0.850 40.800 47.120 0.748 35.904 20.503 0.102 26.617 4.896 16:30:00 30.00 50.000 7 1570 51 63.970 8 0.850 40.800 47.970 0.782 37.536 21.285 0.068 26.685 3.264 17:00:00 30.50 50.000 7 1510 51 65.220 15 1.250 60.000 49.220 1.063 51.000 22.348 0.188 26.872 9.000 17:30:00 31.00 50.000 7 1570 51 66.420 10 1.200 57.600 50.420 1.080 51.840 23.428 0.120 26.992 5.760 18:00:00 31.50 50.000 8 1504 51 67.690 6 1.270 60.960 51.690 1.194 57.302 24.622 0.076 27.068 3.658 18:00:00 31.50 29.4 API Gravity @ 60 F 18:30:00 32.00 50.000 51 68.540 8 0.850 40.800 52.540 0.782 37.536 25.404 0.068 27.136 3.264 19:00:00 32.50 50.000 10 1506 51 68.970 6 0.430 20.640 52.970 0.404 19.402 25.808 0.026 27.162 1.238 19:30:00 33.00 50.000 9 1545 51 69.620 6 0.650 31.200 53.620 0.611 29.328 26.419 0.039 27.201 1.872 20:00:00 33.50 50.000 12 1572 49 70.470 6 0.850 40.800 54.470 0.799 38.352 27.218 0.051 27.252 2.448 20: 1 0:00 33.67 27.2 API Gravity @ 60 F 20:30:00 34.00 150.000\ 12 1506 48 70.470 6 0.000 0.000 54.470 0.000 0.000 27.218 0.000 27.252 0.000 21 :00:00 34.50 50.000 11 1551 48 70.470 6 0.000 0.000 54.470 0.000 0.000 27.218 0.000 27.252 0.000 21:12:00 34.70 26.6 API Gravity @ 60 F 21 :30:00 35.00 I 50.0001 12 1490 48 71.320 6 0.850 40.800 55.320 0.799 38.352 28.017 0,051 27.303 2.448 ( 21 :40:00 35.17 26.2 API Gravity @ 60 F 22:00:00 35.50 I 50.0001 10 1486 50 72.120 6 0.800 38.400 56.120 0.752 36.096 28.769 0.048 27.351 2.304 22:04:00 35.57 Bleeding down LPRN 22:05:00 35.58 Well Shut IN I Prepared by pts 04/22/2003 Page 3 " "roduction Testing Services 10/28/02 Tubing Static Diff. Meter Gas Cum Fluid Fluid Fluid Cum. Oil Oil Cum O/A Temp Pres. Pres Temp Orifice Rate Gas Meter BSW Gain Rate Fluid Gain Rate Oil of psi(g) in. of H2O F in. MMCFID MMCF BBL % BBL BBLID BBL BBL BBLID BBL 0.000 0.000 ( f(u~A ~Test2 .DATE. 10/26/2002 Clock Cum Choke Tubing Date time Time Comments Size Pres. IIA mmldd/yy hblmm hr. in. psi (g) 10/26/02 2nd Test on 1st Zone 22:22:00 0.00 N2 Pumped to 3000 Ibs. 23:00:00 0.63 SITP 3088 @ 73 F Begin N2 Bleed to Tank A 23:00:00 0.63 0 0 23:30:00 1.13 15.00 2550 1600 10/27/02 0:00:00 1.63 15.00 2100 1660 0:30:00 2.13 15.00 1700 1660 1:00:00 2.63 15.00 1385 1677 1 :30:00 3.13 15.00 1120 1640 2:00:00 3.63 15.00 877 1614 2:30:00 4.13 15.00 662 1677 3:00:00 4.63 15.00 467 1649 3:30:00 5.13 15,00 322 1620 4:00:00 5.63 15.00 177 1684 4:30:00 6.13 Pos.choke 16.00 84 1640 5:00:00 6.63 16.00 19 1700 5:30:00 7.13 16.00 11 1644 6:00:00 7.63 16.00 10 1679 6:30:00 8.13 16.00 10 1639 7:00:00 8.63 16.00 11 1636 7:00:00 8.63 Divert Flow Through Manifold Bypass 7:30:00 9.13 64.00 9 1679 8:00:00 9.63 64.00 9 1605 8:30:00 10.13 64.00 8 1642 9:00:00 10.63 64.00 8 1668 9:30:00 11.13 64.00 8 1699 10:00:00 11.63 64.00 10 1638 10:30:00 12.13 Fluid in surface 10:30:00 12.13 64.00 16 1679 10:45:00 12.38 64.00 16 1640 11 :00:00 12.63 64.00 16 1609 11:30:00 13.13 64.00 15 1640 12:00:00 13.63 64.00 19 1664 12:00:00 13.63 10.9 API Gravity @ 60 F 12:30:00 14.13 I 64.001 15 1690 13:00:00 14.63 11.4 API Gravity @ 60 F 13:00:00 14.63 64.00 15 1625 13:30:00 15.13 64.00 16 1651 14:00:00 15.63 Trace gas 64.00 14:00:00 15.63 11.4 API Gravity @ 60 F 14:30:00 16.13 Trace gas I 64.001 15 1531 WELL. TO ( 0 0.000 59 0.000 58 0.000 57 0.000 57 0.000 58 0.000 56 0.000 52 0.000 55 0.000 54 0.000 52 0.000 50 0.000 48 0.000 47 0.000 45 0.000 45 0.000 44 0.000 45 0.000 44 0.000 46 0.000 46 0.000 47 0.000 46 0.000 52 0.000 52 52 0.840 51 1.680 50 2.520 50 4.200 50 5.040 50 7.560 7.560 47 7.560 Prepared by pts 04/22/2003 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0,000 0.000 0,000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 rYC$-- / (Q3 H2O CUM H2O Gain H2O Rate GOR Solids BBL BBL BBLID MMCFIBBL % 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 50.00 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 15.00 7.00 0.840 40.320 0.840 0.781 37.498 0.781 0.059 0.059 2.822 14.00 0.840 40.320 1.680 0.722 34.675 1.504 0.118 0.176 5.645 7.00 0.840 40.320 2.520 0.781 37.498 2.285 0.059 0.235 2.822 5.00 1.680 80.640 4.200 1.596 76.608 3.881 0.084 0.319 4.032 4.00 0.840 40.320 5.040 0.806 38.707 4.687 0.034 0.353 1.613 2.50 2.520 120.960 7.560 2.457 117.936 7.144 0.063 0.416 3.024 4.50 0.000 0.000 7.560 0.000 0.000 7.144 0.000 0.416 0.000 0.00 0.000 0.000 7.560 0.000 0.000 7.144 0.000 0.416 0.000 Page 1 ( 'P..t#5A WELU"'-. RU#5Test2 DATE, 10/26/2002 Clock Cum Choke Tubing Date time Time Comments Size Pres. II A mmldd/yy hh/mm hr. in. psi(g) 15:00:00 16.63 64.00 16 1660 15:00:00 16.63 13.9 API Gravity @ 60 F 15:30:00 17.13 \ 64.00\ 14 1697 16:00:00 17.63 64.00 16 1639 16:00:00 17.63 20.5 API Gravity@ 60 F 16:30:00 18.13 I 64.001 15 1668 17:00:00 18.63 64.00 15 1611 17:00:00 18.63 22.9 API Gravity @ 60 F 17:30:00 19.13 64.00 12 1644 18:00:00 19.63 64.00 11 1699 18:30:00 20.13 64.00 14 1633 19:00:00 20.63 64.00 12 1668 19:30:00 21.13 64.00 14 1607 20:00:00 21.63 64.00 14 1651 20:30:00 22.13 17 API Gravity @ 60 F 20:30:00 22.13 64.00 14 1677 21:00:00 22.63 64.00 15 1618 21:30:00 23.13 64.00 15 1668 22:00:00 23.63 64.00 17 1609 22:10:00 23.80 21.2 API Gravity @ 60 F 22:30:00 24.13 64.00 14 1642 23:00:00 24.63 64.00 16 1702 23:30:00 25.13 64.00 17 1640 10/28/02 0:00:00 25.63 64,00 11 1688 0:30:00 26.13 64.00 11 1627 1:00:00 26.63 26.7 API Gravity @ 60 F 1:00:00 26.63 64.00 15 1679 1 :30:00 27.13 64.00 13 1622 2:00:00 27.63 64.00 13 1671 2:30:00 28.13 64.00 14 1633 3:00:00 28.63 64.00 16 1660 3:30:00 29.13 64.00 14 1607 4:00:00 29.63 64.00 16 1657 4:00:00 29.63 23.4 API Gravity @ 60 F 4:30:00 30.13 I 64.001 16 1710 5:00:00 30.63 24.2 API Gavity @ 60 F 5:30:00 31.13 \ 64.00\ 18 1711 6:00:00 31.63 64.00 14 1655 6:00:00 31.63 23.05 API Gravity ~ 60 F 6:30:00 32.13 1 64.00 17 1704 7:00:00 32.63 64.00 16 1644 TO -Production Testing Services 10/28/02 Tubing Static Diff. Meter Gas Cum Fluid Fluid Fluid Cnm. Oil Oil Cum H2O CUM H2O O/A Temp Pres. Pres Temp Orifice Rate Gas Meter BSW Gain Rate Fluid Gain Rate Oil Gain H2O Rate GOR Solids of psi(g) in. of H2O Fin. MMCF/D MMCF BBL % BBL BBL/D BBL BBL BBL/D BBL BBL BBL BBL/D MMCFIBBL % 50 8.400 1.50 0.840 40.320 8.400 0.827 39.715 7.972 0.013 0.428 0.605 49 10.080 0.75 1.680 80.640 10.080 1.667 80.035 9.639 0.013 0.441 0.605 49 10.920 0.35 0.840 40.320 10.920 0.837 40.179 10.476 0.003 0.444 0.141 50 12.600 0.30 1.680 80.640 12.600 1.675 80.398 12.151 0.005 0.449 0.242 48 13.440 3.00 0.840 40.320 13.440 0.815 39.110 12.966 0.025 0.474 1.210 50 14.280 3.00 0.840 40.320 14.280 0.815 39.110 13.781 0.025 0.499 1.210 51 17.640 25.00 3.360 161.280 17.640 2.520 120.960 16.301 0.840 1.339 40.320 51 19.320 40.00 1.680 80.640 19.320 1.008 48.384 17.309 0.672 2.011 32.256 50 19.320 20.00 0.000 0.000 19.320 0.000 0.000 17.309 0.000 2.011 0.000 50 20.160 44.00 0.840 40.320 20.160 0.470 22.579 17.779 0.370 2.381 17.741 48 21.000 6.00 0.840 40.320 21.000 0.790 37.901 18.569 0.050 2.431 2.419 48 22.680 12.00 1.680 80.640 22.680 1.478 70.963 20.047 0.202 2.633 9.677 46 22.680 12.00 0.000 0.000 22.680 0.000 0.000 20.047 0.000 2.633 0.000 47 22.680 10.00 0.000 0.000 22.680 0.000 0.000 20.047 0.000 2.633 0.000 46 23.520 1.00 0.840 40.320 23.520 0.832 39.917 20.879 0.008 2.641 0.403 46 25.200 1.50 1.680 80.640 25.200 1.655 79.430 22.533 0.025 2.667 1.210 46 25.200 3.50 0.000 0.000 25.200 0.000 0.000 22.533 0.000 2.667 0.000 46 25.200 4.00 0.000 0.000 25.200 0.000 0.000 22.533 0.000 2.667 0.000 49 26.040 2.00 0.840 40.320 26.040 0,823 39.514 23.357 0.017 2.683 0.806 50 26.040 2.50 0.000 0.000 26.040 0.000 0.000 23.357 0.000 2.683 0.000 50 26.040 0.50 0.000 0.000 26.040 0.000 0.000 23.357 0.000 2.683 0.000 49 27.200 1.50 1.160 55.680 27.200 1.143 54.845 24.499 0.017 2.701 0.835 47 27.200 2.00 0.000 0.000 27.200 0.000 0.000 24.499 0.000 2.701 0.000 48 27.200 1.00 0.000 0.000 27.200 0.000 0.000 24.499 0.000 2.701 0.000 47 29.400 0.50 2.200 105.600 29.400 2.189 105.072 26.688 0.011 2.712 0.528 47 29.400 2.00 0.000 0.000 29.400 0.000 0.000 26.688 0.000 2.712 0.000 47 29.400 8.00 0.000 0.000 29.400 0.000 0.000 26.688 0.000 2.712 0.000 47 30.240 4.00 0.840 40.320 30.240 0.806 38.707 27.495 0.034 2.745 1.613 30.240 10.00 0.000 0.000 30.240 0.000 0.000 27.495 0.000 2.745 0.000 47 30.240 9.00 0.000 0.000 30.240 0.000 0.000 27.495 0.000 2.745 0.000 47 31.080 6.00 0.840 40.320 31.080 0.790 37.901 28.284 0.050 2.796 2.419 47 31.080 8.00 0.000 0.000 31.080 0.000 0.000 28.284 0.000 2.796 0.000 47 31.080 10.00 0.000 0.000 31.080 0.000 0.000 28.284 0.000 2.796 0.000 0.8 0.3 0.1 0.0 Prepared by pts 04/22/2003 Page 2 WELL :.~' Date mmlddlyy ( Ki{ 1=:Sft RU#5Test2 DÀTE 10/26/2002 Clock Cum Choke Tubing time Time Comments Size Pres. VA hh/mm hr. in. psi(g) 7:00:00 32.63 23.25 API Gravity @ 60 F 7:30:00 33.13 I 64.00 16 1690 8:00:00 33.63 64.00 15 1631 8:05:00 33.72 Shut in well 8:20:00 33.97 Begin reversing - out fluid 20:45:00 46.38 28K Total Chlorides 20:50:00 46.47 30K Total Chlorides 20:55:00 46.55 30K Total Chlorides 21 :00:00 46.63 31 K Total Chlorides ""roduction T estingServices TO 10/28/02 Tubing Static Diff. Meter Gas Cum Fluid Fluid Fluid Cum. Oil Oil Cum H2O CUM H2O O/A Temp Pres. Pres Temp Orifice Rate Gas Meter BSW Gain Rate Fluid Gain Rate Oil Gain H2O Rate GOR Solids of psi(g) in. of H2O Fin. MMCF/D MMCF BBL % BBL BBL/D BBL BBL BBL/D BBL BBL BBL BBL/D MMCFIBBL % 46 50 31.080 12.00 0.000 0.000 31.080 0.000 0.000 28.284 0.000 2.796 0.000 31.080 0.000 0.000 31.080 0.000 0.000 28.284 0.000 2.796 0.000 100.00 100.00 Prepared by pts 04/22/2003 Page 3 e09-) lo~ "roduction T estingServices WELL. .ltW5A"~'1JSTi.¡¡35~¡I)1\.n:. , . 10!.JOI02':; .; :i¡;J;Q, . : '11I02102~¿!:i:. Clock Cum Choke Tubing Tubing Static Diff. Meter Gas Cum Fluid Fluid Fluid Cum. Oil Oil Cum H2O CUM H2O Date Time Comments Size Pres. I/A O/A Temp Pres. Pres Temp Orifice Rate Gas Meter BSW Gain Rate Fluid Gain Rate Oil Gain H2O Rate GOR Solids mmlddlyy hr. in. psi(g) of psi(g) in. of H2O F in. MMCFIJ:- MMCF BBL % BBL BBL/D BBL BBL BBL/D BBL BBL BBL BBL/D ~MCFIBI % 10/31/02 10:32 0.00 Open well - Initial Flow Period - Shut-In Pressure 3050 PSI Choke 15/64 0 0 10:32 0.00 I 15\ 3050\ 2000\ 10:47 0.25 Initial Shut-In 11:17 0.75 Open well - Main Flow Period - Flowing N2 11:17 0.75 15 2859 1688 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 11:27 0.92 15 2749 1671 57 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 12:00 1.47 15 2352 1656 56 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 12:30 1.97 15 2027 1669 55 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 13:00 2.47 15 1748 1691 56 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 13:30 2.97 cle to 16/64 16 1499 1611 56 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 14:00 3.47 16 1223 1633 56 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 14:30 3.97 16 986 1647 54 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 15:00 4.47 16 770 1655 53 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 15:30 4.97 16 572 1668 52 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 15:45 5.22 cle to 20/64 20 494 1664 52 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 16:00 5.47 20 321 1677 52 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 16:30 5.97 20 134 1644 52 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 17:00 6.47 cle to 50/64 50 36 1642 50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 17:30 6.97 50 11 1679 50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 18:00 7.47 50 12 1728 48 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 18:30 7.97 50 12 1666 48 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 19:00 8.47 50 13 1640 47 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 19:25 8.88 Fluid to Sep 19:25 8.88 \ 50 28 1669 49 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 19:30 8.97 50 32 1620 50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 19:30 8.97 21.7 API ~ 60 F 0.00 20:00 9.47 50 24 1699 52 8.40 7.5 8.40 403.20 8.40 7.77 372.96 7.77 0.630 0.630 30.24 1.50 ( 20:00 9.47 22.7 API' 60 F 7.77 20:30 9.97 50 20 1766 50 14.28 9.0 6.51 312.48 14.91 5.92 284.36 13.69 0.586 1.216 28.12 20:30 9.97 18.9 API @ 60 F 13.12 21:00 10.47 50 29 1706 52 18.48 14.5 5.36 257.28 20~27 4.58 219.97 18.28 0.777 1.993 37.31 0.50 21:30 10.97 50 22 1713 51 25.20 9.5 6.72 322.56 26.99 6.08 291.92 24.36 0.638 2.632 30.64 0.50 22:00 11.47 50 30 1633 50 28.56 5.5 3.36 161.28 30.35 3.18 152.41 27.53 0.185 2.816 8.87 0.50 22:30 11.97 50 17 1739 50 30.24 5.5 1.68 80.64 32.03 1.59 76.21 29.12 0.092 2.909 4.44 0.50 23:00 12.47 50 43 1767 51 36.96 7.0 6.72 322.56 38.75 6.25 299.98 35.37 0.470 3.379 22.58 0.50 23:00 12.47 23.7 API @ 60 F 23:30 12.97 50 20 1677 50 40.32 3.0 3.36 161.28 42.11 3.26 156.44 38.63 0.101 3.480 4.84 0.00 11/01/02 0:00 13.47 50 15 1658 50 42.84 4.8 2.52 120.96 44.63 2.40 115.15 41.03 0.121 3.601 5.81 0.20 0:30 13.97 50 15 1640 50 42.84 1.1 0.00 0.00 44.63 0.00 0.00 41.03 0.000 3.601 0.00 0.20 0:30 13.97 23 API @ 60 F 1:00 14.47 I 50 31 1607 53 49.56 6.0 6.72 322.56 51.35 6.32 303.21 47.35 0.403 4.004 19.35 0.00 Prepared by pts 04/22/2003 Page 1 "'roduction T estingServices WELL RU#5A"..DST#3 DA,TEt . ~;';;tOI3010i>!~,;" . Clock Cum Choke Tubing Tubing Static Diff. Meter Gas Cum Fluid Fluid Fluid Cum. Oil Oil Cum H2O CUM H2O Date Time Comments Size Pres. IJA OIA Temp Pres. Pres Temp Orifice Rate Gas Meter BSW Gain Rate Fluid Gain Rate Oil Gain H2O Rate GOR Solids mm/ddlyy hr. in. psi (g) OF psi (g) in. of H2O F in. MMCFID MMCF BBL % BBL BBLID BBL BBL BBLID BBL BBL BBL BBLID MCFIBI % 1:30 14.97 50 14 1594 51 52.92 6.0 3.36 161.28 54.71 3.16 151.60 50.50 0.202 4.206 9.68 0.00 2:00 15.47 50 13 1603 52 52.92 5.0 0.00 0.00 54.71 0.00 0.00 50.50 0.000 4.206 0.00 0.00 2:30 15.97 50 13 1810 50 52.92 4.7 0.00 0.00 54.71 0.00 0.00 50.50 0.000 4.206 0.00 0.30 3:00 16.47 50 14 1807 52 57.12 7.8 4.20 201.60 58.91 3.87 185.88 54.38 0.328 4.533 15.73 0.20 3:30 16.97 50 19 1792 52 58.80 5.5 1.68 80.64 60.59 1.59 76.21 55.96 0.092 4.626 4.44 0.50 3:30 16,97 24.2 API i 60 F 54.40 ( 4:00 17.47 50 16 1781 51 58.80 5.0 4.40 211.20 64.99 4.18 200.64 60.14 0.220 4.846 10.56 0.00 4:30 17.97 50 15 1755 52 60.48 5.5 1.68 80.64 66.67 1.59 76.21 61.73 0.092 4.938 4.44 0.50 4:30 17.97 22.6 API ~ 60F 5:00 18.47 50 19 1719 52 62.16 3.0 1.68 80.64 68.35 1.63 78.22 63.36 0.050 4.988 2.42 0.50 5:00 18.47 22.8 API @ 60 F 57.62 5:30 18.97 50 19 1706 52 63.84 7.5 6.22 298.56 74.57 5.75 276.17 69.12 0.467 5.455 22.39 0.50 6:00 19.47 50 18 1651 52 67.20 2.0 3.36 161.28 77.93 3.29 158.05 72.41 0.067 5.522 3.23 0.10 6:30 19.97 50 20 1616 51 68.88 0.9 1.68 80.64 79.61 1.67 79.91 74.07 0.015 5.537 0.73 0.10 7:00 20.47 50 20 1605 52 69.72 4.0 0.84 40.32 80.45 0.81 38.71 74.88 0.034 5.571 1.61 0.30 7:30 20.97 50 15 1812 51 72.24 6.0 2.52 120.96 82.97 2.37 113.70 77.25 0.151 5.722 7.26 0.10 8:00 21.47 50 15 1805 50 72.24 0.00 0.00 82.97 0.00 0.00 77.25 0.000 5.722 0.00 8:30 21.97 50 18 1772 48 72.24 0.00 0.00 82.97 0.00 0.00 77.25 0.000 5.722 0.00 9:00 22.47 50 16 1744 50 72.24 0.00 0.00 82.97 0.00 0.00 77.25 0.000 5.722 0.00 9:15 22.72 25.8 API i 60 F 72.24 0.4 0.00 0.00 82.97 0.00 0.00 77.25 0.000 5.722 0.00 9:30 22.97 50 17 1702 52 72.24 0.00 0.00 82.97 0.00 0.00 77.25 0.000 5.722 0.00 10:00 23.47 50 20 1675 52 72.24 0.00 0.00 82.97 0.00 0.00 77.25 0.000 5.722 0.00 10:05 23.55 Shut-In Well 72.24 0.00 0.00 82.97 0.00 0.00 77.25 0.000 5.722 0.00 11/02/02 18:45 56.22 Open Well - Begin revercing-Out 18:45 56.22 13 18:55 56.38 13 ( 19:05 56.55 13 0.1 19:15 56.72 13 19:20 56.80 Water to Surface 98.0 19:25 56.88 29K Total Chlorides 98.0 19:30 56.97 28.5K Total Chlorides 19:35 57.05 CC to 24/64 I 19:35 57.05 28K Total Chlorides 98.0 19:40 57.13 29K Total Chlorides 19:45 57.22 27K Total Chlorides 98.0 19:50 57.30 23.5K Total Chlorides 19:55 57.38 17K Total Chlorides 99.0 20:00 57.47 13.5K Total Chlorides 20:05 57.55 CC to 33/64 I 20:05 57.55 12K Total Chlorides 100.0 20:10 57.63 11.5 Total Chlorides Prepared by pts 04/22/2003 Page 2 WELt. Date mmlddlyy ( ( :~f. RJj#5A~DSTW#3:';(>J),ATJj:::;¡\j~?\'jt3~;tÒÍ3ÖjôZ<;'[j{ . Clock Cum Choke Tubing Time Comments Size Pres. hr. in. psi(g) 20: 15 57.72 11 K Total Chlorides 20:20 57.80 12K Total Chlorides 20:25 57.88 13K Total Chlorides 20:30 57.97 13K Total Chlorides 20:35 58.05 13.5K Total Chlorides 20:40 58.13 18K Total Chlorides 20:45 58.22 28K Total Chlorides 20:50 58.30 30K Total Chlorides 20:55 58.38 30K Total Chlorides 21 :00 58.47 31 K Total Chlorides -Production T estingServices .'!to' '111Ò2I02;':' Tubing Static Diff. Meter Gas Cum Fluid Fluid Fluid Cum. Oil Oil Cum H2O CUM H2O IIA O/A Temp Pres. Pres Temp Orifice Rate Gas Meter BSW Gain Rate Fluid Gain Rate Oil Gain H2O Rate GOR Solids OF psi(g) in. of H2O Fin. MMCFID MMCF BBL % BBL BBLID BBL BBL BBLID BBL BBL BBL BBLIDMCFIBI % 100.0 100.0 100.0 100.0 100.0 Prepared by pts 04/22/2003 Page 3 '\) ') @) FOREST OIL CORPORATION ,.1/0 ¡)(rÝlN)(?( . r':lUf/f') 7(/(J (JCiJlf"h(JN~7e) r-cila,J:-a ,(j,f)/;O! (.r;(¡?) ,¡J.¡S-S(j'((¡ . (.r;07) /;,S'-S(j'('/ (r'-/'0.r) December 19, 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Well Completion Report and Log (Form 10-407) Redoubt Unit #5A Enclosed is Forest Oil's Well Completion Report and Log for the Redoubt Unit #5A well, drilled from the Osprey Platfonn. This well was a sidetrack of the original Redoubt Unit #5, in the Southern Fault Block. The well was logged, drill stem tested and completed with a ESP assembly. If there are any questions, please contact me at 258-8600. CL Paul D. White Drilling Manager - Alaska Division Forest Oil Corporation RECEIVED DEC 20 2002 f\tQlka au & Gas Gons. ÐommiSSltJ Ancb.Qragq -' Attachments: Well Completion Report (fonn 10-407) Redoubt Unit #5A Well Schematic Daily Operations Summary Final Directional Survey )' STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 1909' FSL, 318' FEL, Section 14, T07N, R14W, SM At Top Producing Interval 1058' FSL, 288' FWL, Section 19, T07N, R13W, SM " At :~,a~~~~~~61' FWL, Section 19, T07N, R13W, SM ";"'~~,::; "'~ 5. Elevation in feet (indicate KB, DF, etc,) 6. Lease Designation and Serial No. 90 ft RKB ADL 381203, ADL 374002 12. Date Spudded 13. Date T.D. Reached 14. Date CO~ÁS~s~ qr Aband. 15. Water Depth, if offshore 16. No, of Completions 08/16/2002 09/29/2002 ~ /11i~cr; 2- ~ 1> nla feet MSL 1 17, Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19, Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 17,000' MD I 12,830' TVD 16,575' MD I 12,639' TVD Yes: x No: 14,988' - LLC-3 nla 22. Type Electric or Other Logs Run '7;/"W~-..J ill '-/73 ' ':I1.þ 81/2" Hole - Azimuthal Density, Res, GR 63/4" Hole - ND, Res, GR, CMR, ECSISGT, USIT 1°10,/ / I" Wi:> 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM 30" nla nla Surf. 200' 13 3/8" 68# L-80 Surf. 3,190' 9 5/8" 47# L-80 Surf. 11,500' 75/8" 29,7# L-80 11,290' 15,323' 51/2" 17# L-80 15,118' 16,995' 24, Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 15,350' MD (11,995' TVD) -15,385' MD (12,013' TVD), 15,410' MD (12,027' TVD)- 15,460' MD (12,052' TVD), 15,560' MD (12,104' TVD) -15,600' MD (12,125' TVD), 15,615' MD (12,134' TVD) -15,635' MD (12,145' TVD), 15,765' MD (12,220' TVD) - 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 15,915' MD (12,308' TVD), 15,950' MD (12,327' TVD) -15,960' MD (12,333' TVD), DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 16,020' MD (12,366' TVD) -16,030' MD (12;371' TVD), 16,170' MD (12,443' TVD)- 16,525' MD (12,616' TVD) 33/8" TCP 6 spf 15,733' to 15,735' 1. Status of Well OIL: X GAS: 2. Name of Operator SUSPENDED: ABANDONED: SERVICE: 3. Address HOLE SIZE driven 18 1/2" 12 1/4" 8 1/2" 63/4" 25. SIZE 3 1/2" PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Classification of Service Well 7. Permit Number 202-168 8. API Number 50-733-20513-01 9. Unit or Lease Name Redoubt Unit 10. Well Number NO.5A 11. Field and Pool Redoubt Shoal Field CEMENTING RECORD nla Surface 1286 cu ft 252 cu ft 314 cu ft TUBING RECORD DEPTH SET (MD) 14,946' AMOUNT PULLED None None None None None PACKERSET (MD) 14,990' 3.6 bb116.0 ppg squeeze cement Date First Production nla Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF 10-21 to 11-2 92,2 TEST PERIOD => 191.4 nla Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF Press. 15 psi 1500 psi 24-HOUR RATE => 49.8 nla 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. WA TER-BBL 636.9 WA TER-BBL 165.8 CHOKE SIZE GAS-OIL RATIO 50/64" -250 OIL GRtt€';VE D OEC 2-0 2002 . SSioo ~ 0\\ & Gas Cons. Comm\ A\as Anchorage Core #1 15425'-15485.5' Core #2 15819'-15826' Core #3 16153'-16207' *chips taken from end of core barrels, core was not removed from aluminum barrels. ** interbedded pebble conglomerate, sandstone, siltstone, and claystone~andstone is fine to medium grained, well sorted and rounded. Pebbles are well rounded. ' Form 10-407 Rev. 7-1-80 RBDMS 8FL (,~ CONTINUED ON REYER$E ~IDE FEB 4 2003 Submit in duplicate ) ') 29. 30. GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPTH SSTVD Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase, NAME G-Zone 14,350' 11,407' Upper Hemlock 15,273' 11,812' 145 ft of perforations were shot over the interval 15,350 to 15,635' MD, The well flowed for 23.2 hours and recovered a total of 303 bbls of fluid (99 BO & 204 BW). The final measured oil gravity was 25.8 deg API. The well was open on a 50/64" choke and had a FTP of 15 to 20 psia. Clay Zone 15,650' 12,063' Lower Hemlock 15,760' 12,126' 585 ft of perforations were shot over the interval 15,765 to 16,670' MD. The well flowed for 35.3 hours and recovered a total of 274 bbls of fluid (54 BO & 220 BW), The final measured oil gravity was 26.2 deg API. The well was open on a 50/64" choke and had a FTP of about 10 psia, RECEIVED West Foreland 16,835' 12,670' DEC 2.0 2002 Naska on & Gas Gons. Commission Anchorage 31. LIST OF ATTACHMENTS Well Schematic, Daily Operations Summary, Final Directional Survey 32. I hereby ce.,at the foregoing is true and correct to the best of my knowledge ,,~ . Signed ~..~ Title_Drilling Manager- Date , \ l .20 0,- I NSTR UCTIONS 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 Redoubt Unit .. JÅ Completion - November 2002 A TOL @ 11290 MD TOL @ 15118 MD :5 ~;. ~j, \~ !~ ~ :it i~ 'I'~~ ~I'~' ,,, "'} j'~ ,I;; ~ s" ~+ ~ !H ¡~ i~ i ¡ 1 , f! : i ¡ i ! j ! [; !"- I~'~ , Ii ¡ H i~ ; ! {$:i ì' J . ." '..~.:;; f ~"':. ~ ~~ ~'}il 1- ~_: .J ~ :s- "...~ S.L ~:; ;.¡~~ iE 1/...,,- , .,;~~;-=i t:~~,",','",."-,,. i ...:,w; L' ,,; ~, -I '~~ !S~ 1~ ,'~~J f~ ~i i"\~ ~;; ',.t. ~A'"" ):. ;~ ;A1 ry ..., ~f-;' . 1" ~J S! -.r ~ .. 30" 150# 133/8" 68 # 31/2" P-110 Pup 48 jts 31/2" P-110 Tubing 424 jts 31/2" L-80 Tubing 95/8" 47 # Centrilift ESP Assembly @ 14946 MD ~~ ¡~ ~:,' 1~ #, ¡. f¡ ~, r~ ~ "" ~: ~i n ;: i,tl~, i ~.,' I;,. r1 ~ -.. '--. , 1 LLC-3 Valve set in Baker Model FA Packer @ 14988 MD , '" :j' :=; ~ ;::: ;t, " J '-- ~ '~ :::J.' ~ ~~iI~ l 1 i~. ., , 81~. -- ~ Perforations 7518" 29.7 # EZ Drill @ 16575 MD 51/2" 17 # ) A-36 Welded 200 TVD 200 MD L-80 BTC 2940 TVD 3190 MD L-80 10065 TVD BTC 11500 MD L-80 11980 TVD Hydril 521 15323 MD L-80 Hydril 521 12830 TVD 17000 MD PElC'" ) OPERATIONS SUMMARY REPORT ) T oday's Date: 11/13/2002 WELL NAME: REDOUBT UNIT #5A RIG NAME: FIELD NAME: REDOUBT SHOAL EVENT NO.: 1 DATE: 08/13/2002 0.50 1.50 8,00 1.50 3,00 0,50 0.50 DATE: 08/14/2002 HOURS PH 1.00 0 1.50 0 0,50 0 5.00 0 1.50 0 9.50 0 4,00 0 0.50 0 0.50 0 DATE: 08/15/2002 HOURS PH 8.50 0 0.50 0 2.00 D 13.00 D DATE: 08/16/2002 HOURS PH 1.00 D 1.00 D 0.50 D 0,50 D 6.50 D 4.50 D 0.50 D 2.50 D 2,00 D 5.00 D DATE: 08/17/2002 0 0 0 0 0 0 0 TR CC TR TR TR CC TR OP TR CC RS TR TR LO TR DS TR OP TR RS DS DR OP DR WR TR RS TR TR CC DR CC TR AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 025755 RU #5A 50-733-20513-00 DRILLING 12.25 HOLE, DRILLING 8. DSS: 82 13,722 9.55 CUM COST TO DATE: 7,122,579.63 DEPTH: MUD WT: 25 sxs on top plug, PULL 5 STANDS,DROPPING 25 SX'S - 5,2 BBLS ON TOP OF PLUG. REVERSE CIRC. BTM UP @ 5-6 BPM. CIRC. LONG WAY@ 16 BPM TO CLEAD OUT DP. TRIP OUT OF HOLE. laying down 30 jts. bad hardbanding, MAKE UP BHA TO RUN SCRAPPER TRIP IN HOLE WITH 9 5/8 SCRAPPER. CIRC. FILL PIPE, TRIP IN HOLE WITH 9 5/8 SCRAPPER DSS: 83 7,222,720.58 9.55 CUM COST TO DATE: DEPTH: 11,500 MUD WT: ACT ACTIVITY DESCRIPTION TRIP IN HOLE WITH 95/8 " SCRAPPER. CIRC. & CUT DRILL LINE. RIG SERVICE TRIP OUT OF HOLE. LAY DOWN BHA. TRY TO SET BRIDGE PLUG, COULD NOT GET SET. RUN TOOL OUT OF HOLE. EXSPLOSIVE CHARGE DID NOT IGNITE PRIMERS WENT OFF. RE-FIT TOOL WITH NEW CHARGE RUN IN SET PLUG @ 11500', PULL OUT OF HOLE RIG DOWN LOGGERS, P/U DIRECTIONAL TOOLS AND WHIPSTOCK ORIENTATE, P/U BHA. 1261/2" DC, PULSE TEST DWD. TIH WITH WHIPSTOCK @ 35-40 FPM. DSS: 84 7,298,906.21 11,500 9.55 CUM COST TO DATE: MUD WT: DEPTH: ACT ACTIVITY DESCRIPTION TIH W/ WHIPSTOCK Normal rig service ORIENTATE TO SET WHIPSTOCK, TAG @ 11,497' SET AND SHEAR @ 27 DEG LEFT. WORK FREE AND ESTABLISH MILLING PERAMITERS. MILLING WINDOW F/11 ,473' - 11,492' 19' DSS: 85 DEPTH: 9.55 CUM COST TO DATE: 7,366,859.10 11,500 MUD WT: ACT ACTIVITY DESCRIPTION MILLING WINDOW @ 11,494' REAM AND CLEAN UP WINDOW F/11,473' - T/11 ,494' SWEEP HOLE TRIP OUT OF HOLE RIG SERVo TRIPPING OUT OF HOLE. CHANGE BHA. TRIP IN HOLE CIRC, & CONDITION MUD. CUT WINDOW AND 5' OF NEW FORMATION DEPTH 11,500'. PUMP SWEEP CIRC. HOLE CLEAN. PUMP DRY JOB. TRIP OUT OF HOLE. ," DSS: 86 DEPTH: 9.55 CUM COST TO DATE: 7,452,930.72 11,704 MUD WT: Page No: 18 Copyright @ 1993-99 by Epoch WellSite Services, Inc. All rights reserved. PEiC'" ) OPERATIONS SUMMARY REPORT ) Today's Date: 11/13/2002 WELL NAME: REDOUBT UNIT #5A RIG NAME: FIELD NAME: REDOUBT SHOAL EVENT NO.: 1 DATE: 08/17/2002 HOURS PH OP 1.50 D TR 2,00 D DS 0,50 D TR 3,50 D TR 1,00 D RS 1.00 D CC 0.50 D WR 14.00 D DR DATE: 08/18/2002 HOURS PH OP 6.00 D DR 18,00 D DR DATE: 08/19/2002 HOURS PH OP 12.50 D DR 2.00 D CC 1.00 D TR 7.50 D TR 1.00 D TR DATE: 08/20/2002 HOURS PH OP 2.00 IS-D TR 3.50 IS-D PT 0,50 IS-D RS 1.50 IS-D PT 1.00 IS-D RR 4.50 IS-D TR 6.00 IS-D RR 3.00 IS-D TR 1.00 IS-D CC 1.00 IS-D TR DATE: 08/21/2002 HOURS PH OP 6.00 D DR 0.50 IS-D TR 6,00 IS-D RR 1.00 IS-D TR 0.50 C CC 10.00 D DR AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 025755 RU #5A 50-733-20513-00 DRILLING 12.25 HOLE,DRILLlNG 8. DSS: 11 ,704 86 DEPTH: MUD WT: 9.55 CUM COST TO DATE: 7,452,930.72 ACT ACTIVITY DESCRIPTION UD BHA P/U & M/U BHA & ORIENTATE TRIP IN HOLE T/1 0001' PULSE TEST DWD TRIP IN HOLE T/ K,O.P, CUT DRILL LINE. CIRC, & CONDITION MUD, SHEAR MUD TO HANDLE 400 GPM AT SURFACE. ORIENTATE 30 LEFT TO EXIT WINDOW, WASH AND REAM 6.75 PILOT HOLE SECTION, DRILLING F/11 ,500' - T/11 ,704' DSS: 11,704 7,525,147.07 87 DEPTH: MUD WT: 9,50 CUM COST TO DATE: ACT ACTIVITY DESCRIPTION DRILLING F/11,704' - T/11,785' DRILLING F/11 ,785' - T/11 ,932' DSS: 88 7,596,010.75 12,028 DEPTH: MUD WT: 9.50 CUM COST TO DATE: ACT ACTIVITY DESCRIPTION DRILLING F/11 ,932' - T/12,028' PUMP SWEEP CIRCULATE TO SURFACE. TRIP OUT HOLE TO WINDOW 11,473' PUMP PILL AND TRIP OUT OF HOLE. LAYING DOWN WORN HARDBANDED DRILLPIPE. CHANGE BHA, JARS,MOTOR,BIT DSS: 89 DEPTH: 12,028 MUD WT: 9.50 CUM COST TO DATE: 7,659,616,05 ACT ACTIVITY DESCRIPTION P/U BHA. ORIENT DWD. PULL WEAR RING. SET TEST PLUG. TEST BOP. 250/3,000 PSI. SERVICE RIG. LUBRICATE REMOTE BOP STATION. FUNCTION TEST FOR STATE REP. RIG REPAIR. LOCATE & REPAIR HYDRAULIC LEAK ON TD. C/O SAVERSUB. CULL 48 JTS DP. RIH STRAPPING PIPE. PULSE TEST @ BHA. FILL PIPE @ 6,000 FT. RIG REPAIR. C/.O COOLANT LINES T/ DWKS BRAKES. TIH T/11 ,450. CIRC & SHEAR MUD @ 11,450. WORK INTO WINDOW @ 11,473-11,515. TIH. WASH 100' TI BTM. DSS: 12,470 7,795,753.38 90 DEPTH: 9.50 CUM COST TO DATE: MUD WT: ACT ACTIVITY DESCRIPTION DRILLING. ROTATE F/12,028 T/12182 TOH TO SHOE FOR TD REPAIRS. REPAIR TD. REMOVE GRABBER ASSY. & REPLACE HYD RAM. TIH. WASH T/ BTM. CIRC / SHEAR MUD. DRILLING. ROTATE F/12,182 T/12,470. Page No: 19 Copyright @ 1993-99 by Epoch WellSite Services, Inc, All rights reserved. PEiev' ) OPERATIONS SUMMARY REPORT ) Today's Date: 11/13/2002 WELL NAME: REDOUBT UNIT #5A RIG NAME: FIELD NAME: REDOUBT SHOAL EVENT NO.: 1 AFE NO: 025755 WELL ID NO.: RU #5A API NO.: 50-733-20513-00 EVENT DESC.: DRILLING 12.25 HOLE, DRILLING 8. DATE: 08/22/2002 HOURS PH 24.00 D DATE: 08/23/2002 HOURS PH 24.00 D DATE: 08/24/2002 HOURS PH 16,50 D 3.00 DT 4.00 D 0.50 DT DATE: 08/25/2002 HOURS PH OP 0,50 IS-D RR 23,50 D DR DATE: 08/26/2002 HOURS PH 12,00 D 2,50 IS-D 3.50 IS-D 6.00 IS-D DATE: 08/27/2002 HOURS PH 2.00 D 4.00 D 1.50 DT 4.00 D 5.50 D 1.00 D 1.00 0 2.00 D 1.50 0 0.50 0 1.00 D DATE: 08/28/2002 HOURS PH 3.00 0 OP DR OP DR OP DR RR DR RR OP DR CC TR TR OP TR PT RR TR TR RS CC TR DR DR DR OP DR DSS: 12,844 7,871,181.56 91 DEPTH: MUD WT: 9.50 CUM COST TO DATE: ACT ACTIVITY DESCRIPTION DRLG, ROTATE F/12,420 T/12,720,SLlDE F/12,720 T/12,755. ROTATE T/12,844. DSS: 92 13,124 MUD WT: 9.50 CUM COST TO DATE: 7,947,852.09 DEPTH: ACT ACTIVITY DESCRIPTION DRILLING I SLIDING F/12,844 T/13,124. 40.5 % SLIDE TIME. DSS: 93 13,419 8,096,677.47 DEPTH: MUD WT: 9,50 CUM COST TO DATE: ACT ACTIVITY DESCRIPTION DRILLING 1 SLIDING F/13,124 T/13,398. TOP DRIVE DOWNTIME. SUSPECTED SEAL LEAK FI TORQUE BOOST TI GEAR BOX. DISABLE TORQUE BOOST. DRILLING 1 SLIDING F/13,398 T/13,419. TD REPAIRS. REMOVE CLUTCH ASSY FI TORQUE BOOST. DSS: 94 DEPTH: 13,722 MUD WT: 9.50 CUM COST TO DATE: 8,204,264,10 ACT ACTIVITY DESCRIPTION TD REPAIR. REMOVE CLUTCH ASSY. FROM TORQUE BOOST. DRILLING 1 SLIDING F/13,419 T/13,722 DSS: 95 13,800 MUD WT: 9.50 CUM COST TO DATE: 8,271,364,01 DEPTH: ACT ACTIVITY DESCRIPTION DRILLING 1 SLIDING F/13,722 T/13,800. PUMP HIGH VIS SWEEP. CIRCULATE OUT SWEEP, 25 % INCREASE IN CUTTI~GS. TOH TI WINDOW, PUMP DRY JOB & CLEAN FLOOR. TOH. CULL OUT 51 JTS OF 5" DP FI HARD BANDING. DSS: 96 13,835 8,420,035.26 MUD WT: 9.50 CUM COST TO DATE: DEPTH: ACT ACTIVITY DESCRIPTION Work BHA. Test BOP. Repair rig. Install top drive boost gears. Tripping - BHA work. Load LWD tools. Trip to window. Cut drilling line. Circulate above window. RIH. Work through tight spot at 13250'. Drilling from 13800' to 13818' Work on LWD pulse strength. Drill from 13818' to 13835. DSS: 97 DEPTH: 14,205 8,524,529.68 MUD WT: 9.55 CUM COST TO DATE: ACT ACTIVITY DESCRIPTION Drill from 13835' to 13872'. Page No: 20 Copyright @ 1993-99 by Epoch WellSite Services, Inc. All rights reserved. PElC'" WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 08/28/2002 2.00 0 DR 3.00 0 DR 2.50 0 DR 8,50 0 DR 2,50 0 DR 2.50 0 DR DATE: 08/29/2002 HOURS PH OP 9,50 0 DR 0.50 0 DR 8.50 0 DR 0.50 0 RS 5.00 0 DR DATE: 08/30/2002 HOURS PH OP 24.00 0 DR DATE: 08/31/2002 HOURS PH OP 9.50 0 DR 0.50 0 RS 9.00 D DR 0.50 D RS 1.00 0 CC 0.50 0 RS 2.50 0 DR 0.50 D RS DATE: 09/01/2002 HOURS PH OP 1,00 D DR 1.00 D RS 5.00 0 DR 0.50 D RS 13.50 D DR 1.50 0 CC 1.00 0 DR 0.50 0 CC DATE: 09/02/2002 HOURS PH 6.00 0 ) OPERATIONS SUMMARY REPORT 0) REDOUBT UNIT #5A AFE NO: WELL ID NO.: API NO.: EVENT DESC.: REDOUBT SHOAL 1 DSS: 97 14,205 MUD WT: 9.55 CUM COST TO DATE: 8,524,529.68 DEPTH: Slide to 13996'. Drill to 13970'. Slide to 14005'. Drill to 14161'. Slide to 14177'. Drill to 14205'. Today's Date: 11/13/2002 025755 RU #5A 50-733-20513-00 DRILLING 12.25 HOLE, DRILLING 8. ACT ACTIVITY DESCRIPTION 9.50 CUM COST TO DATE: 8,597,422,27 DSS: 14,565 MUD WT: 98 DEPTH: Drilling/Sliding from 14205' to 14362'. Survey and orient. Drilling/Sliding to 14524', Rig service. Drilling/Sliding to 14565'. DSS: 99 14,905 MUD WT: ACT ACTIVITY DESCRIPTION 9.50 CUM COST TO DATE: 8,698,394.98 DEPTH: Drilling/Sliding from 14565' to 14905'. DSS: 100 15,115 MUD WT: ACT ACTIVITY DESCRIPTION 9,50 CUM COST TO DATE: 8,778,575.49 DEPTH: Drilling/Sliding to 15000'. Normal rig service Drilling/Sliding to 15086'. Replace mud pump swab. Circulate, rotate & recrprocate to clean hole. Replace pump valve seat. Drilling/Sliding to 15115'. Replace mud pump swab. ACT ACTIVITY DESCRIPTION 9.50 CUM COST TO DATE: 8,861,436.92 DSS: 101 15,325 MUD WT: DEPTH: Drilling/Sliding from 15086' to 15114'. Replace valve and seat in mud pump. Drilling/Sliding to 15289'. Lubricate rig. DrillinglSliding to 15315'. Circulate samples. Drilling/Sliding to 15325'. TD. Circulate samples. DSS: 102 15,325 MUD WT: OP CC ACTIVITY DESCRIPTION 9.50 CUM COST TO DATE: 8,931,409.62 DEPTH: ACT Circulate hole clean at TD. Page No: 21 Copyright @ 1993-99 by Epoch WellSite Services, Inc, All rights reserved. PEacý ) OPERATIONS SUMMARY REPORT ) Today's Date: 11/13/2002 WELL NAME: REDOUBT UNIT #5A RIG NAME: FIELD NAME: REDOUBT SHOAL EVENT NO.: 1 DATE: 09/02/2002 8.50 D TR 3.50 D LO 3.50 D PT 2.50 IS-D RR DATE: 09/03/2002 HOURS PH OP 3.50 IS-D RR 6.00 D TR 2,50 D CC 12.00 D LO DATE: 09/04/2002 HOURS PH OP 9.00 IS-O LO 2.50 IS-O DR 5.00 IS-O CC 5.00 IS-O TR 2.50 IS-O RR DATE: 09/05/2002 HOURS PH OP 1.00 IS-D RR 0.50 IS-D RS 2.00 IS-O RS 1.00 IS-D RR 2.50 IS-O TR 3.00 IS-O CC 0.50 IS-D CC 3.50 IS:'D TR 0.50 IS-O RS 4,50 IS-D TR 4.00 IS-D TR 1.00 IS-D BO DATE: 09/06/2002 HOURS PH OP 1,50 0 CS 0.50 0 RS 0.50 0 CS 2.00 0 CS 1.50 0 CS 6.50 0 CS AFE NO: 025755 WELL ID NO.: RU #5A API NO.: 50-733-20513-00 EVENT DESC.: DRILLING 12.25 HOLE, DRILLING 8. DSS: 102 DEPTH: 9,50 CUM COST TO DATE: 8,931,409.62 15,325 MUD WT: POH with bit # 18. No correction to SLM. Down load LWD data and lay down tools. Pressure test BOP. Rig repairs, Work on top drive with service technician. DSS: 103 DEPTH: 15,325 9,50 CUM COST TO DATE: 9,001,246.59 MUD WT: ACT ACTIVITY DESCRIPTION TOP DRIVE DOWNTIME. WORK ON TOP DRIVE W/ CANRIG TECH. P/U BHA CALIBRATE LOGGING TOOLS. TIH W/ HWDP SHALLOW HOLE TEST. TIH T/ WINDOW. SHEAR MUD @ WINDOW, RIG SERVICE. DP LOG W/ SPERRY F/11 ,460. DSS: 104 15,325 9.50 CUM COST TO DATE: 9,070,718.77 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION LOG W/ SPERRY T/13,900 FT @ 175 FT PER HR. REAM F/13,900 T/15,325, PUMP HIGH VIS SWEEP, CIRC HOLE CLEAN. SHORT TRIP T/ WINDOW.WORK TIGHT AREAS @ 14,037 ,13,950,13,860, BK REAM @ 13,309 - 13,250 , WASH F/ 12,070 - 11,930. TOP DRIVE DOWN TIME. WORK WITH CANRIG TECH ON TD ADJUSTMENTS DSS: 105 15,325 9.50 CUM COST TO DATE: 9,155,530,18 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION TOP DRIVE DOWN TIME. WORK WITH CANRIG TECH ON TD ADJUSTMENTS. SERVICE RIG. CUT & SLIP DRLG LINE, ADJUST RBRAKE ROLLERS,TIGHTEN PADS & C/O CROWN SAVER. TOP DRIVE DOWN TIME. WORK ON TORQUE BOOST W/ CANRIG TECH. TIH T/ BTM. PUMP HIGH VIS SWEEP, CIRCULATE HOLE CLEAN. SPOT HIGH VIS PILL ON BTM. TOH. TIGHT SPOT @ 12,223, GO BK THRU SLICK. SERVICE RIG, PUMP DRY JOB & DROP 2 3/8" DRIFT. TOH T/ RUN CSG, PJSM W/ SPERRY, CLN FLOOR, UD JARS. REMOVE SOURCE & DN LD DATAUD LOGGING TOOLS & BHA PULL W/ BUSHING, SET TEST PLUG, C/O BTM RAMS T/7.625. DSS: 106 9.60 CUM COST TO DATE: 9,221,399,81 15,325 MUD WT: DEPTH: ACT ACTIVITY DESCRIPTION PULL WEAR BUSHING, SET TEST PLUG. CHANGE BTM RAMS T/7.625. TEST DOOR SEALS. INSTALL WEAR BUSHING REPAIR RIG. WORK ON CROWNSAVER. PREPARE T/ RUN CASING. M/U CEMENT HEAD AND UD. RIG UP T/ RUN CASING. PJSM. P/U AND BAKERLOK FIRST 4 JOINTS. CHECK FLOAT EQUIPMENT. P/U AND RIG W/7-5/8" LINER. 101 JTS. Page No: 22 Copyright @ 1993-99 by Epoch WellSite Services, Inc. All rights reserved. PERC" WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 09/06/2002 1.50 D CS 0.50 D CC 5.50 D CS 2.50 D CS 1.50 D CS DATE: 09/07/2002 HOURS PH OP 1.00 D CS 4,50 D CC 0.50 D CM 5,00 D CM 2.50 D CM 1.50 D CS 0.50 D CC 6.50 D TR 2.00 D TR DATE: 09/08/2002 HOURS PH OP 2.50 IS-D BO 1.00 IS-D RR 0.50 IS-D RS 0.50 IS-D BO 1.50 IS-D RS 6.00 IS-D TR 2.00 IS-D TR 5.50 IS-D TR 1.25 IS-D TR 0,50 IS-D CC 2.75 IS-D TR DATE: 09/09/2002 HOURS PH OP 1.50 0 TR 0.75 0 PT 4.25 0 DC 1.00 C CC 1.00 IS-D PT 6.00 0 DC 3.00 0 DR 0.50 0 RS 0.50 0 DR ) OPERATIONS SUMMARY REPORT. ) Today's Date: 11/13/2002 REDOUBT UNIT #5A AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 025755 RU #5A 50-733-20513-00 DRILLING 12.25 HOLE,DRILLlNG 8. REDOUBT SHOAL 1 DSS: 106 15,325 9.60 CUM COST TO DATE: 9,221,399.81 DEPTH: MUD WT: M/U HANGER/PACKER ASSY.; BUMPER SUB; 1 JT. 5" DP. R/D CASING TOOLS. BREAK CIRCULATION. 500 PSI @23 SPM. UP WT -125K. DOWN WT -102K. RIH W/ DP @ 2 MIN/STD, FILL PIPE EVERY 10 STDS, ESTABLISH CIRCULATION. CONDITION MUD. RIH WI 7-5/8" LINER DSS: 107 15,325 9.55 CUM COST TO DATE: 9,529,982.94 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION RIH wI 7-5/8" liner. P/U cement head. Tag bottom @15,325' P/U 2'. Establish circulation. Condition mud (4 BPM @ 800 psi) Drop steel ball. Let freefall. Wait on ball to seat. At 12:25 hrs, pump ball - 2558 stks, At 14: 10 hrs, drop second ball (phenolic), Pump down on seat. 3785 stks. At16:15 hrs., set hanger w/1800psi @ 30K down, Release fl hanger w/2500 psi. Verify release, Blow seat wI 3900 psi. PJSM. Pump 5 bbl water. Test lines tJ 4500 psi. Pump 15 bbls. water; 30 bbls 10.5 ppg cement spacer; 45 bbls. 15.8 ppg cement. Displace. Bump plug wI 367 bbls @ 1100 psi. Pressure up to 2000 psi fl 2 min. Check float. 2 bbl return. Set packer w/65K. Pick up 30', reverse circulate, No cement. Pump dry job. Break cement line. UD cement head and pup joint. POOH. Cull Pipe fl bad hard bands while coming out of the hole, UD 15 jts, 5" HWDP; hanger; bumper sub; 3 Monel drill collars; liner running tool DSS: 108 15,325 9.50 CUM COST TO DATE: 9,729,010.01 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION C/O BTM RAMS F/7 5/8" T/ 5", TD DOWNTIME. CANRIG TECH CHECKING TOLERANCES ON GEARING, SERVICE RIG. PULL TEST PLUG, SET WEAR BUSHING. SLIP & CUT DRLG LINE. P/U BHA, ORIENT MTR, UPLOAD SPERRY TOOLS, WORK BOAT. P/U 45 JTS 31/2 HWDP, DRIFT, RATTLE (HEAVY SCALE) SHALLOW HOLE TEST. P/U 129 JTS 4" HT 40 DP, DRIFT, STRAP & RATTLE. CHANGE OVER TI 5" TOOLS, SLM, TIH. CIRC I FILL PIPE @ 7557'. TIH DSS: 109 15,375 9.50 CUM COST TO DATE: 9,836,195.32 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION TIH. SLM. CIRC & TAG UP ON UC @ 15,249. PRES TEST CSG T/3,000 PSI F/30 MIN. GOOD TEST. DRILL UC, F/C & 1/2 OF SHOETRACK T/15,292. CIRC BTM'S UP. PRESSURE TEST CSG T/3,OOO PSI F/30 MIN. GOOD TEST. 15,292. DRILL HARD CMT & SHOE. SHOE @ 13,325. DRILL FORMATION T/15,340. RIG SERVICE. Page No: 23 Copyright @ 1993-99 by Epoch WellSite Services, Inc. All rights reserved. PERCy' WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 09/09/2002 2.00 D CC 0.75 D PT 1.75 D DR 1.00 D CC DATE: 09/10/2002 HOURS PH OP 1.00 D CC 3.00 D DR 3.00 D CC 0.50 IS-D RR 0.50 D RS 8.50 D TR 4,00 D TR 3.50 D PT DATE: 09/11/2002 HOURS PH OP 0,50 D RS 2.50 D TR 9.00 D TR 0.50 D RS 1,00 0 RS 1,50 0 TR 4.50 0 CO 0,50 0 CC 4.00 0 TR DATE: 09/12/2002 HOURS PH OP 4.00 0 TR 3.50 0 TR 3.00 0 TR 7.00 0 TR 3.00 0 CC 1.00 IS-D LO 2.50 0 CC DATE: 09/13/2002 HOURS PH OP 15.50 0 DR 0.50 0 TR 0.50 D RS 0.50 D LO ) OPERATIONS SUMMARY REPORT ) REDOUBT UNIT #5A AFE NO: WELL ID NO.: API NO.: EVENT DESC.: REDOUBT SHOAL 1 Today's Date: 11/13/2002 025755 RU #5A 50-733-20513-00 DRILLING 12.25 HOLE, DRILLING 8, DSS: 109 15,375 MUD WT: 9.50 CUM COST TO DATE: 9,836,195.32 DEPTH: DRILL FORMATION T/15,350 CBU FOR SAMPLES. LOW C-5'S. FIT @ 11,992 TVD, MW 9,5 EMW 10.5. 623 PSI. DRILL T/15375. . CBU SAMPLES, LOOKING FOR HIGHER C-5'S. ACT ACTIVITY DESCRIPTION 9.44 CUM COST TO DATE: 9,931,316.37 DSS: 110 15,425 MUD WT: DEPTH: Circulate samples at 15375'. Drilling to 15425'. Circulate samples at 15425'. Dry Job. Rig Repair. DWK breaks. Normal rig service Tripping - BHA work Unload LWD. BOP test. ACT ACTIVITY DESCRIPTION 9.50 CUM COST TO DATE: 10,043,444.10 DSS: 111 15,485 MUD WT: DEPTH: Normal rig service P/U 60' core barrel. Dress with ESS survey tool. Trip to shoe. Rig Service. Adjust and inspect breaks. Cut drilling line. Wash to bottom, Core from 15425' to 15485'. C&C POH with core barrel. ACT ACTIVITY DESCRIPTION 9.50 CUM COST TO DATE: 10,123,510.65 DSS: 112 15,495 MUD WT: DEPTH: POH with core barrel. Lay down core. Full recovery. Dress core barrel. Make up BHA. Load LWD source. RIH. to shoe. Pump sweep. Circulate hole clean, Log with LWD tools, Slide drilling from 15485' to 15495'. ACT ACTIVITY DESCRIPTION 9.30 CUM COST TO DATE: 10,209,304.76 DSS: 113 15,575 MUD WT: DEPTH: Drilling/Sliding from 15495' to 15552'. Short trip to shoe. Normal rig service. Correlate depth with LWD. Page No: 24 Copyright @ 1993-99 by Epoch WellSite Services, Inc. All rights reserved. P EiCÝ ) OPERATIONS SUMMARY REPORT ) Today's Date: 11/13/2002 WELL NAME: REDOUBT UNIT #5A RIG NAME: FIELD NAME: REDOUBT SHOAL EVENT NO.: 1 DATE: 09/13/2002 1,00 0 TR 6,00 0 DR DATE: 09/14/2002 HOURS PH OP 24.00 0 DR DATE: 09/15/2002 HOURS PH OP 13.00 0 DR 3,00 0 CC 8.00 0 TR DATE: 09/16/2002 HOURS PH OP 2.50 0 TR 0.50 0 TR 1,50 0 TR 6,00 0 TR 1.50 D CC 1,50 D TR 8.00 D CO 0.50 D CO 0.50 D CC 1.50 D TR DATE: 09/17/2002 HOURS PH OP 7.50 D TR 0.50 D TR 2.00 D TR 3.50 D PT 3.00 D TR 7.00 D TR 0.50 D CC DATE: 09/18/2002 HOURS PH OP 0.50 D RS 0.50 D CC 2.00 D LO 4.00 D LO 2.25 D CC 14.75 D DR AFE NO: 025755 WELL ID NO.: RU #5A API NO.: 50-733-20513-00 EVENT DESC.: DRILLING 12.25 HOLE, DRILLING 8. DSS: 113 DEPTH: 15,575 9.30 CUM COST TO DATE: 10,209,304.76 MUD WT: RIH. Drill and slide to 15575'. DSS: 114 15,724 MUD WT: 9.30 CUM COST TO DATE: 10,290,690,09 DEPTH: ACT ACTIVITY DESCRIPTION Drilling/Sliding from 15575' to 15724'. DSS: 115 DEPTH: 15,819 MUD WT: 9.30 CUM COST TO DATE: 10,376,341.42 ACT ACTIVITY DESCRIPTION Drilling/Sliding from 15724' to 15819'. Circulate samples and hole clean. POH with bit # 20RR1, DSS: 116 15,840 MUD WT: 9.40 CUM COST TO DATE: 10,453,939,85 DEPTH: ACT ACTIVITY DESCRIPTION Down load LWD. BHA, Make up core assembly, Load Sperry ESS. RIH. Circulate. Wash to bottom, Survey. Polish bottom, Core from corrected depth 15819' to 15840'. Core barrel jamed, Pick up for ESS survey. Circulate. POH with core barrel. DSS: 117 DEPTH: 15,840 MUD WT: 9,30 CUM COST TO DATE: 10,559,268.90 ACT ACTIVITY DESCRIPTION TOH W/ # 2 CORE BARREL. SET BK HWDP, JARS & DC'S. CLN FLOOR. PULL SURVEY & UD CORE. (7.3 FT RECOVERY) REDRESS & SET BK CORE BBL. TEST BOP'S. P/U BIT, MOTOR & SET & ORIENT @ 1.5 DEG. LOAD & PROGRAM MWD. TIH. FILL PIPE @ 11,350' SHEAR MUD I SLIP & CUT DRLG LINE. DSS: 118 DEPTH: 15,913 10,656,614.90 9.40 CUM COST TO DATE: MUD WT: ACT ACTIVITY DESCRIPTION SLIP & CUT DRLG LINE. SHEAR MUD. CIRC & SHEAR MUD. ORIENT & LOG WI LWD FI 15,345 T/15,385 @ 50FPH. (SHOE DEPTH MOVED TI 15,342) LOG WI LWD F/15,385 T/15,805 @ 120-150 FPH. WASH, REAM & LOG, TAG BTM @ 15,840. (2' FILL) PUMP HIGH VIS SWEEP & SHEAR MUD. RECIP & ROTATE WHILE LIFTING SWEEP. DRLG I SLIDE F/15,842 T/15,913. Page No: 25 Copyright @ 1993-99 by Epoch WellSite Services, Inc. All rights reserved. PE1CÝ ) OPERATIONS SUMMARY REPORT ) Today's Date: 11/13/2002 WELL NAME: REDOUBT UNIT #5A RIG NAME: FIELD NAME: REDOUBT SHOAL EVENT NO.: 1 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 025755 RU #5A 50-733-20513-00 DRILLING 12.25 HOLE, DRILLING 8, DATE: 09/19/2002 HOURS PH OP 7.00 0 DR 1.00 0 TR 6.00 0 TR 2.00 0 TR 2.00 0 TR 1.25 0 TR 4.75 D TR DATE: 09/20/2002 HOURS PH OP 1.50 0 CC 0.50 0 TR 2.00 D CC 20.00 0 DR DATE: 09/21/2002 HOURS PH OP 8.50 D DR 0.50 IS-O RR 10.00 D DR 2.00 D TR 3.00 D TR DATE: 09/22/2002 HOURS PH OP 3.00 D TR 2.00 D TR 5.50 IS-D CO 1.00 IS-D RS 1.00 IS-D CC 2.50 IS-D TR 5,50 IS-D CO 0.50 IS-D CC 3.00 IS-D TR DATE: 09/23/2002 HOURS PH OP 5.00 D TR 1.00 D TR 1.50 D TR 3.00 IS-O PT 3.00 IS-D TR 5.00 IS-D TR 1.00 IS-O CC DSS: 119 DEPTH: 9.50 CUM COST TO DATE: 10,747,024.05 15,923 MUD WT: ACT ACTIVITY DESCRIPTION DRILLING I SLIDING T/15,923. (MUD MTR STALLING PRESSURING UP WHEN BIT IS ON BTM) TOH TI SHOE. SLICK. PUMP DRY JOB. TOH. SLM. PJSM. SET BK JARS & DC'S. UNLOAD SOURCES & DOWN LOAD DATA. STD BK LWD, FLUSH MTR & SET BK TI 0 DEG. BRK BIT & CIO MTR. ORIENT & LOAD SLD I CTN SOURCE. TIH HWDP. SHALLOW TEST. TIH TI SHOE. DSS: 120 DEPTH: 16,041 10,863,667.15 MUD WT: 9.45 CUM COST TO DATE: ACT ACTIVITY DESCRIPTION CIRCULATE & SHEAR MUD @ 15,355, TIH T/15,900, PUMP HI VIS SWEEP. CBU. FAN BTM. ORIENT. SLD IDRILL T/16,041. DSS: 121 16,153 11,007,451.84 DEPTH: MUD WT: 9.35 CUM COST TO DATE: ACT ACTIVITY DESCRIPTION DRILLING I SLIDING I SURVEY T/16,084. REPAIR TD BLOWER HOSE. DRILLING I SLIDING I SURVEY T/16, 153. (ORIGINAL CORE PT 16,140, CHANGED BY SALTMARSH) SURVEY, MONITOR WELL, TOH TI SHOE & PUMP DRY JOB. TOH. 6500' @ REPORT TIME, DSS: 122 9.35 CUM COST TO DATE: 11,091,893.87 16,207 MUD WT: DEPTH: ACT ACTIVITY DESCRIPTION TOH W/6 3/4" DRLG ASSY. REMOVE RA SOURCES, UD MOTOR & DN LOAD LWD TOOLS. PICK UP CORE BBL, LOAD & ORIENT SURVEY PROBE. TIH TI SHOE. CUT I SLIP DRLG LINE. CIRC I SHEAR MUD. TIH T/15,662. TOOK 12 K WT. WASH I REAM T/16,153. CORING F/16,153 T/16,207. CIRCULATE & SURVEY. TOH wI # 3 CORE ASSY. PUMP DRY JOB @ SHOE. TOH, 10,000 FT @ REPORT TIME. DSS: 123 16,209 9.50 CUM COST TO DATE: 11,296,512.16 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION TOH WI # 3 CORE ASSY. CLEAN FLOOR, UD SURVEY TOOL. UD # 3 CORE ( 100 % RECOVERY 54' ) UD CORE BBLS. TEST BOPE 250 13,000. AOGC WAIVED WITNESSING. CLEAR FLOOR. PIU BHA, LOAD SOURCES. TIH BHA, HWDP & SHALLOW TEST. TIH TI SHOE CIRCULATE & SHEAR MUO Page No: 26 Copyright @ 1993-99 by Epoch WellSite Services, Inc. All rights reserved. PERCy' WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 09/23/2002 0.50 15-0 TR 3.50 15-0 TR 0.50 D DR DATE: 09/24/2002 HOURS PH 24.00 D DATE: 09/25/2002 HOURS PH 11.50 D 1.00 D 10.50 D 1,00 D DATE: 09/26/2002 HOURS PH 3.50 D 6.00 D 1,00 D 2.00 D 10.50 D 1.00 D DATE: 09/27/2002 HOURS PH 3.50 D 7.00 D 2,00 D 0.50 D 3.00 D 5.50 D 1.00 D 1.50 D DATE: 09/28/2002 HOURS PH 0.50 D 23.50 D DATE: 09/29/2002 HOURS PH 15.50 D 3.50 D OP DR ) OPERATIONS SUMMARY REPORT ) REDOUBT UNIT #5A AFE NO: WELL ID NO.: API NO.: EVENT DESC.: REDOUBT SHOAL 1 Today's Date: 11/13/2002 025755 RU #5A 50-733-20513-00 DRILLING 12.25 HOLE,DRILLlNG 8. DSS: 123 16,209 MUD WT: 9,50 CUM COST TO DATE: DEPTH: TIH T/15,750. WASH T/15,800 WASH & REAM F/15,800 T/16,207 FAN BOTTOM. DRLG ACT ACTIVITY DESCRIPTION 9.35 CUM COST TO DATE: DSS: 124 DEPTH: 16,365 MUD WT: Drilling/Sliding from 16209' to 16365'. OP DR CC TR TR ACT ACTIVITY DESCRIPTION 9.30 CUM COST TO DATE: DSS: 125 16,440 MUD WT: DEPTH: Drilling/Sliding from 16365' to 16440'. Circulate, survey and dry job, POH. Tight hole at 15865'. Lay down 50 joints of drill pipe for hard banding, Work BHA. Down load LWD data. OP TR TR RS TR DR TR ACT ACTIVITY DESCRIPTION 9.40 CUM COST TO DATE: DSS: 126 16,532 MUD WT: DEPTH: Upload Iwd. Load RA sources. Work BHA. RIH with bit # 27. Cut drilling line. RIH. Wash through tight spots at 15745',15865' & 16120'. Ream 16370' to 16440'. Drilling/Sliding from 16440' to 16532'. Plugged bit. POH. DSS: 127 16,532 MUD WT: 9.55 CUM COST TO DATE: DEPTH: OP TR TR TR RS TR TR CC TR ACT ACTIVITY DESCRIPTION Pull partially plugged drill string into casing, Work through tight hole. POH, Down load sources. Work BHA, Normal rig service Change mud motor, P/U bit # 28. RIH to shoe. Circulate. RIH. Wash in from 16000'. Depth 16400' at report time. OP TR DR ACTIVITY DESCRIPTION 9.45 CUM COST TO DATE: DSS: 128 16,820 MUD WT: DEPTH: ACT Wash and ream to bottom. Drill from 16532' to 16820'. OP DR CC ACT ACTIVITY DESCRIPTION 9.35 CUM COST TO DATE: DSS: 129 17,000 MUD WT: DEPTH: Drilling from 16820' to 17000'. Circulate hole clean. Sweep. Page No: 27 Copyright @ 1993-99 by Epoch WellSite Services, Inc. All rights reserved. 11,296,512.16 11,378,093.01 11,465,427.28 11,548,021.85 11,669,483.66 11,754,083.79 11,836,631.36 PERC¥' WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 09/29/2002 2.00 D TR 2.50 D TR 0.50 D CC DATE: 09/30/2002 HOURS PH OP 3.50 D CC 3.00 D TR 2.00 D RS 2.00 D TR 3.50 D CC 2.00 D TR 3.00 D TR 3.50 D CC 1.50 D TR DATE: 10/01/2002 HOURS PH OP 1,00 D TR 0.50 D RS 1,50 D TR 4.00 D CC 2.50 D TR 9.00 D TR 3,00 D TR 2.50 D PT DATE: 10/02/2002 HOURS PH OP 2.50 D PT 3.50 D LO 15.50 D TR 2.50 D LO DATE: 10/03/2002 HOURS PH OP 1.00 D LO 1.50 D LO 2.50 D LO 11.00 D LO 3.00 D LO 0.50 D LO 4.50 D TR DATE: 1 0/04/2002 ) OPERATIONS SUMMARY REPORT ') Today's Date: 11/13/2002 REDOUBT UNIT #5A AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 025755 RU #5A 50-733-20513-00 DRILLING 12.25 HOLE, DRILLING 8. REDOUBT SHOAL 1 DSS: 129 17,000 9.35 CUM COST TO DATE: 11,836,631.36 DEPTH: MUD WT: Wash and work to shoe. RIH. Ream 15850' to 16000', 16240' to 16370'. No fill on bottom. Circulating on bottom for logging run. DSS: 130 17,000 9.35 CUM COST TO DATE: 11,914,572.01 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION Circulate and condition hole at bottom. POH to shoe. Tight 16320' - 16252'. 16047' - 15342', Cut drilling line. Change saver sub. Rig service. RIH. Ream 15926' to 15986', Ream 16565' to bottom. Circulate the hole clean. POH to shoe, Tight 16892'.16131' and ream at 15800'. RIH to bottom. Ream tight hole at 15800' to 16400'. Circulate the clean. Sweep. POH. Work up throgh tight hole at 16150'. DSS: 131 DEPTH: 17,000 9.60 CUM COST TO DATE: 11,995,283.46 MUD WT: ACT ACTIVITY DESCRIPTION TOH TI SHOE. SERVICE RIG. TIH (TIGHT F/15,800 - 16,200 ) WASH F/15,990 T/16,020. PUMP HIGH VIS SWEEP. WEIGHT UP F/9.4 T/9.5 PPG. TOH TI SHOE. PUMP OUT 16,270 - 16,250 & 15,937. TOH TI SHOE. PUMP DRY JOB. TOH T/4" HT, DROP 2 5/16" RABBIT, TOH. PJSM. CLEAN FLOOR. REMOVE RA SOURCES, DN LOAD LWD TOOL. UD LWD TOOLS & MOTOR. RIG UP & TEST BOPE. 250/3,000 PSI. DSS: 132 DEPTH: 17,000 9.60 CUM COST TO DATE: 12,059,484.83 MUD WT: ACT ACTIVITY DESCRIPTION Finish weekly BOP test. Pick up Schlumberger tools. RIH, Establish circulation each 2000'. Rabbit D.P. Break circulation. Rig up wire line. Depth 15120'. DSS: 133 17,000 9.70 CUM COST TO DATE: 12,117,705.76 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION Rig up wire line side entry sub. RIH with wet connection. Latch up to connection. Prepare to TCL. Begin logging run. Tight at 16155'. Unable to pass 16725'. Log back up to shoe. Tight at 16189'. CMR quit at 15710'. POH with wire line. Lay down side entry sub. Rig down sheave in derrick. Pump dry job. POH with TCL tools CMR, ECL & NGT. DSS: 134 DEPTH: 17,000 9.65 CUM COST TO DATE: 12,372,526.21 MUD WT: Page No: 28 Copyright @ 1993-99 by Epoch WellSite Services, Inc. All rights reserved. PEiC" WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: HOURS PH OP 3.50 D LO 1,50 D LO 2.00 D RS 6,50 D TR 2.50 D CC 3.00 D TR 2,00 D TR 3.00 D CC DATE: 10/05/2002 HOURS PH OP 1,50 D CC 2.00 D TR 0.50 D RS 1.00 D TR 1.00 DT RR 1.50 D TR 4,00 D CC 2.00 D TR 8.00 D TR 1.00 D TR 1.50 D CS DATE: 10/06/2002 HOURS PH OP 3,00 D CS 1.00 D CS 9,50 D CS 2.00 D CC 1,50 D CS 1.50 D CS 1.00 D CM 1.00 D CM 1,00 D CM 1.50 D CC DATE: 10/07/2002 HOURS PH OP 1.00 D CC 0.50 D TR 2.50 D CC 6.00 D TR 0.50 D TR 1.50 D TR 1.00 D TR ) OPERATIONS SUMMARY REPORT ) REDOUBT UNIT #5A AFE NO: WELL ID NO.: API NO.: EVENT DESC.: REDOUBT SHOAL 1 ACT ACTIVITY DESCRIPTION POH with logging tools on drill pipe. Safety meeting. Unload RA source. Lay down tools. Cut drilling line. Rig service. Pick up clean out assembly. RIH to shoe. Condition mud and circulate at bottom. RIH, Ream tight hole at 16147' to 16227'. 16630' to 16645', 16720' to 1670'. Wash, work and ream 16880' to 16970'. Tight and packing off. Rotate, circulate and recriprocate at bottom. Today's Date: 11/13/2002 025755 RU #5A 50-733-20513-00 DRILLING 12.25 HOLE, DRILLING 8. ACT ACTIVITY DESCRIPTION 9.65 CUM COST TO DATE: 12,441,976.96 DSS: 135 17,000 MUD WT: DEPTH: Circulate and condition hole at bottom. POH to shoe. Wash past tight spots 16545', 16215' & 16040'. Normal rig service RIH to 15835'. Stop and POH to shoe. Rig Repair. Repair break cooling leak. RIH. Clean tight hole at 16305' & 16705', Circulate and condition hole, POH to shoe. Wash past 16740',16218' & 15900'. POH. Set aside BHA. Rig up to 5 1/2" production liner. ACT ACTIVITY DESCRIPTION 9.65 CUM COST TO DATE: 12,564,758.71 DSS: 136 17,000 MUD WT: DEPTH: Pick up 45 joints of 5 1/2" 17# production liner. Pick up liner hanger. Rig down casing tools. Run liner in the hole on drill pipe. Circulate at shoe. Record torque and drag. Run liner to bottom. Tag at 16998'. Rig up cement head. Circulate and reciprocate at 16995'. Test lines 4000 psi. Pump preflush and spacer. Pump 56 bbls cement. Displace. Rotate liner. Bump plug. Set hanger, Release HR tool, Set PKR w/60,000 down. Reverse circulate. ACT ACTIVITY DESCRIPTION 9.75 CUM COST TO DATE: 12,687,924.94 DSS: 137 DEPTH: 17,000 MUD WT: REVERSE OUT CEMENT POH 5 STDS, BLOW DOWN CEMENT LINES CBU POH W/ RUNNING TOOL UD BUMPER SUB AND RUNNING TOOL UD 43/4" DC AND 15 JTS OF 31/2" HWDP IN DERRICK Page No: 29 Copyright @ 1993-99 by Epoch WellSite Services, Inc, All rights reserved. PElC¥" WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 10107/2002 1.00 D TR 1.00 0 RS 5.00 0 TR 0.50 D CC 2.50 D CC 1.00 D CC DATE: 10/08/2002 HOURS PH OP 3,00 D CC 3.00 D TR 0.50 D RS 3.50 D TR 1.00 0 TR 3.00 0 RS 6.00 D TR 4.00 D TR D DATE: 10/09/2002 HOURS PH OP 1.50 D TR 3.50 D CC 1.00 0 PT 4.50 D CC 1.00 D PT 9.50 D CC 3.00 0 CC DATE: 10/10/2002 HOURS PH OP 1.50 D CC 4.50 D CC 2.00 0 CC 0.50 D TR 15,50 D CC DATE: 10/11/2002 HOURS PH OP 19,00 D CC 4.00 D CC 1.00 D CC ) OPERATIONS SUMMARY REPORT Today's Date: 11/13/2002 ) REDOUBT UNIT #5A AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 025755 RU #5A 50-733-20513-00 DRILLING 12.25 HOLE, DRILLING 8. REDOUBT SHOAL 1 DSS: 137 DEPTH: 17,000 MUD WT: 9.75 CUM COST TO DATE: 12,687,924.94 PIU SCRAPER BHA RIH WI 4" DP CUT AND SLIP 111' DRLG LINE PIU 9 5/8" SCRAPER AND 5" DP. TRIP IN TO 15,000' BREAK CIRCULATION. TAG 51/2" LINER TOP AT 15,118' MD CBU AT 51/2" LINER TOP REVERSE CIRCULATE AT 51/2" LINER TOP DSS: 138 DEPTH: 17,000 MUD WT: 9.45 CUM COST TO DATE: 12,750,418.05 ACT ACTIVITY DESCRIPTION REVERSE HOLE CLEAN AT51/2" LINER TOP PULL 4 STDS. PUMP DRY JOB, POH LUBRICATE RIG POH WI SCRAPER ASSEMBLY LAY DOWN BHA CHANGE OUT VARIABLES TO 27/8" X 51/2" , TEST DOOR SEALS TO 250/3000 PSI PIU BHA. PIU 31/8" DC. PIU 51 JTS OF 27/8" 10.4# DP. RIG DOWN TONGS. BREAK CIRCULATION RIH WI CLEANOUT ASSEMBLY. 15,000' MD AT REPORT TIME DSS: 139 17,000 DEPTH: 9.35 CUM COST TO DATE: MUD WT: 12,818,344.46 ACT ACTIVITY DESCRIPTION RIH tag landing collar at 16915' with 43/4" bit and scraper. Circulate bottoms up, Test casing to 3000 psi. Good test. Reverse circulate the hole clean. Test casing to 4000 psi. Good test. Reverse circulate while cleaning pits for displacement. Build spacers for displacement. DSS: 140 17,000 DEPTH: MUD WT: 8.50 CUM COST TO DATE: 12,882,678.53 ACT ACTIVITY DESCRIPTION Reverse circulate and mix spacers. Reverse circulate and pump spacers followed by seawater. Store oil base mud on board. Reverse circulate seawater and clean BOP. Pull 5 1/2" scraper from production liner. Clean pits. Transfer fluids. Inject waste. DSS: 141 17,000 DEPTH: 8.50 CUM COST TO DATE: MUD WT: 13,277,409.06 ACT ACTIVITY DESCRIPTION Clean mud pits and flush all lines with bit and scraper above production liner. Reverse circulate sea water - returns to injection. Finish cleaning mud pits. Build completion fluid. Page No: 30 Copyright @ 1993-99 by Epoch WellSite Services, Inc, All rights reserved. PE1CÝ WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 10/12/2002 HOURS PH 24.00 D DATE: 10/13/2002 HOURS PH 23,00 D 1.00 D DATE: 10/14/2002 HOURS PH 13.00 C 0.50 C 10.50 C DATE: 10/15/2002 HOURS PH 5.50 C 0.50 C 2,00 C 6.00 C 1.50 C 8.50 C DATE: 10/16/2002 HOURS PH 5.00 C 0.50 C 6.50 C 3.00 C 1.50 C 0.50 C 2.50 C WR 1.00 C TR 3.50 C TR DATE: 1 0/17/2002 HOURS PH 3.00 C 1.50 C 0.50 C 2.00 C ') , OPERATIONS SUMMARY REPORT ) Today's Date: 12/16/2002 REDOUBT UNIT #5A 025756 RU #5A 50-733-20513-00 COMPLETE WELL # RU 5A REDOUBT SHOAL 2 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: DSS: 17,000 8,50 CUM COST TO DATE: 65,675.95 DEPTH: MUD WT: OP CC ACTIVITY DESCRIPTION Attempted to displace with KCL. Unsuccessful. Circulate sea water in an effort to clean the remnets of oil base mud from the well. Reclean pits. ACT DSS: 2 8.50 CUM COST TO DATE: 132,124.19 17,000 DEPTH: MUD WT: OP CC CC ACTIVITY DESCRIPTION Circulate surfactant / solvent / detergent sweeps to clean oil base mud cake from well Well clean. Mix KCL completion fluid. ACT DSS: 8.60 CUM COST TO DATE: 194,571.69 3 17,000 MUD WT: DEPTH: OP CC RS TR ACT ACTIVITY DESCRIPTION Mix and displace KCL. Filter fluid to final turbidity of 275. Normal Rig service POH with clean out assembly. Stand back BHA. DSS: 17,000 8,60 CUM COST TO DATE: 255,759.19 4 DEPTH: MUD WT: OP BP BP LO LO TR TR ACT ACTIVITY DESCRIPTION TEST BOPS RO 3,000 PSI. TEST WITNESSED BY LOU GRIMALDI RIG DOWN BOP TEST JOINT SECURE 2 7/8" D.P. RIG UP FOR WIRELlNE LOG W/ USIT AND CBL LAY DOWN 3 1/8" COLLARS RIH W/ HALLIBURTON EZ DRILL ON DRILLPIPE DSS: 5 17,000 8.73 CUM COST TO DATE: 386,214.80 DEPTH: MUD WT: OP CC TR TR WR WR WR ACT ACTIVITY DESCRIPTION Circulate and weight up KCL from 8.6 ppg to 8.7 ppg Set EZ Drill at 15,740'. Good indication of set. Sheared at about 40k additional upweight. POH wI running tool Rig up pressure control for perforating w/ 5" DP, pump-in sub, packoff, Test SWS firing head. RIH w/ perf guns. Tag up on EZ Drill at 15,758' WL (Note: 20' difference from WL to DP) Perforate from 15,753' WL to 15,755' WL w/2 7/8" Power Jet, 6spf. Well went on slight vacume after guns fired. Took 1 bbl of KCL. POH w/ wireline. Rig down SWS, M/U EZ Drill and 2 7/8" DP. RIH w/2nd EZ drill assembly. DSS: 6 17,000 441,670.80 8.73 CUM COST TO DATE: MUD WT: DEPTH: OP CM CM CM CM ACT ACTIVITY DESCRIPTION RIH with EZ drill retainer. Set retainer at 15725'. Test lines to 4350 psi. Establish injection rate. Squeeze 4 bbls of cement into perfs, Page No: 1 Copyright @ 1993-99 by Epoch WellSite Services, Inc. All rights reserved. PERCy" WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 10/17/2002 1.50 C CM 2.00 C CM 3,00 C TR 1.00 C RS 3.50 C TR 6.00 C TR DATE: 10/18/2002 HOURS PH OP 2.50 C TR 10,00 C DC 1.00 C TR 3.00 C CC 1.50 C CC 3,00 C CC 1.00 C WR 2.00 C CC DATE: 10/19/2002 HOURS PH OP 3.50 C CC 6.50 C CC 3.50 C CC 7.50 C CC 3.00 C LO DATE: 10/20/2002 HOURS PH OP 13.50 C LO 1.00 C FI 0.50 C FI 2,00 C FI 1.50 C FI 4.50 C FI DATE: 10/21/2002 HOURS PH 1.00 C 3.50 C 3.50 C 6.00 C 1.00 C 2.00 C 2.50 C 1.50 C ) OPERATIONS SUMMARY REPORT ) REDOUBT UNIT #5A AFE NO: WELL ID NO.: API NO.: EVENT DESC.: REDOUBT SHOAL 2 Today's Date: 12/16/2002 025756 RU #5A 50-733-20513-00 COMPLETE WELL # RU 5A DSS: 6 DEPTH: 17,000 MUD WT: 8.73 CUM COST TO DATE: 441,670.80 Pull out of retainer and reverse circulate. No cement in returns. Pull above retainer and circulate drill pipe clean. POH, Cut drilling line. POH, Make up 4.75" bit and BHA. RIH. DSS: 7 DEPTH: 17,000 MUD WT: 8.73 CUM COST TO DATE: 510,599.20 ACT ACTIVITY DESCRIPTION RIH with clean out assembly. Tag cement at 15718'. Drill out cement and retainers. RIH to PBTD 16914'. Circulate hi vis sweeps. Move pit volume to injection. Flush lines. Clean pits. Clean pits. Mix and pump solvent, sufactant, and detergent pills. Displace with sea water. Rig repairs. Power to # 2 mud pump. Displace with sea water chasing sweeps, DSS: 8 17,000 MUD WT: 8.60 CUM COST TO DATE: 582,911.36 DEPTH: ACT ACTIVITY DESCRIPTION Displace well with sea water at 16914' PBTD, Returns to injection. Well clean. Reverse circulate displace sea water with 8.6 # KCL. Reverse circulate filtering brine. Final turbidity value 50 at flowline. One circulation. POH with clean out assembly, Lay down drill collars. Safety meeting, M/U test head. Pick up DST perforation guns. ACT ACTIVITY DESCRIPTION 8.60 CUM COST TO DATE: 661,061.52 DSS: 9 17,000 MUD WT: DEPTH: RIH with DST # 1. Stop near correct depth. Rig up slick line with Schlumberger's G-R memory tool. RIH. Tool would not pass 7827'. POH. Left partial tool string in the hole. RIH with slick line overshot. Pulled 1000# over. POH. No recovery. Fish at 7812'. Second attempt with overshot.pulled 650# off. POH, String parted at hydraulic jars. POH with drill string. Looking for fish. OP FI FI FI WT RS WT WT WT ACT ACTIVITY DESCRIPTION 8.60 CUM COST TO DATE: 767,366.92 DSS: 10 17,000 MUD WT: DEPTH: Remove wire line tools stuck in drill string. POH to DST tools. Change out DST tools damaged by falling wire line tools. RIH. Rabbit drill pipe. Cut drlling line. Rig service. RIH to DST depth. Correlate With Schlumberger. Set top shot on depth. Set PKR at 14985' driller's depth. Page No: 2 Copyright @ 1993-99 by Epoch WellSite Services, Inc, All rights reserved. PEftel ) . OPERATIONS SUMMARY REPORT ) Today's Date: 12/16/2002 WELL NAME: REDOUBT UNIT #5A RIG NAME: FIELD NAME: REDOUBT SHOAL EVENT NO.: 2 AFE NO: 025756 WELL ID NO.: RU #5A API NO.: 50-733-20513-00 EVENT DESC.: COMPLETE WELL# RU 5A DATE: 10/21/2002 3.00 C DATE: 10/22/2002 HOURS PH 0.50 C 3.50 C 20,00 C DATE: 10/23/2002 HOURS PH 16.00 C 8.00 C DATE: 10/24/2002 HOURS PH 24.00 C DATE: 10/25/2002 HOURS PH 4.00 C 4.50 C 0.75 C 14.25 C 0.50 C DATE: 10/26/2002 HOURS PH 6.50 C 4.00 C 8.50 C 5.00 C DATE: 10/27/2002 HOURS PH 10.50 C 0.50 C 3.00 C 4.00 C 3.00 C 4.00 C DATE: 10/28/2002 HOURS PH WT OP WT WT WT OP WT WT OP WT DSS: 10 DEPTH: 8.60 CUM COST TO DATE: 767,366.92 17,000 MUD WT: Rig up surface equipment. Pressure testing. DSS: 11 8.60 CUM COST TO DATE: 844,179.32 17,000 MUD WT: DEPTH: ACT ACTIVITY DESCRIPTION Safety meeting, Pressure test lines and pump N2 cushion. Fire perf guns and flow well for 15 min. Shut in for 30 minutes. Open to test at 11: 15 hrs. ~,'Y DSS: 12 17,000 8.60 CUM COST TO DATE: 901,815.12 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION Flow lower hemlock on DST. DST shut in for final build up. DSS: 13 17,000 957,365.42 DEPTH: MUD WT: 8.70 CUM COST TO DATE: ACT ACTIVITY DESCRIPTION WELL SHUT-IN FOR BUILD-UP DSS: 14 17,000 8.70 CUM COST TO DATE: 1,201,927.82 DEPTH: MUD WT: OP WT WT WT TR TR ACT ACTIVITY DESCRIPTION Well Shut in at LPRN valve Reverse out 25 bbl of oil and 193 bbl of 8.4~8.5 water. Reverse around 8.7+ KCL. Open packer by-pass. Well stable. Unseat packer. Well stable, POH wI DST #1 Assembly. Well took 8 bbl of KCL on trip out. MIU and RIH wI EZ Drill DSS: 15 17,000 8.70 CUM COST TO DATE: 1,257,680.32 DEPTH: MUD WT: OP TR CC TR PT ACT ACTIVITY DESCRIPTION TIH WI EZ DRILL. SET EZ DRILL @ 15,575 WI 35 TURNS TI RHT. PUMP HIGH VIS SWEEP, CIRC HOLE CLEAN. TOH WI RUNNING TOOL. TEST BOP'S. 250 13,000 PSI. ( 1 HR RETRIEVING I SETTING WEAR BUSHING. TEST PLUG 0 RING LEAKED. DSS: 16 17,000 MUD WT: 8.70 CUM COST TO DATE: 1,415,845.90 DEPTH: OP TR WT PT WT WT WT ACT ACTIVITY DESCRIPTION PIU MULE SHOE & 24 JTS 2 7/8" TBG. TIH WI # 2 DST STRING. SET PACKER @15,735'. PJSM. RIU PTS, TEST LINES TI 3,000 PSI. RIU NITROGEN, TEST LINES TI 4,000 PSI. DISPLACE DP WI NITROGEN. 3,070 PSI SURFACE PRESSURE, 1,000 PSI UNDER-BALANCE. # 2 DST. OPENED LPRN @ 1155 HRS WI 1700 PSI ON BK SIDE. INITIATED NITROGEN FLOW BK @ 1205 HRS. (DAYLIGHTS TIME CHANGE) CONTINUE # 2 DST. DSS: 17 17,000 8.70 CUM COST TO DATE: 1,470,443.00 DEPTH: MUD WT: OP ACT ACTIVITY DESCRIPTION Page No: 3 Copyright @ 1993-99 by Epoch WellSite Services, Inc, All rights reserved. PElCÝ ) . OPERATIONS SUMMARY REPORT ') T oday's Date: 12/16/2002 WELL NAME: REDOUBT UNIT #5A RIG NAME: FIELD NAME: REDOUBT SHOAL EVENT NO.: 2 AFE NO: 025756 WELL ID NO.: RU #5A API NO.: 50-733-20513-00 EVENT DESC.: COMPLETE WELL # RU 5A DATE: 10/28/2002 24,00 C WT DATE: 10/29/2002 HOURS PH 2.00 C 6.00 C OP WT WT 2,00 C TR 1.00 C RS 8.00 C TR 5.00 C TR DATE: 10/30/2002 HOURS PH OP 1.50 C TR 4,50 C CC 2.00 C RS 11,50 C CC 4.00 C CC 0.50 C TR DATE: 1 0/31/2002 HOURS PH OP 5,00 C TR 5.50 C TR 0.50 C RS 7,00 C TR 3.00 C PP 2.00 C PP 1,00 C RS DATE: 11/01/2002 HOURS PH OP 1.00 C WT 3.25 C WT 1.75 C WT 18,00 C WT DATE: 11/02/2002 HOURS PH OP 4.00 C WT 20,00 C WT DSS: 17,000 8.70 CUM COST TO DATE: 1,470,443.00 17 DEPTH: MUD WT: FLOW LOWER HEMLOCK ON DST # 2. OIL TI SURFACE @ 1030 HRS. DSS: 18 17,000 8.70 CUM COST TO DATE: 1,563,667.43 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION DST # 2. PJSM. PRES. ANNULUS T/3,200 PSI OPENING RD VALVE @ 0820 AND REVERSE CIRCULATE .BLEED OFF ANNULUS, P/U OPEN RD CIRC SUB, CIRC LONG WAY 800 UNITS @ BTMS UP. RIG DN PTS. TOH W/ DST # 2 STRING. CUT & SLIP DRLG LINE, TOH, UD DST TOOLS & 24 JTS 2 7/8" TBG. P/U RUNNING & EZ-DRILL. TIH. DSS: 19 DEPTH: 17,000 8.70 CUM COST TO DATE: 1,794,515.13 MUD WT: ACT ACTIVITY DESCRIPTION TIH WI EZ-DRILL. SET EZ-DRILL @ 15,700. COMMENCE REV CIRC,1200 UNITS GAS @ BTMS UP. AFTER ONE COMPLETE CIRC. BRINE TOO OILY TO FILTER. CLEAN PITS. PUMP 40 BBL CITRIC ACID,SAFE SURF & HEC SWEEPS. DISPLACE W/ SEAWATER. FILTER BRINE @ 8 BPM.CHECK NTU'S EVERY 1000 STKS,FINAL CHECK 106 NTU'S NTU'S. TOH W/ EZ-DRILL RUNNING TOOL. DSS: 20 17,000 8.70 CUM COST TO DATE: 1,851,143.73 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION TOH W/ EZ-DRILL RUNNING TOOL. PJSM. P/U PERF GUNS & DST TOOLS. SERVICE RIG. TIH W/ # 3 DST ASSY. CORRELATE W/ SWS, SPACE OUT. RIU TEST HEAD, SET PACKER @ 14,990. TS @ 15,367 (WLM) PJSM, RIU PTS, TEST LINES T/ 3,000 PSI. RIU BJ TEST NITROGEN LINE T/ 4,000 PSI. WORK ON BJ PUMPING SKID. ( BROKEN FAN BELTS) DSS: 21 17,000 8,70 CUM COST TO DATE: 2,007,470.66 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION REPAIR BJ NITROGEN PUMPING SKID. BROKEN FAN BELTS, NO SPARES. INSTALL BUG FAN TO COOL UNIT. PUMP N2 CUSHION, 3000 PSI SURFACE PRESSURE. PRES ANNULUS T/3,000 PSI, HELD F/15 SEC. BLEED DN T/2,OOO PSI. (FIRE GUNS @ 10:36 AM) SHUT WELL IN 15 MIN;OPEN LPRN & FLOW WELL F/15 MIN. SHUT IN FI 30 MIN. DST # 3 ( UPPER HEMLOCK) MAIN FLOW PERIOD. DSS: 22 17,000 8.70 CUM COST TO DATE: 2,062,330.53 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION DST # 3 UPPER HEMLOCK. MAIN FLOW PERIOD. SHUT WELL IN @ LPRN & SURFACE FOR 36 HR BUILD UP. Page No: 4 Copyright <9 1993-99 by Epoch WellSite Services, Inc, All rights reserved. PEacy" ) OPERATIONS SUMMARY REPORT ) Today's Date: 12/16/2002 WELL NAME: REDOUBT UNIT #5A RIG NAME: FIELD NAME: REDOUBT SHOAL EVENT NO.: 2 DATE: 11/03/2002 HOURS PH 12,00 C 3.00 C 1.50 C 7.50 C DATE: 11/04/2002 HOURS PH 0.50 C 6,50 C 0.50 C 5.50 C 6.00 C 1.00 C 4.00 C DATE: 11/05/2002 HOURS PH 1.50 C 1.50 C 1,50 C 1.00 C 3.50 C 0.50 C 9.00 C 1.00 C 4.50 C DATE: 11/06/2002 HOURS PH 0.50 C 3,00 C 5.50 C 5,00 C 7.50 C 1.50 C 1.00 C DATE: 11/07/2002 HOURS PH 1.50 C OP WT WT WT TR OP TR TR RS PT TR RS TR OP TR DC CC TR CC RS TR TR TR OP TR CC TR TR TR TR TR OP TR AFE NO: 025756 WELL ID NO.: RU #5A API NO.: 50-733-20513-00 EVENT DESC.: COMPLETE WELL # RU 5A DSS: 23 17,000 8.70 CUM COST TO DATE: 2,117,596.13 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION WELL SHUT IN FOR FINAL BUILD UP. PJSM, PRES ANNULUS T/3,650,SHEAR RD CIRC VALVE. REV CIRC @ 3 BPM (START @ 1BPM FI SAMPLES) (213.56 BBLS H2O I 21,56 BBLS OIL REVERSED) WORK PACKER FREE WI 400 K. MONITOR, WELL STATIC, RIG DN PTS. TOH T/7 5/8 L T @ 11,290, MONITOR, WELL STATIC.( FILL + 2 BBLS @ LIT) 8.77 BBLS LONG ON HOLE FILL FI TRIP. DSS: 24 17,000 DEPTH: MUD WT: 8.70 CUM COST TO DATE: 2,174,305.73 ACT ACTIVITY DESCRIPTION TOH TI OST TOOLS. UD DST TOOLS. SERVICE RIG. TEST BOP'S. TIH T/8,OOO', CHANGE OVER T/5" TOOLS. CUT I SLIP DRLG LINE. TIH TI 5 1/2" LIT. BRK CIRC INTO LIT. SLICK. BREAK CIRC 1 STD FI BRIDGE PLUG. ATTEMPT TO PK OFF. CIRC & WORK PIPE. WASH TI BRIDGE PLUG @ 15,700. DSS: 25 2,444,328.18 17,000 DEPTH: MUD WT: 8.70 CUM COST TO DATE: ACT ACTIVITY DESCRIPTION TAG ON BRIDGE PLUG @ 15,691,PUMP HIGH VIS SWEEP, DRILL BRIDGE PLUG @ 15,691, CIRC & CLEAR SWEEP TI SURFACE, (MINIMUM AMOUNT OF FILL) TIH TI BRIDGE PLUG @ 16,575 (SLICK) PUMP HIGH VIS SWEEP & CIRC OUT. ( 2 CUPS FILL) SERVICE RIG TOH UD JUNK BASKETS. ( 50 % RECOVERY) MIU BHA F I 7 5/8 SCRAPER. TIH WI 7 5/8 SCRAPER. DSS: 26 17,000 2,500,180.18 MUD WT: 8.70 CUM COST TO DATE: DEPTH: ACT ACTIVITY DESCRIPTION TIH TO 15,118, TOP OF 51/2" LINER. CIRCULATE WHILE RECIPROCATING PIPE. TOH UO 3 1/8" DC'S. TIH W/2 7/8" DP & UD SAME. (HIGH WINDS) PIU PACKER ASSY. TIH T/15,000 DROP 1 7/16" KIRKSITE BALL, PUMP 15 MIN, LET BALL GRAVITATE TI BTM.PRES T/2,OOO PSI & PULL 20 KOVER. TOH DSS: 17,000 2,558,285.86 8.70 CUM COST TO DATE: 27 DEPTH: MUD WT: ACT ACTIVITY DESCRIPTION TOH WI BAKER PACKER RUNNING TOOL. Page No: 5 Copyright @ 1993-99 by Epoch WellSite Services, Inc, All rights reserved. PEiCÝ WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 11/07/2002 1.00 C RS 4.00 C TR 0.50 C TR 0,50 C RS 6.00 C TR 5.50 C TR 0.50 C RS 4.50 C AL DATE: 11/08/2002 HOURS PH OP 6.00 C AL 0.50 C RS 4.50 C AL 7.00 C AL 6,00 C TB DATE: 11/09/2002 HOURS PH OP 8.00 C TB 4.00 C AL 9.00 C TB 3,00 C AL DATE: 11/10/2002 HOURS PH OP 22.50 C TB 1.50 C TB DATE: 11/11/2002 HOURS PH OP 4.50 C AL 1.50 C AL 2.50 C AL 4.50 C BP 3.00 C WH 8.00 C MO ') OPERATIONS SUMMARY REPORT Today's Date: 12/16/2002 ) REDOUBT UNIT #5A AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 025756 RU #5A 50-733-20513-00 COMPLETE WELL # RU 5A REDOUBT SHOAL 2 DSS: 27 17,000 MUD WT: 8.70 CUM COST TO DATE: 2,558,285.86 DEPTH: CUT & SLIP DRLG LINE. TOH, UD BAKER RUNNING TOOL. PIU LLC & RUNNING TOOL. SERVICE RIG TIH WI SWS LLC. LATCH INTO PACKER, SET DN 5K. PIU VERIFY STUNG IN. SET DN 15 K, PIU & SHEAR OFF @ 11 K OVER STRING WT. TOH & UD SWS LLC RUNNING TOOL. M/U TEST PLUG & PULL WEAR BUSHING. CLEAR FLOOR I RlU TO RUN ESP PRODUCTION PUMP & TUBING, DSS: 28 17,000 MUD WT: 8.70 CUM COST TO DATE: 2,609,606.39 DEPTH: ACT ACTIVITY DESCRIPTION RIG UP TI RUN CENTRILlFT ESP. REPAIR CENTRILlFT SHEAVE. SERVICE RIG. RIG UP CENTRILlFT. MODIFY CENTRILlFT TOOL STAND, ( 3 RD TIME) PIU CENTRILlFT MOTORS, PUMPS, SEAL ASSY. MK UP PHOENIX CONTROL LINE I CHEMICAL LINES, RlU CABLE SHEAVE, SECURE POWER CABLE. TEST. PIU UP 31/2" L-80 TUBING, DRIFT, HAMMER ( SCALE) TIH WI ESP. DSS: 29 DEPTH: 17,000 8.70 CUM COST TO DATE: 2,727,076,62 MUD WT: ACT ACTIVITY DESCRIPTION RUN CENTRILlFT ESP ON 3 1/2", 9.3 LB L-80 TUBING. DRIFT & HAMMER ( SCALE) TORQUE T/2600 FT LBS. POSITION I TORQUE. LITTLE HEAT. SPLICE & TEST CABLE @ 4,144 FT. (1.8 OHMS, PHASE TI PHASE,2 K MEG) INSTALL 175 TON BJ SPIDER. RUN ESP TI 8,275 FT. CHANGE SPOOLS, REPLACE SHAFT WI BROKEN BULL GEAR. SPLICE & TEST CABLE. . DSS: 30 17,000 MUD WT: 8.70 CUM COST TO DATE: 2,803,319.12 DEPTH: ACT ACTIVITY DESCRIPTION Run 3.5" completion string with ESP and power cord. Make splices and conductivity checks as necessary. Make up tubing hanger and tie power line through penitrator. DSS: 31 DEPTH: 17,000 MUD WT: 8,70 CUM COST TO DATE: 3,384,457.70 ACT ACTIVITY DESCRIPTION Make final splice to penetrator on TBG hgr. Make up injection lines. Check continuity, Land TBG. Set lock down screws. Test seals to 5000 psi. TBG weight down 75,000# wlo block wt. ND BOPE NU Tree and test to 5000 psi. Skid rig from 5A to # 2 well. Secure rig at well center. Page No: 6 Copyright @ 1993-99 by Epoch WellSite Services, Inc. All rights reserved. I Company: field: Site: ',,"eD: WeDpa1h: WeD: Forest 011 COOK INLET Redoubt Redoubt Unit #5 RU#5A Redoubt Unit #5 WeD Position: +N/-S +E/-W Position Uncertainty: ) Forest Oil Corpora\. JI.. ) Deviation Report [)-dte: 10/2912002 Tim": 08 28' 14 Page: ('0-0 rdirud e(N E) Rt>fHt>nct>: WeB Redoubt Unit #5, Grid North \'ertkal (1'\"D) Rt'fert'nn>: Osprey N-429 @ 90' RKB 90.0 St>ctiul1 (\"S) Rden-l1ce: Wen (0,OON,O,OOE,13ì 21Azi) Sur-ny CalcuJation 1\Iethi}d: MlI1imum Curvature Db: Sybase Slot Name: -58.2 ft Northing: 2449931.80 ft 1.0 ft Easting: 200628.00 ft 0.0 ft Survey Program for Defuútive WeUpath Date: 08/13/2002 Validated: No Actual From To Survey ft ft 144.0 132,0 132.0 11384.4 11473.0 17000,0 'Survey I t. AHD ft 130.0 132.0 144.0 174.0 205.0 235.0 295,0 384.0 473.0 563,0 678.5 767.9 856.1 944.0 1036.7 1130,6 1224.0 1320.2 1414.3 1509.5 1604.8 1701.1 1797.3 1891.7 1986.1 2080.9 2173.8 2268.5 2359.5 2452.2 2546.2 2642.4 2736.9 2829.6 2924.2 3018.9 3111.1 3161.4 3251.7 3346.3 3441.3 Iodination deg 0.00 0.04 0.25 0.10 0.25 0.90 2.80 5.37 7.82 9.77 12.47 12.45 11.97 11.86 11.98 13.65 16.53 17.10 18.91 21.74 24.42 26.69 28.56 31.44 31.19 30.15 28.43 28.09 29.91 32.04 29.94 29.73 28.33 29.17 29,14 31.76 33.45 34.70 34.19 34.14 34.07 Rig RU#5 Gyro (1) Rig RU#5 MWD+SAG (1) Rig: RU#5A MWD + SAG TVD BDF X WeUbead ft ft Azimuth deg 0.00 42.00 42.00 356.00 232.00 206.00 198.00 212.00 211.68 211.50 211 .37 211.19 207.06 196.04 183.38 166.78 152,09 146.26 139.41 138.71 137.24 135.98 137.41 136.54 137.09 137.78 138.93 141.81 139.13 139.27 139.11 136.15 134.49 132.89 135.31 135.26 134.03 133.98 133.88 133.79 133.39 130.0 132.0 144.0 174.0 205.0 235.0 295.0 383.7 472.1 561.1 674.4 761.7 847.9 933,9 1024.6 1116.2 1 206.4 1298.5 1388.0 1477 .3 1564.9 1651.8 1737.0 1818.8 1899.4 1981.0 2062.0 2145.4 2225.0 2304.5 2385.1 2468.5 2551 .1 2632.4 2715.0 2796.7 2874.3 2916.0 2990.4 3068.8 3147.4 190.1 220.3 248.9 277.0 308.1 339.8 372.0 404.2 436.5 469.6 503.3 538.7 559.0 595.7 634.1 0.0 0.0 0.0 0.1 0.0 -0.1 -0.8 -3.7 -9.1 -16.3 -27.9 -37.9 -47.0 -53.6 -56.8 -54.9 -46,1 -31.9 -14.3 7.4 32.4 61.0 91.6 123.8 157.4 672.6 Latitude: Longitude: Version: TooIcode CB-GYRO-SS MWD+SAG MWD+SAG Y WeUhead ft 0.0 0.0 0.0 0.1 0,1 -0.2 -2,0 -7.6 -16.3 -28.0 -47.0 -63.5 -79.8 -96.6 -115.3 -135.9 -158,3 -182.2 -205.3 -230.2 -258.0 -288.1 -320.6 -355.1 -390.9 -426.5 -460.4 -495.0 -529.0 -565.1 -601 .7 -637.1 -669.7 -700.5 -732.5 -766.6 -801 .5 -821.1 -856.5 -893.3 -930.1 60 41 43.652 N 151 40 14.489 W 3 Tool Name Camera based gyro single shots MWD + Sag correction MWD + Sag correction V.Section ft 0.0 0.0 0.0 0.0 -0,1 0.0 0.9 3.1 5.8 9.5 15.5 20.8 26.6 34.4 46.0 62.4 84.9 112.0 141.0 174.0 211.4 252.9 297.5 344.7 393.7 442.1 487.5 532.3 576.3 624.0 672.4 720.2 766.0 810.5 856.6 904.5 954.1 982.3 1 033.2 1086.3 1139.5 TYD NAP ft 40.0 42.0 54.0 84.0 115.0 145.0 205.0 293.7 382.1 471,1 584.4 671.7 757.9 843.9 934.6 1026.2 1116.4 1 208.5 1 298.0 1387.3 1474.9 1561.8 1647.0 1728.8 1 809.4 1891.0 1972.0 2055.4 2135.0 2214.5 2295.1 2378.5 2461.1 2542.4 2625.0 2706.7 2784.3 2826.0 2900.4 2978.8 3057.4 D.L-S. deg/100ft 0.00 1.79 1.79 0.65 1.02 Tool TIE LINE CB-GYRO-SS MWD+SAG MWD+SAG MWD+SAG 2.28 MWD+SAG 3.19 MWD+SAG 3.08 MWD+SAG 2.75 MWD+SAG 2.17 MWD+SAG 2.34 MWD+SAG 0.05 MWD+SAG 1.13 MWD+SAG 2.59 MWD+SAG 2.82 MWD+SAG 4,29 MWD+SAG 5.10 MWD+SAG 1.85 MWD+SAG 2,96 MWD+SAG 2.98 MWD+SAG 2.88 MWD+SAG 2.42 MWD+SAG 2,06 MWD+SAG 3.09 MWD+SAG 0.40 MWD+SAG 1.16 MWD+SAG 1.95 MWD+SAG 1.48 MWD+SAG 2.46 MWD+SAG 2.30 MWD+SAG 2.24 MWD+SAG 1.55 MWD+SAG 1.71 MWD+SAG 1.23 MWD+SAG 1 .25 MWD+SAG 2.77 MWD+SAG 1.97 MWD+SAG 2.49 MWD+SAG 0.57 MWD+SAG 0.08 MWD+SAG 0.25 MWD+SAG ) Forest Oil Corpora, JI... ) Deviation Report Compan.y: Forest O~ Date: 10/29/2002 Time: 08 28: 14 r¡~ge: 2 Field: COOK INLE T Co-ordina.t'(N E) Rt'fert'nct': Well: Redoubt Unit #5, Gnd North Site: Redoubt Vertical (TVDI Reff'rence: Osprey. N-429 @ 90' RKB 90 0 Wftl: Redoubt Unit #5 Section (YS) Refereoct': Well (O.OON,O.OOE, 137.21Azij Wt'Upafh: RU#5A Sunt") Calculation Method: Mintmum Curvature Db: Sybase Survey AHD Indb'latJon Azimurb T\'D BDf X. Wt"Uhedd \" \\'ftlmad V.SefIWn T\'D NAP D.L.S. Tool ft deg deg ft ft ft ft ft deg/1 DOff 3537.0 33.06 137,67 3227.2 709.7 -967.8 1192.3 3137.2 2.69 MWD+SAG 3633.9 33.28 137.59 3308.3 745.5 -1007.0 1245.4 3218.3 0.23 MWD+SAG 3730.9 32.31 138.49 3389.8 780.6 -1046.0 1297.8 3299.8 1.12 MWD+SAG 3826.9 32.11 138,40 3471.0 814.5 -1084.3 1349.0 3381.0 0.21 MWD+SAG 3921,1 32,43 138.63 3550.7 847.8 -1122.0 1399.3 3460.7 0.36 MWD+SAG 4015.7 31.84 138.41 3630.8 881.2 -1159.7 1449.6 3540.8 0.64 MWD+SAG 4110.4 31.68 138.08 3711.3 914.3 -1196.9 1499.4 3621.3 0.25 MWD+SAG 4205.9 31.82 138.19 3792.5 947.9 -1234.3 1549.7 3702.5 0,16 MWD+SAG 4301.1 31.70 138.21 3873.5 981.3 -1271.7 1599.8 3783.5 0.13 MWD+SAG 4397.4 31.92 138.25 3955.3 1015.1 -1309.5 1650.6 3865.3 0.23 MWD+SAG 4492.3 31.82 138.47 4035.9 1048.4 -1346.9 1700.6 3945.9 0.16 MWD+SAG 4587.6 32.09 138,64 4116.8 1081.8 -1384.8 1751.1 4026.8 0.30 MWD+SAG 4676.5 30.99 137,93 4192.5 1112.7 -1419.5 1797.6 4102.5 1.31 MWD+SAG 4771.7 30.69 138.67 4274.2 1145.2 -1455.9 1846.4 4184.2 0.51 MWD+SAG 4863.2 31.01 138.65 4352.8 1176.2 -1491.2 1893.3 4262.8 0.35 MWD+SAG 4958,0 31 .49 139,10 4433.9 1208.5 -1528.2 1942.4 4343.9 0.56 MWD+SAG 5052.8 32.01 138.45 451 4.4 1241.4 -1 565.7 1992.3 4424.4 0.66 MWD+SAG 5148.4 31.77 138.40 4595.7 1274.9 -1603.5 2042.8 4505.7 0,25 MWD+SAG 5243.9 31.39 136.62 4676.9 1308.7 -1640.3 2092.8 4586.9 1.06 MWD+SAG 5340.0 32.01 136.98 4758.8 1343.3 -1677.2 2143.3 4668.8 0.67 MWD+SAG 5434.6 32.54 136.94 4838.8 1377.7 -1714.1 2193.8 4748.8 0.56 MWD+SAG 5527,7 31.16 137.70 4917.8 1411.1 -1750.2 2242.9 4827.8 1.54 MWD+SAG 5624.4 30.25 137.67 5000.9 1444.3 -1786.7 2292,3 4910.9 0.94 MWD+SAG 5715.6 30.18 137,81 5079.8 1475.2 -1820.7 2338.2 4989.8 0.11 MWD+SAG 5809.6 30.27 138.15 5161.0 1506.8 -1855.9 2385.5 5071.0 0.21 MWD+SAG 5901.0 30.44 138.19 5239.9 1537.6 -1890.3 2431,7 5149.9 0.19 MWD+SAG 5996.9 30.54 137.81 5322.5 1570,2 -1926.4 2480.3 5232.5 0.23 MWD+SAG 6092.0 30.69 136.70 5404.3 1 603. 1 -1962,0 2528.8 5314.3 0.61 MWD'+SAG 6188.6 30.85 137.00 5487.3 1636.8 -1998.0 2578.2 5397.3 0.23 MWD+SAG 6282.3 31.22 136.82 5567.6 1669.9 -2033.3 2626.5 5477.6 0.41 MWD+SAG 6377.9 31.31 136.91 5649.3 1703.8 -2069.5 2676.1 5559.3 0.11 MWD+SAG 6470.8 31.61 137.13 5728.6 1736.8 -2105.0 2724.6 5638.6 0.35 MWD+SAG 6564.3 31.93 137.89 5808.1 1770.1 -2141.3 2773.8 5718.1 0.55 MWD+SAG 6672.8 31.20 138.15 5900.5 1808.1 -2183.5 2830.6 5810.5 0.68 MWD+SAG 6767.2 30.81 138.42 5981.4 1840.4 -2219,8 2879.2 5891.4 0.44 MWD+SAG 6862.3 30.66 137.94 6063.2 1872.8 -2256.0 2927.8 5973.2 0.30 MWD+SAG 6957.8 30.33 137.56 6145.5 1905.4 -2291.9 2976,3 6055.5 0.40 MWD+SAG 7053.7 29.96 137.29 6228.4 1938.0 -2327.4 3024.5 6138.4 0.41 MWD+SAG 7146.6 29.54 138.01 6309.1 1 969. 1 -2361.4 3070.6 6219.1 0.59 MWD+SAG 7238.2 30.15 136.57 6388.5 2000,0 -2394.9 3116.1 6298.5 1.03 MWD+SAG 7331.3 30.45 137.41 6468.9 2032.0 -2429.3 3163.1 6378.9 0.56 MWD+SAG 7423.8 30.74 138.82 6548.5 2063.4 -2464.3 3210.2 6458.5 0.84 MWD+SAG 7519.1 30.63 138.32 6630.5 2095.6 -2500.8 3258.8 6540.5 0.29 MWD+SAG 7614.4 30.51 140.36 6712.5 2127.2 -2537.6 3307.2 6622.5 1.10 MWD+SAG 7707.4 32.45 139.11 6791.8 2158.6 -2574,6 3355.7 6701.8 2.20 MWD+SAG 7803.5 32.38 137.35 6873.0 2192.9 -2613.0 3407.2 6783.0 0.98 MWD+SAG 7896.1 32.65 136.54 6951 .0 2226.9 -2649.4 3457.0 6861.0 0.55 MWD+SAG 7991 .7 32.44 134.74 7031.7 2262.9 -2686.2 3508.4 6941.7 1.04 MWD+SAG 8084.7 32.64 133.86 7110.0 2298.6 -2721.1 3558.4 7020.0 0.55 MWD+SAG 81 80.7 32.36 133.95 7191.0 2335.8 -2756.9 3609.9 7101.0 0.30 MWD+SAG 8278.1 32.03 133.90 7273.5 2373.2 -2792.9 3661 .7 7183.5 0.34 MWD+SAG 8371.4 31.78 133.30 7352.6 2408,9 -2826.9 3710.9 7262.6 0.43 MWD+SAG 8465,6 32.33 134.93 7432.5 2444.8 -2861.7 3760.8 7342.5 1.09 MWD+SAG ) Forest Oil Corpora,,_Jn ) Deviation Report Com pan)' : Forest O~ D.:rtt"; 1 0/29,'2002 Time: 08'28.14 P~ge: j Field: COOK INLET Co-ordinalt'(N E) Rt'fert'ßc(': Well: Redoubt Unrt #5, Grid North Site: Redoubt Ve-ttlcal (T\ 'D) Rt'ft'"rt'l1ct'": Osprey N-429 @ 90' RKB 90.0 Well: Redoubt Unit #5 Section (YS) ReferenH: Well (0 00N,0.00E,137.21 AZI) WeUpath: RU#5A Sun-e)' Calmlation Method: Mlrumum Curvature Ob: Sybase Survey AHD lnclb1ation AzionJ1b TVD BDF X. Wellhead Y \\'ell.lkad V.Seclion T"O NAP D.L.S. TOtti ft deg deg ft ft ft ft ft deg/1 ooft 8556.8 31.83 133.80 7509.7 2479.4 -2895.5 3809.2 7419.7 0.86 MWD+SAG 8652.4 31.18 133.21 7591.2 2515.6 -2929.9 3859.0 7501.2 0.75 MWD+SAG 8747.2 30.66 133.20 7672.6 2551 . 1 -2963.3 3907.6 7582.6 0,55 MWD+SAG 8839.6 30.25 135.12 7752.2 2584.7 -2995.9 3954.4 7662.2 1.14 MWD+SAG 8938.3 30.16 136.45 7837.6 2619.4 -3031.5 4004.0 7747.6 0.68 MWD+SAG 9031.8 29.43 136.26 7918,6 2651 .4 -3065.1 4050.5 7828.6 0.79 MWD+SAG 9123.0 29.03 135.85 7998.3 2682.4 -3097.2 4095.0 7908.3 0.49 MWD+SAG 9214.9 28.21 135.57 8079.0 2713.1 -3128.7 4139.0 7989.0 0.90 MWD+SAG 9310.2 28.99 134.68 8162.6 2745.3 -3161.0 4184.6 8072.6 0.93 MWD+SAG 9404.0 29.62 135.36 8244.4 2777.7 -3193.5 4230.5 8154.4 0.76 MWD+SAG 9498.6 30.01 136.09 8326.5 2810.6 -3227.2 4277.5 8236.5 0.56 MWD+SAG 9592.5 31.16 136,18 8407.3 2843.7 -3261.6 4325.3 831 7.3 1.23 MWD+SAG 9688.7 31.16 136.06 8489.6 2878.2 -3297.5 4375,0 8399.6 0.06 MWD+SAG 9780.3 31.14 135.48 8568,1 2911.2 -3331.5 4422.4 8478.1 0.33 MWD+SAG 9876.6 31.05 136.64 8650.5 2945.7 -3367.2 4472.1 8560.5 0.63 MWD+SAG 9970.9 30.93 136.04 8731.3 2979.2 -3402.4 4520.7 8641,3 0.35 MWD+SAG 10065.1 30.70 136.95 8812.3 3012.5 -3437.4 4568.9 8722.3 0,55 MWD+SAG 10158.7 31.12 1 36.64 8892.6 3045.4 -3472.4 4617.0 8802.6 0.48 MWD+SAG 10252.5 30.16 136.46 8973.2 3078.3 -3507.1 4664.8 8883.2 1.03 MWD+SAG 10347.1 29.59 136.91 9055.3 3110.6 -3541 .4 4711.9 8965.3 0,65 MWD+SAG 10441.6 29.54 136,99 9137.4 3142.4 -3575.5 4758.5 9047.4 0.07 MWD+SAG 10534.0 29.29 136.96 9218.0 3173.4 -3608.7 4803.9 9128.0 0.27 MWD+SAG 10628.1 29.47 1 36.74 9299.9 3204.9 -3642.3 4850,1 9209.9 0.22 MWD+SAG 10722.7 29.45 136.40 9382.3 3236.9 -3676.1 4896.6 9292.3 0.18 MWD+SAG 10820.0 29,26 1 36,74 9467.1 3269.7 -3710.8 4944.3 9377.1 0.26 MWD+SAG 10913.9 28.37 137.08 9549.4 3300.6 -3743.8 4989.6 9459.4 0.96 MWD+SAG 11011.1 27.63 137.09 9635.2 3331 .7 -3777.2 5035.2 9545.2 0.76 MWD+SAG 11105.3 27.76 137.64 9718.6 3361.4 -3809.4 5079.0 9628.6 0,30 MWD+SAG 11139.6 27.91 136.81 9748.9 3372.2 -3821.2 5095,0 9658.9 1.21 MWD+SAG 11198.3 28.13 137.00 9800,8 3391.1 -3841.3 5122.6 9710.8 0.40 MWD+SAG 11234.3 28.32 137.06 9832.5 3402.7 -3853,8 5139.6 9742.5 0.53 MWD+SAG 11289.9 28.96 137.75 9881 .3 3420.7 -3873.4 5166.3 9791.3 1,30 MWD+SAG 11384.4 29.19 137.71 9963.9 3451 .6 -3907.4 5212.2 9873.9 0.24 MWD+SAG 11473.0 28.86 138.11 1 0041.4 .. 3480.4 -3939.3 5255.1 9951.4 0.43 MWD+SAG 11493.3 30.90 137,92 10059.0 3487.2 -3946,8 5265.3 9969.0 10.04 MWD+SAG 11580.3 36.79 137.08 10131.2 3519.9 -3982.5 5313.7 10041.2 6.79 MWD+SAG 11636.8 41.70 136.54 10174.9 3544.4 -4008.5 5349.4 10084.9 8.71 MWD+SAG 11683,7 41.70 136.42 10209.9 3565.9 -4031.2 5380.6 10119.9 0.17 MWD+SAG 11744.4 42.51 138.54 10255.0 3593.4 -4061.2 5421.3 10165.0 2.69 MWD+SAG 11780.9 44.56 139.36 10281.5 3609.9 -4080.1 5446.4 10191.5 5.82 MWD+SAG 11872.1 47.92 139.57 10344.5 3652.7 -4130.2 5512.2 10254.5 3.69 MWD+SAG 11966.5 52.19 138.58 10405.1 3700.1 -4184.8 5584.6 10315.1 4.59 MWD+SAG 12014.4 54.52 137.63 10433.7 3725.8 -4213.4 5623.0 10343.7 5.12 MWD+SAG 12108.3 56.20 137.08 10487.1 3778.1 -4270.3 5700.3 10397.1 1.85 MWD+SAG 12174.7 57.32 137.31 10523.5 3815.8 -4311.0 5755.8 10433.5 1.71 MWD+SAG 12263.3 59.16 136.86 10570.1 3867.2 -4366.2 5831 . 1 10480.1 2.12 MWD+SAG 12358.2 60.31 136.65 10618.0 3923.3 -4425.9 5913.1 10528.0 1.23 MWD+SAG 12451.8 62.10 135.80 10663.0 3980.0 -4485.1 5995.0 10573.0 2.07 MWD+SAG 12547.6 63.77 136.03 10706.6 4039.4 -4546.4 6080.4 10616.6 1.76 MWD+SAG 12643.6 65.58 135.72 10747.7 4099.8 -4608.6 6167.1 10657.7 1.91 MWD+SAG 12735.3 66.77 136.25 10784.7 4158.1 -4669.0 6251.0 10694.7 1.40 MWD+SAG 12826.9 67.33 136.97 10820.4 4216.0 -4730.3 6335.3 10730.4 0.95 MWD+SAG ) Forest Oil Corpora. Jfi Deviation Report Com pan}': Forest Oil Date: 10/29/2002 Time: 0828.14 Page: -4 Fidd: COOK INLET Co-ordinart"(N E) Rt'fert'n«: Wetl: Redoubt Unit #5. God North Site: Redoubt Vertical (T\'O, Reference: Osprey N-429 @ 90' RKB 90 0 WeU: Redoubt Unit #5 Sf'ction ('S) Rdhenn: Well (0.00N,0.00E,137 21Azi) WeUpath: RU#5A Sun'ey CalruJation Method: Minimum Curvature Db: Sybase Survey ,.\If[) Inclination Azimuth T\'O BDF X WE'Uhead \'\~e~ V. Section T\'O NAP D.L.S. TMI ft deg deg ft tt E k., ft ft deg/1 QOft 12924,3 64.85 138.00 10859.9 4276.2 -4795.9 6424.4 10769.9 2.72 MWD+SAG 13016.0 62.62 138.95 10900.5 4330.7 -4857.4 6506.5 10810.5 2.61 MWD+SAG 13109.5 62.69 138.65 10943.5 4385.4 -4920.0 6589.6 10853.5 0.29 MWD+SAG 13205.4 62.36 138.05 10987,7 4442.0 -4983.5 6674.7 10897.7 0.65 MWD+SAG 13299.8 61.38 136.52 11032.2 4498.4 -5044.7 6757.9 10942.2 1.77 MWD+SAG 13392.4 62.19 134.74 11076.0 4555.5 -5103.0 6839.5 10986.0 1.91 MWD+SAG 13485.2 63.60 134.41 11118.3 4614.4 -5161.0 6922.0 11028.3 1.55 MWD+SAG 13579.7 63.84 133.06 11160.1 4675.6 -5219.6 7006.5 11070.1 1.31 MWD+SAG 13671.9 65.94 133.46 11199.2 4736.4 -5276,8 7089.8 11109.2 2.31 MWD+SAG 13733,7 64.99 133.77 11224.9 4777,1 -5315.6 7146.0 11134.9 1.60 MWD+SAG 13772.0 63.80 134.52 11241.4 4801.8 -5339.6 7180.4 11151.4 3.58 MWD+SAG 13870.4 63.17 134.58 11285.4 4864.6 -5401.4 7268.4 11195.4 0.64 MWD+SAG 13967.0 63.04 135.11 11329. 1 4925.7 -5462.2 7354,5 11239.1 0.51 MWD+SAG 14063.4 64.09 136.19 11372.0 4986.0 -5523.8 7440.7 11282.0 1.48 MWD+SAG 14156.7 64.14 135.70 11412.7 5044.4 -5584.2 7524.6 11322.7 0.48 MWD+SAG 14253.4 64.09 136.34 11454.9 5104.8 -5646.8 7611.6 11364.9 0.60 MWD+SAG 14347.7 64.92 136.43 11495.5 5163.5 -5708.4 7696.8 11405.5 0.88 MWD+SAG 14446.5 63.70 136.81 11538.3 5224.6 -5773.1 7785.7 1144B.3 1.28 MWD+SAG 14541.0 62.08 136.88 11581.4 5282.2 -5834.5 7869.9 11491.4 1.71 MWD+SAG 14638.2 60.68 136.71 11628.0 5340.6 -5896.7 7955.2 11538.0 1.45 MWD+SAG 14732.7 58,97 135.73 11675.5 5397.1 -5955.7 8036,9 11585.5 2.02 MWD+SAG 14823.4 57.88 134.38 11723.0 5451 .7 -6010.4 8114.1 11633.0 1.75 MWD+SAG 14919.4 58.74 134.30 11773.4 5510.1 -6067.4 8195.6 "983.4 0.90 MWD+SAG 15013.0 59.90 134.17 11821.1 5567.8 -6123.6 8276.0 11731.1 1.25 MWD+SAG 15105.9 59.48 133.14 11868.0 5625.8 -6179.0 8356,1 11778.0 1.06 MWD+SAG 15202.9 59.61 133,88 11917.2 5686.4 -6236.5 8439.5 11827.2 0.67 MWD+SAG 15295.2 57.32 131.88 11965.5 5744.1 -6290.1 8518.0 11875.5 3.09 MWD+SAG 15346.7 57.64 130.76 11993.2 5776.7 -6318.7 8561.2 11903.2 1.94 MWD+SAG 15442.3 59.19 128,68 12043.2 5839.3 -6370.8 8641. 9 11953.2 2.46 MWD+SAG 15545,3 58.97 129.08 12096.1 5908.1 -6426.2 8729.3 12006.1 0.40 MWD+SAG 15637.4 55.20 130.19 12146.2 5967.7 -6475.5 8806.0 12056.2 4.21 MWD+SAG 15722.8 54.89 133.90 12195.1 6019.6 -6522.4 8875.6 12105.1 3.58 MWD+SAG 15840.7 52.98 128.18 12264.6 6091.4 -6585.0 8970.4 12174.6 4.24 MWD+SAG 15935.1 55.99 127.06 12319.4 6152.3 -6631.8 9046.1 1 2229.4 3.33 MWD+SAG 16027.8 57.55 133.64 12370.3 6211.3 -6682.0 9123.0 12280.3 6.17 MWD+SAG 16150.0 60.36 143.51 12433.4 6280.3 -6760.5 9227.5 12343.4 7.29 MWD+SAG 16216.5 60.22 143.10 12466.3 6314.8 -6806.7 9284.9 12376.3 0.58 MWD+SAG 16307.0 60.10 140.15 12511 .4 6363.6 -6868.3 9363.1 12421.4 2.83 MWD+SAG 16383.0 61.41 143.81 12548.5 6404.4 -6920.5 9429.2 12458.5 4.54 MWD+SAG 16409.6 61.61 143.00 12561.2 6418.3 -6939.3 9452.5 12471,2 2.78 ,MWD+SAG 16501.1 61.32 140.29 12604.9 6468.2 -7002.3 9532.6 12514.9 2.62 MWD+SAG 16594.8 61.30 139.12 12649.9 6521.3 -7065.0 9614.7 12559.9 1.10 MWD+SAG 16690.7 62.26 136.79 12695.2 6577.9 -7127.7 9699.2 12605.2 2.36 MWD+SAG 16784.3 63.31 135.46 12738.1 6635.6 -7187.8 9782.4 12648.1 1.69 MWD+SAG 16875.2 63.81 133.06 12778.5 6693.9 -7244.6 9863.7 12688.5 2.43 MWD+SAG 16941.4 65.29 132.39 12807.0 6737.8 -7285.1 9923.2 12717.0 2.42 MWD+SAG ., 17000.0 65.29 132.39 12831.5 6777.2 -7321.0 9976.3 12741.5 0.00 MWD+SAG - .~ .- - -- - - ..- .. ... - i~.oJ'-4. Sperry-Sun Drilling Services Alaska Cook Inlet Osprey, Slot Leg 3 - Slot 5 RU#5A Job No. AKMW22065, Surveyed: 28 September, 2002 Survey Report 14 October, 2002 Your Ref: API 507332051301 Surface Coordinates: 2449931.80 N, 200628.00 E (60041'43.6518" N, 151040' 14.4892" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 2550068.20~, 299372.00 W (Grid) Surface Coordinates relative to Structure: 1679.20 S, 2250983.00 W(Grid) Kelly Bushing: 90.00ft above Mean Sea Level Elevation relative to Project V Reference: 90.00ft Elevation relative to Structure: 90.00ft sper'r'y-sui1 bRILLING SERVices A Halliburton Company - - - - - RECEIVED Fl:B 0 J 2003 Alaska Oil & Gas Cons. Commission . Anchorage Survey Ref: svy91 Sperry-Sun Drilling Services Survey Report for Osprey - RU#5A Your Ref: API 507332051301 Job No. AKMW22065, Surveyed: 28 September, 2002 Cook Inlet Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 11384.39 29,190 137.710 9874.12 9964.12 3906.91 S 3451.54 E 2446024.89 N 204079.54 E 5212,53 Tie On Point 11473.00 28.860 138.110 9951.60 1 0041 .60 3938.81 S 3480.36 E 2445992.99 N 204108.36 E 0.432 5255.52 Window Point 11493.35 30.900 137.920 9969.25 1 0059.25 3946.35 S 3487.14 E 2445985.45 N 204115.14 E 10.035 5265,66 11580.33 36.790 137,080 1 0041.46 10131.46 3982.03 S 3519.87 E 2445949.77 N 204147.87 E 6.793 5314,08 11636,81 41.700 136.540 10085.18 10175.18 4008.07 S 3544.33 E 2445923.73 N 204172.33 E 8.714 5349.80 ~11683.68 41.700 136.420 10120.18 10210.18 4030.68 S 3565.80 E 2445901.12 N 204193.80 E 0.170 5380.97 '11744,39 42.510 138.540 10165.22 10255.22 4060.68 S 3593.30 E 2445871.12 N 204221.30 E 2.695 5421.67 11780.91 44.560 139.360 10191.70 10281.70 4079.65 S 3609.81 E 2445852.15 N 204237.81 E 5.822 5446.82 11872,10 47.920 139.570 10254.76 10344.76 4129.70 S 3652.61 E 2445802.10 N 204280.61 E 3,688 5512.64 11966.51 52.190 138.580 10315.36 10405.36 4184.36 S 3700.03 E 2445747.44 N 204328.03 E 4.594 5584.98 12014.39 54.520 137.630 10343,94 10433.94 4212.95 S 3725.68 E 2445718.85 N 204353.68 E 5.120 5623.39 12108.35 56.200 137.080 10397,34 10487.34 4269.81 S 3778.05 E 2445661.99 N 204406.05 E 1,852 5700.69 12174.70 57.320 137,310 10433,71 10523.71 4310,52 S 3815.76 E 2445621.28 N 204443.76 E 1.713 5756.18 12263.35 59.160 136.860 10480.37 10570.37 4365.72 S 3867.08 E 2445566.08 N 204495.08 E 2.120 5831,55 12358.22 60.310 136,650 10528,19 10618,19 4;425.41 S 3923.22 E 2445506.39 N 204551.22 E 1.227 5913.48 12451,78 62,100 135.800 10573.25 1 0663.25 4484.60 S 3979.95 E 2445447.20 N 204607.95 E 2.072 5995.44 12547.64 63.770 136.030 10616.87 10706.87 4545.92 S 4039.33 E 2445385.88 N 204667.33 E 1,755 6080.76 12643.58 65.580 135.720 10657.90 10747.90 4608.16 S 4099.71 E 2445323.64 N 204727.71 E 1.909 6167.43 12735,35 66.770 136.250 10694.97 10784.97 4668.54 S 4158.04 E 2445263.26 N 204786.04 E 1 .400 6251.35 12826.91 67.330 136.970 10730.67 10820.67 4729.81 S 4215.95 E 2445201.99 N 204843.95 E 0.948 6335.64 12924.35 64.850 138,000 10770.16 10860.16 4795.45 S 4276.15 E 2445136.35 N 204904.15 E 2.722 6424.71 13015.96 62.620 138.950 10810.70 10900.70 4856.95 S 4330.61 E 2445074.85 N 204958.61 E 2.606 6506,85 13109.55 62.690 138.650 10853.69 10943.69 4919.50 S 4385.37 E 2445012.30 N 205013.37 E 0.294 6589.96 .,-~ 3205.44 62.360 138.050 10897.93 10987.93 4983.07 S 4441.91 E 2444948.73 N 205069.91 E 0.653 6675.03 3299.82 61.380 136.520 10942.43 11032.43 5044.22 S 4498.36 E 2444887.58 N 205126.36 E 1.767 6758,26 1 ~392.42 62.190 134.740 10986.21 11076,21 5102.54 8 4555.42 E 2444829.26 N 205183.42 E 1,906 6839.80 13485.24 63.600 134.410 11028.50 11118.50 5160.538 4614.28 E 2444771.27 N 205242.28 E 1.552 6922.30 13579,70 63.840 133.060 11070.33 11160.33 5219.088 4675.48 E 2444712.72 N 205303.48 E 1.306 7006.80 13671.92 65.940 133.460 11109.46 11199.46 5276.31 8 4736.28 E 2444655.49 N 205364.28 E 2,311 7090.05 13733,74 64.990 133.770 11135,13 11225.13 5315.108 4777.00 E 2444616.70 N 205405.00 E 1.603 7146.15 1 ~\771.97 63.800 134,520 11151.65 11241,65 5339.11 8 4801.74 E 2444592.69 N 205429.74 E 3,580 7180.56 13870.45 63.170 134.580 11195.62 11285.62 5400.93 8 4864.54 E 2444530.87 N 205492.54 E 0,642 7268,55 1~3967,04 63.040 135.110 11239,31 11329.31 5461,68 S 4925.61 E 2444470.12 N 205553.61 E 0.508 7354,59 14063.38 64.090 136.190 11282.20 11372.20 5523.36 8 4985.91 E 2444408.44 N 205613.91 E 1.482 7440.80 14156.68 64.140 135.700 11322.93 11412.93 5583.69 8 5044.28 E 2444348.11 N 205672.28 E 0.476 7524.71 -_._---' --- 14 October, 2002. 14:20 Page 2 of 4 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Osprey - RU#5A Your Ref: AP/507332051301 Job No. AKMW22065, Surveyed: 28 September, 2002 Cook Inlet Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 14253.40 64.090 136,340 11365.16 11455.16 5646.30 S 5104.70 E 2444285.50 N 205732.70 E 0.598 7611.69 14347.74 64.920 136.430 11405,76 11495.76 5707.95 S 5163.44 E 2444223.85 N 205791.44 E 0,884 7696,82 14446.46 63.700 136.810 11448.56 11538.56 5772.61 S 5224.54 E 2444159.19 N 205852.54 E 1.284 7785.76 14541.00 62.080 136.880 11491.64 11581.64 5834.00 S 5282.10 E 2444097.80 N 205910.10 E 1.715 7869,91 14638.20 60,680 136.710 11538.20 11628.20 5896.19 S 5340.51 E 2444035.61 N 205968.51 E 1 .448 7955.22 14732.75 58,970 135.730 11585,72 11675.72 5955.21 S 5397.06 E 2443976.59 N 206025.06 E 2.018 8036.93 /~14823.42 57.880 134.380 11633.20 11723.20 6009.88 S 5451.62 E 2443921.92 N 206079.62 E 1.748 8114.09 14919.38 58.740 134.300 11683.61 11773,61 6066.95 S 5510.02 E 2443864.85 N 206138.02 E 0.899 8195.61 15012.96 59.900 134.170 11731.35 11821.35 6123.09 S 5567.68 E 2443808.71 N 206195.68 E 1.245 8275.94 15105.91 59.480 133.140 11778.26 11868.26 6178.49 S 5625.74 E 2443753.31 N 206253.74 E 1,058 8355.99 15202.89 59.610 133.880 11827.42 11917.42 6236.04 S 5686.37 E 2443695.76 N 206314.37 E 0.671 8439,37 15295.24 57.320 131.880 11875.72 11965.72 6289.61 S 5744.03 E 2443642.19 N 206372.03 E 3.091 8517.80 15346.70 ;>7.640 130.760 11903.39 11993.39 6318.26 S 5776.61 E 2443613.54 N 206404.61 E 1,938 8560.93 15442.29 59.190 128.680 11953.46 12043.46 6370.28 S 5839.25 E 2443561.52 N 206467.25 E 2.463 8641.57 15545.27 58.970 129.080 12006,37 12096.37 6425.73 S 5908.02 E 2443506.07 N 206536.02 E 0.396 8728,88 15637.42 55.200 130.190 12056.44 12146.44 6475.05 S 5967.60 E 2443456.75 N 206595.60 E 4.214 8805.46 15722,77 54,890 133.900 12105.35 12195.35 6521.88 S 6019.53 E 2443409.92 N 206647.53 E 3.581 8875.06 15840,72 52.980 128.180 12174.82 12264.82 6584.48 S 6091.35 E 2443347.32 N 206719.35 E 4.240 8969.71 15935.10 55.990 127.060 12229.64 12319.64 6631.36 S 6152.20 E 2443300.44 N 206780.20 E 3.332 9045.34 16027.82 57.550 133.640 12280.49 12370.49 6681,56 S 6211.23 E 2443250.24 N 206839.23 E 6.169 9122,21 16150.01 60.360 143.510 12343.61 12433.61 6759.99 S 6280.26 E 2443171.81 N 206908.26 E 7.289 9226,67 16216.47 60.220 143.100 12376.55 12466.55 6806.27 S 6314.75 E 2443125.53 N 206942.75 E 0.576 9284.11 16307,00 60.100 140.150 12421.61 12511.61 6867.83 S 6363.49 E 2443063.97 N 206991.49 E 2.830 9362.44 16383.00 61.410 143.810 12458,74 12548.74 6920.06 S 6404.31 E 2443011.74 N 207032.31 E 4,541 9428.54 ~?409.62 61.610 143.000 12471.44 12561.44 6938.84 S 6418.26 E 2442992.96 N 207046.26 E 2.778 9451,82 16501,12 61,320 140.290 12515,16 12605.16 7001.87 S 6468.14 E 2442929.93 N 207096.14 E 2,621 9532.00 1 q594, 78 61.300 139.120 12560.12 12650.12 7064.54 S 6521 .27 E 2442867.26 N 207149.27 E 1,096 9614.11 16690.66 62.260 136.790 12605.46 12695.46 7127.27 S 6577.85 E 2442804.53 N 207205.85 E 2.364 9698,58 16784.30 63.310 135.460 12648,29 12738.29 7187.29 S 6635.57 E 2442744.51 N 207263.57 E 1,689 9781.82 16875.22 63.810 133.060 12688.78 12778.78 7244.10 S 6693.87 E 2442687.70 N 207321.87 E 2.427 9863,08 16941.37 65.290 132.390 12717.20 12807.20 72\34.62 S 6737.75 E 2442647.18 N 207365.75 E 2.417 9922.58 17'000,00 65.290 132.390 1 2741 ,71 12831.71 73;20.53 S 6777.08 E 2442611.27 N 207405.08 E 0.000 9975.62 Projected Survey 14 October, 2002 - 14:20 --- _. .._-- Page 3 0(4 DrillQlIest 3.03.02.002 Alaska Sperry-Sun Drilling Services Survey Report for Osprey - RU#5A Your Ref: API 507332051301 Job No. AKMW22065, Surveyed: 28 September, 2002 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to Grid North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 137.650° (Grid). Coordinate System is NAD27 Alaska State Planes, Zone 4. Grid Convergence at Surface is -1.457°. Magnetic Convergence at Surface is .22.009°(15-Apr-02) ~d upon Minimum Curvature type calculations, at a Measured Depth of 17000.00ft., Bottom Hole Displacement is 9975.92ft., in the Direction of 137.208° (Grid). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11384.39 11473.00 17000.00 9964.12 1 0041 .60 12831.71 3906.91 S 3938.81 S 7320.53 S 3451.54 E 3480.36 E 6777.08 E Tie On Point Window Point Projected Survey Survey tool program for RU#5A ~. From . \1easured Vertical Depth Depth (ft) (ft) 0.00 384.00 0,00 383.73 14 October, 2002 - 14:20 To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 384.00 17000.00 383.73 Tolerable Gyro(RU#5 Gyro) 12831.71 MWD Magnetic(RU#5) Page 4 0'4 . ..'.'-.' Cook Inlet Dri/lQuest 3.03.02.002 ) ) ~ FOREST OIL CORPORATION ,g 1 0 c£7{951/}cee(: - g9;ufe 700 OS¥nclw~~~ oS¥kI/.JIC4 .9.9;SOI (907) 2Ô'8-86'OO . (907) 258-86'01 (cff0X) December 2, 2002 Cammy Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK, 99501 Re: Redoubt Unit (RU) #5A well, annular disposal Dear Ms. Taylor, Forest Oil Corporation requests that the Application for Sundry Approvals concerning the annular disposal into Redoubt Unit #5A be canceled. The casing design of the well will not allow us to dispose into the annulus and produce concurrently. This is due to the collapse rating of the 9 5/8" intérmediate casing. Production will commence in the next couple weeks, thus eliminating the well's potential use for disposal. Please call me at 258-8600 if you or your staff have any further questions. ~~ Paul D. White Drilling Manager - Alaska Division Forest Oil Corporation RECEIVED DEC 0 22002 Alaska OU& Gas Cons. Commission Anchorage '~ DATE, TIME FAX NO./NAME DURATION PAGE(S) RESULT MODE ) JOB STATUS REPORT 11/15 17:41 2588601 00:00:33 03 OK STANDARD ECM ) TIME: 11/15/2002 17:41 NAME : AOGCC FAX# : 9072767542 TEL# : SER.# : BR02J2502370 ') ) ALA S K A 0 I L & GA sea N S E R V A T ION C OM MIS S ION FAX 907-276-7542 PHONE 907-279-1433 FACSIMILE TRANSMITTAL SHEET TO: \J<A\..J \ W ~\ \- ~ COMPANY: ~\~~\- FROM: \()""- ~~~~(\. \jo~ \ ç l è)OD~ DATE: FAX NUMBER: Ç)S-~-~t:oO\ TOTALNO. OF PAGES INCLUDING COVER: '3 PHONE NUMBER: SENDER'S REFERENCE NUMBER: RE: Q'-.J 5" ~ k. .' YOUR REFERENCE NUMBER: A"",~\<.>, ~~F6. \ 0 URGENT 0 FOR REVIEW 0 PLEASE COMMENT 0 PLEASE REPLY 0 PLEASE RECYCLE NOTES/COMMENTS: AOGCC 333 WEST 7TH AVENUE, SUITE 100 ANCHORAGE, AK 99501-3935 4t ) ~1JfÆu (ill TONY KNOWLES, GOVERNOR A.I1A.~KA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 15,2002 Paul D. White Drilling, Manager Forest Oil Corporation 310 K Street, Suite 700 Anchorage Alaska 99501 Dear Mr. White, On August 29, 2002 Forest Oil Corporation ("Forest") filed an Application for Sundry Approval to conduct annular disposal operations in the Redoubt Unit #5A ("RU #5A") well on the Osprey Platform in the Redoubt Shoal Unit. Additional information consisting of an injectivity test on the subject annulus was submitted on September 16, 2002. The Commission is requesting additional information from Forest before it can fully consider the Sundry application. First, the Application for Sundry Approval and supporting information is very similar to the Applications for Sundry Approval for annular disposal operations in the RU #1 and RU #2 wells. In both those operations, drilling waste returned to surface. Please explain why Forest believes that the proposed annular disposal operations in RU #5A will result any differently than in the RU #1 or RU #2. Please also describe what is different about the RU #5A proposal that will insure that waste is adequately confined and will not return to surface. Any seismic data and interpretation Forest may have from the surface through the proposed disposal intervals might help illustrate confining intervals as well as any shallow faults that may provide waste escape pathways. Second, Forest proposes to conduct annular disposal into strata at a depth of 2939' TVD in the RU #5A well. Forest's application states: " The total dissolved solids (TDS) content of formation waters in the recently completed RU #1 well generally ranges between 3,000 mg/I and 10,000 mg/l from about 1832 feet to about 2450 feet TVD. Below 2450 feet TVD, the TDS content increases to above 10,000 mg/I...." ---'- ) ') Paul D. White November 15,2002 Page 2 of2 However, in the record of Aquifer Exemption Order No.7 ("AEO-7"), Forest submitted a log (plotted on July 26, 2001) that contains a TDS curve that indicates strata shallower than 3749' MD in, the class II disposal well (RU #D 1) contain freshwater with TDS less than 3000 mg/I. Please explain the apparent contradiction between these interpretations. We apologize for the delay in getting this application processed. As soon as the Commission receives Forest's additional information, it will proceed to expedite the decision on the application. . Sincerely, ~2~ Thomas E. Maunder, PE ? Sr. Petroleum Engineer TEM\jjc ) NOTE TO FILE RU 5A...202-168...302-2077 Request for Annular Disposal Approval Forest has requested approval for annular disposal on the subject well. This document analyzes the information and makes a recommendation regarding their requést. RU SA is an exploration/development well drilled from the Osprey Platform in Cook Inlet. Forest has identified 5 wells within the Y4 mite radius of the 9-5/8" shoe of RU #5. The closest well is RU #2 calculated to be 363 feet distant. RU #2 was permitted for annular disposal. While disposing into RU #2, subsurface communication developed with RU #1 which was calculated to be about 350 feet away from RU #1. In addition some oily returns were noted dripping from the 36" pile x 13-3/8" surfacè casing annulus of RU#2 on the platform on July 3, 2001. This was reported to the commission. The supplied cementing and LOT information looks very good. Their summary notes that the pipe was reciprocated. The pipe was cemented with a 2-stage job. Both the original LOT and the subsequent pump in test exhibit smooth pressure increases to breakover. The original LOT indicates that the formation broke at 14.8 EMW and showéd stabilized pump in at about 14.1 EMW. On the pump in test, the break occurred at 13.6 EMW and stabilized pump in was at 13.2 EMW. These pressure plots are much better developed than those of RU #2. RU #2's initialleakoff was estimated to between 13.6 to 13.8, these values are more similar to the pump in test values of RU #5A. The original lOT value for RU #5 is approximately 1 ppg greater. The provided pressure information indicates that the 13-3/8" casing should be well cemented. Forest provides information regarding the salinity of formation waters that the well may penetrate. They indicate that it is unlikely that any fresh waters exist below the casing point, however they do request permission to dispose of the wastes into the formations below the shoe and ask the Commission to allow this since it is not likely that any waters encountered would be used to supply a public water system because of depth and location. In conversations with Forest, Paul White has indicated they desire to have this annulus available to primarily accept camp domestic waste (if they can't discharge) and as a back up in case a problem develops with their disposal well. They also include produced water as a potential disposal fluid. I do not believe that produced water is covered in 20 MC 25.080 (h) (1) and a determination according to (h) (2) may need to be made. As noted, the annulus is desired as a back up for the disposal well. According to the annual report Forest submitted at the end of June, operations are proceeding well with the disposal well. I am not aware of the disposal welt developing any problems since. Forest also requests that a determination made for RU #2 to allow disposal bottom hole pressures up to 18.3 EMW be applied for RU #5A. The 18.3 ppg determination was based on a temperature log provided by Forest that indicated the waste was accepted by a formation in the open hole some distance from the shoe. It is probable that the situation could be the same in RU #5A, however I believe that Forest should perform an injectivity test to develop similar information to that from RU #2. ~- ') Based on the information supplied, I believe that Forest Oil Corporation has complied with the well construction criteria of 20 MC 25.080. If it is necessary to exceed a bottom hole EMW of 14.8 ppg, Forest should conduct an injectivity test followed by a temperature log to develop additional confinement information as provided by 20 MC 25.080(b) (16). Forest should be allowed to pérförm this test in advance if desired. Any annular disposal should be closely monitored with Forest recording the pressure and rate information so plots of each injection batch can be prepared. Tom Maunder, PE Sr. Petroleum Engineer RU #5A Annulus Injectivity Test ) Subject: RU #SA Annulus Injectivity Test Date: Mon, 16 Sep 2002 11 :58:29 -0600 From: Rob Stinson <RDStinson@forestoit.com> To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> CC: Paul White <PDWhite@forestoil.com> Tom, I am attaching the graph of the inJectivitytest performed this weekend on the Redoubt Unit #5A annulus. I believe this satisfies all of your requests for additional information. Based on the behavior of the injectivity test and the original Leak Off Test we are satisfied that we have a sound annulus, mechanically and geologically. If you have any further questions, please contact me or Paul White. Thanks, Rob «RU5ANNULUSTEST91502.xls» Robert Stinson Drilling Engineer.. Alaska Division Forest Oil Corporation (907)-868-2133 ) I", ,,11 Nam~: RU5ANNULUSTEST91502.xts I ~RU5ANNULUSTEST91502.XI~ Type: Microsoft Excel Worksheet (application/vnd.ms-excel) . Encoding: base64 1 of 1 10/4/2002 2: 11 PM Sperry-Sun Drilling Services Horizontal Distance Proximity Scan on Current Survey Data (Highside Reference) Reference Survey: Osprey - Plan: Redoubt Unit #5 - Rig RU#5 MWD Single Point Scan at 3190.00ft. Measured Depth. Scan Radius is Unlimited. . Measured Depth (ft) Comparison Vertical Depth (ft) Cook Inlet Osprey Comparison Well Name - Profile Name R ~..\\-5 Reference Well Measured Vertical Depth Depth (ft) (ft) Proximity Relative Relative Distance HighSide (ft) Direction Alaska 3190.00 3190.00 3190.00 3190.00 3190.00 2939.53 \ Osprey Plan: RU-D1 - RU D1 Teledrift RU#1 - RU#1 RU#2 - RU#2 RU#3 - RU#3 RU#4 - RU#4 PB1 3184.04 3246.33 3391.33 ');558.95 2939.76 2939.76 2939.76 2939.76 N 238.06 S 606.39 S 1182.06 S 327.93 S 4.61 W 1031.60 -165.335 ~ 930.52 E 694.48 -100.541 855.47 E 363.40 -83.661 769.45 E 402.64 19.719 1566.75 E 1116.44 -73.983 All station coordinates were calculated using the Minimum Curvature metho . All data is in feet (us) unless otherwise stated. Directions and coordinates are relative Vertical depths are relative to Well. Northings and Eastings are relative to Well. Coordinate System is NAD27 Alaska State Planes, ZOQ~.4 Foot. Grì(J'Convergence at Surface is -1.45r. ~ -_._------------~--- --~---- -~._~ 30 August, 2002 - 9:49 Page 2 of 2 DrillQuest 2.00.09.006 .......,."./ Alaska Cook Inlet Plan: Redoubt UIIÎt #5 - Rig RU#5 MWD :AIITICOLLISION REPORT 30 August, 2002 Horizontal Distance Proximity Scan on Current Survey Data - Highside Reference Reference Survey: Plan: Redoubt Unit #5 - Rig RU#5 MWD Single Point Scan at 3190.00ft. Measured Depth. Scan Radius is Unlimited. ~., SpE!r"r"Y-SUI! çH'Jl~L I ~t~.,. ]1]5l=t~J C:;J5!? A Halliburton Company RU#5A Annular Dispo$al Request ) ) Subject: RU#5A Annular Disposal Request Date: Thu, 29 Aug 2002 13:07:15 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Paul White <pdwhite@forestoil.com>, Rob Stinson <RDStinson@forestoil.com> Paul and Rob, I have received your latest request for annular disposal on RU#5A. On initial examination, it appears that no new information has been added. You have included the initial LOT information conducted when the 13-3/8" shoe was cemented, however information on the "pump in" test conducted into the 13-3/8" x 9-518" annulus was not included. We cannot consider this application without that information. Tom Maunder Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engiheer ] Alaska Oil and Gas Conservation Commission 'Qo\c Co. \\t':~ ~ \ '?::, \ S- . T,^,~ ~~\ ~\J~Q ~(è " ~'-~\t-.V\ ("\,." ~\- -v-) Q.. \(!:- ~ ~ '\ ~ ~ -\0 ~~ '" ~ S"''O,,-\ \'{. '''''<è'f ~'I\...~() +-c ~<t ~vY6 W <L \UL<L ~ +~ 't w~-"fs 80 '\ ~ \ . Þs-\sa ~SC'.J~S~ 'f\.~<L~ ~rS)~~~G \"-~\'\Iv\O..~ ~ ~ o~~b~" 1 of 1 8/29/20022:02 PM Re: FW: Relative Distances ) Subject: Re: FW: Relative Distances Date: Thu, 29 Aug 2002 14:31 :08 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Rob Stinson <RDStinson@forestoil.com> Than ks Rob... Do you have the distances for all the wells?? Rob Stinson wrote: > Tom, > > Here is the offset information. You mentioned RU #1, however RU #2 and > RU #3 are the closest to the RU #5 surface casing shoe. > > Rob > > > -----Original Message----- > > From: Rob Stinson > > Sent: Friday, April 12, 2002 3:23 PM > > To: Paul White > > Subject: Relative Distances » > > Peach ran the offset info. At the 13 318" shoe of RU #5 these are the > > offsets: » > > RU #2 is 334' away at a Toolface of 78 degrees left > > RU #3 is 473' away at a Toolface of 19 degrees right » » > > Rob Stinson > > Drilling Engineer - Alaska Division > > Forest Oil Corporation > > (907)-868-2133 » ') r,,-.w..^~~--,---^---,_w_---'W'--""W'~'~W^,'_,"^WN_"--..~._.,'_,^_N._~^,~_,~_w._.~.._..v__."-,_'__,"N__W~__'_---_.~_____m,'~'__w~ Tom Maunder <tom_maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 8/29/2002 3: 18 PM c?// I ..L., 6-7- .--"'--""-' - ~~"'''.'~- ,---.- - r:: r ." ';:>'0""" ..7' {.. ;¡"'" @ ) ',.....,,_'"" / --'-""_--"'-~."'-"" ---_.,,~_._.__._~,--- .. ¡:.':)/~ --....,.".--.----! ......... '- I ¡ \ ' I . - I ~ ~~~ ~~~ ï:¡:i: -L/ì/-:!" ~ - o,)- 001./1 I 000 ~ I '" CII CII . ~~:c ~~~ CII(fI~ ) I.I'HfHI) ......... I.LiWW WWW ::J::::C::J: II)VIIIJ) 000 11\00 -('4 ...C"1~ 1IIt"4'''=t .-........ tÑ~N C"4C'4N @ ( ¡;C( S !~ / ./ ~; U ¡" j '~¿:-c:.. 2- Lly 9 .~~ d( J 2~::;)c:; 1-11) :2 ( / ! TU-D /- i:::: 2 U L.) 0 /'\ /r"" ,/ / (l.-J b - ~-3 .,~ 0 ç S77 ¿o/( ,.I k/~ Phff;~ . - ¡¡¡I rt:/$dJ.~~/I Je's~~ k,- / c¡ )( -' G 2d&-~J toV~ " ¡; Á¡&~ M if ~ ,,~k q('r;l...J ;~,~IVØ- l' I~~ J!¡¡;~:;~-,¡~) ~4;:7/~ Cd ðJ:- ~ J ò9'/~- '~ ¿Jp'/J ~ Ii KM:G ~~,J "'/<>/0 ~//J,¡/~, . ) / '~ ~o~1 -AI:- s::i~c-- //=¡/~ç ¡--r~1 .;¿¡ en:;) ~ ç; ( UHf) U) ............ www WWW :z::x::x: U)U)U) 000 11)00 -('4 -C"4~ ~~~ ... ... ... ~~c:. C"IIC"4C"4 @ {, ,ø I' ¡J ¡J; I\t¡ , 2- £'v 1" /3 ( 1(4 1J- v if" c.,., ("1'c<c-, e. /- /j /"1 P ./ I VI- ,.~. ì (:.., /' 'c.., ~ / q A--' 0 ~,çJ :.J ;{r' C, c;.~ /3 0' (-'°, \/;"\.' 0. /'2 < ~ '-'"' II 1,.0' r 5- :; ;') f 1í1!J (jJ; I~ 3/ r- ~Gr ¡: ~ "---... ,7205 () I""'~ '(¡ ~; i:9 3/ 10 !1(J "') Q:? 0,7 ¡ !/D --"-, (J l i' ~" 1')'- './\. ...; 200£ -12- ç;; £ - /"' ..., [ () b ...L. ,,) õ ~ 57/ -r¿/¿;; /fQs i /L/ E 7C¡'a ) ') ~ FOREST 0 I L CORPORATION .; 1 0 dY{cJl1~Æ[. Q9;~¿te 700 QS2I~~J Q9Úaab .9.9501 (.907) 2.5'8-86'00 . (907) 2.58-86'01 (~,~) August 29, 2002 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, AK, 99501 Attention: Commissioner Cammy Taylor Re: Redoubt Unit (RU) #5A well, annular disposal Dear Commissioner Taylor: I Forest Oil Corporation requests approval under 20 AAC 25.080 for the ann~lar disposal of drilling waste in the RU #5A well. Enclosed is an Application for Sundry Approvals (Form 10-403) with supporting information as required by regulation. The TDS profile from the RU #1 well indicates that salinity below the proposed setting depth of the RU #5A surface casing shoe (2939 feet TVD) is generally above 10,000 mg/I, although it occasionally drops below this threshold in some intervals. Forest Oil believes the lower salinity readings are the result of lithology changes and clay content, and not an indication of freshwater. Although freshwater is not likely below 2939 feet TVD in the RU #5A well, Forest Oil requests that the commission issue a finding under 20 AAC 25.080(e)(1) that any freshwater encountered below this depth is likely to have a TDS content greater than 3,000 mg/I, and it is not reasonably expected to supply a public water system because of its location, depth and the abundant availability of water elsewhere in the region. Please call me if you or your staff have any questions about this request or require additional information. Forest Oil will be pleased to meet with you or answer any questions you or your staff may have. Thank You. Q~~ Paul D. White Drilling Manager - Alaska Division Forest Oil Corporation Attachments: 10-403 Application for Sundry Approvals 20 AAC 25.080 Specifics RU #5A Casing Schematic 13 3/8" Surface Casing Cement Job Summary 133/8" Casing Test Graph & LOT Graph L .) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Alter casing: - Change approved program: Suspend: - Repair well: Pull tubing: Operation shutdown: - Re-enter suspended well: - Plugging: - Time extension: Stimulate: Variance: Perforate: Other: nnular Disposal 5. Type of well: 6. Datum elevation (DF or B) Development: - 90' MSL Exploratory: X 7. Unit or Property n e Stratigraphic: Redoubt Sho nit Service: 2. Name of Operator Forest Oil Corporation 3. Address 310 K Street, Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 1909' FSL, 318' FEL, Sec. 14, T07N, R14W, SM At top of productive interval 972' FSL, 231' FWL, Sec. 19, T07N, R13W, SM At effective depth measured 8. Well num r Redo Unit #5A 9. Per' number 2 -168 10 PI number 50-733-20513-01 11. Field/Pool Redoubt Shoal Field At total depth 147' FNL, 1320' FWL, Sec. 30, T07N, R13W, SM 12. Present well condition summary Total depth: measured true vertical 13,835' 11,268' Plugs (measured) Effective depth: measured true vertical 13,835' 11 ,268' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length N/A 200' 3,132' 11 ,500' Size N/A 30" Measured depth N/A 200' 3,190' 11 ,500' True vertical depth N/A 200' 2,939' 10,060' (Liner) true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachements X Detailed operations program: BOP sketch: 14. Estimated date for commencing operatio 01-Sep-02 16. If proposal well verbally approved: 15. Status of well classification as: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby ce~fy,at the foreg~' g is true and correct to the best of my knowledge. Signed: ,,~~ Title: Drilling Manager, Forest Oil Corporation / FOR COMMISSION USE ONLY Conditions of approval: NotWY Commission so representative may witness Plug integri - BOP Test- Location clearance- Mechanic Integrity Test- Subsequent form required 10- Date: '8 J.. 9/02- Approval No. 2 3D -2-'77 ~¿?~ Commissioner Date ::L/Yo 5' Form 10-403 Rev 06/15/88 R B D 1-1 5 8 F L SUBMIT IN TRIPLICATE ÆB I 'L 2003 FOREST OIL CORPORATION OSPREY PLATFORM REDOUBT UNIT #5A (RU #5A) 20 AAC 25.080(b)(1)-Annulus to be used for disposal Forest Oil Corporation proposes to dispose of drilling waste through the 13 3/8 inch by 9 5/8 inch annulus in the RU #5A well. The setting depth of the 13 3/8 inch surface casing is 2939 feet TVD (3190' MD) and the window in the 95/8 inch casing is at 10,060 feet TVD (11,500 feet MD). A well casing diagram is attached. 20 AAC 25.080(b)(2)-Depth to base of freshwater aquifers and permafrost, ifpresent The total dissolved solids (TDS) content of formation waters in the recently completed RU #1 well generally ranges between 3,000 mg/l and 10,000 mg/1 from about 1832 feet (where logging began) to about 2450 feet TVD. Below 2450 feet TVD, the TDS content increases to above 10,000 mg/l, but occasionally drops below 10,000 mg/l through some intervals. Forest Oil believes the lower salinity readings are due to lithology changes and clay content, and does not necessarily indicate freshwater. The TDS content in the RU #1 well generally dovetails with the Redoubt Shoal State 29690 #1 well, where salinity exceeds 10,000 mg/l below 2400 feet TVD. The TDS profile in both wells is based upon petrophysical analysis of log data using an EP A approved method for determining salinity. The RU # 1 well logs are included with this application; the Redoubt Shoal State 29690 # 1 is on file with the commission. At the top of the disposal zone, the RU #5A. well is near the RU #1 well and within one- quarter mile of the Redoubt Shoal State 29690 # 1. Accordingly, the salinity profile for the RU #5A well should correlate well with both the RU # 1 and the Redoubt Shoal State 29690 # 1 wells. Although it is unlikely that freshwater will be encountered below the setting depth of the surface casing shoe at 2939 feet TVD, Forest Oil requests commission authorization under 20 AAC 25.080(e)(I) ,to dispose of drilling wastes into any freshwater that may exist in the RU #5A well below this depth. Formation water in the RU #5A well is not likely to supply a public water system because of its location and depth, and the abundant availability of water elsewhere in the region. There is no permafrost in the area. 20 AAC 25. 080(b )(3 )-Stratigraphic Description The interval proposed for annular disposal in the RU #5A well is between 2939 feet and 10060 feet TVD, and corresponds to the Upper Tyonek Formation in this area. The Upper Tyonek is fluvial in nature and, at the well location, consists primarily of anastomozing stream channels, producing blanket-like sand intervals that are continuous both horizontally and vertically. Interbedded with the Tyonek sands are numerous layers of impermeable tuffaceous siltstones, carbonaceous shale and coal. Porosity and permeability are good within the Tyonek sands. The sands are very friable and generally medium grained, well-rounded and well-sorted. Porosities range from 20 % to ) ) 30 %. These sands should readily accept fluids proposed for annular disposal in the RU #5A well. Overlying the Tyonek Formation is approximately 1600 feet to 1800 feet of Beluga Formation. The Beluga Formation is also fluvial, but stream channels are less numerous and more isolated by siltstone, clay and coal deposits and than in the Tyonek. Based upon the mud log from the Redoubt Shoal State 29690 #1 well, at least 440 feet of clay and 170 feet of siltstone within the Beluga section (between 700 feet and 1800 feet) overlies the disposal zone. Combined with the siltsones, shales and coals within the Tyonek Formation, these impermeable layers provide significant and numerous barriers to upward migration of any fluids disposed through the RU #5A annulus, and should provide adequate protection for any freshwater resource that may exist above the disposal zone. 20 AAC 25.080(b)(4)-Adjacent wells Wells within one-quarter mile of the RU #5A -13 3/8" casing shoe include: Redoubt Shoal State 29690 # 1 and #2 wells Redoubt Unit #1, #2, #3, #4 and #Dl wells There are no publicly recorded water wells within one mile of the RU #5A well. 20 AAC 25.080(b)(5)-Types and volume of waste Drilling waste proposed for annular disposal in the RU #5A well will be limited to that allowed under 20 AAC 25.080(h)(l) & (2). Forest Oil estimates that no more than 10,000 barrels of drilling waste, with an average density of 10'ppg to 11 ppg, from drilling the RU #5A well will be disposed through the annulus. The bulk of waste material will be a waste slurry, composed of drilling muds and cuttings with additives and water. Forest Oil has installed grind and inject equipment on the Osprey Platform to process drill cuttings for disposal. Some rig wash, deck drain storm water, domestic waste and produced waters will also be disposed. Forest Oil also requests approval to use the RU #5A well annulus to dispose of drilling waste from other wells on the platform, and is aware of the 35,000 bbl and one year disposal restriction under 20 AAC 25.080(d). 20 AAC 25.080(1)(6)-Other wastes No waste other than wastes defined under 20 AAC 25.080(h)(l) & (2) are proposed for disposal. 20 AAC 25.080(b)(7)-Anticipated pressure The maximum anticipated pressure at the outer casing shoe during disposal operations should be approximately 2797 psi. This is based upon an equivalent mud weight of 18.3 ppg. Injection pressures necessary to dispose of whole mud in the RU #1 and RU #2 annuli were in this range. AOGCC has agreed to a maximum equivalent mud weight on RU #2 of 18.3 ppg, as per the e-mail from Tom Maunder dated April 5, 2001. ) 20 AAC 25.080(b)(8)-Cementing details Cementing records and the results of the formation integrity test on the surface casing are attached. An over plot of the casing test on top of the LOT shows that the pressure build up meets the criteria shown on the AOGCC Guidelines of 11/14/96. Forest Oil has taken special precautions to ensure a good cement job with the RU #5 well. The size of the surface hole was increased to 18 1/2 inches and centralizers were used on the 13 3/8 inch surface casing. The casing has been cemented in place in two stages using a cement stage collar. The setting depth of the RU #5A surface casing may be above the base of freshwater, as defined under commission regulations. Although TDS content in the RU # 1 well generally exceeds 10,000 mg/l below 2900 feet TVD, it occasionally drops below this threshold in some intervals. As stated above, Forest Oil believes the lower salinity readings are the result of lithology changes and,clay content, and not an indication of freshwater. Although freshwater is not likely below 2939 feet TVD in the RU #5A well, Forest Oil requests that the commission issue a fmding under 20 AAC 5.080(e)(1) that any freshwater encountered below this depth is likely to have a TDS content greater 3,000 mgll, and it is not reasonably expected to supply a public water system because of its location, depth and the abundant availability of water elsewhere in the region. The casing was reciprocated during displacement of the first stage to ensure optimum cementing. 20 AAC 25.080(1)(9)-Casing strength Casing Joint Strength Klbs. 1545 1122 Body Strength Klbs. 1556 1086 Burst Psi 5050 6870 Collapse Psi 2260 4760 13 3/8" 68# L-80 BTC 9 5/8' 47# L-80 BTC 20 AAC 25.08(b)(10)-Downhole pressure The downhole pressure obtained during the leak off test as shown on the attached graph is 2267 psi. 20 AAC 25.080(b)(11)-Hydrocarbon zones No significant hydrocarbon zones are anticipated above the window in the 9 5/8 inch casing at 10,060 feet TVD. 20 AAC 25.0800(12)-Duration Disposal of drilling wastes generated from the drilling of the RU #5A well will exceed 90 days in duration. Forest Oil will likely use the RU #5A well annulus for disposal of drilling wastes from other wells on the Osprey platform, but does anticipate the possibility of exceeding the 35,000 barrel and one year disposal limitations under 20 AAC 25.080(d). A waiver will be requested prior to these needs. 20 AAC 25.080(b)(13)-Prior disposal ) ) The RU #5A well is the sixth well to be drilled on the Osprey platform. Upon approval of this application, the well will be used for annular disposal for the first time. 20 AAC 25.080(b)(14)-N/A RU #5A will be used to dispose of drilling wastes generated during its drilling, as well as drilling wastes from other wells on the Osprey Platform. .) ) Redoubt Unit #5A Casing Plan 30" Conductor 133/8" 68#, L-80 BTC Surface Casing 18 1/2" Hole 75/8" 29.7# L-80 Liner @ 15,300' MD 11,920' TVD 8 1/2" Hole 5 1/2" 17# L-80 Liner set @ 17,118' MD 12,880' TVD - 63/4" Hole - 200' MD - 200' TVD 3,190' MD - 2,939' TVD KOP @ 11,500' MD, 10,060' TVD Baker WindowMaster Whipstock Assembly Baker Bridge Plug set at +/- 11,525' MD 95/8" 47#, L-80 BTC Intermediate Casing 12 1/4" Hole 13,760' MD - 11,927' TVD 8 1/2" hole 15,438' MD - 13,378' TVD ) Redoubt Unit #5 13 3/8" Surface Cement Job The 13 3/8" surface casing was run and cemented on April 21, 2002. The cement job chronology is as follows: 14:30 14:35 14:40 14:45 15:30 16:55 16:56 17:55 18:02 18:05 18:08 22:30 22:35 23:33 23:52 23:53 01:00 01:02 Pump 5 bbl of fresh water T est surface lines Pump 35 bbl of fresh water Pump 584 bbl of 12.5 ppg lead cement Pump 180 bbl of 15.8 ppg tail cement Drop plug on fly wI 5 bbl of cement on top Displace wI 459 bbl of water base mud. Cement returns to surface at 435 bbls of displacement. Reciprocate and land. Bump plug, hold for 2 minutes Bleed down and check floats - no backflow Pressure to 2,800 psi to open ES Cementer Circulate wI rig pump through ES Cementer Pump 5 bbl of fresh water Pump 440 bbl of 12.5 ppg lead cement Pump 95 bbl of 15.8 ppg tail cement Drop closing plug Displace plug wI 255 bbl of water base mud Bump plug wI 2,000 psi to close ES Cementer Bleed back and check ES Cementer - no backflow 900 800 700 600 500 400 300 .. 200 100 J<4 RU#5 LEAK OFF TEST AT 3240' MW 9.3 .. - - . . ,/u, 607 PSI @ 2:02 AM d~ ~<; C. .CJSJ) (.<;:~) ~ <iS~<O::' ~Ç)Cc '\ ?~\=- \ \.-\, % E k. ~ --\~~~ :: d\CD'dr>' ~ \~\~ \ ~\v\W '\ \ START @ 1 :34 AM @ 66.4 PSI END @ 2:04 AM 38 PSI +"- 0 11111111111111 rIll till r II 1 11111111111111 r IIIIIII111111111 11111111111111111111.1 IIII II 11111111111 IIIIIIII1 r I 1111111111111111111111111' 11111111111 11111111111111 r I IIII II !'"II!' r I!!!! !-ti-r] ~ ~ -- -- .. -- , .--- BLEED OFF ..\~ ~ - - - - - MAX PSI = 846 @ 1 :38 AM 741 PSI @ 1:49 AM ~ßfiA~ft~~~fift~ßfiA~fi~~~fi~~ßfiA~fi~~~~~~ t\. ~ 't\. r>}J't\. 'þv't\. 'þ \ 't\. 'þv't\. f>þ 't\. ~ 't\. ~ 't\. ~V't\. ~J't\. ~ 't\. ~J't\. ~v't\. ~ \ 't\. ~v't\. ~OJ't\.<t;>~'t\.<? 't\.<tþv't\.<t;>~'t\.~ 't\.<?J't\.<t;>v't\.~ \ 't\.~v't\.<t;>OJ'n'9~~'9~ ~.9ry,,'n'9~~.<f' ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~v~v~v~v~v TIME (10 SEC. AVE.) \~û...~ ~\-\ ~ e S"'CCL ,,~'~ \~ . - ~.-.r- ,,- ~ r-T'/ - . , - - PUMP 0.5 BPM ~/ I-PSI ~ OSPREY PLATFORM RU#5A ANNULUS TEST 13 3/8" X 9 5/8" 9/15/02 700 - 600 - 600 PSI . -\~ ---- - ------------- MAX 664 PSI 500 ..--------,.____n___. -~~~ ~,--- -~~~~-~,- - -- -_._-~ 400 . . . .. . .. .u- .n . --- -'- START @8:20 12 PSI ---- -- --------- ---------~---- --~---------------- ---- 10 MIN PUMP TIME AT .5 81M .. .. 300 .."---_. --'-"--'--_.~--~--' -~-~ -------- '-- ----'------.--. ::: 1-:--- ---------~=::~:-=-~:~--:_---- - ----- ~--_~TO~:~~~P-~~-:- END TEST AT 9:31 .5 BBLS/MIN ..... .... I I P I I I , I I I I I I I I I I I I I ' I I I I I I I ' I I I I I I I I I I I I I I ' : I I I I I I I I I I I I : I I . I I I ' I ' I I I I I I I I , I I I I I I I I I I I I I I I I I I I I I ¡ I I I I I I ' I I I I , I I I' I I I I 'I I r I I I I I I I I I I ! I I I I ' , I I I ! I I I I I ! I ! I I I I I I I I I I I I ~ I I I I I I I I I I 1 I I ~ I I . I ! I ~ ~ ! I I I I ! I ¡ I I I I I I I I I I I I I I I I I : I ! I I I , I ! I I ! I I I I I I : I I ' : : I I : : I I I I ] I I I I I I I ¡ I I I I I I I I .()() . ~<-;, .~() . ~<-;, .()() . ~<-;, .~() . ~ ,()() . ~<-;, .~() . ~ .()() . ~<-;, ,~() . ~<-;, .()() . ~<-;, .~() . ~ .()() . ~<-;, .~() . ~<-;, .()() . ~<-;, .~() . ~ .()() .~<-;, .~() . ~ . ()() ."v()' ."v"v' .rf' ."vCO' .~. .~~. .~~. .~~. .~'b' .~' .~. .~. .~. .~. ,<-;,~. .<o~. .<oCO' .<o'b' .()(). .()"v' ,()~. .~' .()OJ' .~~. .~~. .~(Q' .~'ò' ."v()' ."v~' .1>' .~. ."vOj' .~"v' ~.~.~.~.~.~.~.~.~.~.~.~.~.~.~.~.~.~.~.~.~.~'~.~.~.~.~.~.~.~.~.~.~. TIME (15 SEC. AVE.) ~~ ~.~ ~~ d~~" ~f~Sd') ,,~~) ~ Ç,~'~\ -=- dCJ1sS- z. \ ~~~ ~.\j.j ~ 'S ,,~'" P \)\1'1\ ~ " \1\ . t-... -..r- .-- -- L ¿~ \ ( ~ ~ =- ~7-\ - '~\d-b:~\I\J ,_/ '~ 3500 3000 2500 - ëñ .E: 2000 w ~ ;:) U) fß 1500 ~ Q. 1000 500 RU #5 13 3/8" CASING TEST 06/15/02 ... . SHUT IN AT 11:38 @ 3031 psi BLEED OFF AT 12:10 @ 2772 psi '~ 0 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I.I.I'.'I'~ I I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~#~~~~~~#~~~«~~~~~~~~#~~~~~ ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~v ~v ~v ~v ~v ~v ~v ~v ~v TIME (30 see avg) ~ ) FOREST OIL ) CORPORATION .oj 1 0 cfYC ç;fl¿~-eÆt. r;J7:u;te 700 QS;fncluJ~~ca!løy Qxtlaðk .9.9501 (.907) ,258-8600 . (907) 258-8601 (~x) August 13, 2002 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill (Form 10-401) Redoubt Unit #5A Enclosed is the Application for the Permit to Drill the Redoubt Unit #5A exploration well from Forest Oil's Osprey Platform. This well is a sidetrack of the existing Redoubt Unit #5. RU #5A will kick off at 11,500' MD and penetrate the Hemlock formation higher up on-structure in the Southern Fault Block. The two new hole sections will be drilled with Oil Based Mud. All mud and cuttings will be re-injected on the Osprey Platform. We have the grind and inject equipment on the platform to perform this task. If there are any questions, please contact me at 258-8600. Yà'\~~ Paul White Drilling Manager Forest Oil Corporation - Alaska Division A!asl<a OH & Anchorage 0, , "" I & '~,I f\ L ~ f\! J~~\ ) ) @ c9J TONY KNOWLES, GOVERNOR AT,ASIiA OIL AND GAS CONSERVAnONCO~SSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul White Drilling Manager Forest Oil Corporation 310 K Street Ste 700 Anchorage AK 99501 Re: Redoubt Unit #5A Forest Oil Corporation Pennit No: 202-168 Surface Location: 1909' FSL, 318' FEL, Sec. 14, T07N, R14W, SM Bottomhole Location: 147' FNL, 1320' FWL, Sec. 30, T07N, R13W, SM Dear Mr. White: Enclosed is the approved application for pennit to redrill the above development well. The pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. The pennit is approved subject to full compliance with 20 MC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Forest Oil assumes the liability of any protest to the spacing exception that may occur. Blowout prevention equipment (BOPE) must be tested in accordance with 20 MC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test perfonned before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Ú ~.~ ca::;techsli Taylor Chair BY ORDER OF THE COMMISSION DATED this.R::th day of August, 2002 cc: DepaFtment ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~9yLf Cþ{5 ) STATE OF ALASKA) ALASKA OIL AND GAS CONSERVATION CùMMISSION PERMIT TO DRILL 20 AAC 25.005 Red rill: X 1 b. Type of well Deepen: Service: 1 a. Type of work Drill: Re-Entry: 2. Name of Operator Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 1909' FSL, 318' FEL, Section 14, T07N R14W, SM At top of productive interval 972' FSL, 231' FWL, Section 19, T07N R13W, SM At total depth 147' FNL, 1320' FWL, Section 30, T07N R13W, SM 12. Distance to nearest 13. Distance to nearest well property line 3. Address 10,409 feet 1,807 feet (Redoubt Unit #3) 16. To be completed for deviated wells S T "f}.1t', I Kickoff depth: 200 feet /I,5C:D t.h:-, Maximum hole angle: 64 18. Casing program ,~ size Specifications Casing Weight Grade Coupling 75/8" 29.7# L-80 Hyd 521 5 1/2" 17# L-80 Hyd 521 Hole 81/2" 63/4" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical measured true vertical Effective depth: 15,438 feet 13,378 feet 13,659 feet 11,851 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 200' 30" 3,190' 13 3/8" 13,760' 95/8" Length 4,000' 2,018' Exploratory: x Developement Gas: 5. Datum Elevation (DF or KB) 90' MSL 6. Property Designation 381203 (Surface) 374002 (TD) 7. Unit or property Name Redoubt Unit 8. Well number Redoubt Unit #5A 9. Approximate spud date 13-Aug-02 14. Number of acres in property Development Oil: Multiple Zone: Stratigraphic Test: Single Zone: 10. Field and Pool Redoubt Shoal Oil Field 11. Type Bond (see 20 AAC 25.025) Type: Statewide Oil and Gas Bond RLBOO01940 Amount: $200,000 15. Proposed depth (MD and TVD) 23,526 17,118'MD/12,880'TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2» Maximum surface 1 ,503 psig At total depth (TVD) Setting Depth 5,796 psig Top Bottom MD TVD 15,~00' 11,920' 17,118' 12,880' Quantity of cement (include stage data) 252 cu ft 333 cu ft MD 11 ,300' 15,100' TVD 9,889' 11,824' Plugs (measured) Junk (measured) Cemented Driven Alaska & Measured depth AnGhOrag(~rue vertical depth 200' 200' Surface 1286 cu ft 3,190' 13,760' 2,939' 11,927' measured true vertical 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Drilling luid program: X Time vs. depth plot: Refraction analysis: 21. I herby ertl that the foregoing is true and correct to the best of my knowledge: Title: Drilling Manager Commission Use Only Permit Number ~ / / 0 API number , , Approval date?~ 2/. See cover letter :2-0 ;2- - ~ D 50- 7:Š ~ - 20 5" I 3 -0 { (J J 1 J O::L- for other requirements Conditions of approval Samples required: [] Yes b(I No Mud log require: [] Yes b(J No Hydrogen sulfide measures [] Yes b(] No Directional survey required 2\1 Yes [] No Required working pressure for BOPE [] 2M; [X] 3M; [] 5M; [] 10M; [] 15M Other: '~~~--K.s.'\-' Cammy Oechsti T aytor Signed: Paul White Approved by Form 10-401 Rev. 12-1-85 'l U Diverter Sketch: Seabed report: Drilling program: X 20 AAC 25.050 requirements: X Date:«? \'? 0'-.. Commissioner by order of the Commission Date: -g 113! Od. ~ l~ Submit in triplicate ') ) Attachments 1. Outline Procedure 2. Well schematic 3. Unit Boundary Plat wI Proposed Well Path 4. Drilling Fluids Program 5. Pressure Information 6. Casing Design 7. Cement Calculations 8. Directional Information 9. Well Head Schematic 10. Nabors BOP schematic 11. Nabors BOP equipment list 12. Nabors Drilling Fluid System Description ) ') Redoubt Unit #5A OUTLINE PROCEDURE 1. Set Baker Bridge Plug at +1- 11,525'. Use Collar Locator to set BP just above collar. 2. Kick off at +1- 11,500' MD with Baker WindowMaster whipstock assembly. 3. Directionally drill 8 Y2" hole to 15,300'MD I 11,920' TVD. LWD (GR, Res, and Azimuthal Density) will be run the last bit run to correctly correlate the top of Hemlock. The azimuth will be held while building to approximately 64 degree inclination angle at 12,400' MD. A tangent section will be drilled and a slight drop will be initiated near the top of Hemlock to a final angle of 58 degrees. This drop is predicted to start near 15,100' MD, but will depend on the correlation. 4. Condition hole, Run and cement 7 5/8" drilling liner from 11,300' MD to 15,300' MD. Note: Liner hanger will be set by means of dropping a ball before the cement job. The liner hanger will have a bearing section, which will allow rotation during the cement job. The liner packer will be mechanically set once cement is in place. The liner will have an 80' shoe track. 5. Pick up 4" HT drill pipe 1 BHA and run in hole. 6. Clean out liner and test lap to 3,000 psi. 7. Drill out cement and float equipment. 8. After drilling 20' , but no more than 50' of new formation, perform Formation Integrity Test to 10.5 ppg EMW. 9. Directionally drill 6 %" hole to TD at 17,118'MD 112,880' TVD. LWD will be run the entire hole section, including Gamma Ray, Resistivity and Neutron Density. 10. Condition hole for liner. 11. Run and cement 5 Y2" liner from 15,.!00' to TD. Note: Liner hanger will be set by means of dropping a ball before the cement job. The liner hanger will have a bearing section, which will allow rotation during the cement job. The liner packer will be mechanically set once cement is in place. The entire length of 5 Y2" liner will be cemented, with an 80' shoe track. 12. Rill with a tapered clean out assembly. 13. Clean out liner and test lap to 3000 psi. 14. Change over to 5% KCl. 15. Run USIT log across the 5 Y2" liner. 16. Drill stem test the Hemlock formation. 17. Run Baker model-FA wI 4.4" ill bore on drillpipe. Set at approximately 15,050' MD. 18. Run Sclumberger LLC-3 valve on drillpipe, set in packer. 19. Run 3 Y2" ESP completion. 20. Nipple up 3 1/8" production tree. ) I ) Redoubt Unit #5A Casing Plan 30" Conductor 13 3/8" 68#, L-80 BTC Surface Casing 18 1/2" Hole ~ ~ 75/8" 29.7# L-80 Liner @ 15,300' MD 11,920' TVD 8 1/2" Hole '- ~ - 5 1/2" 17# L-80 Liner set @ 17,118' MD 12,880' TVD - 63/4" Hole ~ 200' MD - 200' TVD 3,190' MD - 2,939' TVD KOP @ 11,500' MD, 10,065' TVD Baker WindowMaster Whipstock Assembly Baker Bridge Plug set at +/- 11,525' MD 95/8" 47#, L-80 BTC Intermediate Casing 12 1/4" Hole 13,760' MD - 11,927' TVD 8 1/2" hole 15,438' MD - 13,378' TVD ) 36 --~ ~,.......n"^"",^,, ,.."""" 2 ..._-,._-"""'_...............-......~ """""""~w.N'N"~--.-~,"",,,,,,,'---..w.' 11 12 RDL 76 '381203 14 OSPREY 13 "" .. ".. f' ¡ i ! ¡ I ¡ ¡ ! ..- ¡ -- --- --r - - --- ~! REDOUBT SH ST¡220S4 1 ! 23 -¡ 2 1 :t ¡ -""""'-'.",^,",,,,,,,,,,,, ~B REDOUBT BAY U 1 RU 3 .., .....w.- ........ .-..- ....... ......",... .....,. ----- ~ ) 6 ! i I ! ¡ I RoL 74 ¡ ¡ ! ! ¡ ! ---t- - -~..__...- I I ¡ I J ! I ¡ ~ ! .... '1.' . _. -..' -- ..- ..". "" .-- 31 32 378 14 5 33 4 -""'"",^on""''''''''''-----~ ^"'" .7 8 17 . "TIII_oÕ, }[ß]If~'&.--.....'-"1I4o. - 1\ - U 2 RU 4 FINÃL SURrEY ¡ 19 20 ...."""^ --,,,'--'<Þ.",^, ~ .~';Ÿ'^"''''''' "NM ............, ............ ,.,.,....." ¡ I 30 ""---""""'''''''''''~-''''''''' ¡ f i ~........ .J.......... -- -.""'" """^'" ... 31 RDL 67R~ 374002 ,. fOREST OIL tOft!' - REDOUBT U14n PROPOSED RUSR 6 . " I .'- I 9 ~~. .."'''' ~.~ """,. 16 .....:.aPA--- m_--~~r~\k..ulB1..... nl". - ¡". 21 '"",",' .- "'No ......~. ~ ÌII q ) ) Redoubt Unit #5A DRILLING FLUID PROGRAM ') ) Interval Summary - OBM Forest Oil Corporation Redoubt Shoal Unit #5 Sidetrack ~" ...<I. - Depth Interval 11500 -15300' MD 7-5/8" Casing 8-1/2" Hole Recommended Drilling Fluid Properties Mud Plastic Yield HTHP Oil:Water Weight Viscosity Point Fluid Loss Ratio ¡I! j~ j~ D:~:~. Solids ~ (%) 5 to 7 'Hi (ft) 11500 -15300 (PPG) 9.4 - 9.6 (cp.) 23 -27 (lb./100ft2) (ml/30min) 19 - 23 4 - 6 (:) 82:18 n .. ~ ~ n. Product PPB Oil Mud 20 bbls Safecarb M 10 ppb OM Seal 10 bbl G-Seal 10 ppb Volume 22 bbl Mixing Procedure . Place 20 bbls oil mud in slugging pit. Add blend of lost circulation material. Spot across theft zone. Çöa.ISloughingfUI Soltex Spot Soltex pill across suspected coal bed 15 - 20 ppb prior to pulling out of hole for trip. Product Oil Mud PPB 20 bbls 1~~ Mixing Procedure . Place 35 bbls oil mud in slugging pit. Add 15 - 20 ppb Soltex. Spot across theft zone and ap- ply squeeze pressure not greater than annular pressure loss. Weighted high Viscosity Pin Product Oil Mud Base Oil Versa- Ver- Barite If hole cleaning is suspect, pump a coat sawet weighted sweep. Monitor returns for 30 bbls 5 bbls 5 gal 2 gal 120 sx indications of increased cuttings. PPB ~~ leW~~':.:U:...:_!!¡:',::JJ~.~~'::"~;;;:;;~::::~-''''':':'-'~'''''~~"~~ ¡:'~!Ir.wI¡'¡iiilii::::!~.ow.¿.'.'.!.;~r1q¡.i ,.---~.~._..,-~",--~._,.._.:~:!;:~."~.f."M'II':1II'~t...;;;;;.,;,;;.;;an.~WiJAmWfM~\._--:::'_::{:~''Ì,\..... ~~~-~~! ....~>.$»> ~~~ ....-..... Em, ,'~;.;;:':."'::'. ~FE /"''''.- ~ '.:~...,': M-I LLC. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 . Fax: (907) 279-6729 ,: ~ ... . . :.;"~. ~ ::9 ') ) Interval Summary, Cont. Forest Oil Corporation Redoubt Shoal Unit #5 Sidetrack ili~ 'ð~Q 11,500 to 15,300' M.D. .. 8 1/2" Hole . ROP, GPM . Estimated ROP for this interval is 50 to 150 ft/hr. . Estimated flowrate for this interval is 450 - 470 GPM. . Use Virtual Hydraulics models as a guideline for flowrates and hole cleaning. . Lost Circulation . Seepage losses may be controlled with moderate additions of Sa fee arb and/or G-Seal. Severe lost circulation should be handled with LCM pills such as the one listed for this interval Coal Beds . . Sloughing/running coal should be treated by adding 4 - ppb Soltex to the mud system de- pending on the severity of the problem. NOTE: Soltex additions can reduce the rheology of the mud. Be prepared to add rheology modifiers (IMG 400, VersaMod, VersaHRP), as needed to maintain proper rheology. . For severe coal sloughing, a concentrated pill consisting of 15 - 20 ppb Soltexl may be spot- ted across the coal bed prior to POOH for a trip. A slight amount of pressure (equal to the an- nular pressure loss) may be applied to the pill to squeeze it into the coal bed. . Swab/Surge Pressures . Care should be taken while running in the hole and breaking circulation after an extended pe- riod of time out of the hole. Bringing up the pump rates too rapidly while the drilling fluid is cold may cause excessive annular pressure loss on the formation. While running in the hole after trips, circulation should be broken at least once at the casing shoe. At T.D. the pumps should be brought up slowly in order to allow the fluid to heat up prior to reaching normal flowrates. . Casing running fluid properties . The mud should be conditioned prior to POOH to run liner. Moderate or reduce yield point and progressive gel strengths with additions of base oil in order to reduce surge pressure while running casing. NOTE: See recommended liner running speed for this interval in Virtual Hy- draulics. .1 : :~~~::~~=::~~::::t::~:~:t:::: :~::ce ITE CoormMtor. '-.......,..............~.~~.... ~3@'~~ ~~X><'>~ M-I L.L.c. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 . Fax: (907) 279-6729 ~ Œ""" . , . ~ . r" ". -~ , . .~. . §~~':':;;:.":'~:] IFE /<,' ".'. ~.",,; ."; --... '<;f.;,.,---- " r...,_... ':':.~'. - .- ""'. ~ ..,."..,.",., ") ) Interval Summary - OBM Forest Oil Corporation Redoubt Shoal Unit #5 Sidetrack ~, *~~... 15300 -17118' MD 5-1/2" Casing 6-3/4" Hole ~ D:::~. ~, Solids ~ :~); ,:1 I Depth Interval Recommended Drilling Fluid Properties Mud Plastic Yield HTHP Oil:Water Viscosity Weight Point Fluid Loss Ratio (ft) (PPG) (cp.) (lb./100ft2) (mll30min) (:) 15300 -16200 9.0 -10.0 23 -27 19 - 23 4-6 82:18 16200 -17118 9.0 -10.0 23 - 27 19 - 23 3-4 82:18 "¡b n n n t6-==. ~. Product PPB Oil Mud 20 bbls ,Safecarb M 10 ppb I OM Seal 10 bbl G-Seal 10 ppb Volume 22 bbl Mixing Procedure . Place 20 bbls oil mud in slugging pit. Add blend of lost circulation material. Spot across theft zone. Product Oil Mud Coal.Sløughing Pill Soltex Spot Soltex pill across suspected coal bed I' , 15 - 20 ppb prior to pulling out of hole for trip. n TIiill!' ¡¡¡¡In TIf ,<:;m n f.....1~¡; TI1i!!lilI!1 Æ[ 1 !lÆH\!Im .1 PPB 20 bbls IIII ¡ ~I~~ r '!j¡J'"" ¡~ ]¡I I[ I Ai:Iï Mixing Procedure . Place 35 bbls oil mud in slugging pit. Add 15 - 20 ppb Soltex. Spot across theft zone and ap- ply squeeze pressure not greater than annular pressure loss. Weighted high Viscosity Pin Product Oil Mud Base Oil Versa- Ver- Barite If hole cleaning is suspect, pump a coat sawet weighted sweep. Monitor returns for 30 bbls 5 bbls 5 gal 2 gal 120 sx indications of increased cuttings. PPB .. ....~.,," 01} .,,"'''' _il"':,O.':.yc.::.'~::::.:'~:~".''''~_'~'''''''" n ii' 1" '-":';;;'ii¡~=,.'~q~~~;~'~~¡-~~~~:~:~~~~!!"'~:"!_,',,;m,...'" .n" '"" - .,! ...l....... -\v-- ~~~J;:t:.~.9~''''''''-- ""'*~ M-I LLC. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 . Fax: (907) 279-6729 ~IÆœ. .... "..,o, , '. ~:; ..... ,:, ~..-. ..~ . ) ') Interval Summary, Cont. Forest Oil Corporation Redoubt Shoal Unit #5 Sidetrack 'I_-'&~' fbt r , ~h_"fm¡", m, 15,300 to 17, 118' M.D. ææ 6 3/4" Hole . ROP, GPM . Estimated ROP for this interval is 20 ft/hr. . Estimated flowrate for this interval is 250 GPM. . Lost Circulation . Seepage losses may be controlled with moderate additions of Safecarb and/or G-Seal. Severe lost circulation should be handled with LCM pills such as the one listed for this interval Coal Beds . . Sloughing/running coal should be treated by adding 4 - 6 ppb Soltex to the mud system de- pending on the severity of the problem. NOTE: Soltex additions can reduce the rheology of the mud. Be prepared to add rheology modifiers (IMG 400, VersaMod, VersaHRP), as needed to maintain proper rheology. . . For severe coal sloughing, a concentrated pill consisting of 15 - 20 ppb Ventrol401 may be spotted across the coal bed prior to POOH for a trip. A slight amount of pressure (equal to the annular pressure loss) may be applied to the pill to squeeze it into the coal bed. . Swab/Surge Pressures . Care should be taken while running in the hole and breaking circulation after an extended pe- riod of time out of the hole. Bringing up the pump rates too rapidly while the drilling fluid is cold may cause excessive annular pressure loss on the formation. At T.D. the pumps should be brought up slowly in order to allow the fluid to heat up prior to reaching normal flowrates. . Casing running fluid properties . The mud should be conditioned prior to POOH to run liner. Moderate or reduce yield point and progressive gel strengths with additions of base oil in order to reduce surge pressure while running casing. NOTE: See recommended liner running speed for this interval in Virtual Hy- draulics. . VOLUME USA.GE . Estimated fluid volume required for this interval is 650 barrels of new volume. "'~---. - ~ M-I LLC. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 . Fax: (907) 279-6729 IFE æ... " ) ) REDOUBT UNIT #5A PRESSURE INFORMATION The following presents data used for calculation of anticipated surface pressures (ASP) during drilling of the Redoubt Unit #1 and Redoubt Unit #2. Redoubt Shoal State 29690-1, P=5309 psi @ 12,070' TVD from DST #2 (as per 407 Comp Report, 1/9/68) EMW = 8.46 ppg Gradient = 0.440 psi/ft Redoubt Shoal State 29690-2, P=5249 psi @ 12,202' TVD from DST #l(as per 407 Comp Report, 10/15/68) EMW = 8.27 ppg Gradient = 0.430 psi/ft Redoubt Bay Unit #1, P=4800 psi @ 10,953' TVD from DST (as per monthly drilling report, 12/13/76) EMW = 8.43 ppg Gradient = 0.438 psi/ft The most conservative (highest) formation pressure gradient of 8.65 ppg or .45 psi/ft was used in these calculations. Procedure for Calculatine: Anticipated Surface Pressure ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point and a 1/3 gas gradient plus a 2/3 saltwater gradient to the surface. We have chosen this method based on no sign of gas in the Redoubt Unit #1 and Redoubt Unit #2. 1) ASP = ((FG x .052) - 0.10) x D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.10 = gas gradient in psi/ft D = true vertical Depth of casing seat in ft RKB OR 2) ASP= FPP-( 1/3 x 0.10 x D) - (2/3 x.45 x D) where: FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) ') ) ASP Calculations Drilling below Intermediate Casing (9 5/8") ASP = ((FG x .052)- 0.10) x D = ((14.8 x .052) - 0.10) x 2939' = 1968 psi OR ASP = (11920' x .45) - (1/3 x .10 x 11920') - (2/3 x .45 x 11920') = 1391 psi Drilling below Drilling Liner (7-5/8") ASP = ((FG x .052)- 0.10) x D = ((10.5 x .052) - 0.10) x 12880' = 5744 psi OR ASP = (12880' x .45) - (1/3 x .10 x 12880') - (2/3 x .45 x 12880') = 1503 psi Size Hole Casing 8112" 7 5/8" 6 3,4" 5 112" Casing 7 5/8" 29.7# L-80 Hydril 521 5 1/2" 17# L-80 Hydril521 Desi2n Criteria Tension Burst Collapse 7 5/8" Drillin2 Liner Tension Burst Collapse ) REDOUBT UNIT #5A CASING DESIGN Weight 29.7# 17# Specifications Grade Coupling Length L-80 Hydril 521 4,000' L-80 Hydril521 2,018' J oint Strength Klbs 566 338 Body Strength Klbs 683 397 MD 11,300' 15,100' ) Top Setting Depth Bottom TVD MD TVD 9,889' 15,300' 11,920' 11,824' 17,118' 12,880' Burst Psi 6890 7740 Collapse Psi 4790 6290 Straight Hook Load - Ignoring Deviation and Buoyancy Full Column of Gas against deepest formation pressure Except for liners where a 3000 psi test pressure on top of 9.6 ppg fluid is backed on the outside by a fresh water gradient of 0.43 psi/ft. Full evacuation on the inside backed by expected formation gradient of .45 psi/ft. on the outside. = 4000' x 29.7# = 118.8 K = ((11920 x .4992)+3000)-(11920 x .43) = 3825 psi = (12880' x .45) - (.10 x 12880') = 4508 psi 5 Vi' Production Liner Tension Burst Collapse = 2018' x 17# = 34.3 K = ((12880 x .4992)+3000)-(12880 x .43) = 3891 psi = (12880' x .45) - (.10 x 12880') = 4508 psi Rated = 566 K Safety Factor = 4.8 Rated = 6890 psi Safety Factor = 1.8 Rated = 4790 psi Safety Factor = 1.1 Rated = 338 K Safety Factor = 9.9 Rated = 7740 psi Safety Factor = 2.0 Rated = 6290 psi Safety Factor = 1.4 ) REDOUBT UNIT #5A CEMENTING PROGRAM Operator Name: Forest Oil Corporé ') Well Name: REDOUBT UNIT 5aST Job Description: 7 -5/8" Drilling Liner Date: August 13, 2002 JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Liner SizelWeight : Pump Via Total Mix Water Required Pre-Flush Water + 1 gpb MCS-AG Weighted Spacer MCS-4D Density Cement Slurry Class G Cement Density Yield Displacement Drilling Mud Density Report Printed on: Augusl13, 2002 2:05 PM 11,9201t 15,300 ft 8.5 in 75/8in, 29.7 Ibs/ft Drill Pipe 5" 0.0. (4.276" .1.0) 19.5 7 5/8" 0.0. (6.875" .1.0) 29.7 Page 1 1 ,077 gals 20 bbls 30 bbls 10.5 ppg 219 sacks 15.8 ppg 1 .15 cf/sack 384 bbls 9.6 ppg ') !£j Proposal No: 100173314A Gr4109 Operator Name: Forest Oil Corpora) Well Name: REDOUBT UNIT 5a ST Job Description: 7-5/8" Drilling Liner Date: August 13, 2002 WELL DATA ANNULAR GEOMETRY ANNULAR,.UD. 0.,). 8.681 CASING 8.500 HOLE ) E£j Proposal No: 100173314A MEASURED 11 ,500 15,300 SUSPENDED PIPES DIAMETER (in) O~D. I 7.625 I WEIGHT (lljslft) 29.7 Drill Pipe 5.0 (in) OD, 4.276 (in) ID, 19.5 (Ibslft) set @ Drill Pipe 7.625 (in) OD, 6.875 (in) ID, 29.7 (Ibslft) set @ Depth to Top of Liner Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. VOLUME CALCULATIONS 1,500 ft x 0.0770 cf/ft 80 ft x 0.2578 cf/ft with 101 % excess = with 0 % excess = TOTAL SLURRY VOLUME = Report Printed on: Augusl13, 20022:06 PM Page 2 DEPTH(ft) . I . TRUE VERTICAL I 10,065 I 11 ,920 DEPTH(ft) MEASURED I TRUEVERTICAL 15,300 I 11 ,920 11 ,200 ft 15,300 ft 11 ,200 ft 15,220 ft 9.60 ppg Oil Based 180 0 F 145 0 F 232 cf 21 cf (inside pipe) 252 cf 45 bbls Gr4117 Operator Name: Forest Oil Corporaf'\ Well Name: REDOUBT UNIT 5a.it Job Description: 7-5/8" Drilling Liner Date: August 13, 2002 FLUID SPECIFICATIONS Pre-Flush Weighted Spacer FLU ID VOLUME VOLUME CU-FT FACTOR Cement Slurry I 252 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Estimated Pumping Time - 70 BC (HH:MM) Free Water (mls) @ 1400 F @ 900 angle Free Water (mls) @ 1400 F @ 450 angle Fluid Loss (cc/30min) at 1000 psi and 1400 F COMPRESSIVE STRENGTH 12 hrs @ 1800 F (psi) 24 hrs @ 1800 F (psi) RHEOLOGIES FLUID Cement Slurry TEMP @ 140 0 F ) !£j Proposal No: 100173314A 30.0 bbls MCS-4D + 6 Ibs/bbl MCS-D + 22.61 Ibs/bbl Bentonite + 90 Ibs/bbl Barite, Bulk @ 10.5 ppg AMOUNT AND TYPE OF CEMENT 1.15 = 219 sacks Class G Cement + 0.150/0 bwoc R-3 + 0.30/0 bwoc CD-32 + 0.7% bwoc FL-33 + 1 gals/100 sack FP-6L + 43.6% Fresh Water 383.5 bbls Drilling Mud @ 9.6 ppg SLURRY NO.1 15.80 1.15 4.92 4.93 4:30 0.0 0.0 40.0 1800 3000 600 235 300 140 200 103 6 7 3 6 100 59 Pilot tests will be preformed prior to loading. Slight additvie adjustments should be expected to achieve the desired slurry properties based on pilot test results. Report Printed on: August 13,20022:06 PM Page 3 Gr4129 Operator Name: Forest Oil Corpora ') Well Name: REDOUBT UNIT 5a ST Job Description: 5-1/2" Production Liner Date: August 13, 2002 JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Liner SizelWeight : Pump Via Total Mix Water Required Pre-Flush Water + MCS AG Density Weighted Spacer MCS-4D Density Cement Slurry Class G Cement Density Yield Displacement Drilling Mud Density Report Printed on: August 13, 20022:06 PM 12,880 ft 17,118ft 6.75 in 5 1/2 in, 17 Ibs/ft Drill Pipe 5 1/2" 0.0. (4.276" .1.0) 19.5 Drill Pipe 4" 0.0. (3.240" .1.0) 15.7 Casing 5 1/2" 0.0. (4.892" .1.0) 17 1 ,417 gals 15 bbls 8.4 ppg 30 bbls 10.5 ppg 282 sacks 15.7 ppg 1 .18 cf/sack 282 bbls 9.8 ppg Page 5 ) !£j Proposal No: 100173314A Gr41 09 Operator Name: Forest Oil Corpora ') Well Name: REDOUBT UNIT 5a ST Job Description: 5-1/2" Production Liner Date: August 13, 2002 WELL DATA ANNULAR GEOMETRY ANNULAR I.D. (in) 6.875 CASING 6.750 HOLE MEASURED 15,300 17,118 SUSPENDED PIPES DIAMETER (in) O.D~ I 5.500 I ) !£j Proposal No: 100173314A DEPTH(ft) I TRUE VERTICAL I 11,920 I 12,880 DEPTH(ft) MEASURED I TRUE VERTICAL 17,118 I 12,880 Drill Pipe 5.5 (in) OD, 4.276 (in) ID, 19.5 (Ibs/ft) set @ Drill Pipe 4.0 (in) OD, 3.24 (in) ID, 15.7 (Ibs/ft) set @ Drill Pipe 5.5 (in) OD, 4.892 (in) ID, 17 (Ibs/ft) set @ Depth to Top of Liner Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. VOLUME CALCULATIONS 200 ft x 0.0928 cf/ft 1,818 ft x 0.0835 cf/ft 80 ft x 0.1305 cf/ft with 0 % excess with 100 % excess with 0 % excess = TOTAL SLURRY VOLUME = Report Printed on: August 13, 2002 2:06 PM Page 6 11 ,000 ft 15,100 ft 17,118 ft 15,100 ft 17,038 ft 9.80 ppg Oil Based 190 0 F 155 0 F = 19 cf 304 cf 10 cf (inside pipe) 333 cf 59 bbls Gr411ì Operator Name: Forest Oil Corporaf '\ Well Name: REDOUBT UNIT 5a vr Job Description: 5-1/2" Production Liner Date: August 13, 2002 ) [£j Proposal No: 100173314A FLUID SPECIFICATIONS Pre-Flush Weighted Spacer 30.0 bbls MCS-4D + 6 Ibs/bbl MCS-D + 22.61 Ibs/bbl Bentonite + 90 Ibs/bbl Barite, Bulk @ 10.5 ppg FLU ID VOLUME VOLUME CU-FT FACTOR AMOUNT AND TYPE OF CEMENT Cement Slurry 333 I 1.18 = 282 sacks Class G Cement + 0.4% bwoc R-3 + 2% bwow Potassium Chloride + 0.6% bwoc CD- 32 + 0.2% bwoc FL-33 + 1 gals/100 sack FP-6L + 0.2% bwoc Sodium Metasilicate + 0.9% bwoc BA-10A + 44.6% Fresh Water Displacement CEMENT PROPERTIES 282.2 bbls Drilling Mud @ 9.8 ppg Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Estimated Pumping Time - 70 BC (HH:MM) Free Water (mls) @ 1550 F @ 900 angle Free Water (mls) @ 155 0 F @ 45 0 angle Fluid Loss (cc/30min) at 1000 psi and 1550 F COMPRESSIVE STRENGTH 12 hrs @ 1900 F (psi) 24 hrs @ 1900 F (psi) SLURRY NO.1 15.70 1.18 5.02 5.03 5:30 0.0 0.0 20.0 1300 3100 Pilot tests will be preformed prior to loading. Slight additvie adjustments should be expected to achieve the desired slurry properties based on pilot test results. Report Printed on: August 13, 2002 2:06 PM Page 7 Gr4129 ) ) REDOUBT UNIT #SA DIRECTIONAL PROGRAM ') ) ~:~~~bt Unit #SA WP02 DrillQuest''' spel""'lr"y-sun Alaska DRH_L-ING, SERv'Ic:es Cook Inlet It. It<IlIltIunoo C<>II\Paj\)' 10000 - :=- õ5 S -- 11000 - s:. ...... a. Q) 0 -æ () :;:; :.... Q) > 12000 - ;t::: 0 0 0 ..- \I ..c: 0 c :;: 13000 - Q) ëa 0 (j) Drill Quest 2.00,09.006 Single Well Target Data for Plan: Redoubt Unit #SA WP02 Measurement Units: ft Coordinate Target Point TVD Northings Eastings SSTVD Northings Eastings Target Name Type ASPY ASP X Shape RU#5A TD Entry Point 12880.00 7506,80 S 6732.00 E 12790.00 2442425,00 N 207360.00 E Point RU#5A Top Hemlock Entry Point 11910,00 6361.80 S 5672.00 E 11820.00 2443570.00 N 206300.00 E Point Proposal Data for RU#5A WP02 Vertical Origin: Well Horizontal Origin: Well Measurement Units: ft North Reference: Grid North Grid North Convergence: -1.457° Dogleg severity: Degrees per 100 feet (US) Vertical Section Azimuth: 137.650° Vertical Section Description: Well Vertical Section Origin: 0.00 N,O.OO E Coordinate System: NAD27 Alaska State Planes, Zone 4, US Foot Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 11500.00 28.894 138.762 10065.01 3948.83 S 3489,28 E 5268.93 11520,00 31.263 138.000 10082.32 3956.32 S 3495.94 E 5278.95 12.000 12345.76 64.294 137.871 10629.57 4403.92 S 3900.12 E 5882.03 4.000 15126.00 64.294 137.871 11835,53 6261.79 S 5580.52 E 8387.10 0.000 15280,73 58.132 137.208 11910.00 6361.80 S 5672.00 E 8522.63 4.000 15280.74 58.132 137.208 11910.00 6361.80 S 5672.00 E 8522.64 4.000 17117,99 58,132 137.208 12880.00 7506.80 S 6732.00 E 10082,92 0.000 Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: RKB Elevation: Plan: Redoubt Unit #5A 2449931.80 N, 200628.00 E 1679.20 S, 2250983.00 W 60° 41' 43.6518" N, 151° 40' 14.4892" W 90.00ft above Mean Sea Level 90.00ft above Structure -1 .457° Grid North Convergence: North Reference: Units: Grid North Feet (US) ST Exit @ 12.0000/100ft, 9.50° Left TF : 11500.00ftMD,10065.01ftTVD ,00 Begin 8.1/2" Hole Begin Dir @ 4.0000/100ft : 11520.00ft MD, 1 0082. 32ft TVD End Dirt Start Sail @ 64.294° : 12345.76ftMD,10629.57ftTVD Begin Dir @ 4.0000/100ft : 15126.00ft MD, 11835.53ft TVD End Dir, Start Sail @ 58.132°: 15280.74ftMD,11910.0OftTVD Begin 6-314" Hole I 5000 Scale: 1 inch = 1000ft I 6000 I I 10000 11000 Section Azimuth: 137.650° (Grid North) I 7000 I 8000 Vertical Section (Well) I 9000 IS')- ~. ?@ ~ 7~ ~. 'OQ ~ i:'. 4;. '" q, ''\ ~@ ~ Q' <>. ~n.. '-?,S} ~ "'0. i:'. -. 0700,00'1S'~ "'Q <1\1..,. ~~~. ~ ~9 ~ 7{s.: "7J'. ''\ 'V ~q ~o .~~~~ '0<% 0' 00 .' ~<) ~ "i!ffi, ~ '}', ~}', ü>~ °q¡. o~ .>~ "'?\? ~o ~~~..,. 7..,. ~ 7Q 'Ì-<) ~<) ~.9 '~>. .,~ ð Sipa""'''''Y-SUf1 Alaska g:i£i,J;:b:u!~=itë[Ft.\lTè"'ë':š; Cook Inlet It 1tä111110rtQ<ì campllrty Measurement Units: ft Target Name Coordinate Point Type RU#5A TD Entry Point Entry Point RU#5A Top Hemlock -4200 - -4800 - -5400 - - Q5 S -- (f) C> c :ë t -6000 - 0 Z -6600 - ) ) Osprey Redoubt Unit #SA WP02 Single Well Target Data for Plan: Redoubt Unit #SA WP02 DrillQuest~ TVD Northings Eastings SSTVD Northings Eastings Target ASPY ASP X Shape 12880.00 7506.80 S 6732.00 E 1,2790.00 2442425,00 N 207360,00 E Point 11910.00 6361.80 S 5672.00 E 11820.00 2443570.00 N 206300,00 E Point Proposal Data for RU#5A WP02 Vertical Origin: Horizontal Origin: Measurement Units: North Reference: Grid North Convergence: Dogleg severity: Vertical Section Azimuth: Vertical Section Description: Vertical Section Origin: Coordinate System: Measured Incl. Depth Well Well ft Grid North -1.457° Degrees per 100 feet (US) 137.650° Well 0.00 N,O.OO E 11500.00 11520,00 12345,76 15126,00 15280.73 15280.74 17117,99 28.894 31.263 64.294 64,294 58.132 58.132 58.132 NAD27 Alaska State Planes, Zone 4, US Foot Azim. Vertical Northings Eastings Vertical Dogleg Depth Section Rate 138.762 10065.01 3948,83 S 3489.28 E 5268.93 138.000 10082.32 3956,32 S 3495.94 E 5278.95 12.000 137.871 10629.57 4403.92 S 3900.12 E 5882.03 4.000 137,871 11835.53 6261.79 S 5580,52 E 8387.10 0,000 137.208 11910.00 6361.80 S 5672,00 E 8522.63 4.000 137.208 11910.00 6361.80 S 5672.00 E 8522.64 4,000 137.208 12880.00 7506,80 S 6732.00 E 10082.92 0.000 Current Well Properties Well: I Horizontal Coordinates: - -7200 -I Ref. Global Coordinates : Õ I Ref. Structure: g I Ref. Geographical Coordinates : II , . ..c I RKB Elevation: . () ¡ .~ Grid North Convergence: "* North Reference: ð5 -7800 - Units: I I 3300 3900 Scale: 1 inch = 600ft DrillQuest 2,00.09.006 Plan: Redoubt Unit #5A 2449931.80 N, 200628.00 E 1679.20 S, 2250983.00 W 60041' 43.6518" N, 151040' 14.4892" W 90.00ft above Mean Sea Level 9O.00ft above Structure -1 .4570 Grid North Feet (US) I 4500 I 5700 I 6300 Total Depth: 17117.99ftMD,12880.0OftTVD I 6900 Reference is Grid North I 5100 Eastings (Well) Spertf-Sun Drilling Se,'ltices Proposal Data - Plan: Redoubt Unit #5 - RU#5A WP02 Approved Plan MD Delta Inclin. Azimuth I TVD Delta Northings Eastings Dogleg A. Build A. Turn Toolface VS (138°) (ft) MD (ft) (O) (°) I (ft) TVD (ft) (ft) (ft) (0/100ft) (0/100ft) (0/100ft) (°) (ft) ~~-~.!.~_0~.001...--..-1.._?8.8~L._..!~~.:?~.:..~~~~.0~---- ;. 3948.83 81 34~~~_~.;--~_.._---_._.._J--..---L.._..".,,------¡" 5268.9: , 2' l 11520.00: 20.00; 31.26: 138.00 10082.321 17.31\ 3956.328) 3495.94E! 12.00: 11.85! -3.81: 350.511 5279.0 3 12345.76 825.76 64.29 137.87 10629.57 547.26 4403.928 3900.12 E 4.00 4.00 -0.02 359.79 5882.0 4 15126.00 2780.24 64.29 137.87 11835.53 1205.95 6261.798 5580.52 E 0.00 0.00 0.00 0.00 8387.1 5T 15280.73 154.73 58.13 137.21 11910.00 74.47 6361.808 5672.00E 4.00 -3.98 -0.43 185.24 8522.6 6 15280.74 0.01 58.13 137.21 11910.00 0.00 6361.80S 5672.00E 4.00 4.00 0.00 0.00 8522.6 7T 17117.99 1837.25 58.13 137.21 12880.00 970.00 7506.808 6732.00E 0.00 0.00 0.00 0.00 10082.9 .. - -.-- . ........- ,-.-.. n.. .m..''''"... - .. .. . .......... . . n.. ........ ~ "- . -"'--- no", -'" - .~..._u. ,_.....~.~. . - 13 August, 2002 - 10:16 - 1 - DrillQuest ~ A'laska Cosk Inlet Osprey, Slot Leg 3 - Slot 5 Plan: Redoubt Unit #5 - RU#5A WP02 Revised: 13 August, 2002 PROPOSAL REPORT 13 August, 2002 ~. Surface Coordinates: 2449931.80 N, 200628.00 E (60041' 43.6518" N, 151040' 14.4892" W) Surface Coordinates relative to Project H Reference: 2550068.20 5, 299372.00 W (Grid) Surface Coordinates relative to Structure: 1679.20 5, 2250983.00 W (Grid) Kelly Bushing: 90.00ft above Mean Sea Level spa,-,,-,v-suf1 ~;U~,II_L.ING Se:AVIC:E!~ A Halliburton Company Proposal Ref: pr090 Sperry-Sun Drilling Services Proposal Report for Plan: Redoubt Unit #5 Revised: 13 August, 2002 Cook Inlet Alaska Osprey Measured Sub-Sea Vertical Local Coordinates rtical Depth Incl. Azim. Depth Depth . Northings Eastings Section Comment (ft) (ft) (ft) (ft) (ft) Rig RU#5 MWD 0,00 0.000 0.000 -90.00 0.00 0.00 N 200628.00 E 0.00 100.00 0.174 42.000 10.00 100.00 0.11 N 200628.10 E 0.174 -0.01 ~ 200,00 0.201 235.812 110.00 200.00 0.31 N 200628.21 E 0.372 -0.08 300,00 2.936 199.423 209.96 299.96 2.01 S 200627.30 E 2.777 1.02 400.00 5.810 211.923 309.66 399.66 S 200623.68 E 3.011 3.52 500.00 8.405 211.617 408.87 498.87 19.31 S 2449912.49 N 200617.12 E 2.595 6.94 600.00 10.635 211.451 507.49 597.49 33.37 S 2449898.43 N 200608.49 E 2.230 11.52 700.00 12.465 211.327 605.39 6 50.75 S 2449881.05 N 200597.88 E 1.830 17.22 800.00 12.268 209.724 703.05 69.20 S 2449862.60 N 200586.80 E 0.396 23.38 900.00 11 .862 201.581 800.85 . ." 87.80 S 2449844.00 N 200577.47 E 1.748 30.85 1000.00 11 .865 188.357 898.72 107.58 S 55.87 W 2449824.22 N 200572.13 E 2.713 41.87 1100.00 12.995 171.714 996.44 128.72 S 56.01 W 2449803.08 N 200571 .99 E 3.741 57.40 1200.00 15.705 155.350 1093.36 152.15 S 48.90 W 2449779.65 N 200579.10 E 4.852 79.51 1300.00 16.967 147.452 1189.20 177.03 S 34.92 W 2449754.77 N 200593.08 E 2.552 107.31 1400.00 18.620 1284.47 201.55 S 17.04 W 2449730.25 N 200610.96 E 2.721 137.48 1500.00 21 .457 1378.44 1468.44 227.41 S 5.30 E 2449704.39 N 200633.30 E 2.889 171 .63 1600.00 24.285 1470.57 1560.57 256.31 S 31.29 E 2449675.49 N 200659.29 E 2.884 210.50 1700.00 26.664 1560.83 1650.83 287.58 S 60.83 E 2449644.22 N 200688.83 E 2.445 253.52 1800.00 28.642 137.383 1649.42 1739.42 321.36 S 92.63 E 2449610.44 N 200720.63 E 2.081 299.90 1900.00 31.418 136.588 1735.87 1825.87 358.04 S 126.94 E 2449573.76 N 200754.94 E 2.804 350.12 ~ 2000.00 31.037 137.1 89 1821 .34 1911.34 395.94 S 162.43 E 2449535.86 N 200790.43 E 0.492 402.04 2100.00 29.796 138.007 1907.52 1997.52 433.36 S 196.66 E 2449498.44 N 200824.66 E 1.309 452.75 2200.00 28.330 139.720 1995.05 2085.05 469.68 S 228.58 E 2449462.12 N 200856.58 E 1.685 501 .10 2300.00 28.714 140.847 2083.12 2173.12 506.45 S 258.43 E 2449425.35 N 200886.43 E 0.661 548.38 2400.00 30.841 139.193 2169.95 2259.95 544.25 S 290.55 E 2449387.55 N 200918.55 E 2.280 597.95 2500.00 30.972 139.191 2255.23 2345.23 583.79 S 324.64 E 2449348.01 N 200952.64 E 0.132 650.14 2600.00 29.814 137.459 2341.71 2431.71 621.50 S 357.79 E 2449310.30 N 200985.79 E 1 .452 700.35 2700.00 28.874 1 35.1 56 2428.74 2518.74 657.01 S 391 .90 E 2449274.79 N 201019.90 E 1 .469 749.57 2800.00 28.900 133.392 2516.53 2606.53 690.43 S 426.19 E 2449241 .37 N 201054.19 E 0.853 797.37 2900.00 29.144 134.691 2603.89 2693.89 723.99 S 461.43 E 2449207.81 N 201089.43 E 0.676 845.91 13 August, 2002 - 10:37 Page 2 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: Redoubt Unit #5 Revised: 13 August,2002 Cook Inlet Alaska Osprey Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) 3000.00 31.237 135.269 2690.55 2780.55 759.41 8 496.58 E 2449172.39 N 201124.58 E 2.114 895.76 3100.00 33.246 134.172 2775.06 2865.06 797.08 S 534.50 E 2449134.72 N 20~¡~!'2~50 E 2.092 949.14 3200.00 34.482 133.938 2857.77 2947.77 836.11 8 574.93 E 2449095.69 N 201202.93 E 1.243 1005.23 3300.00 34.164 133.834 2940.42 3030.42 875.13 S 615.50 E 2449056.67 N 201243.50 E 0.323 1061.40 3400.00 34.100 133.564 3023.19 3113.19 913.93 S ,,656.04 E 2449017.87 N 201284.04 E 0.165 1117.38 '~ 3500.00 33.433 135.988 3106.20 3196.20 952.78 8 5ttIi4448979.02 N 201324.02 E 1.503 1173.03 3600.00 33.203 137.618 3189.91 3279.91 99 8 . . 2448938.78 N 201361.10 E 0.925 1227.74 3700.00 32.618 138.198 3273.73 3363.73 10 8 2448898.39 N 201397.74 E 0.664 1282.28 3800.00 32.166 138.425 3358.24 3448.24 1073.40 S 2448858.40 N 201433.20 E 0.468 1335.72 3900.00 32.358 138.579 3442.86 3532.86 1113.30 S 2448818.50 N 201468.54 E 0.209 1389.01 4000.00 31.938 138.447 3527.45 1153.278 875.84 E 2448778.53 N 201503.84 E 0.426 1442.34 4100,00 31.697 138.116 3612.45 1192.59 8 910.89 E 2448739.21 N 201538.89 E 0.297 1495.01 4200.00 31 .811 138.183 3697.49 1231 .77 8 946.01 E 2448700.03 N 201574.01 E 0.119 1547.61 4300,00 31 .701 138.210 3782.52 1271.01 8 981.09 E 2448660.79 N 201609.09 E 0.111 1600.25 4400.00 31.917 138.256 3867.50 1310.32 S 1016.21 E 2448621.48 N 201644.21 E 0.217 1652.96 4500.00 31 .842 3952.42 4042.42 1349.79 S 1051.28 E 2448582.01 N 201679.28 E 0.142 1705.75 4600.00 31 .936 4037.25 4127.25 1389.48 S 1086.32 E 2448542.32 N 201714.32 E 0.100 1758.70 4700.00 30.91 5 4122.66 4212.66 1428.25 8 1121.00 E 2448503.55 N 201749.00 E 1.046 1810.71 4800.00 30.789 4208.57 4298.57 1466.57 8 1154.93 E 2448465.23 N 201782.93 E 0.310 1861.88 4900.00 31.196 4294.31 4384.31 1 505.22 8 1188.91 E 2448426.58 N 201816.91 E 0.415 1913.34 5000.00 31.720 138.810 4379.62 4469.62 1544.58 S 1223.17 E 2448387.22 N 201851.17 E 0.524 1965.51 5100.00 31 .892 138.425 4464.51 4554.51 1584.19 8 1258.16 E 2448347.61 N 201886.16 E 0.265 2018.35 ~ 5200.00 31 .562 1 37.443 4549.55 4639.55 1623.38 S 1293.26 E 2448308.42 N 201921 .26 E 0.613 2070.96 5300.00 31 ,752 136.832 4634.79 4724.79 1661.548 1329.01 E 2448270.26 N 201957.01 E 0.373 2123.25 5400.00 32.346 136.955 4719.53 4809.53 1700.338 1365.25 E 2448231.47 N 201993.25 E 0.598 2176.33 5500.00 31 .571 137.467 4804.16 4894.16 1739.36 S 1401.51 E 2448192.44 N 202029.51 E 0.822 2229.60 5600.00 30.480 137.678 4889.90 4979.90 1777.39 S 1436.17E 2448154.41 N 202064.17 E 1.096 2281.05 5700.00 30.192 137.786 4976.28 5066.28 1814.678 1470.07 E 2448117.13 N 202098.07 E 0.293 2331.44 5800.00 30.261 138.115 5062.70 5152.70 1852.03 S 1503.78 E 2448079.77 N 202131 .78 E 0.179 2381.77 5900.00 30.438 138.190 5149.00 5239.00 1889.67 8 1537.48 E 2448042.13 N 202165.48 E 0.181 2432.28 13 August, 2002 - 10:37 Page 3 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: Redoubt Unit #5 Revised: 13 August, 2002 Cook Inlet Alaska Osprey Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Comment (ft) (ft) (ft) (ft) (tt) (ft) (ft) 6000.00 30.545 137.773 5235.17 5325.17 1927.38 S 1571.43 E 2448004.42 N 202199.43 E 0.237 2483.02 6100.00 30.703 136.725 5321.22 5411.22 1964.75 S 1606.05 E 2447967.05 N 20ag,ß4.05 E 0.557 2533.96 6200.00 30.895 136,978 5407.13 5497.13 2002.11 S 1641.04E 2447929.69 N 202269.04 E 0.231 2585.14 6300.00 31.237 136.837 5492.77 5582.77 2039.80 S 1676.33 E 2447892.00 N 202304.33 E 0.349 2636.77 6400.00 31.381 136.963 5578.22 5668.22 2077.71 S 1711.82 E 2447854.09 N 202339.82 E 0.159 2688.70 ~ 6500,00 31 .709 137.369 5663.45 '. .2447815.76 N 202375.43 E 0.391 2741.01 6600.00 31.690 137.974 5748.42 :;; . 2447776.74 N 202410.88 E 0.319 2793.73 6700,00 31.087 138.227 5833.81 2447738.01 N 202445.64 E 0.617 2845.78 6800.00 30.758 138.255 5919.62 2447699.65 N 202479.78 E 0.330 2897.12 6900.00 30.530 137.791 6005.63 2447661.74 N 202513.90 E 0.329 2948.12 7000.00 30.167 137.442 6091 .93 1919.97 E 2447624.43 N 202547.97 E 0.403 2998.65 7100.00 29.750 137.646 6178.5q 1953.78 E 2447587.65 N 202581.78 E 0.429 3048.60 7200.00 29.894 137.164 6265.44 1 987.11 E 2447551.03 N 202615.11 E 0.280 3098.12 7300.00 30.349 137.1 30 6351.90 2021 .46 E 2447514.37 N 202649.46 E 0.455 3148.36 7400.00 30.664 138.460 6438.05 2055.61 E 2447476.80 N 202683.61 E 0.745 3199.13 7500.00 30.652 6524.04 6614.04 2493.31 S 2089.35 E 2447438.49 N 202717.35 E 0.023 3250.17 7600.00 30.526 6610.12 6700.12 2531.73 S 2122.72 E 2447400.07 N 202750.72 E 0.839 3301.04 7700.00 32.296 695.59 6785.59 2571.39 S 2156.20 E 2447360.41 N 202784.20 E 1.824 3352.91 7800.00 32.382 6780.01 6870.01 2611.43 S 2191.84 E 2447320.37 N 202819.84 E 0.961 3406.51 7900.00 32.641 6864.34 6954.34 2650.70 S 2228.54 E 2447281.10 N 202856.54 E 0.571 3460.25 8000.00 32.458 134.661 6948.65 7038.65 2689.07 S 2266.21 E 2447242.73 N 202894.21 E 0.988 3513.99 8100.00 32.595 133.874 7032.93 7122.93 2726.59 S 2304.79 E 2447205.21 N 202932.79 E 0.445 3567.71 .~. 8200.00 32.295 133.940 7117.32 7207.32 2763.81 S 2343.44 E 2447167.99 N 202971.44 E 0.303 3621 .25 8300.00 31.971 133.760 7202.00 7292.00 2800.68 S 2381.75 E 2447131.12N 203009.75 E 0.337 3674.32 8400.00 31.945 133.800 7286.93 7376.93 2837.06 S 2420.03 E 2447094.74 N 203048.03 E 0.034 3726.98 8500.00 32.140 134.507 7371 .57 7461 .57 2874.37 S 2458.02 E 2447057.43 N 203086.02 E 0.423 3780.14 8600.00 31 .536 133.536 7456.51 7546.51 2910.99 S 2496.01 E 2447020.81 N 203124.01 E 0.792 3832.81 8700.00 30.919 133.205 7542.04 7632.04 2946.53 S 2533.73 E 2446985.27 N 203161.73 E 0.640 3884.48 8800.00 30.422 134.292 7628.06 7718.06 2981.62 S 2570.72 E 2446950.18 N 203198.72 E 0.744 3935.33 8900.00 30,193 135.933 7714.43 7804.43 3017.38 S 2606.24 E 2446914.42 N 203234.24 E 0.859 3985.69 13 August, 2002 - 10:37 Page 4 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: Redoubt Unit #5 Revised: 13 August, 2002 Cook Inlet Alaska Osprey Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Comment (ft) (ft) (ft) (ft) (ft) 9000.00 29.678 136.326 7801 .02 7891 .02 3053.56 8 2640.79 E 2446878.24 N 0.551 4035.70 9100.00 29.131 135.954 7888.17 7978.17 3088.93 S 2674.75 E 2446842.87 N 0.577 4084.72 9200.00 28.343 135.617 7975.82 8065.82 3123.43 S 2708.33 E 2446808.37 N 0.804 4132.84 9300.00 28.906 134.773 8063.68 8153.68 3157.32 S 2741.95 E 244677 4.48 N 0.693 4180.53 9400.00 29.593 135.331 8150.93 8240.93 3191.868 2776.52 E 2446739.94 N 0.739 4229.35 '~ 9500.00 30.027 136.091 8237.70 8327.70 3227.45 S "f#2446704.35 N 203439.23 E 0.576 4279.03 9600,00 31 .160 136.171 8323.74 8413.74 3264;19 S '.' 2446667.61 N 203474.54 E 1.133 4329.97 9700.00 31.157 135.988 8409.31 8499.31 33ð1!ít8.S 2446630.32 N 203510.41 E 0.094 4381.70 9800.00 31.121 135.716 8494.90 8584.90 3338.50 S 2446593.30 N 203546.53 E 0.145 4433.39 9900.00 31.020 136.491 8580.55 8670.55 3375.80 S 2446556.00 N 203582.21 E 0.412 4484.99 10000.00 30.858 136.320 8666.31 3412.94 S 2989.78 E 2446518.86 N 203617.78 E 0.184 4536.40 10100.00 30.856 136.834 8752.22 .3.450.20 S 3024.86 E 2446481.60 N 203652.86 E 0.264 4587.57 10200,00 30.698 136.562 8837.98 3487.62 8 3060.15 E 2446444.18 N 203688.15 E 0.211 4639.00 10300.00 29.874 136.684 8924.38 3524.178 3094.78 E 2446407.63 N 203722.78 E 0.826 4689.34 10400.00 29.562 136.955 9011.28 3560.27 S 3128.60 E 2446371.53 N 203756.60 E 0.339 4738.80 10500.00 29.382 9098.32 9188.32 3596.27 S 3162.20 E 2446335.53 N 203790.20 E 0.180 4788.04 10600.00 29.416 9185.49 9275.49 3632.06 S 3195.68 E 2446299.74 N 203823.68 E 0.088 4837.05 10700.00 29.455 " 9272.56 9362.56 3667.82 8 3229.43 E 2446263.98 N 203857.43 E 0.164 4886.21 10800.00 29.299 9359.69 9449.69 3703.43 S 3263.21 E 2446228.37 N 203891.21 E 0.181 4935.28 10900.00 28.502 9447.18 9537.18 3738.768 3296.33 E 2446193.04 N 203924.33 E 0.816 4983.70 11000.00 27.714 137.089 9535.40 9625.40 3773.24 S 3328.40 E 2446158.56 N 203956.40 E 0.788 5030.79 11100.00 27.753 137.609 9623.94 9713.94 3807.41 S 3359.90 E 2446124.39 N 203987.90 E 0.245 5077.26 ~ 11200.00 28.139 137.003 9712.28 9802.28 3841.71 S 3391 .82 E 2446090.09 N 204019.82 E 0.480 5124.12 11300.00 28.984 137.746 9800.14 9890.14 3876.82 S 3424.21 E 2446054.98 N 204052.21 E 0.917 5171.88 11400.00 29.132 137.781 9887.52 9977.52 3912.81 8 3456.92 E 2446018.99 N 204084.92 E 0.148 5220.51 11500.00 28.894 138.762 9975.01 10065.01 3948.83 S 3489.28 E 2445982.97 N 204117.28 E 0.532 5268.93 ST Exit @ 12.0000/100ft, 9.50° Left TI 11500.00ftMD,1 0065.01 ftTVD 13 August, 2002 - 10:37 Page 5 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: Redoubt Unit #5 Revised: 13 August, 2002 Cook Inlet Alaska Osprey Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northin9s Eastin9s Comment (ft) (ft) (ft) (ft) (ft) RU#5A WP02 11520.00 31 .263 138.000 9992.32 10082.32 3956.32 S 3495.94 E 2445975.48 N 12.000 5278.95 Begin Dir @ 4.0000/100ft: 11520.00t MD, 10082.32ft TVD 11600.00 34.463 137.979 10059.51 10149.51 2445943.23 N 204152.99 E 4.000 5322.36 ~ 11700.00 38.463 137.957 10139.91 10229.91 2445899.10 N 204192.77 E 4.000 5381.78 11800.00 42.463 137.939 10215.98 10305.98 2445850.92 N 204236.23 E 4.000 5446.66 11900.00 46.463 137.923 1 0287.33 10377 .33 .. 2445798.93 N 204283.15 E 4.000 5516.69 12000.00 50.463 137.909 10353.63 2445743.39 N 204333.31 E 4.000 5591.53 12100.00 54.463 137.897 10414.55 2445684.56 N 204386.46 E 4.000 5670.81 12200.00 58.463 137.886 10469.78 2445622.74 N 204442.34 E 4.000 5754.14 12300.00 62.463 137.876 10519.07 2445558.22 N 204500.68 E 4.000 5841.13 12345.76 64.294 137.871 10539.57,. 2445527.88 N 204528.12 E 4.000 5882.03 End Dir, Start Sail @ 64.294° : 12345.76ftMD,1 0629.57ftTVD 12400.00 64.294 137.871 10563.10 4440.17 S 3932.90 E 2445491 .63 N 204560.90 E 0.000 5930.90 12500.00 64.294 137.871 10606.48 4506.99 S 3993.34 E 2445424.81 N 204621 .34 E 0.000 6021.01 12600.00 64.294 10649.85 4573.82 S 4053.78 E 2445357.98 N 204681.78 E 0.000 6111.11 12700.00 64.294 10693.23 4640.64 S 4114.22 E 2445291.16 N 204742.22 E 0.000 6201.21 12800.00 64.294 0736.60 4707.46 S 4174.66 E 2445224.34 N 204802.66 E 0.000 6291 .31 12900.00 64.294 10779.98 10869.98 4774.29 S 4235.10 E 2445157.51 N 204863.10 E 0.000 6381.42 13000.00 64.294 10823.36 10913.36 4841 .11 S 4295.54 E 2445090.69 N 204923.54 E 0.000 6471.52 13100.00 64.294 10866.73 10956.73 4907.94 S 4355.99 E 2445023.86 N 204983.99 E 0.000 6561.62 13200.00 64.294 10910.11 11000.11 4974.76 S 4416.43 E 2444957.04 N 205044.43 E 0.000 6651.72 --" 13300.00 64.294 10953.48 11043.48 5041.58 S 4476.87 E 2444890.22 N 205104.87 E 0.000 6741.83 13400.00 64.294 137.871 10996.86 11086.86 5108.41 S 4537.31 E 2444823.39 N 205165.31 E 0.000 6831 .93 13500.00 64.294 137.871 11040.23 11130.23 5175.23 S 4597.75 E 2444756.57 N 205225.75 E 0.000 6922.03 13600.00 64.294 137.871 11083.61 11173.61 5242.06 S 4658.19 E 2444689.74 N 205286.19 E 0.000 7012.13 13700.00 64.294 137.871 11126.99 11216.99 5308.88 S 4718.63 E 2444622.92 N 205346.63 E 0.000 7102.23 13800.00 64.294 137.871 11170.36 11260.36 5375.70 S 4779.07 E 2444556.10 N 205407.07 E 0.000 7192.34 13 August, 2002 -10:37 Page 6 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: Redoubt Unit #5 Revised: 13 August, 2002 Cook Inlet Alaska Osprey Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Comment (ft) (ft) (ft) (ft) {ft} {ft} (ft) 13900.00 64.294 137.871 11213.74 11303.74 5442.53 S 4839.51 E 2444489.27 N 0.000 7282.44 14000,00 64.294 137.871 11257.11 11347.11 5509.35 S 4899.95 E 2444422.45 N 0.000 7372.54 14100.00 64.294 137.871 11300.49 11390.49 5576.18 S 4960.39 E 2444355.62 N 0.000 7462.64 14200.00 64.294 137.871 11343.86 11433.86 5643.00 S 5020.83 E 2444288.80 N 0.000 7552.75 14300.00 64.294 137.871 11387.24 11477.24 5709.82 S 5081.28 E 2444221.98 N 0.000 7642.85 ~ 14400.00 64.294 137.871 11430.62 11520.62 2444155.15 N 205769.72 E 0.000 7732.95 14500.00 64.294 137.871 11473.99 11563.99 2444088.33 N 205830.16 E 0.000 7823.05 14600.00 64.294 137.871 11517.37 11607.37 2444021.50 N 205890.60 E 0.000 7913.16 14700.00 64.294 137.871 11560.74 11650.74 2443954.68 N 205951.04 E 0.000 8003.26 14800.00 64.294 137.871 11604.12 11694.12 2443887.86 N 206011.48 E 0.000 8093.36 14900.00 64.294 137.871 11647.50 11737.50 5443.92 E 2443821.03 N 206071.92 E 0.000 8183.46 15000.00 64.294 137.871 11690.87 11780.87 5504.36 E 2443754.21 N 206132.36 E 0.000 8273.56 15100.00 64.294 137.871 11734.25 11824.25 5564.80 E 2443687.38 N 206192.80 E 0.000 8363.67 15126.00 64.294 137.871 11745.53 11835.53 5580.52 E 2443670.01 N 206208.52 E 0.000 8387.10 Begin Dir @ 4.0000/100ft: 15126.00f MD, 11835.53ftTVD 15200.00 61 .346 137.564 11779.32 11869.32 6310.49 S 5624.80 E 2443621.31 N 206252.80 E 4.000 8452.91 15280,73 58.132 1~)Z+?08\!11820.00 11910.00 6361.80 S 5672.00 E 2443570.00 N 206300.00 E 4.000 8522.63 End Dir, Start Sail @ 58.132° : 15280.74ftMD,11910.00ftTVD Target - RU#5A Top Hemlock, Curren1 Target 15300.00 58.132 137.208 11830.1 7 11 920.17 6373.81 S 5683.12 E 2443557.99 N 206311.12 E 0.001 8539.00 Begin 6-3/4" Hole 7 5/8" Liner 15400.00 58.132 137.208 11882.97 11972.97 6436.13 S 5740.81 E 2443495.67 N 206368.81 E 0.000 8623.92 .-..-/ 15500.00 58.132 137.208 11935.77 12025.77 6498.45 S 5798.51 E 2443433.35 N 206426.51 E 0.000 8708.85 15600.00 58.132 137.208 11988.56 12078.56 6560.77 S 5856.20 E 2443371.03 N 206484.20 E 0.000 8793.77 15700.00 58.132 137.208 12041 .36 12131.36 6623.09 S 5913.90 E 2443308.71 N 206541 .90 E 0.000 8878.70 15800.00 58.132 137.208 12094.15 12184.15 6685.42 S 5971 .59 E 2443246.38 N 206599.59 E 0.000 8963.62 15900.00 58.132 137.208 12146.95 12236.95 6747.74 S 6029.29 E 2443184.06 N 206657.29 E 0.000 9048.55 16000.00 58.132 137.208 12199.75 12289.75 6810.06 S 6086.98 E 2443121.74 N 206714.98 E 0.000 9133.47 16100.00 58.132 137.208 12252.54 12342.54 6872.38 S 6144.68 E 2443059.42 N 206772.68 E 0.000 9218.39 13 August, 2002 - 10:37 Page 7 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: Redoubt Unit #5 Revised: 13 August, 2002 Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 16200,00 58.132 137.208 12305.34 12395.34 16300.00 58.132 137.208 12358.13 12448.13 16400.00 58.132 137.208 12410.93 12500.93 16500.00 58.132 137.208 12463.73 12553.73 16600.00 58.132 137.208 12516.52 12606.52 16700.00 58.132 137.208 12569.32 12659.32 16800.00 58.132 137.208 12622.11 12712.11 16900.00 58.132 137.208 12674.91 12764.91 17000.00 58.132 137.208 12727.71 12817.71 17100.00 58.132 137.208 12780.50 12870.50 17117.99 58.132 137.208 12790.00 Local Coordinates Northings Eastings (ft) (ft) 6934.70 S 6997.02 S 7059.34 S 7121.66 S 7183.98 S 6202.37 E 6260.06 E 6317.76 E 6375.45 E 6433.15 E 7246.30 S 7308;.63 S 737b))95S 7433.27 S 7495.59 S 7506.80 S 6732.00 E All data is in Feet (US) unless otherwise stated. tions and coordinates are relative to Grid North. Vertical depths are relative to Well, Northings and tings are relative to Well. Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot. Grid Convergence at Surface is -1.457°. Coordinate System is NAD Global Coordinates Northings Eastings (ft) (ft) 2442997.10 N 2442934.78 N 2442872.46 N 2442810.14 N 2442747.82 N .2442685.50 N 2442623.17 N 2442560.85 N 2442498.53 N 2442436.21 N 2442425.00 N 206830.37 E 20f?;~ß8.06 E 206945.76 E 207003.45 E 207061.15 E 207118.84 E 207176.54 E 207234.23 E 207291 .93 E 207349.62 E 207360.00 E laska State Planes, Zone 4, US Foot. Magnetic Convergence at Surface is -21.940° (12-Aug-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 137.650° (Grid). Based upon Minimum Curvature type calculations, at a Measured Depth of 17117 .99ft., The Bottom Hole Displacement is 1 0083.25ft., in the Direction of 138.115° (Grid). 13 August, 2002 - 10:37 Page 8 of 10 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Cook Inlet Osprey rtical Section Comment 9303.32 9388.24 9473.17 9558.09 9643.02 ~ 9727.94 9812.86 9897.79 9982.71 10067.64 0.000 10082.92 Total Depth: 17117.99ftMD,12880.00ftTVD 51/2" Liner Target - RU#5A TD, Current Target ~j Dri/IQuesf 2.00.09.006 Alaska Comments Measured Depth (ft) 11500.00 11500.00 11520.00 12345.76 15126.00 15280.74 15300.00 17117.99 Casing details Sperry-Sun Drilling Services Proposal Report for Plan: Redoubt Unit #5 Revised: 13 August, 2002 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10065.01 10065.01 10082.32 10629.57 11835.53 3948.83 S 3948.83 S 3956.32 S 4403.92 S 6261.79 S 11910.00 11920.17 12880.00 6361.80 S 6373.81 S 7506.80 S Fro m Measured Vertical Depth (ft) <Surface> 15300.00 13 August, 2002 - 10:37 11920.17 12880.00 3489.28 E 3489.28 E 3495.94 E 3900.12 E 5580.52 E Begin 8-1/2" Hole ST Exit @ 12.000°/1000, 9.50" Left TF : 1r500.00ftMD,1 0065.01ftTVD Begin Dir @ 4.000°/1000 : 11520.00ft MD, 1 0082.32ft TVD End Dir, Start Sail @ 64.294° : 12345.76ftMD,10629.57ftTVD Begin Dir @ 4.0000/100ft : 15126.00ft MD, 11835.53ft TVD End Dir, Start SãfP@ 58.132°: 15280.74ftMD,11910.00ftTVD ¡gin " Hole ,tal D h : 17117.99ftMD,12880.00ftTVD 5672.00 E 5683.1¡~IE 6732.00 E Casing Detail 7 5/8" Liner 51/2" Liner Page 9 of 10 Cook Inlet Osprey '~ " '-~' Dri//Quest 2.00. 09.006 Alaska Sperry-Sun Drilling Services Proposal Report for Plan: Redoubt Unit #5 Revised: 13 August, 2002 Targets associated with this well path Target Name RU#5A TD Mean Sea Level/Global Coordinates: Geographical Coordinates: RU#5A Top Hemlock 13 August, 2002 - 10:37 Mean Sea Level/Global Coordinates: GéOgraphiCal CðØfâinates: Page 100t 10 7506.80 S 6732.00 E 2442425.00 N 207360.00 E 600 40' 31.4171" N 1510 37' 55.5610" W 11910.00 11820.00 6361.80 S 5672.00 E 2443570.00 N 206300.00 E 60040' 42.4294" N 151038' 17.4062" W Cook Inlet Osprey Target Target Shape Type Point Cu rrent Target Point Cu rrent Target ~ '..-" DrillQuest 2.00.09.006 All DIMENSIONS ARE APPROX. 19.50" 80.68- lB.6Y 28.00- 24.75" ) ') REDOUBT UNIT #5A WELLHEAD SCHEMATIC t--24.31-- C~J ~ 3-1/8 ~ ~~- !~L 13-5/8 5000 6BX ! II AUGNMENT PIN SHOWN 90' OUT OF POSIllON - ::E- ~ ~ 36- 00 CASING ~ ~ 13-3/8" 00 CASING ~9-5/8. 00 CASING ) ) Nabors Rig 429 13-5/8" 5000 psi BOP Stack Redoubt Unit #5A (' '\ 5000 psi Annular ~ ) 5000 psi Blind Rams 5000 psi Pipe Rams 3" Kill Line =:r><:I><C Mud Cross ~ 3" Choke Line 1 2 2 1 1 = HCR Valve 2 = Gate Valve 5000 psi Pipe Rams \ / 13 5/8" 5M ~ Wellhead =t><] 13-3/8" Surface Casing 9-5/8" Intennediate ) BLOWOUT PREVENTION EQUIPMENT NABORS RIG No . 429 13-5/8" BOP Equipment 3 ea 13-5/8" x 5000 psi wp ram type preventers (Hydril) 1 ea 13-5/8" x 5000 psi wp annular preventer (Hydril) 1 ea 13-5/8" x 5000 psi wp drilling spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on both choke and kill lines. 1 ea BOP accumulator, Koomey Model T20000-3S blowout preventer control unit with 280 gallon volume tank, main energy provided by two 20 HP electric motor driven triplex plunger pump charging 16 each II-gallon bladder type separate accumulator bottles. Second energy charging system consists of two air pumps. Above two energy systems backed up by six each 220 cubic feet nitrogen bottles connected to the manifold system. All above system controlled by a Model SU2KB7S S series manifold with six manual control stations at the unit. ) ") DRILLING FLUID SYSTEM DESCRIPTION Mud Pumps 2 ea IDECO T1600 (triplex, single acting pistons), 5000 psi fluid end discharge manifold system. Gear end equipped with electric driven lube oil pump, filtration. Pumps are driven by two each traction motors designed to stroke pumps at a maximum of 120 SPM under full load. Pumps are charged by two 40 HP, 1200 RPM Mission 5" x 6" centrifugal pumps. Mud Tank System (975 bbls Total Volume) Tank #1 (desander tank) appx. 170 bbls. Tank #2 (mud cleaner tank) appx. 145 bbls. Tank #3 (centrifuge tank) appx. 145 bbls. Tank #4 (suction tank) appx. 44 bbls. Tank #5 (pill tank)appx. 44 bbls. Tank #6 (volume tank) appx. 430 bbls. Trip Tank appx. 40 bbls~ Located in the substructure. Mud System Equipment 3 ea 1 ea 1 ea 3 ea 2 ea 3 ea 1 ea 1 ea 1 ea Derrick dual tandem shale shakers Derrick 20 cone desilter Geosource sidewinder mud hopper Brandt 15 HP mud agitators Brandt 5 HP mud agitators Mission Magnum pumps, 6" x 8" centrifugal with 100 HP motors Mission Magnum pump, 4" x 5" centrifugal with 25 HP motor DEMCO desander, two 12" cones Brandt Model CF- 2 centrifuge ~ 1326 t ~ ~ I FOREST OIL CORPORATION t ~ PH. 907-258-8600 f .~ 310 K ST. STE. 700 ~. ~ ANCHORAGE, AK 99501 89-6/1252 ¡ I DATE 8/13/02 ~ f pø " r . ~ TO THE NV"'f"V"' I $..,'..", loa 00 1. ~ l' ORDER OF ~\... '.'. ~ ~i I ~,~ One Hundred and< 00/100 ------------------------------------:-------------- 0. =,'0"'''' f .. . /' DOLLARS I.!J 001,,,,,"-, , ~'i' F,irstN,' ationalBank ' " íl~ 'L,,/' /.1 ~, ., , i ~ ~ of Anchorage ~~ ~4--- I :; RU #5 .t to drill 'z1., ~ ~¿ ;" i i , .iJ~ ,,' M'~, i FOR , --- -- -- . --- ~J_---------------- t ~ 11100 ~ 3 2 b III ; ': ~ 2 5 2 000 b 0 I: 0 2 ~ ~ ~ ~ :II ~ " .. ¡. .L l'J.YifiiiiiJiJ;j{'¡1!'!~~\\\\'''''''''~"!!~l1Jll!j1fi~_~~\~'''\\\''i''¡;'ýj~Ufjli/I~~'''~~"-\\\'\~W!i.ijiþl!1i/ii!;~ -,,!!,~\\'\¥..UWNIldJ1!f¡?J~~~~~"'~~~/~?J!ß!/'L~~-~-~'\\'\U(~'J..?A~,!IH'~!;._~ ~_':..\I:,\~U'W~(':'¡lIil¡i!1:~ ~~~'\~~\"~'lij>~jll!ßJ!;'~~ï:.~\~\'~\~l!f~~~~Jlr"~t!\"' -~_::'\~,\~\'§"'VQmJi¡i/~-~ ~~\\'\\\U'Þ'A'U1U1JJIt'JI!;......~~~-;.¡i~liìi~ ~ E~ A¡' I,'" 'ì 7 (')0"1"') !-), ,h .', ¡ , ¡,1~, 9 ..;.,...' 'V - L tis k", ,-.' Alaska 011& Gons. GmmmSSIO!r Anchoraae ~~. ~v L 1'\111 10f2 ;:II 1"\1 'gO . ~) ~ Subject: Re: RU 2 Annular Disposal Area Date: Wed, 21 Mar 200117:37:31 ..0900 from: Julie Heusser <julie_heusser@admin.state.ak.us> To: JackHa.~~j~ck_hartz@aclmin.state.ak.us> CC: Robert Crandall <Bob_Crandal1@admin.state.ak.us>, "Maunder, Thomas" <tom_maunder@admin.state.ak.us> Thanks Jack. Looks like we're head for approval of annular disposal down RU #2. Julie Jack Hartz wrote: > Bob, > You captured well the essence of the situation. As we discussed, the > likelihood of fluids breaking through to RU-l is very low. The pump test > clearly shows a sand broke down and was taking the fluids in the test. > > Jack > > Robert Crandall wrote: > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > Tom: > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > You have asked me to estimate the likely hood that annular disposal in RU 2 will break through to RU 1. Factors to consider in the assessment of this probability are: 1) Could a high perm (fault related) zone exist between the two wells? This is very unlikely because we required a high resolution geophysical survey of the platform location for shallow drilling hazards prior to approval of the drilling permits. This analysis showed no significant faults in the shallow section. 2) The surface shoe leak off test had a frac gradient of .81 psi/ft. the lithology was siltstone. The pump in test with 4000' of sand rich Tyonek open was .69 psi/ft. .69 psi/ft is consistent with a sand frac gradient and is somewhat higher than expected for a coal with good cleat development, of the type known to exist within the Tyonek. This apparent inconsistency is justifiable in consideration of the coal inhibiting mud additives used in the Cook Inlet. These additives are designed to lock up coals and are effective at doing so. On balance the indications are that that the disposal fluids will frac a very porous and permeable sand face and leak off into the matrix. Hundreds feet of highly porous Tyonek sands are exposed in the wellbore, under these assumptions the disposal fluid will be concentrated in a few tens of feet around RU 2. The possibility exists that a coal could break down in which case the disposal fluids may spread a considerable distance from the well. Annulus pressures in RU 1 should be monitored throughout the disposal operations and disposal operations halted if anomalous pressures are observed. Pumping pressures in RU 2 should be restricted to a value less than the leak off pressure at the shoe, the higher the disposal pressures the greater the likelihood of breaking down a coal. 3121/01 5:38 PM ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~R-hS. r 2O<¿-/&,8 CHECK WHAT APPLIES ,.- // / ¡ Rev: 07/10/02 C\jody\templates PTD# ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE "CLUE" The permit is for a new wellbore segment of existing well 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(1), 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). The permit is approved subject to full comJ}liance with 20 AAC 25.055. Approval to ~ produce is contingent upon issuänce of a conservation orde~pproying a spacing exception. r~ .¡-- (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample'sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. i2e.&Jcvh+ ' , WELL PERMIT-CHECKLIST COMPANY ~ti? ~ WELL NAME ,1.n tl- SA PROGRAM: Exp ../" Dev - Redrll ~ Re-Enter - Serv - Wellbore seg - FIELD & POOL 77 j") Ir:o INITCLASS E>Gp<... (Oì L. - Ì)eji~¿'~AREA B Z/") UNIT# 0/ I~I () ON/OFF SHOREQa;- ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ~N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N . 3,.uniq,uewell~a,meandnumber."""""."",. ~','t", '""",.Jð!I" "I ~ ,,'_.l"{--£J~¿J,/~¡ n ' . ",,/1104- e:;/~~, 4. We~llocated In a defined pool.. . . . . . . . . . . . . . . . .'- . ~-- ~ ~ ¡c....e ~ F ..!:J =t ,,& 5. Welt located proper distance from drilling unit boundary. . . . Y , N .. 6. Well located proper distance from other wells.. . . . . . . .. ~., , II . -- L . n I J /J / / A J APPR DATE 7. Sufficientacreageavaitableindrillingunit............ ," N.'..,-ti~ ÎA.Yt'lt hA- ~ ~ ~/-( ~~~:r-Í({~"""" V,:'\ /)), 0 ":':> 8. If,deviated, is wellbore plat in,cluded.. . . . . . . . . . . . . . ,~ NtV Y'¡ .fl" ~,50J ,77, N, ).' f<!..' 34, ' 3 Lù. ~" 2£JA'*- ¿ç.ö~ J-.'!>--1. ~ ~..D L 9. Operator only affected party.. . . . . . . . . . . . . . . . . . . N ~ s~a C-~4 ..R~ ~.(l;O y-Ía+... ~ 1"2~~;I~" ~<f(, ¡~ ,õ7.. ,f'/~ ) , 10. Oper~torhas~ppropria~ebondinforce... . . . . . . . . '" ~. fdt tJlùi¿/J~7 J¡{ ~(d"'r.":¡: (Í¿"'~/fry~<¿<:-"d~pf,.ñ... 11. Permit can be Issued without conservation order. . . . . . . . N..'" I "A'D 12. Permit can be issued without administrative approval.. . . . . N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #_-:-Y x, y (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. ¡V¥ N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . Y N ~ . 16. Surface casing protects all known USDWs. . . . . . . . . . . Y N S. ~,.,L - "- 0 ~<t- ~ \'\ "'-\.. ~<t \ ( 17. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N'~ ~,...",.. ~ 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y N 19. CMT will cover all known productive horizons. . . . . . . . . . I,' N 20. Casing designs adequate for C: T, B & permafrost. . . . . . . , Y , N ',.,' . , '(. ~~ 21. Adeq,uate tankage or reserve pit.. . . . . . ,. . . . . . . . . . ,Y , N Q...'\,..,\~~~ '" '" ~ ~~c::c.",Q ~\ 22. If a re-drill, has a 10-403 for abandonment been approved. . . N ,~ \\ 23. Adequate wellbore separation proposed.. . . . . . . . . . . . Y N 24. If diverter required, does it meet regulations. . . . . . . . . . ~:¥-N- ~.'" 25. Drimng fluid program schematic & equip list adequate. . . . . IN 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . " Y N "', ~A PP. R D"ATE 27. BOPE press rating appropriate; testto ~ psig. N '--'~~Ç> Ct.<;.:~. Q. \S-<Jjp~ \ ~ ~ 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N ~ . -, t '/l'~~7> 29. Work will occur without operation shutdown. . . . . . . . . . . c:. I ~ 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y (&) (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . Y N \.:J ~ GEOLOGY " 32. Permit can be issued wlo hydrogen sulfide measures. . . .. /"y-'),J.-f1 J~ ~ ¿ c, Jþ, ' wJI ~,ltR ~-~ ~ ~,D' , APPR DATE 33. Data~resented.onpotentialovelJ!ressurezones. . . . , , . . ~ tl4l-ft-,rn., ~ .Lv~ tf ~S' / "('D ~/3.D2--~: ~:~~ :~~:~no:~~:~(~~~~s~~:)~.. '. .. .. .. ., ., '. .. '. '. '. '~A y ~ ¿r? cd.-r.hnlJ ~ ~ ~ ~ ~ ~ (Ê';¡;loratory Only) 36. Contact name/phone for weekly progress reports. . . . . /' Y N ~ ~lta.- (/ ~ '~' ,.0 ð . GEOLOGY: PETROLEUM EN~INEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Commentsllnstructions: RPC- TEM ð~<tSf\3 JDH JBR COT DTS 0 b J 1-:; / 0 ¿ ) Rev: 07/12/02 SF~ WGA MJW G:\geology\permits\checklist.doc ) ') Well History File APPENDIX Infonnation of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. infonnation of this nature is accumulated at the end of the file under APPEN.DIX. No special. effort has been made to chronologically organize this category of information. Core LaI:Ï RESERVOm DPTIKIZATIOJí ) SPECIAL CORE ANALYSIS STUDY Redoubt 5A Unit Well Redoubt Shoals Field Cook Inlet, Alaska FINAL REPORT Performed for: Forest Oil Company 310 K Street Anchorage, Alaska 99501 August 28, 2003 File: 57111-2002-025 (SCAL) 57111-02144 (Routine) Performed by: Core Laboratories Advanced Rock Properties 3430 Unicorn Road Bakersfield, California 93308 661-392-8600 ) l ". / (\) 0Cì ~..-- 00 PETROLEUM SERVICES ) ) Core Lab RESERVOIR DPTIKIZATIDN PETROLEUM SERVICES August 27, 2003 Forest Oil Company 301 K Street Anchorage, Alaska 99501 Attention: Mr. Paul Winslow and Art Saltmarsh Subject: Special Core Analysis Final Report Redoubt 5A Unit Well Redoubt Shoals Field Cook Inlet, Alaska Gentlemen: Presented herein are the final results of the special core analysis study conducted on samples from the subject site. A discussion of the test results follows this letter. A detailed set of test procedures and the final data is then provided. Thank you for this opportunity to be of service to Forest Oil Company. Please do not hesitate to contact us (661 3928600) if you have any questions regarding these results. Yours sincerely, Wade Williams Supervisor - Advanced Rock Properties Core Laboratories, Inc. 3430 Unicorn Road, Bakersfield, California 93308, (661) 392-8600, Fax (661) 392-0824 ') Core LaI:Ï RESERVOm OPTIKIZATInN DISCUSSION OF TEST RESULTS Fi1e# 57111-2002 025 PETROLEUM SERVICES Wettability Analyses Wettability analyses were performed on 3 wettability-restored samples. The modified USBM wettability method was utilized for the testing. In this method, two sets of indices are calculated: Arnott and USBM. Sample 5,15429.2', had a 0.235 Arnott index to water and a 0.000 Arnott index to oil. The USBM index was -0.064. The implication from this data is that the core is intermediate to slightly water-wet. Sample 26, 15450.5', had a 0.375 Arnott index to water and a 0.000 Arnot index to oil. The USBM index was 0.893. The data on this sample suggests moderately water-wet behavior. Sample 45, 15469.5', had a 0.188 Arnott index to water and a 0.000 Arnot index to oil. The USBM index was 0.139. The data on this sample suggests slightly water-wet behavior. It can be concluded from the above data the core is water-wet, though the cores wetting strength is higher in some cores than others. Electrical Properties Seven samples were initially selected for testing. One of the selected samples could not be de saturated due to low permeability, so data was provided for 6 samples. Three samples were tested with 9000 ppm brine and 3 samples were tested with 30000 ppm brine. On the 6 sample set, cementation exponent (m) averaged 1.76. Saturation exponent (n) averaged 1.54. (m) and (n) averages calculated separately using the two different brines were very similar. This indicates (m) and (n) should be constant through 9000 and 30000 ppm brine salinity range, assuming the anion and cations concentrations do not change significantly. This data should be corrected for CEC due to the high clay content of the cores. ) ) Core LaI:Ï RESERVOm OPTIKIZATIDN EXPERIMENTAL PROCEDURES File# 57111-2002 025 PETROLEUM SERVICES Fluid Preparation All synthetic brines were formulated using reagent grade chemicals and deionized water evacuated of air. The brines were evacuated and filtered through a 0.2 micron filter. Stock tank crude oil was provided by Forest. The oil was dewatered and filtered through a 0.45 micron filter prior to use. Density of the fluids was determined using a pycnometer. Sample Preparation The samples selected for testing were chosen from the routine properties sample set. These plugs had previously been extracted of hydrocarbons, leached of salts, and dried. Routine properties were measured at a minimal confining stress of 800 psi. Prior to special core analysis testing, routine properties were remeasured at the reservoir confining stress of 3800 psi. Wettability Analysis The samples were saturated with synthetic formation brine. The samples were then flushed with the synthetic formation brine to assure 100% saturation, loaded into the high speed centrifuge, and spun under crude to initial water saturation at 1600 F. A maximum capillary pressure of 200 psi was used for the displacement. The samples were allowed to age in the crude oil at 1600 F. for 3 weeks. The samples were unloaded, and reloaded in a brine-displacing-oil configuration for the imbibition step. The samples were placed in a high speed centrifuge preheated to 1600 F. and spun at a very low rpm (0.3 psi) for 72 hours to obtain the pseudo-spontaneous data need for Amott index calculation. Capillary pressure was increased to 5 psi and centrifuging continued at several additional pressures up to 200 psi. The sample was unloaded, and reloaded in a oil-displacing-brine configuration for the drainage step. The sample was spun at a very low rpm (0.3 psi) for at 72 hours to obtain the pseudo-spontaneous data need for Amott index calculation. Capillary pressure was increased to 5 psi and centrifuging continued at several additional pressures up to 200 psi. ') ') Ü1re LaI:Ï RESERvam OPTIKIZATIDN File# 57111-2002 025 PETROLEUM SERVICES The samples were unloaded and submitted for Dean-Stark extraction. After additional soxhlet cleaning with methylene chloride and methanol, each sample was dried to constant weight at 60° C. Amott and USBM indices were calculated using the measured data. Electrical Properties Measurements The samples were evacuated of air and pressure saturated with the appropriate synthetic formation brine. The samples were loaded into a hydrostatic coreholder at 3800 psi and resistance measured at net confining stress. Several pore volumes of the brine were injected through the samples daily and resistance measured until a less than 1 % change is observed. Formation resistivity factor was calculated Each porous plate, saturated with the test brine, was loaded into a hydrostatic core holder at 3800 psi net confining stress and its resistance at stress was measured. The sample & porous plate were then loaded into the core holder at 3800 psi net stress. They were reflushed with brine using a 500 psi back pressure to ensure complete saturation. Resistivity was measured, followed by injection of several pore volumes of brine. The resistivity was measured again the following day until stabilized (less than 1% change per day). Formation resistivity factor (FRF) at stress was determined at this point. The samples were de saturated beginning at 10 psi by inj ecting humidified air at a regulated capillary pressure. The volume and weight of displaced brine were monitored and used to calculate brine saturation. Desaturation continued in a "step wise" manner until a final capillary pressure of 150 psi was achieved. At the end of the test, each sample was removed and its weight out was measured. It was Dean-Stark extracted for water, methanol soxhlet extracted for salts, and dried to a constant weight in a vacuum oven at 60°C. The fmal dry weight was measured. Dean-Stark water extracted was used to confIrm the final water saturation . Core Lab Summary of Modified USBM Wettability Analyses Temperature: Ambient, Net Confining Stress = 800 psi, Wettability Restored Samples File: 57111- 02 025 PETROLEUM SERVICES Forest Oil Company Redoubt SA Well Redoubt Shoals Unit Alaska WE1'.1'.ABIUTYANALYSIS Perm Amott WettabiIity Analysis Harvey USBM Wettability Sample Depth to Air Porosity Index to Water Index to Oil Amott Area under the Curve USBM Apparent ~ # feet md fraction Spont. ** I Total ** I Index Spont. ** I Total ** Index Index Water Drive I Oil Drive Index W ettability 5 15429.2 15.6 0.130 0.270 1.15 0.235 0.000 0.740 0.000 0.235 3.65 3.15 -0.064 Intermediate to Slightly Water-Wet 26 15450.5 0.196 0.099 0.090 0.240 0.375 0.000 0.120 0.000 0.375 0.624 4.88 0.893 Moderately Water-Wet 45 15469.5 5.87 0.136 0.150 0.800 0.188 0.000 0.540 0.000 0.188 2.49 3.43 0.139 Slightly Water-Wet Notes: I. Amott Indices for oil or water are given by the ratio of "Volume of fluid spontaneously Imbibed" to "Total volume of fluid imbibed" 2. The "Harvey-Amott Index" is the (Amott Water Index) - (Amott Oil Index). A value closer to -1 indicates oil wetness, closer to + 1 indicates water wetness, closer to "0" indicates intermediate. 3. The "USBM Index" is given by the Log of the ratio of the (Area under the Oil Drive Curve) to (Area under the Water Drive Curve). A negative value indicates oil wetness, a positive value indicates water wetness, closer to "0" indicates intermediate. 4. Spontaneous imbibition values established by spinning at low (approx. 0.2 psi) RPM over 24 hours. The "dynamic" Drive Curves were established maintaining 24 hours per Pc point .~ ;;-> C '¡J r r;- c.o Core Lab File: 57111 - 02 025 Forest Oil Company RU-5A Well Redoubt Shoals Unit Alaska Sample # 11 19 25 14 38 86 100 ~ ... ~ ca u.. C 10- ~ ca E 0 u.. 1 0.0 Depth (ft.) 15435.5 15443.5 15449.5 15438.5 15462.5 16178.5 FORMATION FACTOR & RESISTIVITY INDEX with CAPILLARY PRESSURE (by porous plate) 2- Terminal, 20,000 Hertz Grain Kair Density (md) (gl cc) 19.0 2.64 0.328 2.65 1.91 2.65 8.27 2.64 46.6 2.63 2.46 2.64 Porosity (fraction) PETROLEUM SERVICES Saturant: Resistivity of Saturant, ohm-m @25°C: Net Confining Stress, psi: Average Cementation Exponent (m): V-Intercept (a): Average Saturation Exponent (n): 30000 & 9000 ppm Synthetic Brine 0.426 & 0.634 3800 1.76 1.00 1.54 .~ Formation Factor Cementation Exponent (m) Final Brine Saturation (fraction) Resistivity Index A vg. Sat Exponent (n) (F) (I) 35000 ppm Brine 0.124 41.6 1.79 0.3 24 7.04 1.72 0.121 39.0 1.73 0.518 2.49 1.36 0.115 44.4 1.76 0.421 2.98 1.23 9000 ppm Brine 0.102 54.5 1.75 0.344 5.40 1.56 0.138 32.3 1.75 0.282 6.36 1.46 0.098 60.1 1.76 0.352 5.72 1.66 100. ~_. .~. Average Cementation Exponent 1.76 0.1 1.0 Porosity, fraction - c >< CÞ "C .E ~ 10 ~ II) ïñ CÞ 0:: '}J C ,>J ( 1 0.01 0.1 G-\) Water Saturation, Fraction .. l:are Lab File: 57111 - 02 025 Forest Oil Company RU-5A Well Redoubt Shoals Unit Alaska Sample Depth # (ft.) 11 15435.5 1000 ~ 100 >< Q) "C .E ~ ~ I/) '¡¡¡ Q) 0:: 10 1 0.01 ') ) RESISTIVITY INDEX & CAPILLARY PRESSURE (by porous plate) 2-Tenninal, 20,000 Hertz Grain Porosity Formation Cementation Saturation Brine Resistivity Density at stress Factor Exponent Exponent Saturation Index (glee) (fraction) (F) (m) (n) (fraction) (I) 2.64 0.124 41.6 1.79 1.72 1. 000 0.00 0.811 1.38 0.631 2.17 0.497 3.38 0.459 3.75 0.441 4.11 0.425 4.32 0.413 4,62 0.392 4.87 0.388 5.12 0.372 5.35 0.360 5.61 0.358 6.00 0.345 6.26 0.324 7.04 Saturant: Resistivity of Saturant, ohm-m @25°C: Net Confining Stress, psi: Kair at stress (md) 19.0 0.10 Water Saturation (fraction pore space) 1.00 PETROLEUM SERVICES 30000 ppm Synthetic Brine 0.426 3800 .. Core Lab File: 57111 - 02025 Forest Oil Company RU-5A Well Redoubt Shoals Unit Alaska Sample Depth # (ft.) 19 15443.5 1000 [ 100 >< Q) 'C .5 ~ 'S: ;; 111 iii Q) 0:: 10 1 0.01 ) ') RESISTIVITY INDEX & CAPILLARY PRESSURE (by porous plate) 2- Terminal, 20,000 Hertz Grain Porosity Formation Cementation Saturation Brine Resistivity Density at stress Factor Exponent Exponent Saturation Index (glcc) (fraction) (F) (m) (n) (fraction) (I) 2.65 0.121 39.0 1.73 1.36 1.000 1.00 0.962 1.02 0.957 1.02 0.937 1.07 0.908 1.12 0.747 1.49 0.713 1.58 0.684 1.69 0.655 1.78 0.626 1.87 0.617 1.94 0.592 2.03 0.568 2.15 0.555 2.23 0.518 2.49 Saturant: Resistivity of Saturant, ohm-m @25°C: Net Confining Stress, psi: Kair at stress (md) 0.328 0.10 Water Saturation (fraction pore space) 1.00 PETROLEUM SERVICES 30000 ppm Synthetic Brine 0.426 3800 .. I:ore Lab File: 57111 - 02 025 Forest Oil Company RU-5A Well Redoubt Shoals Unit Alaska Sample # 25 1000 $: 100 >< Q) 'C .5 ~ ~ III iii Q) 0::: 10 1 0.01 ) ) RESISTIVITY INDEX & CAPILLARY PRESSURE (by porous plate) 2-Terminal, 20,000 Hertz Grain Porosity Formation Cementation Saturation Brine Resistivity Density at stress Factor Exponent Exponent Saturation Index (glee) (fraction) (F) (m) (n) (fraction) (I) 2.65 0.115 44.44 1.76 1.23 1.000 1.00 0.811 1.27 0.756 1.40 0.649 1.68 0.637 1.74 0.582 1.93 0.560 2.01 0.545 2.12 0.515 2.23 0.501 2.33 0.490 2.40 0.479 2.49 0.452 2.65 0.441 2.73 0.421 2.98 Saturant: Resistivity of Saturant, ohm-m @25°C: Net Confining Stress, psi: Depth (ft.) Kair at stress (md) 15449.5 1.910 0.10 Water Saturation (fraction pore space) 1.00 PETROLEUM SERVICES 30000 ppm Synthetic Brine 0.426 3800 .. Core Lab File: 57111 - 02 025 Forest Oil Company RU-5A Well Redoubt Shoals Unit Alaska Sample Depth # (ft.) 14 15438.5 1000 ~ 100 Š "0 .5 ~ 'S: .. II) .¡¡¡ ~ 10 1 0.01 ') ) RESISTIVITY INDEX & CAPILLARY PRESSURE (by porous plate) 2-Tenninal, 20,000 Hertz Grain Porosity Formation Cementation Saturation Brine Resistivity Density at stress Factor Exponent Exponent Saturation Index (glee) (fraction) (F) (m) (n) (fraction) (I) 2.64 0.102 54.5 1.75 1.56 1.000 1.00 0.967 1.03 0.769 1.48 0.591 2.34 0.549 2.53 0.502 2.98 0.469 3.30 0.432 3.60 0.413 3,85 0.408 4.05 0.394 4.27 0.376 4.59 0.371 4.76 0.362 4.99 0.344 5.40 Saturant: Resistivity of Saturant, ohm-m @25°C: Net Confining Stress, psi: Kair at stress (md) 8.27 0.10 Water Saturation (fraction pore space) 1.00 PETROLEUM SERVICES 9000 ppm Synthetic Brine 0.634 3800 .. Core Lab File: 57111 - 02025 Forest Oil Company RU-5A Well Redoubt Shoals Unit Alaska Sample # 38 1000 [ 100 ~ 'C .5 ~ ~ II) .¡¡¡ Q 0:: 10 1 0.01 ') ) RESISTIVITY INDEX & CAPILLARY PRESSURE (by porous plate) 2-Tennina1, 20,000 Hertz Grain Porosity Formation Cementation Saturation Brine Resistivity Density at stress Factor Exponent Exponent Saturation Index (glee) (fraction) (F) (m) (n) (fraction) (I) 2.63 0.138 32.3 1.75 1.46 1.000 1.00 0.683 1.72 0.511 2.69 0.424 3.48 0.415 3.69 0.389 4.02 0.381 4.18 0.366 4.40 0.351 4.65 0.345 4,86 0.327 5.02 0.318 5.20 0.307 5.59 0.297 5.78 0.282 6.36 Saturant: Resistivity of Saturant, ohm-m @25°C: Net Confining Stress, psi: Depth (ft.) Kair at stress (md) 15462.5 46.6 0.10 Water Saturation (fraction pore space) 1.00 PETROLEUM SERVICES 9000 ppm Synthetic Brine 0.634 3800 .. Core Lab File: 57111 - 02 025 Forest Oil Company RU-5A Well Redoubt Shoals Unit Alaska Sample Depth # (ft.) 86 16178.5 1000 [ 100 ~ "0 .5 ~ :~ '1ii ¡ii () Q: 10 1 0.01 ~) ) RESISTIVITY INDEX & CAPILLARY PRESSURE (by porous plate) 2-Tenninal, 20,000 Hertz Grain Porosity Formation Cementation Saturation Brine Resistivity Density at stress Factor Exponent Exponent Saturation Index (glee) (fraction) (F) (m) (n) (fraction) (I) 2.64 0.098 60.1 1.76 1.66 1.000 1.00 0.723 1.71 0.663 1.99 0.598 2.36 0.588 2.43 0.538 2.87 0.518 3.04 0.482 3.32 0.457 3.61 0.437 3.91 0.422 4.14 0.412 4.33 0.382 4.92 0.371 5.17 0.352 5,72 Saturant: Resistivity of Saturant, ohm-m @25°C: Net Confining Stress, psi: Kair at stress (md) 2.46 0.10 Water Saturation (fraction pore space) 1.00 PETROLEUM SERVICES 9000 ppm Synthetic Brine 0.634 3800 ') Porosities @ Stress 15.0 -- --- -- ------- -- -- --- - --- -- - -- ------- - - -- --------- - - -- ------ -- - -- ---- -- - - - - - ------ 14.0 13.0 ----------~------------------------ ------------- -~----~----~---_.----~___~__II 12.0 I --)~ )( )( )( )( ~ .nn___----_---- .--_n_---1- ----------- ---- ---.-__-.nn,----- ;------------ 11.0 1- ------ --- ----- --- ------------- --- -- ---- -- - - - --- -- - -- -- - -- - - ---- ----",.- - ---- 1:::-----_-~ ~ l 8.0 -------------------------------~~---:---'------- }( )< ~ 1ñ e ~ 7.0 ----------- - -- - -- - -- -- --- - -- --- -- -- - --- -- - - - -- - --- ----- -- - -------- - - - --- ---- -- ---- +-- -- - - ---- -- - - - --- -- - ---- - -- - -- ----- - - ------ - - - ~ - - -- - -------- - -- -- -- -- - -- -- --- ---- 6.0 ---~ I . - -- - - - -- _--n - -- - --- - - -- -- - - - - -----. - - -- . - -- -- -- - - - -- __n - n - - L -' t - - - - - - - - -- -- I I ::: -----------~------------------ ------------- - --- -- --- --- - -- -- --- - - - -- --- - - - ---- --- - -- - -- --- -- - - -- - ---- - --- - ---- -- --- 3.0 -- -- - - -------- --- --- -- --- ----- ---- --- - - -- --- --- -- - - - -- - --- - - - - - ---- -- - - - - - - --- ---- 2.0 1,0 ----- - - -- - -- - - --- - - - - - --- -- - - - - - - - - - - - - -- - - - - - - -- - - - - - - - - - - - - - - -- -- - - - - - - - - - - - - - -- - - --- - --- - -- -- - - - --- - - - -- -- - - -- -- -- --- - -- - -- -- - -- - - ---- -- - - - -- - ---- -- -- - -- - ---- - -- 0.0 0 3000 Net 08 (psi) 4000 1000 2000 5000 ) /<()À--'G~ --+-15434.5 ---15442.5 15456.5 -*-15457.5 ~15461.5 ----15471.5 -+-15484.5 -15822.4 -16175.5 16179.2 6000 100.0000 10.0000 =ê §. ... :.;;: 1.0000 0 - E ... () a.. 0.1000 0.0100 0 ) Permeabilities @ Stress . . . & . . . )( )( )( )( )( )( ~ +--- . ~ ~ --- 1000 5000 2000 3000 4000 Net 08 (psi) ) --+-15434.5 -8-15442.5 15456.5 -*-15457.5 -*-15461.5 --e-15471.5 --+-15484.5 -15822.4 -16175.5 16179.2 6000 ') ) SUMMARY OF PERMABILITY MEASUREMENTS ;J \-> À- ( ~ g Forest Oil RU-5A Well File: 57111-02144 Grain Pore Porosity Air Klinkenberg Sample Drying Depth Length Diameter Volume Volume 1.0 Perm Perm I.D. Method em em ee ee % md md 8 Humid 15432.5 4.39 2.45 17.63 2.773 13.59 43.7 41.5 8 Dry 15432.5 4.39 2.45 17.45 2.910 14.29 44.5 42.1 0.18 0.14 0.70 11 Humid 15435.5 4.30 2.45 17.50 2.564 12.78 22.5 20.8 11 Dry 15435.5 4.30 2.45 17.34 2.712 13.53 23.6 21.7 0.16 0.15 0.75 12 Humid 15436.5 4.33 2.45 17.62 2.576 12.76 14.7 13.2 12 Dry 15436.5 4.33 2.45 17.47 2.743 13.57 15.7 14.1 0.15 0.17 0.81 17 Humid 15441.5 4.30 2.45 18.13 1.969 9.8 0.321 0.206 17 Dry 15441.5 4.30 2.45 17.89 2.216 11.02 0.394 0.252 0.24 0.25 1.22 24 Humid 15448.5 4.35 2.45 17.85 2.416 11.92 8.65 7.59 24 Dry 15448.5 4.35 2.45 17.69 2.606 12.84 9.25 8.07 0.16 0.19 0.92 25 Humid 15449.5 4.39 2.45 18.10 2.400 11.71 2.60 2.06 25 Dry 15449.5 4.39 2.45 17.94 2.594 12.63 2.88 2.26 0.16 0.19 0.92 26 Humid 15450.5 4.31 2.45 18.35 1.721 8.57 0.152 0.090 26 Dry 15450.5 4.31 2.45 18.06 2.007 10 0.203 0.120 0.29 0.29 1.43 31 Humid 15455.5 4.21 2.45 17.40 2.140 10.95 0.300 0.187 31 Dry 15455.5 4.21 2.45 17.17 2.355 12.06 0.372 0.234 0.23 0.22 1.11 36 Humid 15460.5 4.34 2.45 17.69 2.510 12.43 4.88 3.83 36 Dry 15460.5 4.34 2.45 17.51 2.695 13.34 5.43 4.26 0.18 0.19 0.91 38 Humid 15462.5 4.30 2.44 17.18 2.853 14.24 52.5 50.0 38 Dry 15462.5 4.30 2.44 17.02 2.979 14.9 53.2 50.5 0.16 0.13 0.66 40 Humid 15464.5 4.26 2.44 17.50 2.277 11.52 0.985 0.686 40 Dry 15464.5 4.26 2.44 17.30 2.481 12.54 1.151 0.797 0.20 0.20 1.02 44 Humid 15468.5 4.29 2.45 18.13 1.892 9.45 0.160 0.093 44 Dry 15468.5 4.29 2.45 17.87 2.210 11.01 0.219 0.129 0.26 0.32 1.56 ) ) SUMMARY OF PERMABILITY MEASUREMENTS Forest Oil RU-5A Well File: 57111-02144 Grain Pore Porosity Air Klinkenberg Sample Drying Depth Length Diameter Volume Volume 1.0 Perm Perm I.D. Method em em ee ee % md md 52 Humid 15476.5 4.31 2.48 19.10 0.947 4.72 0.535 0.409 52 Dry 15476.7 4.31 2.48 18.56 1 .453 7.26 0.830 0.649 0.54 0.51 2.54 59 Humid 15485.3 4.21 2.58 20.50 1.341 6.14 0.240 0.166 59 Dry 15485.5 4.21 2.58 19.90 1.998 9.12 0.413 0.298 0.60 0.66 2.98 72 Humid 16164.5 4.29 2.45 19.58 0.718 3.54 0.134 0.085 72 Dry 16164.5 4.29 2.45 19.25 1.103 5.42 0.187 0.117 0.33 0.39 1.88 76 Humid 16168.5 4.19 2.45 17.01 2.442 12.56 9.68 8.24 76 Dry 16168.5 4.19 2.45 16.95 2.561 13.13 10.2 8.64 0.06 0.12 0.57 80 Humid 16172.5 2.65 2.45 11.08 1.272 10.3 0.710 0.487 80 Dry 16172.5 2.65 2.45 11.01 1.373 11.09 0.759 0.516 0.07 0.10 0.79 82 Humid 16174.5 4.39 2.44 18.30 2.001 9.85 2.19 1.75 82 Dry 16174.5 4.39 2.44 18.19 2.145 10.55 2.17 1.72 0.11 0.14 0.70 92 Humid 16186.5 4.30 2.45 17.85 2.154 10.77 5.43 4.57 92 Dry 16186.5 4.30 2.45 17.71 2.231 11.19 5.56 4.67 0.14 0.08 0.42 99 Humid 16197.5 4.27 2.45 18.12 1.900 9.49 0.728 0.513 99 Dry 16197.5 4.27 2.45 17.98 2.015 10.08 0.780 0.546 0.14 0.12 0.59 A Forest Oil Company CL File: 57111-02144 RU-5A Well Redoubt Shoals Unit Core Lab Alaska Permeability & Porosity @ Increasing Net 08 (Humidified Samples) Sample Depth OB Grain Bulk Pore Porosity Air Klinkenberg b beta alpha I.D. Stress Volume Volume Volume Perm Perm ft psi cc cc cc % md md psi 11ft .l 10 15434.5 800 17.455 19.908 2.453 12.32 10.8 9.23 9.26E+00 4.28E+09 1.28E+02 10 15434.5 3780 17.455 19.689 2.239 11.37 7.75 6.68 8.92E+00 9.75E+09 2.1 OE+02 10 15434.5 4206 17.455 19.681 2.231 11.33 7.60 6.54 8.94E+00 9.91 E+09 2.10E+02 ~ 10 15434.5 4631 17.455 19.673 2.223 11.30 7.45 6.43 8.82E+00 1.05E+10 2.18E+02 10 15434.5 5057 17.455 19.664 2.214 11.26 7.31 6.30 8.86E+00 1.08E+10 2.20E+02 10 15434.5 5483 17.455 19.656 2.206 11.22 7.19 6.21 8.73E+00 1.12E+10 2.26E+02 10 15434.5 5903 17.455 19.649 2.199 11.19 7.07 6.11 8.67E+00 1.16E+10 2.30E+02 18 15442.5 800 18.096 20.087 1.991 9.91 0.376 0.242 3.79E+01 2.44E+11 1.91 E+02 18 15442.5 3780 18.096 19.996 1.896 9.48 0.145 0.0847 5.22E+01 6.35E+12 1.71 E+03 18 15442.5 4206 18.096 19.971 1.871 9.37 0.128 0.0712 5.88E+01 3.56E+11 8.40E+01 18 15442.5 4631 18.096 19.939 1.839 9.22 0.120 0.0670 5.79E+01 4.15E+12 9.20E+02 18 15442.5 5057 18.096 19.910 1.810 9.09 0.111 0.0613 5.97E+01 4.39E+12 8.93E+02 18 15442.5 5483 18.096 19.892 1.792 9.01 0.104 0.0558 6.25E+01 1.54E+12 2.85E+02 18 15442.5 5903 18.096 19.888 1.788 8.99 0.0972 0.0518 6.41 E+01 6.25E+11 1.07E+02 32 15456.5 800 15.324 17.339 2.015 11.62 0.584 0.411 2.78E+01 6.63E+11 8.98E+02 32 15456.5 3780 15.324 17.171 1.851 10.78 0.250 0.161 3.88E+01 2.26E+12 1.16E+03 32 15456.5 4206 15.324 17.147 1.827 10.66 0.231 0.145 4.12E+01 1.87E+12 8.89E+02 32 15456.5 4631 15.324 17.132 1.812 10.58 0.219 0.137 4.16E+01 2.23E+12 1.00E+03 ~ 32 15456.5 5057 15.324 17.121 1.801 10.52 0.209 0.130 4.20E+01 2.51E+12 1.07E+03 32 15456.5 5483 15.324 17.111 1.791 10.47 0.201 0.125 4.23E+01 2.87E+12 1.16E+03 32 15456.5 5903 15.324 17.101 1.781 10.41 0.192 0.120 4.24E+01 3.33E+12 1.29E+03 33 15457.5 800 18.411 20.428 2.017 9.87 0.183 0.112 4.58E+01 7.09E+11 2.66E+02 33 15457.5 3780 18.411 20.059 1.649 8.22 0.0580 0.0356 4.86E+01 2.99E+14 3.53E+04 33 15457.5 4206 18.411 20.031 1.621 8.09 0.0467 0.0232 7.80E+01 3.86E+13 2.94E+03 33 15457.5 4631 18.411 20.012 1.602 8.00 0.0420 0.0205 8.16E+01 3.86E+13 2.59E+03 33 15457.5 5057 18.411 19.991 1.581 7.91 0.0378 0.0179 8.58E+01 3.13E+13 1.86E+03 tJ 33 15457.5 5483 18.411 19.970 1.560 7.81 0.0342 0.0158 9.06E+01 1.40E+13 7.36E+02 33 15457.5 5903 18.411 19.960 1.550 7.77 0.0319 0.0144 9.36E+01 2.17E+13 1.02E+03 C~ >J I -. C' ~ A Forest Oil Company CL File: 57111-02144 RU-5A Well Redoubt Shoals Unit ÚJre Lab Alaska Permeability & Porosity @ Increasing Net 08 (Humidified Samples) Sample Depth OB Grain Bulk Pore Porosity Air Klinkenberg b beta alpha I.D. Stress Volume Volume Volume Perm Perm ft psi cc cc cc % md md psi 11ft 1 37 15461.5 800 17.398 19.972 2.574 12.89 19.0 17.5 4.52E+00 2.83E+09 1.61 E+02 37 15461.5 3780 17.398 19.737 2.337 11.84 15.5 14.4 3.85E+00 4.44E+09 2.08E+02 37 15461.5 4206 17.398 19.729 2.329 11.80 15.3 14.3 3.75E+00 4.51 E+09 2.09E+02 ~ 37 15461.5 4631 17.398 19.721 2.321 11.77 15.2 14.2 3.69E+00 4.61 E+09 2.12E+02 37 15461.5 5057 17.398 19.713 2.313 11.73 15.0 14.0 3.67E+00 4.69E+09 2.14E+02 37 15461.5 5483 17.398 19.705 2.305 11.70 14.9 13.9 3.74E+00 4.73E+09 2.13E+02 37 15461.5 5903 17.398 19.699 2.299 11.67 14.7 13.8 3.70E+00 4.82E+09 2.15E+02 47 15471.5 800 17.034 19.766 2.732 13.82 46.0 43.6 2.71 E+OO 6.30E+08 8.91 E+01 47 15471.5 3780 17.034 19.552 2.522 12.90 39.1 37.4 2.36E+00 8.52E+08 1.03E+02 47 15471.5 4206 17.034 19.544 2.514 12.86 38.8 37.0 2.38E+00 8.58E+08 1.03E+02 47 15471.5 4631 17.034 19.538 2.508 12.84 38.5 36.8 2.31 E+OO 8.75E+08 1.04E+02 47 15471.5 5057 17.034 19.529 2.499 12.80 38.2 36.4 2.36E+00 8.81E+08 1.04E+02 47 15471.5 5483 17.034 19.522 2.492 12.77 37.9 36.2 2.31 E+OO 8.96E+08 1.05E+02 47 15471.5 5903 17.034 19.516 2.486 12.74 37.6 36.0 2.30E+00 9.10E+08 1.06E+02 58 15484.5 800 17.156 18.396 1.240 6.74 0.188 0.127 3.41 E+01 9.16E+11 3.89E+02 58 15484.5 3780 17.156 18.218 1.058 5.81 0.0439 0.0267 5.09E+01 1.32E+14 1.13E+04 58 15484.5 4206 17.156 18.195 1.035 5.69 0.0366 0.0206 6.15E+01 5.42E+13 3. 75E+03 58 15484.5 4631 17.156 18.174 1.014 5.58 0.0322 0.0176 6.53E+01 5.17E+13 3.06E+03 ",-,J 58 15484.5 5057 17.156 18.151 0.991 5.46 0.0287 0.0155 6.69E+01 8.80E+13 4.60E+03 58 15484.5 5483 17.156 18.134 0.974 5.37 0.0258 0.0137 7.03E+01 1.12E+14 4.96E+03 58 15484.5 5903 17.156 18.115 0.955 5.27 0.0231 0.0119 7.38E+01 1.20E+14 4.66E+03 60 15822.4 800 18.951 19.940 0.989 4.96 0.262 0.182 3.07E+01 1.27E+11 7.68E+01 60 15822.4 3780 18.951 19.694 0.744 3.78 0.0414 0.0263 4.53E+01 2.83E+14 2.37E+04 60 15822.4 4206 18.951 19.671 0.721 3.67 0.0330 0.0183 6.31 E+01 7.50E+13 4.65E+03 60 15822.4 4631 18.951 19.659 0.709 3.61 0.0286 0.0155 6.68E+01 8.44E+13 4.42E+03 60 15822.4 5057 18.951 19.647 0.697 3.55 0.0243 0.0117 8.59E+01 7.01E+13 2.76E+03 60 15822.4 5483 18.951 19.636 0.686 3.50 0.0215 0.0101 8.90E+01 9.21E+13 3.14E+03 60 15822.4 5903 18.951 19.627 0.677 3.45 0.0193 0.0089 9.27E+01 1.26E+14 3.65E+03 .& Forest Oil Company CL File: 57111-02144 RU.5A Well Redoubt Shoals Unit [ore Lab Alaska Permeability & Porosity @ Increasing Net 08 (Humidified Samples) Sample Depth OB Grain Bulk Pore Porosity Air Klinkenberg b beta alpha I.D. Stress Volume Volume Volume Perm Perm ft psi cc cc cc % md md psi 11ft l 83 16175.5 800 18.453 20.519 2.066 10.07 1.47 1.11 2.04E+01 3.82E+10 1.39E+02 83 16175.5 3780 18.453 20.234 1.784 8.82 0.727 0.551 2.07E+01 5.85E+11 1.04E+03 83 16175.5 4206 18.453 20.217 1.767 8.74 0.682 0.508 2.21 E+01 5.24E+11 8.71E+02 ~ 83 16175.5 4631 18.453 20.203 1.753 8.68 0.641 0.465 2.45E+01 2.31 E+11 3.50E+02 83 16175.5 5057 18.453 20.191 1.741 8.62 0.614 0.445 2.46E+01 2.46E+11 3.57E+02 83 16175.5 5483 18.453 20.180 1.730 8.57 0.591 0.429 2.44E+01 2.95E+11 4.13E+02 83 16175.5 5903 18.453 20.171 1.721 8.53 0.574 0.417 2.42E+01 3.43E+11 4.63E+02 87 16179.2 800 18.133 20.629 2.496 12.10 6.11 5.22 9.53E+00 8.72E+09 1.48E+02 87 16179.2 3780 18.133 20.320 2.190 10.78 4.14 3.57 9.23E+00 2.15E+10 2.48E+02 87 16179.2 4206 18.133 20.302 2.172 10.70 4.03 3.46 9.40E+00 2.11 E+1 0 2.37E+02 87 16179.2 4631 18.133 20.284 2.154 10.62 3.94 3.39 9.30E+00 2.20E+10 2.42E+02 87 16179.2 5057 18.133 20.271 2.141 10.56 3.86 3.33 9.13E+00 2.35E+10 2.54E+02 87 16179.2 5483 18.133 20.257 2.127 10.50 3.79 3.26 9.17E+00 2.39E+10 2.54E+02 87 16179.2 5903 18.133 20.246 2.116 10.45 3.72 3.21 9.11 E+OO 2.47E+10 2.57E+02 ~ ~ ) ) ;;{ÜÀ -/Gf .. Forest Oil Corporation File # : 57111-02144 Redoubt Unit #5A Redoubt Shoals û:8re Lab Vertical Permeability and Porosity Analysis Results (SOD-psi Net Stress) (Humidified Samples) Sample Depth CMS Vertical Permeability b beta alpha Porosity Air I'Klinkenberg ft % md md psi 11ft microns Samples in Red - Permeability too low for measurement, porosity determined at ambient conditions using bulk volume and measured grain volume Pore Volume = Bulk Volume - Grain Volume Porosity (%) = (Pore Volume I Bulk Volume) X 100 1 15425.2 10.9 32.4 28.7 6.62E+00 1.55E+09 1.45E+02 2 15426.4 11.7 21.9 19.2 7.41E+00 2.78E+09 1.73E+02 3 15427.8 3.8 0.0695 0.0413 5.25E+01 4.56E+13 6.47E+03 4 15428.1 3.7 0.0937 0.0572 4.79E+01 1.17E+13 2.27E+03 5 15429.1 12.1 14.3 13.0 5.21 E+OO 4.38E+09 1.86E+02 6 15430.3 12.3 12.8 11.4 6.17E+00 3.57E+09 1.33E+02 7 15431.3 12.7 29.7 27.8 3.52E+00 1.25E+09 1.12E+02 8 15432.3 12.2 15.1 13.5 6.15E+00 3.22E+09 1.42E+02 9 15433.3 13.0 41.3 39.2 2.75E+00 8.33E+08 1.06E+02 10 15434.3 13.7 37.7 35.8 2.71E+00 8.04E+08 9.34E+01 11 15435.3 13.1 28.6 26.9 3.24E+00 1.22E+09 1.07E+02 12 15436.3 13.0 15.2 13.8 5.22E+00 2.55E+09 1.14E+02 13 15437.3 12.6 20.4 18.9 4.15E+00 1.89E+09 1.16E+02 14 15438.3 11.6 3.50 2.83 1.39E+01 1.82E+10 1.68E+02 15 15439.3 11.1 3.31 2.67 1.40E+01 2.28E+10 1.98E+02 16 15440.3 9.2 0.195 0.119 4.61 E+01 1.28E+12 5.11E+02 17 15441.3 9.7 0.352 0.230 3.64E+01 2.68E+11 2.05E+02 18 15442.3 10.0 0.443 0.295 3.37E+01 2.19E+11 2.14E+02 19 15443.3 10.4 0.903 0.649 2.49E+01 4.20E+11 8.99E+02 20 15444.3 13.8 40.0 38.0 2.69E+00 6.37E+08 7.86E+01 21 15445.3 14.1 55.9 53.6 2.11E+00 4.24E+08 7.39E+01 22 15446.3 13.0 30.8 29.0 3.29E+00 1.29E+09 1.21 E+02 23 15447.4 14.0 42.6 40.6 2.55E+00 6.06E+08 7.98E+01 24 15448.3 12.7 18.7 16.9 5.56E+00 2.13E+09 1.17E+02 25 15449.3 8.9 0.171 0.0986 5.29E+01 1.55E+12 5.15E+02 26 15450.3 9.0 0.159 0.0952 4.85E+01 2.14E+12 6.84E+02 27 15451.3 8.7 0.125 0.0713 5.57E+01 3.75E+12 8.90E+02 28 15452.3 9.3 0.138 0.0828 4.90E+01 5.96E+12 1.67E+03 29 15453.3 10.3 0.226 0.138 4.47E+01 1.04E+12 4.83E+02 30 15454.3 11.5 0.652 0.447 3.00E+01 7.70E+10 1.14E+02 31 15455.3 10.5 0.260 0.163 4.19E+01 7.78E+11 4.22E+02 32 15456.3 9.8 0.192 0.116 4.70E+01 1.49E+11 5.80E+01 33 15457.3 11.2 0.492 0.339 3.01 E+01 2.29E+11 2.58E+02 34 15458.3 11.0 0.429 0.270 4.00E+01 1.55E+11 1.39E+02 35 15459.3 11.2 0.869 0.623 2.53E+01 2.22E+11 4.53E+02 36 15460.3 12.2 6.69 5.78 8.82E+00 1.52E+10 2.85E+02 37 15461.3 13.3 17.8 16.2 5.10E+00 3.23E+09 1.70E+02 38 15462.3 11.3 1.29 0.952 2.19E+01 1.61 E+11 5.03E+02 39 15463.3 14.3 46.8 44.4 2.60E+00 7.41 E+08 1.07E+02 40 15464.3 11.3 1.16 0.858 2.18E+01 1.62E+11 4.56E+02 41 15465.3 13.3 5.01 4.14 1.19E+01 1.48E+10 2.00E+02 42 15466.4 12.0 0.930 0.665 2.54E+01 1.74E+11 3.82E+02 43 15467.3 8.3 0.149 0.0916 4.58E+01 4.14E+12 1.28E+03 44 15468.3 9.1 0.125 0.0727 5.30E+01 5.79E+12 1.42E+03 45 15469.3 12.1 2.01 1.56 1.76E+01 5.46E+10 2.79E+02 46 15470.3 11.7 2.13 1.67 1.68E+01 6.99E+10 3.81E+02 47 15471.3 13.3 20.9 19.1 4.90E+00 1.81 E+09 1.13E+02 48 15472.4 14.5 49.8 46.8 3.26E+00 5.73E+08 8.70E+01 49 15473.3 11.3 0.641 0.471 2.37E+01 7.40E+11 1.15E+03 50 15474.3 11.4 0.853 0.640 2.13E+01 6.23E+11 1.31 E+03 51 15475.3 49.2 0.886 0.603 3.01 E+01 2.60E+11 5.17E+02 52 15476.6 5.1 0.871 0.708 1.47E+01 3.88E+08 9.04E-01 53 15477.8 4.2 0.386 0.292 2.17E+01 1.97E+11 1.85E+02 54 15478.3 4.6 1.14 0.969 1.09E+01 2.23E+10 6.97E+01 55 15479.6 4.5 0.683 0.540 1.72E+01 8.00E+10 1.38E+02 56 15484.3 6.2 0.157 0.106 3.48E+01 1.51E+12 5.35E+02 57 15822.2 4.3 0.191 0.136 2.88E+01 1.20E+12 5.42E+02 ") ) . [ore LaI:Ï Forest Oil Corporation Redoubt Unit #5A Redoubt Shoals Vertical Permeability and Porosity Analysis Results (SOO-psi Net Stress) (Humidified Samples) File # : 57111-02144 Sample Depth CMS Vertical Permeability b beta alpha Porosity Air 1...Klinkenberg ft % md md psi 11ft microns Samples in Red - Permeability too low for measurement, porosity determined at ambient conditions using bulk volume and measured grain volume Pore Volume = Bulk Volume - Grain Volume Porosity (%) = (Pore Volume I Bulk Volume) X 100 58 16153.3 1.0 < 0.0001 < 0.0001 59 16154.3 1.1 < 0.0001 < 0.0001 60 16155.3 0.9 < 0.0001 < 0.0001 61 16156.3 1.6 < 0.0001 < 0.0001 62 16157.3 1.1 < 0.0001 < 0.0001 63 16158.3 1.1 < 0.0001 < 0.0001 64 16159.3 1.2 < 0.0001 < 0.0001 65 16160.3 0.7 < 0.0001 < 0.0001 66 16161.8 0.9 < 0.0001 < 0.0001 67 16162.4 8.7 < 0.0001 < 0.0001 68 16163.3 3.6 0.0556 0.0326 5.49E+01 6.14E+13 6.85E+03 69 16164.3 4.1 < 0.0001 < 0.0001 70 16165.3 12.2 8.77 7.48 9.49E+00 4.82E+09 1.18E+02 71 16166.7 0.7 < 0.0001 < 0.0001 72 16167.3 9.3 0.535 0.361 3.20E+01 2.06E+11 2.46E+02 73 16168.3 12.7 12.1 10.6 7.48E+00 2.49E+09 8.63E+01 74 16169.3 12.0 6.14 5.15 1.08E+01 5.27E+09 8.84E+01 75 16170.3 7.9 0.633 0.495 1.82E+01 8.31 E+11 1.36E+03 76 16171.3 5.2 0.0795 0.0493 4.65E+01 2.06E+13 3.46E+03 77 16172.3 9.1 0.465 0.304 3.56E+01 1.44E+11 1.45E+02 78 16174.0 10.3 1.95 1.53 1.67E+01 2.90E+10 1.46E+02 79 16175.3 11.3 1.68 1.28 1.95E+01 3.92E+10 1.64E+02 80 16176.1 6.0 0.278 0.191 3.17E+01 5.17E+11 3.28E+02 81 16177.9 9.8 8.46 7.39 7.92E+00 5.65E+09 1.36E+02 82 16178.4 11.4 11.1 9.72 7.53E+00 4.03E+09 1.27E+02 83 16179.3 12.2 6.86 5.87 9.37E+00 6.71E+09 1.29E+02 84 16182.3 12.3 43.6 39.6 5.16E+00 8.08E+08 1.04E+02 85 16186.6 11.3 11.2 9.85 7.57E+00 4.54E+09 1.46E+02 86 16190.3 11.2 6.11 5.20 9.80E+00 1.11E+10 1.88E+02 87 16191.3 9.7 5.87 4.94 1.06E+01 6.73E+09 1.08E+02 88 16195.3 6.1 0.0795 0.0462 5.49E+01 3.76E+13 5.96E+03 89 16196.3 6.7 0.112 0.0658 5.23E+01 2.05E+13 4.58E+03 90 16197.3 9.5 0.832 0.580 2.80E+01 9.70E+10 1.81 E+02 91 16198.3 9.4 1.91 1.47 1.79E+01 3.30E+10 1.59E+02 ) ) '} '. ¡i;J 0\[;)(- :ç , . Forest Oil Corporation File # : 57111-02144 Redoubt Unit #5A Cere LaI:Ì Redoubt Shoals Horizontal Permeability and Porosity Analysis Results (SOD-psi Net Stress) (Humidified Samples) Sample Depth CMS Horizontal! Permeability b beta alpha Porosity Air IKlinkenberg ft % md md psi 11ft microns Samples in Red - Permeability too low for measurement, porosity determined at ambient conditions using bulk volume and measured grain volume Pore Volume = Bulk Volume - Grain Volume Porosity (%) = (Pore Volume I Bulk Volume) X 100 1 15425.5 10.9 48.7 42.7 7.02E+00 8.62E+08 1.19E+02 2 15426.5 11.1 41.9 36.9 6.82E+00 1.39E+09 1.65E+02 3 15427.5 5.4 < 0.0001 < 0.0001 4 15428.2 3.3 0.104 0.0632 4.80E+01 1.08E+13 2.22E+03 5 15429.2 12.4 14.6 13.3 5.30E+00 3.69E+09 1.58E+02 6 15430.4 11.9 10.7 9.49 7.10E+00 5.00E+09 1.53E+02 7 15431.5 13.0 17.4 15.8 5.32E+00 2.26E+09 1.15E+02 8 15432.5 13.6 43.7 41.5 2.72E+00 8.08E+08 1.08E+02 9 15433.5 12.9 21.6 19.7 5.08E+00 1.95E+09 1.24E+02 10 15434.5 12.3 10.8 9.23 9.26E+00 4.28E+09 1.28E+02 11 15435.5 12.8 22.5 20.8 4.11E+00 1.66E+09 1.12E+02 12 15436.5 12.8 14.7 13.2 5.83E+00 2.83E+09 1.21 E+02 13 15437.5 10.2 0.352 0.217 4.30E+01 2.24E+11 1.57E+02 14 15438.5 12.4 10.3 9.09 7.11E+00 3.98E+09 1.17E+02 15 15439.5 11.9 2.98 2.28 1.84E+01 1.83E+10 1.35E+02 16 15440.5 9.5 0.196 0.118 4.72E+01 3.57E+12 1.36E+03 17 15441.5 9.8 0.321 0.206 3.84E+01 8.75E+11 5.84E+02 18 15442.5 9.9 0.376 0.242 3.79E+01 2.44E+11 1.91 E+02 19 15443.5 10.3 0.599 0.398 3.34E+01 4.38E+11 5.64E+02 20 15444.5 13.5 12.6 10.3 1.16E+01 4.08E+09 1.36E+02 21 15445.5 14.0 34.4 32.4 3.19E+00 8.54E+08 8.94E+01 22 15446.5 13.9 51.4 49.4 2.02E+00 4.89E+08 7.83E+01 23 15447.5 12.8 22.7 21.2 3.73E+00 1.69E+09 1.16E+02 24 15448.5 11.9 8.65 7.59 7.68E+00 5.30E+09 1.30E+02 25 15449.5 11.7 2.60 2.06 1.54E+01 3.13E+10 2.09E+02 26 15450.5 8.6 0.152 0.0903 4.94E+01 4.18E+12 1.28E+03 27 15451.5 10.8 0.368 0.239 3.68E+01 3.43E+11 2.73E+02 28 15452.5 9.3 0.169 0.101 4.89E+01 1.33E+12 4.51 E+02 29 15453.5 10.5 0.234 0.144 4.45E+01 1.55E+12 7.45E+02 30 15454.5 10.6 0.341 0.219 3.83E+01 3.73E+11 2.72E+02 31 15455.5 11.0 0.300 0.187 4.19E+01 6.79E+10 4.23E+01 32 15456.5 11.6 0.584 0.411 2.78E+01 6.63E+11 8.98E+02 33 15457.5 8.9 0.183 0.112 4.58E+01 7.09E+11 2.66E+02 34 15458.5 11.1 0.554 0.375 3.16E+01 4.84E+09 6.01 E+OO 35 15459.5 12.4 2.36 1.81 1.83E+01 5.07E+10 2.99E+02 36 15460.5 12.4 4.88 3.83 1.55E+01 1.37E+10 1.71 E+02 37 15461.5 12.9 19.0 17.5 4.52E+00 2.83E+09 1.61 E+02 38 15462.5 14.2 52.5 50.0 2.43E+00 5.98E+08 9.72E+01 39 15463.5 12.3 5.87 5.07 8.92E+00 1.96E+10 3.23E+02 40 15464.5 11.5 0.985 0.686 2.78E+01 2.55E+11 5.75E+02 41 15465.5 11.4 0.540 0.363 3.23E+01 2.08E+11 2.48E+02 42 15466.5 12.4 1.76 1.38 1.72E+01 8.31 E+1 0 3.72E+02 43 15467.5 8.2 0.141 0.0828 5.17E+01 3.11E+12 8.55E+02 44 15468.5 9.5 0.160 0.0934 5.19E+01 1.19E+12 3.75E+02 45 15469.5 12.2 3.10 2.48 1.46E+01 2.56E+10 2.06E+02 46 15470.5 12.2 5.07 4.25 1.09E+01 1.58E+10 2.19E+02 47 15471.5 13.8 46.0 43.6 2.71E+00 6.30E+08 8.91 E+01 48 15472.5 14.6 57.9 54.7 2.81 E+OO 4.29E+08 7.62E+01 49 15473.5 8.1 0.127 0.0733 5.43E+01 6.33E+12 1.54E+03 50 15474.5 11.1 0.920 0.667 2.42E+01 2.05E+11 4.48E+02 51 15475.5 11.1 0.868 0.654 2.09E+01 5.63E+11 1.21 E+03 52 15476.7 4.7 0.535 0.409 2.02E+01 6.42E+09 8.60E+00 53 15477.3 4.2 1.38 1.13 1.34E+01 1.48E+10 5.51 E+01 54 15478.4 4.8 < 0.0001 < 0.0001 55 15479.5 5.2 < 0.0001 < 0.0001 56 15480.3 4.0 < 0.0001 < 0.0001 57 15481.2 4.7 < 0.0001 < 0.0001 ') ) .. Forest Oil Corporation File # : 57111-02144 Redoubt Unit #5A Redoubt Shoals Core Lab Horizontal Permeability and Porosity Analysis Results (SOO-psi Net Stress) (Humidified Samples) Sample Depth CMS Horizontal! Permeability b beta alpha Porosity Air I' .Klir'lkènberg ft % md md psi 11ft microns Samples in Red - Permeability too low for measurement, porosity determined at ambient conditions using bulk volume and measured grain volume Pore Volume = Bulk Volume - Grain Volume Porosity (%) = (Pore Volume I Bulk Volume) X 100 58 15484.5 6.7 0.188 0.127 3.41 E+01 9.16E+11 3.89E+02 59 15485.3 6.1 0.240 0.166 3.10E+01 2.24E+11 1.24E+02 60 15822.4 5.0 0.262 0.182 3.07E+01 1.27E+11 7.68E+01 61 16153.5 1.7 < 0.0001 < 0.0001 62 16154.5 1.7 < 0.0001 < 0.0001 63 16155.5 1.6 < 0.0001 < 0.0001 64 16156.5 2.3 1.73 1.51 8.42E+00 8.35E+11 4.15E+03 65 16157.5 1.6 < 0.0001 < 0.0001 66 16158.5 1.7 2.60 2.21 1.02E+01 8.82E+09 6.39E+01 67 16159.5 1.8 7.38 6.98 3.15E+00 1.64E+10 3.74E+02 68 16160.5 2.0 13.6 13.1 2.11E+00 7.27E+09 3.10E+02 69 16161.5 1.6 0.0410 0.0221 6.85E+01 2.06E+13 1.57E+03 70 16162.6 4.0 0.155 0.0914 5.09E+01 5.99E+12 1.83E+03 71 16163.5 4.3 0.344 0.221 3.80E+01 9.43E+11 6.93E+02 72 16164.5 3.5 0.134 0.0848 4.28E+01 1.14E+13 3.27E+03 73 16165.5 10.1 4.80 4.03 1.09E+01 2.06E+10 2.70E+02 74 16166.5 1.4 < 0.0001 < 0.0001 75 16167.5 9.8 0.704 0.501 2.64E+01 4.42E+11 7.31 E+02 76 16168.5 12.6 9.68 8.24 9,53E+00 2.56E+09 6.87E+01 77 16169.5 12.4 10,6 9.18 8.45E+00 3.03E+09 9.05E+01 78 16170.4 9.2 0.445 0.287 3.70E+01 9.84E+11 9.41E+02 79 16171.5 4.8 1.26 1.08 1.06E+01 2.83E+11 1.00E+03 80 16172.5 10.3 0.710 0.487 2.98E+01 1.46E+11 2.35E+02 81 16173.5 5.5 < 0.0001 < 0.0001 82 16174.5 9.9 2.19 1.75 1.50E+01 2.98E+10 1.71E+02 83 16175.5 10.1 1.47 1.11 2.04E+01 3.82E+10 1.39E+02 84 16176.2 6.0 0.769 0.598 1.84E+01 2.91 E+11 5.75E+02 85 16177.8 9.4 < 0.0001 < 0.0001 86 16178.5 10.6 4.26 3.37 1.52E+01 2.19E+10 2.41 E+02 87 16179.2 12.1 6.11 5.22 9.53E+00 8.72E+09 1.48E+02 88 16181.8 9.2 < 0.0001 < 0.0001 89 16182.4 12.0 36.5 33.6 4.31 E+OO 1.05E+09 1.15E+02 90 16183.4 11.9 < 0.0001 < 0.0001 91 16185.6 8.9 < 0.0001 < 0.0001 92 16186.5 10.8 5.43 4.57 1.05E+01 1.16E+10 1.73E+02 93 16189.5 8.9 9.08 8.04 7.04E+00 3.13E+09 8.20E+01 94 16190.5 11.0 5.21 4.39 1.06E+01 1.22E+10 1.75E+02 95 16191.5 9.3 3.56 2.94 1.23E+01 1.25E+10 1.20E+02 96 16192.5 6.9 < 0.0001 < 0.0001 97 16195.5 6.7 0.0859 0.0472 6.24E+01 3.09E+13 4.97E+03 98 16196.5 8.5 0.410 0.270 3.52E+01 3.83E+11 3.43E+02 99 16197.5 9.5 0.728 0.513 2.73E+01 4.37E+11 7.39E+02 100 16198.5 9.5 1.24 0.902 2.35E+01 9.16E+10 2.71E+02 101 16200.7 5.6 < 0.0001 < 0.0001 102 16201.2 9.1 1.29 0.942 2.34E+01 6.10E+10 1.89E+02 '4..,,' Forest Oil Corporation G. Redoubt Unit #5A Core Lab Redoubt Shoals Sample Depth Interval Number (ft) 1 15819.30 - 15819.70 2 15820.60 - 15821.20 3 15822.90 - 15823.50 4 15823.50 - 15824.00 5 16187.00 - 16187.60 6 16187.90 - 16188.40 7 16193.30 - 16193.75 8 16194.50 - 16195.00 9 16199.15 - 16199.50 10 16201.90 - 16202.40 11 16203.50 - 16204.00 12 16204.00 - 16204.90 13 16205.50 - 16206.00 Conventional Full-Diameter Samples Permeabilitv lKöir) .-' (Maximum) (90 Deg) (Vertical) md md md 34.4 97.0 13.9 NP 14.6 5.93 13.8 18.5 8.28 20.3 14.5 18.6 10.6 24.7 53.3 11.9 NP 8.32 4.03 9.09 8.59 4.81 13.3 14.5 17.0 9.07 25.8 19.3 3.41 NP 6.76 3.40 5.22 5.22 5.08 8.52 6.45 11.0 6.17 Porosity (Helium) % 9.3 9.2 4.9 8.0 7.7 4.8 4.5 4.7 5.9 4.0 5.4 7.0 4.8 File # : 57111-02144 2.37 2.38 2.49 2.42 2.44 2.53 2.51 2.51 2.49 2.53 2.5 2.45 2.51 Grain Density gm/cc ~' 2.62 2.62 2.62 2.63 2.65 2.66 2.63 2.64 2.64 2.64 2.64 2.64 2.64 "~' )'..J~ ~~). }..\ J -.- .(;~ Gv ') ) '2- 0 2- - I ~ g A Forest Oil Company File No. : 57111-02144 RU5A Carelal:Ï Redoubt Shoals Field SPECTRAL CORE GAMMA SURFACE LOG Depth I Potassium I Uranium I Thorium I Total Gamma I uranium-fr, ee Gamma I ft % ppm ppm API API 15425.00 0.00 5.38 2.44 29.2 0.3 15425.20 0.00 5.37 2.56 37.7 8.8 15425.40 0.00 5.28 2.63 37.3 8.9 15425.60 0.00 5.18 2.62 37.5 9.6 15425.80 0.00 5.04 2.63 37.9 10.8 15426.00 0.00 4.86 2.75 39.5 13.4 15426.20 0.00 4.85 2.64 40.8 14.6 15426.40 0.00 4.87 2.59 41.9 15.7 15426.59 0.00 4.94 2.48 43.1 16.5 15426.79 0.00 5.12 2.43 43.3 15.7 15426.99 0.00 5.17 2.49 44.5 16.8 15427.19 0.00 5.12 2.41 45.5 17.9 15427.39 0.00 5.12 2.24 46.7 19.1 15427.59 0.00 5.16 2.10 47.8 20.1 15427.79 0.00 5.07 1.72 46.2 18.9 15427.99 0.00 4.84 1.32 46.5 20.5 15428.19 0.00 4.52 1.01 45.0 20.6 15428.39 0.00 4.30 0.76 46.0 22.9 15428.59 0.00 4.18 0.57 44.4 21.9 15428.79 0.00 4.13 0.43 44.5 22.3 15428.99 0.00 4.11 0.32 45.4 23.3 15429.19 0.00 4.11 0.24 45.7 23.5 15429.39 0.00 4.26 0.18 43.7 20.8 15429.58 0.00 4.46 0.14 43.0 19.0 15429.78 0.00 4.70 0.10 41.8 16.5 15429.98 0.00 4.77 0.09 42.7 17.0 15430.18 0.00 4.70 0.48 41.4 16.1 15430.38 0.00 4.72 0.82 41.5 16.1 15430.58 0.00 4.88 0.90 41.4 15.2 15430.78 0.00 5.02 1.00 42.1 15.1 15430.98 0.00 4.99 1.21 42.8 15.9 15431.18 0.00 5.00 1.18 42.4 15.5 15431.38 0.00 5.14 1.16 43.0 15.3 15431.58 0.00 5.33 0.97 43.0 14.3 15431.78 0.00 5.51 0.90 42.5 12.8 15431.98 0.00 5.60 0.81 42.6 12.5 15432.18 0.00 5.59 0.66 42.0 11.9 15432.38 0.00 5.60 0.51 42.3 12.2 15432.58 0.00 5.54 0.38 41.5 11.6 15432.77 0.00 5.48 0.29 41.5 12.0 15432.97 0.00 5.54 0.22 41.7 11.9 15433.17 0.00 5.49 0.16 41.3 11.8 15433.37 0.00 5.50 0.12 40.1 10.5 15433.57 0.00 5.50 0.09 39.6 10.0 15433.77 0.00 5.58 0.37 39.2 9.2 15433.97 0.00 5.63 1.15 39.5 9.2 15434.17 0.00 5.69 1.81 40.7 10.0 15434.37 0.00 5.57 2.26 40.8 10.8 15434.57 0.00 5.42 2.74 42.0 12.8 15434.77 0.00 5.19 2.89 41.2 13.2 15434.97 0.00 5.01 2.86 42.4 15.4 15435.17 0.00 4.82 2.67 42.7 16.8 15435.37 0.00 4.55 2.61 44.9 20.4 15435.57 0.00 4.35 2.67 44.6 21.2 15435.76 0.00 4.12 2.68 44.7 22.6 15435.96 0.00 3.93 2.57 43.5 22.4 15436.16 0.00 3.77 2.63 43.4 23.1 15436.36 0.00 3.66 2.75 43.9 24.2 15436.56 0.00 3.59 3.02 44.7 25.3 ) ) 15436.76 0.00 3.77 2.87 45.1 24.8 15436.96 0.00 3.97 2.73 44.7 23.3 15437.16 0.00 4.25 2.64 45.9 23.1 15437.36 0.00 4.58 2.82 46.1 21.5 15437.56 0.00 4.97 2.90 45.7 18.9 15437.76 0.00 5.36 3.06 46.7 17.8 15437.96 0.00 5.55 3.06 45.2 15.4 15438.16 0.00 5.61 2.88 44.6 14.5 15438.36 0.00 5.60 2.81 47.3 17.2 15438.56 0.00 5.64 2.79 46.9 16.6 15438.75 0.00 5.58 2.66 48.5 18.4 15438.95 0.00 5.51 2.28 50.4 20.8 15439.15 0.00 5.42 1.77 50.4 21.2 15439.35 0.00 5.33 1.55 52.4 23.7 15439.55 0.00 5.42 1.39 51.2 22.0 15439.75 0.00 5.64 1.17 52.9 22.6 15439.95 0.00 5.92 0.99 51.6 19.8 15440.15 0.00 6.01 0.91 53.6 21.3 15440.35 0.00 6.08 0.87 53.1 20.4 15440.55 0.00 6.08 0.91 52.2 19.5 15440.75 0.00 6.15 0.86 51.4 18.4 15440.95 0.00 6.07 1.00 50.2 17.6 15441.15 0.00 5.83 1.11 48.4 17.0 15441.35 0.00 5.50 1.17 47.1 17.5 15441.55 0.00 5.29 1.24 47.1 18.7 15441.75 0.00 5.19 1.31 45.6 17.8 15441.94 0.00 5.14 1.40 45.6 17.9 15442.14 0.00 5.07 1.50 45.8 18.6 15442.34 0.00 4.94 1.52 45.1 18.5 15442.54 0.00 5.01 1.39 45.4 18.4 15442.74 0.00 5.00 1.35 45.2 18.3 15442.94 0.00 5.00 1.49 43.6 16.7 15443.14 0.00 4.98 1.63 44.2 17.4 15443.34 0.00 4.91 1.74 42.6 16.2 15443.54 0.00 4.94 1.67 44.2 17.6 15443.74 0.00 5.08 1.68 44.6 17.3 15443.94 0.00 5.16 1.67 45.1 17.3 15444.14 0.00 5.14 1.83 42.8 15.1 15444.34 0.00 5.12 2.12 44.3 16.8 15444.54 0.00 4.87 2.28 42.0 15.8 15444.74 0.00 4.65 2.38 42.8 17.7 15444.93 0.00 4.47 2.59 41.8 17.8 15445.13 0.00 4.21 2.87 40.4 17.7 15445.33 0.00 4.07 3.01 41.6 19.7 15445.53 0.00 3.97 3.12 40.3 18.9 15445.73 0.00 3.93 3.05 42.0 20.8 15445.93 0.00 4.10 2.75 42.2 20.2 15446.13 0.00 4.36 2.60 43.6 20.1 15446.33 0.00 4.52 2.46 43.2 18.9 15446.53 0.00 4.69 2.23 43.7 18.4 15446.73 0.00 4.75 1.97 41.6 16.0 15446.93 0.00 4.84 1.71 41.0 14.9 15447.13 0.00 4.86 1.60 41.7 15.6 15447.33 0.00 4.86 1.41 42.7 16.6 15447.53 0.00 4.88 1,15 41.7 15.4 15447.73 0.00 4.95 0.88 44.9 18.3 15447.92 0.00 5.00 0.67 45.2 18.3 15448.12 0.00 5.06 0.54 47.8 20.6 15448.32 0.00 5.17 0.51 51.2 23.4 15448.52 0.00 5.32 0.58 52.8 24.2 15448.72 0.00 5.48 0.52 51.9 22.4 15448.92 0.00 5.49 0.41 52.7 23.1 15449.12 0.00 5.43 0.50 52.2 23.0 15449.32 0.00 5.27 0.56 51.9 23.6 15449.52 0.00 5.20 0.67 51.5 23.6 15449.72 0.00 5.13 0.77 50.2 22.6 15449.92 0.00 5.12 1.01 50.1 22.6 15450.12 0.00 5.16 1.25 52.0 24.2 15450.32 0.00 5.15 1.45 52.2 24.5 15450.52 0.00 5.13 1.50 51.7 24.1 ') ) 15450.72 0.00 5.18 1.49 51.7 23.8 15450.92 0.00 5.16 1.40 50.7 23.0 15451.11 0.00 5.03 1.43 49.8 22.7 15451.31 0.00 4.86 1.52 49.7 23.5 15451.51 0.00 4.74 1.41 47.3 21.8 15451.71 0.00 4.59 1.19 47.1 22.4 15451.91 0.00 4.47 0.91 45.8 21.8 15452.11 0.00 4.43 0.69 45.8 22.0 15452.31 0.00 4.46 0.52 46.0 22.0 15452.51 0.00 4.56 0.39 45.1 20.6 15452.71 0.00 4.56 0.29 46.9 22.4 15452.91 0.00 4.43 0.38 46.2 22.4 15453.11 0.00 4.26 0.73 47.1 24.2 15453.31 0.00 4.17 0.96 47.1 24.6 15453.51 0.00 4.21 1.15 48.4 25.7 15453.71 0.00 4.26 1.43 46.4 23.5 15453.91 0.00 4.23 1.74 46.5 23.7 15454.10 0.00 4.13 1.99 42.8 20.6 15454.30 0.00 4.24 2.02 43.4 20.6 15454.50 0.00 4.31 2.01 43.7 20.4 15454.70 0.00 4.41 1.85 44.4 20.6 15454.90 0.00 4.47 2.02 44.0 19.9 15455.10 0.00 4.51 2.01 43.8 19.6 15455.30 0.00 4.52 1.89 42.8 18.5 15455.50 0.00 4.56 1.83 44.2 19.6 15455.70 0.00 4.62 1.86 44.8 19.9 15455.90 0.00 4.76 2.02 44.3 18.7 15456.10 0.00 4.93 2.02 43.9 17.4 15456.30 0.00 5.04 1.87 44.7 17.6 15456.50 0.00 5.01 1.70 43.8 16.8 15456.70 0.00 4.96 1.53 44.4 17.7 15456.90 0.00 4.92 1.31 43.8 17.3 15457.09 0.00 5.01 1.01 43.8 16.9 15457.29 0.00 5.09 0.77 44.1 16.7 15457.49 0.00 5.16 0.58 43.5 15.7 15457.69 0.00 5.30 0.55 43.2 14.7 15457.89 0.00 5.56 0.68 42.7 12.8 15458.09 0.00 5.77 1.01 43.8 12.7 15458.29 0.00 5.98 1.31 43.9 11.7 15458.49 0.00 6.11 1.52 42.7 9.8 15458.69 0.00 6.26 1.45 42.7 9.0 15458.89 0.00 6.44 1.19 42.9 8.3 15459.09 0.00 6.51 1.05 44.4 9.4 15459.29 0.00 6.50 0.97 43.4 8.4 15459.49 0.00 6.51 0.90 42.7 7.7 15459.69 0.00 6.45 0.71 42.4 7.6 15459.89 0.00 6.26 0.60 42.0 8.3 15460.08 0.00 6.05 0.84 44.4 11.8 15460.28 0.00 5.78 1.10 45.1 14.0 15460.48 0.00 5.52 1.44 47.3 17.6 15460.68 0.00 5.34 1.60 49.7 21.0 15460.88 0.00 5.26 1.47 52.6 24.3 15461.08 0.00 5.26 1.44 55.3 27.0 15461.28 0.00 5.24 1.46 55.4 27.2 15461.48 0.00 5.27 1.37 53.4 25.1 15461.68 0.00 5.33 1.38 53.6 24.9 15461.88 0.00 5.42 1.31 52.7 23.6 15462.08 0.00 5.56 1.04 51.5 21.6 15462.28 0.00 5.70 0.79 52.1 21.4 15462.48 0.00 5.68 0.60 49.1 18.6 15462.68 0.00 5.71 0.45 51.0 20.3 15462.88 0.00 5.79 0.34 45.4 14.3 15463.08 0.00 5.84 0.25 45.3 13.9 15463.27 0.00 5.88 0.19 44.4 12.7 15463.47 0.00 5.84 0.14 43.3 11.9 15463.67 0.00 5.76 0.11 43.7 12.8 15463.87 0.00 5.69 0.08 43.7 13.1 15464.07 0.00 5.51 0.24 45.0 15.4 15464.27 0.00 5.25 0.56 47.0 18.8 15464.47 0.00 5.16 0.77 47.4 19.6 ) ) 15464.67 0.00 5.08 0.99 46.0 18.6 15464.87 0.00 5.05 1.11 47.9 20.7 15465.07 0.00 5.07 1.42 47.0 19.8 15465.27 0.00 5.11 1.80 47.9 20.4 15465.47 0.00 5.27 2.19 49.9 21.6 15465.67 0.00 5.59 2.48 49.9 19.9 15465.87 0.00 5.82 2.63 50.4 19.0 15466.07 0.00 6.04 2.86 51.5 19.0 15466.26 0.00 6.26 3.06 53.1 19.4 15466.46 0.00 6.37 3.14 53.5 19.3 15466.66 0.00 6.40 2.94 54.6 20.2 15466.86 0.00 6.43 2.59 52.9 18.3 15467.06 0.00 6.41 2.12 53.7 19.2 15467.26 0.00 6.30 1.98 54.8 20.9 15467.46 0.00 6.15 1.70 54.9 21.8 15467.66 0.00 6.10 1.33 53.5 20.7 15467.86 0.00 5.98 1.14 53.0 20.8 15468.06 0.00 5.93 1.09 52.6 20.7 15468.26 0.00 5.83 0.95 52.0 20.6 15468.46 0.00 5.72 1.11 52.3 21.5 15468.66 0.00 5.63 1.05 51.6 21.3 15468.86 0.00 5.70 0.89 51.8 21.2 15469.06 0.00 5.54 0.91 50.7 20.9 15469.25 0.00 5.32 1.00 52.0 23.3 15469.45 0.00 5.12 1.16 51.9 24.3 15469.65 0.00 4.83 1.40 52.3 26.4 15469.85 0.00 4.59 1.47 52.0 27.3 15470.05 0.00 4.40 1.53 49.8 26.1 15470.25 0.00 4.21 1.38 48.1 25.4 15470.45 0.00 4.18 1.24 46.1 23.6 15470.65 0.00 4.19 1.00 45.1 22.5 15470.85 0.00 4.29 0.77 44.4 21.3 15471.05 0.00 4.40 0.58 44.6 20.9 15471.25 0.00 4.52 0.59 45.1 20.8 15471.45 0.00 4.61 0.64 46.9 22.1 15471.65 0.00 4.69 0.75 46.3 21.0 15471.85 0.00 4.74 0.74 47.8 22.3 15472.05 0.00 4.80 0.85 48.1 22.3 15472.25 0.00 4.88 1.16 49.9 23.7 15472.44 0.00 4.90 1.45 50.1 23.7 15472.64 0.00 4.86 1.81 50.8 24.7 15472.84 0.00 4.87 2.04 52.0 25.8 15473.04 0.00 4.90 2.27 52.2 25.8 15473.24 0.00 4.92 2.54 52.6' 26.2 15473.44 0.00 4.99 2.84 52.7 25.9 15473.64 0.00 5.08 2.68 51.2 23.9 15473.84 0.00 5.10 2.35 50.9 23.5 15474.04 0.00 5.12 1.96 51.1 23.5 15474.24 0.00 5.14 1.68 51.0 23.3 15474.44 0.00 5.06 1.33 49.6 22.3 15474.64 0.00 4.95 1.01 49.6 23.0 15474.84 0.00 4.86 0.76 48.5 22.4 15475.04 0.00 4.68 0.57 47.5 22.3 15475.24 0.00 4.50 0.58 46.2 22.0 15475.43 0.00 4.50 0.47 42.5 18.3 15475.63 0.00 4.46 0.57 41.5 17.5 15475.83 0.00 4.52 0.74 40.7 16.4 15476.03 0.00 4.69 1.03 42.1 16.9 15476.23 0.00 4.79 1.22 41.0 15.2 15476.43 0.00 5.00 1.46 41.6 14.6 15476.63 0.00 5.15 1.65 39.7 11.9 15476.83 0.00 5.31 1.71 40.6 12.0 15477.03 0.00 5.37 1.78 41.4 12.5 15477.23 0.00 5.44 1.73 41.6 12.4 15477.43 0.00 5.46 1.63 39.5 10.1 15477.63 0.00 5.62 1.52 39.9 9.7 15477.83 0.00 5.71 1.30 37.9 7.2 15478.03 0.00 5.78 1.00 39.5 8.4 15478.23 0.00 5.74 0.94 38.9 8.0 15478.42 0.00 5.77 0.74 39.3 8.2 ) 15478.62 0.00 5.83 0.62 41.8 10.5 15478.82 0.00 5.87 0.48 41.8 10.2 15479.02 0.00 5.78 0.36 42.4 11.3 15479.22 0.00 5.74 0.27 43.0 12.1 15479.42 0.00 5.64 0.27 41.4 11.1 15479.62 0.00 5.64 0.21 40.1 9.7 15479.82 0.00 5.70 0.16 39.0 8.3 15480.02 0.00 5.66 0.12 37.6 7.1 15480.22 0.00 5.71 0.09 35.5 4.7 15480.42 0.00 5.70 0.07 34.8 4.2 15480.62 0.00 5.62 0.05 33.6 3.3 15480.82 0.00 5.59 0.04 33.8 3.7 15481.02 0.00 5.62 0.03 34.8 4.6 15481.22 0.00 5.54 0.02 34.4 4.6 15481.42 0.00 5.50 0.03 34.6 5.0 15481.61 0.00 5.49 0.18 34.3 4.8 15481.81 0.00 5.48 0.46 34.2 4.7 15482.01 0.00 5.50 0.89 35.0 5.4 15482.21 0.00 5.50 1.33 34.8 5.2 15482.41 0.00 5.39 1.54 34.8 5.7 15482.61 0.00 5.19 1.72 34.3 6.4 15482.81 0.00 4.95 1.96 36.0 9.4 15483.01 0.00 4.66 1.97 36.4 11.3 15483.21 0.00 4.45 1.73 38.5 14.5 15483.41 0.00 4.27 1.35 40.2 17.2 15483.61 0.00 4.14 1.02 42.2 20.0 15483.81 0.00 4.10 0.89 44.1 22.0 15484.01 0.00 4.13 1.01 46.0 23.8 15484.21 0.00 4.22 0.97 45.7 23.0 15484.41 0.00 4.23 1.16 46.6 23.9 15484.60 0.00 4.22 1.46 43.8 21.1 15484.80 0.00 4.24 1.70 39.9 17.0 15485.00 0.00 4.34 1.91 38.6 15.3 15485.20 0.00 4.39 1.85 36.3 12.7 15485.40 0.00 4.42 1.47 34.2 10.4 15485.60 0.00 4.44 1.12 34.2 10.3 15485.80 0.00 4.52 0.84 33.4 9.0 15486.00 0.00 4.70 0.63 34.1 8.8 15819.00 0.00 7.01 0.48 29.7 0.0 15819.21 0.00 7.02 0.49 35.9 0.0 15819.41 0.00 7.11 0.62 35.7 0.0 15819.62 0.00 7.04 0.61 34.3 0.0 15819.82 0.00 6.78 0.58 34.1 0.0 15820.03 0.00 6.44 0.66 32.6 0.0 15820.24 0.00 6.06 0.69 32.5 0.0 15820.44 0.00 5.83 0.76 33.0 1.7 15820.65 0.00 5.64 0.80 34.1 3.8 15820.85 0.00 5.51 0.65 36.3 6.7 15821.06 0.00 5.38 0.51 35.7 6.7 15821.26 0.00 5.33 0.47 37.1 8.4 15821.47 0.00 5.26 0.36 37.7 9.4 15821.68 0.00 5.30 0.28 38.8 10.3 15821.88 0.00 5.21 0.23 39.6 11.5 15822.09 0.00 5.03 0.49 38.8 11.8 15822.29 0.00 4.80 0.56 38.4 12.6 15822.50 0.00 4.54 0.75 37.1 12.7 15822.71 0.00 4.43 0.82 36.3 12.5 15822.91 0.00 4.47 1.03 36.3 12.2 15823.12 0.00 4.54 1.33 36.8 12.4 15823.32 0.00 4.67 1.58 35.4 10.2 15823.53 0.00 4.87 1.73 36.5 10.3 15823.74 0.00 5.16 1.77 35.3 7.6 15823.94 0.00 5.38 1.73 37.5 8.6 15824.15 0.00 5.54 1.70 40.8 11.0 15824.35 0.00 5.56 1.56 44.0 14.1 15824.56 0.00 5.48 1.38 46.4 17.0 15824.76 0.00 5.30 1.24 47.0 18.5 15824.97 0.00 5.03 1.19 45.4 18.3 15825.18 0.00 4.76 1.14 44.4 18.8 15825.38 0.00 4.59 1.23 42.8 18.1 ) ) 15825.59 0.00 4.64 1.42 41.0 16.1 15825.79 0.00 4.76 1.50 39.6 14.0 15826.00 0.00 4.87 1.58 38.7 12.5 16153.00 0.00 4.40 2.02 48.6 22.5 16153.20 0.00 4.45 2.19 65.2 38.8 16153.40 0.00 4.62 2.28 68.2 40.9 16153.59 0.00 4.79 2.41 68.7 40.3 16153.79 0.00 4.98 2.30 70.2 40.7 16153.99 0.00 5.02 2.16 71.2 41.5 16154.19 0.00 4.91 2.15 71.6 42.6 16154.38 0.00 4.82 2.05 71.6 43.0 16154.58 0.00 4.70 1.93 72.5 44.7 16154.78 0.00 4.53 1.80 71.2 44.4 16154.98 0.00 4.32 1.73 71.3 45.7 16155.18 0.00 4.16 1.76 70.4 45.8 16155.37 0.00 3.98 1.74 70.7 47.2 16155.57 0.00 3.89 1.52 71.0 48.0 16155.77 0.00 3.97 1.31 70.9 47.4 16155.97 0.00 4.07 1.13 70.7 46.5 16156.16 0.00 4.11 1.29 71.0 46.7 16156.36 0.00 4.10 1.42 74.6 50.3 16156.56 0.00 4.07 1.70 75.2 51.1 16156.76 0.00 4.09 2.03 77.0 52.8 16156.96 0.00 4.11 2.50 78.0 53.6 16157.15 0.00 4.12 3.03 74.7 50.3 16157.35 0.00 4.18 3.51 77.1 52.3 16157.55 0.00 4.30 3.86 74.8 49.3 16157.75 0.00 4.48 3.85 77.6 51.0 16157.95 0.00 4.75 3.59 77.0 48.9 16158.14 0.00 4.93 3.34 78.6 49.3 16158.34 0.00 5.00 3.02 78.4 48.8 16158.54 0.00 4.84 2.73 77.4 48.7 16158.74 0.00 4.72 2.26 78.0 50.1 16158.93 0.00 4.55 2.22 75.7 48.8 16159.13 0.00 4.41 2.36 75.0 48.9 16159.33 0.00 4.28 2.64 75.5 50.1 16159.53 0.00 4.24 2.77 75.5 50.4 16159.73 0.00 4.29 3.13 76.7 51.3 16159.92 0.00 4.31 3.63 76.2 50.6 16160.12 0.00 4.32 3.86 74.8 49.2 16160.32 0.00 4.41 3.78 75.3 49.2 16160.52 0.00 4.45 3.58 76.0 49.6 16160.71 0.00 4.43 3.38 75.9 49.7 16160.91 0.00 4.35 3.23 73.9 48.1 16161.11 0.00 4.24 2.90 73.7 48.6 16161.31 0.00 4.21 2.45 70.5 45.6 16161.51 0.00 4.18 2.06 68.5 43.7 16161.70 0.00 4.12 1.63 64.4 40.0 16161.90 0.00 4.14 1.24 63.3 38.8 16162.10 0.00 4.26 0.94 62.7 37.4 16162.30 0.00 4.51 0.70 62.4 35.7 16162.49 0.00 4.80 0.53 61.1 32.6 16162.69 0.00 4.97 0.40 62.1 32.6 16162.89 0.00 5.25 0.10 52.6 24.3 16163.09 0.00 3.53 0.03 38.8 18.3 16163.29 0.00 2.06 0.02 29.4 17.3 16163.48 0.00 1.34 0.01 21.6 12.3 16163.68 0.00 0.98 0.01 13.2 5.6 16163.88 0.00 0.74 0.01 10.2 3.7 16164.08 0.00 1.10 0.00 13.7 5.4 16164.27 0.00 1.81 0.00 29.0 18.2 16164.47 0.00 2.11 0.00 22.7 10.2 16164.67 0.00 2.12 0.00 21.8 9.2 16164.87 0.00 1.80 0.00 15.6 4.9 16165.07 0.00 1.39 0.00 12.0 3.8 16165.26 0.00 1.05 0.00 9.4 3.2 16165.46 0.00 0.79 0.00 6.8 2.1 16165.66 0.00 2.61 0.00 28.8 13.3 16165.86 0.00 4.40 1.85 44.0 17.9 16166.05 0.00 4.99 2.83 59.6 30.0 ) ) 16166.25 0.00 4.94 2.57 61.6 32.3 16166.45 0.00 4.78 1.39 65.2 36.9 16166.65 0.00 4.05 0.81 63.6 39.6 16166.85 0.00 3.23 0.30 58.4 39.2 16167.04 0.00 3.00 0.19 53.0 35.3 16167.24 0.00 2.86 0.14 46.4 29.5 16167.44 0.00 2.77 0.11 43.8 27.4 16167.64 0.00 2.71 0.08 40.0 24.0 16167.84 0.00 2.61 0.06 39.1 23.6 16168.03 0.00 2.57 0.04 38.4 23.2 16168.23 0.00 2.54 0.03 38.5 23.4 16168.43 0.00 2.53 0.03 38.3 23.3 16168.63 0.00 2.39 0.10 38.3 24.2 16168.82 0.00 2.26 0.21 37.7 24.3 16169.02 0.00 2.17 0.27 37.4 24.5 16169.22 0.00 2.21 0.23 36.5 23.4 16169.42 0.00 2.30 0.18 37.0 23.4 16169.62 0.00 2.39 0.14 37.5 23.3 16169.81 0.00 2.61 0.10 39.0 23.5 16170.01 0.00 2.83 0.08 39.0 22.2 16170.21 0.00 2.99 0.06 41.0 23.3 16170.41 0.00 3.15 0.04 41.2 22.5 16170.60 0.00 3.35 0.03 41.7 21.8 16170.80 0.00 3.59 0.02 41.1 19.8 16171.00 0.00 3.73 0.02 40.3 18.2 16171.20 0.00 3.74 0.01 38.9 16.8 16171.40 0.00 3.80 0.01 39.1 16.6 16171.59 0.00 3.96 0.01 38.4 14.9 16171.79 0.00 4.01 0.01 39.3 15.5 16171.99 0.00 3.90 0.00 38.5 15.4 16172.19 0.00 3.78 0.00 40.2 17.8 16172.38 0.00 3.69 0.00 41.0 19.1 16172.58 0.00 3.60 0.00 42.9 21.6 16172.78 0.00 3.37 0.00 43.6 23.7 16172.98 0.00 3.19 0.00 45.8 26.8 16173.18 0.00 3.11 0.00 45.1 26.7 16173.37 0.00 3.02 0.00 44.5 26.6 16173.57 0.00 2.92 0.00 44.5 27.2 16173.77 0.00 2.80 0.00 43.6 27.1 16173.97 0.00 2.68 0.00 41.7 25.8 16174.16 0.00 2.60 0.00 41.3 25.9 16174.36 0.00 2.47 0.00 39.5 24.8 16174.56 0.00 2.36 0.00 40.2 26.2 16174.76 0.00 2.33 0.00 39.0 25.2 16174.96 0.00 2.35 0.00 39.7 25.7 16175.15 0.00 2.48 0.00 45.1 30.3 16175.35 0.00 2.46 0.00 44.6 30.0 16175.55 0.00 2.43 0.00 47.6 33.2 16175.75 0.00 2.38 0.00 45.1 31.0 16175.95 0.00 2.26 0.00 43.7 30.3 16176.14 0.00 2.14 0.00 42.8 30.1 16176.34 0.00 1.97 0.00 35.4 23.7 16176.54 0.00 1.85 0.00 34.5 23.5 16176.74 0.00 1.88 0.00 31.8 20.7 16176.93 0.00 2.16 0.00 34.1 21.3 16177.13 0.00 2.28 0.00 33.6 20.1 16177.33 0.00 2.47 0.00 35.4 20.7 16177.53 0.00 2.58 0.00 35.8 20.5 16177.73 0.00 2.62 0.00 34.9 19.4 16177.92 0.00 2.71 0.00 34.6 18.5 16178.12 0.00 2.76 0.00 33.6 17.2 16178.32 0.00 2.78 0.00 32.4 15.9 16178.52 0.00 2.80 0.00 31.5 14.9 16178.71 0.00 2.88 0.00 29.7 12.6 16178.91 0.00 3.20 0.00 31.3 12.4 16179.11 0.00 3.36 0.00 31.1 11.1 16179.31 0.00 3.42 0.00 34.6 14.3 16179.51 0.00 3.35 0.00 32.3 12.4 16179.70 0.00 3.05 0.00 43.4 25.1 16179.90 0.00 2.59 0.00 22.4 7.0 ) ') 16180.10 0.00 2.00 0.00 16.4 4.5 16180.30 0.00 1.51 0.00 12.9 3.9 16180.49 0.00 1.14 0.00 8.3 1.6 16180.69 0.00 0.54 0.00 20.1 16.9 16180.89 0.00 1.71 0.00 29.7 19.6 16181.09 0.00 2.20 0.00 28.0 15.0 16181.29 0.00 2.10 0.00 32.2 19.8 16181.48 0.00 1.66 0.00 31.7 21.9 16181.68 0.00 1.77 0.00 34.2 23.7 16181.88 0.00 1.98 0.00 35.0 23.2 16182.08 0.00 2.10 0.00 34.6 22.1 16182.27 0.00 2.08 0.00 33.9 21.6 16182.47 0.00 2.13 0.00 34.3 21.6 16182.67 0.00 2.28 0.00 32.0 18.5 16182.87 0.00 2.33 0.00 32.4 18.6 16183.07 0.00 2.36 0.00 29.3 15.3 16183.26 0.00 2.37 0.00 30.4 16.4 16183.46 0.00 2.46 0.00 30.4 15.8 16183.66 0.00 2.63 0.00 31.6 16.1 16183.86 0.00 2.78 0.00 32.6 16.1 16184.05 0.00 2.96 0.00 35.5 18.0 16184.25 0.00 3.18 0.00 34.5 15.6 16184.45 0.00 3.41 0.00 35.2 14.9 16184.65 0.00 3.65 0.00 35.3 13.6 16184.85 0.00 3.77 0.00 35.5 13.1 16185.04 0.00 3.89 0.00 35.9 12.8 16185.24 0.00 3.99 0.00 35.9 12.3 16185.44 0.00 4.14 0.00 36.6 12.1 16185.64 0.00 4.13 0.03 36.9 12.4 16185.84 0.00 3.87 0.02 36.5 13.6 16186.03 0.00 3.70 0.14 37.1 15.1 16186.23 0.00 3.58 0.29 37.5 16.2 16186.43 0.00 3.52 0.30 38.4 17.5 16186.63 0.00 3.36 0.24 37.4 17.5 16186.82 0.00 3.24 0.18 40.8 21.6 16187.02 0.00 3.22 0.14 40.9 21.8 16187.22 0.00 3.25 0.10 43.1 23.9 16187.42 0.00 3.28 0.08 44.2 24.8 16187.62 0.00 3.26 0.06 45.3 25.9 16187.81 0.00 3.24 0.04 46.0 26.8 16188.01 0.00 3.29 0.03 46.7 27.2 16188.21 0.00 3.29 0.02 45.2 25.7 16188.41 0.00 3.32 0.02 45.5 25.8 16188.60 0.00 3.30 0.01 44.8 25.2 16188.80 0.00 3.20 0.01 43.1 24.1 16189.00 0.00 3.16 0.01 42.6 23.8 16189.20 0.00 3.17 0.01 43.1 24.3 16189.40 0.00 3.14 0.00 43.6 25.0 16189.59 0.00 3.10 0.00 43.8 25.5 16189.79 0.00 3.07 0.00 43.1 24.9 16189.99 0.00 2.99 0.00 43.6 25.9 16190.19 0.00 2.86 0.00 41.3 24.3 16190.38 0.00 2.74 0.00 38.6 22.3 16190.58 0.00 2.74 0.00 36.4 20.1 16190.78 0.00 2.75 0.00 32.2 15.9 16190.98 0.00 2.73 0.00 29.7 13.5 16191.18 0.00 2.79 0.00 29.4 12.8 16191.37 0.00 2.91 0.00 29.4 12.2 16191.57 0.00 3.03 0.00 30.7 12.8 16191.77 0.00 3.10 0.00 34.0 15.7 16191.97 0.00 2.91 0.00 40.1 22.8 16192.16 0.00 2.86 0.00 42.6 25.6 16192.36 0.00 2.76 0.00 46.6 30.3 16192.56 0.00 2.59 0.00 46.5 31.2 16192.76 0.00 2.41 0.00 44.9 30.6 16192.96 0.00 2.28 0.00 41.7 28.2 16193.15 0.00 2.31 0.00 39.4 25.7 16193.35 0.00 2.38 0.00 38.0 23.9 16193.55 0.00 2.45 0.00 37.5 23.0 16193.75 0.00 2.60 0.00 39.6 24.1 ) ) 16193.95 0.00 2.80 0.00 39.6 23.0 16194.14 0.00 2.91 0.00 41.8 24.5 16194.34 0.00 3.01 0.00 42.8 25.0 16194.54 0.00 3.06 0.00 43.5 25.4 16194.74 0.00 3.10 0.00 43.6 25.2 16194.93 0.00 3.09 0.00 43.1 24.7 16195.13 0.00 3.04 0.08 43.1 25.1 16195.33 0.00 3.04 0.34 43.9 25.9 16195.53 0.00 2.89 0.45 43.9 26.8 16195.73 0.00 2.67 0.40 44.1 28.3 16195.92 0.00 2.52 0.38 42.7 27.8 16196.12 0.00 2.31 0.35 40.4 26.7 16196.32 0.00 1.73 0.13 27.8 17.5 16196.52 0.00 0.79 0.05 11.2 4.0 16196.71 0.00 0.43 0.03 11.8 6.6 16196.91 0.00 0.27 0.02 13.1 7.8 16197.11 0.00 0.20 0.01 13.8 8.8 16197.31 0.00 0.15 0.01 14.7 10.0 16197.51 0.00 0.11 0.01 13.4 8.3 16197.70 0.00 0.68 0.00 10.3 3.9 16197.90 0.00 1.92 0.00 34.2 22.8 16198.10 0.00 2.81 0.00 41.3 24.4 16198.30 0.00 2.85 0.00 40.0 23.0 16198.49 0.00 2.79 0.00 38.1 21.5 16198.69 0.00 2.76 0.00 39.1 22.7 16198.89 0.00 2.84 0.00 42.6 25.6 16199.09 0.00 2.84 0.00 42.6 25.6 16199.29 0.00 2.79 0.00 38.4 21.8 16199.48 0.00 2.75 0.00 37.2 20.9 16199.68 0.00 2.81 0.00 41.0 24.1 16199.88 0.00 2.89 0.00 39.0 21.7 16200.08 0.00 2.97 0.00 45.9 28.2 16200.27 0.00 3.02 0.00 39.5 21.5 16200.47 0.00 3.00 0.00 46.0 28.2 16200.67 0.00 3.02 0.00 40.3 22.2 16200.87 0.00 2.96 0.00 45.9 28.2 16201.07 0.00 2.88 0.00 38.1 20.9 16201.26 0.00 2.79 0.00 39.0 22.3 16201.46 0.00 2.69 0.00 35.0 18.9 16201.66 0.00 2.55 0.00 36.6 21.3 16201.86 0.00 2.42 0.00 41.7 27.2 16202.05 0.00 2.36 0.00 38.0 23.9 16202.25 0.00 2.33 0.00 38.2 24.2 16202.45 0.00 2.38 0.00 39.7 25.6 16202.65 0.00 2.45 0.00 37.5 22.8 16202.85 0.00 2.57 0.00 35.4 20.1 16203.04 0.00 2.64 0.00 38.1 22.4 16203.24 0.00 2.58 0.00 36.9 21.5 16203.44 0.00 2.52 0.00 41.2 26.2 16203.64 0.00 2.43 0.00 39.3 24.7 16203.84 0.00 2.36 0.00 38.3 24.2 16204.03 0.00 2.30 0.00 39.6 26.0 16204.23 0.00 2.33 0.00 36.4 22.4 16204.43 0.00 2.42 0.00 42.9 28.4 16204.63 0.00 2.44 0.00 37.5 22.9 16204.82 0.00 2.59 0.00 37.5 22.1 16205.02 0.00 2.69 0.00 35.7 19.6 16205.22 0.00 2.42 0.00 42.1 27.6 16205.42 0.00 2.31 0.00 36.5 22.6 16205.62 0.00 2.35 0.00 36.4 22.4 16205.81 0.00 2.42 0.00 41.2 26.7 16206.01 0.00 2.42 0.00 40.5 25.9 16206.21 0.00 2.32 0.00 36.5 22.6 16206.41 0.00 2.26 0.00 36.8 23.3 16206.60 0.00 2.20 0.00 34.9 21.8 16206.80 0.00 2.11 0.00 33.0 20.4 16207.00 0.00 2.11 0.00 33.3 20.6 . Forest Oil Company File No. : 57111-02144 RU5A Redoubt Shoals Field Core LaI:Ï FTIR Mineralogy (Weight Percent) ;S' ;S' J!. Q J!. / Q ~ ~ " tlj .~ 15425.0 - 15425.8 2.63 72 6 0 0 6 0 0 0 16 1 3 12 15426.3 - 15427.0 2.64 69 7 5 0 7 0 0 1 11 2 0 9 15427.0 - 15428.0 2.63 57 12 0 0 6 0 0 0 25 1 0 24 15428.0 - 15429.0 2.64 53 7 5 0 9 6 0 0 20 5 5 10 15429.0 -15430.0 2.63 67 10 0 3 7 0 0 0 13 2 0 11 15430.0 - 15430.5 2.63 64 10 0 0 9 0 0 0 17 4 4 9 15431.0 -15432.0 2.63 65 9 0 0 8 0 0 0 18 3 4 11 15432.0 - 15433.0 2.63 65 8 5 0 7 0 0 0 15 4 3 8 15433.0 -15434.0 2.63 59 12 0 0 7 0 0 0 22 0 0 ~22 15434.0 - 15435.0 2.63 67 11 0 0 8 0 0 0 14 3 3 8 15435.0 - 15436.0 2.63 65 10 0 0 8 0 0 0 17 4 4 9 15436.0 - 15437.0 2.63 67 8 0 0 8 0 0 0 17 4 4 9 15437.0 - 15438.0 2.63 63 10 0 0 8 0 0 0 19 4 5 10 15438.0 - 15439.0 2.63 60 8 0 0 8 0 0 0 24 4 7 13 15439.0 - 15440.0 2.63 52 12 0 0 7 0 0 0 29 0 6 23 15440.0 - 15441.0 2.63 57 10 0 1 8 0 0 0 24 6 5 13 ~ 15441.0 - 15442.0 2.63 58 10 0 0 8 0 0 0 24 7 7 10 15442.0 - 15443.0 2.62 58 11 0 2 9 0 0 0 20 4 4 12 15443.0 - 15444.0 2.63 61 10 0 0 10 0 0 0 19 5 4 10 15444.0 - 15445.0 2.63 63 11 0 0 8 0 0 0 18 2 4 12 15445.0 - 15446.0 2.62 52 14 0 0 7 0 0 0 27 0 5 22 15446.0 - 15446.8 2.63 66 8 0 0 9 0 0 0 17 3 5 9 \'\ 15447.3 -15448.0 2.63 64 11 0 0 8 0 0 0 17 3 4 10 ~ 15448.0 -15449.0 2.63 60 8 5 0 8 0 0 0 19 3 4 12 r7 "-- 15449.0 - 15450.0 2.63 54 12 0 0 9 0 0 0 25 4 6 15 )..i 15450.0 - 15451.0 2.63 56 10 0 0 10 0 0 0 24 4 4 16 15451.0 - 15452.0 2.63 47 13 0 0 9 0 0 0 31 1 5 25 --, C- ~ A Forest Oil Company File No. : 57111-02144 RU5A Redoubt Shoals Field I:ore Lab FTIR Mineralogy (Weight Percent) ~ .~ ~ 8- li q ~ H- ! :; q ~ ~ .~ ~ q) ~ .~ 15452.0 - 15453.0 2.63 54 12 0 0 9 0 0 0 25 6 6 13 15453.0 - 15454.0 2.63 55 0 14 0 7 0 0 0 24 3 7 14 15454.0 - 15455.0 2.63 57 12 0 0 7 0 0 0 24 4 6 14 15455.0 -15456.0 2.63 57 11 0 1 8 0 0 0 23 4 4 15 15456.0 - 15457.0 2.63 56 11 0 0 9 0 0 0 24 4 5 15 15457.0 - 15458.0 2.63 47 14 0 0 9 0 0 0 30 0 5 25 15458.0 - 15459.0 2.63 59 9 4 0 8 0 0 0 20 4 5 11 15459.0 - 15460.0 2.63 61 11 0 0 9 0 0 0 19 4 5 10 15460.0 - 15460.5 2.63 62 11 0 0 10 0 0 0 17 3 4 10 15461.0 - 15462.0 2.63 61 9 0 0 9 0 0 0 21 2 6 13 15462.0 - 15463.0 2.63 61 11 0 0 10 0 0 0 18 3 4 11 15463.0 - 15464.0 2.63 51 13 0 0 10 0 0 0 26 0 4 22 15464.0 - 15465.0 2.63 60 10 4 0 8 0 0 0 18 4 5 9 15465.0 - 15465.8 2.63 56 13 0 0 9 0 0 0 22 4 6 12 15466.3 - 15467.0 2.63 57 11 0 1 10 0 0 0 21 4 5 12 15467.0 - 15468.0 2.63 52 11 0 0 10 0 0 0 27 5 6 16 ,-",' 15468.0 - 15469.0 2.63 54 12 0 0 10 0 0 0 24 3 4 17 15469.0 - 15470.0 2.63 50 14 0 0 9 0 0 0 27 0 3 24 15470.0 -15471.0 2.63 59 10 0 0 10 0 0 0 21 4 6 11 15471.0 -15471.8 2.63 63 9 0 0 9 0 0 0 19 4 5 10 15472.3 -15473.0 2.63 65 10 0 0 9 0 0 0 16 1 4 11 15473.0 - 15474.0 2.63 53 12 0 0 10 0 0 0 25 4 6 15 15474.0 -15475.0 2.63 60 8 4 0 8 0 0 0 20 5 6 9 15475.0 - 15476.0 2.63 55 13 0 0 9 0 0 0 23 0 2 21 15476.0 -15477.0 2.63 48 8 10 6 5 0 0 0 23 5 6 12 15477.0 - 15478.0 2.62 50 10 11 0 4 0 0 0 25 6 4 15 15478.0 - 15478.5 2.62 47 11 8 0 7 0 0 0 27 6 5 16 . Forest Oil Company File No. : 57111-02144 RU5A Redoubt Shoals Field Core Lab FTIR Mineralogy (Weight Percent) ~ ~ ~ q ~ f q ~ ~ " qj -- / 15479.0 -15480.0 2.62 47 10 8 0 8 0 0 0 27 4 5 18 15480.0 - 15481.0 2.62 57 10 4 0 9 0 0 0 20 3 3 14 15481.0 - 15482.0 2.63 61 10 0 0 6 0 0 0 23 0 3 20 15482.0 - 15483.0 2.63 71 7 0 0 3 0 0 0 19 2 4 13 15483.0 -15484.0 2.63 70 7 0 0 4 0 0 0 19 2 4 13 15484.0 - 15485.0 2.62 49 13 0 2 9 0 0 0 27 4 6 17 15485.0 -15486.0 2.62 46 13 0 2 7 0 0 0 32 4 9 19 15819.0 -15820.0 2.63 61 14 0 2 6 0 0 0 17 1 6 10 15820.0 - 15820.6 2.63 58 9 0 0 3 0 0 0 30 0 6 24 15821.2 -15822.0 2.64 49 5 15 3 0 1 0 0 27 4 11 12 15822.0 - 15824.0 2.63 32 12 22 0 6 0 0 0 28 4 8 16 15824.0 - 15825.0 2.64 64 7 8 0 0 0 0 0 21 5 5 11 15825.0 - 15826.0 2.63 68 9 0 0 5 0 0 0 18 2 5 11 16153.0 - 16154.0 2.63 42 6 7 0 0 0 0 0 45 14 4 27 16154.0 - 16155.0 2.64 35 9 0 0 0 0 0 0 56 13 4 39 16155.0 - 16156.0 2.63 39 5 7 0 0 0 0 0 49 15 4 30 ~ 16162.0 - 16162.8 2.64 41 9 0 0 3 0 0 0 47 11 5 31 16163.3 - 16164.0 2.64 43 10 0 2 3 0 0 0 42 12 4 26 16164.0 - 16165.0 2.63 46 7 4 0 4 0 0 0 39 7 5 27 16165.0 - 16165.8 2.64 67 8 6 0 5 0 0 0 14 5 0 9 16166.4 - 16167.0 2.64 64 7 0 0 5 0 0 0 24 6 3 15 16167.0 - 16168.0 2.64 35 9 0 0 0 0 0 0 56 15 10 31 16168.0 - 16169.0 2.65 68 11 0 0 5 0 0 1 15 4 0 11 16169.0 -16170.0 2.63 71 7 0 0 6 0 0 0 16 3 4 9 16170.0 -16170.5 2.66 60 7 0 0 6 0 0 1 26 4 4 18 16171.0 -16172.0 2.64 56 8 0 0 5 0 0 0 31 11 6 14 16172.0 - 16173.0 2.64 65 10 0 0 6 0 0 0 19 6 2 11 . Forest Oil Company File No. : 57111-02144 RU5A Redoubt Shoals Field Core Lab FTIR Mineralogy (Weight Percent) S S re- Q ~ # Q §- ~ ~ q; '-'. 16173.0 -16174.0 2.64 66 7 0 0 7 0 0 0 20 6 5 9 16174.0 -16175.0 2.63 67 9 0 0 6 0 0 0 18 4 0 14 16175.0 - 16176.0 2.64 62 7 0 0 8 4 0 0 19 5 5 9 16176.0 -16177.0 2.64 63 7 0 0 7 6 0 0 17 0 0 17 16177.0 - 16178.0 2.63 68 5 0 0 7 0 0 0 20 5 5 10 16178.0 -16179.0 2.64 70 12 0 0 5 0 0 0 13 3 0 10 16179.0 - 16180.0 2.63 74 6 0 0 5 0 0 0 15 3 3 9 16180.0 - 16181.0 2.63 67 9 0 0 6 0 0 0 18 4 5 9 16181.0 -16182.0 2.63 66 14 0 0 8 0 0 0 12 0 0 12 16182.0 - 16182.5 2.63 65 9 0 0 7 0 0 0 19 0 3 16 16183.0 - 16184.0 2.64 69 7 0 0 7 0 0 0 17 4 6 7 16184.0 - 16185.0 2.64 68 7 0 0 5 0 0 0 20 5 7 8 16185.0 -16186.0 2.64 75 6 0 0 5 0 0 0 14 4 4 6 16186.0 - 16187.0 2.64 73 8 0 0 4 0 0 0 15 3 4 8 16187.6 - 16187.9 2.64 62 10 0 0 4 0 0 0 24 5 9 10 16188.4 - 16189.0 2.63 63 7 0 0 5 0 0 0 25 0 8 17 ~ 16189.0 - 16189.8 2.64 68 7 0 0 2 0 0 0 23 2 7 14 16190.3 -16191.0 2.64 69 5 0 0 5 0 0 0 21 3 7 11 16191.0 -16192.0 2.63 68 4 0 0 6 0 0 0 22 3 7 12 16192.0 -16193.0 2.63 49 8 4 0 8 0 0 0 31 8 10 13 16193.0 - 16194.0 2.63 55 9 0 0 10 2 0 0 24 4 6 14 16194.0 -16195.0 2.64 53 15 0 0 8 0 0 2 22 0 4 18 16195.0 - 16196.0 2.63 62 5 0 0 6 0 0 0 27 8 8 11 16196.0 -16196.8 2.64 64 6 0 0 5 0 0 0 25 5 8 12 16197.3 -16198.0 2.63 64 10 0 2 6 0 0 0 18 3 4 11 16198.0 - 16199.0 2.63 65 5 0 0 5 0 0 0 25 0 6 19 16199.0 -16200.0 2.63 74 5 0 0 4 0 0 0 17 1 3 13 . Forest Oil Company File No. : 57111-02144 RU5A Redoubt Shoals Field Core Lab FTIR Mineralogy (Weight Percent) S' S' II- Q II- f Q ~ ~ " (Q ~ 16200.6 -16201.0 2.65 62 6 0 0 3 6 0 1 22 0 6 16 16201.0 - 16201.9 2.64 72 0 0 0 6 2 0 0 20 3 6 11 16202.4 - 16203.0 2.64 58 6 0 0 3 6 0 0 27 7 7 13 16203.0 -16203.5 2.64 57 12 0 2 5 2 0 0 22 3 10 9 16204.9 - 16205.0 2.60 41 14 0 0 32 0 0 0 13 0 0 13 16205.0 - 16205.5 2.64 59 0 14 0 4 0 0 0 23 4 8 11 16206.0 - 16207.0 2.64 52 9 12 0 0 0 0 0 27 6 10 11 .~ ,J DJ- -I G 8 RESERVOIR EVALUATION REDOUBT UNIT No. SA WELL (HEMLOCK CONGLOMERATE) REDOUBT SHOAL FIELD COOK INLET, ALASKA Prepared for: Forest Oil Corporation Job No. 030178 Core Laboratories, Inc. Petroleum Services Advanced Technology Center 6316 Windfern Houston, Texas 77040 April 1 0, 2003 Mr. Art Saltmarsh - Geologist Forest Oil Corporation 310 K Street Suite 700 Anchorage, AK 99501 Subject: Well: Location: Job Number: Reservoir Evaluation Study Redoubt Unit No. 5A Redoubt Shoal Field, Cook Inlet, Alaska 030178 Dear Mr. Saltmarsh: This report presents a reservoir evaluation of fifteen (15) conventional core samples from the Redoubt Unit No. 5A Well. Redoubt Shoal Field. Cook Inlet, Alaska. The samples come from the Oligocene-age Hemlock Conglomerate over the depth interval between 15436.50 feet and 16197.50 feet. Detailed thin section descriptions (including a 250- point modal analysis), scanning electron microscopy (SEM), and whole rock and clay X- ray diffraction (XRD) data are included for each sample. The petrographic descriptions can be found in Plates 1 through 15 after the text portion of this report. while the XRD data is given in Table 2. Six (6) paper copies and one (1) CD copy of this report have been sent to your office in Anchorage, Alaska. Thank you for selecting Core Laboratories. Inc. to perform this study. If you have any questions or comments concerning this report, please contact me on my direct number at (713) 328-2537 or by email atmquest@corelab.com. Yours sincerely. Core Laboratories, Inc. Dr. Martin Quest. Senior Geologist. Petroleum Services Brian D. Nicoud, Manager Reservoir Geology, US Gulf Coast Petroleu m Services TABLE OF CONTENTS GEOLOGIC ANALYSIS INTRODUCTION............................................................................................................ 1 Study Methods................................................................................................................ 1 Table 1. Listing of Samples Selected for Petrographic Analysis...................................................... 1 DISCUSSION OF RESULTS.......................................................................................... 2 Table 2. Whole Rock and Clay Mineralogy from X-Ray Diffraction Table 3. Point Count Data Figure 1. Ternary Diagram - Folk et. al. (1970) Sandstone Classification RESERVOI R PROPERTI ES........................................................................................... 4 Figure 2. Porosity vs. Klinkenberg Permeability Cross-plot Figure 3. Relationship Between Core Porosity and Rock Fragment Abundance/Average Grain Size FORMATION SENSITIVITY............................................................................................ 4 REFERENCES............................................................................................................... 5 THIN SECTION & SEM DESCRIPTIONS WITH PHOTOMICROGRAPHS INTRODUCTION At the request of Forest Oil Corporation, a reservoir evaluation has been made of fifteen (15) conventional core samples recovered from the Redoubt Unit No. 5A Well. Redoubt Shoal Field. Cook Inlet, Alaska. The samples are from the Oligocene-age Hemlock Conglomerate and were taken over the depth interval between 15436.50 feet and 16197.50 feet. A detailed thin section description (including a 250-point modal analysis) was made of each sample to document textural characteristics, detrital grain composition. authigenic mineralogy, diagenetic features. pore types. and pore inter- connectivity with the aim of characterizing reservoir quality. Analysis of the samples by scanning electron microscopy (SEM) provided information about clay types, the location of clay minerals, and textural relationships between authigenic mineral phases. X-ray diffraction analysis (XRD) provided data on the bulk and clay mineral composition. All samples were photographed to document textural and compositional features. Digital images of the samples are presented in Plates 1 through 15 following the text of this report. Study Methods Fifteen (15) samples were selected by Forest Oil Corporation for detailed petrographic analysis (Table 1). The thin section samples were vacuum impregnated with blue dyed epoxy resin to accent porosity. and stained for carbonates with a solution of Alizarin Red S and potassium ferricyanide. This stains non-ferroan calcite pink, ferroan calcite purple. and ferroan dolomite turquoise. while non-ferroan dolomite is unstained. One low- and one high-magnification photomicrograph were taken of each thin section. SEM samples were coated under vacuum with a gold-palladium alloy and then examined with a Hitachi S-2400 Scanning Electron Microscope operating at 20 kV. The samples are named using the sandstone classification scheme of Folk et al (1970). Table 1. Listing of Samples Selected for Petrographic Analysis Depth, Classification Average Sorting Porosity, Kinf, feet, Grain Size \ mm ~ . . I .." ~ . 15436.50 15441.50 15448.50 15449.50 15450.50 15455.50 15462.50 15464.50 15476.70 15485.30 16164.50 16168.50 16174.50 16186.50 16197.50 Feldspath iclitharenite Feldspathic litharenite Feldspathic litharenite Feldspathic litharenite Feldspathic litharenite Feldspathic litharenite Feldspathic litharenite Feldspathic litharenite Litharenite Litharenite Feldspathic litharenite Litharenite Litharen ite Litharen ite Litharenite 0.349 0.271 0.369 0.266 0.301 0.245 0.318 0.365 0.946 0.297 0.071 & 0.157 0.431 0.333 0.433 0.318 Moderate Moderate Moderately well Moderately well Moderately well Moderately well Moderately well Moderate Poor Moderately well Well Moderate Moderate Moderate Moderate 12.8 9.8 11.9 11.7 8.6 11.0 14.2 11.5 4.7 6.1 3.5 12.6 9.9 10.8 9.5 1 Average grain size is based on 20 random grain measurements per thin section. 1 13.2 0.206 7.59 2.06 0.0903 0.187 50.0 0.686 0.409 0.166 0.0848 8.2400 1.75 4.57 0.513 Whole rock and clay X-ray diffraction (XRD) analysis was performed to determine formation mineralogy. Samples selected for XRD were dried and cleaned of any obvious contaminants. before being weighed and placed in a sonic cell disrupter. The resultant slurry was then centrifuged to separate each sample into a > 4 microns and a < 4 microns fraction. The < 4 microns sample was analyzed in an air-dried state on a Phillips APD 3600 diffractometer. then treated with ethylene glycol vapor for 24 hours and analyzed again. The> 4 microns fraction was milled and packed into an aluminum sample holder before being analyzed with the diffractometer. The resultant diffracto- grams were analyzed for mineral content using a profile-fitting algorithm. The integrated areas from the profile-fitting algorithm were then entered into a spreadsheet that contained the correction coefficients for numerous minerals. These coefficients were obtained according to the adiabatic method outlined by Chung (1974). XRD data is given in Table 2. DISCUSSION OF RESULTS The samples are mainly sandstones. with one (1) pebbly sandstone (15476.70 ft) and one (1) micaceous sandstone (16164.50 ft). Average grain size from thin section ranges from 0.245 mm (upper fine sand) to 0.946 mm (upper coarse sand), with most samples in the lower to upper medium sand class. The micaceous sandstone at 16164.50 feet shows size-sorted laminae (Plate 11A), with average grain size from 0.071 mm (lower very fine sand) to 0.157 mm (lower fine sand). Sorting ranges from poor to well. with most samples in the moderate to moderately well sorted range. Sorting tends to be poorest in the samples with the coarsest average grain size, while laminated samples can have variable sorting (e.g. 16164.50 ft - Plate 11A). Grain packing varies considerably among the analyzed samples. and appears to be partly responsible for the observed variation in reservoir quality. Tightly packed samples are characterized by a predominance of long and concavo-convex grain contacts (with rare sutured or interpenetrating contacts) and typically have low porosity and permeability (Plate 10). Samples with loose to moderate packing have a predominance of point contacts and preserve open intergranular areas with moderate to good porosity and permeability (Plate 7). Sorting and the precipitation of pore-filling cements modify this basic relationship. Point count modal analysis indicates that quartz and rock fragments are the most common detrital grains, ranging in abundance from 38.30/0 to 70.1 %2 and 22.4% to 54.6°k respectively (Table 3). Most of the quartz is monocrystalline, although poly- crystalline grains are common in the coarser grained samples. Quartz abundance from XRD varies between 560/0 and 770/0. although this will also include a contribution from quartz cement. chert. and rock fragments (Table 2). The rock fragments are dominated by volcanic and argillaceous sedimentary clasts (siltstone, shale, and sandstone). with less common igneous plutonic and metamorphic fragments. Chert is present in the deeper samples. Many of the rock fragments appear to be relatively soft (ductile), and are deformed around more resistant quartz and feldspar grains (Plates 18. 58, & 88). Feldspars are the third major sandstone component, ranging in abundance from 6.40/0 to 16.5%, with from 2.50/0 to 13.3% potassium feldspar and 0.70/0 to 6.1 % plagioclase. 2 Modal analysis expressed as volume percent. 2 XRO estimates of total feldspar abundance range from 80/0 to 250/0. with potassium feld- spar ranging from 20/0 to 130/0 and plagioclase from 60/0 to 160/0 (Table 2). Comparisons between thin section modal analysis and XRO estimates of feldspar abundance are complicated by the occurrence of igneous plutonic and volcanic rock fragments, all of which contain feldspars. However, both data sets indicate a crude decrease in total feldspar abundance with depth. Thin section analysis indicates that the potassium feldspar is a mixture of untwined orthoclase and microcline. Sericite replacement and partial to complete grain dissolution are features of all feldspars (Plates 1 B. 5B, 7B. 7C, 10B. 12B. 14B. & 15B). Based on the relative proportions of quartz. feldspar, and rock fragments. the samples are classified as a mixture of feldspathic litharenite and litharenite according to the sandstone classification of Folk et al (1970 - Figure 1). Accessory grains identified in thin section include biotite, muscovite, hornblende. and olivine. The mica plates are commonly deformed around. or squeezed between. more resistant grains (Plates 4B. 5B, & 8B). This helps to isolate intergranular pores. Mica is abundant in the sample from 16164.50 feet. Fine-grained matrix is not observed in any of the studied thin sections. which probably reflects high depositional energies. The rock fragments and heavy mineral suite suggest that the sediments in the studied interval were derived from an igneous plutonic and volcanic-dominated source. However. some erosion of laterally adjacent floodplain deposits is suggested by the occurrence of siltstone and shale lithoclasts. Authigenic minerals are poorly developed among the studied samples. with induration occurring mainly via mechanical compaction. Identified cementing minerals include clay. quartz, and pyrite, with trace amounts of calcite seen in some samples. Kaolinite is the only clay mineral identified in thin section. occurring as a milky white, pore-filling cement (Plates 2B, 3B. 6B, 7B, 12B. & 13B). Under the SEM kaolinite occurs as poorly formed vermicular aggregates filling intergranular areas (Plates 10, 120. 130, 140. & 150). Kaolinite abundance from XRO ranges between 8°,10 and 49% of the clay fraction (Table 2), or between 1 % and 80/0 of the whole rock. Authigenic illite is also identified under the SEM (Plates 20, 30. 40. 50. 60, & 100). It occurs as a pore-lining and pore-bridging clay, consisting of ragged ribbons and filaments. It probably has a greater exposure to completion or stimulation fluids than the kaolinite because of its pore-lining habit. XRO estimates of authigenic illite abundance are complicated by the presence of detrital illite in rock fragments and by the occurrence of mica (Table 2). Other clay minerals identified by XRO include smectite and chlorite. Smectite abundance from XRO ranges between 14% and 700/0 of the clay fraction, or from 2% to 130/0 of the whole rock. Most samples have less than 5% smectite. The location of the smectite is problematic, because it is only identified in one SEM sample (15476.70 ft- Plate 90). It is likely that most of the smectite is associated with altered volcanic rock fragments, and hence may not have a large surface area exposed to completion or stimulation fluids. However, it still poses a risk of formation damage. Authigenic chlorite is similarly absent under the SEM. although thin section observations suggest 3 that it occurs as an alteration product of rock fragments. Chlorite abundance from XRO ranges from 100/0 to 21 % of the clay fraction. or between 1 % and 30/0 of the whole rock. Quartz cement is a minor component of the studied samples, forming thin. incomplete syntaxial overgrowths around detrital quartz grains (Plates 10, 3D. 40. 50, 80, & 150). It has a limited role in the lithification of the studied samples. Pyrite occurs as a replacement mineral after rock fragments and iron-rich mica. RESERVOIR PROPERTIES Helium porosity and Klinkenberg permeability for the studied samples are displayed in Figure 2. Porosity ranges between 3.50/0 and 14.20/0 (average = 9.90/0). while permeability varies between O.0848md and 50.0md (average = 5.98md, median = O.686md). The majority of the visible pores are primary intergranular, with lesser amounts of secondary intragranular and grain moldic pores also noted. The latter are associated with dissolved feldspars and rock fragments. Intergranular pores are reduced by mechanical compaction, with some loss also through clay authigenesis. Intercrystalline micropores occur in argillaceous rock fragments and authigenic clays. Although mechanical compaction is the principal agent of porosity loss, the studied samples respond differently to compaction depending on their detrital mineralogy. Samples with relatively high quantities of quartz and feldspar and relatively low quantities of rock fragments tend to resist compaction and preserve open intergranular pore systems. This can be seen in the photomicrographs for the sample from 15462.5 feet (Plate 7 A). This sample has 68% quartz, 90/0 feldspar. and 230/0 lithics from point count modal analysis (normalized to exclude porosity). Conversely. samples with high amounts of ductile rock fragments tend to suffer severe compaction. with the softer grains deforming around more resistant quartz and feldspar to occlude adjacent intergranular areas. The sample from 15485.30 feet is a good example (Plate 10A). This sandstone has 460/0 quartz. 12% feldspar, and 43% lithics and has scattered poorly connected intergranular pores. The relationship between rock fragment abundance and porosity is illustrated in the upper graph in Figure 3. This shows that porosity increases with decreasing amounts of rock fragments. The lower graph in Figure 3 shows that there is also a grain size effect on porosity. with porosity being higher in coarser grained samples. In summary, there appears to be a good relationship between framework grain composition, grain size, and porosity preservation among the studied sample suite. FORMATION SENSITIVITY Smectite clay may lead to permeability loss through swelling reactions when exposed to freshwater. The location of the clay is important, since grain-replacing clay is less of a problem than pore-lining clay. The lack of obvious pore-lining smectite in most of the studied samples suggests that it is mostly grain replacive, and hence poses less of a potential for formation damage. However. in reservoirs that contain swelling clays, a number of approaches may be used to inhibit the potential damage. Swelling clays are in equilibrium with formation fluids; therefore, formation brines will cause the least 4 amount of additional clay swelling. If formation brine is not available, drilling with potassium and calcium chlorite-treated fluids will reduce the swelling of sodium smectite. Hydrofluoric acid treatment can lead to formation damage through adverse reactions with potassium feldspar and sodium plagioclase. which can dissolve and re-precipitate as an insoluble fluorosilicate gel. The presence of authigenic chlorite may also lead to formation damage when using HCI as a clean up or break down fluid. Iron is released during partial dissolution of the chlorite and can precipitate immediately as ferric hydroxide. In addition, interplanar cations within the chlorite structure (e.g. Fe2+. Mg2+. and A13+) are leached during HCI stimulation to leave a silica residue. Other reservoir problems may be caused by excessive flow rates and/or high-pressure differentials, which may lead to migration of fines. Almost all reservoirs contain fine particles or 'fines'. These commonly are clays, of which kaolinite and illite are the most damaging. Both clays are identified in the studied samples. Some of these are loosely attached and will migrate to pore throats at elevated flow rates. Determining maximum flow rates and types of clays through laboratory experiments can minimize migration of fines. Perforate with low to underbalanced pressures to prevent pressure surges. The use of clay stabilizers. which may include potassium hydroxide. hydroxy-aluminium, various polymers. and heavy-end hydrocarbons. can help bind particles to grain surfaces. REFERENCES Chung, F .H. (1974). A new X-ray diffraction method for quantitative multicomponent analysis. Advances in X-ray Analysis. 17. p. 106-115. Chung, F.H. (1974). Quantitative interpretation of X-ray diffraction patterns of mixtures. I. Matrix-flushing method for quantitative multicomponent analysis. Journal of Applied Crystallography, 7, p. 519-525. Chung, F.H. (1974). Quantitative interpretation of X-ray diffraction patterns of mixtures. II. Adiabatic principle of X-ray diffraction analysis of mixtures. Journal of Applied Crystallography, 7, p. 526-531. Folk, R. L., Andrews, P. B., & Lewis, D. W. (1970). Detrital sedimentary rock classification and nomenclature for use in New Zealand. New Zealand Journal of Geology and Geophysics. 13. No.4. p. 937-968. 5 Company: Forest Oil Corporation Well : Redoubt Unit No. 5A Location: Redoubt Shoal Field, Cook Inlet, Alaska Table 2. Whole Rock and Clay Mineralogy from X-Ray Diffraction 15436.50 67 13 10 0 ' 0 10 20 27 41 12 15441.50 62 9 13 0 10 15448.50 65 10 11 0 0 14 20 26 38 15 15449.50 63 9 15 0 24 11 15450.50 60 11 13 0 0 16 33 28 28 11 15455.50 62 8 13 0 28 14 15462.50 72 7 12 0 0 9 25 26 37 12 15464.50 64 9 13 0 25 14 15476.70 81 2 6 0 0 11 61 16 12 11 15485.30 56 9 16 0 19 11 16164.50 59 6 12 0 0 23 22 30 34 14 16168.50 77 6 7 0 10 10 16174.50 70 7 9 0 1 13 15 26 41 18 16186.50 73 7 6 0 14 38 21 16197.50 70 9 9 0 0 12 17 26 39 18 Tr = trace Petroleum Services 6316 Windfern Houston, TX 77040 (713) 328-2673 http://www.corelab.com CORE LABORATORIES, INC. - PETROLEUM SERVICES Company Well Age Location Forest Oil Corporation Redoubt Unit No. 5A Oligocene (Hemlock Conglomerate) Redoubt Shoal Field, Cook Inlet, Alaska Table 3. Point Count Data C.L. File Number Date Geologist 030178 Apr. 2003 M. Quest Modal Percent* Sample. Number "... .'.,. '. ".12 ,. " .17 ... '.. ,24 25 ,26..,. 31 ,. .38 , 40 . '&'.' ..'..~.,.., .... '.. ..' ., ,.,..'. "'."15441.50' 15448.5015449.50" ,,' '.' ".,., *based on a 250 point count Tr = trace «0.4%) 28.0 39.2 44.4 17.6 12.0 9.2 17.2 6.4 8.8 7.2 4.0 10.8 4.8 7.2 2.0 2.8 3.6 5.2 3.2 1.2 1.6 2.0 2.8 2.0 3.6 8.0 9.6 8.4 6.0 7.2 11.6 9.6 10.0 4.0 2.4 0.8 2.0 2.4 2.0 0.4 1.6 8.0 8.4 10.4 9.6 12.0 8.8 6.4 11.2 Tr 4.0 5.2 4.0 3.0 8.0 5.0 3.8 10.0 2.0 Tr 1.0 0.8 0.6 1.0 2.8 Tr Tr Tr Tr 2.0 Tr 1.0 Tr Tr Tr Tr Tr Tr Tr Tr Tr Tr Tr Tr Tr Tr Tr 0.8 1.6 0.4 0.4 1.2 0.8 0.4 10.0 6.8 7.6 5.6 7.2 9.6 10.4 3.2 1.0 1.0 2.0 2.0 1.0 1.0 Tr 1.0 2.2 0.8 2.4 1.2 1.0 2.2 1.2 Page 1 of 2 .. Coœ Lab RESE1\VOIR OPTIKlZATIOK CORE LABORATORIES, INC. - PETROLEUM SERVICES Table 3. Point Count Data Company Well Age Location Forest Oil Corporation Redoubt Unit No. 5A Oligocene (Hemlock Conglomerate) Redoubt Shoal Field, Cook Inlet, Alaska C.L. File Number Date Geologist Modal Percent* 030178 Apr. 2003 M. Quest Sample Number ..'.', ..' '. ,". ,. . ,,',. , . ...' ..' 52< .'.. ..' .59.. ...' ",... ,<72 ' 76'....82. ... .92. .. 99 .".'_,1.-'~,..,-- .'...',.... ,,' .,.'.'.'..",1 "15485.30..',.'1' . .;.,'1.'.16174.50.,.;.1' ,.. 1 *based on a 250 point count Tr = trace «0.4%) 30.8 34.4 35.2 37.8 6.0 7.6 6.0 8.4 9.6 9.0 8.0 4.8 8.4 4.0 4.4 3.2 3.6 2.0 2.0 2.4 0.4 1.2 2.0 2.8 3.2 2.8 0.4 0.4 0.8 40.8 15.6 9.2 8.4 12.4 10.8 10.0 0.8 0.8 0.4 5.2 6.0 20.8 3.2 9.6 9.2 8.0 9.2 2.0 2.0 1.0 2.0 4.0 35.0 2.1 4.4 0.8 3.2 0.8 3.4 Tr Tr Tr 2.0 Tr 2.0 2.0 Tr Tr 2.0 1.0 1.0 1.0 0.8 2.8 1.6 0.8 1.8 8.8 8.4 7.6 5.6 0.2 2.0 2.0 2.0 2.0 2.0 4.4 2.0 0.4 2.8 Page 2 of 2 . Core Lab RESERVOIR OPTIMIZATION Figure 1 Sandstone Composition (Folk et ai, 1970) Forest Oil Corporation Redoubt Shoal No. 5A Well Redoubt Shoal Field, Cook Inlet, Alaska HMDC 8-16 25 Depth I Qtz 5502.98 I 73 5502.98 I 73 5502.98 I 73 5502.98 I 73 5502.98 I 73 5502.98 I 73 5502.98 I 73 5502.98 I 73 5502.98 73 I Average 73.0 I Fldspr I Rock Frgs I Chert I I 13 I 4 I 0 I I 13 I 4 I 0 I I 13 I 4 I 0 I I 13 I 4 I 0 I I 13 I 4 I 0 I I 13 I 4 I 0 I I 13 I 4 I 0 I I 13 I 4 I 0 I 13 4 0 13.0 4.0 0.0 1 Total I Q I 90 870/0 90 73°/Ó 90 85% 90 890/0 90 89% 90 88% 90 880/0 90 85°/Ó 90 81 % 720/0 770/0 64°/Ó 80% 900/0 81% 90.0 810/0 F I L 1 % 120/0 1°/Ó 250/0 2% 13% 0% 110/0 00/0 11 0/0 0% 12% 1 % 12°/Ó 00/0 15% 1°/Ó 18% 2% 27% 2% 21°/Ó 0% 36% 1 % 19% 1% 9% 2°/Ó 17°/Ó 14% 4% Figure 1 Sandstone Composition (Folk et ai, 1970) Forest Oil Corporation Redoubt Shoal No. SA Well Redoubt Shoal Field, Cook Inlet, Alaska Quartz Quartzarenite ------- ------- Subfeldsarenite , , , , , , , , - -- - - - - - - -- - - -'<. - - - - - - - -- - - - -. \\ //~'\\ // Sublitharenite ':.... ..\~\<~/nn~:*:~:\I¥n~~:*I.... ,::~:.. ....;, \\ ;/ \\ ,/ \, # \\ .;/ ':,:,:nmn':::\( .mm~,)«(nm:~,\:~,..nm :'~:~.mnn:,:,;, mnmn':':"lm n.>\/:.....::~\/~n...:\,l.. n::':'~"l.n..nm , , , ,\ ;\ ;, ".' Feldsarenite .~~~- __m 'Lithic Feldspathic .-- -}: FeldS~,~;nite\\ / Lit~~~enite " \\\ ,/;/ Feldspar Litharenite \\... /1/ " Lithics Petroleum SeNices, Core Laboratories, Inc. Forest Oil Corporation Redoubt Unit No. SA Well Figure 2. Porosity vs. Klinkenberg Permeability Cross-plot. 100 . 10 e-8 U) ~ . CJ ... ca :'2 E ~ :c co 1 CI> E ... CI> D. ~ CI> .c c CI> ~ .5 52 0.1 . 0.01 0 2 4 6 8 10 12 14 16 Porosity, percent Petroleum SeNices, Core Laboratories, Inc. .. Core tab RESERVOIR DI'TtMIZATIQK Forest Oil Corporation Redoubt Unit No. SA Well Figure 3. Relationship Between Core Porosity and Rock Fragment Abundancel Average Grain Size from Thin Section Modal Analysis. 60 50 ..... c CI) ~ CI) 40 c. .i c CI) 30 E C) cu ~ LL 20 ~ CJ 0 a:: 10 0 0 2 4 6 8 10 12 14 16 Porosity, percent 0.5 fn 0.45 ~ ~ 0.4 E == 0.35 .s .. 0.3 CI) N ü) 0.25 c 16 0.2 ~ C) CI) 0.15 C) ~ 0.1 > « 0.05 0 0 . .,~ .#~ . ~ . .. . 2 6 10 12 14 16 8 4 Porosity, percent Petroleum Services, Core Laboratories, Inc. Core Inventory Forest Oil /Osprey ;{ 0 ~ '- 1 & g RU #5A 09/11/02 Total 21 boxes Core #1 Box #1 Box #2 Box #3 Box #4 Box #5 Box #6 Box #7 Box #8 Box #9 Box# 10 Box # 11 Box #12 Box # 13 Box # 14 Box #15 Box # 16 Box # 1 7 Box #18 Box # 19 Box #20 Box #21 15425' - 15428' 15428' -15431' 15431' - 15434' 15434' - 15437' 15437' - 15440' 15440' - 15443' 15443' - 15446' 15446' - 15449' 15449' - 15452' 15452' - 15455' 15455' - 15458' 15458' - 15461' 15461' - 15464' 15464' - 15467' 15467' - 15470' 15470' -15473' 15473' - 15476' 15476' - 15479' 15479' - 15482' 15482' - 15485' 15485' - 15485.5' ,,' Core Inventory Forest Oil/Osprey RU #5A 09/22/02 Total 22 boxes Core #2 Box #1 15819'-15822' Box #2 15822' - 15825' Box #3 15825' - 15826' Core #3 Box #1 16153' - 16156' Box #2 16156' - 16159' Box #3 16159' - 16162' Box #4 16162' - 16165' Box #5 16165' - 16168' Box #6 16168' - 16171' Box #7 16171' - 16174' Box #8 16174' - 16177' (two sections of core in the box, this was the connection point) Box #9 16177' -16180' Box#10 16180' - 16183' Box #11 16183' - 16186' Box#12 16186' -16189' Box #13 16189' - 16192' Box #14 16192' -16195' Box #15 16195' - 16198' Box #16 16198' -16201' Box #17 16201' - 16204' Box #18 16204' - 16206' (last 2' of core barrel) Box # 19 16206' - 16207' (core left in the shoe) ~~~\Y\& &C@-033 :30&-/ {o?: p: ~::' ~ ~~~¡~ ,F~. '^"# I IL~ (; ,"~:) l~ 'f'''/ t') ^ I ß;"~ ,If if '~,.f\' /I '~f ~::) i:' ¡f "bl j~~ iF 18=~ "'\::'" i lIt 'I ""'~"" #~. U'~ A d #5A ("l ¡§,;:) ,I ~'". {\ï '. J ;.: ~~; n F'.',"¥l""~l'), ""\,{' G ..~.. (~"t' i !..~. f ,f'''~. Ir"~l A,'.' 1'" a:"" ,") i~ " . ~t! . ..-, f "'~ . '"" . .~ ll. ~~ ~~". .d~~ '1~.r;r; ~~ , c""\ ,.""", ,..' C of.' I 'II.." . ) ~ ..... "",,~ ~ê "",,.,.,r ~ ." " \ ) ~"" f.~"";~ Ji"" \irl~' ",,", ,,,,,,. ,," [''''''Ii' '11.J'. ~ ;....... fi' f J l"]I r'" l."''''f':J (..~, ~..., r"" r" i: . "l '.r ~(.' I I, r::'~r'-' llt l~ ~~.J1.4~A-~, J. ,g' ..... ~"""" , ., .f! ~ """,': "1 %oJ¡ f \ft FINAL WELL REPORT October 1, 2002 í""~ f''''''' (~t E" I. ~ 11:'" (, ':") ~ ,.,.., ""...\ ~", ,~ '.1'''-''11 ...~ "r.!"f"",. ..; '.~ 't:"ft"'.f" {,PH 232003 ,) i\!~~~~ft or~ li Gas Gonr;. GümrM~1{n ^mi1m~~ Lees Browne, Jr. - Sr. Logging Geologist Chris Ornt - Logging Geologist George Baker - Sr. Logging Geologist Andrew Buchanan - Sr. Logging Geologist Peter Dykema - Logging Geologist [== El~OCH ) Forest Oil Corporation Redoubt Unit #5 TABLE OF CONTENTS WELL RESU ME..... ...... ............ ..... .... ..... ..... .'...... ..... ...... .'... ..... .... .... .'.... ............ ....... ...........2 G EO LOG ICAL DISC U SSION ........ ......... .......... ............. ......... ....... .......... ..... .............. .... 4 CAI L Y ACTIVITY SU M MARY................... ... ................... ................... .... ................... ......6 LITHOLOGY AN D COM MENTS ................................................................ ...................21 SURVEY INFO RMA TIO N ... ........ .... ...... ......... ........ ....... ... ....... .... ... .... ..... .... ... ............ ....67 CAI L Y MUD PROP ERTIES.... ............. ........... ....................... .................................. ...... 74 BIT RECORD ... ..... ........ ...... .... .... ......... ... ............... ..... ..... ............ ......... .................... .... 78 TIM E DISTRIB UTIO N... ... ..................... ........ ............ ....... ....... ... ... ..... .... ... ..... ......... .... ...81 ) ~ EPOCH I Forest Oil Corporation Redoubt Unit #5 WELL RESUME Company: Forest Oil Corp. Well: Redoubt Unit # 5 & Redoubt Unit #5A Field: Redoubt Shoals Region: Cook Inlet Location: Section 14, Township 7 N, Range 14W, SM Coordinates: 1918' FSL, 315' FEL Elevation: 90.0' RBK - MSL, 45' low water depth County, State: API Index: Kenai, Alaska 50-733-20513-00 RU #5 50-733-20513-01 RU #5A ) Spud Date: 4/16/2002 8/15/02-RU#5A Total Depth: RU #5 RU #5A 15438' MD 13378.3' TVD 170QQ'MD 12831.6' TVD Contractor: Nabors Alaska Drilling Company Representative: Mike Mello, Mike Murray Don Stagner Rigrrype: Nabors #429 1 Platform Epoch Logging Unit: #31 Epoch Personal: Lees F. Browne Jr. George Baker Christian Ornt Company Geologist: Art Saltmarsh [:1 EPOC=-I 2 (, ) Casing Data: Hole size: Mud Type: Logged Interval: Electric Logging Co: Logs Run: ) Forest Oil Corporation Redoubt Unit #5 30" landed at 200' 13 5/8" landed at 3196' 9 5/8" landed at 13760' RU#5A 11489' 7 5/8" hanging liner landed at 15325' RU#5A 18 %" to 3502' 12 %" to 13980' 8 %" to 15438' 6.75" 17000'(RU#5A) Spud to 3205' Oil Based to 15438' 17000'-RU#5A Monitor Gas to 5000' Full Logging to 15438' 17000' -RU#5A Schlumberger to Caliper-Gamma Ray Array Induction-Density-Neutron-GR Caliper-Gamma Ray Array 1 nduction-Density-Neutron-G R Caliper-Gamma Ray Array Induction-Density-Neutron-GR Ultra Sonic Bore Hole Imager to to to ': [1 EPOCH 3 Forest Oil Corporation Redoubt Unit #5 GEOLOGICAL DISCUSSION Forest Oil Corporation spudded the Redoubt Unit #5 well on April 15, 2002 with Nabors Alaska Platform Rig #429. Surface hole was drilled to a depth of 3205' and 13 3/8" casing was run. On April 24, 2002 all drilling operations were suspended pending a court injunction. Drilling resumed June 15, 2002 with no rig delays to 15438' MD I 13378.3' TVD. After logs were run RU#5 was plugged back to a depth of 13722'MD. A bridge plug was then set at 11500'MD. A whipstock was run and a window was milled at 11473'MD. Drilling on the RU#5A sidetrack commenced on August 15, 2002 until reaching the casing point at 15325'MD/11979'TVD. A Sperry Sun LWD tool was utilized from 13800'MO to T.O. The RU#5A reached a total depth of 17000'MO/12831'TVD on September 28, 2002. ) The primary objectives of this Redoubt Unit well were the conglomeratic sands of the Hemlock formation of the Tertiary Kenai Group, on the eastern boundary of the north fault block previously discovered by the NO.1 well. The Hemlock was encountered at 14367' (sample depth). Minor gas increases were observed over the Hemlock in very carbonaceous shale and sublignitic coals. Background gas ran a steady 30 to 40 units through the upper Hemlock. No C-4's were logged over the top of the Hemlock. Sporadic C-4's were observed in minor amounts (1-10 ppm) on the chromatograph through the middle interval of the Hemlock and a slight increase of 15 units of gas. Core #2 (14715' to 14726') yielded 10.6' of typical conglomerate Hemlock before jamming. Core #3 (14860' to 14866') recovered 4.5' of conglomerate sand after jamming. A good steady reading of 15 ppm C-4 was recorded throughout the lower Hemlock (14900' to 15130') with just a trace amount of C-5 at 14960'. The top of the West Foreland was drilled at 15177'(sample depth). No shows were noted in the West Foreland with only a slight amount of sand logged. This section was noted by an increase of tuffaceous siltstone and ash. The well reached a total depth of 15438' on 05/08/02. The geologic section encountered in the RU#5A progressively became more similar to the RU#3 well than the original RU#5. A good gas show of over 400 units was recorded from 14096'MD/11386'TVD to 14127'MD/11399'TVD in the lower Tyonek. This excellent gas show was drilled in the same stratigraphic position as a similar gas zone in the RU#3 well. The Hemlock top(Base of first coal) was encountered at 1 5240'MD/11936'TVD and the well was drilled to 15325'MD/11979'TVD to set 7 5/8" liner. The top of the upper Hemlock pay was drilled at 15392'MD/12017'TVD. The best pay interval here was from 15392'MD to 15440'MD/12042'TVD. This interval produced an excellent gas profile with significant increases in C-4's and C-5's. The lower pay section was cored from 15425'MD/12034'TVD to 15485'MD/12065'TVD. Over 50°1'0 of the core exhibited heavy oil staining in a conglomeratic sandstone. Oil stained sections in Core #1 exhibited good visible porosity with excellent oil fluorescence. Core #2 was drilled from 15819'MD/12252'TVD to 15840'MD/12265'TVD. Only 7 feet of core out of a total of 21 feet was recovered. No oil shows were observed in this conglomeratic sand core. Core #3 was drilled from 16153'MD/12435'TVD to 16207'MD/12461 'fTVD. This [:I 3POCH 4 Forest Oil Corporation Redoubt Unit #5 core exhibited 100% recovery with 54 feet of conglomeratic sandstone recovered in the core barrel. This core exhibited spotty oil shows which were labeled as fair. The top of the West Foreland was drilled at the base of a non-silty claystone marker at 16840'MD/12763'TVD. No shows were recorded in the fine grained sandstones and siltstones in the upper West Foreland. Epoch Well Services provided RIGWA TCH 2000TM Drilling Monitoring services and DML TM Mudlogging Service. Hydrogen flame ionization (FID) Total Gas and (FID) Gas Chromatograph detectors were employed to detect and analyze formation gases. Constant mud gas was generated by Texaco's patented Quantitative Gas Measurement (QGMTM) electrically driven gas trap located at the shale shaker header box and extracted continuously from the trap to the unit by sample pumps. The gas trap was frequently cleaned and positioned to obtain optimum sampling, and the gas system was tested and calibrated on a regular basis. Cuttings samples were collected at regular 30' intervals in oil base mud beginning at 5000' and 10' samples were collected over the entire Hemlock and West Foreland to TD as directed by Forest Oil's sampling program. ') ~ EPOCH 5 Forest Oil Corporation Redoubt Unit #5 ) DAILY ACTIVITY SUMMARY 4/13/02 Prepare the rig for moving: Work on rig choke line and change out the top drive service loop. Move the rig 5' south and make up the choke line. Change out the core on the electric brake and move the rig south to RU #5. Unload the supply boat and install the flow line to the shakers. Install the tie downs on the skid rails. Repair the Baylor brake and pick up the riser. Install the riser and pick up and install the flow nipple, flow line and floor plates in the cellar. Install the lines in the trip tank. 4/14/02 Nipple up the hole fill flow line, floor drains and over board lines (in the leg room). Install the mouse hole and change the liners in the mud pumps from 5.5" to 7". Change the bearings on the auger in the pit room. Work on electrical service loop on the top drive and install a new hydraulic clutch and new over riding clutch. Install an extension on the cuttings auger. Install hubs on the Baylor brake and DNK. Set the brake in place and set alignment. Install air and glycol lines and work on the service loop and torque booster. Mix gel and vis up the mud pits. ) 4/15/02 Work on service loop on the top drive. Hold a pre job safety meeting and strap, rabbit and pick up and stand in the derrick 30 joints of HWDP. Hold a pre job safety meeting and pick up 18.5" BHA. Work on the top drive and check the tolerance on the draw works bearings. Work on the torque boost and wire in electrical brake. Cut and slip 150' of new drill line and work on the top drive. Pick up the BHA and change out stab blades. DWD & UBHO and run gyro. Tag bottom at 145' and hold a pre job safety meeting. Slide ahead to 180' and rotate to 199'. 4/16/02 Drill to 379' and lost part of survey tool. Pull out of the hole and retrieve tool. Change out a stab with galled threads. Trip back to bottom and drill ahead. No trip gas noted. 4/17/02 Drill formation to 2657 and circulate at a reduced pump rate to allow emptying of SWACO cuttings tank. Drill ahead with routine rig service. 4/18/02 Drill ahead to 3170' and pump a high vis sweep for hole cleaning. Pull out of the hole to change out the BHA. Pick up a stiff assembly for a wiper run. Service the rig and cut and slip 350' of new drill line. 4/19/02 Run to bottom and wash the last 120'. Drill formation to 3205' and mix and pump a 150- barrel hi-vis sweep. Pull out of the hole and hold a pre job safety meeting. Stand back ~ EPOCH 6 Forest Oil Corporation Redoubt Unit #5 the jars and 2 drill collars. Lay down the rest of the BHA and clean the drill floor. Hold a pre job safety meeting and rig up to run 13.375" casing. Make up Lafluer tool and pick up tongs and landing joint. Make up the tool and tongs and lay them down. Pick up the bails, elevators, slide and spider. Hold a pre job safety meeting and rig up and begin to run in the hole with 13.375" casing. Test the float and run 12 centralizers. 4/20/02 Run 13.375" casing to 3125'. Pick up 13.375" hanger and landing joint. Circulate and condition the mud for the cement job. Hold a pre job safety meeting and break and lay down the Lafluer tool and make up the cement head. Cement the 13.375" casing. Bump the plug and check the float = open. Stage the collar with 2800 psi. Circulate the contaminated cement. Wait on cement to dry. Hold a pre job safety meeting and begin to pump a second stage of cement. 4/21/02 Finish second stage of the cement job and blow down cement lines. Rig down cement head, breakout landing joint and 9' pup. Lay down WF casing tools. Nipple down drip pan, drilling nipple, and trip tank lines. Lay down the drilling nipple and surface riser. Pick up 2 joints of 13 5/8" acme adapt from 13 5/8" hanger. Pick up and set wellhead spool and nipple up. Hold a pre job safety meeting and lay down cement head and casing tools. Hold a pre job safety meeting and nipple down the surface riser and set the well head. Hold a pre job safety meeting and nipple up the riser and move the flow line to tie on the BOP. Pick up the BOP and set on the riser. Install clamp, flow line nipple, trip tank lines, kill line, drip pan cover and secure the BOP. Function test. 4/22/02 Nipple up the choke line and install the master bushings and bails. Pick up the BHA and drill pipe. Set test plug and make up the floor safety valves to the test plug. Test wing valves, choke and kill HCR valves. Test floor dart valve and floor safety valves. All tests passed. Change the door seal on the middle pipe ram. Test the blind rams and pull the test plug. Set the wear ring. Trip into the hole with the BHA and lay down the MWD, bit, MTR stab and straighten the MTR and lay down and make up a new BHA. Service the rig and run in the hole and tag cement at 1702'. Break circulation and test the casing for 30 minutes. Drill out the ES cementer and run in the hole and ream out cement stringers from 1780' to 1910' . Tag cement at 3083' and ream to 3093'. Circulate out contaminated mud and drill cement to 3099'. Test the casing for 30 minutes. 4/23/02 Drill cement plug and retainer at 3099'. Drill out cement from 3104' to 3118'. Drill out cement plug to 3120'. Drill out landing collar from 3120' to 3124'. Drill out cement from 3124' to 3159'. Test the casing at 3159'. Circulate and clean the hole with no trip gas noted. Pull out of the hole to the BHA. Work on the BHA and service the rig. Run in the hole with a casing scrapper and circulate and clean the hole at 3150'. Perform an injection test on RU#3. Pull out of the hole and lay down the scrapper. Pull the float and ) [J EPOCH 7 Forest Oil Corporation Redoubt Unit #5 change out the savor sub, HYD well control valve on the top drive. Clean the pits and adjust the torque tube. Unload the boat and lay down the BHA. 4/24/02 Lay down the BHA and start cleaning the pits. Run HWDP in holes and lay down and pull wear bushings. Continue to clean pits and trip tank. Clean rig floor drip pan. Set 9 5/8" hanger and blow down mud lines. Clean mud pump suction pit. Nipple down BOP and nipple up BOP and secure the well. RU #5 suspended through court order. 4/25/02 TO 6/14/02 RU#5 is shut down pending a court injunction. 6/15/02 Circulate and displace RU#5 well and tag bottom of cement at 3156'. Displace the hole with oil base mud at 6 bbl/min. Clean the possum belly and shaker screens and circulate and condition oil base mud increasing from 3 bbl/min to 9.7 bbl/min. Rig up and test 13 3/8" casing to 3000 psi. Pull out of the hole and hold a pre job safety meeting. Pick up BHA and shallow test MWD. Replace breaker to top drive and service the rig. Pick up BHA and run in the hole with HWDP and 5" drill pipe and tag bottom at 3161'. Drill out hard cement to 3204' and tag the shoe. ) 6/16/02 Drill out shoe at 3205' and drill formation to 3240'. Survey and circulate bottoms up and run leak off test. Drill and slide to 4096' and service the rig. Drill and slide to 4869'. 6/17/02 Drill and slide formation. 6118/02 Drill to 6641' and service the rig. Drill to 6648' and pump a high vis sweep and pull out of the hole for bit trip. 6119/02 Lay down the BHA: unable to break out DWD from drill collar and stab from pony flex drill collar to galled threads (All three cones missing). Clear and clean the rig floor and pick up and drift 85 joints of 5" drill pipe from the deck. Pull out of the hole to 2650' and make up junk basket BHA and trip into the hole. Service the rig and run in the hole with a bit and junk basket. Ream from 6580' to 6648' (TO). Drill on junk and work the junk basket. Drill to 6670' and work the junk. Circulate and mix/pump a dry job and work the pipe without pumps. Pull out of the hole and lay down the bit and junk basket and clean a small amount of junk (bit in gauge - teeth good - center of bit scarred). Make up second junk basket and magnet and prep to run in the hole. ) [1 EPOCH 8 Forest Oil Corporation Redoubt Unit #5 6/20/02 Run in the hole to 3205' and cut and slip new drill line and circulate the hole. Trip in the hole to 6610' and circulate and fill the drill pipe. Work magnet down on junk to the bottom of the hole at 6666'. Mix and pump a dry job and pull out of the hole. Lay down the magnet and BHA. Rig up and test the BOPE. Hold a pre job safety meeting and pick up the new BHA and run in the hole to 2300' and fill the drill pipe. Continue to run in the hole to 6550' and circulate to shear the drilling mud. Drill formation from 6666' to 6745'. 6/21/02 Drill to 7195' and circulate and back ream to clean the hole from 7196' back up to 7126'. Hole is,tight at 7130'. Drill ahead to 7498' and circulate another sweep. 6/22/02 Drill ahead to 7631' and mix and pump a high vis sweep to clean out cuttings from the hole. Drill ahead to 7749' and mix and pump another high vis sweep. Drill ahead. 6/23/02 Drill formation to 8255'. Mix and pump a high vis sweep and drill ahead to 8760'. 6124/02 Drill formation to 8820'. Mix and pump a high vis sweep and drill ahead to 9160'. ) 6125102 Drill formation to 9207'. Mix and pump a high vis sweep and mix and pump a dry job. Begin to pull out of the hole for bit trip. Pull out of the hole to 8915' and pump out of the hole from 8915' to 7686' due to hole packing off. Circulate and clean the hole: reciprocate the hole from 7686' to 7592'. Pump a high vis sweep around with a 50%> increase in cuttings over the shaker. Continue to pump out of the hole and mix and pumping two more high vis sweeps. Pump out of the hole to 5699'. 6126/02 Continue to pump out of the hole to 5088'. Hole packed off. Work pipe free and rotate and circulate bottoms up from 5031' to 4935'. Abundant cuttings returned to surface on bottoms up. Continue to pump out of the hole from 5031' to 3225'. Work pipe and circulate bottoms up under the shoe. Circulate and pump a dry job at 2817'. Pull out of the hole and lay down the BHA. Hold a pre job safety meeting and test BOPE. Pick up BHA and run in the hole to 3230'. Break circulation and shear the drilling mud. 6127102 Trip into the hole to 7600' and circulate and mix a high vis sweep. Shear the drilling mud and trip in the hole to 7740' and wash and rotate to 8261'. Hole packed off. Picked up a single and worked the drill pipe free. Circulate bottoms up and continue to rotate and washing to 8920'. Circulate and mix a high vis sweep at 650 GPM, 110 RPM and reciprocate from 8290' to 8195'. Continue to wash and ream the hole from 8290' to 9204'. Circulate bottoms up and prepare to drill ahead. [~ EPOCI-:~ 9 Forest Oil Corporation Redoubt Unit #5 ) 6/28/02 Drill formation. Pump high vis sweep at 9230'. 6/29/02 Drill formation. Pump a high vis sweep at 10000'. 6130/02 Drill formation. Pump a high vis sweep at 10378'. 7/1/02 Drill formation to 10631'. Pressure loss of 250 psi, followed by another loss of 200 psi. Begin to pull out of the hole and find the washed out drill pipe at 7602'. Run in the hole and ream the hole from 10521' to 10631' with 45' of fill at the bottom of the hole. Pump a HiVis sweep and drill formation to 10767'. 712/02 Drill and slide formation to 11000'. Pump a HiVis sweep and circulate the hole clean. 7/3/02 Pull out of the hole with no problems. Test BOP equipment. Run in the hole with Bit #8. Cut and slip drill line at 13 3/8" casing shoe. ) 714/02 Run in the hole and ream through tight spots. Wash and ream from 10411' to 11000'. Drill formation from 11000'. 715/02 Drill formation to 11480'. Pump a HiVis sweep at 11440'. Pull one stand and circulate out the sweep. Drill formation from 11480'. 7/6/02 Drill formation to 11638' and circulate. Pull back one stand of drill pipe and pump a H iVis sweep. Circulate the hole clean and pull out of the hole for bit trip. 7/7/02 Run in the hole with bit #9 (rotary drill assembly). Circulate at the shoe and service the rig. Run in the hole "clean" with no fill. Rotary drill to 11952'. 7/8/02 Rotary drill formation to 12184'. 7 19/02 Service the top drive and rotary drill to 12343'. Pump a HiVis sweep and circulate the hole clean. Pull 8 stands and slug the pipe. Begin to pull out of the hole. [:I EPOCH ]0 Forest Oil Corporation Redoubt Unit #5 ) 7/10/02 Pull out of the hole IIslick". Test the BOP equipment. Run in the hole with bit #10 to the shoe and shear the drilling mud while servicing the top drive. Run in the hole to TO. Wash and ream the last 70' to bottom with no fill. Drill ahead to 12425'. 7111/02 Drill formation to 12683'. Hole is tight at 12415' to 12460'. Wash and ream for 20 minutes. 7/12/02 Drill formation to 12912'. 7/13/02 Drill formation to 13085'. Top drive is broken down (broken gear tooth). Pump a HiVis sweep and circulate clean. Pull out of the hole. Work a tight spot at 12861'. 7/14/02 Pull out of the hole IIslick", working a tight spot at 8032'. Begin to repair top drive. 7/15/02 Repair top drive and change mud pump liners to 5.5". ) 7/16/02 Finish top drive repairs and test the BOP equipment. Pick up new BHA and run in the hole. 7/17/02 Run in the hole and shear the drilling mud at 3298', 8988' and 11908'. Hole is tight at 5960', 9650', 9785' to 9835' and 12450'. Wash and ream from 12400' to 13085'. Drill formation to 13195'. 7/18/02 Drill formation. 7/19/02 Drilling and lost 700 psi pump pressure. Pull out of the hole for IIwash out" 16 stands down. Run in the hole and continue to drill formation. 7/20/02 Drill formation to 13776' and lose pressure again. Pull out of the hole for IIwash out" at 12800'. Trip in the hole and drill formation to 13921'. Circulate up samples and drill formation to 13950'. Circulate samples up. [:I EPOCH 11 Forest Oil Corporation Redoubt Unit #5 7/21/02 Continue to circulate samples up and drill ahead to 13980'. Circulate samples up and circulate a weighted sweep. Short trip the pipe and circulate a HiVis sweep and pull out of the hole to run casing. 7/22/02 Prep to run casing. Begin to run casing. 7/23/02 Finish running casing and circulate cement around casing. 7/24/02 Change out rams and test BOP equipment. Make up new BHA and trip in the hole and tag cement at 13572'. Circulate and shear the drilling mud and drill cement, float and shoe. Circulate and perform FIT test = 10.5 EMW. ) 7/25/02 Wash and ream from 13780' to 13986'. Drill formation to 13991' and pump a HiVis sweep and pull out of the hole and lay down stabs and stand back BHA. Clean the rig and service the rig and begin to cut and slip new drilling line. Pick up core barrel and run in the hole. Circulate and shear the drilling mud at the shoe. Wash to bottom and survey. Core from 13991' to 14003'. 7/26/02 Core from 14000' to 14052'. Pull out of the hole and lay down the core. Clean the rig floor and pick up BHA and service the rig. Work on rig SCR. 7/27/02 Repair electrical problems on the draw works. Pick up the BHA and run in the hole and shear the drilling mud at the shoe. Trip to bottom and drill formation to 14195". 7/28/02 Drill and circulate up samples from 14195' to 14361'. Drill formation to 14500'. 7/29/02 Drill and sweep around HiVis sweep. Circulate bottom's up and pull out of the hole. Change the BHA and bit and pick up 5" drill pipe singles. Begin to run in the hole. 7/30/02 Run in the hole and cut and slip new drilling 1ine. Run in the hole to bottom and drill formation to 14715'. Circulate and pull out of the hole. Hole is tight at 14450'. Pull out of the hole and pick up core barrel. Run in the hole to core. 8/2/02 Run in the hole to the shoe. Circulate and shear the mud. Run in the hole, washing and reaming from 14500' to 14715'. Core from 14715' to 14726'. Pump out of the hole ) ~ EPOCH 12 Forest Oil Corporation Redoubt Unit #5 ) from 14726' to 14410'. Pull out of the hole. Lay down the core barrel. Pick up new core barrel and stand back. Service the rig. Test BOP's. Pick up drilling BHA and run in the hole. 8/3/02 Pick up 5" Drill Pipe singles. Lay down 32 joints of 5" drill pipe. Run in the hole to the shoe. Cut and slip the drilling line while circulating and shearing the mud. Run in the hole. Drill formation from 14726' to 14850'. Circulate bottoms up. Drill formation from 14850' to 14860'. Pump sweep and circulate bottoms up. 8/4/02 Circulate hole. Pull out of the hole. Pick up core barrel. Run in the hole to the shoe. Circulate and shear the mud at the shoe. Run in the hole. Wash in the hole 100' to bottom. Core from 14860' to 14866'. Pull out of the hole to the shoe. Lay down 5" drill pipe singles. 8/5/02 Pull out of the hole. Lay down core barrel and change out BHA. Service the rig. Pick up 30 5" drill pipe singles. Run in the hole to the shoe. Cut and slip drilling line. Run in the hole. Wash to bottom. Pull out of the hole to the shoe for top drive repairs. Repair top drive. ) 8/6/02 Repair top drive. Run in the hole. Wash to bottom. Drill formation from 14866' to 14950' . 8/7/02 Drill formation from 14950' to 14980'. Lost swab on Pump #2 and charge pump on #1 , repaired both. Drill formation from 14980' to 15154'. Lubricate the rig. Drill formation from 15154' to 15200'. 8/08/02 Drill formation from 15200' to 15438'. Pump HiVis sweep and circulate bottoms up. Pull out of the hole to the shoe. Lubricate the rig. Run in the hole. Pump HiVis sweep and circulate the hole clean. 8/09/02 Circulate and condition mud. Pump dry job. Pull out of the hole to the shoe. Pull out of the hole culling and laying down 30 joints of 5" drill pipe for hardband. Lay down BHA. Clean rig floor. Rig up Schlumberger wireline. Pick up Quad Combo. Run Quad Combo. Run Gamma Ray, ECC, CMR In. ) [J EPOCH 13 Forest Oil Corporation Redoubt Unit #5 ) 8/10/02 Continue to run wireline. Run UVI and Gamma Ray. Run RFT and Gamma Ray. Hold a pre job safety meeting. Pull the wear bushing and set the test plug. Test BOP; Annular pipe rams, blind rams, TD valves, mud cross valves, TIW + dart valves. Test choke manifold. Pull the test plug and set the wear bushing. Make up the BHA. Run in the hole, shearing the mud at 4500'. Continue to run in the hole. 8/11/02 Run in the hole for clean out run. Shear the mud at 8500' and 13600'. Cut and slip drilling line at the shoe. Run in the hole, washing to bottom with no fill. Pump HiVis sweep and circulate the hole clean. Pump dry job and pun out of the hole, laying down the BHA. Rig up and run Schlumberger for Gamma Ray and Sonic run. 8/12/02 Finish running Shlumbeger CBL. Run in the hole with Baker cement retainer. Shear the mud. Set packer at 13722'. Perform LOT for cement plug back. Circulate and shear the mud. Plug back with 60Bbl squeeze. Pull 5 stands and reverse circulate a bottoms up with cement to surface. Circulate the long way at 16 Bbllmin. Pump dry job and pull out of the hole. ) 8/13/02 pun out of the hole. Make up BHA for 9 51811 scraper run. Pick up and drift 30 joints of 51' drill pipe. Run in the hole to 8900'. Circulate and fill the pipe. Run in the hole to 120331. Circulate and Cut and Slip the drilling line. Pump dry job and pull out of the hole. Hold pre job safety meeting and lay down scraper BHA. Clean the rig floor. Hold pre job safety meeting and rig up Schlumbereger. Run in the hole with bridge plug. Bridge plug did not set Pull out of the hole and redress the bridge plug. Run in the hole with bridge plug. ) / ~ EPOCH 14 Forest Oil Corporation Redoubt Unit #5 ) Begin RU #5A 08/14/02 8/14/02 Set bridge plug with wireline at 11500'. Rig down Schlumberger. Pick up 9518" casing whipstock BHA. Shallow pulse test DWD. Run in the hole at 35 - 40 fUmin with whipstock. Lubricate the rig. Orient the whipstock. Tag the bridge plug at 11497'. Set casing whipstock and shear off. Mill window from 11473' to 11491', pumping a HiVis sweep at 11487'. 8/15/02 Drill formation with mill from 11491' to 11494'. pumping a sweep at 11494'. Ream and clean up the window. Pump sweep and circulate. Pull out of the hole. Service the rig. Pull out of the hole. Change out the BHA. Run in the hole. Fill the drill pipe and circulate to condition the mud. Wash to bottom. Mill on the window to 11500'. Pump H iVis sweep and circulate. 8/16/02 Circulate HiVis sweep around at 11500'. Pump dry job and remove the blower hose from the top drive. Pull out of the hole. Lay down the mill BHA. Pick up drilling BHA. Orient the mud motor. Run in the hole to 1001' and shallow pulse test the DWD tool. Run in the hole. Cut and slip 85' of drilling line. Circulate and condition the mud. Orient the mud motor. Ream out the rathole from 11493' to 11500'. Slide from 11500' to 11602'. ) 8/17/02 Drill formation from 11602' to 11785', pumping a HiVis sweep at 11716'. Drill and slide formation from 11785' to 11870'. 8/18/02 Drill formation from11870' to 11961', pump a sweep at 11915'. Drill formation from 11961' to 12028'. Pump sweep and circulate out of the hole. Pull out of the hole to the window. Pump the dry job and check for flow. Pull out of the hole while laying down worn drill pipe. 8/19/02 Pull out of the hole, laying down bad drill pipe. Lay down 12 joints of HWDP and change out the BHA. Orient the mud motor and DWD. Pull the wear bushing, set the test plug, and test the BOP. Service the rig. Locate and repair a hydraulic leak on the top drive. Change the savor sub. Run in the hole, picking up 48 joints of 5" drill pipe. Shallow pulse test the DWD. Run in the hole to 5030'. Remove guards and replace the brake rim lines. ) i [:I EPOCH 15 Forest Oil Corporation Redoubt Unit #5 ) 8/20/02 Repair the coolant lines to the draw works brakes. Run in the hole to 11450'. Circulate and shear the mud. Work into window at 11473' to 11515' with the pumps off. Run in the hole to 11925'. Wash and ream from 11925' to 12028'. Drill formation from 12028' to 12182'. Pull out of the hole to the shoe. Clean the rig floor and prepare for grabber removal. Repair the top drive, change out the hydraulic ram. Run in the hole to bottom. Circulate and shear the mud. Drill formation from 12178' to 12276'. 8/21/02 Drill formation from12276' to 12758'. 8/22/02 Drill formation from 12758' to 13057'. 8/23/02 Drill formation from 13057' to 13398'. Repair leak on the top drive. suspected leak from torque boost to gear box. 8/24/02 Repair the top drive. disconnect the torque boost and change out the contaminated oil in the gear box. Drill formation from 13398' to 13419'. Repair the top drive, remove the clutch assembly from the torque boost. Drill formation from 13419' to 13675'. ) 8/25/02 Drill formation from 13675' to 13800'. Pump sweep and circulate around. Pull out of the hole to the shoe. Pump dry job and clean the rig floor. 8/26/02 Pull out of the h01e. 1aying down 51 joints of 5" driH pipe. H01d a pre job safety meeting and work BHA. Hold a pre job safety meeting, pull wear bushing, and rig up to test BOPS. Test BOPS, all rams, floor valves, choke manifold, and top drive KC valves. Install the wear bushing. Work on the top drive, install torque boost gears. Pick up new BHA, orient the motor, load sources, and program. Hold a pre job safety meeting and pick up 51 joints of 5" drill pipe. Run in the hole to the window. Cut and slip 100' of drilling line. 8/27/02 Shear the mud. Run in the hole, washing a tight spot at 13250'. Run in the hole to bottom. Establish circulation and drill formation from 13800' to 13818'. Work on MWD surveys (noise in surveys). Drill formation from 13818' to 14141'. 8/28/02 Drill formation from 14141' to 14362'. Deviation survey twice and orient. Drill formation from 14362' to 14510'. ~. EPOCH 16 Forest Oil Corporation Redoubt Unit #5 8/29/02 Drill formation from 14510' to 14524'. Lubricate rig, change filter, and service the top drive. Drill formation from 14524' to 14832'. 8/30/02 Drill formation from 14832' to 15000'. Lubricate the rig. Drill formation from 15000' to 15070'. 8/31/02 Drill formation from 15070' to 15086'. Replace swab in Pump #2. Obseved packoff when picking up off bottom, pump a HiVis sweep, and circulate until the sweep is in the casing. Replace the valve and seat in Pump #1. Drill formation from 15086' to 15114'. Replace swab in Pump #1. Drill formation from 15144' to 15124'. Replace valve and seat in Pump #2. Drill formation from 15124' to 15289'. Lubricate the rig. Drill formation from 15289' to 15276'. 9/1/02 Drill formation from 15276' to 15315'. Circulate out samples for the mud logger. Drill formation from 15315' to 15325'. Circulate out samples for the mud logger. Pump HiVis sweep and circulate while rotating and reciprocating until the hole cleaned up. Pull out of the hole, puling tight at 14390', 14110' and 14000'. Unload source and download L WD tools. Lay down the bit and mud motor. ) 9/2/02 Test BOP equipment. Check Top Drive and pick up Cal. Logging tools. Shear drilling mud at window. Begin logging with Sperry from 11460' to 12223' at 225 fph. 9/3/02 Finish logging and begin to wash and ream to bottom. Pump a sweep and circulate bottom's up. Start a short trip to the window. 9/4/02 Pull out of the hole to the window. Hole tight at 14037' 1 13950' and 13860'. Back ream at 13309' and wash from 12070' to 11930'. Repair top drive and cut and slip new drill line. Service the rig and run in the hole. Pump a sweep and circulate the hole with four bottoms up circulations. Begin to pull out of the hole. Hole is tight at 12223'. Service the rig and pump a dry job. Drop 2 3/8 drift and begin to pull out of the hole. 9/5/02 Pull out of the hole and hold a pre job safety meeting with Sperry. Lay down jars and remove IIsource". Download data and lay down the BHA. Change out bottom rams and test rams. Repair crown saver and rig up to run casing. Run casing and make up hanger/packer assembly. Rig down casing running tools and run in the hole with drill pipe at 2 minutes per stand and filling the drill pipe every 10 stands. [:I. EPOCH 17 Forest Oil Corporation Redoubt Unit #5 ) 9/6/02 Run in the hole with liner and circulate and shear drilling mud at the window. Run in the hole with liner and pick up cement head and tag bottom at 15325' and circulate drilling mud. Trip gas = 716 units with a recycle of 207 units. Drop steel ball. Drop second ball and seat. Set hanger and cement liner. Set packer with no cement to surface. Pull out of the hole and cull pipe with bad hard band. 9/7/02 Lay down liner tools and change rams and test. Repair the top drive and service the rig. Cut and slip new drilling line. Pick up new BHA, 3.5" HWDP and 4" drill pipe. 9/8/02 Pick up 4" drill pipe and run in the hole with 5" drill pipe. Tag float at 15249' and test casing. Drill out landing collar and float collar at 15249' to 15252'. Drill cement to 15292' and circulate bottoms up. Test casing and drill cement to shoe at 15325'. Drill formation to 15340'. 919102 Drill formation from 15340' to 15350' and circulate bottoms up for samples. Run a F.I.T. at 15359' and drill ahead to 15375'. Circulate bottoms up for samples and drill ahead to 15425'. Circulate bottoms up for samples and repair rig brakes and service the rig. Pull out of the hole and lay down 48 joints of 5" drill pipe. Hold a pre job safety meeting and down load logging tools and lay down BHA. ) 9/10/02 Continue to down load LWD and change out pulser probe. Lay down mud motor and test BOP equipment. Service the rig and pick up the core barrel. Trip in the hole to 4730 and pick up 4" drill pipe. Trip in the hole to the shoe and service the rig. Cut and slip new drill line and run in the hole to 15425'. Begin to core. 9/11/02 Core from 15461' to 15485' and circulate out samples to 15453'. Pull out of the hole to the shoe and pump a dry job. Pull out of the hole to 15320' and lay down 24 joints of 5" drill pipe. Continue to pull out of the hole and clean the rig florr. Hold a pre job safety meeting and pull Sperry survey tool and lay down the core barrel. Redress the core barrel and stand back. Make up new BHA and hold a pre job safety meeting. Upload survey tools and load source. Run in the hole and circulate around a sweep. 9/12/02 Log from 15425' to 15485'. Drill and slide to 15543'. 9/13/02 Drill and slide from 15552' to 15675'. U EPOCH 18 Forest Oil Corporation Redoubt Unit #5 ) 9/14/02 Drill and slide formation from 15675' to 15800'. Pump a sweep around and circulate. Begin to pull out of the hole. 9/15/02 Pull out of the hole and download Sperry tools. Lay down the mud motor and make up the core barrel. Load Sperry tools and trip into the hole and shear the drilling mud at the shoe. Finish running in the hole and wash from 15700' to 15819'. Begin coring at 15819'. Trip gas 14 units. 9/16/02 Core from 15819 to 15840'. Work core barrel. Core jammed. Survey and circulate drilling mud. Pull out of the hole and lay down core barrel. Test BOP equipment and pick up BHA and load sources. Run in the hole. 9/17/02 Trip in the hole to the shoe and cut and slip new drilling line. Circulate and shear the drilling mud and log from 15345' to 15385' at 50' per hour. Log at 150' per hour from 15385' to 15840'. Circulate a sweep and drill and slide from 15885'. 9/18/02 Drill and slide to 15922'. Monitor the well and pun out of the hole slick to 15300'. Slug the pipe and trip out of the hole for bit. ) 9/19/02 Prepare and orient BHA #35 (bit #24). Run in the hole to 15355' and circulate and shear the drilling mud. Run in the hole to TO. Pump a high vis sweep at 15900'. Drill and slide formation to 16021. 9/20/02 Drill and slide to 16084'. Circulate and repair Top Drive blower hose. Drill formation to 16153'. 9/21/02 Drill formation to 16153' and monitor the well. Pull out of the hole and slug the pipe at the shoe. Pull out of the hole and pick up the core barrel. Run in the hole with core barrel to 15286'. Circulate and shear the drilling mud while cutting and slipping new drill line. Wash and ream from 15662' to 16153'. No fill on bottom. Begin coring at 16153'. 9/22/02 Core #3 to 16207' and survey. Pull out of the hole to the shoe and pump a slug. Pull out of the hole and lay down core. Recover 100% of core. Test BOP equipment. Run in the hole with Bit #26. [J EPOCH '19 Forest Oil Corporation Redoubt Unit #5 ) 9/23/02 Wash and ream from 15800' to 16207' and drill/slide ahead. 9/24/02 Drill formation to 16440'. Circulate and pump dry job. Pull out of the hole for a new bit. 9/25/02 Pull out of hole for new bit. Lay down bad 5" drill pipe. Run in hole with new bit #27. Run in hole with BHA #38 with MWO/LWO tools. Run in hole to 15368'. Circulate while slip and cut drill line. Run in hole and wash and ream tight spots. No fill on bottom. Drill from 16440' to 16490'. 9/26/02 Drill to 16532'. Pull out of hole for plugged jets. Establish partial circulation. Pull out of hole working tight spots. Tripping slug pumped in shoe. Run in hole with BHA #39 with bit #28. Trip to shoe and circulate. 9127/02 Run in hole with BHA #39(bit#28). Run in with MWO/L WO/mud motor/POCo Shear mud at shoe. Run in hole and wash and ream from 16150' to 16532'. Resume drilling. ) 9/28/02 Drill to T.O. of 17000'MO/12831'TVO. Start to circulate and condition mud. fJ EPOCH 20 Forest Oil Corporation Redoubt Unit #5 ) LITHOLOGY AND COMMENTS 5000' Tuffaceous Siltstone Light gray; poor occasionally moderate indurated; crumbly to crunchy; slightly sectile in part occasionally stiff; earthy fracture; earthy habit; frosted to earthy luster; silty to clayey texture; generally composed of equal amounts of silt and clay; grad to very fine to fine grained sand. 5045' Coal Black occasionally brownish black; firm; resinous luster occasionally becoming earthy; smooth texture; blocky to occasionally hackly fracture; no visible bleeding gas from cuttings; composed of generally subbituminous to lignitic coal. 5075' Sand Medium light gray; clast size ranges from medium upper to fine lower; subround occasionally subangular; moderate sphericity; moderate to poor sorting; chipped to impacted texture; immature; non to very weak silic cement; non to occasionally moderate silUclay packed hydrophilic matrix; grain and matrix support; composed of 70 quartz, 20% chert, 10% metamorphic, feldspar and various lithic fragments; oil base mud in hole. ) 5130' Sand Medium light gray; clast size ranges from coarse lower to fine upper; generally becoming subround with depth; mod to well developed sphericity with better rop; moderate sorting; polished texture; immature to submature; non to very weak silic cement; non to slight hydrophilic silUclay packed matrix material; dominantly grain supported; composed of 700/0 quartz, 20 chert, 100k metamorphic, feldspar and various lithic fragments; fair to good estimated poro and permeability; oil base mud. 5195' Tuffaceous Siltstone Light brownish gray to medium light gray; poor to mod induration; brittle; crumbly; mushy in part; tacky; earthy fracture; earthy habit; earthy luster; silty to clayey texture; grad beds of silt, clay and sand; coal bed at 5230'. 5235' Sand Medium light gray; clast size ranges from coarse upper to lower to med lower; subround occasionally subangular in coarse grains; moderate to well developed sphericity moderate occasionally poor sorting; polished texture submature; non to very weak silic cement non to slight matrix material; dominantly grain support; composed of aOok quartz, 100k chert, 10% metamorphic, greenstone; good estimated porosity and permeability; oil base mud. [:I EPOCH 21 Forest Oil Corporation Redoubt Unit #5 ( 5290' Sand and Conglomerate Medium light gray to medium gray; clast size ranges from very coarse upper to medium lower occasionally fine upper in parts; subangular to subround occasionally angular bit impacted fragments; mod sphericity; poor sorting; polished and chipped texture; submature occasionally immature; non to slight silic cement; non to slightly tuffaceous- silty matrix; dominantly grain sup; composed of 700/0 quartz, 200/0 chert, 1 Oak metamorphic, greenstone and various lithic fragments; fair to good porosity and permeability; oil base mud. 5360' Sand and Conglomerate Medium light gray; clast size ranges from very coarse upper to fine upper (poss matrix); subround occasionally angular bit impacted fragments; mod sphericity; very poorly to poor sorting; polished occasionally chipped texture; immature to submature; non to very slight silic cement; non to slight silt packed matrix composed of 80% quartz, 10% chert, 10% metamorphic, greenstone and various lithic fragments; fair to good estimated porosity and permeability; no oil ind I oil base mud. 5425' Tuffaceous Siltstone Medium gray; poor to moderate induration; brittle; crumbly cohesive; earthy fracture; subnoduJar habit; earthy luster; silty-clayey texture; homogeneous beds of silt; generally composed of 70% silt, 30% clay. ( 5460' Sand Medium light gray; clast size ranges from medium upper to fine upper; subangular to subround; moderate sphericity moderate to well sorted; frosted to chip to impacted texture; submature occasionally mature; non to very slight cement; slightly silt hydrophilic matrix; dominantly grain sup; composed of 90% quartz, 10% metamorphic greenstone and various lithic fragments; fair to good estimated porosity and permeability no oil ind/oil base mud. 5520' Coal and Carbonaceous Shale Black to grayish black; firm; resinous occasionally earthy luster; matte texture; subblocky to blocky fracture; composed of very carbonaceous shale grading to predominantly lignitic coal. 5550' Tuffaceous Siltstone Medium gray; poor to moderate induration; brittle in parts crumbly to slightly elastic; cohesive; earthy fracture; subnodular habit; earthy luster; silty to clayey texture; interbedded and grading to tuffaceous clay; generally composed of 700/0 silt, 30% clay. ( 5590' Tuffaceous Claystone Light gray to medium light gray; mushy to pasty consistency; soft to very soft tenacity; irregular to earthy fracture; massive cuttings habit; dull to earthy luster; clayey to silty texture; thick bedding structure with sand to siltstone interbedded. ~ EPOCI-= 22 Forest Oil Corporation Redoubt Unit #5 ( 5635' Coal Black to grayish black with reddish black secondary hue; brittle to dense tenacity; conchoidal to irregular fracture; flaky to massive cuttings habit; waxy luster; matte to gritty texture; Thin bedding structure; slight visible gas bleeding. 5675' Tuffaceous Siltstone Medium gray; poor to moderate induration; brittle in parts crumbly to slightly elastic; cohesive; earthy fracture; subnodular habit; earthy luster; silty to clayey texture; interbedded and grading to tuffaceous clay; generally composed of 70% silt, 30% clay. 5715' Tuffaceous Claystone Medium gray to medium light gray with dark gray secondary hue; mushy consistency; adhesive; soft to very soft occasionally crumbly; massive cuttings habit; dull to waxy luster; clayey to silty texture; massive bedding structure. 5755' Sand Light gray to medium light gray; upper medium to upper fine clast sizes; fair to well sorted; rounded to subrounded; moderate to high sphericity; dominantly clear to frosted quartz with minor amounts of lithic and meta fragments; unconsolidated; matrix supported; no visible oil indicators. ( 5800' Coal Black to grayish black with reddish black secondary hue; brittle to dense tenacity; conchoidal to irregular fracture; flaky to massive cuttings habit; waxy luster; matte to gritty texture; thin bedding structure; lignite to carbonaceous shale grading. 5840' Tuffaceous Claystone Light gray to medium light gray; mushy to pasty consistency; soft to very soft tenacity; irregular to earthy fracture; massive cuttings habit; dull to earthy luster; clayey to silty texture; thick bedding structure with sand to siltstone interbedded. 5885' Tuffaceous Siltstone Medium gray to medium light gray with dark gray secondary hue; crumbly to crunchy occasionally soft tenacity; irregular to earthy fracture; massive cuttings habit; dull to earthy occasionally waxy luster; silty to clayey texture; massive bedding structure with fine grained sand, carbonaceous material, and clay interbedded. 5940' Carbonaceous Shale Blackish red to dusky brown with black secondary hue; crumbly to crunchy tenacity; irregular to planar fracture; massive to flaky cuttings habit; greasy to waxy luster; matte to silty occasionally clayey texture; thin bedding structure; grading from carbonaceous shale to carbonaceous clay with occasional lignite coal. ( ~ EPOCI-= 23 Forest Oil Corporation Redoubt Unit #5 (' 5995' Tuffaceous Claystone Medium gray to medium light gray with dark gray secondary hue; mushy consistency; adhesive; soft to very soft occasionally crumbly; massive cuttings habit; dull to waxy luster; clayey to silty texture; massive bedding structure. 6035' Coal Black to grayish black; crunchy to brittle occasionally crumbly; conchoidal to planar fracture; massive to wedgelike cuttings habit; greasy to polished occasionally waxy luster; matte to silty texture; thin bedding structure; lignite to carbonaceous clay; no visible gas bleeding. 6080' Sand Medium light gray; clast size ranges from medium upper to fine upper; subround; moderate sphericity; moderate sorting; impacted to chipped texture; mature texture; non to very weak silic cement; non to very slight clay matrix; dominantly grain support; composed of 70% quartz, 20% chert, 10% metamorphic, greenstone and various lithic fragments; good estimated poro & permeability; grading to coarse grain sand interbedded with siltstone at the base. 6155' Coal and Carbonaceous Shale Black; firm; resinous luster; smooth occasionally matte texture; blocky to subblocky fracture; composed of predominantly lignitic to subbituminous coal. ( 6180' Tuffaceous Claystone Medium dark gray to medium gray; soft to firm; brittle to slightly sectile occasionally stiff in parts; sub nodular habit; dull earthy luster; silty to clayey texture; massive homogeneous beds of silty clay generally composed of 50% silt and 50% clay. 6220' Coal and Carbonaceous Shale Black occasionally mott brownish black; firm; resinous occasionally earth luster; smooth occasionally matte texture; blocky to subblocky texture; composed of very carbonaceous shale grading to sub lignitic coal. 6255' Sand and Sandstone Medium gray to medium dark gray; clast size ranges from medium upper to fine upper occasionally grading to silt; subround; moderate sphericity; moderate sorting; impacted to chipped texture; mature; non to very slight silic cement; non to moderate silt packed matrix; grain and matrix supported; occasionally thin bed of tuffaceous siltstone scattered; poor to fair estimated porosity and permeability; no oil indicators/oil base mud. ( ~ EPOCH 24 ~.... Forest Oil Corporation Redoubt Unit #5 '( 6315' Tuffaceous Siltstone Medium gray; poor to moderate induration; brittle in part; crumbly occasionally crunchy; slightly seetHe; occasionally stiff; cohesive; earthy fracture; subnodular habit; earthy luster; silty texture; massive beds of uniform silt and clay; generally composed of 800k silt, 20% clay occasionally grading into silty sandstone. 6360'Sand Medium gray; clast size ranges from medium upper to fine upper; predominantly subround; moderate sphericity; mod sort impacted to chipped texture; mature; non to very slight silic cement; non to slight silt matrix; dominantly grain support wI secondary matrix support in parts; fair estimated porosity and permeability; no oil indicators oil base mud. 6410' Sand and Sandstone Medium gray to medium dark gray; clast size ranges from medium upper to fine upper with scattered coarse; subround; moderate sphericity; moderate sorting; impacted to chipped texture; mature to submature; slight to well developed silic cement; slight to mod silt packed matrix with matrix support & secondary grain support; interbedded with devitrified ash and lithic tuff fragments; composed of 70% quartz, 20% chert, 100k metamorphic; fair to poor porosity and permeability; no oil indicators with oil base mud. ( 6480' Tuffaceous Siltstone Medium dark gray; moderate to poor induration; stiff in parts; earthy fracture; subnodular habit earthy luster; silty to clayey texture; massive beds of uniform silt; generally composed of 70% silt, 30% clay; occasionally interbedded tuff fragments; overall appears reworked and redeposited. 6525' Tuffaceous Claystone Medium gray to medium light gray with dark gray secondary hue; mushy consistency; adhesive; soft to very soft occasionally crumbly; massive cuttings habit; dull to waxy luster; clayey to silty texture; massive bedding structure. 6565' Sand and Conglomerate Medium light gray to medium gray with light gray secondary hue; clast sizes range from upper fine to bit fractured pebble; poor to fair sorting; subangular to subrounded; low to moderate sphericity; 80% quartz and 20% lithic and metamorphic fragments; matrix supported; unconsolidated; no visible oil indicators. 6615' Tuffaceous Siltstone Medium gray to medium dark gray; crumbly to crunchy; irregular to earthy fracture; massive cuttings habit; dull to earthy luster; thin carbonaceous laminations interbedded. ( [:I EPOCH 25 Forest Oil Corporation Redoubt Unit #5 (' 6685' Sand Medium gray; clast size ranges from coarse lower to fine upper; subround; moderate to well developed sphericity; poor sorting; predominantly polished occasionally chip texture submature to mature; non to silic cement slight clay matrix - very hydrophilic & loosely packed; composed of 80% quartz, 10% metamorphic, greenstone and various lithic fragment fair to good porosity and permeability; no oil indicators I oil base mud. 6750' Devitrified Ash Very light gray mottled light gray; poor induration; porcelain to greasy luster; ashy to silty texture; composed of 50% devitrified ash, 50% silt; reworked and redeposited structure. 6785' Coal Black occasionally grayish black; firm; resinous luster; matte texture; irregular to hackly fracture; composed of predominantly subbituminous; visible bleeding gas cuttings 6810' Tuffaceous siltstone Light brownish gray to light gray; poor to moderate ind crumbly to crunchy; stiff in parts; cohesive; earthy fracture; subnodular habit; earthy to greasy luster; silty to ashy texture; massive beds of reworkedl redeposited silt and ash; generally composed of 60% silt, 30% ash, 10% sand; occasionally carbonaceous flakes interbedded. ( 6860' Devitrified Ash Very light gray mottled light gray; poor induration; porcelin to greasy luster; ashy to silty texture; composed of 500k ash, 40% silt, 10% very fine grained sand; appears reworked. 6890' Carbonaceous Shale and Coal Black to brownish black; firm; resinous occasionally earthy luster; matte texture; blocky fracture; composed of various degrees of very carbonaceous shale to lignite to sub bituminous coal; visible bleeding gas from cuttings. 6930' Tuffaceous Siltstone Light brownish gray mottled light gray; poor to mod induration; brittle in parts; crumbly to crunchy; cohesive; earthy fracture; sub nodular habit; greasy to earthy luster; silty/ashy texture; massive beds of reworked/redeposited ashy siltstone; composed of 70% silt. 30% ash and various detrital material; appears dirty 6980' Coal/carbonaceous shale Black to brownish black; firm; resinous occasionally earthy luster; matte texture; blocky to sbblky fracture; composed of very carbonaceous shale grading to lignitic and subbitum; occurs as thin to thick beds grading to very dirty/detritalish tuffaceous silt ( [:I EPOCH 26 - Forest Oil Corporation Redoubt Unit #5 ~' 7020' Tuffaceous Siltstone Light brownish gray mottled light gray; poor to mod induration; crumbly to crunchy; earthy fracture; cohesive; subnodular habit; greasy to earthy luster; silty to ashy occasionally gritty texture; massive beds of reworked/redeposited silt with interbedded devitrified ash, very fine grained sand and various amounts of detrital material; appears dirty; scattered thin lams of very carbonaceous shale. 707S' Tuffaceous Siltstone Light brownish gray mottled light gray; moderate ind; crumbly to crunchy; soft sediment bit deformation; stiff in parts; cohesive; irregular fracture; massive to earthy fracture; patchy habit earthy luster; silty to gritty texture; massive beds of silt reworked/redeposited; composed of 70°1'0 silt, 20°1'0 very fine grained sand, 10% devitrified ash; appears dirty and detritalish. 7130' Sandstone Light grayish brown to med light gray; clast size ranges from silt fine upper; subround to subangular; mod sphericity; very poorly sorted; polished to chipped texture; submature; slight to moderate silic cement; abundant matrix silt and ash; dominantly matrix support; composed of predominantly quartz with minor amounts of detrital material; poor porosity and permeability no oil indicators/oil base mud. ( 718S' Tuffaceous Claystone Light gray to very light gray with medium light gray secondary hue; mushy to pasty consistency; soft to very soft occasionally crumbly tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; waxy to dull luster; clayey to silty texture; massive bedding structure. 723S' Coal and Carbonaceous Shale Black to blackish red; brittle to crunchy tenacity; planar to slightly conchoidal fracture; massive cuttings habit; greasy to polished luster; matte texture; thin bedding structure; subbituminous to carbonaceous shale. 727 S' Sandstone Medium light gray to medium gray with light gray secondary hue; clast sizes range from upper medium to lower fine with occasional bit fractured pebble; poorly sorted; subangular to subrounded; moderate sphericity; soft to easily friable; matrix supported; no visible oil indicators. 7320' Tuffaceous Siltstone Medium gray to brownish gray; crumbly to crunchy tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; dull to earthy occasionally waxy luster; silty texture; massive bedding structure with thin carbonaceous laminations interbedded. ( [:I EPOCH 27 Forest Oil Corporation Redoubt Unit #5 ( 7365' Sand Light gray to very light gray with medium light gray secondary hue; clast sizes range from upper medium to lower fine; poor to fairly sorted; subangular to subrounded; low to moderate sphericity; 70% quartz and 30% chert, lithic, and metamorphic fragments; unconsolidated to soft; high amounts of ash matrix present; no visible oil indicators present. 7420' Coal Black to grayish black with blackish red secondary hue; dense to brittle tenacity; planar to conchoidal fracture; massive cuttings habit; polished to metallic luster; smooth to matte texture; thin bedding structure; no visible gas bleeding. 7475' Tuffaceous Siltstone Medium gray to medium light gray; moderate induration; crumbly to crunchy; stiff in parts; earthy fracture; subnodular habit; earthy-frost luster; silty to gritty texture; massive beds of tuffaceous silt interbedded and grad to sandstone; composed of 60% silt, 30% sand 10%) devitrified ash; becoming compressive through soft sediment bit deformation. 7525' Carbonaceous Shale and Coal Brownish black to black occasionally blackish red in parts; firm resinous to earthy luster; smooth to matte texture; blocky to hackly fracture composed of various degrees of very carbonaceous shale grading to lignite; visible bleeding gas from cuttings. ( " 7570' Carbonaceous Shale and Clay Brownish black mottled black; firm; earthy luster smooth to matte texture; hackly fracture composed of predominantly reworked carbonaceous shale grading to carbonaceous claystone; appears reworked in parts; some laminations with planar orientation; no visible bleeding gas from cuttings (7610'). 7615' Tuffaceous Claystone Medium light gray to light gray with light brownish gray secondary hue; mushy to pasty consistency; soft to crumbly tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; waxy to dull luster; clayey to silty texture; massive bedding structure with thin black carbonaceous laminations interbedded throughout. 7670' Tuffaceous Siltstone Medium gray to medium light gray; crumbly to crunchy tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; dull to earthy occasionally waxy luster; silty to gritty texture; massive bedding structure with carbonaceous laminations interbedded. ( [:I3POCH 28 Forest Oil Corporation Redoubt Unit #5 ( 7715' Coal and Carbonaceous Shale Black to grayish black with blackish red secondary hue; brittle to crunchy tenacity; planar occasionally conchoidal fracture; massive to flaky cuttings habit; waxy occasionally metallic luster; matte to silty texture; thin bedding structure; lignite to carbonaceous shale grading; slight visible gas bleeding. 7765' Tuffaceous Siltstone Medium gray to medium dark gray with light brownish gray secondary hue; crumbly to crunchy tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; waxy to dull luster; silty to clayey texture; massive bedding structure with thin black carbonaceous laminations interbedded throughout. 7820' Sandstone and Sand Medium light gray to light gray with very light gray secondary hue; clast size range from upper medium to upper fine; poor to fair sorting; angular to subangular; low to moderate sphericity; easily friable to soft; calcareous cement; matrix supported; black carbonaceous material interbedded. ( 7870' Coal and Carbonaceous Shale Black to grayish black with brownish black secondary hue; brittle to crunchy tenacity; irregular to planar occasionally conchoidal fracture; massive to flaky cuttings habit; waxy occasionally metallic luster; matte to silty texture; thin bedding structure; lignite to carbonaceous shale grading; no visible gas bleeding. 7940' Tuffaceous Siltstone Medium light gray to light brownish gray; moderate ind; crumbly to crunchy; stiff in parts; cohesive; PDC grooved fracture and habit earthy luster; 'silty to gritty texture; massive beds of homogeneous silt; composed of 70% silt, 20% very fine grained sand, 10% ash. 7980' Carbonaceous Shale, Clay, and Coal Black to brownish black; brittle to firm; earthy occasionally resinous luster; matte texture; hackly PDC fracture; composed of very carbonaceous shale and clay with micro laminations grading to lignitic coal; no visible bleeding gas from cuttings. 8020' Devitrified Ash White mottled light gray; poor occasionally moderate induration; bright earthy to greasy luster; ashy to silty texture; reworkedlredeposited; interbedded with silt, very fine grained sand and pyroclastic relic shards; occurs as thick beds grading to tuffaceous siltstone; becoming expansive. ( ~ EPOCH 29 Forest Oil Corporation Redoubt Unit #5 (' 806S' Tuffaceous Siltstone Medium gray mott white to very light gray; moderate ind; crumbly to crunchy becoming mushy to sectile in parts; occasionally slimy to slightly tacky; cohesive to slightly adhesive; earthy fracture; massive habit; greasy to earth luster; silty to ashy texture; massive beds of grad silt composed of SO% silt. 500k devitrified ash, very fine-med grain sands occasionally grading to very silty sandstone wI abundant matrix support; overal1 expansive & ashy. 812S' Coal and Carbonaceous Shale Grayish black to brownish black occasionally black to red black firm; resinous to earthy luster; smooth to matte texture; hackly fracture; composed of very carbonaceous shale to lignitic occasionally subbituminous coal; visible bleeding gas from cuttings. 8165' Sand and Sandstone Very light gray to light brownish gray; clast size ranges from medium upper to fine upper; subround; moderate occasionally well developed sphericity; moderate sort polished texture; submature; non to slightly silic cement; abundant ash/silt matrix; dominantly matrix support; composed of 90% quartz, 10% chert, metamorphic and various lithic fragments; poor porosity and permeability; no oil indicators/oil base mud. ( 8220' Coal and Very Carbonaceous Shale Black mottled brownish black occasionally grayish black; firm; resinous to earthy luster; smooth to matte texture; hackly fracture composed of very carbonaceous shale at contacts to lignitic to subbituminous coal at the gas peak; visible bleeding gas noted in cuttings at 8270'. 8265' Tuffaceous Siltstone Medium gray to medium dark gray; crumbly to crunchy tenacity; irregular fracture; PDC grooved to massive cuttings habit; dull to earthy occasionally waxy luster; silty to gritty texture; massive bedding structure. 8305' Sandstone and Sand Very light gray to light gray with medium light gray secondary hue; clast sizes range from upper medium to lower fine; poorly sorted; subangular to subrounded; low to moderate sphericity; soft to easily friable; siliceous cement; high amounts of devitrified ash matrix; black carbonaceous material interbedded; no visible oil indicators present. 8360' Coa\ Black to grayish black; brittle to crunchy tenacity; planar to irregular fracture; massive to flaky cuttings habit; waxy to metallic luster; matte texture; thin bedding structure; no visible gas bleeding. 839S' Devitrified Ash White to very light gray; mushy to pasty consistency; soft to very soft tenacity; waxy luster; clayey texture; dominantly found as a matrix material in sandstone. ( [:I. EPOCH 30 - Forest Oil Corporation Redoubt Unit #5 ( 8425' Tuffaceous Siltstone Dark gray to medium dark gray with grayish brown secondary hue; crumbly to crunchy tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; dull to earthy occasionally waxy luster; silty to gritty occasionally clayey texture; massive bedding structure with thin black carbonaceous laminations interbedded throughout. 8480' Tuffaceous Claystone Light gray to medium light gray; pasty to mushy consistency; soft to crumbly tenacity; irregular fracture; PDC grooved to massive cuttings habit; waxy to dull occasionally earthy luster; clayey texture; massive bedding structure with thin carbonaceous laminations silt, and sand interbedded. 8530' Tuffaceous Siltstone Medium gray to medium dark gray; crumbly to crunchy tenacity; irregular fracture; PDC grooved to massive cuttings habit; dull to earthy occasionally waxy luster; silty to gritty texture; massive bedding structure with thin black carbonaceous laminations interbedded throughout. ( 8575' Tuffaceous Claystone Light gray to very light gray; pasty to mushy consistency; soft to very soft occasionally crumbly tenacity; irregular fracture; massive to PDC grooved cuttings habit; waxy to dull luster; clayey texture; massive bedding structure with thin black carbonaceous laminations interbedded. 8625' Sand Medium light gray to medium gray with a salt and pepper appearance; lower coarse to upper fine with occasional bit fractured pebble; poor to fair sorting; angular to subangular; low sphericity; 70% quartz and 30% various chert, lithic, and metamorphic fragments; unconsolidated to soft; matrix supported; black carbonaceous material interbedded; no visible oil indicators present. 8685' Tuffaceous Siltstone Medium gray to light brownish gray; crumbly to crunchy tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; dull to earthy occasionally waxy luster; silty to gritty texture; massive bedding structure with thin carbonaceous laminations. 8745' Coal and Carbonaceous Shale Black mottled brownish black occasionally grayish black; firm; resinous occasionally earthy luster; smooth to matte texture; hackly fracture; composed of very carbonaceous shale grad to lignite and subbituminous coal; no visible bleeding gas from cuttings. ( ~ EPOCH 31 8 Forest Oil Corporation Redoubt Unit #5 ( 8785' Tuffaceous Siltstone Medium light gray to brownish gray with medium dark gray secondary hue; crumbly to crunchy tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; dull to earthy occasionally waxy luster; silty to gritty texture; massive bedding structure with thin carbonaceous laminations interbedded. 8835' Tuffaceous Claystone Light gray to light brownish gray with medium light gray secondary hue; mushy to pasty consistency; very soft to soft tenacity; irregular fracture; massive to PDC grooved cuttings habit; waxy to dull luster; clayey texture; massive bedding structure with thin carbonaceous laminations interbedded throughout. 8885' Tuffaceous Claystone Light gray to medium light gray; hydrophilic; pasty to mushy consistency; very soft to soft tenacity; irregular fracture; massive cuttings habit; waxy luster; clayey texture; massive bedding structure. 8920' Coal Black to grayish black; brittle to crunchy tenacity; irregular to planar occasionally conchoidal fracture; massive to flaky cuttings habit; greasy to metallic luster; matte to silty texture; thin bedding structure; lignite to carbonaceous shale grading; no visible gas bleeding. ( 8965' Sand Light gray to medium light gray; upper medium to upper fine occasional coarse to bit fractured pebble; poor sorting; angular to subangular; low to moderate sphericity; friable to easily friable; siliceous cement; matrix supported; black carbonaceous material interbedded; no visible oil indicators. 9010' Tuffaceous Siltstone Medium gray to brownish gray with medium dark gray secondary hue; crumbly to . crunchy tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; waxy to dull occasionally earthy luster; silty to gritty texture; massive bedding structure with thin black carbonaceous laminations interbedded throughout. 9060' Coal Black to grayish black with brownish black secondary hue; crunchy to brittle tenacity; irregular to planar occasional conchoidal fracture; massive to scaly cuttings habit; metallic to greasy luster; matte to silty texture; thick bedding structure; no visible gas bleeding; subbituminous to carbonaceous shale grading. ( [:I EPOCH 32 Forest Oil Corporation Redoubt Unit #5 ( 9110' Sand and Conglomerate Sand Light gray; clast size ranges from coarse lower to fine upper; subround; moderate sphericity; poor sorting; polished (med-fgr) to chip (coarse grained) texture; submature; non to slight silic cement wI slight secondary calc @ upper beds; slight clay matrix with dominantly grain support with depth; composed of 90% quartz, 10% chert, metamorphic (argillite), feldspar greenstone and various lithic fragments; fair estimated porosity and permeability no oil indicators I oil base mud. 9210' Conglomeratic Sand and Sand Light gray to very light gray; clast size ranges from very coarse lower to medium; subround medium grains with subangular coarse; poor sorting; chip coarse to polished medium grains; submature; non to very slightly silic cement; non to slight matrix silt; dominantly grain support; composed of 80% quartz, 10% chert, 10% metamorphic, greenstone, tuff and various lithic fragments; fair porosity and fair permeability; no oil indicators. 9270' Carbonaceous Shale and Coal Brownish black mottled black occasionally reddish brown hues and streak; firm; earthy to resinous luster; smooth to matte texture; hackly (coal) - planar fracture (carbonaceous shale); composed of very carbonaceous shale grad to lignitic coal. ( 9305' Tuffaceous Claystone Light brownish gray to medium light gray; firm; crumbly stiff in parts; PDC grooved fracture and habit; some soft sediment deformation; dull earthy luster; silty to clayey texture massive homogeneous beds of clay and silt; composed of 50% silt, 50% clay. 9345' Tuffaceous Siltstone Medium light gray to light gray with brownish gray secondary hue; crunchy to crumbly tenacity; irregular fracture; PDC grooved to massive cuttings habit; waxy to dull luster; silty to gritty texture; massive bedding structure with thin black carbonaceous laminations interbedded. 9395' Tuffaceous Claystone Light gray to medium light gray; pasty to mushy consistency; soft to crumbly tenacity; irregular fracture; massive to PDC grooved cuttings habit; dull to earthy occasionally waxy luster; clayey texture; massive bedding structure. 9435' Coal Black to grayish black; crunchy to brittle tenacity; planar to irregular fracture; platy to massive cuttings habit; greasy to metallic luster; matte to silty texture; thin bedding structure; subbituminous to carbonaceous shale grading; no visible gas bleeding. ,( [J EPOCH 33 Forest Oil Corporation Redoubt Unit #5 ( 9475' Sand Light gray to very light gray with medium light gray secondary hue; grain sizes range from upper fine to lower coarse with occasional bit fractured pebble; poor to moderately sorted; angular to subangular; low sphericity; 70% quartz, 20% lithic, and 100k various chert and metamorphic fragments; unconsolidated to soft; matrix supported; no visible oil indicators present. 9535' Tuffaceous Siltstone Medium gray to light brownish gray with medium light gray secondary hue; crunchy to crumbly tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; dull to earthy occasionally waxy luster; silty to gritty texture; massive bedding structure with carbonaceous material, sand, and tuffaceous claystone interbedded throughout. 9595' Tuffaceous Claystone Medium light gray to light gray with light brownish gray secondary hue; crumbly tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; waxy to dull luster; clayey texture; massive bedding structure. ( 9635" Carbonaceous Shale and Coal Grayish black to black occasionally mottled reddish black to reddish brown in carbonaceous shales; firm becoming soft in parts; earthy to resin luster; smooth to matte texture; hackly to subplanar fracture in carbonaceous shale; no visible bleeding gas in cuttings. 9675' Tuffaceous Siltstone Light brownish gray; poor to moderate induration; brittle in parts; crumbly occasionally crunchy; cohesive; PDC grooved fracture and habit moderate earthy luster; silty texture; massive beds of homogeneous silt; composed of 70% silt, 30% clay occasionally carbonaceous microlaminae. 9735' Tuffaceous Siltstone Light brownish gray; poor to moderate induration; brittle in parts; crumbly to crunchy; PDC groove fracture and habit; some soft sediment deformation; moderate earthy luster; silty texture; appears reworked with interbedded devitrified ash, fine grain sand (loose) and various detrital material. 9780' Coal and Carbonaceous Shale Grayish black to black occasionally mottled reddish black; firm earthy to resinous luster; smooth to matte texture; hackly to subplanar fracture; no visible bleeding gas from cuttings. ( 9810' Tuffaceous Claystone Light brownish gray to light gray; soft occasionally brittle; mushy; PDC grooved fracture and habit; occasionally soft sediment deformation; mod earthy luster; silty to clayey texture; expansive in parts; microlaminae of carbonaceous material. [:I EPOCH 34 Forest Oil Corporation Redoubt Unit #5 ( 9850' Sand and Conglomerate Sand Light gray; clast size ranges from coarse upper to fine lower; subangular coarse grains to subround to finer grains; moderate sphere poor sorting; chip coarse grains to polished fine grains; submature; non to very slight silic cement; non to slight silt matrix; dominantly grain support; composed of 70% quartz. 10°!'o chert, 20% metamorphic ¡argillite greenstone and various lithic fragments; fair porosity and permeability; no oil indicators/oil base mud. 9915" Carbonaceous Shale and Coal Brownish black occasionally grayish black; firm; earthy to resinous luster; smooth to matte texture; hackly fracture occasionally planar along micro laminae of carbonaceous zones; composed of predominantly very carbonaceous shale grad to lignitic coal. 9955' Tuffaceous Siltstone Brownish gray to medium gray with medium light gray secondary hue; crumbly to crunchy tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; dull to earthy occasionally waxy luster; silty to gritty texture; massive bedding structure. ( 10000' Sand and Conglomerate Light gray to medium light gray with medium gray secondary hue; clast sizes range from very coarse to upper fine; very poorly sorted; subangular to subrounded occasionally angular; low to moderate sphericity; unconsolidated to soft; matrix supported; 70% quartz, 10% chert, and 20°!'o lithic and metamorphic fragments; black carbonaceous material interbedded; no visible oil indicators loil base mud. 10060' Tuffaceous Siltstone Brownish gray to medium gray with light brownish gray secondary hue; crumbly to crunchy tenacity; irregular occasionally earthy fracture; PDC grooved to massive cuttings habit; dull to earthy luster; silty to gritty texture; massive bedding structure with thin black carbonaceous laminations interbedded throughout. 10110' Carbonaceous Shale Brownish black to black; brittle to crunchy tenacity; irregular to planar fracture; massive to flaky cuttings habit; waxy luster; silty to matte texture; thin bedding structure. 10145' Coal Black to grayish black; dense to brittle tenacity; planar to irregular fracture; massive to flaky cuttings habit; waxy to metallic luster; matte texture; thin bedding structure. 10175' Tuffaceous Siltstone Light brownish gray to medium light gray; firm; stiff in parts; crumbly to crunchy; PDC groove fracture and habit; moderate to dull earthy luster; silty to gritty texture; massive bedding of homogeneous silt; generally composed of 90% friable silt, 100k very fine grained sand, carbonaceous and various detrital material. ( [:I EPOCH 35 Forest Oil Corporation Redoubt Unit #5 ( 10240' Coal and Carbonaceous Shale Brownish black to grayish black; firm; earthy to resinous luster; smooth to matte texture hackly fracture in coal; planar fracture along carbonaceous shale laminations; no visible bleeding gas from cuttings; composed of various grades of very carbonaceous shale to lignitic coal. 10285' Tuffaceous Siltstone Light brownish gray to medium light gray; firm; stiff in parts; crumbly to crunchy; PDC groove fracture and habit; moderate to dull earthy luster; silty to gritty texture; massive beds of uniform silt generally compose of 90°..'0 friable silt, 10% devitrified ash, carbonaceous detrital material and scattered loose sand grains. 10335' Tuffaceous Siltstone Light brownish gray to light gray; firm; stiff in parts crumbly to crunchy; PDC grooved fracture and habit; moderate to dull earthy lust; silty to gritty texture; massive bedding of homogeneous silt; generally composed of 90% friable silt, 10% very fine grain sand, carbonaceous material and other detrital material. 10385' Coal Black to grayish black; dense to brittle tenacity; planar to irregular fracture; massive to flaky cuttings habit; waxy to metallic luster; matte texture; thin bedding structure. ( 10415' Tuffaceous Siltstone Medium gray to brownish gray with medium light gray secondary hue; crumbly to crunchy tenacity; irregular occasionally earthy fracture; PDC grooved to massive cuttings habit; dull to earthy luster; silty to gritty texture; massive bedding structure with thin carbonaceous laminations. 10465' Tuffaceous Claystone Medium gray to medium dark gray with light gray secondary hue; pasty to mushy consistency; soft to crumbly tenacity; irregular fracture; massive to PDC grooved cuttings habit; waxy to dull luster; crayey texture; massive bedding structure. 10510' Carbonaceous Shale Brownish black to black; brittle to crunchy; irregular to planar fracture; massive to flaky cuttings habit; waxy to dull luster; silty to clayey texture; thin bedding structure. 10560' Carbonaceous Shale and Coal Black to grayish black grading to brownish black; firm; earthy to resinous luster; smooth to matte texture; hackly fracture; composed of very carbonaceous shale grading to lignitic coal; no visible bleeding gas from cuttings. ( ~ EPOCH 36 Forest Oil Corporation Redoubt Unit #5 ( 10615' Tuffaceous Siltstone Medium gray to medium dark; crunchy to crumbly tenacity; irregular to earthy luster; PDC grooved to massive cuttings habit; dull to waxy luster; silty to gritty texture; massive bedding structure. 1 0650' Coa1 Black to grayish black; planar to irregular occasionally conchoidal fracture; massive to flaky occasionally blocky cuttings habit; metallic to vitreous luster; smooth to matte texture; thick bedding structure; subbituminous to carbonaceous shale grading. 10695' Tuffaceous Siltstone Medium gray to brownish gray; crumbly to crunchy tenacity; irregular fracture; massive to PDC grooved cuttings habit; dull to earthy occasionally waxy luster; silty to gritty texture; massive bedding structure. 10750' Tuffaceous Siltstone Light brownish gray to medium light gray; poor to mod induration; brittle in parts; crumbly to crunchy; PDC grooved fracture and habit; moderate earthy luster; silty to gritty texture; becoming interbedded with abundant devitrified ash and loose med- coarse grain sands with very carbonaceous shale and carbonaceous material. ( 10800' Tuffaceous Claystone Grayish brown to brownish gray and various hues of both; firm; slightly sectile; stiff in parts; fracture and habit; dull earthy luster; smooth clayey occasionally silty texture; thick distinct bed of brownish clays. 10835' Carbonaceous Shale Brownish black to dusky brown; crumbly to soft tenacity; irregular occasionally planar fracture; massive cuttings habit; dull to earthy occasionally waxy luster; silty to clayey texture; thin bedding structure. 10870' Sandstone Light gray to medium light gray; clast sizes range from upper coarse to lower fine with occasional bit fractured pebble; poorly sorted; angular to subangular; low to moderate sphericity; friable to easily friable; clay and silt matrix; minor amounts of carbonaceous material interbedded; no visible oil indicators. 1 0920' Tuffaceous Siltstone Medium gray to medium light gray with light brownish gray secondary hue; crumbly to crunchy tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; waxy to dull luster; silty to gritty texture; massive bedding structure. ( (I EPOCH 37 Forest Oil Corporation Redoubt Unit #5 ( 1 0960' Sandstone Light gray to very light gray; upper coarse to upper fine; poorly sorted; subangular to angular; low to moderate sphericity; dominantly quartz with minor amounts of chert, lithic, and metamorphic fragments; ash I clay matrix; no visible oil indicators. 11010' Coal Black to grayish black; dense to crunchy tenacity; planar to irregular occasionally conchoidal fracture; massive to flaky cuttings habit; metallic to waxy occasionally vitreous luster; matte texture; thin bedding structure; subbituminous to lignite grading. 11055' Tuffaceous Siltstone Medium dark gray to medium gray with brownish gray secondary hue; crunchy to crumbly tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; dull to earthy occasionally waxy luster; silty to gritty texture; massive bedding structure with thin carbonaceous laminations interbedded throughout. 11105' Sand and Conglomerate Light gray to very light gray with medium light gray secondary hue; clast sizes range from lower medium to lower coarse with occasional bit fractured pebble; poorly sorted; subangular to angular; low to moderate sphericity; unconsolidated to soft; ash I clay matrix; abundant carbonaceous material present; no visible oil indicators. ( 11160' Tuffaceous Claystone Medium gray to medium dark gray; pasty to mushy consistency; crumbly to soft occasionally crunchy tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; dull to waxy luster; clayey texture; massive bedding structure. 11205' Ash White to very light gray; mushy to pasty consistency; soft to very soft tenacity; irregular fracture; massive to PDC grooved cuttings habit; waxy luster; clayey texture. 11235" Carbonaceous Shale and Coal Brownish black to black; crunchy to crumbly occasionally brittle tenacity; irregular to planar fracture; massive to flaky cuttings habit; dull to earthy occasionally waxy luster; silty to matte texture; thin bedding structure. 11275' Tuffaceous Siltstone Dark to medium dark gray; slightly hard to crunchy tenacity; irregular fracture; massive cuttings habit w/abundant PDC markings; dull earthy luster; silty to gritty; occasionally slightly sandy; abundant carbonaceous to coaly laminations; interbedded with thin coal/carbonaceous shale. ( ~-I ~-Y)OCL--- L-...-.J -.A- _.Jr=,- 38 Forest Oil Corporation Redoubt Unit #5 ( 11320' Sandstone and Conglomeratic Sandstone Light gray to offwhite; predominantly soft; upper coarse to fine grained; angular to subangular; poorly to mod sorting; low to mod sphericity; predominantly matrix supported; ash/clay matrix; some light orange to gray chert; some black carbonaceous material as thin laminations; no oil indicators. 11390' Tuffaceous Siltstone Dark gray to dark brownish gray; firm to slightly hard; crunchy in part; irregular to splintery fracture massive to slightly platy cuttings; dull to slightly waxy luster; silty to gritty texture sandy in part; very carbonaceous; occasionally with thin coaly streaks. 11430' Sandstone Light gray to offwhite; abundant loose grains; upper medium to fine grained; angular to subangular; mod sorted; low to mod sphericity; matrix to grain supported; < 1 OOk chert; ash/clay matrix; occasionally grading to tuff; soft to firm; occasionally carbonaceous w/ thin reddish brown to black carbonaceous laminations; no oil indicators. 11480' Sand Medium gray to medium light gray; upper fine to upper medium with occasional upper coarse to bit fractured pebble; fairly sorted; subangular to subrounded; moderate sphericity; unconsolidated to soft; calcareous cement; matrix supported; abundant carbonaceous material presents; no visible oil indicators. ( 11530' Tuffaceous Siltstone Medium gray to medium dark gray; crunchy to crumbly tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; dull to earthy luster; silty to gritty texture; massive bedding structure. 11565' Coal Black to grayish black; crunchy to brittle tenacity; irregular to planar fracture; massive to flaky cuttings habit; waxy to metallic luster; matte to silty texture; thin bedding structure; lignite to carbonaceous shale grading. 11600' Sandstone and Conglomeratic Sandstone Predominantly loose grains; some light to medium gray preserved specimens; clast size ranges from broken pebble to fine grained; dominantly medium grained; angular to subangular; poorly sorted; low to mod sphericity; dominantly grain supported; clay matrix; abundant red to green grains; < 20% chert; some scattered carbonaceous material; no oil indicators. 11675' Coal and Carbonaceous Shale Black to dark gray; mod hard to brittle; irregular to planar fracture; platy to wedgelike cuttings; dull earthy to slightly resinous luster; matte texture; thinly bedded. [:I EPOCH 39 Forest Oil Corporation Redoubt Unit #5 11705' Tuffaceous Siltstone Dark gray; firm to slightly crunchy; massive to platy cuttings; irregular fracture; slightly vitreous to dull earthy luster; silty texture; occasionally sandy wI upper to lower fine quartz grains; scattered carbonaceous mat; interbedded with thin coalsJcarbonaceous shales. 11780" Carbonaceous Shale and Coal Brownish black to black; crunchy to brittle tenacity; planar to irregular fracture; flaky to massive cuttings habit; waxy to metallic luster; matte to silty texture; thin bedding structure; carbonaceous shale to lignite grading. 11820' Tuffaceous SHtstone Medium gray to brownish gray with medium light gray secondary hue; crumbly to crunchy tenacity; irregular to earthy fracture; massive cuttings habit; dull to earthy occasionally waxy luster; silty to gritty texture; massive bedding structure with microthin carbonaceous laminations interbedded. 11870' Tuffaceous Claystone Medium light gray to light gray; pasty consistency; soft to crumbly tenacity; irregular fracture; massive cuttings habit; waxy to dull luster; clayey texture; massive bedding structure with carbonaceous laminations interbedded. ( 11910' Coal and Carbonaceous Shale Grayish black to black wI shaly brownish black sects; mod hard wI brittle to crunchy tenacity~ irregular to planar fracture habit; slightly vitreous to dull earthy luster; massive wI local interbeds of carbonaceous laminations in siltstone and claystone. 11950' Sandstone and Conglomeratic Sandstone Predominantfy loose grains; some light gray preserved pieces rare broken coarse to fine grained; dominantly upper to lower medium; poorly sorted; angular to subangular; low to mod sphere; predominantly clay matrix w/some calcite fill; rr red grains; very carbonaceous wI thin black coaly streaks at 11985'; no oil indicators. 12000) Coal and Carbonaceous Shale Black to dark gray; firm to slightly hard; hackly to planar fracture; platy cuttings habit; dull earthy to slightly resinous luster; rough texture; thick bedded. 12030' Sandstone and Conglomeratic Sandstone Predominantly loose grains; clast size ranges from broken upper coarse to fine grained; poorly sorted; angular to subrounded; low to moderate sphericity; rare clay matrix supported specimens; dominantly clear quartz grains; < 10% chert; some carbonaceous material; no oil indicators. ( [J EPOCE 40 . . Forest Oil Corporation Redoubt Unit #5 1(' 12075' Sand and Conglomerate Medium gray to medium light gray; clast sizes range from lower medium to bit fractured pebble; poor to very poorly sorted; subangular to angular with high amounts of bit impacted grains; low to moderate sphericity; 700k quartz, 1 Oak chert, and 200/0 various lithic and metamorphic fragments; calcareous cement; matrix supported; no visible oil indicators. 12130' Coal Black to grayish black; dense to brittle tenacity; planar to conchoidal fracture; wedgelike to platy cuttings habit; metallic to resinous luster; matte to smooth texture; thick bedding structure; no visible gas bleeding. 12165' Tuffaceous Siltstone Light to medium gray to dark brownish gray; firm to crumbly; irregular fracture; massive to slightly platy cuttings habit; dull earthy to slightly waxy luster; rough to silty to occasionally gritty texture; occasionally grades to very fine grained sandstone; abundant carbonaceous material. 12225' Coal and Carbonaceous Shale Black; firm to mod hard; brittle in part; blocky fracture; blocky to platy cuttings; slightly vitreous to resinous luster; smooth to rough texture; thinly bedded; interbedded with claystone. ( 12265' Tuffaceous Siltstone Medium dark gray to medium gray with brownish gray secondary hue; crumbly to crunchy tenacity; irregular to earthy fracture; massive cuttings habit; dull to earthy occasionally waxy luster; silty to gritty texture; massive bedding structure with microthin carbonaceous laminations. 12315' Tuffaceous Claystone Medium gray to medium light gray; pasty consistency; soft to crumbly tenacity; irregular to earthy fracture; massive cuttings habit; dull to waxy luster; clayey texture; massive bedding structure. 12360' Tuffaceous Siltstone Medium gray to brownish gray; mod hard to firm; irregular to blocky fracture; massive cuttings; dull earthy luster; silty texture; sandy in part; some carbonaceous material. 12410' Coal to Carbonaceous Shale Black; slightly hard to brittle; planar fracture; platy to scaly cuttings; dull to slightly resinous luster; rough to occasionally smooth texture; thickly bedded. ( [:I EPOCH 41 .~< Forest Oil Corporation Redoubt Unit #5 ( 12440' Sandstone Predominantly loose grains; clast size ranges from lower medium to fine grained; mod sorted; angular to subangular; low to mod sphericity; argillic in part wI some preserved clay matrix supported specimens; rare green and redbrown grains; rare carbonaceous and silty laminations; no oil indicators. 12485' Tuffaceous Claystone Medium gray to medium dark gray; firm; irregular fracture; massive to slightly platy cuttings; dull earthy luster; slightly silty texture; abundant black carbonaceous lam; silty in part; grading to medium gray siltstone. 12525' Coal to Carbonaceous Shale Black; firm; brittle in part; planar fracture; platy to wedgelike cuttings; dull earthy to slightly resinous luster; smooth to rough texture; some brown/black carbonaceous shale. 12555' Tuffaceous Siltstone Medium dark gray to medium gray with brownish gray secondary hue; crunchy to crumbly occasionally hard; irregular to earthy fracture; massive to PDC grooved cuttings habit; dull to earthy luster; silty to gritty texture; massive bedding structure with sand, clay, and thin carbonaceous laminations interbedded throughout. -( 12610' Sand Medium light gray to very pale orange with medium gray secondary hue; clast sizes range from lower medium to upper fine; fair to poorly sorted; subrounded to rounded with occasional subangular; moderate sphericity; soft to unconsolidated; calcareous cement; matrix supported; clay and carbonaceous laminations interbedded; minor amounts of chloritization; no visible oil indicators. 12670' Carbonaceous Shale to Coal Black; minor amts of brown/black; firm to brittle; planar to blocky fracture; platy to flaky cuttings; dull earthy luster; smooth to rough texture; thinly bedded. 12705' Sandstone White to very light gray; firm! nonfriable; clast size from lower medium to very fine grained; mod sorted; grain supported; angular to subangular; grain to matrix supported; silty in part grading to argillaceous siltstone; abundant ash/clay in matrix; very carbonaceous w!carbonaceous laminations; poor visible porosity and permeability; trace amt of chert; no oil indicators. 12760' Coal to Carbonaceous Shale Black; firm to mod hard; blocky to planar fracture; blocky to platy cuttings; dull to slightly resinous luster; smooth to rough texture; interbedded with claystone. ( [:I EPOCH 42 Forest Oil Corporation Redoubt Unit #5 ( 12790' Tuffaceous Siltstone Medium gray to medium dark gray with brownish gray secondary hue; crumbly to crunchy tenacity; irregular fracture; PDC grooved to massive cuttings habit; dull to earthy luster; silty to gritty texture; massive bedding structure. 12830' Sand Light gray to medium light gray; upper to lower medium grain sizes; fair to poorly sorted; angular to subangular; low sphericity; matrix supported; unconsolidated; no visible oil indicators. 12865' Coal Black to grayish black; crunchy to brittle tenacity; planar occasionally conchoidal fracture; flaky to wedglike cuttings habit; metallic to resinous luster; matte occasionally smooth texture; thick bedding structure; lignite to carbonaceous shale grading. 12905' Sandstone Offwhite to light gray; firm to nonfriable; lower medium to lower fine grained; angular to subangular; mod sorting; low to mod sphericity; matrix to grain support w/ abundant clay/ash; trace chert; trace green grains; tight to poor porosity and permeability; carbonaceous material and laminations; no oil indicators. ( 12955' Coal to Carbonaceous Shale Black; mod hard to brittle; blocky to platy cuttings; irregular to blocky fracture; slightly vitreous luster; smooth to matte texture; thinly interbedded with siltstone. 12990' Tuffaceous Siltstone Dark gray to grayish brown with medium dark gray secondary hue; crumbly to crunchy tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; dull to earthy occasionally waxy luster; silty to gritty texture; massive bedding structure. 13035' Tuffaceous Claystone Medium gray to medium dark gray with medium light gray secondary hue; crumbly to slightly soft tenacity; irregular to earthy luster; PDC grooved to massive cuttings habit; waxy to dull luster; clayey texture; massive beddings structure. 13090' Tuffaceous Siltstone Light brownish gray; poor to moderate induration; brittle occasionally stiff; crumbly to crunchy; PDC grooved fracture and habit; dull earthy luster; silty to gritty texture; massive homogeneous beds of friable silt; generally composed of 80% silt, 20°Æ, clay; scattered coarse grained loose sand; occasionally carbonaceous shale/ thin beds. ( 13135' Tuffaceous Siltstone to Very Fine Sandstone Light to medium gray; mod hard to dense; massive cuttings; irregular fracture; dull earthy luster; gritty to silty texture; clay to silic matrix; grading to very fine to fine grained sandstone; some carbonaceous laminations. ~ EPOCH 43 8 Forest Oil Corporation Redoubt Unit #5 ( 13180' Sandstone Predominantly loose grains; clast size from rare broken coarse to fine grained; angular to subangular; poorly to mod sorted; low to mod sphericity; abundant ash matrix in samples; ash/clay matrix; poorly preserved; 20°1Ó chert; becoming conglomeratic at 13220'; abundant greenish grains; predominantly grain supported; abundant carbonaceous laminations; no oil indicators. 13255' Tuffaceous Siltstone Light gray to medium dark gray; some mod hard preserved, specimens; massive cuttings; irregular fracture; predominantly clay matrix; very gritty texture; grades to sandstone; carbonaceous in part. 13290' Coal to Carbonaceous Shale Grayish black to brownish black occasionally black; firm; dull earthy occasionally resinous luster; smooth to matte texture; PDC hackly fracture; composed of predominantly lignitic coals grading to very carbonaceous shale. 13320' Tuffaceous Siltstone Light brownish gray to light gray; poor to moderate induration; brittle occasionally stiff in parts; crumbly to crunchy; PDC grooved fracture and habit; dull earthy luster; silty to gritty texture; massive beds of grad silt with occasionally scattered fine sand. ( 13360' Tuffaceous Siltstone Light brownish gray; poor to moderate induration; brittle occasionally stiff; crumbly to crunchy; PDC grooved fracture and habit; dull earthy luster; silty to ashy texture; becoming interbedded with devitrified ash and fine grain sand; occasionally becoming very detritalish. 13400' Coal to Very Carbonaceous Shale Grayish black to brownish black occasionally black; firm; dull earthy to resinous luster; smooth to matte texture; PDC hackly fracture; composed predominantly of very carbonaceous shale to lignitic coal. 13435' Sandstone Very light gray to white gray; soft; clast size from lower medium to fine grained; angular to subangular; mod well sorted; mod sphericity; abundant white ash matrix material in samples; matrix to grain supported; <10% chert; carbonaceous laminations; grading to tuffaceous siltstone; no oil indicators. 13500' Tuffaceous Siltstone to Sandstone Very light gray to white gray; soft to firm; silt to lower medium quartz grains; angular quartz; mod well sorted; white ash/clay matrix; pedom matrix supported; very carbonaceous to coaly; very coaly at 13520' with quartz grains embedded in coal; no oil shows. ~ EPOCH 44 Forest Oil Corporation Redoubt Unit #5 ( 13555' Devitrified Ash Very light gray mottled med light gray occasionally salt and pepper; very poorly indurated; greasy occasionally satin luster ashy texture; appears altered and redeposited; smectite; visible pyroclastic relic shards; interbedded with silt and grading to siltstone. 13590' Tuffaceous Siltstone Medium light gray poor to moderate induration; brittle occasionally stiff; crumbly to crunchy occasionally mushy to pasty in ashy sections; PDC fracture and habit; dull earthy luster; silty to ashy texture; massive beds of grad silts; occasionally interbedded with ash and fine grain sand. 13630' Coal to Very Carbonaceous Shale Black to brownish black; firm occasionally hard; resinous to earthy luster; smooth to matte texture; hackly PDC fracture; composed of very carbonaceous shale to lignitic coal; no visible bleeding gas from cuttings. 13665' Devitrified Ash Light gray mottled medium light gray; very poorly indurated; greasy to satin luster; ashy to silty texture; appears reworked and redeposit smectite; visible pyroclastic relic shards; interbedded with silt and carbonaceous detrital material. ( 13705' Coal to Carbonaceous Shale Black; firm to mod hard; blocky to platy cuttings; hackly to splintery fracture; slightly resinous to earthy luster; smooth to matte texture. 13735' Sandstone Light gray to light white! gray; clast size ranges from lower medium to fine grained; angular to subangulac low to mod sphericity; mod sorted; grain to matrix supported; abundant white ash/silt matrix material; slightly carbonaceous; grades to siltstone; no oil indicators. 13800' Sand Very light gray; size ranges from coarse lower to fine upper; subround occasionally subangular; moderate sphericity; mod to poor sorting; polished texture; submature non to very slight silic cement; abundant clay/ash supported matrix; composed of predominantly quartz with secondary chert, metamorphic and greenstone; note the appearance of c-4's and c-5's @ 13800'. 13845' Tuffaceous Siltstone Ught gray mottle light brownish gray; poor induration; PDC grooved fracture and habit; greasy to earthy luster; ashy to silty texture; decreasing ash content; interbedded with thin to thick beds of conglomerate sands. ( ~ E:?OCH 45 Forest Oil Corporation Redoubt Unit #5 (~ 13880' Sand Light gray; clast size range med upper to fine upper; subround; mod sphericity poor sorting; polished texture; submature; non to very slight silic cement; abundant to massive silUash matrix grading to siltstone; poor porosity and permeability; oil indicators masked by mud system. 13920' Coal to Carbonaceous Shale Black mottled brownish black; firm; earthy occasionally resinous luster; matte texture; PDC hackly fracture. 13940' Sandstone to Siltstone Light gray; firm clast size from lower medium to fine grained; trace broken coarse grains; mod sorted; low to mod sphericity; grain to matrix supported; ash matrix; grading to siltstone; trace amts of chert; becoming cleaner at 13970'. 14005' Coal (14015' to 14032') Black; brittle planar fracture; vitreous luster; smooth texture; homogeneous and uniform; gas bleeding from core chips. 14035' Carbonaceous Shale Dark gray; mod hard to dense; thin coaly plant remains; variable amounts of silt; interbedded with carbonaceous siltstone. ( 14060' Coal (14075') Black; firm; vitreous to metallic luster; smooth to matte texture; subconchoidal to hackly fracture; composed of predominantly bituminous coal; visible bleeding gas from cuttings. 14090' Conglomeratic Sand Light gray; clast size very coarse lower to medium upper; subangular to subrounded; moderate sphericity; moderately sort; polish to chip texture abundant ash/silt support matrix; composed of 80 quartz, 10% chert, 10% very lithic fragments; poor - fair porosity and permeability; no oil indicators. 14125' Carbonaceous Shale Black to brownish black; firm to hard; earthy occasionally resinous luster; smooth to matte/gritty texture; hackly occasionally subplanar fracture; composed of very carbonaceous shale grading to sublignitic coal. 14160' Tuffaceous Siltstone Light to medium gray; firm to mod hard; massive cuttings; irregular fracture; dull luster; silty texture; with variable amounts of ash in matrix; carbonaceous material and thin laminations; interbedded with thin coal/carbonaceous shale. ( / ~ EPOCH 46 Forest Oil Corporation Redoubt Unit #5 ( 14200' Tuffaceous Siltstone to Sandstone Light to medium gray; soft to mod hard; massive cuttings; irregular fracture; abundant ash in samples; ash/clay matrix; becoming sandy in part; greasy to earthy luster; silty to gritty texture; interbedded with thin carbonaceous shale/coal intervals. 14240' Sandstone Predominantly loose grains; poorly preserved; clast size from lower medium to very fine grained; trace matrix supported specimens; angular to subangular; low to mod sphericity; increase ash content in samples; trace green grains; predominantly ash matrix; very carbonaceous; no oil indicators. 14310' Tuffaceous Siltstone Pinkish gray to light brownish gray; mod induration; earthy fracture; subnodular habit; greasy to earthy luster; silty occasionally ashy texture composed of 600/0 silt, 30% ash, 10% very fine grained sand and various detrital material; scattered cong sand and ash; app reworkedlredeposited. 14350' Coal Black to brownish black; firm to hard; resinous to earthy luster; matte texture; hackly fracture; composed of very carbonaceous shale at contacts to subbituminous coal. ( 14380' Coal (14395' to 14405') Black occasionally brownish black; firm occasionally hard; resinous to earthy luster; matte texture; subblocky to hackly fracture; composed of lignitic to subbituminous coal; visible bleeding gas from cuttings. 14415' Tuffaceous siltstone Brownish gray to pale yellowish brown; mod indurated; stiff; earthy fracture; subnodular habit earthy luster~ silty/clayey texture; composed of 70% silt, 300k clay; slightly carbonaceous. 14450' Sandstone and Conglomerate Light gray; clast size ranges from broken pebble to lower medium; poorly sorted; low to mod sphericity; dominantly angular grains w/minor subrounded; silUclay matrix; dominantly grain supported; <20% chert; occasionally trace redbrown to green grains; some very hard, siliceous specimens sandstone specimens preserved in samples; no oil indicators in oil base mud. 14505' Sandstone and Conglomerate Predominantly loose grains; some preserved light grain specimens; clast size from upper coarse to fine grained; angular to subangular; mod sphericity; poorly sorted; increase in siltstone thru this interval matrix to grain supported; clay/silt matrix; trace amts redbrown to green grains; trace amts of carbonaceous mat; minor amts of chert<10%; occasionally grades to sandy siltstone; occasionally slightly calcareous; occasionally thin coaly streaks. ( [:I. EPOCH 47 Forest Oil Corporation Redoubt Unit #5 I (' 14570' Conglomerate Sandstone Light gray; clast size from broken pebble to lower medium grained; poorly to mod sorted; angular to subrounded; low to mod sphericity; matrix supported; silUclay matrix; occasionally mod siliceous; some grain supported siliceous specimens; <20ok chert; scattered carbonaceous material; no c-4's or c-5's; thinly interbedded with carbonaceous shale which exhibits trace amounts of c'4. 14645' Sandstone and Conglomeratic Sandstone Very light gray; soft to friable; grain size from upper fine to lower medium; angular to subangular; mod sorted; low to moderate sorting; matrix supported; predominantly clay/silt matrix~ 200k chert; minor amts of black metamorphic/lithic fragments. 14710' Core #2 - Conglomerate Sand 14715'-14722' Very light gray to medium light gray; clast sizes range from scattered pebble predominantly coarse grained to fine upper; coarse grained subrounded to subangular low to poor sorting; chip texture; weak silic cement; grain supported with loose clay matrix; grad to med to fine sand at 14726'; predominantly quartz with minor chert scattered coal fragments interbedded (pebble size); fair to good porosity and permeability; no oil indicators/oil base mud. ( 14760' Sand and Conglomerate Sand Light brownish gray to pale yellowish brown; clast size ranges from pebble/coarse grain to fine; subangular to subround; mod occasionally low developed sphericity; poor sorting; chip to impacted texture; non calc; very weak silic cement; mod silt/ash support at 14770' grading to predominantly grain support at 14800'; fair to good estimated porosity 14810' Tuffaceous siltstone Medium light gray to light brownish gray~ poor to moderate induration; stiff in parts~ PDC grooved fracture and habit; earthy luster; silty texture; thin beds of very carbonaceous shale grading to coal at 14825-14836'. 14855' Sand Light brownish gray to pale yellowish brown; clast size ranges from medium upper to fine lower occasionally scattered coarse grained~ subround to subangular; moderate sphericity; moderate sorting; chip to impact texture submature; non to slight silic cement; non calc; very slight clay/ash matrix; dominantly grain support; composed of 70% quartz 10% chert, 20% metamorphic, feldspar and various lithics fragments; fair to good porosity and permeability. 14910' Sand Light brownish gray to medium gray; clast sizes range from upper fine to upper very coarse; very poor sorting; subangular to subrounded with occasional bit impacted grain; moderate to low sphericity; grain supported with occasional silt matrix; dominantly quartz with minor amounts of chert and metamorphic fragments; fair to good visual porosity and permeability. ( [:I EPOCH 48 Forest Oil Corporation Redoubt Unit #5 ( 14985' Sand Light brownish gray to pinkish gray with very light gray secondary hue; clast sizes range from upper fine to upper coarse; poor to very poor sorting; subangular to subrounded with occasional bit fracture; low to moderate sphericity; silt to ash matrix material; black carbonaceous material interbedded throughout; fair to good visual porosity and permeability; no visible oil indicators J oil base mud. 15045' Carbonaceous Shale to Coal Brownish black to grayish black; brittle to firm; earth to subresinous luster; matte to smooth texture; irregular to hackly fracture; composed of very carbonaceous shale grading to lignitic coal at 15067'. 15080' Sand to Sandstone Light brownish gray to very pale orange; clast size ranges from medium lower to fine lower; subangular to subround; moderate sphericity; mod sorting; chip to impacted texture; sub mature; slight silic cement; dominantly grain supported; slight silUclay matrix-loose attachment; composed of 70% quartz, 10% chert 20% metamorphic and various lithic fragments; fair to good porosity and permeability; no oil indicators I oil base mud. ( 15140' Carbonaceous Shale Grayish black occasionally brownish gray; moderate induration; sub planar to splintery fracture; subplaty habit; dull earthy luster; smooth to matte texture; thick bed of very carbonaceous shale becoming brownish gray at contacts grading to very ashy tuffaceous siltstone. 15180' Tuffaceous Claystone Brownish gray to medium dark gray; pasty consistency; soft to very soft tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; waxy to dull luster; clayey texture; massive bedding structure. 15220'Tuff White to very light gray; pasty consistency; very soft tenacity; irregular fracture; massive to PDC grooved cuttings habit; waxy luster; clayey texture. 15270' Tuffaceous siltstone Medium dark gray to brownish gray; crumbly to crunchy tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; dull to earthy luster; silty to gritty texture; massive bedding structure. 15305' Carbonaceous Shale Very dusky red to moderate brown; crumbly to soft tenacity; planar to irregular fracture; flaky to PDC grooved cuttings habit; waxy to dull luster; clayey to silty texture; thin bedding structure. ( U EPOCH 49 l '( ( ( Forest Oil Corporation Redoubt Unit #5 15340' Tuffaceous Siltstone and Devitrified Ash Very pale orange mottled pinkish gray to very light gray; very poorly indurated; brittle; mushy; irregular fracture; massive habit; mod to bright greasy to earthy luster; ashy texture; thick to massive beds of rework silt and ash; expansive; interbedded with various detrital material: mod reddish brown carbonaceous, pyroclastic relic shards, silt, and very fine grain sand; difficult to discern between silt and devitrified ash boundaries. 15400' Carbonaceous Clay Reddish brown to grayish brown occasionally grayish black; poor to moderate induration; brittle to stiff; PDC fracture and habit; earthy luster; clayey/silty texture; thin beds of carbonaceous clay. [:I. EPOCH 50 Forest Oil Corporation Redoubt Unit #5 (' Begin RU #5A 11515' Conglomeratic Sandstone Predominantly loose grains; clast size from broken pebble to fine grained; rare light gray grain supported specimens wI claylsilt matrix; poorly sorted; mod sphericity; dominantly angular to subangular w/minor amts of subrounded grains; 10% light to medium gray chert; thinly interbedded with thin carbonaceous shale intervals; no oil indicators. 11570' Coal and Carbonaceous Shale Black; mod hard; occasionally brittle; platy to flaky cuttings habit; planar to irregular fracture; dull to slightly vitreous luster; smooth to rough texture; lignite to carbonaceous shale. 11600' Tuffaceous Siltstone Medium gray to medium dark gray; crunchy to crumbly tenacity; irregular to earthy fracture; massive cuttings habit; dull to earthy occasionally waxy luster; silty texture; massive bedding structure. ( 11635' Sand Medium gray to brownish gray; clast sizes range from upper fine to lower coarse with occasional bit fractured pebble; poorly sorted; subangular to angular; low to moderate sphericity; unconsolidated; matrix supported; no visible oil indicators. 11675' Coal and Carbonaceous Shale Black to grayish black; crunchy to brittle tenacity; planar to conchoidal fracture; massive cuttings habit; waxy to dull luster; matte to silty texture; thin bedding structure; carbonaceous shale to lignite grading. 11715' Tuffaceous Claystone Medium light gray to light gray; mushy to pasty consistency; soft to crumbly tenacity; irregular to earthy fracture; massive cuttings habit; waxy to dull luster; clayey texture; massive bedding structure with thin black to reddish black carbonaceous laminations. 11760' Carbonaceous Shale and Coal Black to dark gray; mod hard; platy to flaky cuttings; planar to irregular fracture; dull to slightly vitreous luster; matte to smooth texture; some slightly visible gas bleeding from coal specimens. 11795' Tuffaceous Siltstone Medium gray to medium dark gray; massive cuttings; mod to very hard; irregular fracture; dull to earthy luster; clayey to silty texture; variable amts of clay; some carbonaceous material; thinly bedded with claystone and thin coals. [:I EPOCH 51 8 Forest Oil Corporation Redoubt Unit #5 1(' 11835' Carbonaceous Shale and Coal Black to dark gray; hard to brittle; platy cuttings; planar to occasionally blocky fracture; dull earthy to slightly resinous luster; thinly bedded. 11880' Tuffaceous Claystone Medium dark gray to medium gray with brownish black secondary hue; pasty occasionally mushy consistency; soft to crumbly tenacity; irregular to earthy fracture; massive cuttings habit; dull to waxy occasionally earthy luster; clayey occasionally silty texture; massive bedding structure with thin carbonaceous laminations. 11935' Carbonaceous Shale and Coal Black; mod hard to brittle; platy to flaky cuttings irregular to planar fracture; dull earthy to slightly vitreous luster; rough to smooth texture; thinly interbedded with claystones and siltstones. 11970' Tuffaceous Claystone Light gray to medium gray; mod hard; massive cuttings habit; irregular fracture; dull earthy luster; silty to clayey texture; silty in part; carbonaceous in part; interbedded with thin carbonaceous/coaly beds. ( 12005' Conglomeratic Sandstone Predominantly loose grains; some light gray matrix supported specimens; clast size from coarse to fine grained; poorly sorted; angular to subrounded; clay/ash matrix; low sphericity; unconsolidated; no visible oil indicators. 12055' Coal and Carbonaceous Shale Black to grayish black with brownish black secondary hue; crumbly to crunchy tenacity; irregular to planar fracture; massive to flaky cuttings habit; waxy to dull luster; matte to clayey occasionally silty texture; thin bedding structure; carbonaceous clay to lignite grading. 12105' Tuffaceous Siltstone Light gray to very light gray; crumbly to soft tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; waxy to dull occasionally greasy luster; silty to gritty texture; massive bedding structure; grades from a siltstone to fine grained sandstone. 12190' Conglomeratic Sandstone Light gray to offwhite gray; friable; clast size from broken pebble to fine grained; angular to subangular; low sphericity; dominantly matrix supported with ash/silt matrix; minor amounts of greenstone and redbrown grains; poorly sorted; slightly calcareous; abundant carbonaceous laminations; no oil indicators. ( [:I EPOCH 52 Forest Oil Corporation Redoubt Unit #5 ( 12250' Coal and Carbonaceous Shale Black to dark gray; platy to flaky cuttings; planar to conchoidal fracture; mod hard; occasionally brittle; dull to slightly resinous luster; smooth to rough texture; thinly bedded. 12275' Tuffaceous Siltstone Medium gray to brownish gray with medium dark gray secondary hue; soft to crumbly tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; waxy to dull luster; silty to gritty texture; massive bedding structure; minor amounts of black carbonaceous material interbedded throughout. 12340' Tuffaceous Claystone Light gray to medium light gray; pasty consistency; soft to crumbly tenacity; irregular fracture; massive to PDC grooved cuttings habit; dull to earthy occasionally waxy luster; clayey texture; massive bedding structure. 12380' Coal and Carbonaceous Shale Black to grayish black with reddish black secondary hue; crunchy to crumbly tenacity; planar to irregular fracture; massive to flaky cuttings habit; greasy to resinous luster; matte to silty texture; thin bedding structure. i( 12420' Sand Medium light gray to light gray; clast sizes range from lower medium to lower fine; fair to poorly sorted; subangular to subrounded; moderate to low sphericity; friable to soft; matrix supported; matrix material ranges from ash and clay to silt; abundant black carbonaceous material interbedded throughout. 12470' Tuffaceous Siltstone Medium gray to brownish gray with medium dark gray secondary hue; soft to crumbly tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; waxy to dull luster; silty to gritty texture; massive bedding structure; minor amounts of black carbonaceous material interbedded. 12520' Tuffaceous Claystone Dark gray to med dark gray; crumbly to crunchy tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; dull to earthy occasionally waxy luster; clayey texture; massive bedding structure. 12555' Tuffaceous Siltstone Light gray to medium dark gray; firm to crumbly; massive to PDC grooved cuttings; dull earthy luster; silty to clayey texture; variable amts of silt; grading to silty claystone; variable amounts of carbonaceous material. ( (J EPOCH 53 Forest Oil Corporation Redoubt Unit #5 '( 12595' Tuffaceous Claystone Dark gray to medium dark gray; firm to mod hard; massive cuttings with PDC markings; irregular fracture; dull earthy to slightly waxy luster; silty to clayey texture silty in part; grading to siltstone; abundant carbonaceous material and thin carbonaceous laminations. 12640' Carbonaceous Shale and Coal Black to dark gray; platy to flaky cuttings; mod hard to brittle; splintery to planar fracture; dull earthy to slightly resinous luster; rough texture; some visible gas bleeding from coal specimens. 12680' Tuffaceous Claystone Medium dark gray to medium gray; firm to crumbly; massive cuttings with PDC markings; irregular fracture; dull earthy luster; silty to occasionally gritty texture; silty to slightly sandy; variable amts of carbonaceous material. 12720' Sandstone Predominantly loose grains; clast size ranges from lower medium to fine grained; mod sorted; angular to subangular; some matrix supported specimens; trace chert and greenstone; low to mod sphericity; ash/clay matrix; moderately to slightly carbonaceous; no oil indicators. ( 12760' Sand Light brownish gray to medium light gray with brownish gray secondary hue; clast sizes range from upper coarse to lower fine; poorly sorted; subangular to subrounded; low to moderate sphericity; unconsolidated to friable; matrix supported; dominantly silt with minor amounts of ash and clay matrix; minor amounts of black carbonaceous material interbedded; no visible oil indicators. 12835' Coal and Carbonaceous Shale Black to brownish black with blackish red secondary hue; crunchy to brittle tenacity; splintery to planar fracture; massive to flaky cuttings habit; greasy to resinous luster; matte to silty occasionally smooth texture; thin bedding structure; carbonaceous shale to subbituminous grading. 12885' Sandstone Predominantly loose grains; light gray to offwhite gray; friable; clast size ranges from lower medium to fine grained; mod sorted; dominantly angular to subangular with minor subrounded grains; low to mod sphericity; matrix supported; ash/clay matrix; minor amts of red brown grains; trace medium gray chert; carbonaceous laminations; no oil indicators. : ( [:I EPOCH 54 Forest Oil Corporation Redoubt Unit #5 '( 12940' Sandstone Light gray to offwhite; dominantly fine grained; clast size from lower medium to fine grained; mod well sorted; angular to subangular; abundant white ash matrix material in samples; matrix supported; crumbly in part; rare redbrown and greenstone grains; moderately carbonaceous; low to mod sphericity; no oil indicators. 12990' Tuffaceous Claystone Light to medium dark gray; some black carbonaceous intervals; firm to soft; crumbly in part abundant PDC tubular cuttings and markings; massive to slightly platy; irregular fracture; dull earthy luster; clayey to silty texture; variable amounts of silt; interbedded with thin carbonaceous shale; becoming silty to sandy below 13000'. 13040' Coal and Carbonaceous Shale Black to blackish red; brittle to crunchy tenacity; splintery to planar fracture; flaky to massive cuttings habit; greasy to resinous luster; matte to silty texture; thin bedding structure; carbonaceous shale to lignite grading. ( 13080' Tuffaceous Claystone Medium dark gray to dark gray with brownish gray secondary hue; crumbly to crunchy tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; dull to earthy occasionally waxy luster; clayey occasionally silty texture; massive bedding structure with thin black to blackish red carbonaceous laminations interbedded throughout. 13135' Tuffaceous Siltstone Medium dark gray to medium gray with brownish gray secondary hue; crunchy to crumbly tenacity; irregular to èarthy fracture; massive to PDC grooved cuttings habit; waxy to dull occasionally earthy luster; silty to gritty texture; massive bedding structure. 13180' Coal Black; mod hard to brittle; platy to blocky cuttings; blocky to planar fracture; slightly vitreous luster; smooth to rough texture; massive coal; some visible gas bleeding from specimens. 13210' Sandstone Light gray; predominantly loose grains; clast size ranges from lower medium to fine grained; angular to subangular; mod well sorted; low to mod sphericity; grain to matrix supported; variable amts of ash/clay in matrix; redbrown grains; this sand produced a minor gas show of 80 units. 13275' Coal Black; hard; occasionally brittle; blocky to platy cuttings; blocky to planar fracture; resinous to slightly vitreous luster; smooth to rough texture; some visible bleeding gas. ( [J EPOCH 55 ." . Forest Oil Corporation Redoubt Unit #5 ( 13305' Tuffaceous Siltstone Medium dark gray; firm to soft; massive cuttings; abundant PDC markings; irregular fracture; dull earthy luster; silty texture; grading to silty claystone; minor amts of carbonaceous material. 13340' Tuffaceous Claystone Medium dark gray; soft to firm; massive cuttings; abundant PDC markings; irregular fracture; clayey to silty texture; dull earthy luster; minor amounts of ash; variable silt content; minor amounts of carbonaceous material; grades to argillaceous siltstone. 13400' Coal and Carbonaceous Shale Black to grayish black with brownish black secondary hue; brittle to crunchy tenacity; planar to conchoidal fracture; massive to flaky cuttings habit; greasy to resinous luster; matte to silty texture; thin bedding structure; subbituminous to carbonaceous shale grading; slight visible gas bleeding. 13450' Tuffaceous Claystone Medium gray to brownish gray; crumbly to crunchy tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; dull to waxy luster; clayey texture; massive bedding structure. ( 13485' Tuffaceous Siltstone Medium dark gray to medium gray; soft to crumbly; massive cuttings w/PDC markings; irregular fracture; dull to slightly waxy luster; silty to clayey texture; occasionally thin very fine sand interbeds; thin carbonaceous laminations; massive. 13525' Tuffaceous Claystone Medium dark gray to medium gray; soft; massive with PDC tubular to ridge cuttings; dull earthy luster; silty to clayey texture; very fine carbonaceous mat; variable amts of silts; 10% loose sand. 13560' Carbonaceous Shale Dark brown to dark gray; very hard; platy to massive; irregular fracture; dull earthy luster; rough texture; occasionally coaly fragments (plant stems); overlies thin coal. 13590' Coal Black; mod hard; blocky cuttings habit; blocky to planar fracture; vitreous luster; smooth texture; thinly bedded; interbedded with carbonaceous shale; some visible gas bleeding. 13620' Sandstone Offwhite to light gray; friable; grain size ranges from lower medium grained to fine grained; moderate to well sorted; angular to subangular; moderate sphericity; matrix supported; matrix material ranges from silt to ash and clay; high amounts of black carbonaceous material interbedded; no visible oil indicators present. ( ~ EPOCH 56 Forest Oil Corporation Redoubt Unit #5 ( 13670' Tuffaceous Siltstone Medium gray to medium dark gray with brownish gray secondary hue; crunchy to crumbly occasionally brittle tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; dull to earthy luster; silty to gritty texture; massive bedding structure. 13715' Tuffaceous Claystone Medium dark gray to brownish gray; crunchy to crumbly tenacity; irregular to earthy fracture; scaly to PDC grooved cuttings habit; dull to earthy luster; clayey texture; massive bedding structure; silt and sands interbedded. 13770' Tuffaceous Siltstone and Claystone Dark gray; mod to very hard; platy to massive cuttings; irregular fracture; PDC markings; silty to clayey texture; moderately to very carbonaceous; dull earthy luster; interbedded with carbonaceous shale. 13830' Tuffaceous Siltstone Medium gray to medium dark gray; crumbly to crunchy tenacity; irregular fracture; massive to PDC grooved cuttings; dull to earthy luster; silty to gritty texture; massive bedding structure. ( 13865' Coal and Carbonaceous Shale Black to very dusky red; crunchy to crumbly tenacity; planar to irregular fracture; wedgelike to massive occasionally PDC grooved cuttings habit; resinous to waxy luster; matte to polished texture; thin bedding structure; lignite to carbonaceous shale grading; slight visible gas bleeding. 13910' Sandstone Offwhite to light gray; soft clast size ranges from lower medium to fine grained; angular to subrounded; predominantly matrix supported with ash/silt matrix; mod sorted; mod sphericity; 10% gray to black chert; <10% black metamorphic/lithic fragments; trace amounts of greenstone; occasionally moderately carbonaceous w/black carbonaceous laminations; no oil indicators. 13965' Tuffaceous Claystone Medium gray to grayish brown (oil base mud coating); firm massive cuttings; abundant PDC markings; irregular fracture; dull earthy luster; silty texture; occasionally thin very hard silic siltstone; variable amts of silt and carbonaceous material; good lithology change at 14008'; becoming tuffaceous sandstone with abundant white ash in samples. ( 14020' Tuffaceous Sandstone and Tuff Offwhite; soft to crumbly; friable; clast size ranges from lower medium to silt size grains; mod sorted; angular to subangular; abundant white ash in samples; abundant loose quartz grains; ash matrix supported; grading to ash; trace amts of light green grains; trace chert; thin carbonaceous laminations and coaly particles; no oil indicators. [:I EPOCH 57 Forest Oil Corporation Redoubt Unit #5 { ( 14075' Sandstone Predominantly loose grains; white to light gray; friable; clast size from upper medium to fine grained; angular to subrounded; mod well sorted; ash/silt matrix; grain to matrix supported; trace greenstone; trace carbonaceous material; very slight calc; no visible oil indicators; this interval produced a good gas show. 14125' Devitrified Ash Dominantly found as a matrix material; very pale orange to off white with pinkish gray secondary hue; pasty consistency; very soft to soft tenacity; irregular fracture; massive to PDC grooved cuttings habit; waxy to greasy luster; silty to crystal'n texture; massive bedding structure. 14185' Coal and Carbonaceous Shale Black to dark reddish brown with moderate brown secondary hue; crumbly to crunchy tenacity; planar to irregular fracture; flaky to wedgelike occasionally PDC grooved cuttings habit; resinous to polished luster; matte to silty texture; thin bedding structure; lignite to carbonaceous clay grading. ( 14235' Tuffaceous Claystone Medium gray brown (oil base mud); firm to occasionally mod hard in silty specimens; massive to slightly platy; irregular fracture; silty to clayey texture; dull earthy luster; variable amts of silt; grading to siltstone; very fine carbonaceous material; occasionally thin coaly laminations; non to very slightly calcareous. 14285' Tuffaceous Sandstone Offwhite to light gray; occasionally salt & pepper appearance; soft to crumbly; clast size from lower medium to fine grained; reworked ash; angular to subrounded; low to mod sphericity; <10%) lithic fragments; trace amts of greenstone and chert; white ash/silt matrix; predominantly matrix supported; grading to tuff; minor amts of carbonaceous material as laminations or particles; becoming coaly at base. 14350' Coal and Carbonaceous Shale Black; mod hard to brittle; blocky fracture; blocky to platy cuttings; abundant PDC markings; resinous to dull earthy luster; rough to smooth texture; grading to carbonaceous shale; interbedded w/sand. 14385' Sandstone Abundant loose grains; light graywhite to white; friable to crumbly; clast size from lower medium to very fine grained; mod sorted; grain to matrix supported in tuffaceous pieces; abundant lithic fragments from greenstone to gray chert; silUclay matrix; some slightly siliceous examples; angular to subrounded grains; mod sphericity; no increase in c-5's over this interval; no oil indicators. ( (;I EPOCH 58 8 Forest Oil Corporation Redoubt Unit #5 14445' Sandstone Light gray to offwhite; crumbly; clast size f/rare broken coarse to fine grained; angular to subrounded; poorly to mod sorted; predominantly matrix supported; abundant ash matrix material in samples; ash/ clay/silt matrix; overall decrease in medium grains; increase in ash/silt component; no increase in c-S's- no oil indicators. 14500' Devitrified Ash Very light gray to off white with pinkish gray secondary hue; pasty to mushy consistency; soft to crumbly tenacity; irregular fracture; massive to PDC grooved cuttings habit; waxy to greasy luster; silty texture; massive bedding structure. 14555' Conglomeratic Sand Very pale orange to very light gray with light brownish gray secondary hue; clast sizes range from upper fine to bit fractured pebble; poorly to moderately sorted; angular to subrounded; moderate to low sphericity; friable to unconsolidated; slight calcareous cement; matrix to grain supported; ash and silt matrix material; black carbonaceous material interbedded; no visible oil indicators. ( 14615' Sandstone and Conglomeratic Sandstone Light gray; light brown gray (oil base mud); clast size from broken pebble to fine grained; angular to subrounded; low to mod sphericity; predominantly clay/silt matrix; some preserved grain supported pieces with siliceous cement; abundant greenstone; abundant lithic fragments; no oil indicators. 1466S' Carbonaceous Shale Black to dark gray; some brownish black; mod hard; slightly platy cuttings; splintery to irregular fracture; dull earthy luster; smooth to silty texture; interbedded w/ coal& siltstone. 14695' Coal Black; brittle in part; blocky to flaky cuttings; planar fracture; mod vitreous luster; smooth texture; some visible bleeding gas. 14720' Tuffaceous Siltstone Medium dark gray to medium gray; mod hard to very hard; massive to slightly platy cuttings; abundant PDC markings; irregular fracture; silty to clayey texture; dull earthy luster; trace amts of carbonaceous material interbedded with thin coaly intervals. 14780' Coal and Carbonaceous Shale Black to occasionally brownish black in shale; mod hard; platy to flaky cuttings; splintery to planar fracture; slightly vitreous to dull earthy luster in shale; smooth to matte texture; some thin siltstone interbeds. ( [j EPOCH 59 . . Forest Oil Corporation Redoubt Unit #5 14795' Tuffaceous Siltstone Medium gray to light brownish gray with medium dark gray secondary hue; crumbly to soft tenacity; irregular to earthy fracture; PDC grooved to massive cuttings habit; waxy to dull luster; silty to gritty texture; massive bedding structure; thin carbonaceous lamination interbedded. 14840' Sand Light brownish gray to light gray with off white secondary hue; clast sizes range from lower medium to upper coarse with occasional bit fractured pebble; moderately to poorly sorted; subangular to subrounded; moderate to low sphericity; unconsolidated; matrix supported; high amounts of carbonaceous material; no visible oil indicators. 14895' Tuffaceous Siltstone Light gray to light brownish gray; soft to crumbly tenacity; irregular fracture; massive to PDC grooved cuttings habit; waxy to greasy occasionally dull luster; silty to gritty texture; massive bedding structure with ash and sands interbedded 14935' Sandstone Predominantly loose grains; some light gray preserved specimens; mod hard; clast size from lower medium to fine grained; mod well sorted; low to mod sphericity; angular to subangular; preserved specimens exhibit calc and siliceous cement; matrix supported; occasionally very carbonaceous; no visible oil indicators. ( 14985' Tuffaceous Siltstone Medium dark gray; firm to slightly hard; massive to slightly platy cuttings; irregular fracture; silty texture; occasionally slightly waxy luster; predominantly earthy; variable amts of sand; some thin clay to carbonaceous shale laminations; slightly carbonaceous; interbedded with thin carbonaceous shale. 15030' Sandstone Light gray; soft; clast size is dominantly fine grained w/abundant loose med grains; angular to subangutar; mod wett sorted; tuffaceous matrix; predominantly matrix; some black carbonaceous striations; tuffaceous sandstone grading to tuff; no oil indicators. 15085' Tuffaceous Siltstone Medium gray to medium light gray with light brownish gray secondary hue; crumbly to crunchy tenacity; irregular to earthy fracture; massive to PDC grooved cuttings habit; silty to gritty texture; massive bedding structure. 15125' Sand Light gray to pinkish gray; upper medium to lower fine with occasional bit fractured pebble; fair to poorly sorted; subangular to subrounded; low to moderate sphericity; unconsolidated to friable; grain supported; silt and ash matrix material; abundant carbonaceous material; no visible oil indictors. ( [:I EPOCH 60 Forest Oil Corporation Redoubt Unit #5 (' 15175' Sandstone Light gray to offwhite; slightly friable; upper medium to lower fine grained; mod well sorted; angular to subrounded; grain to matrix supported ash/silt matrix; ash matrix material; trace greenstone; no oil indicators. 15240' Coal and Carbonaceous Shale Black; platy to flaky cuttings; mod hard; planar fracture; dull earthy in shale to resinous in coal; some brown black carbonaceous shale; some visible bleeding gas. 15285' Tuffaceous Claystone Medium gray to brownish gray; crumbly to crunchy; irregular fracture; PDC grooved cuttings; waxy to dull luster; clayey texture; massive bedding structure. 15330'Sand Very light gray; clast size range from medium grain to upper very fine; subrounded to subangular; moderate sphericity; poor occasionally moderate sorting; impact to chipped texture; submature; non to very weak siliceous cement; non increasing to slight clay and silt matrix with increasing silt; composed of 90% quartz, fair to good porosity and permeability; no visible oil indicators, oil base mud. ( 15375' Sandstone Loose grains; rare light gray preserved specimens; clast size range from upper medium to very fine grained; moderate to well sorted; angular to subangular; rare siliceous cement to clay and silt matrix; minor amounts of chert; estimated good porosity and permeability; exhibited good oil show from appearance of c-5's and good increase in c- 4's from 15392' to current depth of 15425'. 15440' Conglomeratic Sandstone and Sandstone Light to medium brown- heavily oil stained; clast size from pebble to fine grained; dominantly medium grained; angular to subangular; occasionally subround; very friable; poor to mod to well sorted; silic cement minor kaolinite fill in some non productive; abundant brown mica, trace green mica; 200k black lithics fragments; excellent visible porosity and permeability even brown oil stain; exhibits gold to bright yellow oil flour; oil stain intervals on core marked black (over 500/0 of the core exhibited good oil staining). 15510' Sandstone Predominantly loose grains; light gray; slightly friable; clast size from upper medium to fine grained; mod w sorted; angular to subangular; grain supported; siliceous to some clay fill; trace mica; minor amts of black lithic fragments; slide interval-poor sample quality; no oil indicators. [:I3POCH 61 Forest Oil Corporation Redoubt Unit #5 15555' Conglomeratic Sand and Sand Light gray; clast size very coarse grained to very fine grain; angular bit impact coarse grained to subround very fine pr occasionally mod sort; chip to impact texture; sub mature; n-slightly silic cement; non to slight ash/silt loosely attached pore fill matrix; dominantly grain support; composed of 70% quartz, 20% chert, 10% metamorphic ( argillite), feldspar fair porosity and permeability; oil mud. 15600' Carbonaceous Shale and Coal First coal in hemlock 15624'-below massive conglomerate equivalent to 14642'md-ru#5: 14622'md ru#2; 16060'md ru#3; black to dark brown in carbonaceous shale; firm to slightly hard; platy cuttings; planar fracture; slightly vitreous luster; smooth texture; some plant imprints; overlying thin beds of sandy claystone and siltstone. 15650' Tuffaceous Siltstone Medium light gray to brownish gray; poorly indurated; crumbly occasionally crunchy; PDC bit grooved fracture and habit; earthy luster; silty to ashy texture; thick beds of uniform silt; generally composed of 60°,1> silt, 30% ash, 10% clay; scattered coarse/pebble sand fragments. ( 15690' Conglomerate Medium gray to light gray clast size ranges from pebble to coarse; angular to subangular bit impacted fragments moderate to poor sphericity; moderate to poor sorting; predominantly polished w/ chip texture submature; slight to moderate fine to medium grain matrix sand; dominantly grain supp slight silUash matrix fill; fair porosity and permeability; oil base mud. 15740' Sandstone Light gray; crumbly; dominantly medium grained; some loose broken coarse grains; prob conglomeratic in part; mod sorted; angular to subangular; mod to low sphericity; predominantly siliceous with some clay/silt fill; trace amts of greenstone and loose black lithic fragments; trace amts of chert; oil indicators masked by oil base mud. Core #2 15819-15822' Conglomeratic Sand Med gray; clast size has two factions pebble to very coarse grain with medium grain matrix sands; coarse grained subround, mod sphericity, pr sort, polish-impact texture; matrix sand subangular; moderately sorted; chip to impact texture, slight to moderate siliceous cement composed of predominantly quartz with minor chert, metamorphic, greenstone; grading to conglomerate at 15825'; predominantly weak cement pebbles to very coarse grain; dominantly grain support; core 15826-15840' based on sample caught when coring/15826-840 core was not recovered; oil base mud/no shows. ( ~ EPOCH 62 Forest Oil Corporation Redoubt Unit #5 (: 15865' Conglomerate Sand and Conglomerate Medium light gray to light brownish gray; clast size ranges pebble and coarse grained upper to coarse lower with med to fine grain matrix sands; angular to subangular; low to mod sphericity; polish and chip texture; silic cement; dominantly grain support composed of 80% quartz, 10% chert, 10°1'0 metamorphic, greenstone, feldspar various iithics fragments; becoming dense; app as loose grains wI matrix sands; no visible oil indicators present, oil base mud. 15935' Conglomeratic Sand Light brownish gray to medium light gray with pinkish gray secondary hue; clast sizes range from lower medium to very coarse and bit fractured pebble; poorly to very poorly sorted; angular to subangular with high amounts of bit fractured grains; low sphericity; unconsolidated; grain supported; minor amounts of black carbonaceous material interbedded; no visible oil indicators present, oil mud. 15995' Conglomerate and Conglomerate Sand Light brownish gray; clast size from pebble to fine lower; subangular coarse grained to subround medium to fine grain; very poorly sorted; chip to impact texture; submature; silic cement; slightly to mod silUash matrix; dominantly grain support wI fine grain matrix sands; composed of predominantly quartz wI secondary chert and various lithics; scattered silic dark gray-black carbonaceous fragments; fair to poor estimate porosity and permeability; oil base mud. ( 16050' Tuffaceous Siltstone Brownish gray to medium dark gray with light brownish gray secondary hue; crunchy to crumbly occasionally brittle tenacity; irregular to earthy fracture; massive cuttings habit; dull to earthy occasionally waxy luster; silty occasionally clayey texture; massive bedding structure. 16095' Conglomeratic Sand Light brownish gray to light brown with medium light gray secondary hue; clast sizes range from upper fine to upper coarse; poor t very poorly sorted; angular to subangular with bit fractured grains; low to mod sphericity; unconsolidated; grain supp; oil base mud. 16135' Coal and Carbonaceous Shale Black to brownish black; firm; earthy-resinous luster; matte texture; irregular-hackly fracture; composed of lignitic to subbituminous grad to carbonaceous clay. ,( [1 E?OCH 63 8' Forest Oil Corporation Redoubt Unit #5 ( 16153' to 16207' Conglomeratic Sandstone - Core #3 Medium light gray to dark gray to light brownish gray; clasts in 2 sizes of pebble with medium grained matrix sand; some quartz overgrowth; dominantly grain supported; good porosity from 16174' to 16183' with no to very slight hydrocarbon odor; spotty light brown oil stain at 16181' t016183'; very weak to moderate yellow spotty sample fluorescence at 16168' ,16180' -16183',16186,16192' and at 16201'; very weak to moderately fluorescence cut; slow to moderate increasing to cloudy to milky cut; faint straw to straw residual cut; fair shows. 16207' Conglomeratic Sandstone/Conglomerate Light brownish gray to medium gray with light gray secondary hue; clast sizes range from lower fine to upper coarse with bit fractured pebbles; very poorly to poorly sorted; subangular to angular with high amounts of bit impacted grains; low to moderate sphericity; grain supported; siliceous cement; some black carbonaceous material; no visible oil indicators with oil base mud. 16270' Conglomeratic Sandstone Light brownish gray to medium light gray; clast size ranges from upper fine to lower coarse with occasional bit fractured pebbles; poorly to very poorly sorted; subangular to angular with bit impacted grains present; low to moderate sphericity; soft to easily friable; siliceous cement; grain supported; no visible oil indicators with oil base mud. ( 16340' Conglomeratic Sandstone/Conglomerate Light brownish gray with occasional very pale orange; clast size from pebble to lower coarse with medium to fine matrix sands; angular to subangular bit impacted fragments; poor to moderate sphericity; poorly sorted; siliceous cement; trace clay matrix; dominantly grain supported; composed of 90% quartz, 10% chert,metamorphic,feldspar,greenstone, and various lithic fragments; fair estimated porosity and permeability. 16390' Sandstone Light brownish gray to medium light gray; clast size ranges from lower medium to upper coarse with bit fractured pebbles; very poorly sorted; subangular to angular; siliceous cement; grain supported; no visible oil indicators with oil base mud. 16440' Conglomeratic Sandstone Predominantly loose grains; clast size from broken pebble to fine grained; some offwhite to light gray preserved specimens; angular to subangular; low to moderate sphericity; poorly sorted; some si\iceous cement; 20% lithic fragments from greenstone to chert; grain supported; no visible oil indicators in oil base mud; trace amounts of medium. gray to dark gray siltstone. \( [:I. EPOCH 64 Forest Oil Corporation Redoubt Unit #5 (' 16510' Conglomeratic Sandstone Predominantly loose grains; rare light gray siliceous specimens; clast size ranges from broken pebble to fine grained; poorly sorted; low to moderate sphericity; angular to subrounded; abundant greenstone and dark gray chert; appearance of minor amounts of siltstone and claystone below 16630'. 16560' Tuffaceous Claystone Medium dark gray to brownish gray with dark gray secondary hue; crumbly to crunchy tenacity; irregular fracture; PDC grooved to massive cuttings habit; waxy to greasy luster; clayey to matte texture; thin bedding structure. 16600' Carbonaceous Shale Brownish black to black; crumbly to crunchy tenacity; planar to irregular fracture; massive to PDC grooved cuttings habit; waxy to greasy luster; clayey to matte texture; thin bedding structure. 16640' Sandstone Light brownish gray to medium light gray with very pale orange secondary hue; clast sizes ranges from lower fine to upper medium with occasional bit fractured pebbles; fair to poorly sorted; subangular to subrounded; moderate sphericity; easily friable to abundant loose grains; silt and ash matrix; black carbonaceous material; oil indicators masked by oil base mud. ( 16690' Carbonaceous Shale/Coal Dark reddish brown to black with very dusky red secondary hue; crumbly to crunchy tenacity; planar fracture; PDC grooved to flakey cuttings habit; greasy to waxy luster; clayey to matte texture; thin bedding structure. 16730' Sandstone Light gray; abundant loose grains; slightly' hard; fine to very fine grained; angular to subangular; moderately well sorted; siliceous cement; moderate amounts of carbonaceous material; moderate amounts of silt; grading to siltstone; trace amounts of greenstone; oil indicators masked by oil base mud. 16810' Claystone Medium gray to medium dark gray; some grayish brown ( oil base mud); firm; platy to massive cuttings; irregular fracture; smooth to slightly silty texture; very fine carbonaceous material; dull earthy texture; very slightly silty; very fine mica; abundant loose sand cavings from uphole. 16860' Sandstone Light brownish gray to medium light gray with very pale orange secondary hue; clast sizes range from upper fine to upper medium; fair sorting; subangular to subrounded; moderate to low sphericity; easily friable; silt matrix supported; oil indicators masked by oil base mud. ( ~. EPOCH 65 ( ( ( 8 Forest Oil Corporation Redoubt Unit #5 16880' Tuffaceous Siltstone Light brownish gray to light gray with very pale orange secondary hue; soft to crumbly occasionally crunchy tenacity; irregular fracture; PDC grooved to massive cuttings habit; greasy to waxy luster; silty to gritty texture; massive bedding structure; grades from fine grained sandstone to siltstone. 16930' Carbonaceous Shale/Coal Very dusky red to black with dark reddish brown secondary hue; crumbly to crunchy tenacity; planar to irregular fracture; PDC grooved to platy cuttings habit; waxy to greasy luster; clayey to matte texture; thin bedding structure; carbonaceous clay grading to lignite. [:I. EPOCH 66 Forest Oil Corporation Redoubt Unit #5 (( SURVEY INFORMATION Measured Depth TVD Inclination Azimuth Coordinates Dog Leg Feet Feet De~rees De2rees N(+) S(-) E(+) W(-) De~rees/1 00' 144.00 144.00 0.25 42.00 0.2 0.2 0.17 174.00 174.00 0.10 356.00 0.3 0.3 0.65 205.00 205.00 0.25 232.00 0.3 0.2 1.02 235.00 235.00 0.90 206.00 0.0 0.0 2.28 295.00 294.96 2.75 198.00 -1.8 -0.6 3.11 384.00 383.74 5.30 212.00 -7.4 -3.5 3.05 473.00 472.16 7.75 211.68 -16.1 -8.9 2.75 563.00 561.11 9.70 211.50 -27.8 -16.1 2.17 678.00 674.46 12.40 211.37 -46.8 -27.7 2.34 767.90 761.78 12.38 211.19 -63.3 -37.7 0.50 856.10 848.01 11.90 207.06 -79.6 -46.8 1.13 944.00 934.05 11.79 196.04 -96.4 -53.4 2.57 1036.70 1024.79 11.91 183.38 -115.1 -56.6 2.80 1130.60 1116.40 13.58 166.78 -135.6 -54.7 4.27 1224.00 1206.63 16.46 152.09 -158.1 -45.9 5.09 1320.20 1298.76 17.03 146.26 -182.0 -31.7 1.84 ( 1414.30 1388.29 18.84 139.41 -205.1 -14.1 2.95 1509.50 1477.60 21.67 138.71 -230.0 7.6 2.98 1604.80 1565.31 24.35 137.24 -257.8 32.6 2.88 1701.10 1652.23 26.63 135.98 -287.9 61.2 2.43 1797.30 1737.50 28.50 137.41 -320.4 91.8 2.06 1891.70 1819.30 31.38 136.54 -354.9 124.0 3.09 1986.10 1899.40 31.19 137.09 -390.7 157.5 0.40 2080.90 1981.00 30.15 137.78 -426.3 190.3 1.16 2173.80 2062.00 28.37 138.93 -460.2 220.4 2.01 2268.50 2145.50 28.03 141.81 -494.7 249.0 1.48 2359.50 2225.10 29.85 139.13 -528.6 277.0 2.46 2452.20 2304.60 31.98 139.27 -564.6 308.] 2.30 2546.20 2385.30 29.88 139.11 -601.2 339.7 2.24 2642.40 2468.78 29.67 136.15 -636.5 371.8 1.55 2736.90 2551.45 28.27 134.49 -669.0 404.0 1.71 2829.60 2632.77 29.11 132.89 -699.7 436.2 1.23 2924.20 2715.03 29.14 135.31 -732.3 469.8 1.25 3018.90 2796.66 31. 76 135.26 -766.4 503.5 2.77 3111.10 2874.33 33.45 134.03 -801.3 538.9 1.97 3161.38 2916.00 34.70 133.98 -820.9 559.1 2.49 3251.66 2990.40 34.19 133.88 -856.3 595.9 0.57 ( ~ EPOCH 67 Forest Oil Corporation Redoubt Unit #5 ( Measured Depth TVD Inclination Azimuth Coordinates Dog Leg Feet Feet Degrees Degrees N(+) S(-) E(+) W(-) Degrees/1 00' 3346.32 3068.80 34.14 133.79 -893.1 634.3 0.08 3441.29 3147.40 34.07 133.39 -929.9 672.8 0.25 3537.03 3227.20 33.06 137.67 -967.6 709.9 2.69 3633.95 3308.30 33.28 137.59 -1006.8 745.6 0.23 3730.86 3389.80 32.31 138.49 -1045.8 780.7 1.12 3826.91 3471.00 32.11 138.40 -1084.1 814.7 0.21 3921. 15 3550.70 32.43 138.63 -1121.8 848.0 0.36 4015.73 3630.80 31.84 138.41 -1159.5 881.4 0.64 4110.36 3711.30 31.68 138.08 -1196.6 914.5 0.25 4205.88 3792.50 31.82 138.19 -1234.1 948.1 0.16 4301.11 3873.50 31.70 138.21 -1271.4 981.5 0.13 4397.45 3955.30 31.92 138.25 -1309.3 1015.3 0.23 4492.28 4035.90 31.82 138.47 -1346.7 1048.6 0.16 4587.62 4116.80 32.09 138.64 -1384.6 1082.0 0.30 4676.47 4192.50 30.99 137.93 -1419.3 1112.9 1.31 4771.69 4274.20 30.69 138.67 -1455.7 1145.4 0.51 4863.24 4352.80 31.01 138.65 -]490.9 1176.4 0.35 4958.04 4433.90 31.49 139.10 -1528.0 1208.7 0.56 5052.76 4514.40 32.01 138.45 -1565.5 1241. 6 0.66 ( 5148.44 4595.70 31.77 138.40 -1603.3 1275.1 0.25 5243.85 4676.90 31.39 136.62 -1640.1 1308.9 1.06 5340.01 4758.80 32.01 136.98 -1677.0 1343.4 0.67 5434.62 4838.80 32.54 136.94 -1713.9 1377.9 0.56 5527.73 4917.80 31.16 137.70 -1750.0 1411.2 1.54 5624.39 5000.90 30.25 137.67 -1786.5 1444.5 0.94 5715.63 5079.80 30.18 137.81 -]820.5 1475.3 0.11 5809.64 5161. 00 30.27 138.15 -1855.6 1507.0 0.21 5901.02 5239.90 30.44 138.19 -1890.1 1537.8 0.19 5996.86 5322.50 30.54 137.81 -1926.2 1570.4 0.23 6091. 99 5404.30 30.69 136.70 -1961. 8 1603.2 0.61 6188.56 5487.30 30.85 137.00 -1997.8 1637.0 0.23 6282.32 5567.60 31.22 136.82 -2033.1 1670. 1 0.41 6377.85 5646.69 31.42 136.91 -2072.5 1706.7 0.11 6470.78 5725.92 31.61 137.13 -2108.0 1739.9 0.24 6564.32 5808.]0 31.93 137.89 -2141.1 1770.3 0.55 6672.76 5900.50 31.20 138.15 -2183.3 1808.3 0.68 6767.21 5981.40 30.81 138.42 -2219.6 1840.6 0.44 6862.32 6063.20 30.66 137.94 -2255.8 1873.0 0.30 6957.78 6145.50 30.33 137.56 -2291. 7 1905.6 0.40 ( ~. EPOCH 68 Forest Oil Corporation Redoubt Unit #5 ( Measured Depth TVD Inclination Azimuth Coordinates Dog Leg Feet Feet Degrees Degrees N(+) S(-) E(+) W(-) Degrees/! 00' 7053.72 6228.40 29.96 137.29 -2327.2 1938.2 0.41 7146.62 6309.10 29.54 138.01 -2361.2 1969.3 0.59 7238.16 6388.50 30.15 136.57 -2394.7 2000.2 1.03 7331.26 6468.90 30.45 137.41 -2429.1 2032.2 0.56 7423.80 6548.50 30.74 138.82 -2464.1 2063.6 0.84 7519.15 6630.50 30.63 138.32 -2500.6 2095.8 0.29 7614.42 6712.50 30.51 140.3 6 -2537.4 2127.4 1.10 7707.36 6791.80 32.45 139.11 -2574.4 2158.8 2.20 7803.49 6873.00 32.36 137.35 -2612.8 2193. 1 0.98 7896.07 6951.00 32.53 136.54 -2649.2 2227.1 0.55 7991. 75 7031. 70 32.44 134.74 -2686.0 2263.1 1.04 8084.69 7110.00 32.63 133.86 -2720.9 2298.8 0.55 8180.72 7191.00 32.36 133.95 -2756.7 2336.0 0.30 8278.13 7273.50 32.03 133.90 -2792.7 2373.4 0.34 8371.41 7352.60 31.66 ]33.30 -2826.7 2409. I 0.43 8465.58 7432.50 32.33 134.93 -2861.4 2445.0 1.09 8556.76 7509.70 31.83 133.80 -2895.3 2479.6 0.86 8652.36 7591.20 31.18 133.21 -2929.7 2515.8 0.75 8747.19 7672.60 30.66 133.20 -2963.1 2551.3 0.55 ( 8839.57 7752.20 30.25 135.12 -2995.7 2584.9 1.14 8938.34 7837.60 30.16 136.45 -3031.3 2619.6 0.68 9031. 76 7918.60 29.43 136.23 -3064.9 2651.6 0.79 9123.05 7998.30 29.03 135.85 -3097.0 2682.6 0.49 9214.94 8079.00 28.21 135.37 -3128.5 2713.3 0.90 9310.23 8162.60 28.99 134.68 -3160.8 2745.5 0.93 9404.03 8244.40 29.62 135.36 -3193.3 2777.9 0.76 9498.59 8326.50 30.01 136.09 -3226.9 2810.7 0.56 9592.49 8407.30 31.16 136.18 -3261.4 2843.8 1.23 9688.68 8489.60 31.16 136.06 -3297.3 2878.3 0.06 9780.35 8568.10 31.14 135.48 -3331.2 2911. 4 0.33 9876.58 8650.50 3].05 136.64 -3367.0 2945.9 0.63 9970.88 8731.30 30.93 136.04 -3402.2 2979.4 0.35 10065.13 8812.56 30.70 136.95 -3437.2 3012.7 0.55 10158.75 8892.69 31.2] ] 36.64 -3472.1 3045.4 0.57 10252.49 8973.31 30.15 136.46 -3506.8 3078.3 1.13 10347.14 9055.30 29.59 ]36.91 -3541.2 3110.8 0.65 10441.56 9137.40 29.54 136.99 -3575.3 3142.6 0.07 10534.03 9218.00 29.29 136.96 -3608.5 3 1 73 .6 0.27 10628.08 9299.90 29.47 136.74 -3642.] 3205.1 0.22 ( / U EPOCH 69 Forest Oil Corporation Redoubt Unit #5 ( Measured Depth TVD Inclination Azimuth Coordinates Dog Leg Feet Feet Degrees Degrees N(+) S(-) E(+) W(-) Degrees/IOO' 10722.71 9382.30 29.45 136.40 -3675.9 3237. 1 0.18 10820.02 9467.42 29.26 136.74 -3710.3 3269.6 0.26 10913.90 9549.67 28.37 137.08 -3743.3 3300.5 0.96 11011.09 9635.49 27.63 137.09 -3776.7 3331.6 0.77 11105.31 9718.91 27.76 137.64 -3808.9 3361.3 0.31 11198.28 9801.04 28.13 137.00 -3840.8 3391.0 0.41 11234.33 9832.81 28.31 137.06 -3853.2 3402.5 0.54 11289.94 9881.61 28.96 137.75 -3872.9 3420.6 1.30 11384.39 9964.16 29.19 137.71 -3906.8 3451.4 0.25 11478.60 10046.30 28.84 138.14 -3941.1 3482.4 0.43 11509.93 10073.70 28.92 139.05 -3952.4 3492.4 1.43 11542.19 10101.90 29.21 138.50 -3964.2 3502.8 1.22 11573.70 10129.40 29.06 137.60 -3975.6 3513.0 1.47 11607.03 10158.57 29.00 138.58 -3987.7 3523.8 1.44 11669.19 10212.90 29.53 138.79 -4010.4 3543.8 0.29 11718.97 10256.45 28.76 139.27 -4028.6 3559.6 0.91 11761.60 10293.98 29.39 138.50 -4043.8 3572.8 1.72 11791.20 10319.70 29.87 137.12 -4054.7 3582.7 2.80 11856.30 10375.96 30.55 139.62 -4079.2 3604.4 2.19 ( 11904.98 1041 7.41 31.48 139.38 -4098.5 3621.0 1.91 11950.09 10455.70 32.37 139.47 -4116.6 3636.5 1.98 12043.32 10533.80 33.86 140.19 -4156.0 3668.8 1.65 12075.06 10560.20 33.44 141.11 -4169.6 3680.0 2.08 12099.63 10580.80 33.30 141.63 -4180.2 3688.4 1.30 12135.88 10611. 00 33.43 142.43 -4195.9 3700.7 1.27 12168.33 10638.00 34.05 140.52 -4210.0 37.11.9 3.79 12199.72 10664.00 34.47 140.71 -4223.7 3723. 1 1.38 12230.45 10689.30 34.44 139.86 -4237.0 3734.2 1.57 12296.17 10743.40 34.69 137.62 -4265.1 3758.8 1.97 12325.26 10767.30 34.78 139.71 -4277.5 3769.8 4.11 12374.07 10807.40 35.09 140.23 -4298.9 3787.8 0.88 12420.47 10845.10 36.12 138.89 -4319.5 3805.3 2.78 12470.32 10885.19 36.75 139.14 -4341.8 3824.7 1.30 12514.96 10921.07 36.25 137.89 -4361.7 3842.2 2.01 12561.36 10958.40 36.44 138.98 -4382.3 3860.5 1.45 12607.54 10995.60 36.29 138.63 -4402.9 3878.6 0.55 12641.70 11023.20 35.96 138.64 -4418.0 3891.9 0.97 12703.29 11073.10 35.91 138.07 -4445.0 3915.9 0.55 12750.47 11111.20 36.40 138.29 -4465.7 3934.4 1.07 ,( [J EPOCH 70 Forest Oil Corporation Redoubt Unit #5 ( Measured Depth TVD Inclination Azimuth Coordinates Dog Leg Feet Feet Degrees Degrees N(+) S(-) E(+) W(-) Degrees/! 00' 12798.98 11150.20 36.57 138.91 -4487.4 3953.5 0.84 12892.89 11225.80 36.12 138.83 -4529.3 3990. I 0.48 12927.59 11253.90 36.07 138.22 -4544.6 4003.7 1.05 12988.73 11303.30 36.00 139.21 -4571.6 4027.4 0.96 13084.82 11381.28 36.09 139.53 -4614.2 4063.9 0.22 13177.55 11456.13 36.26 139.04 -4655.7 4099.6 0.36 13276.23 11535.93 35.80 139.30 -4699.6 4137.5 0.49 13368.55 11610.90 35.59 140.30 -4740.8 4172.3 0.67 13463.31 11688.57 34.30 139.68 -4782.4 4207.2 1.42 13558.25 11767.12 33.56 140.56 -4823.3 4241.4 1.15 13651.54 11844.99 32.59 139.31 -4862.6 4274.5 1.26 13747.00 11925.90 31.59 139.21 -4901.0 4307.6 1.06 13845.20 12010.30 29.79 139.52 -4939.1 4340.3 1.84 13870.95 12032.70 29.64 139.79 -4948.8 4348.5 0.78 13927.16 12081.50 28.66 139.63 -4970.0 4366.5 1.75 14000.00 12146.20 27.98 138.35 -4995.4 4388.5 14020.17 12164.02 27.94 138.23 -5002.4 4394.8 0.34 14054.13 12194.00 28.10 138.23 -5014.3 4405.5 0.47 14088.61 12224.38 28.29 138.74 -5026.5 4416.3 0.87 ( 14143.50 12272.56 28.98 139.33 -5046.4 4433.5 1.37 14178.18 12302.84 29.39 139.02 -5059.2 4444.6 1.25 14207.17 12328.06 29.70 138.89 -5070.0 4454.0 1.09 14305.08 12412.10 30.84 140.58 -5108.3 4486.5 1.46 14398.26 12491.70 31. 74 140.16 -5145.6 4517.4 0.99 14440.08 12527.20 31.82 141.17 -5162.6 4531.3 1.29 14491. 79 12571.10 32.31 140.92 -5183.9 4548.6 0.98 14542.18 12614.05 32.93 141.48 -5204.5 4564.9 1.37 14599.11 12661.66 33.56 140.15 -5228.6 4584.7 1.69 14649.58 12703.78 33.31 139.95 -5250.0 4602.6 0.54 14715.88 12759.49 32.37 138.88 -5277.3 4625.9 1.67 14782.93 12824.50 30.92 137.93 -5308.2 4653.4 1.99 14901.81 12918.00 30.77 137.45 -5349.4 4691. 0 0.48 15002.67 13004.80 30.52 137.61 -5388.3 4724.7 0.70 15094.71 13084.20 30.24 136.10 -5422.2 4756.5 0.88 15185.18 13162.20 30.56 134.67 -5454.8 4788.6 0.87 15279.60 13243.20 31.33 134.33 -5488.9 4823.3 0.84 15369.70 13320.0 31.80 132.70 -5521.3 4857.5 1.08 15438.60 13378.3 TD ( [:I EPOCH 71 Forest Oil Corporation Redoubt Unit #5 ( Measured Depth TVD Inclination Azimuth Coordinates Dog Leg Feet Feet Degrees Degrees N(+) S(-) E(+) W(-) Degrees/100' Be~in RU #5A 11384.39 9963.90 29.19 137.71 -3907.2 3451.8 0.00 11473.00 10041.40 28.86 138.11 -3939.1 3480.6 0.43 11493.35 10059.00 30.90 137.92 -3946.6 3487.4 10.04 11580.33 10131.20 36.79 137.08 -3982.3 3520.1 6.77 11636.81 10174.90 41.70 136.54 -4008.3 3544.6 8.71 11683.68 10209.90 41.70 136.42 -4030.9 3566. 1 0.17 11744.39 10255.00 42.51 138.54 -4060.9 3593.6 2.69 11780.91 10281.50 44.56 139.36 -4079.9 3610.1 5.82 11872.10 10344.50 47.92 139.57 -4130.0 3652.9 3.69 11966.51 10405.41 52.19 138.58 -4184.3 3699.9 4.59 12014.39 10433.70 54.52 137.63 -4213.2 3725.9 5.12 12108.35 10487.10 56.20 137.08 -4270.1 3778.3 1.85 12174.70 10523.50 57.32 137.31 -4310.8 3816.0 1.71 12263.35 10570.10 59.16 136.86 -4366.0 3867.3 2.12 12358.22 10618.00 60.31 136.65 -4425.7 3923.5 1.23 12451.78 10663.00 62.10 135.80 -4484.9 3980.2 2.07 12547.44 10706.50 63.77 136.03 -4546.1 4039.5 1.76 12643.58 10747.70 65.58 135.72 -4608.4 4100.0 1.91 ( 12735.35 10784.70 66.77 136.25 -4668.8 4158.3 1.40 12826.91 10820.40 67.33 136.97 -4730.1 4216.2 0.95 12924.35 10859.90 64.85 138.00 -4795.7 4276.4 2.72 13015.96 10900.50 62.62 138.95 -4857.2 4330.9 2.61 13109.55 10943.50 62.69 138.65 -4919.8 4385.6 0.29 13205.44 10987.70 62.36 138.05 -4983.3 4442.2 0.65 13299.82 11032.20 61.38 136.52 -5044.5 4498.6 1.77 13392.42 11076.00 62.19 134.74 -5102.8 4555.7 1.91 13485.24 11118.30 63.60 134.41 -5160.8 4614.5 1.55 13579.70 11160.10 63.84 133.06 -5219.3 4675.7 1.31 13671.92 11199.20 65.94 133.46 -5276.6 4736.6 2.31 13733.74 11224.90 64.99 133.77 -5315.4 4777.3 1.60 13771.97 11241.40 63.80 134.52 -5339.4 4802.0 3.58 13870.45 11285.40 63.17 134.58 -5401.2 4864.8 0.64 13967.04 11329.10 63.04 135.11 -5461.9 4925.9 0.51 14063.38 11372.00 64.09 136.19 -5523.6 4986.2 1.48 14156.68 11412.40 64.14 135.70 -5584.5 5044.2 0.48 14253.40 11454.60 64.09 136.34 -5647.1 5104.7 0.60 14347.74 11495.78 64.92 136.43 -5707.9 5163.4 0.88 14446.46 11538.57 63.70 136.81 -5772.6 5224.5 1.28 ( [:I EPOCH 72 8 Forest Oil Corporation Redoubt Unit #5 Measured Depth TVD Inclination Azimuth Coordinates Dog Leg Feet Feet Degrees Degrees N(+) S(-) E(+) W(-) Degrees/tOO' 14541.00 11581. 66 62.08 136.88 -5834.0 5282.1 1.72 14638.20 11628.22 60.78 136.71 -5896.2 5340.5 1.45 14732.75 11675.30 58.97 135.73 -5955.2 5397.0 2.01 14823.42 11722.80 57.80 134.38 -6010.6 5451.5 1.81 14919.38 11773.62 58.74 134.30 -6066.9 5510.0 0.90 15012.96 11821.43 59.81 134.17 -6123.0 5567.6 1.15 15105.91 11867.90 59.48 133.14 -6179.2 5625.6 1.06 15202.89 11917.20 59.52 133.88 -6236.7 5686.2 0.66 15295.24 11965.40 57.28 134.00 -6291.4 5742.9 2.53 15346.70 11993.53 57.64 130.76 -6318.1 5776.5 1.93 15442.29 12043.60 59.19 128.68 -6370.1 5839.1 2.46 15545.27 12096.00 58.97 129.08 -6426.4 5907.9 0.40 15637.42 12146.10 55.20 130.19 -6475.8 5967.5 4.21 15722.77 12195.02 54.89 133.90 -6522.5 6019.3 3.58 15840.72 12264.60 52.98 128.18 -6584.7 6091. 6 4.24 15935.10 12319.40 56.01 127.06 -6631.5 6125.5 3.35 16027.82 12370.20 57.55 133.64 -6681. 8 6211.5 6.16 16150.01 12433.40 60.36 143.51 -6760.3 6280.5 7.29 16216.47 12466.30 60.22 143.10 -6806.5 6315.0 0.58 ( 16307.00 125 11.40 60.10 140. 15 -6868.1 6363.8 2.83 16383.00 12548.50 61.41 143.81 -6920.3 6404.6 4.54 16409.62 12561.20 61.61 143.00 -6939.1 6418.5 2.78 16501.12 12604.92 61.32 140.29 - 7002.1 6468.4 2.62 16594.78 12649.90 61.30 139.12 -7064.8 6521.5 1.10 16690.66 12695.20 62.26 136.79 -7127.5 6578.1 2.36 16784.30 12738.20 63.31 135.46 -7186.7 6636.7 1.69 16875.22 12778.70 63.81 133.06 -7243.5 6695.0 2.43 16941.37 12807.10 65.30 132.39 - 7284.1 6738.9 2.43 17000.00 12831.60 65.30 132.39 -7320.0 6778.3 0.00 ~ EPOCH 73 Forest Oil Corporation Redoubt Unit #5 DAILY MUD PROPERTIES Date Depth Weight FV PV YP Gels APIFL Cake Solids OillWater Sand PH CI Ca 4/16/02 199 8.9 97 12 24 16/47/52 4.5 0/96 0.5 10.0 1250 80 4/17/02 1664 9.1 98 15 30 20/52/68 6.0 0/94 0.66 10.0 1200 120 4/18/02 2720 9.5 90 13 29 14/42/49 6.0 0/94 0.66 10.0 1200 120 4/19/02 3170 9.6 88 13 27 14/40/44 6.0 0/94 0.5 10.0 1200 120 4/20/02 3205 9.6 80 12 26 10/28/40 6.0 0/94 0.66 10.0 1200 100 4/21/02 3205 8.5 32 2 7 11.0 4/22/02 3205 8.5 32 2 7 11.0 4/23/02 3205 8.9 52 9 33 1 0/28/40 11.0 4/24/02 3205 8.8 42 8 32 9/23/36 11.0 RIG SHUT DOWN 4/25/02 TO 6/15/02 HTHP FL OIL BASE MUD IN HOLE 6/16/02 3204 9.2 155 21 19 15/25/28 6.0@250 NA/2 11.49 80/20 15000 6/17/02 4870 9.4 122 25 33 25/37/40 4.0@250 NA/2 11.37 80/20 18000 6/18/02 6171 9.5 104 25 29 23/37/40 4.4@250 NA/2 13.24 80/20 21000 6/19/02 6648 9.5 104 28 34 28/41/44 4.4@250 NA/2 12.40 81/19 17000 6/20/02 6670 9.4 139 26 29 25/34/37 4.8@250 NA/2 12.50 80/20 14500 6/21/02 6745 9.6 190 26 33 22/40/44 4.8@250 NA/2 14.45 79/21 16000 6/22/02 7498 9.4 122 30 36 32/45/47 5.0@250 NA/2 12.28 80/20 20000 6/23/02 7965 9.4 100 30 34 30/42/44 4.0@250 NA/2 12.28 82/18 20000 6/24/02 8760 9.3 96 25 28 26/37/39 8.0@250 NA/2 11.27 83/17 20000 6/25/02 9160 9.3 80 27 26 25/37/39 8.0@250 NA/2 11.25 85/15 20000 6/26/02 9207 9.5 101 30 27 23/30/32 9.0@250 NA/2 12.32 87/13 18000 6/27/02 9207 9.4 104 26 21 21/30/32 9.6@250 NA/2 12.42 86/14 16000 6/28/02 9207 9.7 95 29 30 29/38/40 10.0@250 NA/2 13.37 86/14 17000 6/29/02 9722 9.6 96 27 26 22/35/38 9.0@250 NA/2 12.11 86/14 23000 6/30/02 10238 9.5+ 97 28 27 22/43/48 8.8@250 NA/2 12.12 85/15 23000 7/1/02 10568 9.6 114 33 27 29/46/52 9.0@250 NA/2 12.09 84/16 24000 7/2/02 10767 9.6 121 34 22 30/48/50 8.6@250 NA/2 12.13 84/16 23000 7/2/02 10767 9.6 121 34 22 30/48/50 8.6@250 NA/2 12.13 84/16 23000 7/3/02 11 000 9.5+ 104 34 23 36/48/52 8.4@250 NA/2 12.22 84/16 21000 7/4/02 11 000 9.6 160 30 30 33/46/52 9.2@250 NA/2 12.31 85/15 19000 ~ EPOCH 74 '~ ~ ~ Forest Oil Corporation Redoubt Unit #5 Date Depth Weight FV PV YP Gels HTHP FL Cake Solids OillWater Sand PH CI Ca 7/5/02 11306 9.6 121 34 27 26/47/50 8.8@250 NA/2 13.22 84/16 21000 7/6/02 11638 9.65 151 38 27 30/50/56 8.8@250 NA/2 12.25 85/15 20000 7/7/02 11771 9.55 200 33 27 30/46/54 8.6@250 NA/2 12.25 85/15 20000 7/8/02 11952 9.6 145 40 26 32/43/48 8.8@250 NA/2 12.19 85/15 21500 7/9/02 12184 9.55 125 33 29 28/36/45 7.8@250 NA/2 12.35 86/14 17500 7/1 0/02 12353 9.6 147 36 25 27/42/56 7.8@250 NA/2 12.34 85/15 18000 7/11/02 12425 9.65 160 38 27 27/44/51 8.0@250 NA/2 12.24 85/15 20500 7/12/02 12683 9.55 136 39 27 30/48/55 7.6@250 NA/2 12.23 85/15 20500 7/13/02 12912 9.55 133 35 29 28/50/54 7.8@250 NA/2 12.19 85/15 21500 7/14/02 13085 9.55 147 35 27 27/48/52 7.6@250 NA/2 12.26 84/16 23500 7/15/02 13085 9.6 165 41 28 29/50/53 8.0@250 NA/2 12.13 84/16 23000 7/19/02 13085 9.6 215 36 30 25/56/60 8.0@250 NA/2 12.29 84/19 22500 7/20/02 13211 9.6 165 38 27 38/58/68 8.0@250 NA/2 12.38 84/16 20000 7/21/02 13486 9.6 142 41 29 34/54/64 7.0@250 NA/2 12.34 84/16 21000 7/22/02 13762 9.5 116 32 26 38/55/60 6.0@250 NA/2 11.84 84/16 21000 7/23/02 13950 9.6 113 36 29 34/55/58 5.4@250 NA/2 13.00 84/16 21000 7/24/02 13980 9.6 125 34 26 31/53/58 5.0@250 NA/2 13.34 85/15 21000 7/25/02 13980 9.7 225 34 26 31/53/59 5.0@250 NA/2 12.70 84/16 21000 7/26/02 13980 9.7 215 45 25 31/55/58 6.0@250 NA/2 12.94 79/21 18000 7/27/02 13980 9.6 155 38 29 31/50/55 5.0@250 NA/2 11.67 79/21 23000 7/28/02 14021 9.5 177 39 27 30/45/48 4.0@250 NA/2 11.17 80/20 23000 7/29/02 14052 9.5 200 39 28 31/46/49 4.0@250 NA/2 11.17 80/20 23000 7/30/02 14199 9.5 123 38 27 29/50/54 4.0@250 NA/2 11.02 82/18 26000 7/31/02 14513 9.4 85 31 20 22/42/46 4.0@250 NA/2 11.13 84/16 23000 8/01/02 14600 9.5 80 30 21 22/40/46 4.0@250 NA/2 11.20 86/14 21000 8/02/02 14715 9.5 84 29 21 20/39/44 4.0@250 NA/2 11.28 86/14 23000 8/03/02 14726 9.6 140 28 20 20/40/45 4.0@250 NA/2 11.60 86/14 23000 8/04/02 14860 9.4 103 30 19 19/38/42 4.0@250 NA/2 11.28 86/14 23000 8/05/02 14866 9.5 103 28 17 27/39/45 4.0~250 NA/2 11.25 86/14 24000 8/06/02 14866 9.4 130 28 17 27/39/45 4.0~250 NA/2 11.25 86/14 24000 8/07/02 14966 9.4 100 29 18 26/42/48 4.0@250 NA/2 10.75 85/15 24000 8/08/02 15200 9.45 90 29 19 21/42/44 4.0@250 NA/2 11.21 85/15 21000 [:I EPOCH 75 .~ ~ ~ Forest Oil Corporation Redoubt Unit #5 Date Depth Weight FV PV YP Gels HTHP FL Cake Solids OillWater Sand PH CI Ca 8/9/02 15438 9.45 92 29 18 14/38/41 4.0@250 NA/2 11.17 85/15 22000 8/10/02 15438 9.45 135 29 20 14/39/43 4.0@250 NA/2 11.17 85/15 22000 8/11/02 15438 9.6 153 24 29 18/39/42 4.0@250 NA/2 11.17 85/15 22000 8/12/02 15438 9.55 104 28 19 18/21/40 4.0@250 NA/2 11.17 85/15 22000 8/13/02 13722 9.6 116 29 19 19/39/41 4.0@250 NA/2 11.17 85/15 22000 8/14/02 13722 9.6 115 30 23 20/42/46 4.4@250 NA/2 11.17 85/15 22000 Begin RU #5A 8/15/02 11491 9.6 123 30 24 19/39/44 4.2@250 NA/2 11.17 85/15 22000 8/16/02 11500 9.6 117 30 21 19/39/42 4.2@250 NA/2 11.17 85/15 22000 8/17/02 11602 9.6 112 29 26 22/42/47 4.6@250 NA/2 11.10 85/15 23500 8/18/02 11870 9.5 97 31 22 20/44/46 4.0@250 NA/2 12.08 85/15 24000 8/19/02 12028 9.5 96 30 26 19/41/43 3.8@250 NA/2 12.12 85/15 23000 8/20/02 12028 9.5 108 30 22 19/41/43 4.0@250 NA/2 12.12 85/15 23000 8/21/02 12276 9.5 126 33 22 23/43/47 3.8@250 NA/2 12.08 85/15 24000 8/22/02 12758 9.5 102 37 23 18/40/46 4.4@250 NA/2 11.66 83/17 22500 8/23/02 13057 9.5 90 37 20 16/42/44 4.4@250 NA/2 11.13 84/16 23000 8/24/02 13398 9.5 86 28 22 15/34/38 4.0@250 NA/2 11.16 84/16 22500 8/25/02 13675 9.5 82 27 20 14/31/34 3.8@250 NA/2 11.18 84/16 22000 8/26/02 13800 9.5 85 28 18 16/34/40 3.6@250 NA/2 11.18 84/16 22000 8/27/02 13800 9.5 147 25 24 15/32/38 4.6@250 NA/2 11.18 84/16 22000 8/28/02 14141 9.55 81 25 20 15/34/38 3.8@250 NA/2 11.20 84/16 21500 8/29/02 14522 9.5 75 26 17 17/33/35 3.6@250 NA/2 11.78 85/15 23000 8/30/02 14865 9.5 78 24 22 17/32/35 3.8@250 NA/2 11.31 86/14 22000 8/31/02 15086 9.5 72 24 21 17/32/35 4.0@250 NA/2 11.34 84/16 21000 9/01/02 15285 9.5 79 26 19 19/35/41 4.0@250 NA/2 11.34 86/14 21000 9/02/02 15325 9.5 88 22 22 17/35/37 4.0@2250 NA/2 11.38 86/14 20000 9/03/02 15325 9.5+ 89 24 20 19/35/38 4.0@250 NA/2 12.50 88/13 20000 9/04/02 15325 9.5 88 26 18 18/34/37 4.0@250 NA/2 11.38 88/13 20000 9/05/02 15325 9.5 95 25 19 19/30/35 4.0@250 NA/2 11.38 88/13 20000 9/06/02 15325 9.6 130 24 20 20/31/36 4.0@2250 NA/2 11.88 87/13 20000 9/07/02 15325 9.5 96 23 18 21/31/40 4.0@250 NA/2 11 .44 88/13 18000 9/08/02 15325 9.5 120 23 19 21/32/41 4.0@250 NA/2 11 .44 89/11 18000 [:I EPOCH ~ ~' 76 ~ Forest Oil Corporation Redoubt Unit #5 Date Depth Weight FV PV YP Gels HTHP FL Cake Solids OillWater Sand PH CI Ca 9/09/02 15350 9.5 98 21 20 21/32/38 3.4@250 NA/2 11.41 86/14 19000 9/10/02 15425 9.4 130 25 19 20/33/39 3.4@250 NA/2 11.16 84/16 20000 9/11/02 15475 9.5 118 25 18 21/33/35 3.4@250 NA/2 11.38 85/15 20000 9/12/02 15485 9.5 140 24 20 21/34/38 3.4@250 NA/2 11.25 85/15 20000 9/13/02 15553 9.3 98 24 20 22/35/39 3.4@250 NA/2 10.38 84/16 20000 9/14/02 15675 9.3 96 26 20 21/33/37 3.4@250 NA/2 10.38 84/16 20000 9/15/02 15800 9.3 96 23 23 21/34/37 3.4@250 NA/2 9.85 84/16 18000 9/16/02 15838 9.4 106 26 19 20/35/37 3.4@250 NA/2 10.35 84/16 18000 9/17/02 15840 9.3 130 25 19 21/35/38 3.4@250 NA/2 9.85 83/17 18000 9/18/02 15906 9.4 104 27 20 22/34/37 3.4@250 NA/2 10.47 82/18 17000 9/19/02 15922 9.5 97 27 21 18/30/32 3.6@250 NA/2 11.34 85/15 18000 9/20/02 16021 9.4+ 99 26 21 16/28/31 3.4@250 NA/2 11.35 83/17 18000 9/21/02 16151 9.3+ 95 27 16 15/32/35 3.2@250 NA/2 10.35 83/17 18000 9/22/02 16193 9.3+ 107 25 17 14/32/34 3.2@250 NA/2 10.35 84/16 18000 9/23/02 16207 9.5 120 25 16 15/29/31 3.6@250 NA/2 11.44 84/16 18000 9/24/02 16335 9.3+ 91 26 15 14/28/29 3.4@250 NA/2 10.35 84/16 18000 9/25/02 16440 9.3 119 32 20 14/32/34 6.8@250 NA/2 10.57 73/27 13000 9/26/02 16490 9.4 104 30 18 14/28/32 4.8@250 NA/2 11.29 80/20 20000 9/27/02 16532 9.55 127 32 24 16/32/35 4.2@250 NA/2 11.23 75/25 22000 9/28/02 16753 9.45 105 29 22 14/30/34 4.0@250 NA/2 10.57 75/25 26000 9/29/02 17000 9.35 97 28 22 15/31/35 3.6@250 NA/2 9.8 80/20 31500 [:I EPOCH 77 ~ .~ ""-" Forest Oil Corporation Redoubt Unit #5 BIT RECORD Bit Grading I 0 D L B G 0 R N U U 0 E A T E N T L C A U H A E E L A R G E S R R T I E R 0 C I N N R R H 0 G C 0 0 A N S H P W W R A U S S R L L E D Bit No. Size Make Type SIN Jets Depth Depth Ftg Hrs Ave Ave Ave Ave (in) (32") In Out FtlHr Wob Rpm psi 1 18.5 STC MSDSHC LK4745 2x14 146' 3170' 3024' 40.01 115.1 19.2 51 2321 4 6 R G E 3 W T 2x20 9 t D 2rr2 18.5 STC MSDSHC Lk4744 3x18 3170' 3205' 35' 1.05 46 32 106 1957 2 3 W A E 2 G T 1x12 t R D 3 12.25 STC FGXICPS MJ8388 3x16 3205' 3205' 0' 0 0 0 0 0 1x12 3rr1 12.25 STC M05S0DG LR0149 3x22 3205' 3205' 0' 0 0 0 0 0 C 1x11 3rr2 12.25 STC M05S0DG LR0149 3x22 3205' 3205' O' 0 0 0 0 0 C 1x11 4 12.25 STC T&S MJ8388 3x18 3205' 6648' 3443' 50.39 105 26 94 2830 L 1x16 c 5 12.25 SEC ELC1N 755565 3x22, 6648' 6666' 18' .76 32 31 72 1765 1 1 In B 1x11 H A U EPOCH 78 ~ ~ ~. Forest Oil Corporation Redoubt Unit #5 6 12.25 STC M68HVPX JS 7943 4x16, 6666' 9207' 2541 ' 79.15 53 13 66 3077 7 8 R G X In L P 4x15 0 M R 7 12.25 STC MA62PX JS7232 3x22, 9207' 11000' 1793' 81.83 35.9 12.4 80.1 3348 3 3 W A X In C B 4x18 T T H A 8 12.25 SEC FM2765 5012815 3x22, 11000' 11771' 771' 31.04 46.0 15.1 59.5 3663 1 2 W G X In N P 4x18 T 0 R 9 12.25 STC 15GFDPS MJ5462 3x28, 11771' 12353' 582' 48.54 17.9 30 93 3651 2 3 W A E In N H 1x13 T 0 R 10 12.25 GEO MDT35HS JR9062 7x18, 12353' 13085' 732' 54.34 19.2 13.3 83 3594 2 4 B A X 1/ C R PX 2x16 T 1 T R 6 11 rr1 12.25 SEe FM2765 5012815 3x22, 13085' 13980' 895' 63.95 19.8 15.1 105 3666 2 4 B a X In W T 4x18 T T D DEPTH CaRR +5' 9rr3 8.5 HTC MXC1 Y22JX 3x22, 13986' 13991 ' 5' .15 92 15.4 58 3628 3 3 R G E In W C 1x10 G T P CB#10 8.5 DPI CMM34F 1964421 5x11, 13991' 14052' 61 5.84 14.5 13.7 59 1577 C 0 R E # 1 3x12 11 8.5 STC 20GFIDGP MM0034 3x22 14052' 14600' 609' 37.18 20 33.2 100 3031 6 2 B E In L H D T T R S 12 8.5 SEC FM2643r 5014266 6x20 14600' 14715' 115' 6.86 19.6 14.7 102 3477 1 1 W A X In N C T 0 P 1 Orr1 8.5 DPI CMM34F 1964421 5x11, 14715' 14726' 11.6' 2.3 9.2 11.1 68.5 1531 C 0 R E # 2 3x12 12rr1 8.5 SEC FM2643r 5014266 6x20 14726' 14860' 133' 12.35 20.5 15.2 104.5 3447 3 3 W A X In C C T T P 13 8.5 DPI CMM34F 1964422 5x11 , 14860' 14866' 6 2.88 12.3 5.6 59.5 1497 C 0 R E # 3 3x12 14 8.5 SEC FM2643r 5014265 6x20 14866' 15438' 572' 40.99 17.4 11.3 80.5 3410 2 5 B A X In C T T T D WELL PLUGGED BAC TO 1147 K 3 MILL 8.0 6C-7900 11473' 11493' 18' 9.04 6.2 18.8 101.0 2390 15 6.75 HTC EP4983 Y75JC 3x22 11493' 11500' 7' 1.05 4.7 17.8 101.4 2503 1 1 W A E In N B T a H A 16 8.5 STC GFiDGPD MM0119 3x18 11500' 12028' 528' 40.62 22.1 36.0 31.6 3136 8 8 c A F % L T R T Q ~ EPOCH 79 ~ ~ ~.' Forest Oil Corporation Redoubt Unit #5 17 8.5 SEC FM2643r 1038922 3x18, 12028' 13800' 1172' 96.21 28.2 15.1 68.8 3059 2 8 R H X In B H 7 3x22 0 T R s 18 8.5 GEO MGR29 J88365 4x18, 13800' 15325' 1532' 95.51 22.6 15.1 66 3363 3 4 W A X In C T YPX 4x16 T T D 19rr1 8.5 GEO MRG29PX J88365 4X18, 15325' 15325' 0 0 0 0 0 0 3 4 W A X In C C 4X16 T T 0 20 6.75 SEC FM2643r 5013316 3x18 15325' 15425' 100' 7.26 35.1 14.7 56 2302 0 1 W G X In N C t 0 p 21 6.75 DPI CMM 35F 1963909 15425' 15485' 60' 4.02 17.6 5.9 56 1704 20rr1 6.75 SEC FM2643r 5013316 3x18 15485' 15800' 315' 44.51 9.4 5.7 30 3184 4 4 W A X In B C T T p 22 6.75 DPI CMM35F 1963910 15819' 15840' 21' 8.11 3.3 8.0 61 1624 23 6.75 SEC FM2643r 5013317 3x18 15840' 15922' 82' 12.11 11.4 5.7 24 3220 2 8 R G X In W W 0 T R 24 6.75 STC XR32TD MK4146 3x18 15922' 16153' 231' 35.58 10.5 14.6 36.7 3047 3 3 B A E 1/ W H 2GPD T 1 T R 6 s 25 6.75 DPI CMM35F 2015653 16153' 16201' 53' 5.08 13.0 4.4 59.1 1693 26 6.75 STC XR32TD MK4142 3x18 16201' 16440' 233' 33.50 10.0 19.6 51.3 2131 3 3 B A E In W H 2GDP T T R s 27 6.75 SEC FM2643r WV0916 3x16 16440' 16532' 92' 9.11 12.1 8.8 68.8 3516 2 4 W A X In C D T T M F 28 6.75 GEO MA32QPX JS6335 3x14, 16532' 17005' 473' 35.89 16.2 9.1 72.4 3401 2 3 W A X In C T 3x12 T T D ~ EPOCH 80 ~ ~ ~ . '" Forest Oil Corporation Redoubt Unit #5 (, TIME DISTRIBUTION DATE DRILL TRIPP CASING RIG E-LOGS RIG-UPI COND BOP CUT& TEST CEMENT WORK MISC REPAIR SERVo MUD SLIP CASG BHA 4/15/02 2.5 4.0 9.5 1.0 7.0 4/16/02 21.0 2.0 0.5 0.5 4/17/02 21.5 2.5 4/18/02 13.0 2.5 2.5 1.0 4.5 0.5 4/19/02 1.0 3.5 12.0 0.5 2.5 4.5 4/20/02 3.5 0.5 10.5 5.5 4.0 4/21/02 1.5 21.0 1.5 4/22/02 1.0 4.5 1.5 1.5 8.5 2.0 4.5 0.5 4/23/02 3.0 8.0 8.0 4.0 1.0 4/24/02 1.0 12.0 11.0 6/15/02 2.5 3.0 0.5 11.5 1.0 6.5 6/16/02 23.0 0.5 0.5 6/17/02 23.5 0.5 6/18/02 17.5 4.0 2.0 0.5 6/19/02 13.5 1.0 2.0 9.5 6/20/02 2.5 8.5 3.5 3.0 1.0 5.5 6/21102 22.5 1.5 6/22/02 23.0 0.5 0.5 6/23/02 23.5 0.5 6/24/02 23.5 0.5 6/25/02 5.5 11.0 7.5 6/26/02 12.5 4.5 2.5 4.5 ( 6/27/02 7.0 7.0 10.0 6/28/02 23.5 0.5 6/29/02 22.5 1.5 6/30/02 24.0 7/1/02 16.0 5.5 2.5 7/2/02 19.0 0.5 4.5 7/3/02 14.0 2.0 1.0 2.5 4.5 7/4/02 12.0 9.0 3.0 7/5/02 22.0 0.5 1.5 7/6/02 10.0 7.5 1.5 5.0 717/02 15.5 5.0 1.5 2.0 7/8/02 23.5 0.5 7/9/02 16.5 3.5 0.5 3.5 7/10/02 4.0 10.5 2.5 2.5 0.5 7/11/02 23.5 0.5 7/12/02 23.5 0.5 7/13/02 3.0 17.5 1.0 2.5 7/14/02 8.5 14.5 1.0 7/15/02 24.0 7/16/02 2.5 18.0 3.5 TOTAL 488.5 168.5 15.5 67.5 0.0 22.5 70.5 55.5 3.0 4.0 7.0 34.5 70.0 WELL DRILLI TRIPPI CASIN RIG E-LOGS RIG-UPI COND BOP CUT& TEST CEMEN WORK MISC TOTAL 1209.3 640.3 66.0 147.0 73.0 81.0 219.5 89.8 5.0 6.5 7.0 86.5 102.3 !( [;I EPOCf=~ 8] Forest Oil Corporation Redoubt Unit #5 ( DATE DRILL TRIPP CASING RIG E-LOGS RIG-UPI COND BOP CUT& TEST CEMENT WORK MiSe REPAIR SERVo MUD SLIP CSG BHA 4/15/02 2.5 4.0 9.5 1.0 7.0 4/16/02 21.0 2.0 0.5 0.5 4/17/02 21.5 2.5 4/18/02 13.0 2.5 2.5 1.0 4.5 0.5 4/19/02 1.0 3.5 12.0 0.5 2.5 4.5 4/20/02 3.5 0.5 10.5 5.5 4.0 4/21/02 1.5 21.0 1.5 4/22/02 1.0 4.5 1.5 1.5 8.5 2.0 4.5 0.5 4/23/02 3.0 8.0 8.0 4.0 1.0 4/24/02 1.0 12.0 11.0 6/15/02 2.5 3.0 0.5 11.5 1.0 6.5 6/16/02 23.0 0.5 0.5 6/17/02 23.5 0.5 6/18/02 17.5 4.0 2.0 0.5 6/19/02 13.5 1.0 2.0 9.5 6/20/02 2.5 8.5 3.5 3.0 1.0 5.5 6/21/02 22.5 1.5 6/22/02 23.0 0.5 0.5 6/23/02 23.5 0.5 6/24/02 23.5 0.5 6/25/02 5.5 11.0 7.5 6/26/02 12.5 4.5 2.5 4.5 6/27/02 7.0 7.0 10.0 6/28/02 23.5 0.5 6/29/02 22.5 1.5 ( 6/30/02 24.0 7/1/02 16.0 5.5 2.5 7/2/02 19.0 0.5 4.5 7/3/02 14.0 2.0 1.0 2.5 4.5 7/4/02 12.0 9.0 3.0 7/5/02 22.0 0.5 1.5 7/6/02 10.0 7.5 1.5 5.0 717/02 15.5 5.0 1.5 2.0 7/8/02 23.5 0.5 7/9/02 16.5 3.5 0.5 3.5 7/10/02 4.0 10.5 2.5 2.5 0.5 7/11/02 23.5 0.5 7/12/02 23.5 0.5 7/13/02 3.0 17.5 1.0 2.5 7/14/02 8.5 14.5 1.0 7/15/02 24.0 7/16/02 2.5 18.0 3.5 TOTAL 488.5 168.5 15.5 67.5 0.0 22.5 70.5 55.5 3.0 4.0 7.0 34.5 70.0 WELL DRILLI TRIPPI CASIN RIG E-LOGS RIG-UPI COND BOP CUT& TEST CEMEN WORK Mise TOTAL 1252.3 555.0 50.0 148.0 26.5 66.0 205.5 123.3 6.0 10.5 14.0 94.8 158.3 (if, [:I EPOCE 82 Forest Oil Corporation Redoubt Unit #5 t ( DATE DRILL TRIPP CASING RIG E-LOGS RIG-UPI COND BOP CUT& TEST CEMENT WORK MISC REPAIR SERVo MUD SLIP CASG BHA 8/30/02 23.5 0.5 8/31/02 20.0 3.0 1.0 9/1/02 4.0 9.0 8.0 3.0 9/2/02 3.5 6.0 8.5 2.5 3.5 9/3102 2.0 12.0 5.0 5.0 9/4/02 13.0 4.5 3.0 3.5 9/5/02 9.5 10.5 0.5 3.0 0.5 9/6/02 7.0 8.5 8.5 917/02 17.5 1.0 5.5 9/8/02 13.3 5.5 0.5 3.0 1.7 9/9/02 5.3 8.5 0.5 0.5 7.0 0.8 1.5 9/1 0/02 3.0 11.3 1.0 3.8 2.3 2.8 9/11/02 1.5 21.5 1.0 9/12/02 20.0 1.0 3.0 9/13/02 24.0 9/14/02 19.0 2.0 3.0 9/15/02 4.5 18.0 1.5 9/16/02 6.5 10.5 0.5 3.5 3.0 9/17/02 8.8 4.5 6.0 1.0 3.8 9/18/02 13.0 7.0 4.0 9/19/02 14.0 4.8 4.0 1.3 9/20/02 23.5 0.5 9/21/02 4.0 12.0 1.0 1.0 4.0 2.0 9/22/02 4.0 12.5 3.0 4.0 0.5 9/23/02 18.5 1.0 1.0 3.5 9/24/02 17.5 5.5 1.0 !( 9/25/02 5.5 12.5 1.0 0.5 4.5 9/26/02 5.0 13.0 0.5 0.5 5.0 9/27/02 17.0 5.5 0.5 1.0 9/28/02 9/29/02 TOTAL 275.3 218.0 19.0 13.0 26.5 21.0 64.5 12.3 0.0 2.5 0.0 25.8 18.3 WELL DRILLI TRIPPI CASIN RIG E-LOGS RIG-UPI COND BOP CUT & TEST CEMEN WORK MISC TOTAL 1252.3 555.0 50.0 148.0 26.5 66.0 205.5 123.3 6.0 10.5 14.0 94.8 158.3 ¡( ~ EPOCI-:~ 83 1% 5% ,-~ l'.~ .. . $l:~..A'':: Forest 011 Corporation Redoubt Unit #5 ~.__._-~--------~--~-~--------~--------------~- RU #5 & RU #5A TIME DISTRIBUTION [] DRILLING 0 CASING mTRIPPING 0 RIG-UP! SERVICE 0 COND MUD DSOP 0 CEMENTING 0 WORK BHA Em Mise -------------~----- 6% 3% 20% [~ EPOCH ~. DRIG REPAIR . CUT & SLIP 14 E-LOGS 0 TEST CASG --- >. 47% 84 .--<